The URL can be used to link to this page

Home My WebLink About217-0147. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 15-32C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 217-104 50-029-22462-03-00 ADL 0028306 11277 Conductor Surface Intermediate Liner Liner 8906 80 3492 8292 370 2843 8160 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/4" x 2-7/8" 8156 38 - 118 38 - 3530 35 - 8327 8165 - 8535 8434 - 11277 2700 38 - 118 38 - 3530 35 - 8319 8161 - 8514 8421 - 8906 10857 470 2260 4760 5410 10530 9405, 10150, 10810, 10857, 11208, 11235 1490 5020 6870 7240 10160 7951 - 11234 4-1/2" 12.6# 13Cr80 41 - 79447949 - 8906 Structural 4-1/2" HES TNT , 7819 , 7817 No SSSV Date: Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY 11/01/2025 Current Pools: PUT RIVER Proposed Pools: PUT RIVER Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:15 pm, Oct 14, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.10.14 16:01:26 - 08'00' Bo York (1248) 325-630 CDW 10/21/2025 A.Dewhurst 22OCT25 11/01/2025 10-404 DSR-10/15/25WCB 10-27-2025 Test tree saver, IA PRV, and pump kickouts to the set pressures listed in table. JLC 10/27/2025 10/28/25 FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03-00 Well Name:15-32C Permit to Drill:217-104 Current Status:Operable, Producer API Number:50-029-22462-03-00 Estimated Start Date:November 1 th, 2025 Estimated Duration:7 days IOR:524 Rig:EL, Frac, CT, SL, Test AFE:252-00614 Cost:$650,000 Regulatory Contact:Carrie Janowski Sundry Number: First Call Engineer:Jerry Lau (907) 564-5280 (O)(907) 360-6233 (M) Second Call Engineer:Leif Knatterud (907) 564-4667 (O)(432) 227-4342 (M) Program Revision:Original Current Bottom Hole Pressure:4025 psi @ 7900 TVDss From 15-32C on 8/13/25 Max Anticipated Surface Pressure:2700 psi Based on 0.168 psi/ft gas gradient Put River Western Lobe KWF: 9.80 ppg Last SI WHP:2600 psi (09/24/2025) Min ID:3.725 XN Nip @ 7932 MD (After dropping TCP assembly) Max Angle:5 deg @ 7932 MD Brief Well Summary: A reservoir P&A was completed in July 2025. In July 2025, a UHRC RWO was performed to place production packer above the Western Lobe of the Put River and run new 4-1/2 TBG. Post rig, the packer was set and well was MITd. TCP guns hanging from the completion on the TBG tail were pressure actuated to perforate the target interval. Objectives: Perform pre Frac MIT-T Cut to drop TCP guns into the rat hole and below bottom perforation Frac Put River Western Lobe sands in 15-32C Perform FCO and Flowback via portable test separator Current Status: Operable Well Completion Information: Wellhead: FMC, 13-1/2 x 4-1/2 TC-II tubing hanger Recent Integrity: 8/02/2025 MIT-T Passed to 3802 psi (We will get a passing test to 4500 psi or greater prior to frac) 08/02/2025 MIT-IA Passed to 3155 psi 02/24/2025 PPPOT-IC Passed to 3500 psi 02/24/2025 PPPOT-T Passed to 5000 psi E-Line 1. Perform mechanical cut to drop TCP assembly fish into rat hole. a. The 70 fish will fall 84 and land atop TBG stub at 8100. This will put the top of fish at 8030, which is 19 below the bottom perf at 8011. GR/CCL logs from TBG cut and completion space out were used to correlate depths. b. Northern solutions designed a cut to release triple connection with the single upper connection hanging off the upper completion and two connections facing down. The outer downfacing FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 connection is hanging off a 5.5 joint with a muleshoe and the inner downfacing connection is hanging off a 4.5 joint with the TCP assembly. Welltech will space-out a no-go collar on their cutter BHA to land on the XN nip to ensure the inner string is cut at the target depth. Slickline + Fullbore 1. Set DGLVs, Set a BHP gauge in bottom mandrel. 2. MIT-T to 4500 psi Frac 1. Spot water tanks and fill with fresh water a. Heat water to 90 degF b. Minimum pumping temp for water: 80 degF 2. Pull water from each tank and have SLB lab test our water quality: a. pH - ~7 i. Higher pH delays the hydration of the gel and delays break b. Calcium/magnesium <500 mg/l i. Mg/Ca Negative side effects in the formation such as carbonate deposits, which tend to be insoluble c. Bicarbonate - <400 mg/l i. High bicarbonate levels will cause slow hydration times and elevated delay times with X- linking fluids. If we have elevated bicarbonate levels and have introduced delay agents, it could have an exponential effect in delay times. d. Chlorides-<10,000 mg/l i. This fluid system should be able to cope with elevated Chloride levels e. Iron (Fe+3) - <5 mg/l i. Elevated Iron concentrations exist, the ammonium persulfate (breaker) can have an accelerated effect. Can cause viscosity degradation in linear gels (especially if batch mixed). Also can interfere with X-linking b/c iron will tie up the X-linking sites. f. TDS minimal/<5000 i. Effects depend on the solids that are dissolved in the fluid. 3. RU and set tree saver 4. RU SLB Frac 5. Ensure frac fluid QAQC has been agreed on with OE 6. Perform pressure tests prior to performing hydraulic fracture stimulation. a. Pressure test surface lines and tree saver to 7,790 psi. b. Pressure test pump kick outs to 6,450 psi. c. Pressure test IA Pop-Off system to ensure functioning properly. IA Pop-Offs to be set at 2,995 psi. d. Bring IA pressure up and hold at 2,700 psi. 7. Pump the hydraulic fracture stimulation per the proposed pump schedule below. Maximum allowable treating pressure is 6,790 psi. 8. RDMO SLB frac, flowback equipment, and tree saver. MIT-T to 4500 psi FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Pump Schedule Pressures MIT-T 4,500 psi MIT-IA 3,155 psi Maximum Anticipated Treating Pressure:5,600 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA): 2,995 psi IA Minimum Hold Pressure (POP-off ~300 psi):2,700 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T/1.1): 6,790 psi w/ 2,700 psi on IA Stagger Pump Kickouts Between 90 95% of MATP: 6,110 psi 6,450 psi N2 POP-off set pressure (MATP): 6,790 psi Treating Line Test Pressure (MATP + 1000 psi): 7,790 psi OA Pressure:Maintain open bleed on OA Max Anticipated Proppant Loading:6 PPA FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Coil 1. Contingent Post Frac FCO Slickline 1. Install LGLVs 2. Swap out BHPG Testers: 1.MIRU portable testers and line heater 2.Utilize poor boy gas lift if needed 3.Flowback into LP via adjacent flowline. 4.Slow bean up 5.Continue flowing back until production is less than 0.5% solids and 1% WC Attachments Current Wellbore Schematic Wellbore Schematic after dropping TCP assembly Reference Log for Put River Perforations and Formation Tops Sundry Revision Change Form FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Current Wellbore Schematic: FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Wellbore Schematic after dropping TCP assembly FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Reference Log for Put River Perforations and Formation Tops FRAC Put River Western LobeWell: 15-32CPTD: 217-104API: 50-029-22462-03Sundry Revision Change Form:Changes to Approved Sundry ProcedureDate:Subject:Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApprovalReceived (Personand Date)Approval:Operations Manager DatePrepared:Operations Engineer Date FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 1 Date: October 14, 2025 Subject: 15-32CC Fracture Stimulation From: Jerry Lau O: (907) 564-5280 C: (907) 360-6233 To: AOGCC Estimated Start Date: 11/01/2025 Attached is Hilcorps proposal and supporting documents to perform a fracture stimulation on well 15-32C (PTD #217-104) in the Western Lobe of the Put River Reservoir of the Prudhoe Bay Unit. The objective of this program is to perform a single stage fracture stimulation to the existing Put River perforations to improve well performance. 15-32C was recently recompleted as a Put River Western Lobe producer, previously an Ivishak producer. The Ivishak perforations were plugged on 7/16/2025 with cement filling the Ivishak production liner. Isolation from the Ivishak was demonstrated with a state witnessed passing MIT-T on 7/20/2025. The Put River interval was recompleted and perforated on 07/01/2025. Hilcorp requests a variance to sections 20 AAC 25. 283, a, 3- 4 which require identification of fresh - water aquifers and a plan for base-water sampling. Please direct questions or comments to Jerry Lau. FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 2 SECTION 1 - AFFIDAVIT (20 AAC 25.283, a, 1): Below is an affidavit stating that the owners, landowners, surface owners and operators identified on a plat within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283, a 1 FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 3 SIGNED AFFIDAVIT: FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 4 COPY OF NOTIFICATION SENT VIA EMAIL: FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 5 SECTION 2 - PLAT IDENTIFYING ALL WELLS WITHIN ½ MILE (20 AAC 25.283, a, 2): Plat of wells within one-half mile at surface. This includes the entirety of Drillsite 15. There are no additional wells from other drillsites within the one-half mile radius. FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 6 LIST OF WELLS IN PLAT WITHIN ½ MILES ON SURFACE (20 AAC 25.283, a, 2, C): 192 wells CDW 10/21/2025 FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 7 SECTION 3 and 4 - EXEMPTION FOR FRESWATER AQUIFERS and PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS (20 AAC 25.283, a, 3-4): Well 15-32C is located in the Eastern Operating Area of Prudhoe Bay (AIO 4G, 2015). Conclusion #10 (Area Injection Order 4A, August 12, 1993, Page 5) states that No underground sources of drinking water (USDWs) are known to exist in the Eastern Operating Area of the Prudhoe Bay Unit. Area Injection Order 4G, October 15, 2015, Page 3 states that All information related to AIO 4, AIO 4A, AIO 413, AIO 4C, AIO 4D, AIO 4E and AIO 4F is hereby incorporated by reference into the record for this order. Based on the Area Injection Order sections referenced above, Hilcorp requests exemption from 20 AAC 25. 283, a, 3- 4 which require identification of freshwater aquifers and establishing a plan for base-water sampling. Exemption not approved. See attached emails for freshwater aquifer and offset water well information. -A.Dewhurst 22OCT25 FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 8 FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 9 SECTION 5 - DETAILED CEMENTING AND CASING INFORMATION (20 AAC 25.283, a, 5): All casing is cemented and tested in accordance with 20 AAC 25.030, g when completed. See wellbore schematic for casing details: FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 10 FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 11 SECTION 6 - ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL (20 AAC 25.283, a, 6): Summary: 9-5/8 Production CSG: The original completion documents indicate that the primary cement job on the 9-5/8 casing went as followed: 241 bbls of cement were pumped, plug did not bump, floats held. Tagged CMT 125 above float collar. After backing out 125 of cement from tag and 82 of shoe tract for a total of 207, it was determined that 226 bbls made it behind pipe. The volumetric TOC including 30% washout calculates TOC at 5210 behind 9-5/8 CSG. This calculation was previously verified by AOGCC during the 15-32C sundry #325-353 approval process. The CSG was pressure tested to 3500 psi after cementing. 7 Production LNR: Cemented with57 bbls of Class G cement, 33% excess when backing out liner lap volume. The original completion documents report circulating out 25 bbls of cement returns after pumping primary job. Estimated TOC at 8165 top of liner. The LNR was pressure tested to 3500 psi after cementing. 4-1/2 x 7 Annulus Cement Squeeze In preparation for a dual string exit for the 15-32C sidetrack, service coil squeezed the 4-1/2 x 7 annulus from tubing punch holes at 8176 to beneath the 15-32C KOP of 8535. A 5/27/25 CBL found excellent cement coverage from the top of 3-1/2 15-32C sidetrack CTD liner at 8427 up to TOC at 8157, which is 8 above the 7 top of production liner. 15-32C CTD LNR 2017 CTD sidetrack exited parent bore at 8,535, not affecting isolation within confining zones of job scope. Ivishak Reservoir Abandonment 2-7/8 4-1/2 Cement plug Coiled Tubing downsqueezed 12 bbls 15.3 ppg Class G cement through retainer at 8225, 2 bbls excess on 7/16/25 to cement wellbore from retainer to 9405 with 3000 psi of squeeze pressure then laid 2 bbls atop retainer. Final TOC was 8160 MD, slickline tagged at 8129 SLM with AOGCC witness on 7/20/25 Prior wellbores 15-32 parent 7 LNR perforations, 15-32A CTD sidetrack and 15-32B sidetrack were previously P&Ad and are further isolated by the completed Ivishak Reservoir Abandonment of the 15- 32C sidetrack cement plug. FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 12 SECTION 7 - PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASINGS AND TUBING INSTALLED IN THE WELL (20 AAC 25.283, a, 7): Post RWO, the tubing was pressure tested to 3,802 psi with a MIT-T and the IA was pressure tested to 3,155 psi with a MIT-IA. Anticipated pressures in the table below assume a passing MIT-T of 4500 psi or more, which will be performed prior to pumping a hydraulic fracturing stimulation. The production casing annulus pressure will be monitored during the frac, if any change of pressure is seen outside of thermal expansion, the job will be flushed and the pressure source diagnosed before frac operations continue. Anticipated Pressures: MIT-T 4,500 psi MIT-IA 3,155 psi Maximum Anticipated Treating Pressure:5,600 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA):2,995 psi IA Minimum Hold Pressure (POP-off ~300 psi):2,700 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T/1.1): 6,790 psi w/ 2,700 psi on IA Stagger Pump Kickouts Between 90 95% of MATP:6,110 psi 6,450 psi N2 POP-off set pressure (MATP):6,790 psi Treating Line Test Pressure (MATP + 1000 psi): 7,790 psi OA Pressure: Maintain open bleed on OA Max Anticipated Proppant Loading: 6 PPA FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 13 SECTION 8 - PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD (20 AAC 25.283, a, 8): Wellbore Tubular Ratings Size/Name Weight Grade Burst, psi Collapse, psi 13-3/8 Surface Casing 68#L-80 5,020 2,260 9-5/8 Production Casing 47#L-80 6,870 4,760 4-1/2 Production Tubing 12.6#L-80 8,430 7,500 Wellhead FMC manufactured wellhead 5,000 psi. Tubing head adaptor: 13-5/8" 5,000 psi x 4-1/16" 5,000 psi Tubing Spool: 13-5/8 5,000psi w/ 2-1/16 side outlets Casing Spool: 13-5/8 5,000psi w/ 2-1/16 side outlets Tree: CIW 4-1/16 5,000psi -A 10,000-psi rated TreeSaver will be used during the fracturing operation. FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 14 SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES (20 AAC 25.283, a, 9): *Depths are taken from 15-32C FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 15 SECTION 10 LOCATION, ORIENTATION, AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE (20 AAC 25.283, a, 10): The map shows a gold one-half mile radius around the 15-32C transection of Put River formation. All wells transections of the Put River formation within the area of review are shown in Purple. These wells show the Put River formation within logs with the exception of 15-03. The Proposed frac is modeled with 281 half lengths. A 281 radius circle in light purple shows the modeled half length radius. A black line within the half length radius shows the most likely orientation of the frac, which is 10 deg W of N. No seismic faults were identified within the area of review. 15-01 15-01A 15-01B 15-03 15-04B15-04BPB1 15-06A 15-06APB1 15-08APB1 15-08APB2 15-08CL1 15-12 15-12A 15-12APB 15-12BPB1 15-13 15-14A 15-19 15-20 15-20A 15-20APB1 15-20B 15-20C 15-2415-24PB1 15-32 15-32A 15-32B 15-32BPB1 15-32C 15-32PB1 15-39 15-39A 15-43 8 15-48A 15-48B 15-49A 15-06 15-05 15-27 15-43 15-19 15-08A 15-26 15-20 15-20B15-39-04 1515-03 15-48 15-39A 15-32 15-2315-23A 15-31 15-24 15-47 15-13 15-38 15-1215-01 5-02 15-02B 15-12B 673500 674000 674500 675000 675500 676000 676500 677000 677500 678000 678500 679000 679500 673500 674000 674500 675000 675500 676000 676500 677000 677500 678000 678500 679000 679500 0 1000 2000 3000 4000 5000ftUS 1:8389 1 5-3 2C 1 /2 Mile AOI Su rface Map 1:8389 10/08/2025 Proposed frac location in white square. Brown circle has 1/2 mile radius around frac location. FRAC Put River Western LobeWell: 15-32CPTD: 217-104API: 50-029-22462-03Page 16Casing and Cement assessments for all wells that transect the confining zone (AOR): FRAC Put River Western LobeWell: 15-32CPTD: 217-104API: 50-029-22462-03Page 17 48 bbls ceme nt pump ed, 44.5 bbls calcul ated behin d pipe. See attach ed email. - A.De whurs t 22OC T25 FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 18 SECTION 11 - LOCATION OF, ORIENTATION OF, AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFING ZONES (20 AAC 25.283, a, 11): Hilcorps technical analysis based on seismic, well, and other subsurface information available indicated that there are no faults transecting the confining zones within the area of review. FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 19 SECTION 12 PROPOSED HYDRAULIC FRACTURING PROGRAM (20 AAC 25.283, a, 12): Proposed Procedure: 1. Conduct safety meeting, inspect location, and review 10-403. 2. Ensure all pre-frac well work has been completed, and the tubing & IA are freeze protected. 3. MIRU frac equipment and associated frac tanks. 4. Pressure test surface lines to at least 7,790 psi. 5. Test IA Pop-off system to ensure functioning properly. IA Pop-off to be set at 2,995 psi. 6. Bring IA pressure up to a hold pressure of 2,700 psi. 7. Pump the fracture stimulation per the proposed pump schedule below. Maximum allowable treating pressure is 6,790 psi. 8. RDMO frac equipment. Ensure tubing is freeze protected. 9. Return the well to production / flowback post slickline gas lift and contingent coiled tubing cleanout. Fracture Stimulation Pump Schedule: There are two overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are staggered between 90% and 95% of the maximum allowable treating pressure. 2) There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 20 Frac Dimensions: Frac #MD Location, ft TVDss top, ft TVDss Bottom, ft Frac Half-Length, ft 1 7,960-7,995-7,887 -7,922 ~281 Frac Modelling: Maximum Anticipated Treating Pressure: ~5,600 psi Surface pressure and fracture dimensions were modeled using 15-47 logs Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Hilcorp is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 21 Pre-Job Anticipated Chemicals to be pumped: Additive Additive Description F103 Surfactant 1.0 Gal/mGal 71.9 gal J475 Breaker J475 6.0 lb/mGal 431.4 lbm J511 Stabilizing Agent 2.0 lb/mGal 143.8 lbm J532 Crosslinker 2.5 Gal/mGal 179.8 gal J580 Gel J580 30.0 lb/mGal 2,157.1 lbm L065 Scale Inhibitor 1.0 Gal/mGal 71.9 gal L071 Clay Control Agent 2.0 Gal/mGal 143.8 gal M275 Bactericide 0.5 lb/mGal 36.0 lbm S522-1620 Propping Agent varied concentrations 60,000.0 lbm S526-1620 Propping Agent varied concentrations 95,000.0 lbm ~ 79 % ~ 21 % < 1 % < 1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.1 % < 0.01 % < 0.01 % < 0.01 % < 0.01 % < 0.01 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % < 0.0001 % 100 % 64-19-7 Acetic acid (impurity) Total * Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third- parties. * The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. 14464-46-1 Cristobalite 14808-60-7 Quartz, Crystalline silica 127-08-2 Acetic acid, potassium salt (impurity) 111-46-6 2,2''-oxydiethanol (impurity) 1310-73-2 Sodium hydroxide (impurity) 7447-40-7 Potassium chloride (impurity) 14807-96-6 Magnesium silicate hydrate (talc) 9002-84-0 poly(tetrafluoroethylene) 7786-30-3 Magnesium chloride 7631-86-9 Silicon Dioxide (Impurity) 10377-60-3 Magnesium nitrate 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 91053-39-3 Diatomaceous earth, calcined 10043-52-4 Calcium chloride 112-42-5 1-undecanol (impurity) 25038-72-6 Vinylidene chloride/methylacrylate copolymer 68131-39-5 Ethoxylated Alcohol 7647-14-5 Sodium chloride 67-63-0 Propan-2-ol 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 50-70-4 Sorbitol 107-21-1 Ethylene Glycol 129898-01-7 2-Propenoic acid, polymer with sodium phosphinate 56-81-5 1, 2, 3 - Propanetriol 7727-54-0 Diammonium peroxodisulphate 1303-96-4 Sodium tetraborate decahydrate 66402-68-4 Ceramic materials and wares, chemicals 9000-30-0 Guar gum 67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride CAS Number Chemical Name Mass Fraction - Water (Including Mix Water Supplied by Client)* YF130ST:WF130 71,904 gal Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. Fluid Name & Volume Concentration Volume FRAC Put River Western Lobe Well: 15-32C PTD: 217-104 API: 50-029-22462-03 Page 22 SECTION 13 - POST FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN (20 AAC 25.283, a, 13): After the fracture stimulation and potentially during the post frac coil fill cleanout, the well will be put on production through a portable well test separator. All liquids will be captured and either sent to production facilities or diverted to flowback tanks if solids percentage becomes too high for our production facility to manage. The initial flowback period is intended to produce back the fracture fluids to tanks as quickly as possible, until the well is produced less than 0.5% solids, at which time the produced fluids meet the FS3 acceptance criteria for start-up. There will be a tank farm on pad to store the produced fluids from flowback operations. The flowback fluids not suitable for FS3 processing will be hauled to another facilitys slop tank for additional settling time and/or disposal. Hilcorp will work to separate and recover fluid that meets the facility specification for the flowback fluids. A fluid manifest form will be completed for each load trucked offsite. 20 AAC 25.283 Hydraulic Fracturing Application Checklist PBU 15-32C (PTD No. 217-104; Sundry No. 325-630) Paragraph Sub-Paragraph Section Complete? AOGCC Page 1 October 22, 2025 (a) Application for Sundry Approval (a)(1) Affidavit Provided with application. A.Dewhurst 16OCT25 (a)(2) Plat Provided with application. A.Dewhurst 16OCT25 (a)(2)(A) Well location Provided with application. Well lies in Section 22 of T11N, R14E, UM. A.Dewhurst 16OCT25 (a)(2)(B) Each water well within ½ mile Provided in supplementary email. No water wells. A.Dewhurst 22OCT25 (a)(2)(C) Identify all well types within ½ mile Provided with application. Hilcorp has identified 64 wells within a ½-mile. A.Dewhurst 16OCT25 (a)(3) Freshwater aquifers: geological name; measured and true vertical depth Provided in supplementary email. No freshwater aquifer. A.Dewhurst 22OCT25 (a)(4) Baseline water sampling plan None required. A.Dewhurst 22OCT25 (a)(5) Casing and cementing information Provided with application. Proposed schematic attached, as built included. CDW 10/21/2025 (a)(6) Casing and cementing operation assessment 13-3/8 surface casing cemented to surface. 9-5/8 casing cemented with volumetric top (30% excess) calculated as 5210 ft. 4.5x7 annulus. Cement squeeze process. TD TOC CBL 8157 ft (8 ft above 7 liner top. 4.5 tubing will be anchored with a retrievable packer set at approx. 7819 ft with perforations of 7951-8011 ft. CDW 10/21/2025 (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 No freshwater aquifers present. (See Section (a)(3), above.) A.Dewhurst 22OCT25 (a)(6)( B) Each hydrocarbon zone is isolated Yes, cement isolates each hydrocarbon zone. A.Dewhurst 22OCT25/ 20 AAC 25.283 Hydraulic Fracturing Application Checklist PBU 15-32C (PTD No. 217-104; Sundry No. 325-630) Paragraph Sub-Paragraph Section Complete? AOGCC Page 2 October 22, 2025 Put River is shallowest HC zone and is target of this hydraulic fracture. Put River is isolated by 9-5/8 intermediate casing cement. (a)(7) Pressure test: information and pressure-test plans for casing and tubing installed in well Provided with application. 3155 psi MITIA, 4500 psi MITT. CDW 10/21/2025 (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPE, treating head Provided with application. 10K psi treesaver, max. frac. Pressure 6790 psi. Pump knock out 6110-6450. Psi, N2 POP-off 6790 psi., treesaver test 7790 psi, lines test 7790 psi. CDW 10/21/2025 (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (a)(9)(E) Fracture pressure for each zone Upper confining zone: HRZ shale with a TVT of ~200 and an anticipated fracture gradient of 0.883 psi/ft. Fracturing Zone: Put River sandstone with a TVT of 70 and an anticipated fracture gradient of 0.726 psi/ft. Lower confining zone: Kingak shale with a TVT of ~250 and an anticipated fracture gradient of 0.889 psi/ft. Detailed depths are provided in the application. A.Dewhurst 22OCT25 (a)(10) Location, orientation, report on mechanical condition of each well that may transect the confining zones and sufficient information to determine wells will not interfere with containment of hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory It is highly unlikely that any of the wells or wellbores within a ½-mile radius will interfere with hydraulic fracturing fluids from this operation because of cement isolation and / or separation distance. There are 18 parent wells (not including child sidetracks and plugbacks) within ½ mile of PBU 15-32C that penetrate the confining intervals. AOGCC evaluated all wells that may transect the confining zones within the PBU 15-32C Area of Review and found it highly unlikely that any of these wells will interfere with fracturing fluids due to cement-isolation and/or separation distance or direction. A.Dewhurst 22OCT25/ CDW 10/21/2025 20 AAC 25.283 Hydraulic Fracturing Application Checklist PBU 15-32C (PTD No. 217-104; Sundry No. 325-630) Paragraph Sub-Paragraph Section Complete? AOGCC Page 3 October 22, 2025 (a)(11) Faults and fractures, Sufficient information to determine no interference with containment of the hydraulic fracturing fluid within ½ mile of the proposed wellbore trajectory None. The operator has not identified any faults or fracture zones through seismic or well data within a ½-mile radius of PBU 15-32C. It is therefore unlikely that any faults will interfere with containment of the injected fracturing fluids; however, if there are indications that a fracture has intersected a fault or natural-fracture interval during frac operations, the operator will go to flush and terminate the stage immediately. A.Dewhurst 20OCT25 (a)(12) Proposed program for fracturing operation Provided with application. CDW 10/21/2025 (a)(12)(A) Estimated volume Provided with application. 2000 bbl total dirty vol. 155K lb total proppant CDW 10/21/2025 (a)(12)(B) Additives: names, purposes, concentrations Provided with application. CDW 10/21/2025 (a)(12)(C) Chemical name and CAS number of each Provided with application. Schlumberger disclosure provided. CDW 10/21/2025 (a)(12)(D) Inert substances, weight or volume of each Provided with application. CDW 10/21/2025 (a)(12)(E) Maximum treating pressure with supporting info to determine appropriateness for program Simulation shows max estimated treating pressure of 5600 psi. Max. 6790 psi allowable treating pressure. Max pressure is 6110 psi to 6450 psi to Pump shutdown, N2 POP-off 6790 psi. With 2700 psi back pressure IA (IA popoff set 2995 psi), max tubing differential should be 4090 psi. CDW 10/21/2025 (a)(12)(F) Fractures height, length, MD and TVD to top, description of fracturing model Provided with application. The anticipated half-length of the induced fracture is 281 according to the Operators computer simulation. The anticipated height of the induced fracture will be about 35. It should not penetrate through either of the confining intervals. A.Dewhurst 20OCT25 (a)(13) Proposed program for post-fracturing well cleanup and fluid recovery Well cleanout and flowback procedure provided with application. Disposal options discussed. CDW 10/21/2025 20 AAC 25.283 Hydraulic Fracturing Application Checklist PBU 15-32C (PTD No. 217-104; Sundry No. 325-630) Paragraph Sub-Paragraph Section Complete? AOGCC Page 4 October 22, 2025 (b)Testing of casing or intermediate casing Tested >110% of max anticipated pressure 2700 psi back pressure, plan to test to 3155 psi, popoff set as 2995 psi CDW 10/21/2025 (c) Fracturing string (c)(1) Packer >100 below TOC of production or intermediate casing 4.5 tubing will be anchored with a retrievable packer set at approx. 7819 ft with perforations of 7951-8011 ft. 13-3/8 surface casing cemented to surface. 9-5/8 casing cemented with volumetric top calculated as 5210 ft. TD TOC CBL 8157 ft (8 ft above 7 liner top. No cement concerns for stimulation. CDW 10/21/2025 (c)(2) Tested >110% of max anticipated pressure differential Tubing test of 4500 psi. Max pressure differential is estimated as 4090 psi (6790 with 2700 psi backpressure) so test of 4500 psi satisfies 110% CDW 10/21/2025 (d) Pressure relief valve Line pressure <= test pressure, remotely controlled shut-in device 7790 psi line pressure test, pump knock out 6110 and 6450 psi with max. global kickout 6790 psi. IA PRV set as 2995 psi. CDW 10/21/2025 (e) Confinement Frac fluids confined to approved formations Provided with application. CDW 10/21/2025 (f) Surface casing pressures Monitored with gauge and pressure relief device IA PRV set at 2995 psi. Surface annulus open. Frac pressures continuously monitored. CDW 10/21/2025 (g) Annulus pressure monitoring & notification 500 psi criteria During hydraulic fracturing operations, all annulus pressures must be continuously monitored and recorded. If at any time during hydraulic fracturing operations the annulus pressure increases more than 500 psig above those anticipated increases caused by pressure or thermal transfer, the operator shall: CDW 10/21/2025 (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (h) Sundry Report 20 AAC 25.283 Hydraulic Fracturing Application Checklist PBU 15-32C (PTD No. 217-104; Sundry No. 325-630) Paragraph Sub-Paragraph Section Complete? AOGCC Page 5 October 22, 2025 (i) Reporting (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (j) Post-frac water sampling plan Not required (see Section (a)(3), above). A.Dewhurst 22OCT25 (k) Confidential information Clearly marked and specific facts supporting nondisclosure Non-confidential well. A.Dewhurst 20OCT25 (l) Variances requested Modifications of deadlines, requests for variances or waivers No plan for post fracture water well analysis. Commission may require this depending on performance of the fracturing operation. 1 Dewhurst, Andrew D (OGC) From:Jerry Lau <Jerry.Lau@hilcorp.com> Sent:Wednesday, 22 October, 2025 15:05 To:Dewhurst, Andrew D (OGC) Cc:Wallace, Chris D (OGC) Subject:RE: [EXTERNAL] PBU 15-32C Frac Sundry (325-630): Questions Andy, Answers in blue below: Regarding the freshwater aquifer requirements, the only way to be exempt from them is to have an Aquifer Exemption Order, like there is for the west side of PBU or a No USDW Determination from the EPA. In this case, would you identify any freshwater aquifers as de ned in 20 AAC 25.990(27), and any water wells (if any) within a ½-mile? We do not have freshwater formations/aquifers or water wells within the ½ mile AOR What is the shallowest signi cant hydrocarbon zone at PBU 15-32C? The Put River Western Lobe itself if the shallowest signi cant hydrocarbon zone within the well Would you con rm that the HRZ is the upper con ning zone and the Kingak the lower con ning zone? Section 9 also includes the Sag River and Shublik; are they acting as additional con nement? Just wanted to make sure Im not misunderstanding something. I con rm that the HRZ is the upper con rming zone and the Kingak is the lower con ning zone. I had included the Sag and Shublik for reference. Finally, thank you for the AOR. It is very clear. For the PBU 15-48 well, would you please con rm the total cement volumes pumped; the well le doesnt have much detail regarding the 7 casing cement job but reports a total of 48 bbls. I had a typo on the comments section for 15-48 7 CSG cement job. I had stated that 85 bbls were pumped. The actual volume pumped was 48 bbls with 44.5 bbls making it behind pipe after accounting for shoe tract. The submitted TOC provided is correct because I used 44.5 bbls in the caclulation just an error in the comments on volume. The Daily Drilling IADC report snippet below con rms the slurry was 48 bbls of cement. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Let me know if you have any more questions. Regards, Jerry Lau Hilcorp North Slope Prudhoe Bay East FS3 Operations Engineer (DS 06,07,13,14,15) Cell: (907) 360-6233 Office: (907) 564-5280 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, October 22, 2025 10:22 AM To: Jerry Lau <Jerry.Lau@hilcorp.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: [EXTERNAL] PBU 15-32C Frac Sundry (325-630): Questions Jerry, I am completing my review of the PBU 15-32C frac sundry and have a few questions: Regarding the freshwater aquifer requirements, the only way to be exempt from them is to have an Aquifer Exemption Order, like there is for the west side of PBU or a No USDW Determination from the EPA. In this case, would you identify any freshwater aquifers as de ned in 20 AAC 25.990(27), and any water wells (if any) within a ½-mile? What is the shallowest signi cant hydrocarbon zone at PBU 15-32C? Would you con rm that the HRZ is the upper con ning zone and the Kingak the lower con ning zone? Section 9 also includes the Sag River and Shublik; are they acting as additional con nement? Just wanted to make sure Im not misunderstanding something. Finally, thank you for the AOR. It is very clear. For the PBU 15-48 well, would you please con rm the total cement volumes pumped; the well le doesnt have much detail regarding the 7 casing cement job but reports a total of 48 bbls. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-06-24_23033_KRU_3R-101L1_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23033 KRU 3R-101L1 50-029-23574-60 Caliper Survey w/ Log Data 24-Jun-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 217-014 T39106 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.03 09:07:00 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-06-25_23034_KRU_3R-101L1_JewelryLog_Updated_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23034 KRU 3R-101L1 50-029-23574-60 Jewelry Log 25-Jun-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC *** Updated with the L1 added to the well name and the corrected api number **** Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 217-014 T39085 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.28 12:37:39 -08'00' DATA SUBMITTAL COMPLIANCE REPORT 7/27/2017 Permit to Drill 2170140 Well Name/No. KUPARUK RIV UNIT 3R-1011-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23574-60-00 MD 15896 TVD 3540 Completion Date 4/27/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log No V/ Samples No / Directional Survey Yes V -,--/ DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Periscope (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Step P CH Received Comments ED C 28185 Digital Data _ 9390 9805 5/10/2017 _ Electronic Data Set, Filename: CPAI 3R- 101L1_scope Resistivity_RM_LAS _LWD007.las' ED C 28185 Digital Data 9613 9805 5/10/2017 Electronic Data Set, Filename: CPAI_3R` 1011-1 Scope Resistivity_RM_LAS _LWD007ST.las ED C 28185 Digital Data 9768 15896 5/10/2017 Electronic Data Set, Filename: CPAI_3R- 101L1_ Scope Resistivity_RM_LAS_LWD008.1as ED C 28185 Digital Data 126 2254 5/10/2017 Electronic Data Set, Filename: CPAI_3R- 101L1_VISION Resistivity_RM_LAS_LWD001.1as ED C 28185 Digital Data 2182 8078 5/10/2017 Electronic Data Set, Filename: CPAI_3R- 101L1_VISION Resistivity_RM_LAS _LWD002.las. ED C 28185 Digital Data 8027 9742 5/10/2017 Electronic Data Set, Filename: CPAI_3R- 101L1 VISION ' Resistivity_RM_LAS_LW D003.1 -as ED C 28185 Digital Data 106 15896 5/10/2017 Electronic Data Set, Filename: CPAI_3R- - 101L1_scope Resistivity_RM_LAS.las ED C 28185 Digital Data 106 15896 5/10/2017 Electronic Data Set, Filename: CPAI_3R- - 101L1_Scope Resistivity_Custom_RM.las ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 1011-1 LWD001 VISION _ Resistivity_RM_DLIS.dlis ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1 LWD001 VISION _ Resistivity_RM_DLI S.htm I ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 1011-1 LWD002 VISION Resistivity_RM_DLIS.dlis AOGCC Page I of 6 Thursday, July 27, 2017 DATA SUBMITTAL COMPLIANCE REPORT 7/27/2017 Permit to Drill 2170140 Well Name/No. KUPARUK RIV UNIT 3R -101L1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23574-60-00 MD 15896 TVD 3540 Completion Date 4/27/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1 LWD002 VISION - Resistivity_RM_DLIS. htm I ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI 3R- , 101L1 LWD003_VISION Resistivity_RM_DLI S. dlis ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI 3R- 1011-1 LWD003 VISION Resistivity_RM_DL IS. htm I ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI 3R- 101L1_LWD006_TeleScope_RM_DLIS.dlis .. ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101 L1_LW D006_TeleScope_RM_DLIS.html ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1_LWD007_Scope Resistivity_RM_DLIS.dlis ED C 28185 Digital Data 5/10/2017 Electronic File: CPA]3R- 101L1 LWD007 Scope Resistivity_RM_DLIS. htm I ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1 LW0007ST_Scope Resistivity_RM_DLI S.dlis ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI 3R- 101L1_LWD007ST_Scope Resistivity_RM_DL I S. htm I ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 1011-1_LWD008_Scope Resistivity_RM_DLIS.dlis - ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1 LWD008 Scope Resistivily_RM_DLI S. htm I ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R-101L1_Scope Resistivity_RM_D LI S.dlis ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI 3R-101L1_Scope Resistivity_RM_DLIS.htm I ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI 3R- 101 L1_Scope_Resistiv@y_2in_MD_RM.pdf ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI 3R- 101L1_Scope_Resistivity_2in_TVD_RM.pdf AOGCC Page 2 of Thursday, July 27, 2017 DATA SUBMITTAL COMPLIANCE REPORT 7/27/2017 Permit to Drill 2170140 Well Name/No. KUPARUK RIV UNIT 3R-10111 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23574-60-00 MD 15896 TVD 3540 Completion Date 4/27/2017 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 28185 Digital Data 10/2017 Electronic File: CPAI_3R- 4x/ 101 L1_Scope_Resistivity_Sin_MD_RM.pdf ED C 28185 Digital Data 5/10/2017 Electronic File: CPAI_3R- P 101L1_Scope_Resistivity_5in_TVD_RM.pdf ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-1011-1 NA027 CompassSurveys.pdf ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-101 Lt NAD27 [Canvas].txt ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-101 L1 NAD27 [Macro].txt ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-1011-1 NA027 [Petrel].bd ED C 28185 Digital Data 5/10/2017 Electronic File: 3R -101L1 NAD27.txt - ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-101 L1 NAD83 CompassSurveys.pdf ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-1011-1 NA083 [Canvas].txt- ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-1011-1 NAD83 [Macro].txt- ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-1011-1 NAD83 [Petrel].txt - ED C 28185 Digital Data 5/10/2017 Electronic File: 3R-1011-1 NAD83.txt Log C 28185 Log Header Scans 0 0 2170140 KUPARUK RIV UNIT 3R-101 L1 LOG HEADERS j Log C 28186 Log Header Scans 0 0 2170140 KUPARUK RIV UNIT 3R -101L1 PB1 LOG HEADERS ED C 28186 Digital Data 9390 9805 5/10/2017 Electronic Data Set, Filename: CPAI_3R- 1011-1PB1 Scope Resistivity_RM_LAS _LW D007.Las ED C 28186 Digital Data 126 2254 5/10/2017 Electronic Data Set, Filename: CPAI_3R-. 1011-11DB1 VISION Resistivity_RM_LAS_LW D001.1as ED C 28186 Digital Data 2182 8078 5/10/2017 Electronic Data Set, Filename: CPAI_3R+ j 1011-1P61 VISION Resistivity_RM_LAS _LW D002.las ED C 28186 Digital Data 8077 9409 5/10/2017 Electronic Data Set, Filename: CPAI_3R- 101L1PB1 VISION Resistivity_RM_LAS _LW D003.Las ED C 28186 Digital Data 106 9805 5/10/2017 Electronic Data Set, Filename: CPAI_3R- 101L1P131_Scope ResistiAty_RM_LAS.las AOGCC Page 3 of 6 Thursday, July 27, 2017 DATA SUBMITTAL COMPLIANCE REPORT 7/27/2017 Permitto Drill 2170140 Well Name/No. KUPARUK P,IV UNIT 3R -101L1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029.23574-60-00 MD 15896 TVD 3540 Completion Date 4/27/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 28186 Digital Data 106 9805 5!10/2017 Electronic Data Set, Filename: CPAI_3R- ' 1011-1 P131_Scope Resistivity.las ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1PB1 LWD001_VISION. Resistivity_RM_DLISAlis ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1PB1 LWD001 VISION _ Resistivity_RM_DLIS. html ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1PB1_LWD002_VISION Resistivity_RM.dlis ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101 L1 PB1_LW D002_VISION Resistivity_RM.html ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101LlPB1_LW0003_VISION Resistivity_RM.dlis ED C 28186 Digital Data 5/10/2017 _ Electronic File: CPAI_3R- 101L1PB1 LWD003_VISION' Resistivity_RM.html ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1P81_LWD007_Scope Resistivity_RM.dlis` ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1PB1_LWD007_Scope Resistivity_RM.html ` ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R-101LIP131_Scope , Resistivity_RM_DLI S.dlis ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R-101L1PB1_Scope Resistivity_RM_DLI S. htm I ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI_3R- 101L1PB1_Scope_Resistivity_2in_MD_RM.pdf ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI 3R- 101L1PB1_Scope_Resistivity_2in_TVD_RM.pdf ED C 28186 Digital Data 511012017 Electronic File: CPAI_3R- �% 101L1PB1_Scope_Resistivity_5in_MD_RM.pdf ED C 28186 Digital Data 5/10/2017 Electronic File: CPAI 3R- 1011 -1P61 Sc0pe_Resistivity_5in_TVD_ RM.pdf, ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101l1PB1 NAD27 CompassSumeys.pdf - AOGCC Page 4 of 6 Thursday, July 27, 2017 DATA SUBMITTAL COMPLIANCE REPORT 7/27/2017 Permit to Drill 2170140 Well Name/No. KUPARUK RIV UNIT 313-10111 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23574-60-00 MD 15896 TVD 3540 Completion Date 4/27/2017 Completion Status 1-0I1 Current Status 1-0I1- UIC No ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD27 [Canvas].txt ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD27 [Macro].txt ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD27 [Petrel].txt , ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD27.txt . ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1NAD83- CompassSurveys.pdf ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD83• [Canvas].txt ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD83 [Macro].txt ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD83 [Petrel].txt ED C 28186 Digital Data 5/10/2017 Electronic File: 3R-101L1PB1 NAD83.txt Well Cores/Samples Information: -- Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVEq/A Completion Report Production Test InformatioGeologic Markers/Tops lY� COMPLIANCE HISTORY Completion Date: 4/27/2017 Release Date: 3/16/2017 Description Directional / Inclination Data/ ` Y Mechanical Integrity Test InformationY NA Daily Operations Summary Y Date Comments AOGCC Page 5 of 6 Mud Logs, Image Files, Digital Data Y) N Core Chips YJAComposite Logs, Image, Data Files/rc 'Core Photographs YCuttings Samples (Y�/0 Laboratory Analyses Y Thursday, July 27, 2017 DATA SUBMITTAL COMPLIANCE REPORT 7/27/2017 Permit to Drill 2170140 Well NamelNo. KUPARUK RIV UNIT 3R-1011-1 Operator CONOCOPHILLIPS ALASKA, INC. MD 15896 TVD 3540 Completion Date 4/27/2017 Completion Status 1-0I1- Current Status 1-0I1 Comments: Compliance Reviewed By: __... API No. 50-029-23574.60-00 UIC No Date: 72r A000( Page 6 of 6 Thursday, July 27, 2017 STATE OF ALASKA ALASKA OIL AND CAS CONSFRVATInM rtnnnnnlcclnkl "c'LOCIvED MAY 2 6 2011 ,AC)n%r% WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20nnc 25.105 20n C25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Development ❑✓ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or y/t�/ta 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 4/2ek2w « 217-014 , 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 4/13/2017 50-029-23574-60-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 1630.5' FNL, 2959.2' FEL, Se 9, T13N, R9E, UM 4/20/2017 1 KRU 3R-101L1/3R-101L1PB1 Top of Productive Interval: 9. Ref Elevations: KBA8.9 17. Field / Pool(s): 817' FNL, 57' FEL, Sec 5, T13, R9E, UM GL: 9.9 BF: Kuparuk River FieldNVest Sak Oil Pool" Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1015' FNL, 1266' FEL, Sec 6, T13N, R9E, UM N/A 355023, ADL 355024 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 520626 y- 6031732 Zone -4 15896/3540 , 931933000, 931934000 TPI: x- 518216 y- 6037818 Zone -4 12. SSSV Depth MDfFVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 511729 y- 6037607 Zone -4 N/A 1 1730/1701 5. Directional or Inclination Survey: Yes � (attached) No 13. Water Depth, if Offshore: 121. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 1 9410/3604 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Periscope 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 20 62.6 B 39 119 39 119 42 Existing 133/8 68 L-80 42 2243 42 2165 16 932 sx 11.0ppg, Class G, 260 sx 9518 40 L-80 39 9732 39 3634 12.25 1878 sx 15.8ppg, ClassG 41/2 12.6 L-80 9466 15967 3608 3551 8.75 Liner 24. Open to production or injection? Yes ❑� No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 7323 N/A SLOTTED LINER @ 9628-10357 MD, 3615-3601 TVD COMPLETION 10517-11486 MD, 3603-3595 TVD DATE 11644-12153 MD, 3587-3569 TVD NWas A a 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. hydraulic fracturing used during completion? Yes EJ No ❑✓ 12360-12902 MD, 3566-3571 TVD ___ 13068-13586 MD, 3571-3575 TVD VERIFIED 13753-14319 MD, 3574-3566 TVD - Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 14480-15045 MD, 3564-3561 TVD 15206-15727 MD, 3560-3545 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): CPAI intends to produce with ESP up the WAITING FOR HOOK-UP tubing and gas up the IA to increase production (20 AAC 25.200(d)). Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): V776/B/ / T Ids 611741?- Form 10-407 Revised 512017 �,�i/t CONTINUED ON AGE 2 RBDMS LL MAY j 0 261 pubmit ORIGINAL 7 ly'1 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No R] If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1730 1701 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 9392 3602 information, including reports, per 20 AAC 25.071. Formation @ TPI -West Salk D WEST SAK D 9361 3601 TD 15896 3540 3R-1010PI31 9605 3610 Formation at total depth: West Sak D 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Reports, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaicalrwell test results, per 20 AAC 25,070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. B t Authorized Name: G.L. Alvord Contact Name: Ben Tolman s(zs(zori Authorized Title: AK Drilling Manager Contact Email: Ben.V.TOIman co .com Authorized n Contact Phone: 265-6828 Signature: - {J, s'� Date: -�ZS ( 2 a r 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 Is: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed iogs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only W el Ibeod / Tubing Head / Tree, 13-318" x 4-K", 5,000psi I rewnM CooMcmr Casing, 20', 94 N, K55 x 34", 0312"WT® +/-108'MD 13-3/8", 68N, 480, Hyd'1-563 @2,24e MD 12, IW TVD @ 35" Inc TD 16" hole Baker SUXP Packer @-9,223' MD/ 3,5W ND @ 88° inc Lund Envy Module POST -\ 3.150'L in,, nipple prafle@9,310'(LBM) Sedbore Divenc (SBD)PDS-1 �, 4-I/2",12.6 0. L-80, TXP 3R-101 Dual 1,2teral Producer (As Ran) MardmL 4 -III' x 1-1Q" w/ro valves@ 2567' MD /2.413' TVD@ 501 Inc Merdrel, 4 In' x 1.112' W dummy vdve ®1,154' MD/ 3,310' ND @ J8a ian Mu, - Dischuge and lmakc Bank up @ 1,216' MD mud ESP -wireline mrievable pump/tubing conveyed moor. MD/ 3,404' ND @ 19° ure MLMPnAAnchor kA 9-5/8", 4W, L80, Hydril 563&521 ` @ 9,132' W / 3,635' ND TD 12-1/4" hole@ 8&6c inc. LI Window Tap @ 9,39T MD / 3,6034' TVD @ 86.15° inc LI Window BM @ 9.41P MD / M03.2' ND @ 88.29° inn n03 ML luanlion Sys= 4-1/2', 1368 L80, T% P, SWned Lim S-WDsendlaund �I5,864'MD/3,546'ND TD@15,896'M/3,gffi 3,54W WD 6,504'f LYuen al Ul & WaW Tnner CannWp @ 9,591-& 12,330 13,126',14.614, & Sloecd Lwrr TD@ 1 KUP PROD 3R-101 Wnocorhuup56Ve11Attributes Max AngleBMD TO Alesky„tIC w•nbon AP1AIM P1•MNwlw w-1w.nsxs 500292357400 TRACT OPERATION WSAKTROS PROD nail MDIMeI Aa eon lMe) 98.19 16,346.29 16.4330 Camrenl .(Pm) Ab M--= Entl GM Iia SSSV: NONE La&WO' -no RIp RMep•DM 39.10 4/28/101] MULTIPLE LATERALS 3R-101,PM 3R -I, 525rz017 T1238 W u:IMmBc ecNN Annotation De n q IRNBI EM AM Mnetalbn By Fntl _... _. _ LaN Tag: Rev Reason: New Well ppmIaYvanMPC 5452017 MANGER', S•➢� Casing Strings G -g npanipllon OG lint ID(N) Top INNS) Gl Mptb 181(81 Sol.Pm nVD)... YWlan 11... GrPG TOP TMwE CONDUCTOR 20 19.124 39.0 X90 1190 6258 B ........ sa.o-ttaD Description .(i.) ID (in) Top 18X8) Sen Dow"(81te) SON Open" fr"14. Wllten(I_. Top ThemecorvbucrOq: SURFACE 13 WB 12415 41.6 2.2439 2,165.5 68.00 LAD W135W fGUnB comingpinvollon 1-1 ID(iN Top 18X01 SM Doptn Me) SN pool RVDI... Wtllen D...M Top Thread INTERMEDIATE 9516 8835 389 9,)32.2 3,633.6 40.00 4,-60 Hyd 521 -0i) GVM, Do✓unauon W ID(.. Top(N(8) y10.pMM.) SM Dop111 (TVp1... wYLan 1... Gnda TPp TMsd SEALSOREDIVERTER 848 3.710 9,3852 9.507.3 3.612.3 SUREACE;41.9-x)439 LATERAL LI GAS LIFT: ..Shea G&nil DasulPtle MUM) IOlinl TBp fMB)9tl pp111 (NIB) y1 GpN )... W1Aon IC Grad- TPp TlllYd WINOOW 5.2 1958 9,392.0 9,4096 3,607.6 Ca-Inp D--Vm- CG 11n) 101in1 WPIBNBI=IDMIn(MB) Bw GpNINDI... wuL-n(1... W roP TMNO LEWSLZXP 41/2 3.958 9,223.0 8.407.8 3,603.5 1260 LA0 Wirt Gan,:NR-'een OGlln) mlin) roplMB) SXWa INKBI BeIGpM lrvol... MLnnll... Gma. Tap TinnedGee UFT:I to LDWERLATERAL 4112 3.9M 9,4662 15,9673 3,5516 1260 L-60 TXP-m LINER Liner Details Gvyy/Pump$-mrv', )y1S.t TPP (NNB) TOPI )1NNRl ropin.l(l Ium One Com Nominal lG 9,4662 3,608.5 8488 PACKER Baker MLZXP Liner hangar Packer 7X9518',7'29# 5090 ERP POrop I2a3A Hydnl 563 pin on ESP PuIp-p.ma ES"oni 1.]011 ESP Mold• 8 CMbF ].509.1 9,4929 3,6109 64.69 TOREDUCING X07'2WHyddI563IKXX5I12'IfLNHydN15W pin Cwt, IE... are, ESFMdan 9 Ca bc,T,321.0 80942 3811.0 m 68 Baal Bore Baker 1904],675' ID Seal Bore Exleneion, 512' Ektenalon M0563 term. Din 4.750 10,2944 3,6059 9372 SYre1l Packer Baker swell pekap 412'x8.25"F SM -0531- 3.970 61-0013 10,314.8 3,604.5 93.63 Screen Tremmo TrocerGNitlpe, S12Y5.5 pPf HYtl 511 3.958 Pin. Pin, ser# d 11,443.8 3,595.1 88.0 Bonet Packer BakerpNNNpacker,4-1WXS.25-'F BN0531-3.960 6t-001-1 11,703.5 3,5933 92.74 Seall Packer BaIPN.11packar,4-12'x828'0' SIN -0531 3960 61-001-4 11,726.2 3,592.2 931tt BMeen Tremrco Tracer Certntl9e, 812'155 D0f HYtl 511 3.958 Pin x Pin, wr# 3 UPpap U TERA. LINER w 13,125.6 3,5925 09.5] Swell Pacer Baker swell paker,442'x 0.25"C' SIN -053181 3.960 RN -f l.nesT p]80s1s➢63B LEw912RP, B.ZL3PSA0]B F wlrvoow: edsx➢9A0a. -00141 13.1463 3,592.6 89.62 Screen Trooam3TnN.rCadtldge,S1275.5ppf*dsl, 3950 Pin x Pin. Per# 2 14.6142 3,579.4 9057 fink 11Paker BakerswglpRkR o-12'x8.25"B' S/N-053161 SSW 14,634.4 3,579.1 90.81 $teen T..Tmmr Oaddd,e,5-12'15.5ppf Fid511 3.958 Pin x Pin, ser# 1 15,6304 3,554.6 91.96 Swell Peker Baker swell pecker, 0.12' x 82S'A' 811,1-053161 3.9]0 -001-2 REEUBORE MVERTER Tubing Strings IATERPL LI: B.PBsl-0,50]3 Tubing Gxnplion SNnB Ma.. IDIinI Top (NMB) S.t GpT IN..5M ONION VO)(... WIIIdYI) Gado TOP Conn.alon TUBING 412 3.958 34.() ).322.9 3404.0 1260 L-80 TXT Completion Details Top 1NNs1 Top(We)I.) Top lnu l') Por Ou Cpm Nombl.l lD 4n) I Ixreaweowreaesa.)921 340 340 0.19 HANG Vet G 103/4'x45'- co lay aBsat M0228 hallgerw/ atESB pareM5ow1(13A18') ], MA 3,382.8 7 26 Gaups/Pump Cern118 Discharge Gua,e Unit, ELE SAN Saner 1,283.8 3.396.4 )0.88 ESPPumps Centindift Base Receiving, RCVG 3480($51'513 SEAL, 3.958 4.S NSCT sink 13237WO B."Te O.Asd-Io,Poax � C 7,2903 3,3 4 7873 ESP UmDs Carat Seal ,ESP. B3DB UT PER HLH SN# KOTeat032st tPa3) 113954711 7,301 2 33998 776 ESP Pumila CeN6141 Seal. ESP, GSB3DB LT PER HL H6 SPIN 1396]409 ],308.1 3,401.1 ]0 ]9 E MobrsB 141X811 r60MP 15W 242W 3862/ 10M 06R SW Ceblae 1413811] - 7,319.1 3,4 W. 78.84 ESP Moors CanMlift Motor ON age Kit Step 192-01048 Cables ),3210 3403.6 78&5 ESP MobrsB 2 /e'CenldliN Motor Centre17er1685'(55) caNeP 84,07$173463-12,%9fi�� C Perforations 8 Slots SbOt Gn9 TPPITAD) an" Ovol (nNOMx T.P (BNaI BNn INNB) INNER 161{8) OP.D.lo n Ty P. Gnm 10,345.1 10,8692 3,61 3,688.4 4,12/2017 32.0 SLOTS 11,032.5 11,43).7 3,589.3 3,5949 4112/2017 32.0 SLOTS 11,]54] 1 ,2829 3,590.] 3,589.1 4112201] 320 SL ----- 910rs: 1317ea13711'3 12,"62 1 ,9566 3,5187.3 3,590617,22017 320 SLO Ams:11999a1a N6.1 13,176A 13,7113 3,592.18 3,587.5 N1220R 32.0 SLOTS 13,81 14,446.1 3,584.2 3.500.3 4/122017 32.0 SLOTS 14,685.0 15,180.7 ,5786 3,573.9 4/12201] 32.0 SLOTS 153050 15,8243 3.574.0 3,SEES 1 1212017 32.0 SLOTS Mandrel Inserts SUITSk KNNSA45.1817�i an Bwrb:1s.30s➢.,392u�i roil DVDI v.I- WCn I PONT a1u TRO Run N Top 19X8) is B) Mak- M...l 00(In) GTI T TYP- 9n) (WD Run O -n COT 7,154.5 3,370.1 Cameo MMG 1112 GAS LI, DMV BK NO, 0.0 428201] LOWERIATERALLINER: 9Are3-15.9P)A� KUP PROD 3R-101 i-onocorniuips Naska,lpc. MULPFIEIATERNS-9R-1015/[SQOi)J:1240 PM BIMeI m HPNGER', 300 -- s: e33ere Ene oef. pnmlMlon ............... ... ... ... ... . ...... . NOTE: CONDVCiOR, 3901190 SURFACE: 41S-2.243 9 GA4 LIFT: 3,5680 GAS LIR; ],1565 Geuy/RINK v:1216.1 ]B ESPPUIIp¢:]20EEN EBP Pury¢;)M03 SEN.....).308? ENP OYYon 6 GSOks: ).]18. f ESP........., 321. UNNERL TE LINER W RAM., 8.S.." M19 3ENRSE R:B3'13.6900TJ WIN DOW: 93920.0,409 6 .Fl NEDIVEATER LATERAL L1:8.]05.2-8.SD] ] IXIERMEdATE:90 B-0.)323 BLOTS', 10905.1iom,03-r SL0T$11.0S2.S11.637)-- r SLWIL 11.)8.3-12.M2H-1 SLOTS. 12i46.Y12.95EA � SLOT&, 191)6A13,)1)3� SLOTS 13.M,110,M61 -� SLOTSI u4665419,10oT� . SLOTS I S]OSdi6,Bb.3�� LOWER LATERAL LINER; _,__A8,166.T IS .14 /1` \ KUP PROD 3R -101L1 t-onocornim Well Attributes Max Mgle & MD TD AG6N :(IC WellOoreAPIlUW1 Fialtl Xnu WekomSWus nG P) N.'rap, a---- 50029235]660 TRACT OPERATION WSAKTR05 PROD 9620 11758.10 15,896.0 COrllnlont IQS (pprrQ pay MrraWbn 6n00are K9GN p0 RIp FkIeW OYe 39.10 N2B/201] ••• MIILPPLEIATER S-3R!GIL1.5/15/l7] 13'.01PM MrlPylNn Oepopmes) Ene OW MMNbn Laat MOO KY En4py Rev Reamn'. New Well ppmven 51242017 NANGE 3,.,c CausingrTnge Gsin9 Cestliplion 000n1 10 (inl Top (0.1(81 SN Oep1M1 (flKR) Sel OaptM1 (iV0)... WOLen (I.. GrMo Top TMmtl UPPER LATEPAL LINER dtl2 3.958 9,300.5 15,BfiJ.9 3.541.1 12 60 LA0 TXP-m wl RAM M1anger Liner Details . .. ..- ... top lfll(el TOP RVOT (aKSI Top lrlPJm Ibm Dae Wm xomm.l ID (in) 9,300.5 3,601.fi 88.53 Hanger Baker RAM Hangar,(A50ve pmfile) 6.09 CONDUCTOR39el190 9,5976 3,613.9 8].91 Screen Traci Tracer Cartridge, 5512' 15.5 Me Hyl 511 3950 Pin x Pin, cer# 6 123297 3,565.6 90.14 Screen Trecew Tracer Cadridge,5-1/2.15.5ppIHyl511 3.958 Pin x Pin, Ser# 5 Perforations & Slots 9130.FACE:61.a23639 Dons Top (WD) TOPIMB M&n Map) MKS) 0M(TVO) (KKK) (GOW IDn. pay 4 "P. Lpr1 GAB LIFT: 2,SE0,8 9,62].9 10,356.8 3,814.7 3,801.2 424201] 32.0 SLOTS 10,51].5 1 ,4 5. 3,fiO3.6 ,595] 1] 32.0 SLOTS 11,644.2 1 ,1529 3,58].6 ,568.8 17 32.0 SLOTS 12,359.8 12.9024 3,565.6 3,571.0 4124201] 32.0 SLOTS GPSLIFr; l,1N3 13,0684 13.586.8 3,5714 3,575.1 424201]M.0 SLOTS 137527 UTU 3,573.6 3.565.9 V1472FI] 320 SLOTS 14,480.1 15,0455 3,564.3 3,551.0 4242017 32.0 SLOTS 15 20651 15.]2].2 3,560.0 1 3,544.] 626/201] 32.0 SLOTS GUNa / Rmp yrwr, ),218.1 Notes: Gerreml8 Safety End Omar Mnoylion NOTE: ESP q.qs, ),2034 FSP Fuge; ]2913 ESPPurgm;]301] ESP MMps & Gli.:1.309.1 ESPMGpsB LaP E9 Ablcr[ 8 LoY.i e: T.1 .1 A S INTERNEMATE; YSA.YJ21 LEM5 ..OMMS AO)A SE490RE OIVERTER IATERK Lt; 82851-8.50].] 7f BLOT&: R62]R10.]538�� SLOTS: 10.517A-11,M5.9� SLOT: 113N1 -Tr ael- ` SLOTS: 12A59. 129324 SLOT513...8 -ia'ski C� SLOTS, 13,]53.]-14?19.1 -� SLOTS; fa,H0.4ISA15.5- SLOTS: 15208.51523]1 VPPE0.LATFRKLINER "'A RMI nargar:g.ai1 K.S. Operations Summary (with Timelog Depths) "0 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tima End Time Dur (hr) Phase Op Cotle Activity Code Time P -T -X Operation Sted Depth (r1KB) End Depth(ftKB) 3/22/2017 3/22/2017 0.75 MIRU MOVE RURD P Rig release from 3R-102 at 16:00 hrs. 0.0 0.0 16:00 16:45 Swap to generator power. Continue blowing down steam lines. Remove cuttings tank and containment. Continue disconnecting service lines. 3/22/2017 3/22/2017 0.75 MIRU MOVE MOB -F- Move power complex and rockwasher 0.0 0.0 16:45 17:30 1 and stage on pad. 3/22/2017 3/22/2017 1.25 MIRU MOVE MOB P Move pump module and pit module 0.0 0.0 17:30 18:45 and stage on pad. Continue moving rockwasher and move pipeshed module and stage on pad. 3/22/2017 322/2017 0.75 MIRU MOVE MOB P Skid rig floor and install tongue for 0.0 0.0 18:45 19:30 towing substructure. 3/22/2017 322/2017 1.75 MIRU MOVE MOB P Lift sub stompers and finish installing 0.0 0.0 19:30 21:15 tongue for towing substructure. 3/22/2017 3/232017 2.75 MIRU MOVE MOB P Pull substructure off 3R-102. Shuffle 0.0 0.0 21:15 00:00 and lay dg mats for spotting sub on 3R -101. 3/23/2017 3/23/2017 0.50 MIRU MOVE MOB P Cont. to spot sub base over well 3R- 0.0 0.0 00:00 00:30 j 101 3/232017 3/23/2017 1.50 MIRU MOVE MOB P Set down rear stompers and apply 0.0 0.0 00:30 02:00 pressure. Skid the rig floor over the center of the well. Remove towing tongue from sub. 3/23/2017 3/23/2017 1.00 MIRU MOVE MOB P Spot pit complex, hook up 0.0 0.0 02:00 03:00 interconnect lines between sub base and pit complex. Hook up lines post rig floor skid. 3/23/2017 3/23/2017 2.00 MIRU MOVE MOB P Spot pump complex, SIMOPS hook up 0.0 0.0 03:00 05:00 interconnects. 323/2017 3/23/2017 0.50 MIRU MOVE MOB P Spot motor complex, SIMOPS, hook 0.0 0.0 05:00 05:30 up interconnects between pump complex and pit complex. 3/23/2017 3/23/2017 1.00 MIRU MOVE MOB P Spot rock washer. 0.0 0.0 05:30 06:30 3/23/2017 3/23/2017 2.00 MIRU MOVE MOB P Spot pipe shed. 0.0 0.0 06:30 08:30 3/23/2017 3/23/2017 1.50 MIRU MOVE RURD P Scope cattle chute to sub and install 0.0 0.0 08:30 10:00 skate ramp. Install cuttings box and bene area. Install berming around cellar, complete interconnects, and start sending steam around rig. Rig accepted at 10:00 his. 323/2017 323/2017 4.50 MIRU MOVE RURD P Install studs in diverter, lower riser 0.0 0.0 10:00 14:30 through table and nipple up. SIMOPS Take on spud mud to pits. 3/23/2017 3/23/2017 3.00 MIRU MOVE RURD P Continue tightening up flanges, Make 0.0 0.0 14:30 17:30 up hydraulic hoses to diverter, Wrap diverter and apply heat to thaw out, take on 2nd load of spud mud. Inspect conductor ports on starter head and grind down outlets to provide more clearance between conductor outlets and starter head. 3/23/2017 3/23/2017 1.25 MIRU MOVE RURD P Install mouse hole and change out die 0.0 0.0 17:30 18:45 blocks on iron roughneck 3/23/2017 3/23/2017 0.75 MIRU MOVE SFTY P Hold pre -spud with crew and CPAI 0.0 0.0 18:45 19:30 drilling engineer for 3R-101. Page 1150 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Our(hd Phase Op Code Activity Code Time P-T-X Operation Start oepm (toe End Depth (flKa) 3/23/2017 3/23/2017 2.75 MIRU MOVE PULD P Pick up and rack back 20 x stands 5" 0.0 0.0 19:30 22:15 19.5# 8-135 NC50 OF, drifted w/ 2.867" rabbit. RIH and tag up at 112.85' MD. 3/23/2017 3/24/2017 1.75 MIRU MOVE PULD P Pick up and rack back 5 x stands 5" 0.0 0.0 22:15 00:00 HWDP Standard 1340 grade, 50.38ppf adjusted weight NC50, and jar stand w/ 6-1/4" WFT Mechanical jars. SIMOPS prep for koomey test and prime mud pumps. 3/24/2017 3/24/2017 1.00 MIRU MOVE BOPE P Perform diverter test, witnessed 0.0 0.0 00:00 01:00 waived AOGCC rep Brian Bixby. Test all gas alarms, PVT alarms, rig evacuation alarms, surface annular, and knife valve - good tests. Annular closing time = 28 seconds. Knife opening time = 7 seconds. Perform Koomey drawdown test, Initial pressure = 3050 psi, Manifold pressure = 1500 psi. System pressure after functioning annular = 1900 psi. Build 200 psi in 13 seconds using 2 x electric pumps. Continue building pressure with 2 x electric and 2 x air pumps to full system pressure in 82 seconds. Average pressure of 6 x nitrogen backup bottles = 2600 psi. Finish priming mud pumps and hold PJSM for making up BHA. 3/24/2017 3/24/2017 1.00 MIRU MOVE BHAH P Mobilize BHA components to dg floor 0.0 0.0 01:00 02:00 via beaver slide. 3/242017 3/24/2017 1.00 MIRU MOVE SHAH P M/U BHA # 1, dean out BHA 0.0 31.0 02:00 03:00 consisting Baker Hughes MX-1 16" mill-tooth bit, 9-5/8" Mud motor w/ " 1.83° bend, 12-1/8" NM Stab, XO, and 5" HWDP. 3/24/2017 3/24/2017 0.50 MIRU MOVE SEQP P Fill lines and conductor w/thinned out 31.0 31.0 03:00 03:30 spud mud and inspect for leaks, good. Pressure test lines to 3500 psi, good. 3/24/2017 3/24/2017 1.00 SURFAC DRILL DDRL P RIH and spud 16" hole at 03:30 hrs. 45.0 200.0 03:30 04:30 Drill 16" Surface hole from 113-ft to 200-ft MD, 200 -ft TVD at 450 gpm at 460 psi with 20% return flow. Rotating at 40 rpm's at 3k on, 3K off TO w/ 6K WOB. 56K Up wt, 56K Dn Wt, 56K Rot Wt, MW @ 8.9 ppg, AST = .0, ART = .50, ADT = .50, Bit hrs =.50 3/24/2017 3/24/2017 0.25 SURFAC DRILL TRIP P Stand back 2 stands of 5" HWDP to 200.0 31.0 04:30 04:45 the mud motor to 31' MD and blow down top drive. 3/24/2017 3/24/2017 2.75 SURFAC DRILL BHAH P M/U BHA # 2, drilling BHA consisting 31.0 200.0 04:45 07:30 of MX-1 16" bit, 1.83 deg motor, GyroPluse, acrVison and Telescope to 125' MD as per SLB DD. Page 2150 Report Printed: 5/212017 Operations Summary (with Timelog uepths) rr 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log tart STime Eml Time Dw(hr) Phase Op Cme Activity Code Time P-T-X Operepon Start Depth (flK a End Depth (XKa) 3/24/2017 3/24/2017 4.50 SURFAC DRILL DDRL P Drill 16" Surface hole from 200-ft to 200.0 460.0 07:30 12:00 460-ft MD, 460 -ft TVD at 450-500 gpm, On Bum SPP 750 psi, Off Bim SPP 500 psi with 15% return flow. Rotating at 50 rpm's at 8k on, 7K off TQ w/ 22K WOB. 67K Up wt, 76K Dn Wt, 79K Rot Wt, MW @ 9.0 ppg, AST . =.97, ART, ART= 1.22 , ADT = 2.19, Bit his =.2.69, Jar hours= 16.95. Note: Kicked off at 215'. 3/24/2017 3/24/2017 6.00 SURFAC DRILL DDRL P DDrill 16" hole f/ 460' to 870' MD, 866' 460.0 870.0 12:00 18:00 TVD, w/ 550 gpm, On btm SPP 1015 psi, Off btm SPP 758 psi, 16% F/O, 50 rpm, 5-7k Tq, 20-25k WOB, PUW 93k, SOW 85k, ROT 83k w/ 3k Tq, MW 9.1 ppg, AST 2.18, ART 1.61, ADT 3.79, Bit hrs 6.06, Jar hrs 20.74. Note: Swapped from GyroPulse to Telescope readings from 676' onwards. 3/24/2017 3/25/2017 6.00 SURFAC DRILL DDRL P DDrill 16" hole f/ 870'to 1164' MD, 870.0 1,164.0 18:00 00:00 1061' TVD, w/ 550 gpm, On Btm SPP 1000 psi, Off Btm SPP 788 psi, 16% F/O, 60 rpm, 3-5k Tq, 20-25k WOB, PUW 90k, SOW 100k, ROT 85k w/ 4k Tq, MW 9.3 ppg, AST 3.68, ART 0.46, ADT 4.14, Bit hrs 10.62, Jar hrs 24.88. 3/25/2017 3/25/2017 6.00 SURFAC DRILL DDRL P Drill 16" Surface hole from 1164' MD 1,164.0 1,613.0 00:00 06:00 to 1613' MD, TVD= 1590' at 550 gpm, On Btm SPP 1240 psi, Off Btm SPP _ 990 psi with 16% return flow. Rotating at 50 rpm's at 6k on, 4K off TO w/ 20- 25K WOB. 104K Up wt, 108K On Wt, 107K Rot Wt, MW @ 9.3 ppg, AST = 2.5, ART= 2.43 , ADT = 4.43, Bit hrs =15.55, Jar hours= 29.81. 3/25/2017 3/25/2017 6.00 SURFAC DRILL DDRL P Drill 16" Surface hole from1613' MD to 1,613.0 2,170.0 06:00 12:00 2170' MD, TVD= 2109" pump 550- 700 gpm, On Btm SPP 1320-1650 psi, Off Btm SPP 1540 psi with 16% return flow. Rotating at 50 rpm's at 7k on, 5K off TQ w/ 20-25K WOB. 117K Up wt, 112K Dn Wt, I I9 Rot Wt, MW @ 9.5 ppg, AST = 2.17, ART= 1.97 , ADT = 4.14, Bit hrs =19.26, Jar hours= 33.52. 3/25/2017 3/25/2017 1.00 SURFAC DRILL DDRL P Drill 16" Surface hole from2170' MD to 2,170.0 2,254.0 12:00 13:00 2254' MD, TVD= 2174' pump 700 gpm, On Btm SPP 1650 psi, Off Btm SPP 1540 psi with 16% return flow. Rotating at 50 rpm's at 7k on, 5K off TQ w/ 20-25K WOB. 117K Up wt, 112K Dn Wt, 119K Rot Wt, MW @ 9.5 ppg, AST = 0.87, ART= 0, ADT = 0.87, Bit hrs =20.13, Jar hours= 34.39. Page 3150 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time End Time Dur hr ( ) Phase Op Code Adiviry Code Time P -T -X Operation Stan Depth (fIKB) End Depth (flKB) 3/25/2017 3/25/2017 1.00 SURFAC CASING CIRC P Circulate bottoms up at TO 2,254.0 2,195.0 13:00 14:00 reciprocating between 2254'- 2195' w/ 800 gpm, 1824 psi, 23% F/O, 60 rpm, 4k Tq, PUW 120k, SOW 114k, ROT 120k. 3/25/2017 3/25/2017 0.50 SURFAC CASING OWFF P Monitor well for flow while rotating at 2,195.0 2,195.0 14:00 14:30 rpm, 2k Tq, ROT 120k - well static. 3/25/2017 3/25/2017 2.25 SURFAC CASING BKRM P Backream OOH f/ 2195' -1720' MD w/ 2,195.0 1,720.0 14:30 16:45 800 gpm, 1820 psi, 23% F/O, 60 rpm, 4k Tq, 500 ft/hr pulling speed, slowing as needed when pump pressure increases through slides. 3/25/2017 3/25/2017 3.25 SURFAC CASING BKRM P Backream OOH V 1720'- 770' MD w/ 1,720.0 770.0 16:45 20:00 550 gpm, ICP 916 psi, FCP 798 psi, 17% F/O, 60 rpm, 1-5k Tq, 500 ft/hr pulling speed and slowing to 300 ft/hr for last two stands to CBU x 1 per stand. 3/25/2017 3/25/2017 0.25 SURFAC CASING OWFF P Blowdown topdrive, fill trip tank, and 770.0 770.0 20:00 20:15 monitor well for flow at lop of HWDP - well static. 3/25/2017 3/25/2017 0.75 SURFAC CASING TRIP P Pull OOH on elevators f/ 770'- 124' 770.0 124.0 20:15 21:00 MD, standing back 5" HWDP and 6- 3/4" NMDC's, monitoring displacement Ion trip tank. 3/25/2017 3/2512017 2.00 SURFAC CASING SHAH P Pull OOH f/ 124'- surface laying out 124.0 0.0 21:00 23:00 BHA #1 per SLB, monitoring displacement on trip tank. Bit was packed off with clays, but other than that no issues observed with BHA. Both 12-1/8" NM Stabilizers were in gauge. The 15-7/8" stabilizer on the mud motor came out 1/8" undergauge. The Baker MX -1 bit graded 1 -1 -WT -A- E -0 -NO -TD. 3/25/2017 3/26/2017 1.00 SURFAC CASING BHAH P Clear floor of BHA components. 0.0 0.0 23:00 00:00 3/26/2017 3/26/2017 2.00 SURFAC CASING RURD P Rig up to run 13-3/8" casing. Rig up 0.0 0.0 00:00 02:00 GBR Volant, Spiders, bail extensions and 150T elevators. SIMOPS, prep pipe shed for running casing and install stop collars on shoe track. 3/26/2017 3/26/2017 1.00 SURFAC CASING PUTS P RIH w/ 13-3/8", 68#, L-80 Hydrill 563 0.0 122.0 02:00 03:00 casing. M/U Shoe track consisting of DavisLynch float collar and DavisLynch float shoe to 122' MD. Test floats, good. 3/26/2017 3/26/2017 5.50 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80 Hydrill 563 122.0 1,760.0 03:00 08:30 casing f/ 122' MD to 1760' MD installing a bow spring centralizer around every collar.. Ran 29 joints of 13-3/8" Hydrill 563 Dopeless from # 4 to #32. Torqued dopeless pipe to 33K to fully make up. After # 32 13-3/8" Hydrill 563 doped pipe was made up to 26K. 3/26/2017 3/26/2017 1.00 SURFAC CASING CIRC P Circulate casing volume below base of 1,760.0 1,760.0 08:30 09:30 permafrost. Stage pumps up to 6 bpm= 150 psi. P/U= 142K, S/0= 136K, Page 4150 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Tmie P -T -X Operation Sten Depm rftKB) End Depth (hKB) 3/26/2017 3/26/2017 1.50 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80 Hydrill 563 1,760.0 2,199.0 09:30 11:00 casing f/ 1760' MD to 2199' MD installing a bow spring centralizer around every collar. A total of 55 bow springs ran in the hole. 3/26/2017 3/26/2017 0.25 SURFAC CASING CIRC P Circulate while moving the landing 2,199.0 2,199.0 11:00 11:15 joint to pipe skate. Stage pumps up to 3 bpm= 108 psi. P/U= 190K, S/0= 150K. 3/26/2017 3/26/2017 0.25 SURFAC CASING HOBO P M/U GE mandrel casing hanger and 2,199.0 2,243.0 11:15 11:30 landing joint. RIH and landing casing on load ring aQ 2243' MO PIU 191K, S/O= 153K. 3/26/2017 3/26/2017 3.50 SURFAC CEMENT CIRC P Circulate / condition mud through 2,243.0 2,243.0 11:30 15:00 - volant tool while reciprocating pipe f/ 2243'- 2213', staging up pumps to 7 bpm, 65 psi, 7% F/O, PUW 184k, SOW 160k. Pump 85 bbl red -dye marker pill and circulate around, see at surface at 5700 strokes. 3/26/2017 3/26/2017 0.25 SURFAC CEMENT RURD P Blow down topdrive and dg up cement 2,243.0 2,243.0 15:00 15:15 hose to side -entry sub on volant tool. 3/26/2017 3/26/2017 1.25 SURFAC CEMENT CIRC P Circulate / condition mud through 2,243.0 2,243.0 15:15 16:30 cement hose while reciprocating pipe f/ 2243'- 2213' at 7 bpm, 171 psi, 8% F/O, PUW 189k, SOW 1631k, total strokes pumped = 16143. Hold PJSM with crew for cement job. 3/26/2017 3/26/2017 2.25 SURFAC CEMENT CMNT P Line up to Schlumberger cementers 2,243.0 2,243.0 16:30 18:45 and pressure test lines to 4500 psi - good test. Reciprocate pipe -20 ft and Pump 40.3 bbis of 8.3ppg CW100 at 6.5 bpm, 135 psi, followed by 80 bbls of 10.5ppg Mudpush II spacer at 5.5 bpm, 90 psi. Shut down and drop bottom plug, using back-up tongs while releasing / making up Volant tool to prevent moving landing joint. Pump 316.6 bbis 11.0ppg Litecrete lead cement at 6.5 bpm, ICP 200 psi, FCP 180 psi, 10% F/O, followed by 75.9 bbis 12.Oppg Deeperete tail cement at 6.5 bpm, 200 psi, 8% 1`10. Observe hole suddenly get sticky, losing 40k down weight with 50 bbis of tail pumped so landed pipe for remaining part ofjob. Shut down and drop top plug, using back-up tongs while releasing / making up Volant tool to prevent moving landing joint. Page 5150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 16 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Stad Time End Thne our fe) Phase Op Code Activity Code Time P -T -x operation (WEI) End Depth (WE) 3/26/2017 3/26/2017 1.00 SURFAC CEMENT CMNT P Line up to rig pump and displace 2,243.0 0.0 18:45 19:45 cement with treated 9.6ppg spud mud at 7 bpm, ICP 166 psi, FCP 455 psi, 9% F/O. Slow down to 3 bpm, 290 psi, 5% F/O 10 bbls prior to bumping plug. Bump plug at 3090 strokes and pressure up to 600 psi. Hold for 5 minutes, bleed off and check floats - floats holding. Total of 86 bbls of cement returned to surface. Cement in place @ 19:39 hrs. 3/26/2017 3/26/2017 1.25 SURFAC CEMENT RURD P Rig down volant tool, drain riser and 0.0 0.0 19:45 21:00 stack, and flush surface equipment with black water pill. Blow down and clean out cement valves. Clean / dear rig floor. 3/26/2017 3/26/2017 2.00 SURFAC CEMENT RURD T Attempt to back out 13-3/8" landing 0.0 0.0 21:00 23:00 joint with chain tongs (right-hand release) with bushings installed - unsuccessful. Make up rig tong for right-hand release and attempt to back - out 13-3/8" landing joint with bushings installed - unsuccessful. Rig down riser and pull bushings. Attempt to back out landing joint with rig tong while monitoring coupling in middle of landing joint - observe top pup making up into bottom pup joint. Discuss path forward with town. Note: Hanger has 13-5/8" Stub ACME pin w/ 2 threads per inch looking up. Bottom of 13-3/8" BTC landing joint makes up into "landing sub" which is 13-318" BTC box looking up by 13-5/8" Stub ACME pin looking down. Observe 13-3/8" landing joint naturally wanting to lean towards driller cab and contacting side of flow box at rig floor. 3/26/2017 3/27/2017 1.00 SURFAC CEMENT RURD T Hold PJSM with crew. Nipple down 0.0 0.0 23:00 00:00 - surface annular at knife valve, de - energize starting head, make up bridge crane to annular and lift above top of wellhead and secure lines. Observe landing sub still made up flush to wellhead. Start heating up ACME connection with steam. SIMOPS - continue cleaning pits, load 5" DP in shed, and prep for rigging down diverter line. 3/27/2017 3/27/2017 1.50 SURFAC CEMENT RURD T Hold PJSM with crew. Re -install 0.0 0.0 00:00 01:30 bushings and rig up GBR Volant tool while heating up ACME connection with steam. Attempt to back -out landing joint w/ 30k torque to the right - unsucessful. No movement observed. Page 6/50 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth De Sta rt Time End Time our (hr) Phase Op code ActiWty Cade Time P-T-X Operation (g End Dept (flK0) 3/2712017 3/27/2017 1.00 SURFAC CEMENT RURD T Remove Volant tool, pull bushings, 0.0 0.0 01:30 02:30 and make up rig tong for right-hand release while heating ACME connection with steam. Attempt to back-out landing joint with 30k torque - observe buttress connection making up into landing sub just above wellhead. No sign of movement for ACME connection - landing sub still flush on lop of wellhead. Discuss path forward with town. SIMOPS - Install 9-5/8" casing rams in top set of rams in BOP. 3/27/2017 3/27/2017 2.00 SURFAC CEMENT RURD T Weld top and bottom of coupling to 0.0 0.0 02:30 04:30 landing joint to ensure top pup would not make up anymore into bottom pup. Weld top of landing sub to landing joint to ensure buttress connection would not make up anymore into landing sub. Heat up ACME connection with torch (rose-bud tip) to temperature limit of 300"F per Vetco. 3/27/2017 3/27/2017 0.25 SURFAC CEMENT RURD T Make up rig tong for right-hand 0.0 0.0 04:30 04:45 release and attempt to back-out landing joint with bushings removed, staging up slowly to 42k torque - at 42k torque, observe entire landing joint / landing sub / hanger / landing ring turn 2.5 inches. Discuss path forward with town. 3/27/2017 3/27/2017 0.50 SURFAC CEMENT RURD T Weld bottom part of landing ring to 0.0 0.6- 04:45 05:15 conductor and re-heat ACME connection with torch (rose-bud tip) to temperature limit of 300°F per Vetco. 3/27/2017 3/27/2017 0.25 SURFAC CEMENT RURD T Make up rig tong for right-hand 0.0 0.0 05:15 05:30 release and attempt to back-out landing joint with bushings removed, staging up slowly to 42k torque - at 42k torque, observe ACME connection come free and start turning. Make up chain tongs and confirm landing joint released from hanger. 3/27/2017 3/27/2017 0.50 SURFAC CEMENT RURD T Lower surface annular and starting 0.0 0.0 05:30 06:00 head back down onto conductor and secure. 3/27/2017 3/27/2017 0.50 SURFAC CEMENT RURD P Back out landing joint with chain longs 0.0 0.0 06:00 06:30 and pull to rig floor. Inspect ACME threads - no noticeable damage observed to indicate galling. Lay down landing joint. 3/27/2017 3/27/2017 1.00 SURFAC CEMENT RURD P Rig down GBR Volant tool, bail 0.0 0.0 06:30 07:30 extensions, and elevators and clear rig floor. SIMOPs - Nipple down diverter line. 3/2712017 3/27/2017 1.50 SURFAC WHDBOP NUND P Nipple down surfacediverter and 0.0 0.0 07:30 09:00 starting head. Page 7150 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tune End Time our (hr) Phase op Code Activity Code Time P-T-X Op era6cn End Depth (flKa) 3/27/2017 3/27/2017 2.00 SURFAC WHDBOP ' NUND P Remove starting thread protector on 0.0 0.0 09:00 11:00 casing hanger and nipple up Vetco MB 222A wellhead system. Test seal sub to 2000 psi / 15 min - good test. Note: Inspected internal ACME threads on hanger - no signs of galling or damage observed. 3/27/2017 3/27/2017 4.50 SURFAC WHDBOP NUND P Nipple up spacer spools and 13-5/8" 0.0 0.0 11:00 15:30 BOPE stack w/ 9-5/8" casing rams in top set and 3-1/2" x 6" VBR's in bottom set. Install riser. Remove 4" valves and 90' elbows on Conductor and install caps. Install mousehole. 3/27/2017 3/28/2017 8.50 SURFAC CEMENT PULD P Pick up and rack back 70 x stands 5" 0.0 0.0 15:30 00:00 19.5# S-135 NC50 drill pipe via mousehole. 3/28/2017 3/2812017 1.00 SURFAC CASING P Cont to pick up 5" DP via mouse hole 0.0 0.0 00:00 01:00 and stand back in the derrick. Picked IPULD up a total of 77 stands of 5" OR 3/28/2017 3/28/2017 1.00 SURFAC WHDBOP RURD P Rig to test BOPE, set test plug, install 0.0 0.0 01:00 02:00 9-5/8" test joint and purge air from system. 3/28/2017 328/2017 5.00 SURFAC WHDBOP BOPE P_ The BOPE was tested on 3/28/17 0.0 0.0 02:00 07:00 with 5" and 9-5/8" test joint to 250/3500 psi. Guy Cook of AOGCC waived witness Test Sequence as follows: With 9-5/8 Test joint 1) Annular, Mud Manifold valves 1,12,13, 14, and 4" Kill line, 4-1/2" IF Dart Valve 2) Upper Rams, Mud Manifold valves 9, 11 and Mezz Kill line, 4-1/2" IF Full Open Safety Valve 3) Upper Rams, Mud Manifold valves 8,10 and HCR Kill line 4) Upper Rams, Mud Manifold valves 6, 7 and HCR Kill line 5) Manually Operated Choke 6) Super Choke 7) Manual Kill, Mud Manifold valves 2 and 5 8) HCR Choke 9) Manual Choke With 5" Test Joint 10) Annular, and Upper IBOP 11) LPR's with 3-1/2 x 6" VBR's, and Lower IBOP 12) Blinds, Mud Manifold valves 3, 4, and 6 System Pressure = 3,050 psi PSI after closure = 1,800 psi 200 psi Attained = 9 seconds Full Pressure attained = 51 seconds N2 = 6 each @ 2,583 psi Pass / Fails Choke valve #8, greased and cycled, pass Page 8160 Report Printed: 61212017 Operations Summary (with Timelog Depths) lte 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time our (hr) Phase Op Code Activity Code Time P -TX Operation (ftKe) End Depth r(Ka) 3128/2017 3/28/2017 1.00 SURFAC WHDBOP RURD P RID testing equipment, blow down 0.0 0.0 07:00 08:00 choke and kill lines. Install GE wear bushing, ID- 12-3/8". 3/28/2017 3/28/2017 3.00 SURFAC CASING BHAH P Pick up BHA as per SLB, M/U 12-1/4" 0.0 413.0 08:00 11:00 MSi619 bit, Xceed, Telescope and arcVision. 3/28/2017 3/28/2017 2.00 SURFAC CASING TRIP P RIH with 5" DP up wt = 108k, OWN 413.0 2,022.0 11:00 13:00 100K. Monitor displacement via trip tank. 3/28/2017 3/28/2017 2.00 SURFAC CASING SLPC P Slip Cut 44' Drill line. Calibrate blocks. 2,022.0 2,022.0 13:00 15:00 3/28/2017 3/28/2017 1.00 SURFAC CASING PRTS P RU and flood lines Test surface casing 2,022.0 2,155.0 15:00 16:00 to 3000 PSI. charted 30 min (PASSED). 47 STKS to pressure up with 4 1/2 BBLS bleed back. 3/28/2017 3/28/2017 6.00 SURFAC CASING DRLG P Drill out shoe track from TOC at 2,155' 2,155.0 2,254.0 16:00 22:00 to 2,254' MD at 450 GPM 535 PSI 15% F/O 60 RPM, 71K tq, 2-20K WOB. Off bottom = 530- PSI UP WT =108K, DWN WT=100 K. ROT= 108K 5K TO. 3/28/2017 3/28/2017 0.50 SURFAC CASING DRLG P Drill 20' new hole in prep for FIT. 2,254.0 2,274.0 22:00 22:30 2,274' MD. 2,174' TVD. @ 512 GPM 682 PSI DPP. 17% F/O 60 RPM, 3- 6K TQ. 4K WOB Off BTM = 669 PSI Up WT111K,DWN=100K. ROT- . 108K 5K TQ. 3/28/2017 3/28/2017 0.50 SURFAC CASING CIRC P Circulate bottoms up plus to condition 2,274.0 2,274.0 22:30 23:00 mud prior to FIT. 9.5 in / out. 3/28/2017 3/29/2017 1.00 SURFAC CASING LOT P Perform LOT / PIT 2. 12.6 PPG 2,274.0 2,274.0 23:00 00:00 achieved @ 340 PSI. Total strokes = 8. Bled .2 BBLS back. 3/29/2017 3/29/2017 1.00 INTRM1 DRILL CIRC P Displace well to 9.2 LSND. 800 GPM 2,274.0 2,274.0 00:00 01:00 at 1000 PSI. Send down links to orient Xoeed due to quick tum. 3/29/2017 3/29/2017 5.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 2,274.0 2,928.0 01:00 06:00 2274' MD to 2928' MD, TVD= 2625'. Pump @ 800 gpm= 1039 psi w/ 20 % FO. Rotate @ 120 rpm w/ 71K Tq on, 4K Tq off. WOB= 1-81K, ECD= 9.7 ppg EMW with 9.2 ppg MW. ADT= 4.14, Bit hrs= 4.14, Total Jar hrs= 152.42. P/U= 120K, S/O= 102K, ROT= 116K. Max gas= 0. Obtain slow pump rates @ 2822' MD, TVD= 2569 Pump #1: 30 spm= 120 psi, 40 spm=150 psi. Pump # 2:30 spm= 120 psi, 40 spm= 140 psi. Page 9/50 Report Printed: 51212017 Operations Summary (with Timeiog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time End Time our (hr) Phase Op Code AcWity Code Time P-T-X Operation stmt Depth (d e) End Depth (flKa) 3/29/2017 3/29/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 2,928.0 3,950.0 06:00 12:00 2928' MD to 3950' MD, TVD= 2836'. Pump @ 926 gpm= 1605 psi w/ 22 % FO. Rotate @ 160 rpm w/ 13K Tq on, 8K Tq off. WOB= 6-9K, ECD= 9.82 ppg EMW with 9.2 ppg MW. ADT= 4.11, Bit hrs= 8.25, Total Jar hrs= _ 156.53. P/U= 123K, S/0= 89K, ROT= 106K. Max gas= 0. 2822' TVD SPR 1 - 30 SPM 120 / 40 SPM 150 SPR 2 - 30 SPM 120 / 40 SPM 140 3/29/2017 3/29/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 3,950.0 5,050.0 12:00 18:00 3950' MD to 5,050' MD, TVD= 3,000'. Pump @ 925 gpm= 1,902 psi w/ 22 % FO. Rotate @ 160 rpm w/ 1-13K Tq on, 7K Tq off. WOB= 6-9K, ECD= 10.09 ppg EMW with 9.4 ppg MW. ADTe: 4.38, Bit hrs= 12.63, Total Jar hrs= 160.91. 4,855' TVD/ 2,970' TVD/ MW=9.4/ 1730 PM SPR 1 - 30 SPM 150 / 40 SPM 180 SPR 2 - 30 SPM 150 140 SPM 180 3/29/2017 3/30/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 5,050.0 5,808.0 18:00 00:00 5,050' MD to 5,808' MD, TVD= 3,131'. Pump @ 925 gpm= 2.132 psi w/ 22 % FO. Rotate @ 100-160 rpm w/ 12K Tq on, 7-15K WOB, ECD= 10.10 ppg /Off Bottom -2,126 PSI, UP WT = 132 / OWN WT = 90K. ROT 112K w/8K TO // EMW with 9.4 ppg MW. ADTe: 4.06, Bit hrs= 16.69, Total Jar hrs= 164.97. 3/30/2017 3/30/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 5,808.0 6,659.0 00:00 06:00 5,808' MD to 6659' MD, TVD=3280'. Pump @ 925 gpm= 2415 psi w/ 22 % FO. Rotate Q 100-160 rpm w/ 14K Tq on, 4-15K WOB, ECD= 10.30 ppg / Off Bottom -2240 PSI, UP WT = 1501 OWN WT = 72K. ROT 115K w/8K To, 9.4 ppg MW. ADT= 4.2, Bit hrs= 20.89, Total Jar hrs= 169.17. Page 10/50 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log scan TimM e E Time Duf (hr) Phase OP Code Activity Cotle Time P -T -X Operation D Start e Depth (fit De End Depth (fixe) 3/30/2017 3/30/2017 6.00 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 6,659.0 7,405.0 06:00 12:00 6659' MD to 7405' MD, TVD=3422 '. Pump @ 925 gpm= 2515 psi w/ 22 % FO. Rotate @ 150-160 rpm w/ 13K Tq on, 4-17K WOB, ECD= 10.04 ppg / Off Bottom -2436 PSI, UP WT = 158 / DWN WT = 79K. ROT 115K w/12K TO, 9.4 ppg MW. ADT= 4.63, Bit hrs= 25.52, Total Jar hrs= 173.80. Obtain slow pump rates @ 6848' MD, TVD= 3305 Pump #1: 30 spm= 220 psi, 40 spm=240 psi. Pump # 2: 30 spm= 220 psi, 40 spm= 240 psi. 3/30/2017 3/30/2017 7.25 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 7,405.0 8,030.0 12:00 19:15 7405' MD to 8030' MD, TVD=3501'. Pump @ 750 gpm= 1775 psi w/ 21 % FO. Rotate @ 160 rpm w/1 5K TQ , 5- 15K WOB, ECD= 10.22 ppg / Off Bottom -1790 PSI, UP WT= 161 /DWN WT=82K. ROT 114K w/12K TO, 9.4 ppg MW. ADT= 5.42, Bit hrs= 30.94, Total Jar hrs= 179.22. Obtain slow pump rates @ 7,505' MD, TVD= 3,440'@ 13:15hrs Pump #1: 30 spm= 200 psi, 40 spm= 240 psi. Pump # 2: 30 spm= 200 psi, 40 spm= 240 psi. 3/30/2017 3/30/2017 0.75 INTRMI DRILL CIRC P Rotate and circulate bottoms up to 8,030.0 8,030.0 19:15 20:00 clean hole & send dwn links. from 8,030' MD to 7,983' MD @ 850 GPM ' 2,257PSI, 21% F/O. 120 RPM with 12K TQ. TOT slks = 7,822 Discuss with Anch tum requirements. 3/30/2017 3/30/2017 0.50 INTRMI DRILL DDRL P DDrill 12-1/4" Intermediate hole from 8,030.0 8,078.0 20:00 20:30 8,030' MD to 8,078' MD, TVD=. Pump @ 751 gpm= 1791 psi w/ 21 % FO. Rotate @ 160 rpm w/1 5K TQ , 7K WOB, ECD= 10.12 ppg / Off Bottom -1795 PSI, UP WT = 164 / OWN WT = 72K. ROT 118K w11 2K TO , 9.4 ppg MW. ADT= 1.36, Bit hrs= 31.22, Total Jar hrs= 179.5. 3/30/2017 3/30/2017 1.00 INTRM1 DRILL CIRC T Rotate and circulate bottoms ul while 8,078.0 8,078.0 20:30 21:30 in discussion with Anchorage over inability to gain desired directional turn. Rotating from 8,058'to 7,983' @ 850 GPM 2,229 PSI 120 RPM. 14K TO total strokes 11,947. Page 11150 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Tune End Tone Dur (hr) Mase Op Code AcWity Code Time P -T -X Operation Stan Depen (fIKB) End Depth (flKB) 3/30/2017 3/31/2017 2.50 INTRMI DRILL BKRM T BROOH from 8,078'to 7,418'@ 909 8,078.0 7,418.0 21:30 00:00 GPM ICP=2,462'22%F/0.150 RPM 15K TQ. Up WT 164K OWN 72K w/o pumping Prior to BROOK 8,056' MD 3,504' TVD MW PPG - 9.4 PPG. Time 2130 hrs. MP1 - 30 SPM 225PSI 40 SPM 275 PSI MP2 - 30 SPM 225PSI 40 SPM 275 PSI Perfom no flow check for 10 min prior to BROOH. (Passed) 3/31/2017 3/31/2017 6.00 INTRMI DRILL BKRM T BROOH from 7,418'to 5140' MD. 7,418.0 5,140.0 00:00 06:00 Circulating 900 SPM @ 2,410 PSI DPP 150 RPM @11KTO. ECD= 10.21 PPG. 97 UP WT. 3/31/2017 3/31/2017 7.00 INTRMI DRILL BKRM T BROOH from 5140'to inside casing 5,140.0 2,422.0 06:00 13:00 shoe @ 2208' MD. Circulating 900 SPM @ 2,145 PSI DPP 150 RPM @ 4K TQ. ECD = 10.15 PPG. 98 UP WT. Observed cuttings load increase 100% @ — 2700' MD and increase 300% @ 2450' MD. Circulating out large Gay/sand balls about 4" to 8" in diameter. 3/31/2017 3/31/2017 3.00 INTRMI DRILL TRIP T Monitor for flow (Static) and POOH on 2,422.0 182.0 13:00 16:00 elvators to 413' Stand back HW DP and prep to LD BHA 3/31/2017 3/312017 2.00 INTRMI DRILL BHAH T LD BHA #2 as per SLIMS DD. Monitor 182.0 0.0 16:00 1800 well for flow. (Static). 3/31/2017 3/31/2017 1.50 INTRMI DRILL BHAH T Clean dg floor and LD BHA3@ 0.0 0.0 18:00 19:30 outside. Pick up BHA#3 from outside and prepare to RIH. 3/31/2017 3/31/2017 3.00 INTRMI DRILL BHAH T PU Intermediate BHA #3 as per SLB 0.0 238.0 19:30 22:30 DO to 238'MD Monitor disp via TT. 3/31/2017 3/31/2017 1.25 INTRMI DRILL. TRIP T PU Non mag HWDC & HWDP to 425' 238.0 2,215.0 22:30 23:45 MD. Up WT63KDWN=71K. Continue to RIH to 2,215' MD UP 105K OWN 106K Monitor disp via TT. 3/31/2017 4/12017 0.25 INTRMI DRILL DHEQ T Shallow hole test of MWD / roll hole to 2,215.0 2,220.0 23:45 00:00 1.5% lube 656 GPM 893 PSI DPP. 22% F/O good test. UP WT = 108K Up. 99K OWN. 4/1/2017 4/1/2017 6.00 INTRMI DRILL TRIP T Circulate and rotate while RIH filling 2,220.0 7,998.0 00:00 06:00 every ten stands and performing check shot surveys. RIH fromt 2,210 MD - to - 7,998' MD... 675 GPM, 1270 PSI, 19% FIC, 20 RPM 4K TQ. MW in 9.3 - MW out 9.3+ Obtain SPR's and service washpipe. UP WT 107K DWN WT = 109K. ROT 106K. SPR @ 2,210' MD 2,137' TVD MW = 9.3 PPG Time 0030 - MP -1) 20 SPM - 100 PSI 130 SPM - 120 PSI MP -2) 20 SPM -100 PSI / 30 SPM - 120 PSI Page 12150 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 ..1qW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stad Time End Time Our hr ( ) Phase O Cots p Acb Code "ItY Time P4- X Operation Start Depth rt Ka) Erol Depth (RKa) 4/1/2017 4/1/2017 1.25 INTRMI DRILL CIRC T CBU to condition hole and remove 7,988.0 8,078.0 06:00 07:15 heavy mud post trip. Rotate and Recip from 7998' MD to 8078' MD, pump @ 650 gpm= 1600 psi, 20% FO, 50 rpm's W/ 12K Tq, ECD= 9.81, MW= 9.3 + ppg. P/U= 153K, S/0= 79K, ROT= 121 K. SPR @ 8,068' MD 3,504' TVD MW = 9.3+ PPG Time 0700 MP-1) 20 SPM-200 PSI / 30 SPM - 230 PSI MP -2) 20 SPM - 200 PSI / 30 SPM - 230 PSI 4/1/2017 4/1/2017 4.75 INTRMI DRILL DDRL P DDRIL from 8078' MD to 8,240' MD 8,078.0 8,240.0 07:15 12:00 3,520' TVD. 850 GPM 2,560 PSI DPP. 22% FID, 40 RPM, 15K TO, 6.5K WOB ECD = 9.83, UP WT = 150K, OWN WT = 79K, ROT = 123K, 13K To, ADT = 2.01, ART = .51, AST =1.5 BIT HRS=2.01, jar hrs= 181.51. 4/1/2017 4/1/2017 6.00 INTRMI DRILL DDRL P DDRIL from 8,240' MD to 8,535' MD 8,240.0 8,535.0 12:00 18:00 3,572' TVD. 635 GPM 1,618 PSI DPP. 22% F/O, 40 RPM, 15K To, 6.5K WOB ECD = 9.84, UP WT = 160K, OWN WT = 72K, ROT = 115K, 13K TO, ADT = 3.13, ART =.66, AST =2.47 BIT HRS=5.14, jar hrs= 184.64. 4/1/2017 4/2/2017 6.00 INTRMI DRILL DDRL P DDRIL from 8,240' MD to 8941' MD 8,535.0 8,941.0 18:00 00:00 3,520' TVD. 7750 GPM 2415 PSI DPP. 22% F/O, 40 RPM, 15K To, 15K WOB ECD = 9.94, UP WT = 150K, DWN WT = 70K, ROT = 116K, 14K To, ADT = 3.81, ART =.44, AST =3.37 BIT HRS=8.95, jar hrs= 188.45. SPR @ 8841' MD 3591' TVD MW = 9.5 PPG Time 2230 MP-1) 20 SPM-330 PSI /30SPM- 360 PSI MP-2) 20 SPM - 320 PSI 130 SPM - 340 PSI 4/2/2017 4/2/2017 6.00 INTRMI DRILL DDRL P DDrill 12-114" Intermediate hole from 8,941.0 9,538.0 00:00 0600 8941' MD to 9538' MD, TVD= 3612'. Pump @ 850 gpm= 3150 psi w/ 80% FO. Rotate @ 40 rpm's w/ 15K Tq on / 13K off. WOB= 4K, ECD= 10.3 ppg w/ 9.4 ppg MW. P/U 171 K, S/0= 81 K, ROT= 130K. ADT= 3.43, AST= .66, ART= 2.77, Total bit hours= 12.38, Total Jars hours= 191.88. Page 13150 ReportPrinted: 5/212017 Operations Summary (with Timeiog Depths) �j 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tnne End tone our (hr) Phase DP Code Activity Code Time P44 operafion Stan Depth (ItKB) End Depth (WB) 4/2/2017 4/2/2017 4.50 INTRM1 DRILL DDRL P DDrill 12-1/4" Intermediate hole from 9,538.0 9,743.0 06:00 10:30 9538' MD to 9743' MD, TVD= 3636'. Pump @ 650 gpm= 2300 psi w/ 20% FO. Rotate @ 40 rpm's w/ 15K Tq on / 13K off. WOB= 4K, ECD= 10.3 ppg w/ 9.5 ppg MW. P/U 184K, S/O= 77K, ROT= 130K. ADT= 2.27, AST= 1.48, ART= .79, Total bit hours= 15.01, Total Jars hours= 194.51. 4/2/2017 4/2/2017 1.50 INTRMI CASING CIRC P Obtain on bottom survey as per DO 9,743.0 9,691.0 10:30 12:00 and stand 1 stand back to 9691' MD. Pump 70 bbls of weighted high vis sweep and circulate sweep around. Pump @ 850 gpm= 3420 psi w/ 20% FO, Rotate @ 80 rpm's w/ 16K Tq. ECD= 10.3 ppg EMW. 4/2/2017 4/2/2017 0.25 INTRMI CASING OWFF P 9691 Observer well for flow. NOflow. 9,691.0 9,691.0 12:00 12:15 4/2/2017 4/2/2017 6.25 INTRMI CASING BKRM P BKRM OOH 9,691-7,955 MD UP WT 9,691.0 7,955.0 12:15 18:30 171 K. DWN = 87K. 850 GPM w/ICP = 3,290 PSI, FCP = 2,920 PSI. F/O 22%,40 RPM, 15K TQ. ROT WT 130K. Observed tight spot at 8,300' MD. 10.3 ECD. Circ and condition hole while backreamming. 4/2/2017 4/2/2017 0.25 INTRMI CASING OWFF P OWFF 1 Blow down top drive. 7,955.0 7,995.0 18:30 18:45 4/2/2017 4/3/2017 5.25 INTRMI CASING TRIP P POOH on elevators monitor 7,995.0 2,697.0 18:45 00:00 displacement via TT. UP WT = 177K DWN WT = 70K. Observe 30K overpull at 3,966', 3,490', 3,465' MD. 4/3/2017 4/3/2017 0.50 INTRMI CASING TRIP P Continue to POOH from 2,697'to 2,697.0 2,220.0 00:00 00:30 2,220' MD. up wt = 107K DWN = 106K 4/3/2017 4/3/2017 1.00 INTRM1 CASING CIRC P Pull stripping rubber and circulate 2,220.0 2,220.0 00:30 01:30 bottoms up while rotating and reciprocating from 2,220'- 2,130' MD. 850 GPM at 1,970 PSI. F/O 23% at 40 RPM 3-61K TQ. MW in / out 9.5 PPG. Dry job 11.4#. install strip rubber and BD TD. 4/3/2017 4/3/2017 1.00 INTRMI CASING TRIP P POOH from 2,220'to 425'MD. 2,220.0 425.0 01:30 02:30 Monitor disp via TT. 4/3/2017 4/3/2017 0.25 INTRMI CASING OWFF P Pull stripping rubber and monitor well 425.0 0.0 02:30 02:45 f1l0 min. dropped 1'. 4/3/2017 4/3/2017 2.75 INTRMI CASING BHAH P Stand back HWDP & collars. LD BHA 0.0 0.0 02:45 05:30 #3 per DD from 425'. Monitor well disp via TT. Trip disp = 90.6 BBLS. 4/3/2017 4/3/2017 3.00 INTRMI CASING RURD P Clean rig floor and surrounding area. 0.0 0.0 05:30 08:30 LD BHA on and off floor. Take measurements and photo's for Anch. Flush stack and pull wear bushing. Rig up casing running equipment Volant CRT, install bail extensions/ elevators/spiders and verify casing count. Page 14150 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Seed Time Ertl Time Our hr ( ) Phase O Cotle p ArAv Cotle ity Time P -T- X Operation slant Depth (MB) End Depth (1tKB) 4/3/2017 4/3/2017 3.50 INTRMI CASING PUTB P PJSM and RIH with 9 518" 40# casing 0.0 1,027.0 08:30 12:00 per pipe tally. fill on the fly with Volant CRT. top off every ten joints check float equip on joint Q. (passed). 2 BPM = 5% F/O, 5 BPM = 7% F/O. 8 BPM = 13% F/O. Torqing connections to 15K FT/LB. 4/3/2017 4/3/2017 3.00 INTRMI CASING PUTB P RIH with 9 5/8" 40# casing from 1027- 1,027.0 2,228.0 12:00 15:00 2228' MD, fill on the fly with Volant CRT. top off every ten joints. 15K TQ. 413/2017 413/2017 0.50 INTRMI CASING CIRC P Cir and condition mud. stage pumps 2,228.0 2,228.0 15:00 15:30 up to 6 BPM. ICP = 81 PSI. 8% F/O. UP WT= 116K, DWN WT= 116. ROT WT = 118 with 4K TQ.@ 20 RPM. 4/3/2017 4/3/2017 6.00 INTRMI CASING PUTS P Continue to RIH from 2228 - 4380' 2,228.0 4,380.0 15:30 21:30 MD. Inslaling Hydroform centralizers and stop rings on the fly. TQ conn to 15K. fill with Volant tool every 10. 4/3/2017 4/3/2017 1.00 INTRMI CASING CIRC P Mud weight found to be 9.8+ during 4,380.0 4,380.0 21:30 22:30 displacement. Stag up pumps to 6 BPM. ICP = 220 PSI. FCP 163 PSI. 8% F10 Mup weight in 9.4 Final mud weight out = 9.6 PPG. Pumped 3,490 strokes. Wt increase toll4K after shutting pumps dwn. 4/3/2017 4/4/2017 1.50 INTRMI CASING PUTB P Continue to RIH with 9 5/8" casing 4,380.0 5,075.0 22:30 00:00 installing Hydraform centralizers on rig floor. torque all conections to 15K. 4/4/2017 4/4/2017 3.00 INTRMI CASING PUTB P Continue to RIH with 9 5/8" casing as 5,075.0 6,410.0 00:00 03:00 per pipe tally. 15K TQ filling on the fly every 10 joints. 4/4/2017 4/4/2017 1.50 INTRMI CASING CIRC P Circulate bottoms up while RIH with 6,410.0 6,500.0 03:00 04:30 three joints to 6,500' MD. 6 BPM @ 230 PSI, 7% F10. Pumped a total of 3,800 STKS MW in 9.5 PPG. MWO 9.7 PPG. DWN WT 109K. 4/4/2017 4/4/2017 5.50 INTRMI CASING PUTB P Continue to RIH with 9 5/8" Hydril 521 6,500.0 8,816.0 04:30 10:00 Casing to 8,816' MD. all connections torqued to 15K with Volant tool. Fill on fly every 10 joints. 4/4/2017 4/4/2017 2.75 INTRMI CASING PUTB P C/O elevators and make up cross over 8,816.0 9,692.0 10:00 12:45 from 9 5/8" 521 to 9 5/8"563 casing. Continue to RIH with Hydril 563 casing to 9,565 MD. Torque all conenctions to 15K and fill on the fly with Volant tool. Top off every 10. 74K DWN WT. 4/4/2017 4/4/2017 0.25 INTRMI CASING PUTB P MU hanger and landing joint / pull 9,692.0 9,732.0 12:45 13:00 spiders and RIH to 9,732' MD 4/4/2017 4/4/2017 1.50 INTRMI CASING CIRC P Reciprocate casing from 9,732'-9,724' 9,732.0 9,732.0 13:00 14:30 MD conditioning mud. Stage pumps to 7 BPM. 296 GPM = 389 PSI, Up WT=268K. DWN WT=54K. Pumped total 22 BBIs. 9.5 PPG in / 10.3 out VIS 250 H2O @ 20. Page 16150 Report Printed: 5/212017 AftOperations Summary (with Timelog Uepths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Time End Time Our (hr) Phase Op Code Activity Code Time P -T -x Operation Start Depth (MB) End Depth(N(e) 4/4/2017 4/4/2017 2.25 INTRM1 CASING CIRC P Install cement hose and reciprocate 9,732.0 9,732.0 14:30 16:45 from 9,732'-9,724' MD. Staging pumps up to 8 BPM. 342 GPM = 408 PSI. UP WT=268K SWN WT=54K. 9.6 PPG in / 9.8 out Vis 78 1-12o @ 10. 4/4/2017 4/4/2017 0.75 INTRMI CASING HOSO P Challenges working pipe back down 9,732.0 9,732.0 16:45 17:30 after reciprocating this whole time. Setting down to 35k and slowly work through obstruction and land hanger on Ring. Continue to circulate at 8 BPM GPM = 342 PSI=408. 13,844 strokes pumped. Lost a total of 8 BBLS while RIH with 9 518" casing. 4/4/2017 4/4/2017 0.50 INTRMI CEMENT SFTY P Pre job with dg crew and 9,732.0 9,732.0 17:30 18:00 Schlumberger crews for cement program. Included situ ops with W WT installing SS in pipe shed and loader loading DP. 4/412017 4/4/2017 4.50 INTRMI CEMENT CMNT P PT all lines to 4,500 PSI ( passed). 9,732.0 9,732.0 18:00 22:30 Pump 60 BBLS 12.5 PPG mud push II @ 5 BPM. 260 PSI, 5% F/O. Drop bottom PLUG (9.34" OD). Pump 388 BBLS 15.8 PPG Class G cement @ 5.5 BPM. 250 PSI, 7% F/0. Drop top PLUG (9.16') OD. Chase with 10 BBLS fresh water @ 4 BPM , 90 PSI, 4% F/O. Changeover to rig pumps to displace cement with 9.5 PPG LSND @ 8 BPM, ICP = 193 6% F/O. Slow to 7 BPM, 192 PSI 9% F/0, @ 1550 Strokes. Observe 175 PSI pressure drop @ 6512 strokes. Slow rale to 5 BPM , 823 PSI @ 6690 Strokes. Slow rate to 4 BPM, 730 PSI @ 6,785 strokes. Slow rate to 2 BPM 785 PSI @ 7,030 strokes. Bump plug at 7,171 strokes (724 bbls). FCP =839. 3% F/O. Increase psi to 1,400 PSI and hold for 5 min. CIP @2216. Bleed down to 50 PSI and prep for final casing test. Lost a total of 24 BBLS during cement job. 4/4/2017 4/4/2017 1.00 INTRMI CEMENT PRTS P Test 9 5/8" casing L-80 40# hydril 9,732.0 9,732.0 22:30 23:30 5631521 mix to 3,500 PSIG and charted for 30 min. (PASSED). 10.8 BBLS to pressure up 1// 10.7 BBLS bled back. RD Cement hose and blow down. 4/4/2017 4/5/2017 0.50 INTRMI CEMENT RURD P RD Volannt CRT, 9 5/8" landing joint 9,732.0 9,732.0 23:30 00:00 and casing elevators. 4/5/2017 4/5/2017 0.50 INTRMI CEMENT RURD P Clean rig floor. BD Top drive drain 9,732.0 00:00 00:30 and flush stack. 4/5/2017 4/5/2017 2.50 INTRMI CEMENT W WSP P Rig up pack off running & testing tool 00:30 03:00 and RIH with same. Set packoff. Test to 5000 PSI for 20 min. (Passed). Sim ops of cleaning out cement valves and loading pipe shed with 5" DP Strap and install SS. Page 16/50 Report Printed: 51212017 r Operations Summary (with Timelog Depths) {t 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log aiad 7me End Time Dur (hr) Phase Op Code Ag vtty Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 4/5/2017 4/5/2017 3.50 INTRMI CEMENT RURD P Contiue to move SS to rig floor and 03:00 06:30 stage. Continue to strap and install 5" DP in shed. Move HWDP and RIH With 19 STNDs DP and 5 STNDs HWDP. 4/5/2017 4/52017 5.50 INTRMI CEMENT RURD P RIH PU 30 jls of HWDP / drift t 2.625". 06:30 12:00 POOH standing back HWDP & 19 STNDS DP installing SS 4' above pin end on the fly. Finish loading pipe shed. Continuing to install SS in pipe shed. 4/5/2017 4/512017 10.50 INTRMI CEMENT FULD P MU 62 stands of 5" DP via mousehole. 12:00 22:30 Sim ops continue installing SS in pipeshed. Freeze protecting 13 3/8" X 9 5/8" ANN. LOT = 700 PSI hold 5 min bleed off to 560 PSI. LRS pumped 150 BBLS of H2O, @ 3.5 BPM / pump 131.1 BBLS Isotherm freeze protect @ 2.1 BPM . ICP 700 PSI. FCP = 1135. Monitor for 15 min then bled off to 720 PSI. 4/5/2017 4/6/2017 1.50 INTRMI WHDBOP RURD P Begin preparation for BOPE test. 22:30 00:00 Witness waived by Matt Herrera at 1045PM 4/5/2017 via email. MU test joints and TIW darts. Set test plug and perform shell test. 4/6/2017 4/6/2017 5.00 INTRMI WHDBOP BOPE P Perform BOPE test. Test BOP 00:00 05:00 250/3500 PSI, using 5" and 4 1/2" test joint. Uppers are dressed with 9 5/8" were not tested. Accum draw down Initial am = 3,075. 1825 PSI after function of annular, 2# HCR's, 3X function of LPR's. 2,025 obtained in 8 sec. Full system pressure obtained in 48 sec. 6 BTL average = 2,593 PSI. BOP test witness waived by Matt Herrera w/ AOGCC on 4/5/2017 2248 hrs. 4/6/2017 4/6/2017 1.00 INTRM1 WHDBOP RURD P Blow dawn and rig down all testing 05:00 06:00 equipment. Drain stack / pull test plug and install wear bushing. 4/6/2017 4/6/2017 2.00 INTRMI CEMENT BHAH P PJSM / PU BHA as per DD to 338' 0.0 338.0 06:00 08:00 MD. Monitor displacement via TT. 4/6/2017 4/6/2017 2.75 INTRMI CEMENT TRIP P RIH on DP to 6,455' MD monitor 338.0 6,455.0 08:00 10:45 displacement via TT. UP WT = 155K - -- DWN WT= 64K 4/6/2017 4/6/2017 1.25 INTRMI CEMENT DHEQ P Fill pipe and test MWD. w/ 480 GPM 6,455.0 6,583.0 10:45 12:00 at 1,150 PSI. 16% F/O, + downlink. Press test new washpipe, BD TD. Confine RIH to 6,965' MS. 4/6/2017 4/6/2017 1.75 INTRMI CEMENT TRIP P Continue to RIH to 8,350' MD. 6,583.0 8,350.0 12:00 13:45 Observe DWN WT increwase to 48K. Kelly up fill pipe. Up WT 178K, Dwn WT 50K 4/6/2017 4/62017 1.75 INTRMI CEMENT SLPC P Slip and Cut 75' drill line. Simops 8,350.0 8,350.0 13:45 15:30 while circulating @ 3 BPM 127 GPM @244 PSI. 5% F/O. BD Top drive. 4/6/2017 4/6/2017 0.25 INTRMI CEMENT TRIP P RIH to 8450 MD. Monitor Disp via TT. 8,350.0 8,400.0 15:30 15:45 Up WT 178K, DWN WT=48K. Watch WT decrease to 42K. Page 17/50 Report Printed: 51212017 . Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sted Time End Time our (Ar) Phase Op Catla Activity Code Time P-T-X Operation (ft De sten Depth End Depth (tlKB) 4/6/2017 4/6/2017 4.00 INTRMI CEMENT COCF P Wash down from 8,400' MD to cleacn 8,400.0 9,715.0 15:45 19:45 above float collar. No cement witnessed. 4/6/2017 4/6/2017 2.25 INTRM1 CEMENT DRLG P Begin drilling Shoe track to 9,743' MD 9,715.0 9,763.0 19:45 22:00 then 20' of new hole to 9,763' MD 3,640' TVD. No indication of cement on top of plug. 500 GPM @ 1,419 PSI. 15% F/O. 50 RPM 20K TQ. 7,854 strokes pumped. 4/6/2017 4/6/2017 1.00 INTRMI CEMENT FIT P BD top drive and dg up to perform FIT. 9,763.0 9,763.0 22:00 23:00 at 9,706' MD. Achieve 13.4 Mud WT Equivalent Wf700 PSI. Pumped 17 Strokes and bled back 1.5 BELS. 4/6/2017 417/2017 1.00 PROD1 DRILL DDRL P Drill 8 3/4" Lower Lateral Prod hole 9,763.0 9,803.0 23:00 00:00 from 9,763 to 9,803' MD 3,636' TVD. @ 500 GPM 1,473 PSI 16% F/O. 50 RPM to 7K TQ. 7-16K WOB with ECD's 11.05 off bottom = 1,470 PSI, Up WT= 175K, Own WT=45K. ROT =118K. 16KTQ. MW=9.3+, 4/7/2017 47/2017 0.50 PROD? DRILL CIRC P Continue to displace well to 9.3# Flo- 9,803.0 9,803.0 00:00 00:30 thu w 245 GPM, 1200 PSI, 15% F/0, 80 RPM, 9K TQ. Obtain TQ & Drag & SPR's P/U 168K, S/O 98K, ROT = - 126K, 9K TO. SPR @ 9795' MD / 3,644' TVD MW= 9.3 PPG Time 00:25 MP-1 20 SPM-240 PSI 30 SPM - 300 PSI MP-2 20 SPM-240 PSI 30 SPM - 290 PSI OA 300 PSI 4/7/2017 4/7/2017 1.00 PROD? DRILL DDRL P Drill 8 3/4" hole from 9,803 MD 3,627' 9,803.0 9,879.0 00:30 01:30 TVD - 9,879' MD. , W 500 GPM, 1500 PSI, 16% F/O 80 RPM, 9K TQ WOB ECD=11.16. Max gas units= 0, Up WT= 164K, Dwn WT = 101 K, ROT= 126K, 8K TQ. ADT = 1.61, Total bit hours 1.61, Total Jars = 1.61. 4/7/2017 4/7/2017 0.75 PROD1 DRILL SRW P Obtain 30'surveys & roll test as per 9,879.0 9,896.0 01:30 02:15 MWD. 4/7/2017 4/7/2017 4.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 9,896' MD - 9,896.0 10,214.0 02:15 06:15 10,214 MD —3,610 TVD., W 550 GPM, 1720 PSI, 17% F/O 150 RPM, 6K TO WOB ECD=11.47. Max gas units = 0, Up WT = 158K, Own WT = 95K, ROT = 125K, 8K TQ. ADT = 2.41, Total bit hours 4.02, Total Jars = 4.02 4/7/2017 4/7/2017 5.75 PROD1 DRILL DDRL P Drill 8 3/4" hole from 10,214' MD - 10,214.0 10,569.0 06:15 12:00 10,569 MD —3,596 TVD., W 550 GPM, 1760 PSI, 17% F/O 150 RPM, 11K TQ WOB ECD=11.54. Max gas units = 0, Up WT = 158K, Own WT = 95K, ROT = 125K, 8K TQ. ADT = 3.91, Total bit hours7.93, Total Jars = 7.93 Page 18150 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tima EM Time Dur (hoPhase Op Code Activity Code Time P -T -X Operation start Depth (fLKB) EM Depth (MB) 4/7/2017 4/7/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 10,569' MD - 10,569.0 11,107.0 12:00 18:00 11,107 MD —3,590 TVD. , W 550 GPM, 1847 PSI, 20% F/O 150 RPM, 5K TQ WOB ECD=11.67. Max gas units = 0, Up WT = 153K, Dwn WT = 88K, ROT = 121K, 10.5K TQ. ADT = 4.66, Total bit hours 12.59, Total Jars = 12.59 4/7/2017 4/8/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 11,107' MD - 11,107.0 11,550.0 18:00 00:00 11,550 MD —3,597 TVD., W 560 GPM, 1917 PSI, 18% F/O 180 RPM, 14K TQ 7K-WOB ECD=11.77. Max gas units = 0, Up WT = 161 K, Dwn WT = 86K, ROT = 119K, 12.5K TQ. ADT = 4.64, Total bit hours 17.23, Total Jars = 17.23 4/8/2017 4/8/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 11,550' MD - 11,550.0 12,073.0 00:00 06:00 12,073 MD —3,588' TVD. W 570 GPM, 2,030 PSI, 17% F/O 180 RPM, 15K TQ 4K-WOB ECD=11.9. Max gas units = 0. Up WT = 167K, Dwn WT = 84K, ROT = 122K, 12-13K TQ. ADT = 4.32, Total bit hours 21.55, Total Jars = 21.55 SPR @ 11,876' MD / 3,584' TVD MW= 9.2 PPG Time 04:26 MP -1 30 SPM -400 PSI 40 SPM - 500 PSI MP -2 30 SPM -500 PSI 40 SPM - 500PS1 OA 250 PSI 4/8/2017 4/8/2017 6.00 PROD1 DRILL DDRL P Drill 83/4" hole from 12,073' MD- 12,073.0 12,600.0 06:00 12:00 12,600' MD —3,588' TVD. W 570 GPM, 2,070 PSI, 18% F/O 180 RPM, 14-15K TO 4K-WOB ECD=11.98. Max gas units = 0 , Up WT = 168K, Dwn WT = 85K, ROT = 120K, 13K TQ. ADT = 4.73, Total bit hours 26.28, Total Jars = 26.28 SPR @ 12,352' MD / 3,589' TVD MW= 9.3 PPG Time 09:13 MP -1 30 SPM -480 PSI 40 SPM - 560 PSI MP -2 30 SPM -500 PSI 40 SPM - 560PSI OA 250 PSI 4/8/2017 4/8/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 12,600' MD - 12,600.0 13,123.0 12:00 18:00 13,123' MD --3,592' TVD. W570 GPM, 2,216 PSI, 19% F/O 180 RPM, 16K TQ 5K-WOB ECD=12.32. Max gas units = 0, Up WT = 172K, Dwn WT = 70K, ROT = 119K, 14.5K TO ADT = 4.42, Total bit hours 30.70, Total Jars = 30.70 Page 19150 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hr) Phase Op Code Activity Cade Tme P -T -X Operation scan Depth (8KB) End Depth (flKB) 4/8/2017 4/9/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from13,123' MD - 13,123.0 13,615.0 18:00 00:00 13,615' MD --3,591' TVD. W570 GPM, 2,290 PSI, 19% F/O 180 RPM, 16K TQ 6K-WOB ECD=12.47. Max gas units = 0, Up WT = 175K, Own WT = 65K, ROT = 118K, 14.7K TQ. ADT = 4.55, Total bit hours 35.25, Total Jars = 35.25 SPR @ 13,584' MD / 3,592' TVD MW= 9.3 PPG Time 23:30 MP -1 30 SPM -520 PSI 40 SPM - 600 PSI MP -2 30 SPM -520 PSI 40 SPM - 600 PSI OA 250 PSI Total losses for 24 hr period = 91 BBLS 4/9/2017 4/9/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from13,615' MD — 13,615.0 14,200.0 00:00 06:00 3,591' TVD to 14,200' MD - 3,581 TVD. W 570 GPM, 2,310 PSI, 17% F/O 180 RPM, 18K TQ 4K-WOB ECD=12.48., Up WT= 194K, Own WT = N/A, ROT = 124K, 16K TO. ADT = 4.54, Total bit hours 39.79, Total Jars = 39.79 4/9/2017 4/9/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 14,200 MD - 14,200.0 14,722.0 06:00 12:00 3,581 TVD to 14,722' M - 3,578 TVD. W 570 GPM, 2,265 PSI, 19% F/O 180 RPM, 19K TQ 8K-WOB ECD=12.32. , Up WT = 198K, Dwn WT = N/A, ROT = 123K, 15K TQ. ADT = 4.55, Total bit hours 44.34, Total Jars = 44.34 SPR @ 14,249' MD /3,580' TVD MW= 9.3 PPG Time 06:20 MP -1 30 SPM -560 PSI 40 SPM - 660 PSI MP -2 30 SPM -560 PSI 40 SPM - 660 PSI OA 210 PSI Page 20150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime End Time Wr(hr) Phase op code Activity Code 7me P -T -X Cpeiation Start Depth (RKa) End OapN (RKB) 4/9/2017 4/9/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 14,722' MD - 14,722.0 15,420.0 12:00 18:00 3,578 TVD to 15,420' MD - 3,575' TVD. W 570 GPM, 2,350 PSI, 19% F/O 180 RPM, 20K TQ 5K-WOB ECD=12.48. , Up WT = 194K, Dwn WT = N/A, ROT = 109K, 15K TQ. ADT = 4.46, Total bit hours 48.80, Total Jars =48.80 SPR @ 15,194' MD /3,574' TVD MW= 9.3 PPG Time 15:45 MP -1 30 SPM -520 PSI 40 SPM - 620 PSI MP -2 30 SPM -520 PSI 40 SPM - 620 PSI OA 200 PSI 4/9/2017 4/10/2017 6.00 PROD1 DRILL DDRL P Drill 8 3/4" hole from 15,420' MD - 15,420.0 16,031.0 18:00 00:00 3,575' TVD to 16,031' MD - 3,549' TVD. W 570 GPM, 2,500 PSI, 19% F/O 180 RPM, 22K TQ 8K-WOB - ECD=12.29. , Up WT = 21 OK, Dwn WT = N/A, ROT = 115K, 18K TQ. ADT = 4.62, Total bit hours 53.42, Total Jars =53.42 4/10/2017 4/10/2017 4.50 PROD1 DRILL DDRL P Drill 83/4"hole from 16,031'MD- 16,031.0 16,433.0 00:00 04:30 3,549' TVD to 16,433' TVD . W 500 GPM, 2,250 PSI, 16% F/O 150 RPM, 19K TQ 6K-WOB ECD=12.51. , Up WT = 220K, Dwn WT = N/A, ROT = - 135K, 17K M. ADT = 3.07, Total bit hours 56.49, Total Jars =56.49 SPR @ 16,035' MD /3,549' TVD MW= 9.2 PPG Time 00:17 MP -1 30 SPM -500 PSI 40 SPM - 600 PSI MP -2 30 SPM -500 PSI 40 SPM - 600 PSI OA 210 PSI 4/10/2017 4/10/2017 1.50 PROD1 CASING SRVY P Obtain bottom survey - RB stand @ 16,433.0 16,316.0 04:30 06:00 CBU with rot & Recip from 16,404' to 16,316' MD. 530 GPM, 2,510 PSI, 17% F/O 150 RPM, 16-19K TQ, ECD=12.51. Total stks pumped = 8,500. MW in=9.3 Mud WT out 9.3+, Obtain SPR's tq&Drag. Up WT = 135K. Down link xceed t 0/0. TO called. SPR @ 16,402' MD /3,515' TVD MW= 9.3 PPG Time 06:00 MP -1 30 SPM -650 PSI 40 SPM - 720 PSI MP -2 30 SPM -650 PSI 40 SPM - 720 PSI OA 200 PSI Page 21150 Report Printed: 5/212017 Operations Summary (with Timeiog Depths) r, 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall Time Em! Time our (ho Phase Op Code Activity Code Time P-T-X Operation SM Depth (flXa) End OePm (flKB) 4/10/2017 4/10/2017 1.50 PROD1 CASING OWFF P OWFF (Well Breathing) measure 16,316.0 16,404.0 06:00 07:30 quanity to a timed VIS cup. Initial time 3 sec. Final time 161 sec t fill 1 QT vis cup. Drop 2.38" drift with 107' tail on stand 170. (HWDP stand #11). 4/10/2017 4/10/2017 4.50 PROW CASING BKRM P BROOH from 16,404' MD to 14,914' 16,404.0 14,914.0 07:30 12:00 MD. W/570 GPM @ 2,160 PSI, 17% F/O. 180 RPM, 15K TO, ECD = 11.75. ROT 110. 4/10/2017 4/10/2017 6.00 PROD1 CASING BKRM P BROOH from 14,914' MD to 12,500' 14,914.0 12,500.0 12:00 18:00 MD. W/570 GPM @ 21,950 PSI, 17% FlO. 180 RPM, 10.51K TO, ECD = 11.38. ROT 109. 4/10/2017 4/11/2017 6.00 PROD1 CASING BKRM P BROOH from 12,500' MD to 10,180' 12,500.0 10,180.0 18:00 00:00 MD. W/570 GPM @ 21,950 PSI, 17% F/O. 180 RPM, 10.5K TQ, ECD = 11.38. ROT 109. Noted heavy pull at 10,554' MD worked area until no OP. 4/11/2017 4/11/2017 2.00 PROD1 CASING BKRM P BROOH from 10,180' MD to 9,706' 10,180.0 9,706.0 00:00 02:00 MD. Pumping 500 GPM @ 1350 PSI, 17% FlO. 80 RPM, 7-11 K TQ, ECD = 10.9 ppg PU wt 158k, SO wt 98k. 4/11/2017 4/11/2017 1.50 PROD1 CASING CIRC P Circulate two bottom's up while 9,706.0 9,706.0 02:00 03:30 reciprocate and rotate f/ 9706' to 9614'. Pumping 570 gpm w/ 1600 psi, 17% Flow out. Rotate 80 rpm w/ 9k ft Ibs of torque. ECD's 10.85 ppg. Mud weight in 9.3+, mud weight out 9.4 ppg. Pumped 1036 bbls. 4/11/2017 4/11/2017 0.50 PROD1 CASING OWFF P Blow down the top drive. Monitor well- 9,706.0 9,706.0 03:30 04:00 static. 4/11/2017 4/11/2017 3.50 PROD1 CASING BKRM P BROOH from 9706' MD to 7150' MD. 9,706.0 7,150.0 04:00 07:30 Pumping 570 GPM @ 1300 PSI, 17% F/O. Rotate 80 RPM w/ 5K TQ, ECD = 10.9 ppg PU wt 158k, SO wt 98k. 4/11/2017 4/11/2017 1.25 PROD1 CASING CIRC P Pump a 30 bbl hi vis sweep while 7,150.0 7,150.0 07:30 08:45 reciprotate and rotate from 7150' to 7059'. Pumping 570 gpm w/ 1360 psi, 17% flow out. Rotate 80 rpm w/ 4-6k ft lbs of torque. Pumped 710 We. PU wt 135k, SO wt 11 Ok. 4/11/2017 4/11/2017 0.25 PROD1 CASING OWFF P Blow down the top drive. Monitor well- 7,150.0 7,150.0 08:45 09:00 static. 4/11/2017 4/11/2017 0.75 PROD1 CASING TRIP P Trip out on elevators 117150' to 6493'. 7,150.0 6,493.0 09:00 09:45 Monitor displacement on the trip tank- ok. 4/11/2017 4/11/2017 0.25 PROD1 CASING CIRC P Pump 20 bbl dry job. Install stipping 6,493.0 6,493.0 09:45 10:00 rubbers and air slips. Blow down top drive. 4/11/2017 4/11/2017 2.00 PROW CASING TRIP P Trip out on elevators f/ 6493'to 2516'. 6,493.0 2,516.0 10:00 12:00 Monitor displacement with the trip tank. PU wt 112k. Outer annulus pressure 100 psi. 4/11/2017 4/11/2017 1.50 PROD1 CASING TRIP P Continue pulling OOH on elevators f/ 2,516.0 338.0 12:00 13:30 1 2516'- 338', monitoring displacement via trip tank. PUW 69k Page 22150 Report Printed: 5/212017 Operations Summary (with Timeiog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stall Time End Time our(hr) ( ) Phase op code Activit' code Time P -T -X Opembon Start Depih (WB) End Depth(OKB) 4/11/2017 4/11/2017 0.25 PROD1 CASING OWFF P Monitor well for flow at top of HWDP- 338.0 338.0 13:30 13:45 well static. 4/11/2017 4/11/2017 2.75 PROD1 CASING SHAH P Pull OOH f/ 338'to surface, racking 338.0 0.0 13:45 16:30 back jars and NMDC's and laying down remaining BHA per SLB. Bit graded 0 -1 -CT -S -X -1 -NO -TD. Note: Retrieved 2-3/8" rabbit on top of jars, observed wire tangled up, had slight issue pulling out of pipe. 4/11/2017 4/11/2017 0.50 PROD1 CASING BHAH P Clean/ clear rig floor of BHA 0.0 0.0 16:30 17:00 equipment. 4/11/2017 4/11/2017 1.75 COMPZI CASING RURD P Rig up to run 4-1/2" liner with GBR 0.0 0.0 17:00 18:45 double -stack tongs. Confirm pipe count and running order in shed. 4/11/2017 4/12/2017 5.25 COMPZI CASING PUTB P PJSM. RIH w/ 4-1/2" 12.6ppf L-80 0.0 3,124.0 18:45 00:00 TXP-m lower completion per tally to 3124' MD, PUW 77k, SOW 75k. Baker -lock pin and box end of float collar. Use JelLube Run-NSeal dope and torque to 7400 ft -lbs. Install free- floating centralizer on every joint and install stop ring 6' above pin on joints directly above swell packers. OA pressure at midnight = 75 psi 4/12/2017 4/12/2017 3.75 COMPZI CASING PUTB P PJSM. RIH w/ 4-1/2" 12.6ppf L-80 3,124.0 6,448.0 00:00 03:45 TXP-m lower completion per tally from 3124' MD to 6448' MD. Use JetLube Run -N -Seal dope and torque to 7400 ft -lbs. Install free-floating centralizer on every joint and install stop ring 6' above pin on joints directly above swell packers. 4/12/2017 4/12/2017 1.50 COMPZI CASING PUTB P Rig up handling equipment. Pick up 6,448.0 6,512.0 03:45 05:15 Baker MLZXP liner hanger/pkr and Schlumberger slim MWD tool. Scribe MWD to liner hanger pre marked bottom mark of the liner hanger (matched to bottom index inside of liner top). Fill liner tieback sleeve with Xan-Plex. PU wt 89k, SO wt 81 k, block wl 43k. 4/12/2017 4/12/2017 0.50 COMPZ1 CASING RUNL P Pickup 1st stand of 5" drill pipe. 6,512.0 6,603.0 05:15 05:45 Circulate 15 bbls, pumping 100 gpm w/ 325 psi and 5% flow out. Blow down the top drive. 4/12/2017 4/12/2017 1.00 COMPZI CASING RUNL P Run 4-1/2" liner in the hole on total of 6,603.0 8,215.0 05:45 06:45 4 stands 5" dp, then 5" rip w/ Western Well Tools super sliders on the dp (4- 6' above pin end) from 6603' to 8215'. Total of 18 stands in the hole. Running speed 907minute. Monitor displacement on the trip tank. Page 23160 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Cade Activity Cade Time PJA Operation Start Depth (nKS) End Depth (MG) 4/12/2017 4/12/2017 3.75 COMPZI CASING OLOG P Fill pipe. Shallow hole test MWD, 8,215.0 8,363.0 06:45 10:30 pumping 110 gpm w/ 420 psi and 6% flow out. Start logging f/ 8215' (shoe depth) to find K-15 marker @ 1906' MD. Log to 8363'. Found K-15 @ -1905' MD. 4/12/2017 4/12/2017 1.00 COMPZI CASING RUNL P Blowdown topdrive and RIH liner on 5" 8,363.0 9,719.0 10:30 11:30 DP w/ Western Well Tools super sliders on the dp (4-6' above pin end) from 8363' to 9719'. Running speed 907minute. Pipe would not self -fill fast enough so rigged up fill -up hose and filled on the fly, monitoring displacement on pit #5. 4/12/2017 4/12/2017 1.00 COMPZI CASING CIRC P Circulate 70 x bbls (to top of first 9,719.0 9,719.0 11:30 12:30 slotted joint) at 3 bpm, 550 psi, 6% F/O. Obtain parameters at shoe. PUW 128k, SOW 104k, ROT 117k @ 25rpm, 5.4k Tq. Blow down topdrive. 4/12/2017 4/12/2017 4.25 COMPZI CASING RUNL P RIH w/ liner on total of 4 x stands 5" 9,719.0 15,952.0 12:30 16:45 DP slick, 81 x stands 5" DP w/ super sliders, and 15 x stands 5" HWDP w/ super sliders to 15952' MD, filling pipe on the fly with fill -up hose, topping off every 5 x stands, and monitoring displacement on pit #5. 4/12/2017 4/12/2017 1.00 COMPZ1 CASING PACK P Pick up 1 x single 5" DP (31.58'), RIH 15,952.0 15,966.0 16:45 17:45 and mark pipe at set depth of 15966' MD. Break circulation w/ 110 gpm, 640 psi, 6% f/O. Orient MLZXP hanger to 22° left of highside. PUW 200k, SOW 114k,. 127 bbls pumped. 4/12/2017 4/12/2017 1.50 COMPZI CASING PACK P Drop 1.625" ball and pump down at 15,966.0 15,966.0 17:45 19:15 2.5 bpm, 615 psi, 6% F/O for 727 strokes. Reduce rate to 1.5 bpm, 380 psi, 4% F/O and seat ball at 1413 strokes. 4/12/2017 4/12/2017 0.75 COMPZI CASING PACK P Increase pressure to 1900 psi and 15,966.0 9,466.3 19:15 20:00 slack off 60k weight to set hanger - observe hanger set. Pressure up to 2500 psi and start staging up in 200 psi increments, holding for -30 seconds, to function pusher tool, up to 3400 psi. Hold at 3400 psi and then increase up to 4000 psi to release from liner, observing shear at -3600 psi. Bleed off pressure, and pick up with bleeder open to confirm released from liner - observe PUW 186k. Pick up 5'to expose dogs. Observe SOW 136k. Rotate at 25 rpm, 7.5k Tq, ROT 165k and slack off 60k on liner top to confirm set. Pick up and work out torque and slack off with no rotary to tag liner top - observe tag 1' deep. Liner lop packer set at 9,466.28' MD 4/12/2017 4/12/2017 0.50 COMPZI CASING PRTS P Line up to pump down IA and 9,466.3 9,466.3 20:00 20:30 pressure test liner top packer to 3500 psi 110 min, charted - good test. Bleed off pressure. Page 24/50 Report Printed: 51212017 Operations Summary (with Timeiog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our Ile) Phase op Code Activity Code Time P-T-X Openadon Start DepAn (111<13)13)a) End Ceplh (flKa) 4/12/2017 4/12/2017 1.00 COMPZ1 WELLPR RURD T Troubleshoot inability to function /BOP 9,466.3 9,466.3 20:30 21:30 to open position. Attempt to equalize pressure unsuccessfully. Set slips and slowly break out top drive and function IBOP open. 4/12/2017 4/12/2017 1.00 COMPZI WELLPR CIRC P Lay down 5" DP single and pick up to 9,466.3 9,466.3 21:30 22:30 high circulation point, total of 30'. Pump 25 bbl corrosion-inhibited brine and chase with 156 bbls 9.3ppg FloThru at 258 gpm, 510 psi, 9% F/O. 4/12/2017 4/12/2017 0.50 COMPZI WELLPR OWFF P Rack back stand of 5"HWDP, blow 9,466.3 9,466.3 22:30 23:00 down top drive, and monitor well for 10 minutes - well static. 4/12/2017 4/13/2017 1.00 COMPZI WELLPR TRIP P Pull OOH on elevators to 8414' MD, 9,466.3 8,414.0 23:00 00:00 racking back 5" HWDP w/ super sliders and monitoring displacement on pit#5. PUW 155k. Observed pipe pulling dry. OA pressure at midnight = 150 psi 4/13/2017 4/13/2017 0.50 COMPZI WELLPR TRIP P Continue to pull out of the hole on 8,414.0 8,041.0 00:00 00:30 elevators from 8414' MD to 8041', racking back 5" HWDP and 5" DP w/ super sliders and monitoring displacement on pit #5. PUW 155k. Observed pipe start pulling wet once on drill pipe. 4/13/2017 4/13/2017 0.25 COMPZI WELLPR CIRC P Pump a 20 bbl dry job. Blow down the 8,041.0 8,041.0 00:30 00:45 1 1 1 top drive. 4113/2017 4/13/2017 3.75 COMPZI WELLPR TRIP P Continue to pull out of the hole on 8,041.0 91.0 00:45 04:30 elevators from 8041' MD to 91', racking back 5" DP w/ super sliders and monitoring displacement on pit #5. Calculated displacement 74.8 bbls, Actual displacement 92 bbls. 4/13/2017 4/13/2017 0.75 COMPZI WELLPR BHAH P Lay down Baker liner running tools 91.0 0.0 04:30 05:15 and Schlumberger MWD. Observe good indication on dog sub to confirm liner lop packer is set. Observed ball on seat in running tool and all o-rings, etc. on tool. 4/13/2017 4/13/2017 1.25 COMPZI WELLPR DHEQ P Pick up Baker FJD tool. Test w/ pump 0.0 0.0 05:15 06:30 rale to see when 8 disconnects. With 3 x 18's installed, stage up pumps and observe tool function at 500 gpm. Remove 18's and install 3 x 20's and re-test. Observe tool function at 500 gpm. Remove 20's and intsall 3 x 24's and re-lest. Observe tool function at 500 gpm. Remove 24's and re-test with no nozzles installed. Stage up pumps w/ 400 gpm / 375 psi, 450 gpm 1490 psi, 500 gpm / 588 psi, and 510 gpm / 655 psi - observe tool function at 510 gpm. Lay down tool and blow down the top drive. Sim Ops: Mobilize whipstock tools to rig floor. Page 25150 Report Printed: 51212017 " Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Shetn a End Time our (hr) (d Phase O cod. p AC11vl Cotle H Time P-- TX Operation Slart Depm (ftKB) End Depth(ftKS) 4/13/2017 4/13/2017 1.75 PROD2 WHPST BHAH P Pre job safety meeting on picking up 0.0 0.0 06:30 08:15 Whipstock assembly. Make up mills and MWD. Orient MWD to bolt hole of window mill. From bolt hole, mark 180 deg. MWD highside was left of mark. Calculated to be 121.04 deg clockwise to match mark on pipe. Set back in derrick. 4/13/2017 4/13/2017 2.00 PROD2 WHPST BHAH P Make up whipstock assembly: Gent 0.0 87.1 06:15 10:15 Whipstock, debris sub, string magnet, drain sub, blank sub, safety disconnect, unloader, seals, pup jt and MLZXP Anchor = 87.09' to bottom of collet on anchor. Align lowest point of guide to match face of whipstock. Lowerwhipstock assembly in the hole. 4/13/2017 4/13/2017 1.25 PROD2 WHPST BHAH P Make up stand with mills and 87.1 210.0 10:15 11:30 Schlumberger MWD, Connect stand with mills to whipstock with 35k brass bolt. Lower milling assembly in the hole. Continue to build milling assembly BHA above the MWD with 3 x string magnets. RIH to 210'. 4/13/2017 4/13/2017 125 PROD2 WHPST TRIP P.. Run whipstock assembly in hole on 5" 210.0 1,621.0 11:30 12:45 DP / HWDP with super sliders installed at max 60 ff/min running speed, monitoring displacement via trip tank. SOW 88k. Note: Utilized same pipe for running whipstock as we did for running liner. 4/13/2017 4/13/2017 0.25 PROD2 WHPST DHEQ P Fill pipe and perform shallow hole test 1,621.0 1,621.0 12:45 13:00 w/ 450 gpm, 470 psi, 17% F/O - good test. SOW 93k with pipe full. 4/13/2017 4/13/2017 0.25 PROD2 WHPST TRIP P Continue RIH on 5" DP with super 1,621.0 1,948.0 13:00 13:15 sliders installed f/ 1621'- 1948'MD, monitoring displacement via pit #5, SOW 93k. 4/13/2017 4/13/2017 1.00 PROD2 WHPST DLOG P RIH on 5" DP with super sliders 1,948.0 2,078.0 13:15 14:15 installed logging f/ 1948'- 2078' MD (1860'- 1990' MWD sensor) across K- 15 marker at 200 ft/hr running speed w/ 450 gpm, 460 psi, 17% F/O - observe K-15 marker at 1904' MD. SOW 96k. Blowdown topdrive. 4/13/2017 4/13/2017 5.75 PROD2 WHPST TRIP P RIH on 5" DP / HWDP with super 2,078.0 9,372.0 14:15 20:00 sliders installed f/ 2078'- 9372' MD, filling pipe every 20 x stands, monitoring displacement on pit #1. PUW 178k, SOW 1301k. Note: Swapped rig to generator power at 20:00 hrs due to continuing issue of hi-line unable to supply enough power to rig while drilling. 4/13/2017 4/13/2017 0.75 PROD2 WHPST WPST P Make up topdrive to stand #98, fill 9,372.0 9,465.0 20:00 20:45 pipe, RIH to 9430', and orient whipstock assembly to V left of highside at 450 gpm, 1240 psi, 16% FlO, parameters with pumps on PUW 164k, SOW 124k. RIH to 9465'. Page 26150 Report Printed: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time End Time Dur(ho Phase Op Cots Activity Code Time P -T -X Opemtlon s Depth (rt11 Ke) End Depth (ftKB) 4/13/2017 4/13/2017 0.75 PROD2 WHPST WPST P RIH and latch whipstock anchor into 9,465.0 9,392.0 20:45 21:30 MLZXP packer w/ 450 gpm, 1240 psi, 16% F/O, PUW 164k, SOW 125k, tagging up on depth at 9480.2' MD (9479.1' MD to collet latch point). Observe toolface shift to 20" left of highside once anchor latched in, confirming correct orientation. Pick up 1 O overpull to 173k to confirm latched in. Slack off 35k weight to shear bolt - no shear observed. Pick up and observe PUW decrease to 162k and pipe traveling, indicating bolt had sheared. Also observed toolface shift to 14° left of highside, further indicating bolt had sheared. Obtain parameters at 450 gpm, 1240 psi, 16% F/O, PUW 162k, SOW 123k, ROT 142k @ 5 rpm, 6k Tq. Kill rotary, RIH and position window mill at bolt, rotate at 5rpm and observe torque stall out quickly to 1Ok, confirming boll had sheared and whipstock set in place. Top of slide @ 9392' MD Bottom of slide @ 9409.6' MD 4/13/2017 4/14/2017 2.50 PROD2 WHPST MILL P Mill whipstock bolt and window in 9- 9,392.0 9,400.0 21:30 00:00 5/8" casing to 9400' MD @ 450 gpm, 1250 psi, 16% NO, 80-90 rpm, 1-3k WOB, 8-10k Tq. Pumps off PUW 178k, SOW 130k. Pumps on PUW 162k, SOW 122k, ROT 140k w/ 7k Tq. Note: See increase in erratic torque as lower mill transitioned onto slide and then stabilized out after -2 ft OA at midnight = 250 psi 4/14/2017 4/14/2017 4.75 PROD2 WHPST MILL P Mill window f/ 9400'- 9409' MD w/ 450 9,400.0 9,409.0 00:00 04:45 gpm, 1280 psi, 16% F/O, 90-100 rpm, 8-11k Tq, 1-3k WOB, MW iNout 9.3/9.3+ with 50 vis, pumping 2 x 15 bbl 300 -funnel vis sweeps per Baker. Minimal metal shavings seen across the shakers and no additional cuttings seen with sweeps. 4/14/2017 4/14/2017 0.50 PROD2 WHPST MILL P Observed ROP fall off to 50 minutes 9,409.0 9,409.0 04:45 05:15 for 1 ftjust prior to upper mill tmnsifioning onto slide and window mill coming off slide. Pick up 7ft and start reaming slowly back to bottom - observe string stall out at 17k tq. Pick up and wipe section to top of window, observing several short overpulls of 10 -20k. Slowly ream back to bottom. Note: Observe shakers blinding off and started seeing some dumps of metal shavings coming over scalpers. Page 27150 ReportPrinted: 512/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log alga Tone End Time Dur (hr) Phase Op Code Activity Coda Time P-T-X Operation Start Depth (Po(B) End Depth (flKB) 4/14/2017 4/14/2017 3.25 PROD2 WHPST DDRL P Mill window f/ 9409'- 9415' MD w/ 450 9,409.0 9,415.0 05:15 08:30 gpm, 1280 psi, 16% F/O, 90-100 rpm, 8-12k Tq, MW in/out 9.3ppg w/ 50 funnel vis, staging up WOB from 2k to 8k as window mill and lower mill transitioned off slide. Pumped 1 x 30 bbl 300 funnel-vis sweep, observing slight increase in shavings over shakers and temporary blinding off of screens. Note: Phase 1 conditions fieldwide at 08:00 his. 4/14/2017 4/14/2017 0.25 PROD2 WHPST REAM P Observe ROP not picking up it was 9,415.0 9,415.0 08:30 08:45 expected to once lower mill off slide. Pick up and wipe section to top of window and ream back to bottom w/ 450 gpm, 1230 psi off him SPP, 16% F/O, 100 rpm, 7k off btm Tq. 4/14/2017 4/14/2017 1.25 PROD2 WHPST DDRL P Mill window f/ 9415'- 9425' MD w/ 450 9,415.0 9,425.0 08:45 10:00 gpm, 1280 psi, 16% F/O, 100-120 rpm, 8-13k Tq, WOB 6-9k. Observe ROP initially increase to 18 fl/hr then start falling off to 6 fl/hr w/ 9k WOB. 4/14/2017 4/14/2017 0.75 PROD2 WHPST DDRL P Pick up and wipe section to top of 9,425.0 9,429.0 10:00 10:45 window. Ream back to bottom and mill window f/ 9425'- 9429' MD w/ 450 gpm, 1280 psi, 16% F/O, 120 rpm, 9- 13k Tq. 3-6 f /hr ROP w/ 9-101k WOB. Upper mill transition off slide at 9429' MD. 4/14/2017 4/14/2017 0.50 PROD2 WHPST DDRL P Continue milling out gauge hole in 9,429.0 9,430.0 10:45 11:15 formation f/ 9429'- 9430' MD w/ 450 gpm, 1270 psi, 120 rpm, 9-12k Tq, 9- 10k WOB. 4/14/2017 4/14/2017 0.25 PROD2 WHPST REAM P Pick up and wipe section to top of 9,430.0 9,430.0 11:15 11:30 window. Circulate at top of window and pump 30 bbl 300-vis sweep then ream down to bottom w/ 450 gpm, 1350 psi, 16% F/O, 100 rpm, 7-1 Ok Tq. 4/14/2017 4/14/2017 2.75 PROD2 WHPST DDRL P Continue milling out gauge hole in 9,430.0 9,438.0 11:30 14:15 formation f/ 9430'- 9438' MD w/ 450 gpm, 1300 psi, 120-125 rpm, 9-12k Tq, 9-11k WOB. Total of 9' of 8-3/4" hole milled past bottom of window. 4/1412017 4/14/2017 1.00 PROD2 WHPST CIRC P Pick up to top of window and circulate 9,438.0 9,377.0 14:15 15:15 hole clean w/ 450 gpm, 1300 psi, 16% F/O, 100 rpm, 7-11k Tq, reciprocating pipe above window, total of 781 bbls pumped, MW in/out 9.3ppg w/ 58 vis. Obtain parameters and take SPR's. PUW 188k, SOW 124k with pumps off - SPRs @ 9377' MD 3601' TVD, MW=9.30 ppg, 15:15 hours MP#1: 30 spm=440 psi, 40 spm=500 psi. MP #2: 30 spm=440 psi, 40 spm=500 psi. Page 28150 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time EM rime ( r) our(hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (fa(B) End Depth (fit®) 4/14/2017 4/14/2017 0.25 PROD2 WHPST TRIP P Trip milling assembly through window 9,377.0 9,377.0 15:15 15:30 to bottom and pull back to top of window at 600 ft/hr running speed, observing minimal drag across window of 1-3k, PUW 188k, SOW 124k. 4/14/2017 4/14/2017 0.50 PROD2 WHPST TRIP P Rack back 3 x stands to 9186', pick up 9,377.0 9,282.0 15:30 16:00 1 x stand slick 5" DP and RIH to 9282' MD. Blow down top drive. Note: Swap rig to hi -line power at 16:00 hrs. 4/14/2017 4/14/2017 2.00 PROD2 WHPST FIT P Rig up test equipment and line up to 9,282.0 9,282.0 16:00 18:00 pump down drill pipe and IA and purge air out of lines. Perform FIT at top of window, 9392' MD / 3602.9' TVD, with 9.3ppg to 805 psi surface pressure, giving a 13.6ppg EMW. 2 bbls pumped / 2 bbls returned using mud pump #2. Rig down test equipment and blow down lines. Note: On first test using mud pump #1, required more than expected volume of 5.5 bbls to pressure up system. Lined up mud pump #2 and re -tested, only requiring 2 bbls to pressure up system. 4/14/2017 4114/2017 1.50 PROD2 WHPST SLPC P Slip / cul drilling line and calibrate 9,282.0 9,282.0 18:00 19:30 amphion system. 4/14/2017 4/14/2017 0.50 PROD2 WHPST SVRG P Service and inspect topdrive and 9,282.0 9,282.0 19:30 20:00 blocks. 4/14/2017 4/14/2017 1.00 PROD2 WHPST TRIP P Pull OOH on elevators N 9282'- 8069', 9,282.0 8,069.0 20:00 21:00 racking back 5" HWDP, monitoring displacement via pit #1. 4/14/2017 4114/2017 0.50 PROD2 WHPST CIRC P Pump dry job, blow down top drive, 8,069.0 8,069.0 21:00 21:30 and install power slips. 4/14/2017 4/15/2017 2.50 PROD2 WHPST TRIP P Pull OOH on elevators V 8069'- 4676' 8,069.0 4,676.0 21:30 00:00 MD, adjusting top collars on each super slider as needed per W WT, monitoring displacement via pit #1. OA pressure at midnight = 150 psi 4115/2017 4/15/2017 5.50 PROD2 WHPST TRIP P Pull OOH f/4676' - 122' MD, racking 4,676.0 122.0 00:00 05:30 back 5" DP and changing out worn super sliders per W WT, monitoring displacement on pit #1. Note: Adjust super slider lop collars on stands #63 - 45 and swap placement of bottom / top super slider collars on stands #44 - 5. Replace total of 4 x collars and 1 x slider due to significant wear. 4/15/2017 4115/20172.50 PROD2 WHPST BHAH P PJSM. Pull OOH and lay down milling 122.0 0.0 05:30 08:00 assembly. Observe pockets on each magnet full - clean off magnets, recovering -15 gallons of debris. Upper 8-3/4" watermelon mill was in - gauge. Clean/clear rig floor of BHA. Page 29150 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stag Time End Time our (hr) Phase Op Catle ActiNly Code Time P -T -X Operation Stet Depth (We) End Depth(tiKe) 4/15/2017 4/15/2017 1.00 PROD2 WHPST PULD P Lay down 9 x stands of 5" DP from off- 0.0 0.0 08:00 09:00 drillers side via mousehole. 4/15/2017 4/15/2017 1.00 PROD2 WHPST W W WH P Make up stack washer and jet stack to 0.0 0.0 09:00 10:00 clear out any metal debris and cycle rams. Lay down stack washer. 4/15/2017 4/15/2017 2.50 PROD2 WHDBOP RURD P Pull wearbushing, Install test plug, and 0.0 0.0 10:00 12:30 Rig up to test BOPE. Rig up 5' test joint and purge all air out of system with water. Perform initial shell test 250 / 3500 psi. Service lopdrive and blocks and mobilize BHA equipment to Floor while obtaining final confirmation from AOGCC rep whether or not witness is waived. 4/15/2017 4/15/2017 5.25 PROD2 WHDBOP ROPE P Test BOPE w/ 5" and 4-1/2" test joints, 0.0 0.0 12:30 17:45 250 / 3500 psi for 5 / 5 min, witness waived by AOGCC rep Jeff Jones. Test Sequence as follows: With 5" Test joint 1) Annular, Choke valves #1,12,13, 14, 4" Kill line, and 4-1/2" IF Dart Valve 2) Annular, Choke valves #9, 11, Mezzanine Kill line valve, and 4-1/2" IF Full Open Safety Valve 3) Annular, Choke valves #8,10, and HCR Kill line 4) Annular, Choke valves #6, 7, and Upper IBOP 5) Annular, Super choke, and Manual Choke - tested to 2000 psi high 6) Annular, Choke valves #2, 5, Manual Kill, and Lower IBOP 7) 3-1/2" x 6" Lower pipe rams Pull 5" TJ 8) Blind rams, Choke valves #3 and 4 With 4-1/2" Test Joint 10) Annular and HCR choke 11) Annular and Manual choke 12) 3-1/2" x 6" Lower pipe rams System Pressure = 3,000 psi PSI after closure = 1,700 psi 200 psi Attained = 8 seconds with 2 x electric pumps Full Pressure attained = 57 seconds with 2 x electric pumps and 2 x air pumps 6 x bottle Nitrogen backup Average pressure = 2,542 psi Test all gas and pit sensors - pass. 4/15/2017 4/15/2017 1.00 PROD2 WHDBOP KURD P Blow down and dg down test 0.0 0.0 17:45 18:45 equipment. Pull test plug, Drain stack, and Install wearbushing. Page 30150 Report Printed: 512/2017 { Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slad Depth Start -rim EM Tme Ouch (7 Phase op Code AcbVi Code b ix Time P-- opemhan (flKB) Ena Depth (mca) 4/15/2017 4/152017 3.75 PROD2 WHPST SHAH P PJSM. Confirm pipe count and 0.0 - 398.0 18:45 22:30 running order in derrick. Pick up 8-3/4" Motor Drilling BHA #7 per SLB, picking up 8-3/4" Baker T606X PDC bit w/ 6 x 16's, 1.5` Mud Motor w/ 7/8 5 -stage power section (0.28 revs/gal) and 8-5/8" straight -bladed stabilizer, 8- 518" NM Integral spiral -bladed Stabilizer, NM XO, 6-3/4" PeriScope, 6 -3/4" TeleScope, and 6-3/4" GyroPulse. Scribe per SLB/Gyrodata. Pick up 1 x stand 6-3/4" NMDC's w/ 8- 9/16" NM stabilizer that was racked back in derrick and RIH. Pick up 3 x singles 5" HWDP from pipe shed followed by jar stand that was racked back in derrick (1 x 6-1/4" Hydraulic jar w/ 2 xjoints 5" HWDP). RIH to 398' MD. MWD to Motor offset = 42.67° GWD to Motor offset = 260.07° 4/15/2017 4115/2017 0.50 PROD2 WHPST BHAH P RIH w/ 3 x stands 5" DP from off- 398.0 721.0 22:30 23:00 driller's side. Pick up Baker X-treme magnets from pipe shed (3 x magnets w/ 2 x crossovers left made up together after milling run) and RIH to 721' MD. 4/15/2017 4/16/2017 1.00 PROD2 WHPST TRIP P RIH w/5"DID stands f/721'-2142' 721.0 2,142.0 23:00 00:00 MD, monitoring displacement via pit _ #1. PUW 107k, SOW 107k OA pressure at midnight = 100 psi 4/16/2017 4/16/2017 4.00 PROD2 WHPST TRIP P RIH w/ 5" DP from 2142'- 8956' MD, 2,142.0 8,956.0 00:00 D4:00 monitoring displacement via pit #1. SIMOPS: Stage 4 x vac trucks by pits / rockwasher and prep for displacement. 4/16/2017 4/16/2017 1.50 PROD2 WHPST DISP P PJSM. Kelly up to stand #88 and 8,956.0 9,240.0 04:00 05:30 displace well from 9.3ppg FloThru to new 9.3ppg FloThru. Pump 30 bbl hi - vis pill followed by 822 bbls 9.3ppg FloThm w/ 545 gpm, 1750 psi, 17% F/O, initial ECD 11.33 ppg, Final ECD 10.77 ppg, 20 rpm, 8k Tq. While displacing, RIH slowly w/ 3 x stands to 9232' MD. After displacement finished on stand #90, kill rotary and orient to 20' left of highside. PUW 158k, SOW 94k, ROT 125k. 4/16/2017 4/16/2017 0.50 PROD2 WHPST TRIP P Trip in through window with BHA f/ 9,240.0 9,418.0 05:30 06:00 9240'- 9418' MD. Observe brief 15k drag at lop of window as bit passed through and then 2-5k drag across window. Tag up on gauge hole @ 9418' MD w/ 5k weight. 4/162017 4/16/2017 0.50 PROD2 WHPST WASH P Stage up pumps to 450 gpm, 1322 9,418.0 9,438.0 06:00 06:30 psi, 15% F/O, 10.57 ppg ECD, orient string per DD and wash to bottom. Page 31/50 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL rime Log Sbtl Time End Time Our (hr) Phase Op COW Acfi^Code Time P -T -X Opermon Slart Oeplh (ftKe) End Mph (111<13) 4/16/2017 4/16/2017 2.50 PROD2 DRILL DDRL P DDrill 8-314" hole V 9438'to 9548' MD 9,438.0 9,548.0 06:30 09:00 wl 450 gpm, On btm SPP 1415 psi, Off btm SPP 1306 psi, 14% RO, 10 rpm, 9.5k Tq, 3-12k WOB, PUW 158k, SOW 94k, ROT 122k w/ 8k Tq, MW 9.2+ ppg, AST 0.80, ART 0.17, ADT 0.97, Bit hrs 0.97, Jar hrs 57.46. Note: Swap rig to generator power at 08:00 hrs to allow for work on transformer for hi -line power. 4/16/2017 4/16/2017 1.50 PROD2 DRILL DDRL P Observe string start taking weight with 9,548.0 9,557.0 09:00 10:30 upper 8-9/16" stabilizer -8' down on the slide @ 9548' MD. Set down 15k weight, pick up and observe 30k overpull. Repeat two additional times with same results. Slack off to 125k HL and engage rotary at 5 rpm, 9k Tq and Drill V 9548'- 9557' MD w/ 450 gpm, On Btm SPP 1380 psi, Off Btm SPP 1330 psi, 14% F/O, 10.52ppg ECD, 5 rpm, 8-9k Tq 4/16/2017 4/16/2017 1.50 PROD2 DRILL DDRL P DDrill 8-3/4" hole V 9557'to 9615' MD, 9,557.0 9,615.0 10:30 12:00 3617' TVD w/ 450 gpm, On btm SPP 1441 psi, Off Non SPP 1400 psi, 14% F/O, 10 rpm, 9k Tq, 3-15k WOB, PUW 157k, SOW 94k, ROT 125k w/ 8k Tq, MW 9.4 ppg, AST 0.29, ART 0.27, ADT 0.56, Bit hrs 1.53, Jar hrs 58.02. 4/16/2017 4/16/2017 1.25 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 9615'- 9660' MD, 9,615.0 9,660.0 12:00 13:15 3614' TVD w/ 450 gpm, On btm SPP 1460 psi, Off btm SPP 1400 psi, 14% _ F/O, 25 rpm, 10k Tq, 4k WOB, PUW 159k, SOW 95k, ROT 120k 9k Tq, MW 9.2 ppg, AST 0, ART .25, ADT .25. SPRs @ 9615' MD 3617' TVD, MW=920 ppg, 12:35 hours MP#1: 30 spm=340 psi, 40 spm=420 psi. MP #2: 30 spm=320 psi, 40 spm=400 psi. Note: Interference on MWD surveys cleaned up after MWD sensor was -100' out from window (sensor depth of 9509' MD). 4/16/2017 4/16/2017 2.25 PROD2 DRILL DDRL P DDrill 8-3/4" hole V 9660'- 9805'MD, 9,660.0 9,805.0 13:15 15:30 3614' TVD w/ 450 gpm, On btm SPP 1460 psi, Off btm SPP 1400 psi, 14% F/O, 25 rpm, 10k Tq, 4k WOB, PUW 159k, SOW 95k, ROT 120k W 9k Tq, MW 9.2 ppg, AST 0.77, ART 0.96, ADT 1.73, Bit hrs 3.51, Jar hrs 60.00. Page 32/50 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (M) Phase Op Code Activity Cade Time PJA Operafion Start Oeplh (flKB) End Oeplh (ftKB) 4/16/2017 4/16/2017 2.00 PROD2 DRILL CIRC T Observe higher than expected motor 9,805.0 9,745.0 15:30 17:30 yields and projections indicate bit will be out of zone too much if we continue. Discuss path forward with town. Pick up off bottom and circulate / reciprocate pipe f/ 9787' to 9745' MD wl 450 gpm, 1380 psi, 14% F/O, PUW 159k, SOW 95k, ROT 120k wl 9k Tq while waiting. Note: Rig swap to hi -line power at 16:20 hrs after modifications made to transformer - power is now being delivered correctly to rig and functioning well. 4/16/2017 4/16/2017 0.50 PROD2 DRILL TRIP T Decision made to perform open -hole 9,745.0 9,660.0 17:30 18:00 sidetrack. Pull OOH f/ 9745'- 9660' MD, monitoring displacement on pit #1. PUW 159k, SOW 95k, ROT 120k w/ 8k Tq. 4/16/2017 4/16/2017 0.75 PROD2 DRILL KOST T Begin troughing f/ 9660'to 9611' MD 9,660.0 9,660.0 18:00 18:45 w/ 450 gpm, 1380 psi, 14% F/O. 4/16/2017 4/16/2017 1.00 PROD2 DRILL DDRL T Perform open hole sidetrack at 9660' 9,660.0 9,701.0 18:45 19:45 MD per DD. Slide 0.8 It and begin rotating @ 80 rpm, 1 O Tq, Ok WOB, 450 gpm, 1380 psi (total bit revs = 206 rpms). Continue drilling to 9701' MD. Note: Decision was made to perform conservative open -hole sidetrack by rotating instead of sliding to minimize risk of obtaining too high of a dogleg and dropping us below plan. 4/16/2017 4/16/2017 0.75 PROD2 DRILL KOST T Ream through sidetrack section f/ 9,701.0 9,701.0 19:45 20:30 9701' to 9617'w/ 450 gpm, 1350 psi, 14% VO, 80 rpm, 9.5k Tq. Pick up above sidetrack point, kill rotary and RIH, tagging up at 9701' MD - sidetrack confirmed. 4/16/2017 4/16/2017 1.25 PROD2 DRILL DDRL T DDrill 8-3/4" hole f/ 9701'- 9805' MD, 9,701.0 9,805.0 20:30 21:45 361 8'TVD w/ 450 gpm, On btm SPP 1450 psi, Off btm SPP 1380 psi, 14% F/O, 30 rpm, 10k Tq, 3k WOB, PUW 159k, SOW 98k, ROT 120k w/ 91k Tq, MW 9.2 ppg, AST 0.46, ART 0.69, ADT 1. 15, Bit him 4.66, Jar hrs 61.15. 4/16/2017 4/16/2017 1.25 PROD2 DRILL SRVY P Perform multiple survey check shots 9,805.0 9,798.0 21:45 23:00 per SLB and Gyrodata and obtain SPR's. Downlink to set GWD into memory mode and perform calibration per Gyrodata. SPRs @ 9798' MD 3618' TVD, MW=9.20 ppg, 22:55 hours MP#1: 30 spm=310 psi, 40 spm=400 psi. MP #2: 30 spm=300 psi, 40 spm=390 psi. Page 33150 Report Printed: 51212017 ,' Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slap Time Em! Time Durft) Please Op Code A vlly Code Time P -T -X Operation a Dem SI(flXB) End 4 pr (exB1 4/16/2017 4/17/2017 1.00 PROD2 DRILL TRIP P Pull OOH f/ 9798'- 9335' MD, 9,798.0 9,335.0 23:00 00:00 monitoring displacement via pit #1. PUW 159k, SOW 95k. Stop at 9630' MD and trip through sidetrack section with no pumps/ no rotary to 9680' MD - no issues. At 9600' MD, orient to 20° left of highside and continue pulling BHA through window and up into casing - no issues. OA pressure at midnight = 200 4/17/2017 4/17/2017 7.50 PROD2 DRILL TRIP P Pull OOH on elevators f/ 9335'- 721' 9,335.0 721.0 00:00 07:30 MD, monitoring displacement via pit #1. Obtain GWD surveys at every connection, ensuring string is stationary for 2 minutes starting from the when driller finished breaking out stand, as per GyroData hand. Perform sensor calibration every 1000' MD or 25° INC change (whichever comes first) as per GyroData hand. 4/17/2017 4/17/2017 1.25 PROD2 DRILL SHAH P Monitor well for flow at top of BHA and 721.0 662.0 07:30 08:45 hold PJSM - well static. Pull OOH f/ 721'- 682'. Clean and lay down 3 x Baker Xtreme magnets. Recover 1 x full 5 gallon bucket of debris off magnets. 4/17/2017 4/17/2017 0.25 PROD2 DRILL TRIP P Pull OOH f/682'-398', racking back 3 682.0 398.0 08:45 09:00 stands of 5" drill pipe. 4/17/2017 4/17/2017 1.00 PROD2 DRILL TRIP P Stand back jar stand and 1 xstand of 398.0 111.0 09:00 10:00 5" HWDP f/ 398'to 211'. Stand back 1 x stand of 6-3/4" NMDC's to 111'. 4/17/2017 4/17/2017 0.50 PROD2 DRILL SHAH P Pull tools from the 6-3/4" Gyro Pulse 111.0 80.0 10:00 10:30 collar. Lay down BHA from 11 V to 80'. 4/17/2017 4/17/2017 0.75 PROD2 DRILL SHAH P Pull OOH f/ 80' to surface, breaking 80.0 0.0 10:30 11:15 out bit and laying down remaining BHA. Observed damaged gauge cutters, most likely attributed to circulating / displacing fluid inside casing. Bit graded 0 -3 -BT -S -X -1 -CT -TD. Calculated fill 86 bbls, actual 94.6 Wis. 4/17/2017 4/17/2017 0.75 PROD2 DRILL SHAH P Clean and clear floor of BHA tools. 0.0 0.0 11:15 12:00 4/17/2017 4/17/2017 0.50 PROD2 DRILL SVRG P Crew change. Prepare BHA. Service 0.0 0.0 12:00 12:30 rig. Open and inspect saver sub on the top drive. Needs changed, will do above the window. 4/17/2017 4/17/2017 0.25 PROD2 DRILL SFTY P Pre job safety meeting on picking up 8 0.0 0.0 12:30 12:45 -3/4" Rotary steerable BHA. Page 34150 ReportPrinted: 51212017 - Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sta4 Time End Time our (hr) Phase Op code Activity Code Time P-T-X Operafian (rt De Shit Depth End Depth (NCB) 4/17/2017 4/17/2017 2.25 PROD2 DRILL SHAH P Make up BHA # 8 as per 0.0 370.0 12:45 15:00 Schlumberger Directional driller to 370'. Pick up 8-3/4" Smith X616 Axeblade PDC bit w/ 6 x 16's, Xceed 675 RSS w/ dummy float and 8-5/8" stabilizer, 6-3/4" Periscope, 6-3/4" TeleScope, NM XO, 8-5/8" NM Stabilizer w/ ported flapper float, 1 x 6- 3/4" NMDC, 8-518 NM Stabilizer, 2 x 6- 3/4" NMDC's, Saver sub, 3 x 5" HWDP, 6-1/4" Hydraulic jar, and 2 x 5" HWDP. 4117/2017 4/17/2017 5.00 PROD2 DRILL TRIP P RIH w/ BHA #8 on 5" DP stands with 370.0 8,890.0 15:00 20:00 no super sliders f/ 370' to 6901' MD and with 5" DP with super sliders f/ 6901' - 8890' MD, filling pipe every 20 x stands and monitoring displacement via pit #1. Shallow hole test MWD on first fill - good test. PUW 150k, SOW 100k. 4/17/2017 4/17/2017 1.50 PROD2 DRILL SVRG P PJSM. Change outworn 4-1/2" IF 8,890.0 8,890.0 20:00 21:30 saver sub for new one and service topddve, monitoring well via pit #1 - well static, no losses observed. 4/17/2017 4/17/2017 1.00 PROD2 DRILL TRIP P RIH wl BHA #8 on 5" DP stands with 8,890.0 9,715.0 21:30 22:30 super sliders 11 8890'to 9715' MD, monitoring displacement via pit #1. PUW 152k, SOW 100k. Observe 0-1k drag running bit across slide and out into open hole. Observe 5-15k drag f/ 9447'- 9517' MD. 4/17/2017 4/18/2017 1.50 PROD2 DRILL SRW P Obtain surveys and roll-checks per 9,715.0 9,805.0 22:30 00:00 SLB at 9715', 9745', 9775', 9790', and 9800' MD to allow for effective batch - corrections of surveys once we start drilling. Obtain SPR's. PUW 149k SOW 98k, ROT 115k. Continue to bottom at 9805' MD. SPRs @ 9800' MD 3618' TVD, MW=9.30 ppg, 23:45 hours MP#1: 30 spm=260 psi, 40 spm=340 psi. MP #2: 30 spm=260 psi, 40 spm=340 psi. OA pressure at midnight = 220 psi. 4/18/2017 4/18/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 9805'to 10394' 9,805.0 10,394.0 00:00 06:00 MD, 3598' TVD w/ 550 gpm, 1670 psi, Off btm SPP 1600 psi, 17% F/O, ECD 11.10 ppg, 100-170 rpm, 12k Tq, 2-8k WOB, PUW 159k, SOW 91 k, ROT 110k w/ 10k Tq, MW 9.3 ppg, Max gas 116 units, ADT 4.16, Bit him 4.16, Jar hrs 69.2. Concretions @ 9971'- 9976', 9980'- 9982'. 10061'- 10065', 10389' - 10394' MD. Note: At 10210' MD, observed shakers start trying to blind off and running wet with 200 API screens on all three shakers. Page 35/50 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) (" 1 Phase O Code P ACINI Cole ry Time P-T- X Opeaeon Start Depth (rt De End Depth (flKa) 4/18/2017 4118/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 10394' to 10920' 10,394.0 10,920.0 06:00 12:00 MD, 3598' TVD w/ 550 gpm, 1730 psi, Off btm SPP 1700 psi, 18% F/O, ECD 11.43 ppg, 100-180 rpm, 14-17k Tq, 2 -8k WOB, PUW 160k, SOW 77k, ROT 105k wl 16k Tq, MW 9.3 ppg, Max gas 521 units, ADT 4.22, Bit hrs 8.38, Jar hrs 73.42. Concretions @ 10394'- 10401', 10460'- 10470', and 10717'- 10722', Crossed 12' DTW fault @ 10406' MD and 13' DTE fault @ 10585' SPRs @ 10788' MD 3611' TVD, MW=9.30 ppg, 11:30 hours MP#1: 30 spm=340 psi, 40 spm=440 psi. MP #2: 30 spm=340 psi, 40 spm=420 psi. 4/18/2017 4/18/2017 0.50 PROD2 DRILL CIRC T Observed fluid loss over shakers 10,920.0 10,920.0 12:00 12:30 increasing significantly. Pick up off bottom at 10920' MD, drop flow rate to 174 gpm, 463 psi, and circulate / reciprocate while screening down shakers to 170 API screens and moving mud. Recycle fluid from rockwasher to pits per mud engineer and add in new fluid. Stage pumps up to 500 gpm, 1446 psi and ream back to bottom. 4/18/2017 4/18/2017 5.50 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 10920'to 11348' 10,920.0 11,348.0 12:30- 18:00 MD, 3605' TVD w/ 550 gpm, 1665 psi, Off btm SPP 1650 psi, 17% F/O, ECD 11.22 ppg, 100-180 rpm, 15k Tq, 5k WOB, PUW 160k, SOW 79k, ROT 119k w/ 12k Tq, MW 9.3 ppg, Max gas 101 units, ADT 2.68, Bit hrs 11.06, Jar hrs 76.10. Concretions drilled at 11315'- 11330'. Page 36150 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(M) Phase Op Code Activity Cotla Time P -T-% Operation Start Depth (WB) End Depth (flKB) 4/18/2017 4/19/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 11348'to 11819' 11,348.0 11,819.0 18:00 00:00 MD, 3576' TVD w/ 550 gpm, 1730 psi, Off btm SPP 1700 psi, 18% F/O, ECD 11.48 ppg, 120-180 rpm, 18k Tq, 5- 10k WOB, PUW 167k, Unable to get slackoff weight, ROT 110k w/ 16k Tq, MW 9.2 ppg, Max gas 160 units, ADT 5.06, Bit hrs 16.12, Jar hrs 81.16. Concretions drilled at 11442'- 11452', 11546'- 115571,11586'- 11590', and 11638'- 11641'. Crossed -30' DTE fault at 11522' MD. Note: Lost ability to get slackoff weight at midnight at 11819' MD. Fluid continue to run wet off the shakers. Recycle fluid from rockwasher and perform new mud dilutions per mud engineer. Observe sticky / oily cuttings coming over shakers. SPRs @ 11725' MD 3585' TVD, MW=9.20 ppg, 23:05 hours MP#1: 30 spm=360 psi, 40 spm=440 psi. MP #2: 30 spm=360 psi, 40 spm=440 psi. OA pressure at midnight = 280 psi 4/19/2017 4/19/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 11819'to 12293' 11,819.0 12,293.0 00:00 06:00 MD, 3566' TVD w/ 550 gpm, 1770 psi, Off btm SPP 1750 psi, 18% F/O, ECD 11.51 ppg, 180 rpm, 20-23k Tq, 2-1 Ok WOB, PUW 157k, Unable to get slackoff weight, ROT 108k w/ 19k Tq off , MW 9.3 ppg, Max gas 160 units, ADT 4.41, Bit hrs 20.53, Jar hrs 85.57. Concretions drilled at 11826'-1 1829', 11830'- 11837', 11961'- 11967', 11981', 11984', 12008'-12010' and 12093'- 12104'. Increased lube concentration to 1.5% with Lo-Torq at 12150' due to high torque. Page 37150 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur(hr) Phase op CodeStart AWhty Code Tvne P -T -X Operation Depth (t1KB) End Depen M) 4/19/2017 4/19/2017 6.00 PROD2 DRILL DDRL P DDO18-3/4" hole f/ 12293' MD to 12,293.0 12,946.0 06:00 12:00 12946' MD, ND= 3571. Pump @ 550 gpm= 1915 psi on, 1890 psi off w/ 18 % flow out. Rotate @ 180 rpm's w/ 20- 21 K Tq on, 20K Tq off, 2-1 OK WOB, ECD= 11.88 ppg, Max gas= 210. P/U= 164K, Unable to slack off, ROT= 104K. ADT= 4.54, Bit hrs = 25.07, Jar hrs = 90.11 Concretions drilled at 12361'-12366', 2378'-12385', 12404' -12413',12896' - 12900', and 12943' SPRs @ 12296' MD 3781' TVD, MW=9.3 ppg, 07:00 hours MP#1: 30 spm=380 psi, 40 spm=460 psi. MP #2: 30 spm=380 psi, 40 spm=460 psi. 4/19/2017 4/19/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 12946' MD to 12,946.0 13,581.0 12:00 18:00 13581' MD, TVD= 3576. Pump @ 550 gpm= 1920 psi on, 1915 psi off w/ 18 % flow out. Rotate @ 180 rpm's w/ 18- 22K Tq on, 16K Tq off, 61K WOB, ECD= 11.73 ppg, Max gas= 81. P/U= 175K, Unable to slack off, ROT= 108K. ADT= 4.68, Bit hrs = 29.75, Jar hrs = 94.79 Concretions drilled at 12946' - 12948', 13350'- 13354', 13359'- 13370', 13514'- 13525', and 13581'. Increased lube concentration to 2.0% with Lo-Torq at 13500' MD due to high torque. SPRs @ 13334' MD 3578' TVD, MW=9.25 ppg, 14:50 hours MP#1: 30 spm=460 psi, 40 spm=540 psi. MP #2: 30 spm=480 psi, 40 spm=560 psi. 4/19/2017 4/20/2017 6.00 PROD2 DRILL DDRL P DDrill 8-314" hole f/ 13581' MD to 13,581.0 13,922.0 18:00 00:00 13922' MD, TVD= 3571. Pump @ 550 gpm= 1955 psi on, 1940 psi off w/ 18 % flow out. Rotate @ 120-180 rpm's w/ 18-20K Tq on, 16K Tq off, 2-1 OK WOB, ECD= 11.83 ppg, Max gas= 93. P/U= 181K, Unable to slack off, ROT= 109K. ADT= 4.79, Bit hrs = 34.54, Jar hrs = 99.58 Concretions drilled at 13581'- 13595', 13650'- 13667', 13678'- 13684', 13696' - 13705',13718'- 13724', 13726'- 13731', 13735' - 13770', 13867'- 13878', and 13896'- 13898'. Performed 290 bbl dump/dilute @ 13850' MD OA pressure at midnight = 200 psi Page 38/50 Report Printed: 51212017 AN. % Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log $tart Time End Tim Dur (hr) Phase op Code Ar Ay Code Time P -T -X Operation Start Depth (flKa) End Depth (ftKa) 4/2012017 4/20/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 13922' MD to 13,922.0 14,739.0 00:00 06:00 14739' MD, TVD= 3560. Pump @ 550 gpm= 2010 psi on, 2000 psi off w/ 18 % flow out. Rotate @ 180 rpm's w/ 19- 21K Tq on, 18K Tq off, 2-1 OK WOB, ECD= 12.00 ppg, Max gas= 210. P/U= 205K, Unable to slack off, ROT= 99K. ADT= 4.78, Bit hrs = 39.32, Jar bra = 104.36 Concretions drilled at 14055'- 14065' and 14082'- 14090'. SPRs @ 14477' MD 3565' TVD, MW=9.3 ppg, 04:00 hours MP#1: 30 spm=460 psi, 40 spm=540 psi. MP #2: 30 spm=460 psi, 40 spm=540 psi. Note: Started picking up HWDP stands w/ super sliders @ 14567' MD onwards. 4/20/2017 4/20/2017 6.00 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 14739' MD to 14,739.0 15,375.0 06:00 12:00 15375' MD, TVD= 3598. Pump @ 550 gpm= 2200 psi on, 2185 psi off w/ 18 % flow out. Rotate @ 180 rpm's w/ 20- 22K Tq on, 20K Tq off, 4-8K WOB, - - - ECD= 12.10 ppg, Max gas= 60. P/U= 210K, Unable to slack off, ROT= 111 K. ADT= 4.17, Bit him = 43.49, Jar his = 108.53 Concretions drilled at 14740' - 14750', 14976'- 14980', 15286'- 15291', and 15319'- 15328'. 4/20/2017 4/20/2017 5.75 PROD2 DRILL DDRL P DDrill 8-3/4" hole f/ 15375' MD to TO 15,375.0 15,896.0 12:00 17:45 - of 15896' MD, TVD= 3542'. Pump @ 550 gpm= 2290 psi on, 2285 psi off w/ 16 % flow out. Rotate @ 180 rpm's w/ 21K Tq on, 19K Tq off, 12K WOB, ECD= 12.03 ppg, Max gas= 155. P/U= 217K, Unable to slack off, ROT= 127K. ADT= 4.75, Bit him = 48.24, Jar him = 113.28 Concretions drilled at 15468'- 15480', 15670' - 15673',157041- 157091, 15732' - 15736',15750'- 15755', 15760'- 15770', and 15872'- 15879'. SPRs @ 15495' MD 3556' TVD, MW=9.25 ppg, 12:50 hours MP#1: 30 spm=540 psi, 40 spm=620 psi. MP #2: 30 spm=540 psi, 40 spm=620 psi. Page 39160 Report Printed: 5/212017 - : Operations Summary (with Timeiog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Tone Writs) Phase Op Code Aclimly Code Time P -T -X Operation rtftlol)De Start Depth End Depth (flKB) 4/20/2017 4/20/2017 1.50 PROM CASING CIRC P Obtain final survey and SPR's at TO 15,896.0 15,865.0 17:45 19:15 and circulate 1 x bottoms up f/ 15894' -15810' MD w/ 570 gpm, 2400 psi, 17% F/O, 160 rpm, 21k Tq, Initial ECD 12.06 ppg, Final ED 11.87 prig. Obtain final parameters of PUW 218k, SOW 91k, ROT 135k at 30 rpm w/ 18k Tq. SPRs @ 15896' MD 3541' TVD, MW=9.20 ppg, 17:50 hours MP#1: 30 spm=520 psi, 40 spm=620 psi. MP #2: 30 spm=520 psi, 40 spm=620 psi. Note: After reaming stand while CBU, we were able to regain slackoff weight. 4/20/2017 4/20/2017 0.75 PROD2 CASING OWFF P Lay down 5" DP single and monitor 15,865.0 15,865.0 19:15 20:00 well for Flow for 30 minutes while rotating 10 rpm, 15k Tq - well showing - static losses of -3.5 bbls/hr. Clean out air intake vents for traction motors on topdrive. Drop 2.375" OD hollow rabbit w/ 110' of wire on stand # HW14. 4/20/2017 4/21/2017 4.00 PROD2 CASING BKRM P Backream OOH f/ 15866- 14938' MD 15,865.0 14,938.0 20:00 00:00 w/ 550 gpm, 2140 psi, 16% F/0, 180 rpm, 18k Tq, ROT 117k, pulling speed 300-700 ff/hr, monitoring displacement via pit #5. Note: Observed packoff tendencies at 15643' MD with SPP increase 150 psi and torque increase 3k. Drop down and wipe stand. Pull slowly through section and cotinue backreaming observing pressure and torque dropping back to normal with no further issues. OA pressure at midnight = 200 psi 4/21/2017 4/21/2017 12.50 PROD2 CASING BKRM P BROOH f/ 14938' MD to 9829' MD, 14,938.0 9,829.0 00:00 12:30 Pump @ 550 gpm, Initial 1900 psi, Final 1645 psi, 16% FO, Rotate @ 180 rpm's, Initial 18k Tq, Final 13k Tq, Initial ROT weight= 117k, Final ROT weight= 106K, monitoring displacement via pit 95. 4/21/2017 4/21/2017 1.00 PROD2 CASING BKRM P Reduced rotary RPMs to 80 rpm's 9,829.0 9,629.0 12:30 13:30 while Jars and NMFC go across slide and cont to BROOH f/ 9829' MD to 9629' MD, reduce pulling speed to 500 fph. From TO to window: Calculated displacement = 67.5 bbls - Actual displacement = 199.1 bbls Total volume lost downhole while backreaming OOH = 127 bbls (lost -5 bbls to rockwasher while trying 230 - API screen size on shakers) Page 40150 Report Printed: 51212017 . Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Time Em Time Dur(m) Phase Op Code Acvity tiCote Time P-T-X Operation (rt De Start Depth End Depth (N(a) 4/21/2017 4/21/2017 1.00 PROD2 CASING PMPO P Pull from 9629'-9360'MD w/no 9,629.0 9,360.0 13:30 14:30 rotary at 370 gpm, 854 psi, 13% F/O, PUW 145k-no overpull observed pulling BHA through window. 4/21/2017 4/21/2017 1.50 PROD2 CASING CIRC P Circulate 2.5 bottoms w/ 550 gpm, 9,360.0 9,266.0 14:30 16:00 1553 psi, 16% F/O, 80 rpm, 6k Tq, PUW 1441k, SOW 103k, ROT 120k. 4/21/2017 4/21/2017 0.25 PROD2 CASING OWFF P Monitor well for flow -well static. 9,266.0 9,266.0 16:00 16:15 4/21/2017 4/21/2017 4.00 PROD2 CASING TRIP P Pump dryjob and pull OOH on 9,266.0 370.0 16:15 20:15 elevators f/ 9266'- 370' MD, monitoring displacement via trip tank. Note: Observe minimal to zero hardbanding left on 5" DP from stands #30 - surface. All super sliders in place and do not need modification for completion operations. 4/21/2017 4/21/2017 0.25 PROD2 CASING OWFF P Monitor well for flow -well static. 370.0 370.0 20:15 20:30 PJSM for laying out BHA. 4/21/2017 4/21/2017 2.00 PROD2 CASING BHAH P Lay down BHA #8 per DD, racking 370.0 0.0 20:30 22:30 back 1 x stand HWDP for use on whipstock retrieval run. Observe top 8- 5/8" NM stabilizer 1/4" undergauge and middle 8-5/8" NM stabilizer 3/16" undergauge. Observed hardbanding wom down smooth on new saver sub. 8-5/8" stabilizers on Xceed RSS were in gauge. Bit graded 0-0-NO-A-X-0- NO-TD Note: Found 2-3/8" OD hollow drift on top of jar mandrel with no wire on it - connection piece on top of drift was partially washed out. Wire was found at top of NMDC's and was stuck in the float sub above the Telescope MWD. From window to surface: Calculated displacement 83.2 bbls Actual displacement 100.8 bbls 4/21/2017 4/21/2017 0.50 PROD2 CASING BHAH P Clean and clear dg floor of BHA 0.0 0.0 22:30 23:00 equipment. 4/21/2017 4/22/2017 1.00 COMPZ2 FISH SLPC P PJSM. Slip / cut 88' of drilling line. 0.0 0.0 23:00 00:00 Note: Observe -1 bbl/hr static losses. OA pressure at midnight = 100 psi 4/22/2017 4/22/2017 1.00 COMPZ2 FISH SLPC P Cont to slip and cut drilling line. 0.0 0.0 00:00 01:00 4/22/2017 4/22/2017 1.00 COMPZ2 FISH BHAH P Mobilize BHA components and sub to 0.0 0.0 01:00 02:00 1 rig floor via beaver slide. 4/22/2017 4/22/2017 1.00 COMPZ2 FISH SHAH P M/U whipstock retrieval BHA as per 0.0 283.0 02:00 03:00 Baker fishing rep to 283' MD Page 41/50 ReportPrinted: 6/212017 . Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tone End e Time Dur(hr) Phase Op Code Activity Cade me TiP-T-% Operation ft De St(MB)� End Depth 4/22/2017 4/22/2017 5.50 COMPZ2 FISH TRIP P RIH w/ whipstock retrieval BHA f/283' 283.0 9,338.0 03:00 08:30 MD to 9338' MD. Shallow hole test tools @ 2000' MD , pump @ 430 gpm w/ 735 psi, good test. Actual Displacement for trip in= 88.4 bbis Calculated displacement trip in= 96.3 bbis 4/22/2017 4/22/2017 1.00 COMPZ2 FISH WASH P Establish circulation @ 450 gpm w/ 9,338.0 9,407.0 08:30 09:30 1504 psi. Orient to 160°R ( placing circ hole @ 20° L) to wash whipstock and retrieval slot down to 9405' MD. Observed fill/cuttings being washed clear of slide, pump pressure varied from 1100 psi to 2300 psi as material was being washed clean. P/U= 165K, S/O= 122K. 4/22/2017 4/22/2017 0.75 COMPZ2 FISH FISH P Pump @ 375 gpm w/ 1068 psi. Orient 9,407.0 9,307.0 09:30 10:15 to 20°L, slack off to 9397' MD and observed hook set down in retrieval slot, set down 1OK. Pick up to 195K (25K over) and observed unloader shear. Once unloader sheared lost returns until Fluids equalized between laterals, 11 bbis lost. Picked up to 21 OK ( 45K over) and observed anchor release. Stand back one stand and single to 9307' MD. Observed 10K extra drag after hooking whipstock, P/U= 175K. 4/22/2017 4/22/2017 0.75 COMPZ2 FISH CIRC P Circulate BU @ 635 gpm= 2500 psi. 9,307.0 9,307.0 10:15 11:00 Did not reciprocate string while CBU. 4/22/2017 4/22/2017 0.25 COMPZ2 FISH OWFF P Blow down top drive and monitor well 9,307.0 9,307.0 11:00 11:15 for flow - static to slight loss. 4/22/2017 4/222017 2.25 COMPZ2 FISH TRIP P Pull OOH racking back 5" HWDP and 9,307.0 6,298.0 11:15 13:30 5" DP f/ 9307'- 6298' MD, monitoring displacement via trip tank, PUW 144k. 4222017 4/22/2017 0.25 COMPZ2 FISH CIRC P Pump 20 bbl dry job @ 6298' MD and 6,298.0 6,298.0 13:30 13:45 blow down top drive. 4/2212017 4/22/2017 3.75 COMPZ2 FISH TRIP P Pull OOH racking back 5" DP f/ 6298' - 6,298.0 238.0 13:45 17:30 238' MD, monitoring displacement via trip tank. Page 42150 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sled Time End Timea' Dur(hd Phase Op Code Acbvo Code Time P-T.X Operabon Depth (W-B) EntlIhfiKa ( ) 4/22/2017 4/22/2017 2.50 COMPZ2 FISH BHAH P Lay down Baker retrieval BHA and 238.0 0.0 17:30 20:00 whipstock BHA f/ 238'to surface, monitoring displacement via trip tank. Observe small amount of metal debris on magnet above and below whipstock. Observe mill track follow center of whipstock slide and start tracking off slighty, clockwise of high - side at the bottom of the slide (1.5" off center). Observe seal assembly with several damaged seals but all were recovered. Confirm anchor still aligned with highside of whipstock - no offset observed. Clean off magnets and lay out tools. Actual displacement for trip out = 117.3 bbls Calculated displacement for trip out = 89.7 bbls 4/22/2017 4/22/2017 1.00 COMPZ2 FISH BHAH P Clean and clear floor of BHA 0.0 0.0 20:00 21:00 equipment. Note: Static losses of —2 bbl/hr observed. 4/222017 4/22/2017 0.75 COMPZ2 RLED RURD P Rig up GBR casing longs and 4-1/2" 0.0 0.0 21:00 21:45 handling equipment for running seal bore diverter. 4/22/2017 422/2017 1.25 COMPZ2 RLED SHAH P PJSM. Pick up seal bore diverter 0.0 130.0 21:45 23:00 assembly to 130' MD, baker -locking each connection. Align anchor point with seal bore diverter per Baker. 4/222017 4/22/2017 0.50 COMPZ2 RLED DHEO P Set slips and dog collar and function 130.0 130.0 23:00 23:30 test FJD running tool per Baker. Stage up pumps 400 gpm/379 psi, 452 gpm/494 psi, 475 gpm/552 psi. Pick up and confirm still latched. Stage up to 500 gpm/608 psi, pick up and confirm still latched. Stage up to 510 gpm/620 psi, pick up and observe tool still latched. Stage up to 520 gpm/640 psi, pick up and observe tool still latched. Stage up to 540 gpm/690 psi, pick up and observe tool still latched. Drop flow rate to 400 gpm and inspect tool at surface. Stage up to 550 gpm/715 psi, pick up and observe tool released. Drop flow rate to 475 gpm/530 psi allowing tool to re- engage. Pick up and confirm latched in. Stage up pumps to 550 gpm/710 psi and re -confirm tool released. Kill pumps and pick up to confirm tool re- engaged in seal bore i iverter. Note: No jets installed in nozzles on FJD tool per previous flow test. 4/22/2017 4/22/2017 0.25 COMPZ2 RLED BHAH Pick up Telescope MWD w/ XO's and j 130.0 162.0 23:30 23:45 scribe MWD to anchor point - measure IP 332.67° offset (clockwise) from MWD highside to anchor point. Page 43/50 Report Printed: 5/2/2017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(aKB) 4/22/2017 4/23/2017 0.25 COMPZ2 RLED TRIP P Run in hole on 5" DP f/ 162'- 351' MD, 162.0 351.0 23:45 00:00 monitoring displacement via trip tank. OA pressure at midnight = 140 psi Total downhole losses for 24 hours = 69 bbis 4/23/2017 4/23/2017 5.75 COMPZ2 RLED TRIP P Cont to RIH with Baker Seal Bore 351.0 9,428.0 00:00 05:45 Diverter f/ 351' MD to 9428" MD. Pumps off PUW 176K, SOW 130k, Actual displacement= 108.6 bbls, Calculated displacement= 93.5 Wis. 4/23/2017 4/23/2017 0.75 COMPZ2 RLED OTHR P Install Baker SBD as follows: Establish 9,428.0 9,507.0 05:45 06:30 circulation@ 400 gpm= 1104 psi, Pumps on PUW 165K, SOW 124K. Orient to 8"L and slack off to 9507' MD, set down 20K. Observe toolface roll to 13'L . Pick up to 185K (20K over) observe toolface roll to 17"L. Set down 20K and pick up to 200K (35K over) observe toolface roll to 20°L. Set down 20K and increase pumps to 550 psi= 1780 psi to release. Pick up to 175K, no release. Set down 20K and increase pump to 600 gpm=2000 psi, pick up to 175K, no release. Set down 30K and increase pumps to 650 gpm= 2300 psi. Pick up and confirm release, free travel at 165K. Wash out top of seal bare diverter while pulling out running tool. 4/23/2017 4/23/2017 0.50 COMPZ2 RLED OWFF P Stand back 1 stand and UD single to 9,507.0 9,390.0 06:30 07:00 9390' MD. OWFF, static. 4/23/2017 4/23/2017 5.00 COMPZ2 RLED TRIP P POOH w/ FJD running tool from 9390' 9,390.0 351.0 07:00 12:00 MD to 351' MD. W WT rep inspected super sliders while POOH. 4/23/2017 4/23/2017 0.75 COMPZ2 RLED BHAH P UD MWD tools, XO and Baker FJD 351.0 0.0 12:00 12:45 running tool from 351' MD to Surface. Actual displacement= 91.5 bbls, Calculated displacement- 91.5 bbls. 4/23/2017 4/23/2017 1.00 COMPZ2 RLED RURD P Clean and Gear rig floor. 0.0 0.0 12:45 13:45 4/23/2017 4/23/2017 0.50 COMPZ2 CASING SVRG P Service rig, grease blocks and top 0.0 0.0 13:45 14:15 drive. 4/23/2017 4/23/2017 0.50 COMPZ2 CASING RURD P Rig up casing handling equipment for 0.0 0.0 14:15 14:45 running 4-1/2" liner. 4/23/2017 4/23/2017 7.00 COMPZ2 CASING PUTB P PJSM. Make up 5-1/2" guide shoe and 0.0 6,444.0 14:45 21:45 float collar and run in hole on 4-1/2" 12.6 Wit L-80 TXP-m slotted / blank liner per tally to 6444' MD, installing 4- 1/2" x 6-1/8" hydrofonn centralizers free floating every joint, monitoring displacement via trip tank. Calculated displacement = 28.4 bbls Actual displacement = 14.3 bbls Page 44160 Report Printed: 5/2/2017 e Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase op coCe Activity Code Time P -T -X opersti. Start Depth (rt De Entl Depth (flKa) 4123/2017 4/23/2017 1.00 COMPZ2 CASING PUTB P Make up 3-12" inner string, change 6,444.0 6,489.0 21:45 22:45 out handling equipment, and make up RAM hanger assembly per Baker to 6489' MD. PUW 92k, SOW 75k 4/23/2017 4/23/2017 0.50 COMP72 CASING RUNL P Make up 1 x stand 5" DP and RIH to 6,580.0 6,580.0 22:45 23:15 6580' MD. Make up topdrive and establish circulation, 2 bpm / 68 psi / 4% F/O, staging up to 4 bpm / 147 psi / 6% F/O, total 14 bbls pumped. PUW 92k, SOW 75k, ROT 80k w/ 25 rpm, 3k Tq. Blow down topdrive. 4/23/2017 4/24/2017 0.75 COMPZ2 CASING RUNL P RIH on 5" DP f/ 6580'- 8098' MD at 90 6,580.0 23:15 00:00 ft/min per Baker, monitoring displacement via trip tank, PUW 116k, SOW 88k. Total downhole losses for 24 hours = 50 bbls OA pressure = 100 psi 4/24/2017 4/24/2017 1.00 COMPZ2 CASING RUNL P Cont to RIH w/ 4-1/2" liner on 5" DP f/ 8,098.0 9,385.0 00:00 01:00 8098' MD to 9385' MD, 4/24/2017 4/24/2017 0.50 COMPZ2 CASING CIRC P Obtain parameters before exiting the 9,385.0 9,385.0 01:00 01:30 window @ 9392' MD. Pump @ 4 bpm=190 psi, Rotate @ 15 rpms with 5K tq. P/U= 130K, S/O= 99K, ROT=130K. 4/24/2017 4/24/2017 3.50 COMPZ2 CASING RUNL P Cont to RIH w/ 4-1/2" liner on 5" 9,385.0 15,745.0 01:30 05:00 DP/HWDP to 15745' MD. Actual displacement = 105 bbls, Calculated displacement= 121 bbls. 4/24/2017 424/2017 0.75 COMPZ2 CASING RUNL P Snap RAM hanger into collet on SBD 15,745.0 15,863.9 05:00 05:45 easy as follows: Establish circulation @ 15745' pump @ 4 bpm= 500 psi, MD, P/U= 200K, S/O= 115K. Wash down to 15834' MD. Break off top drive and RIH and tag collet @ 15864' MD, RAM collet depth @ 9388' MD. Slack off to 80K ( 35K down) and snap into collet. P/U to 220K (20K over) to confine latch. Attempted to unsnap from collet by pulling 30K over, 50K over and 60K over, unsuccessful. Set down 20K on collet then attempted to unsnap again. Pulled 60K over and 65K over, no success. Set down 35K on collet and discuses options with town. 4/24/2017 4/24/2017 1.75 COMPZ2 CASING RUNL T Confer with town on issues and 15,863.915,863.0 05:45 07:30 options about not being able to un snap from SBD assy. Decision made to continue forward and release from RAM liner hanger. Page 45160 Report Printed: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Tme End Torre Dur hr Dur(hr) Phew Op Code Activity Code Time P -T -X Operation Start Depth (fIKB) End Depth (ttl a) 4/24/2017 4/24/2017 2.50 COMPZ2 CASING PACK P Release from RAM Liner hanger as 15,863.0 9,450.0 07:30 10:00 follows. Drop 29/32" ball and pump down @ 3 bpm= 367 psi, reduce to 2 bpm=300 psi @ 700 strokes, reduce to 1.5 bpm= 200 psi @ 1290 strokes. Ball landed on seal late @ 2050 strokes ( 1450 calculated). Pressure up to 2800 psi and hold for 1 min, PIU to 180K did not release. Slack off to 80K and pressure up to 3400 psi, hold for 1 min. Pick up out of RAM hanger and confirmed release. P/U= 185K. Pick up until guide nose above seal bore diverter, RIH and set down 1 Ok on 3.71" shoulder inside seal bore diverter to confirm correct orientation and access to main bore - good tag. 4/24/2017 4/24/2017 0.75 COMPZ2 CASING PACK P Shear ball seat on running tool as 9,450.0 9,380.0 10:00 10:45 follows. Set down to 100K and pressure up to 4200 psi, no success. Bleed off pressure and line up to use test pump along with mud pumps. Pressure up to 4200 psi with mud pumps, shut in mud pumps and pressure up to 4900 psi with test pump. Observed shear @ 4900 psi. 4/24/2017 4/24/2017 4.00 COMPZ2 RWRID TRIP P Blow down top drive and pull OOH 9,380.0 97.0 10:45 14:45 racking back 5" DP / HWDP f/ 9380'- 380'-97' 97'MD, PUW 137k, SOW 105k, monitoring displacement via trip tank. 4/24/2017 4/24/2017 0.50 COMPZ2 RWRID SHAH P Lay down RAM hanger running tools f/ 97.0 0.0 14:45 15:15 97'to surface, monitoring displacement via trip tank. Actual displacement = 111.2 bbls. Calculated displacement = 91.8 bbls 4/24/2017 4/24/2017 1.00 COMPZ2 RWRID SHAH P Clean and clear rig floor. 0.0 0.0 15:15 16:15 4/24/2017 4/2412017 0.50 COMPZ2 RWRID SVRG P Service crown. Simops: Rig up GBR 0.0 0.0 16:15 16:45 and handling equipment and confirm order in pipeshed. 4/24/2017 4/24/2017 3.00 COMPZ2 RWRID PUTS P PJSM. Pick up LEM assembly w/ 3 x 0.0 195.0 16:45 19:45 joints 4-1/2" IBTm tubing, 3.75" nipple, Sealbore extension, and SLZXP Liner top packer. Make up inner string with Slimpulse MWD and scribe - measure offset to LEM at 305.06° clockwise from MWD highside. 4/24/2017 4/25/2017 4.25 COMPZ2 RWRID RUNL P RIH w/ LEM assembly on 5" DP / 195.0 7,501.0 19:45 00:00 HWDP stands w/ super sliders installed to 7501' MD, filling pipe every 20 x stands and shallow hole testing MWD on first fill - good test. Monitor displacement via trip tank. PUW 137k, SOW 103k. OA pressure at midnight= 120 psi Total downhole losses for 24 hours = 59 bbls Page 46150 Report Printed: 51212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (,t De Start Depth Entl Depth (N(B) 4/25/2017 4/25/2017 2.25 COMPZ2 RWRID RUNL P RIH w/ LEM assembly on 5" DP / 7,501.0 9,354.0 00:00 02:15 HWDP stands w/ super sliders installed to f/ 7501'- 9354' MD, filling pipe every 20 x stands - good test. Monitor displacement via trip tank. PUW 173k, SOW 128k. 4/25/2017 4/25/2017 1.50 COMPZ2 RWRID OTHR P Pick up space out pups to be spaced 9,354.0 9,407.0 02:15 03:45 out for blowing down top drive prior to pressure test. Orient LEM to 7"L w/ 109 gpm, 550 psi and RIH to snap in LEM. Set down 10k at 9204', work pipe up to PUW 169k w/ no overpull. RIH and snap LEM collet into RAM, setting 17k down at 9405' and seeing it breakover to 124k and continue in and tag up at 9407'w/ 20k, seeing toolface roll to 107"R as LEM stabbed in. Pick up to 18K and confirm latch, pick up 27K over pull and unlatch from collet. Set down 20K again to latch in, obverted exact same toolfaoe roll ( 107°R) when latching into collet. Discussed unexpected orientation, discovered that the scribe had been carried up incorrectly form the XO, not SLZXP. 4/25/2017 4/25/2017 1.75 COMPZ2 RWRID PACK P Set SLZXP as follows: Drop 1-5/8" ball 9,407.0 9,407.0 03:45 05:30 and pump down @ 2 bpm=415 psi, - slow pumps to 1.5 bpm= 329 psi at 1110 strokes. Observed ball seat @ 1370 strokes. Pressure up to 2600 psi hold for 1 min,observed packer set, continue walking pressure up to 4000 psi holding for 1 min every 200 psi to release. Confirmed release. 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID RURD P P/U to confirm release ( 174K up) and 9,407.0 9,400.0 05:30 06:00 rig up to pressure test IA. 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID PRTS P Pressure test 9-5/8" production 9,400.0 9,400.0 06:00 06:30 annulus to 3500 psi for 30 min on chart, good test. 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID TRIP P POOH, removing running tool and 9,400.0 9,292.0 06:30 07:00 MWD from tie -back sleeve to 9292' MD. P/U= 172K 4/25/2017 4/25/2017 3.50 COMPZ2 RWRID DISP P Displace well to 9.4 ppg NaCl brine as 9,292.0 9,292.0 07:00 10:30 follows: Pump 30 bbls of high viscosity spacer followed by 955 We of NaCl brine. Bring pumps up to 150 gpm=255 psi to confirm MWD tool bypass. Cont to stage pumps up to . 410 gpm=800 psi. Brine observed @ shakers at 8000 strokes and continue to dump fluid until clean brine was observed @ 9855 strokes. 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID PULD P POOH, laying down 14 ints of HWDP. 9,292.0 8,922.0 10:30 11:00 I 4/25/2017 4/25/2017 0.50 COMPZ2 RWRID PULD P RIH with 3 stands HWDP from derrick 8,922.0 8,922.0 11:00 11:30 and lay down same. Page 47150 ReportPrinted: 5/212017 Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Jab: DRILLING ORIGINAL Time Log Stars Time EM e Tim our Ind Phase Op Code AOvity Code T Time P- - X Operation Statl Depth n De Entl Depth (fl(8) 4/25/2017 4/25/2017 10.50 COMPZ2 RWRID PULD Continue POOH laying down 5" 8,922.0 80.0 11:30 22:00 HWDP and 5" DP to completion running tools. Calculated Displacement = 67.2 bbls Actual Displacement = 92.5 bbls 4/25/2017 4/25/2017 0.75 COMPZ2 RWRID PULD P LD SLZXP running tools and SLB 80.0 0.0 22:00 22:45 1 1 MWD BHA. 4/25/2017 4125/2017 0.75 COMPZ2 RPCOMP RURD P MU bushing puller and pull wear 0.0 0.0 22:45 23:30 bushing. 4/25/2017 4/26/2017 0.50 COMPZ2 RPCOMP W W WH P MU stack washer and flush stack. 850 0.0 0.0 23:30 00:00 GPM, 136 PSI, 21 % Flow Out, 40 RPM, 1.5k TO. BD TD. Total downhole losses over 24 hrs = 29 bbls OA Pressure= 100 psi 4/26/2017 4/26/2017 4.50 COMPZ2 RPCOMP PULD P Rig up Centrilift to run ESP. Mobilze 0.0 0.0 00:00 04:30 tools to rig floor, rig up sheave, snake line over windwalls to rig floor, unload and count cannon clamps. 4/26/2017 4/26/2017 3.50 COMPZ2 RPCOMP PULD P MU ESP motor and fill with mineral oil. 0.0 0.0 04:30 08:00 Make up seals and service ESP. 4/26/2017 4/26/2017 2.00 COMPZ2 RPCOMP T Penetrator for ESP determined to be 0.0 0.0 08:00 10:00 incorrect, conferwith town and wait on decision before beginning to RIH with ESB assembly. 4/26/2017 4/26/2017 0.50 COMPZ2 RPCOMP SVRG P Service blocks, crown and wash pipe. 0.0 0.0 10:00 10:30 4/26/2017 426/2017 1.50 COMPZ2 RPCOMP SLPC P Slip and cut drill line. 72' of drill line cut 0.0 0.0 10:30 12:00 off and replaced. Total Losses to Formation for Tour = 19 bbl 4/262017 4/26/2017 0.50 COMPZ2 RPCOMP SVRG Clean and clear rig floor, calibrate 0.0 0.0 12:00 12:30 block weight. 4/26/2017 4/26/2017 2.00 COMPZ2 RPCOMP PULD - Hold PJSM, PU ESP receiver, RCVG 0.0 48.0 12:30 14:30 Gas DISSP 512 Seal and MU to ESP motor as per Centdlift. RIH U48' installings cannon clamps as directed. 4/26/2017 4/26/2017 0.25 COMPZ2 RPCOMP PULD M/U 4-1/2" 12.6# L-80 TXP-m pups, 1 48.0 111.0 14:30 14:45 full jnt and centrilift discharge unit f/48' 0110'. Monitor displacement on trip tanks and install cannon clams on each coupling. 4/26/2017 426/2017 1.00 COMPZ2 RPCOMP PULD Splice motor lead as per Centrilit 111.0 111.0 14:45 15:45 Page 48/60 Report Printed: 5/212017 . Operations Summary (with Timelog Depths) 3R-101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sun Time End Tore Dur(hd Phase op Cotle Activity Code Tim P -T -X Operation start Depth (ftKB) EM Depth(ftKB) 4/26/2017 4/27/2017 8.25 COMPZ2 RPCOMP PUTB RIH with 4-1/2" 12.6# L-80 TXP-m 111.0 5,010.0 15:45 00:00 completion as per tally f/11 l' to 5010' MD. Cannoc clamps installed on each connection, ESP cable tested every 1000'. Displacement monitored on trip tank. UP WT = 86K, S/O WT = 79K, CALC DIPS = 22.4 BBL, ACTUAL DISP. _ 13.1 BBL Total Losses to formation for tour = 20 bbls 4/27/2017 4/27/2017 3.50 COMPZ2 RPCOMP PUTS P Continue RIH w/ 4 1/2" 12.6# L-80 5,010.0 00:00 03:30 TXP-m completion 1/5010 U7288' MD intallings cannon clamps on each connection. ESP cable function tested every 1000' MD. UP WT = 105K, DWN WT = 75K 4/27/2017 4/27/2017 1.00 COMPZ2 RPCOMP THGR P MU tubing hanger and orient, install 03:30 04:30 penetrator and space out ESP cable for cut. SIMOPS: Tail excess ESP cable back to spooling unit. 4/27/2017 4/27/2017 2.50 COMPZ2 RPCOMP THGR P Splice ESP cablewith connector as 04:30 07:00 per Centrilift. SIMOPS: RD GBR casing equipment. 4/27/2017 4/27/2017 1.00 COMPZ2 RPCOMP THGR P Terminate ESP cable on penetrator 07:00 08:00 and check conductivity as per centdlift. Land tubing hanger as per Vetoo. UP WT = 122K, DWN WT = 79K 182 cannon clamps total installed. 4/27/2017 4/27/2017 1.00 COMPZ2 RPCOMP THGR P Run in LDS and TQ to spec as per 08:00 09:00 Vecto. Rig down oentrilift. RD sheave and demob tools, job box and extra cannon clamps from rig floor. 4/27/2017 4/27/2017 0.50 COMPZ2 RPCOMP THGR P Test hager void to 5000 psi for 15 min 09:00 09:30 as per Vetce. Test good, witnessed by CPAL 4/27/2017 4/27/2017 2.50 COMPZ2 WHDBOP NUND P ND BOPE. Pull flow riser, remove 09:30 12:00 choke and kill lines, rack back BOP stack and RD spacer spools. Total losses to formation for tour = 15 bbls Calculated displacement for tour = 33 bbls, actual displacement = 19 bbls. 4/27/2017 4/27/2017 1.75 COMPZ2 WHDBOP NUND P INUtree. Re -test ESP cable 12:00 13:45 cor dudivity via penetrator as per Centdlift. SIMOPS: Install mouse hole and LD flow nipple riser. 4/27/2017 4/27/2017 0.25 COMPZ2 WHDBOP PRTS P Test void U 250/5000 psi f/ 10 min as 13:45 14:00 per Vecto. Test good. Page 49150 Report Printed: 5/2/2017 I -" Operations Summary (with Timelog Depths) 362101 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme EM Time Dur ((hr)Phau Op Code Activity Code Time P -T -X Operation Stat Depth mKB) EM Depth(ftKB) 4/27/2017 4/27/2017 0.25 COMPZ2 WHDBOP PRTS P Install test dart with dry rod in 'HP' 14:00 14:15 BPV. Fill tree with diesel and test tree to 250/5000 psi f/15 min. Test good. 4/27/2017 4/27/2017 0.50 COMPZ2 WHDBOP MPSP P Pull test dart and BPV with dry rod 14:15 14:45 (annulus valve open and no psi confirmed). 4/27/2017 4/27/2017 2.50 COMPZ2 WHDBOP FRZP P RU to freeze protect LRS. PT lines to 14:45 17:15 3500 psi, pump 140 bbis of diesel down IA taking returns through the tubing at 2 bpm. ICP = 500psi, FCP = 800psi. Returns observed at surface after 19 bbis diesel pumped. SIMOPS: Begin LD 64 stands 5" DP via mouse hole. 4/27/2017 4/27/2017 1.00 COMPZ2 WHDBOP FRZP P Line up tubing and IA, allow well to U- 17:15 18:15 tube. SIMOPS: LD 5" DP via mousehole. IA = 200 psi, Tubing = 200 psi 4/27/2017 4/27/2017 0.75 COMPZ2 WHDBOP MPSP P PU lubricator and set 'H' BPV as per 18:15 19:00 Vecto. LD lubricator. IA = 125 psi, Tubing = 125 psi 4/27/2017 4/27/2017 3.50 DEMOB MOVE PULD P LD remaining 33 stands of 5" DP via 19:00 22:30 mousehole. SIMOPS: B/D water, pits. Disconnect interconnect lines in pump and pit complexes. C/o upper rams f/ 9 5/8" t/ 3 1/2" x 6" VBRs. 4/27/2017 4/28/2017 1.50 DEMOB MOVE RURD P Empty freese protect returns in rock 22:30 00:00 washer. SIMOPS: UD mousehole, lower beaver slide and and remove steam traps on sub. 4/28/2017 4/28/2017 2.00 DEMOB MOVE RURD P Blow down steam, disconnect mud 00:00 02:00 lines in sub, rig down pipe skate, disconnect electrical in all interconnects. Release dg @ 02:00 Page 50150 Report Printed: 51212017 NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-101 L1 Definitive Survey Report 05 May, 2017 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kupawk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-1011-1 Survey Calculation Method: Minimum Curvature Design: 3R-1011-1 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 Wen 3R-101 Date Well Position +NIS 0.00 usft Northing: 6,031,732.16 usft Latitude: 70° 29'52.272 N +El -W 0.00 usft Easting: 520,625.98 usft Longitude: 149° 49'52.775 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90usft Nellbore 3R-1011-1 aagrletics .Model Name Sample Date Declination Dip Angle Field Strength (0) (% (nT) BGGM2016 4/13/2017 17.71 81.04 57,551 Design 3R-1011.1 Date Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 9,619.39 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction 676.74 (usft) (usft) (usft) (% 2,208.44 39.10 0.00 0.00 303.60 Survey Program Date From To Map Map (waft) (ualt) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 3R-101 Srvy 1 - SLB _GYD-GC-SS (3R-1 GYD-GCSS Gyrodata gyro single shots 3/24/2017 8:28:, 676.74 2,153.783R-101 Srvy 2-SLBMWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/24/2017 8:31: 2,208.44 2,208.44 3R-101 Spry 3 - SLB _GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/25/2017 8:33:• 2,297.00 8,026.553R-101 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/29/2017 8:47:- 8,102.69 9,327.483R-101 Srvy 5-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/1/2017 2:48:0- 9,392.00 9,409.593R-1011-1PB1 Srvyl- Inc + Trend (3R-10 INC+TREND Inclinometer +known azi trend 4/14/2017 859- 9,438.00 9,619.393R-101 L1 Pet Srvy2- SLB _GWD70(3R- GYD-GC-SS Gyrodata gyro single shots 4/14/2017 9:10: 9,659.83 9,698.073R-101Ll Srvyi-SLB_GWD70(3R-101 GYD-GC-SS Gyrodata gyro single shots 4/17/2017 9:33: 9,770.96 15,832.583R-101 L1 Srvy2-SLB_MWD+GMAG(3R MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/17/2017 9:50: Survey 5'52017 2:21:08PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azl TVD TVDSS +NAS +E/ -W Northing Easting DLS Section (usft) 0 (1) (usft) (weft) (usft) (usft) (ft) Ift) (91007 (ft) Survey Tool Name 39.10 0.00 0.00 39.10 490 0.00 0.00 6,031,732.16 520,625.98 0.00 0.00 UNDEFINED 135.69 0.74 51.62 135.69 86.69 0.39 0.49 6,031,73255 520,626.47 0.77 -0.19 GYD-GC-SS(1) 169.59 0.74 47.48 169.58 120.58 0.67 082 6,031,732.83 520,626.80 0.16 -0.31 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 21311 2.03 1.24 6,031,734.19 520,627.21 0.95 0.09 GYD-GCSS(1) 356.57 2.27 336.68 366,51 307.51 4.69 0.47 6,031,736.85 520,626.44 1.34 2.21 GYD-GCSS(1) 451.]6 3.38 327.54 451.58 402.58 8.79 -178 6,031,740.95 520,624.17 1.25 6.35 GYD-GC-SS(1) 545.32 3.75 318.73 544.96 495,96 13.42 -528 6,031,745.56 520,620.66 0.71 11.82 GYD-GC-SS(1) 5'52017 2:21:08PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellborn: 3R-1011-1 Survey Calculation Method: Minimum Curvature Design: 3R-101 Ll Database: OAKEDMP2 Survey Map Map Vertical MD Inc AzI TVD TVDSS +Nh4 +E1 -IN NorthIng Easting DLS Section (usft) (% (') (ust) lust) (usm (usft) (ft) (ft) (°71009 (ft) Survey Teol Name 63881 5.49 307.39 638.15 589.15 1843 -10.85 6,031,750.56 520,615.08 209 1924 GYD-GC-S$(1) 676.74 6.24 302.09 675.88 626.88 20.63 44.04 6,031,752.75 520,611.88 2.44 23.11 MWD+IFR-AK-CAZ-SC(2) 770.88 7.30 300.95 769.36 720.35 26.42 -23.50 6,031,75852 520,60240 1.13 34.20 MWD+IFR-AK-CAZ-SC(2) 853.73 9.86 309.12 861.17 812.17 34.47 -34.73 6,031,766.53 520,591.15 3.05 48.01 MWD+IFR-AK-CAZSC(2) 959.68 9.96 317.32 95569 906.69 45.76 -06.73 6,031,777.78 520,579.13 1.47 64.25 MWD+IFR-AK-CAZSC(2) 1,053.73 12.30 328.76 1,047.98 998.98 60.31 -57.44 6,031,792.30 520,568.37 3.41 81.22 MWD+IFR-AK-CAZ-SC(2) 1,149.13 13.66 347.18 1,140.98 1,091.98 79.99 65.22 6,031,811.96 520,560.55 4.54 98.59 MWD+IFR-AK-CAZ-SC(2) 1,243.57 14.34 35531 1,232.62 1,183.62 102.52 68.65 6,031,834.48 520,557.05 2.20 113.91 MWD+IFR-AK-CAZSC(2) 1,338.60 14.97 357.92 1,324.58 1,275.56 12652 -70.06 6,031,858.47 520,555.58 0.96 128.36 MWD+IFR-AK-CAZ-SC(2) 1,433.41 15.24 35978 1,416.09 1,36209 151.21 -70.55 6,031,883.16 520,555.02 0.59 142.44 1VWD+IFR-AK-CAZSC(2) 1,527.63 14.50 0.11 1,507.16 1,458.16 175.39 -70.57 6,031,907.34 520,554.93 0.79 155.84 MWD+IFR-AK-CAZ-SC(2) 1,620.81 17.27 0.21 1,596.77 1,547.77 20089 -70.50 6,031,932.84 520,554.93 2.97 169.89 MWD+IFR-AK-CAZ-SC(2) 1,716.88 16.84 1.37 1,688.62 1,639.62 229.07 -70.12 6,031,961.01 520,555.24 0.57 185.16 MWD+IFR-AK-CAZSC(2) 1,811.40 19.06 358.74 1,778.53 1,729.53 258.19 -70.13 6,031,990.13 520,555.14 2.50 20128 MWD+IFR-AK-CAZ-SC(2) 1,905.14 20.91 356.99 1,857.56 1,818.56 290.54 -71.36 6,032,022.47 520,553.83 2.05 22021 MWD+IFR-AK-CAZ-SC(2) 2,ODD,W 24.98 355.65 1,954.26 1,905.26 327.16 -7375 6,032,059.08 520,551.33 4.36 242.46 MWD+IFR-AK-CAZSC(2) 2,094.43 28.81 355.00 2,038.19 1,989.19 369.59 -77.23 6,032,101.50 520,547.73 4.08 268.84 MWD+IFR-AK-CAZSC(2) 2,153.78 30.11 355.47 2,089.86 2,040.86 398.68 -79.66 6,032,130.57 520,545.23 2.22 286.96 MW13NFR-AK-CAZ-SC(2) 2,208A4 33.91 357.04 2,136.21 2,087.21 427.58 51.53 6X2,15947 520,54328 7.12 304.51 GYD-GC-SS(3) 2,243.00 34.53 357.36 2,164.78 2,115.78 446.99 62.48 6,032,178.88 520,542.27 1.88 31604 MWD+IFR-AKCAZSC(4) 1338" 2,297.00 35.51 357.84 2,209.00 2,160.00 477.96 53.77 6,032,209.84 520,54089 1.88 334.26 MWD+IFR-AK-CAZ-SC(4) 2,353.55 37.24 35870 2,254.53 2,205.53 511.48 -84.78 6,032,243.35 520,539.79 3.19 353.64 MWD+IFR-AK-CAZ-SC(4) 2,448,06 41.36 358.32 2,327.65 2,278.65 571.31 56.34 6,032,303.17 520,538.06 4.37 388.05 MWD+IFR-AK-CAZSC(4) 2,543.56 45.79 0.39 2,396.83 2,347.83 637.11 57.04 6,032,368.96 520,537.19 4.87 425.04 MWD+IFR-AKCAZSC(4) 2,637.75 49.08 0.59 2,460.53 2,411.53 706.47 56.44 6,032,438.31 520,537.59 3.50 462.93 MWD+IFR-AK-CAZ-SC(4) 2,732.27 54.02 1.62 2,519.29 2,470.29 780.45 54.99 6,032,512.29 520,538.83 5.30 502.66 MWD+IFR-AK-CAZ-SC(4) 2,825.93 58.92 0.47 2,571.55 2,522.56 859.32 53.57 6,032,591.16 520,540.03 527 545.12 MWD+1FR-AK-CAZ-SC(4) 2,919.52 63.48 0.11 2,616.16 2,567.16 940.43 53.17 6,032,672.27 520,540.21 4.94 589.67 MWD+IFR-AKCAZ-SC(4) 3,015.11 67.32 358.34 2,655.94 2,606.94 1,027.32 54.36 6,032,759.14 520,53877 4.36 638,74 MWD+IFR-AK-CAZ-SC(4) 3,110.07 71.37 357,59 2,689.43 2,640.43 1,11610 57.53 6,032,84290 520,535.37 4.33 690.50 MWD+IFR-AK-CAZ-SC(4) 3,204.89 75.87 355.15 2,716.17 2,667.17 1,206.86 -93.31 6,032938.63 520,529.33 5.35 745.54 MWD+IFR-AK-CAZSC(4) 3,300.84 80.10 354.91 2,736.14 2,68744 1,300.33 -101.44 6,033,032.07 520,520.95 4.42 804.04 MWD+IFR-AKCAZSC(4) 3,39553 80.99 355.26 2,751.69 2,702.69 1,393.39 -109.44 6,033,125.10 520,512.69 1.01 862.20 MWD+IFR-AK-CAZ-SC(4) 3,490.19 81,39 356.24 2,766.19 2,717.19 1,486.67 -116.37 6,033,218.36 520,505.50 1.11 919.59 MWD+IFR-AK-CAZ-SC (4) 3,582.99 81.43 356.62 2,780.05 2,731.05 1,578.25 -122.08 6,033,309.91 520,499.63 0.41 97503 MWD+IFR-AKCAZSC(4) 3,679.39 81.52 355.89 2,794.34 2,745.34 1,673.38 -128.31 6,033,405.02 520,493.04 0.75 1,032.85 MWD+IFR-AK-CAZSC(4) 3,77467 81.52 354.32 2,808.39 2,759.39 1,767.28 -136.35 6,033,498.88 520,484.74 1.63 1,091.51 MWD+IFR-AKCAZ-SC(4) 3,889.26 81.14 354.65 2,822.65 2,773.65 1,860.35 -145.34 6,033,591.92 520,475.49 0.53 1,150.50 MWD+IFR-AK-CAZ-SC(4) 3,963.62 81.59 354.57 2,836.82 2,787,82 1,953.23 -154.10 6,033,684.76 520,466.47 0.48 1,209.19 MWD+IFR-AK-CAZ-SC(4) SWO17 2:21.:08PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kupamk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R -101L1 Survey Calculation Method; Minimum Curvature Design: 3R-101 1-7 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Ari TVD TVDSS +N/ -S +E/ -W Northing Fasting OLS Section (usft) (0) (0) (usft) (usm (waft) (usft) (ft) (ft) (91001 (ft) Survey Tool Name 4,058.18 81.39 354.86 2,850.81 2,801.81 2,046.35 -162.72 6,033,777.85 520,457.60 0.37 1,267.89 MWD+IFR-AK-CAZ-SC(4) 4,153.32 81.31 355.47 2,865.12 2,816.12 2,14D.07 -170.64 6,033,871.54 520,449.41 0.64 1,328.36 MWD+IFR-AK-CAZ-SC(4) 4,247.21 81.19 356.30 2,879.41 2,830.41 2,232.63 -177.30 6,033,964.07 520,442.50 0.88 1,383.12 MWD+IFR-AK-CAZSC (4) 4,341.81 8129 357.42 2,893.81 2,844.81 2,325.99 -182.42 6,034,057.40 520,437.12 1.17 1,439.05 MWD+IFR-AK-CAZSC(4) 4,436.87 81.31 358.76 2,908.19 2,859.19 2,419.90 -185.56 6,03,151.29 520,433.73 1.39 1,493.62 MWD+IFR-AK-CAZ-SC(4) 4,532.86 81.46 359.12 2,922.57 2,873.57 2,514.79 -187.31 6,034,246.17 520,431.71 0.40 1,547.59 MWD+IFR-AK-0AZSC(4) 4,627.23 81.49 358.61 2,938.56 2,887.56 2,608.10 -189.16 6,034,339.46 520,429.60 0.54 1,60077 MWD+IFR-AK-CAZ-SC(4) 4,722.52 81.62 358.05 2,950.55 2,901.56 2,702.31 -191.91 6,034,433.66 520,426.59 0.60 1,655.19 MWD+IFR-AK-CAZ-SC(4) 4,816.15 81.17 357.64 2,964.57 2,915.57 2,794.82 AW39 6,034,526.15 520,422.86 0,65 1,709.28 MWD+IFR-AK-CAZSC(4) 4,910.05 81.65 357.59 2,978.59 2,929.59 2,887.59 -199.25 6,034,618.90 520,418.74 0.51 1,763.83 MWD+IFR-AK-CAZ-SC (4) 5,005.50 8145 357.34 2,992.62 2,943.62 2,981.91 -20343 6,034713.20 520,414.30 0.33 1,819.50 MWD+IFR-AK-CAZ-SC(4) 5,099.31 80.43 356A9 3,007.39 2,958.39 3,074.40 -208.65 6,034,805.66 520,408.82 1.63 1,87503 MWD+IFR-AK-CAZSC(4) 5,194.23 79.74 356.96 3,023.73 2,974.73 3,167.73 -214.24 6,03,899.97 520,402.97 1.08 1,931.33 MWD+IFR-AK-CAZ-SC(4) 5,288.73 80.17 357.41 3,040.22 2,991.22 3,260.67 -218.81 6,034,991.89 520,398.14 0.65 1,9f.57 MWD+IFR-AK-CAZ-SC(4) 5,384.03 80.16 355.86 3,056.49 3,007.49 3,354.41 -224.32 6,035,065.60 520,392.37 1.60 2,04303 MWD+IFR-AK-CAZSC(4) 5,478.50 80.16 35501 3,072.64 3,023.64 3,447.19 -231.73 6,035,178.35 520,384.71 0.89 2,100.54 MWD+IFR-AK-CAZSC(4) 5,574.37 79.88 352.33 3,089.26 3,040.26 3,541.03 -242.14 6,035,272.15 520,374.04 2.77 2,161.13 MWD+IFR-AK-CAZ-SC(4) 5,668.19 80.05 352.29 3,105.61 3,056.61 3,632.58 -254.50 6,035,36366 520,361.43 0.19 2,222.09 MWD+IFR-AK-CAZ-SC(4) 5,762.98 79.70 350.63 3,122.27 3,07327 3,724.85 -268.36 6,035,455.89 520,347,32 1.76 2,284.70 MWD+IFR-AK-CAZSC(4) 5,858.90 79.93 350.94 3,139.23 3,090.23 3,818.04 -283.48 6,035,549.02 520,331.94 0.40 2,308.86 MWD+IFR-AK-CAZ-SC(4) 5,953.58 79.83 352.59 3,155.87 3,106.87 3,910.29 -296.83 6,035,641.22 520,318.34 1.72 2,411.02 MWD+IFR-AK-CAZ-SC(4) 6,008.38 79.78 353.57 3,17265 3,123.65 4,002.91 -308.07 6,035,73380 520,306.84 1.02 2,471.63 MWD+IFR-AK-CAZ-SC(4) 6,142.31 80.65 351.82 3,188.61 3,139.61 4,094.72 -319.84 6,035,825.57 520,294.81 2.06 2,53224 MWD+IFR-AK-CAZSC(4) 6,237.62 80.49 349.06 3,204.23 3,155.23 4,187.42 -335.45 6,035,918,22 520,278.95 2.86 2,598.55 MWD+IFR-AK-CAZ-SC(4) 6,332.89 80.84 348.35 3,219.69 3,170.69 4,279.61 353.86 6,036,010.35 520,260.28 11.82 2,662.89 MWDAFR-AK-CAZ-SC(4) 6,427.09 80.50 345.89 3,234.96 3,185.96 4,370.22 -370.58 6,036,100.89 520,239.31 2.60 2,730.29 MWD+IFR-AK-CAZ-SC(4) 6,521.45 80.15 344.77 3,250.82 3,201.82 4,460.20 398.14 6,038,190.80 520,215.51 1.23 2,799.70 MWD+IFR-AK-CAZ-SC(4) 6,615.67 79.69 343.22 3,267.31 3,218.31 4,549.37 -02371 6,036,279.88 520,189.69 1.69 2,870.35 MWD+IFR-AK-CAZ-SC(4) 6,710.05 8009 339.00 3,283.88 3,234.88 4,637.26 -453.79 6,036,36268 520,159.37 442 2,944.03 MWD+IFR-AK-CAZ-SC(4) 6,802.95 79.71 338.08 3,300.18 3,251.18 4,722.38 -487.25 6,036,452.70 520,125.68 1.06 3,019.00 MWD+IFR-AK-CAZSC(4) 6,898.97 79.47 335.69 3,317.53 3,268.53 4,809.23 -524.32 6,036,53944 520,088.37 246 3,097.94 MWD+IFR-AK-CAZ-SC(4) 6,993.80 78.57 334.02 3,335.59 3,286.59 4,893.50 563.87 6,036,623.59 520,048.59 1.97 3,177.52 MWD+IFR-AK-CAZ-SC(4) 7,088.66 7701 334.51 3,355.65 3,306.65 4,977.01 504.13 6,036,706.98 520,008.10 1.72 3,257.26 MWD+IFR-AK-CAZ-SC(4) 7,183.15 78.05 332.54 3,376.06 3,327.05 5,059.59 545.26 6,036,789.44 519,966.75 2.31 3,337.22 MWD+IFR-AK-CAZ-SC(4) 7,277.04 78.65 332.66 3,395.02 3,346.02 5,141.23 587.58 6,036,870.95 519,924.21 0.65 3,417.64 MWD+IFR-AK-CAZSC(4) 7,370.87 79.07 330.57 3,413.15 3,364.15 5,222.22 -731.34 6,DW,951.81 519,880.22 2.23 3,498.91 MWD+IFR-AK-CAZSC(4) 7,466.77 81.05 330.18 3,429.70 3,380.70 5,304.33 -778.03 6,037,03378 519,833.31 2.10 3,583.24 MWD+IFR-AK-CAZ-SC(4) 7,561.29 8267 327.76 3,443.09 3,39409 5,384.49 -828.27 6,037,113.80 519,784.86 3.06 3,667.77 MWD+IFR-AK-CAZ-SC(4) 7,654.42 83.63 32312 3,45420 3,405.20 5,46062 578.71 6,037,189.77 519,732.21 5.05 3,753.58 MWD+IFR-AK-CAZ-SC(4) 7,749.17 83.29 318.54 3,465.00 3,416.00 5,533.58 -938.15 6,037,262.56 519,672.58 4.82 3,843.46 MWD+IFR-AK-CAZSC(4) 5/52017 2.21:08PM Page 4 COMPASS 5"..1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) She: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-1011.1 Survey Calculation Method: Minimum Curvature Design: 3R-1011.7 Database: OAKEDMP2 Survey Map Map vertical MD Inc Azi TVD TVDSS +N/3 +E/ -W Northing Easting DLS Section (usft) (9 0 (usR) (usft) (usft) (usft) (ft) (ft) ('/188') (ft) Survey Tool Name 7,843.93 83.31 316.31 3,476.05 3,427.05 5,602.88 -1,001.81 6,037,331.68 519,608.72 2.34 3,934.84 MWD+IFR-AK-CAZ-SC(4) 7,937,29 83.12 313.16 3,487.09 3,438.09 5,668.12 -1,067.66 6,037,396.73 519,542.70 3.36 4,025.79 MWD+IFR-AK-CAZSC(4) 7,980.65 82.66 310.87 3,492.45 3,443.45 5,696.91 -1,099.63 6.37,425.43 519,510.66 5.35 4,068.35 MWD+IFR-AK-CAZ-SC(4) 8,026.55 82.82 310.75 3,498.26 3,449.26 5,72867 -1,134.09 6,037,455.09 519,476.12 0.43 4,113.52 MWD+IFR-AK-CAZ-SC(4) 8,102.69 84.02 308.30 3,506.98 3,457.98 5,774.80 -1,192.43 6,037,503.06 519,417.65 3.56 4,188.74 MWD+IFR-AK-CAZ-SC(5) 8,19627 83.30 307.17 3,517.32 3,468.32 5,831.72 -1,265.98 6,037,559.77 519,343.95 1.43 4,281.51 MWD+IFR-AK-CAZ-SC(5) 8,290.64 80.09 306.79 3,530.94 3,481.94 5,887.89 -1,340.57 6,037,61572 519,269.22 3.42 4,37471 MWD+IFR-AK-CAZSC(5) 8,385.81 78.59 302.73 3,548.56 3,499.56 5,941.21 -141238 6,037,668.82 519,192.26 4.48 4,468.20 MWD+IFR-AK-CAZ-SC(5) 8,480.48 82.05 294.76 3,564.50 3,515.50 5,986.01 -1,499.13 6,037,713.39 519,110.39 9.07 4,561.09 MWD+IFR-AI(-CAZ-SC(5) 8,575.24 86.75 290.20 3,573.75 3,524.75 6,022.04 -1,58623 6,037,749.17 519,023.20 6.89 4,653.57 MWD+IFR-AK-CAZSC(5) 8,669,02 86.22 286.91 3,579.50 3,530.50 6,051.82 -1,674.96 6,037,778.71 518,934.40 3.55 4,743.96 MWD+IFR-AK-CAZ-SC(5) 8,763.77 89.34 281.26 3,583.17 3,534.17 6,074.84 -1,766.74 6,037,801.47 518,842.56 6.81 4,833.15 MWD+IFR-AIC-CAZSC(5) SAW11 89.82 275.16 3,583.87 3,534.87 6,038.45 -1,861.06 6,037,814.82 518,748.22 842 4,919.24 MWD+IFR-AK-CAZSC(5) 8,954.08 8952 271.80 3,584.42 3,535.42 6,094.21 -1,95584 6.37,820.32 518,653.43 3.55 5,001.37 MWD+IFR-AK-CAZ-SC(5) 9,047.67 86.64 271.51 3,58755 3,538.55 6,096.92 -2,049.33 6,037,822.76 518,559.95 3.09 5,080.74 MWD+IFR-AK-CAZ-SC(5) 9,141.11 87.22 269.20 3,592.56 3,543.56 6,097.49 -2,142.63 6,037,823.08 518,466.66 2.55 5,158.77 MWD+IFR-AK-CAZSC(5) 9,234.58 88.14 268.86 3,596.34 3,547.34 6,095.91 -2,236.00 6,037,821.24 518,373.29 1.05 5,235.68 MWD+IFR-AK-CAZ-SC(5) 9,327.48 88.28 269.08 3,599.24 3,550.24 6,094.24 -2,328.84 6,037,81931 518,280.47 0.28 5,312.08 MWD+IFR-AK-CAZ-SC(5) 9,391.00 86.18 269.65 3,602.31 3,553.31 6,093.54 -2,39228 6,037,818.43 518,217.04 3.42 5,364.53 INC+TREND(6) 9 618" x 12-1/4 9,392.00 86.15 269.66 3,602.38 3,553.38 6,093.53 -2,39328 6,037,818.42 518,216.04 3.42 5,365.35 INC+TREND(6) 9,409.59 8829 268.88 3,603.23 3,554.23 6,093.31 -2,41085 6,037,818.15 518,198.47 12.95 5,379.87 INC+TREND(6) 9,438.00 87.72 270.95 3,60422 3,55522 6,093.27 -2,439.24 6,037,818.03 518,170.09 7.55 5,403.49 GYD-GCSS(7) 9,525.02 85.26 262.99 3,609.56 3,560.56 6,088.69 -2,525.90 6,037,813.21 518,083.45 956 5,473.14 GYD-GCSS(7) 9,619.39 88.72 260.24 3,614.51 3,565.51 6,074.95 -2,619.11 6,037,799.21 517,990.29 4.68 5,543.18 GYD-GC-SS (7) 9,659.83 87.48 261.82 3,615.85 3566.85 6,068.65 -2,659.03 6,037,792.80 517,950.39 4.96 5,572.94 GYD-GCSS (8) 9,698.07 86.39 260.08 3,617.90 3,568.90 6,062.64 -2,696.73 6.37,786.69 517,912.70 5.36 5,601.03 GYD-GCSS (8) 9,770.96 90.75 260.43 3,619.71 3,570.71 6,050.31 -2,768.53 6,037,774.16 517,840.94 6.00 5,654.01 MWD+IFR-AK-CAZSC(9) 9,865.39 9368 260.64 3,616.07 3,567.07 6,034.79 -2,861.60 6,037,75839 517,74293 3.11 5,722.94 MWD+IFR-AK-CAZ-SC(9) 9,960.11 90.49 261.23 3,612.62 3,553.62 6,019.88 -2,955.6 6,037,74322 517,654.52 342 5,792.54 MWD+IFR-AK-CAZ-SG(9) 10,054.31 91.77 259.89 3,610.76 3,561.76 6,004.40 -3,047.96 6,037,727.48 517,561.68 2.01 5,861.35 MWD+IFR-A1C-CAZ-SC(9) 10,149.10 92.04 259.98 3,607.61 3,558.61 5,987.80 3,141.23 6,037,710.62 517,468.6 0.32 5,929.85 MWD+IFR-AK-CAZ-SC(9) 10,243.91 92.37 261.70 3,603.96 3,554.96 5,972.72 3,234.76 6,037,695.28 517,374.99 1.85 5,999.41 MWD+IFR-AK-CAZ-SC(9) 10,338.55 9076 263.17 3,601.38 3,552.38 5,960.26 -3,328.53 6,037,682.57 517,281.25 2.30 6,070.63 MWD+IFR-AK-CAZSC(9) 10,43344 89.14 263.82 3,60146 3,552.46 5,949.51 -3,422.81 6,037,671.56 517,187.02 1.84 6,14321 MWD+IFR-AK-CAZ-SC(9) 10,52809 88.04 266.16 3,603.79 3,554.79 5,941.25 3,517.06 6,037,663.04 517,092.80 2.73 6,217.14 MWD+IFR-AK-CAZ-SC(9) 10,621.97 88.31 270.42 3,605.78 3,557.78 5,938.45 -3,610.83 6,037,659.98 516,999.05 4.54 6,293.70 MWD+IFR-AK-CAZ-SC(9) 10,716.41 90.77 270.79 3,607.54 3,558.54 5,939.45 -3,70.5.25 6,037,660.71 516,904.63 263 6,372.90 MWD+IFR-AK-CAZSC(9) 10,811.03 90.74 270.18 3,606.29 3,557.29 5,940.25 -3,799.86 6,037,661.25 516,810.03 0.65 6,452.14 MWD+IFR-AK-CAZ-SC(9) 10,905.00 90.00 268.76 3,605.69 3,556.69 5,939.38 3,893,82 6,037,660.12 516,716.08 1.70 6,529.93 MWD+IFR-AK-CA7-SC(9) 532017 22v08PM Page 5 COMPASS 5000.1 BuIM 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True WeSbom: 3R-1011.1 Survey Calculation Method; Minimum Curvature Design: 3R-101 L7 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +E1 -W Northing Easting DLS Section (loft) 0 (0) (usft) (usft) (usft) (usft) (it) (ft) (011909 (ft) Survey Tool Name 11,000.45 89.81 266.85 3,605.84 3,558.84 5,935.72 3,989.20 6,037,656.20 516,620.73 2.01 6,607.35 MWD+IFR-AK-CAZSC(9) 11,094.67 89.65 267.15 3,606.29 3,557.29 5,930.79 4,083.29 6,037,651.01 516,526.66 0.36 6,682.99 MWD+IFR-AK-CAZ-SC (9) 11,18953 90.48 266.64 3,606.18 3,557.18 5,925.66 4,178.01 6,037,645.61 516,431.96 1.03 6,759.04 MND+IFR-AK-CAZSC(9) 11,284.13 91.99 266.72 3,604.14 3,555.14 5,920.18 4,272.42 6,037,639.87 516,337.57 1.60 6,834.66 MWD+IFR-AK-CAZ-SC(9) 11,378.89 91.58 267.17 3,601.19 3,552.19 5,915.13 4,36200 6,037,63456 516,243.02 0.64 6,910.84 MND+IFR-AK-CA2-SC(9) 11,471.23 94.01 267.55 3,596.69 3,547.69 5,910.88 4,459.13 6,037,630.06 516,150.91 2.66 6,985.03 MWD+IFR-AK-CAZSC(9) 11,568.32 92.48 267.57 3,591.19 3,542.19 5,90676 4,555.97 6,037,62566 516,054.09 1.58 7,063.41 MWD+1FR-AK-CAZSC(9) 11,663.04 93.38 267.37 3,586.35 3,537.35 5,902.58 4,650.47 6,037,621.23 515,959.61 0.97 7,139.81 MWD+IFR-AK-CAZ-SC(9) 11,758.11 94.20 268.78 3,580.07 3,531.07 5,89939 4,745.28 6,037,617.78 515,864.82 1.71 7,217.02 MWD+IFR-AK-CAZ-SC(9) 11,852.56 93.15 259.12 3,574.01 3,525.01 5,897.67 4,839.52 6,037,61579 515,770.60 1.17 7,294.% MND+IFR-AI(-CAZ-SC(9) 11,946.96 90.90 289.07 3,570.68 3,52168 5,896.18 4,933.84 6,037,614.04 515,676.29 238 7,372.30 MWD+IFR-AK-CAZSC(9) 72,041.61 89.84 271.14 3570.07 3,521.07 5,896.35 -5,028.48 6,037,613.95 515,581.66 2.46 7,451.23 MWD+IFR-AK-CAZ-SC(9) 12,137.27 9129 272.42 3,569.12 3,520.12 5,899.32 -5,124.09 6,037,676.65 515,486.05 2.02 7,532.50 MND+IFR-AK-CAZ-SC(9) 12,230.94 91.41 272.83 3,566.92 3,517.92 5,903.61 521263 6,037,620.68 515,392.51 0.46 7,61280 MWD+IFR-AK-CAZSC(9) 12,325.71 90.18 271.97 3,565.60 3,516.60 5,907.58 5,312.31 6,037,624.39 515,297.83 1.58 7,693.85 MWD+IFR-AK-CAZSC(9) 12,420.62 89.79 272.10 3,566.12 3,517.12 5,910.95 -5,407.15 6,037,627.49 515,202.98 1.05 7,774.72 MWD+IFR-AK-CAZ-SC(9) 12,514.94 89.27 270.81 3,567.39 3,518.39 5,913.34 5,501.43 8,037,629.63 515,108.71 1.37 7,854.57 MWD+IFR-AK-CAZ-SC(9) 12,609.47 89.18 270.48 3568.67 3,519.67 5,914.41 -5,595.95 6,037,630.43 515,014.20 0.36 7,933.89 MWD+IFR-AK-CAZSC(9) 12,704.11 89.31 269.89 3,569.92 3,520.92 5,914.71 -5,690.58 6,037,63047 514,979.58 0.64 8,012.88 MWD+IFR-AK-CAZ-SC(9) 12,799.17 89.98 269.19 3,570.50 3,521.50 5,913.95 5,785.63 6,037,629.44 514,824.54 1.02 8,09163 MWD+IFR-AK-CAZ-SC(9) 12,893.33 89.51 268.77 3,570.92 3,521.92 5,912.27 -5,879.78 6,037,627.51 514,730.41 0.67 8,169.12 MWD+1FR-AK-CAZSC(9) 12,987.64 89.96 268.94 3,571.36 3,522.36 5,910.39 -5,973.97 6,037,625.36 514,636.23 0.51 8,246.53 MND+IFR-AK-CAZ-SC (9) 13,081.98 90.02 269.39 3,571.38 3,522.38 5,909.01 5,068.40 6,037,623.72 514,547.81 0.48 8,324.43 MWD+IFR-AK-CAZ-SC(9) 73,176.96 88.12 269.29 3,572.92 3,523.92 5,907.92 5,163.35 6,037,622.37 514,446.87 2.00 8,402.91 MWD+IFR-AK-CAZSC(9) 13,272.05 89.19 269.04 3,575.15 3526.15 5,906.53 5,258.41 6,037,620.72 514,351.83 1.16 8,481.32 MWD+IFR-AK-CAZSC(9) 13,366.17 89.85 269.96 3,575.94 3,526.94 5,905.71 5,352.52 6,037,619.64 514,257.73 1.20 8,55926 MND+IFR-AK-CAZ-SC(9) 13,460.80 89.88 270.65 3,576.16 3,527.16 5,906.22 5,447.14 6,037,619.88 514,163.11 0.73 8,638.36 MND+IFR-AI(-CAZ-SC(9) 13,55564 90.83 270.26 3,575.57 3,52657 5,906.97 5,541.98 6,037,620.37 514,068.29 1.08 8,717.76 MWD+IFR-AKCAZ-SC(9) 13,650.19 90.77 277.06 3,574.25 3,525.25 5,908.06 5,836.51 6,037,621.19 513,973.76 0.85 8,797.11 MWD+IFR-AK-CAZSC(9) 13,744.83 89.99 271.71 3,573.63 3,524.63 5.9 s!i 5,731A3 6,037,622.72 513,879.14 0.83 8,876.91 MWD+1FR-AK-CAZSC(9) 13,840.07 91.35 273.34 3,572.51 3,523.51 5,913.55 5,826.29 6,037,626.15 513,783.99 2.74 8,958.22 MWD+1FR-AK-CAZSC(9) 13,934.79 91.43 272.02 3,570.21 3,521.21 5,917.98 5,920.87 6,037,630.32 513,68940 140 9,039.45 MWD+IFR-AK-CAZSC(9) 74,029.33 90.71 271.32 3,568.45 3,519.45 5,920.73 -7,015.35 6,037,632.81 513,594.92 1.06 9,119.67 MND+1FR-AK-CAZSC(9) 14,123.74 90.80 269.47 3,567.20 3,518.20 5,921.38 -7,109.75 6,037,633.20 513,50053 1.96 9,198.66 MND+IFR-AK-CAZ-SC(9) 14,218.35 90.13 269.02 3,566.44 3,51]44 5,920.13 -7,204.35 6,037,63169 513,405.95 0.85 9,276.77 MWD+IFR-AK-CAZ-SC(9) 14,312.36 9044 268.85 3,555.97 3,516.97 5,918.39 -7,298.34 6,037,629.68 513,311.97 0.38 9,354.09 MWD+IFR-AK-CAZ-SC(9) 14,406.91 90,62 268.39 3,565.09 3,516.09 5,916.11 -7,392.85 6,037,62214 513,217.47 0.52 9,431.56 MND+1FR-AK-CAZSC(9) 14,500.96 90.56 268.14 3,564.13 3,515.13 5,913.26 -7,466.86 6,037,624.04 513,123.49 0.27 9,508.28 MND+IFR-AK-CAZ-SC(9) 14,594.71 90.41 267.13 3,563.33 3,514.33 5,909.39 -7580.53 6,037,619.91 513,029.84 1.09 9,584.16 MWD+IFR-AK-CAZ-SC(9) 14,687.46 90.48 268.25 3,562.61 3,513.61 5,905.66 -7,673.20 6,037,61591 512,937.19 1.21 9,659.28 MWD+IFR-AK-CAZ-SC(9) SWO17 2:21:08PM Page 6 COMPASS 5000. I Build 74 Definitive Survey Report company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-1011-7 Survey Calculation Method: Minimum Curvature Design: 3R-1011_1 Database: OAKEDMP2 Survey O Surface Coordinates 1-1 Declination & Convergence 0 GRS Survey Corrections 2] Survey Tool Codes SLB DE; Brandon Temple 11;01441464&�%, jy Client Representative. Digiol" by Bei Tolman Ben Tolman tE^) 1111AN 14M Nn71IM105106 4Bi0a Date: 5/812017 Map Map Vertical Mo Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) 0 0 (usft) Wall) (usft) (usft) (ft) (ft) (°M001 (ft) Survey Tool Name 14,760.45 90.18 269.01 3,562.08 3,513.08 5,903.43 -7,766.16 6,037,613.43 512,84424 call 9,735.48 MWD+1FR-AK-CAZSC(9) 14,87304 9000 269.97 3,561.93 3,512.93 5,90261 -7,858.74 6,037,612.35 512,751.67 1.05 9,812.14 MWD+IFR-AK-CAZSC(9) 14,967.31 90.45 27026 3,561.56 3,512.56 5,902.60 -7,95301 6,037,612.28 512,65241 0.57 9,890.77 MWDNFR-AK-CAZSC(9) 15,060.54 90.41 270.80 3,560.86 3.511.86 5,903.66 5,046.23 6,037,612.88 512,564.20 0.58 9,968.89 MWD+IFR-AK-CAZ-SC(9) 15,15324 9D29 270.41 3,560.29 3,511.29 5,904.64 5,138.93 6,D37,613.60 512,471.51 0.44 10,046.64 MWD+1FR-AK-CAZSC(9) 15,246.21 90.24 271.28 3,559.86 3,510.86 5,906.01 5,231.89 6,037,614.72 512,378.56 0.99 10,124.83 MWD+IFR-AK-CAZSC(9) 15,339.98 9125 270.36 3,558.65 3,509.65 5,907.35 5,325.64 6,037,615.80 512,284.81 146 10,203.66 MWD+IFR-AXCAZ-SC(9) 15,433.33 92.90 271.48 3,555.27 3,506.27 5,909.85 5,418.91 6,037,617.04 512,191.55 2.14 10,282.18 MWD+IFR-AK-CAZSC(9) 15,525.98 91.79 259.55 3,551.47 3,502.47 5,909.68 5,511.47 6,037,617.61 512,098.99 2.40 10,359.74 MWDNFR-AK-CAZ-SC(9) 15,619.48 9131 268.09 3,548.62 3,499.62 5,907.76 5,604.90 6,037,615.43 512,005.57 1-56 10,436,50 MWD+IFR-AK-CAZSC(9) 15,712.68 92.43 268.76 3,545.25 3,496.25 5,905.20 5,698.01 6,037,612.61 511,912.49 1.05 10,512.64 MWD+IFR-AK-CAZ-SC(9) 15,806.16 91.01 268.04 3,542.45 3,493.45 5,902.59 5,791.41 6,037,609.74 511,819.10 1.70 10,588.99 MWD+IFR-AKCAZSC(9) 15,832.56 91.44 268.47 3,541,88 3,492.88 5,901.78 5,817.81 6,037,608.86 511,792.71 2.30 10,610.53 MWD+IFR-AK-CA7-SC(9) 15,863.00 9144 268.47 3,541.12 3,492.12 5,900.97 5,848.21 6,037,60297 511,762.31 0.00 10,635.41 PROJECTED to TD 4112' 15,896.00 9144 268.47 3,540.29 3,491.29 5,900.09 5,881.18 6,037,607.00 511,729.34 000 10,662.39 PROJECTED to TD Final Definitive Survey Verified and Signed -of All targets and/or well position objectives have been achieved. Cl Yes ❑ No ! have Checked to the best of my ability that the following data is correct: O Surface Coordinates 1-1 Declination & Convergence 0 GRS Survey Corrections 2] Survey Tool Codes SLB DE; Brandon Temple 11;01441464&�%, jy Client Representative. Digiol" by Bei Tolman Ben Tolman tE^) 1111AN 14M Nn71IM105106 4Bi0a Date: 5/812017 515/2017 2:27'08PM Page 7 COMPASS 5000.1 Build 74 NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-101L1PB1 Definitive Survey Report 05 May, 2017 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellborn: 3R-101L1PB1 Survey Calculation Method: Minimum Curvature Design: 3R-101 L1 PB1 Database: OAKEDMP2 Project Kupamk River Unit, North Slope Alaska, United States 9.90 usf Map System: US State Plane 1927 (Enact solution) System Datum: Mean Sea Level Gan Datum: NAD 1927 (NADCON CONUS) 3/29/2017 8:47:, Using Well Reference Point Map Zone: Alaska Zone 04 MWD+IFRAKCAZSCC Using geodetic scale factor Veil 3R-101 Audit Notes: To Veil Position +NIS 0.00 usft Northing: 6,031,732.16 usft Latitude: 70° 29'52.272 1 9,327.48 +E/ -W 0.00 usft Easting: 520,625.98 usft Longitude: 149° 49'52.775 V 'osition Uncertainty (usft) 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usf Wellbore 3R-101L1PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength l°) V) (nT) BGGM2016 4/20/2017 17.69 81.04 57,550 Design 3R-101L1PB1 Date Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tle On Depth: 9,327.48 vertical Section: Depth From (TVD) +N/ -S +EI -W Direction 676.74 (usft) (usft) (usft) (°) 2,208.44 39.10 0.00 0.00 335.11 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 3R-101 Srvy 1 - SLB_GYD-GC-SS (3R-1 GYD-GC-SS Gymdata gyro single shots 3/24/2017 8:28> 676.74 2,153.783R-101 Srvy2-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/24/2017 8:31: 2,208.44 2,208.44 3R-101 Srvy 3 - SLB_GYD-GCSS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/25/2017 8:33 2,297.00 8,026.553R-101 Srvy4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/29/2017 8:47:, 8,102.69 9,327.483R-101 Srvy 5- Sue _MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/1/2017 2:48:0 9,392.00 9,409.593R-101L1PB1 Srvyl- Inc + Trend (3R-10 INC+TREND Inclinometer +known azi trend 4/14/2017 8:59, 9,438.00 9,713.813R-101L1PBl Srvy2-SLB_GWD70(3R- GYD-GCSS Gyrodata gyro single shots 4/14/2017 9:10: Survey 552017 2:27:23PM Page 2 COMPASS 50001 Build 74 Map Map vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (') V) (usft) (usft) (usft) (usft) (ft) (it) (waw (ft) Survey Tool Name 39.10 000 0.00 39.10 -990 0.00 0.00 6,031,732.16 520,625.98 0.00 0.00 UNDEFINED 135.69 0.74 51.62 135.69 86.69 0.39 049 6,031,732.55 520,626.47 0.77 0.15 GYD-GC-SS(1) 169.59 0.74 47.48 169.58 120.58 0.67 0.82 6,031,732.83 520,626.80 0.16 0.26 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 213.71 2.03 1.24 6,031,734.19 520,627.21 0.95 1.32 GYD-GC-SS(1) 356.57 2.27 336.68 356.51 307.51 469 0.47 6,031,736.85 520,626.44 1.34 4.06 GYD-GCSS(1) 451.76 3.38 327.54 451.58 402.58 8.79 -1.78 6,031,740.95 520,624.17 1.25 8.73 GYD-GC-SS(1) 545.32 3.75 318.73 544.96 495.96 13.42 528 6,031,745.56 520,620.65 0.71 14.39 GYD-GC-SS(1) 638.81 5.49 307.39 638.15 58.9.15 1643 -10.85 6,031,750.56 520,615.08 2.09 21.29 GYD-GC-SS(1) 676.74 6.24 302.09 675.88 62888 20.63 -14.04 6,031,752.75 520,611.88 2.44 24.62 MWD+IFR-AK-CAZSC(2) 552017 2:27:23PM Page 2 COMPASS 50001 Build 74 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-101 Project- Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wel@ons: 3R -1011-1P81 Survey Calculation Method: Minimum Curvature Design: 3R-101L1PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AM TVD TVDSS NUS +E/ -W Northing Easting OLS Section (usft) (1) (9 (lust) (usft) (usft) (usft) (ft) (ft) (°Moo') (it) Survey Tool Name 770.88 7.30 300,95 769.36 720.36 26.42 -23.50 6,031,758.52 520,602.40 1.13 33.86 MWD+IFR-AK-CA7-SC(2) 863.73 9.86 309.12 861.17 812.17 34.47 -34.73 6,031,766.53 520,591.15 3.05 45.89 MWD+IFR-AK-CAZ-SC(2) 959.66 9.96 317.32 955.69 906.69 45.76 -46.73 6,031,777.78 520,579.13 1.47 61.18 MWD+IFR-AK-CAZSC(2) 1,053.73 12.30 328.76 1,047.98 998.98 60.31 -5744 6,031,792.30 520,568.37 3.41 76.88 MWD+IFR-AK-CA7-SC(2) 1,149.13 13.66 347.18 1,140.98 1,091.98 79.99 -65.22 6,031,811,96 520,560.55 4.54 100.01 MWD+IFR-AK-CAZSC(2) 1,243.57 14.34 355.31 1,232.62 1,183.62 102.52 58.65 6,031,834.48 520,557.05 2.20 121.89 MWD+IFR-AK-CAZSC(2) 1,338.60 14.97 357.92 1,324.55 1,275.55 126.52 -70.06 6,031,858.47 520,555.58 0.% 144.25 MWD+IFR-AK-CAZ-SC(2) 1,433.41 15.24 359.78 1,416.09 1,367.09 151.21 -70.55 6,031,883.16 520,55502 0.59 166.86 MWD+IFR-AK-CAZ-SC (2) 1,527.63 14.50 0.11 1,507.16 1,458.16 175.39 -70.57 6,031,907,34 520,55493 0.79 188.80 MWDAFR-AI(-CAZ-SC(2) 1,620.81 1727 0.21 1,596.77 1,547.77 200.89 -70.50 6,031,932.84 520,554.93 2.97 211.91 MWD+IFR-AK-CAZ-SC(2) 1,716.88 16.84 1.37 1,688.62 1,639.62 229.07 -70.12 6,031,961.01 520,555.24 0.57 237.30 MWD+IFR-AK-CAZSC(2) 1,811.40 19.05 358.74 1,778.53 1,729.53 258.19 -70.13 6,031,990.13 520,555.14 2.50 263.72 MWD+IFR-AK-CAZ-SC(2) 1,90614 20.91 356.99 1,867.56 1,818.56 290.54 -71,36 6,032,022.47 520,553.83 2.05 293.58 MWD+IFR-AK-CAZ-SC(2) 2,000.30 24.98 355.65 1,954.26 1,905.26 327.16 -73.75 6,032,059.08 520,551.33 4.36 327.80 MWD+IFR-AK-CAZSC(2) 2,094.43 28.81 355.00 2,038.19 1,989.19 MR% -77.23 6,032,101,50 520,547.73 4.08 367,76 MWD+IFR-AK-CAZ-SC(2) 2,153.78 WAl 355.47 2,089.86 2,040.86 398.68 -79.65 6,032,130.57 520,545.23 2.22 395,16 1AWD+IFR-AK-CAZ-SC(2) 2,208.44 33.91 35].04 2,136.21 2,087.21 427.58 51.53 6,032,15947 520,543.28 7.12 422.17 GYD-GC-SS(3) 2,243.00 34.53 357.36 2,164.78 2,115.78 446,99 52.48 6,032,178.88 520,542.27 1.88 44018 MWD+IFR-AK-CAZSC(4) 133/8" 2,297.00 35.51 357.84 2,209.00 2,160.00 477.95 -83.77 6,032,209.84 520,540.89 1.88 468.81 MWD+IFR-AK-CAZ-SC(4) 2,353.55 37.24 35870 2,254.53 2,205.53 511.48 54.78 6,032,243.35 520,539.79 3.19 499.64 MWD+IFR-AK-CAZSC(4) 2,448.06 41,36 358.32 2,327.65 2,278.65 571.31 -86.34 6,032,303.17 520,538.06 4.37 554.57 MWD+IFR-AK-CAZ-SC(4) 2,543.56 45.79 0.39 2,396.83 2,347.83 637,11 57.04 6,032,368.96 520,537.19 4.87 614.55 MWD+IFR-AK-CAZ-SC(4) 2,637.75 49.OB 0.59 2,460.53 2,411.53 706.47 56.44 6,032,438.31 520,537.59 3.50 677.21 MWD+IFR-AK-CAZSC(4) 2,732.27 54,02 1.62 2,519.29 2,470.29 780.45 14.99 6,032,512.29 520,538.83 5.30 743.71 MWD+IFR-AK-CAZ-SC(4) 2,826.93 58.92 0.47 2,571,56 2,522.56 859.32 -83.57 6,032,591.16 520,540.03 5.27 814.66 MWD+IFR-AK-CAZ-SC(4) 2,919.52 63.48 0.11 2,616.16 2,567.16 940.43 413.17 6,032,672.27 520,540.21 4.94 888.06 MWD+IFR-AK-CAZSC(4) 3,015.11 67.32 358.34 2,655.94 2,606.94 1,027.32 -84.36 6,032,759.14 52Q538.77 4.36 967.38 MWD+IFR-AK-CA7-SC(4) 3,110.07 71.37 357.59 2,689.43 2,640.43 1,116.10 57.53 6,032,84790 520,535.37 4.33 1,04924 MWD+IFR-AK-CAZ-SC(4) 3,204.89 75.87 35515 2,716.17 2,667.17 1,206.86 -93.31 6,032,938.63 520,529.33 5.35 1,134.00 MWD+IFR-AK-CAZ-SC(4) 3,300.64 80.10 354.91 2,736.14 2,687.14 1,300.33 -101.44 6,033,032.07 520,520.95 442 1,222.21 MWD+IFR-AK-CAZSC(4) 3,395.53 80.99 355.26 2,751.69 2,702.69 1,393.39 -109.44 6,033,125.10 520,512.69 1.01 1,309.99 MWD+IFR-AK-CAZSC(4) 3,490.19 81.39 356.24 2,766.19 2,717.19 1,466.67 -116.37 6,033,218.36 520,505.50 1.11 1,397.52 MWD+IFR-AK-CAZ-SC(4) 3,58299 81.43 356.82 2,780.05 2,73105 1,578.25 -122.08 6,033,309.91 520,499.53 0.41 1,48300 MWD+IFR-AK-CAZ-SC(4) 3,679.39 81.52 35589 2,794.34 2,745.34 1,673.38 -128.31 6,033,405.02 520,493.04 075 1,571.91 MWD+IFR-AK-CAZ-SC(4) 3,774.67 81.52 354.32 2,808.39 2,759.39 1,767.28 -136.35 6,033,498.88 520,48434 1.63 1,600.47 MWD+IFR-AK-CAZSC(4) 3,869.26 81.14 354.65 2,822.65 2,773.65 1,860.35 -145.34 6,033,591.92 520475.49 0.53 1,748.68 MWD+IFR-AK-GAZSC(4) 3,963.62 81.59 364.57 2,836.82 2,787.82 1,953.23 -154.10 6,033,68476 520,465.47 0.48 1,836.61 MWD+IFR-AK-CAZ-SC(4) 4,05B.18 B1.39 354.86 2,850.81 2,801.81 2,046.35 -162.72 6,033,777.85 520,45760 0.37 1,924.71 MWD+IFR-AK-CAZ-SC(4) 4,153.32 81.31 355.47 2,865.12 2,816.12 2,140.07 -170.64 6,033,871.54 520,449.41 0.64 2,013.05 MWD+IFR-AK-CAZ-SC(4) 532017 2.27:23PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kupanik River Una TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101LiPB1 Survey Calculation Method: Minimum Curvature Design: 3R-101UP81 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) 0 (usft) (usft) (usft) (usft) (ft) (ft) ('11001 (ft) Survey Tool Name 4,247.21 81.19 356.30 2,87941 2,830.41 2,232.63 -177.30 6,033,964.07 520,44250 0.88 2,099.82 MWD+IFR-AK-CAZSC(4) 4,341.81 8129 357.42 2,893.81 2,844.81 2,325.99 -182.42 6,034,057.40 520,437.12 1.17 2,186.66 MW0+IFR-AK-CAZSC(4) 4,436.87 81.31 358.76 2,908.19 2,859.19 2,419.90 -185.56 6,034,151.29 520,433.73 1.39 2,273.16 MWD+IFR-AK-CAZ-SC(4) 4,532.86 81.46 359.12 2,922.57 2,873.57 2,514.79 -187.31 6,034,246.17 520,431.71 0.40 2,359.97 MWD+IFR-AK-CAZSC(4) 4,627.23 81.49 358.61 2,936.56 2,887.55 2,608.10 -189.16 6,034,339.46 520,42960 0.54 2,40.5.39 MWD+IFR-AK-CAZ-SC(4) 4,722.52 81.62 358.05 2,950.56 2,901.56 2,702.31 -191.91 6,034,433.66 520,426.59 0.60 2,532.01 MWD+IFR-AK-CAZSC(4) 4,816.15 81.17 357.64 2,964.57 2,915.57 2,794.82 -195.39 6,034,526.15 520,422.86 0.65 2,617.39 MWD+IFR-AK-CAZ-SC(4) 4,910.05 81.65 WT59 2,978.59 2,929.59 2,887.59 -199.25 6,034,618.90 520,418.74 0.51 2,703.16 MWD+IFR-AK-CAZ-SC(4) 5,055.50 81.45 357.34 2,992.62 2,943.62 2,981.91 -203.43 6034,713.20 520,414.30 0.33 2,790.48 MWD+IFR-AK-CAZSC(4) 5,099.31 80.43 356.19 3,007.39 2,958.39 3,074.40 -20865 6,034,805.66 520408.82 1.63 2,876.57 MWD+IFR-AK-CAZ-SC(4) 5,194.23 79.74 356.96 3,023.73 2,974.73 3,167.73 -214.24 6,034,898.97 520,402.97 1.08 2,963.59 MWD+IFR-AK-CAZ-SC(4) 5,288.73 80.17 357.41 3,040.22 2,991.22 3,260.67 -218.81 6,034,991.89 520,398.14 065 3,04981 MWD+IFR-AK-CAZSC(4) 5,384.03 80.16 355.86 3,056.49 3,007.49 3,354.41 -224.32 6,035,085.60 520,392.37 1.60 3,137.16 MWD+IFR-AK-CAZ-SC (4) 5,478.50 80.16 MEW 3,072.64 3,023.64 3,447.19 -231.73 6,035,178.35 520,384.71 0.89 3,224.44 MWD+IFR-AK-CAZ-SC(4) 5,574.37 79.88 352.33 3,089.26 3,040.26 3,541.03 -242.14 6,035,272.15 520,374.04 2.77 3,313,94 MWD+IFR-AK-CAZ-SC(4) 5,668.19 80.05 352.29 3,105.61 3,056.61 3,832.58 -254.50 6,035,363.66 520,361.43 0.19 3,402.19 MWD+IFR-AK-CAZSC(4) 5,762.98 79.70 350.63 3,122.27 3,073.27 3,724.85 -268.36 6,035,455.89 520,347.32 1.76 3,491.72 MWD+IFR-AK-CAZ-SC(4) 5,858.90 79.93 350.94 3,139.23 3,090.23 3,818.04 -283.48 6,035,549.02 520,331.94 0.40 3,58262 MWD+IFR-AK-CAZSC(4) 5,953.58 79.83 352.59 3,155.87 3,106.87 3,910.29 -296.83 6,035,641.22 520,318.34 1.72 3,671.91 MWD+IFR-AK-CAZ-SC(4) 6,048.38 79.78 35357 3,17265 3,123.65 4,002.91 508.07 6,035,733.80 520,306.84 1.02 3,760.66 MWD+IFR-AK-CAZ-SC(4) 6,142.31 806W 351.82 3,188.61 3,139.61 4,094.72 -319.84 6,035,825.57 520,29461 2.06 3,848.89 MWD+IFR-AK-CAZ-SC(4) 6,237.62 80.49 349.06 3,204.23 3,155.23 4,187.42 -335,45 6,035,918.22 520,278.95 2.86 3,939.56 MWD+IFR-AK-CAZSC(4) 6,332.89 80.84 348.35 3,219.69 3,170.69 4,279.61 553.85 6,036,010.35 520,260.28 0.82 4,030.93 MWD+IFR-AK-CAZ-SC(4) 6,42709 80.50 345.89 3,234.96 3,185.96 4,370.22 574.58 6,036,100.89 520,239.31 2.60 4,121.64 MWD+IFR-AK-CAZSC(4) 6,521,45 80.15 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,036,190.80 520,215.51 1.23 4,213.38 MWD+IFR-AK-CAZ-SC(4) 6,615.67 79.69 343.22 3,267.31 3,218.31 4,549.37 -423.71 6,036,279.88 520,189.69 1.69 4,305.02 MWD+IFR-AK-CAZ-SC(4) 6,710.05 80.09 339.00 3,283.88 3,234.88 4,637.26 -45379 6,036,367.68 520,159.37 4.42 4,397.41 MWD+IFR-AK-CAZSC(4) 6,802.95 79.71 338.08 3,300.18 3,251.18 4,722.38 -487.25 6,036,452.70 520,125.68 1.06 4,488]0 MWD+IFR-AK-CAZ-SC(4) 6,898.97 79.47 33569 3,317.53 3,268.53 4,809.23 524.32 6,036,539.44 520,088.37 246 4,583.09 MWD+IFR-AK-CAZ-SC(4) 6,993.80 78.57 334.02 3,335.59 3,286.59 4,893.50 -563.87 6,036,623.59 520,048.59 1.97 4,676.18 MWD+IFR-AK-CAZ-SC(4) 7,08866 77.01 334.51 3,355.65 3,305.65 4,977.01 504.13 6,035,706.98 520,008.10 1.72 4,768.88 MWD+FR4kK-CAZ-SC(4) 7,183.15 78.05 332.54 3,376.06 3,327.06 5,059.59 645.26 6,036,789.44 519,966.75 2.31 4,851.10 MWD+IFR-AK-CAZSC(4) 7,277.04 78.65 33266 3,395.02 3,346.02 5,141.23 687,58 6,036,870.95 519,924.21 0.65 4,952.96 MWD+IFR-AK-CAZSC(4) 7,370.87 79.07 330.57 3,413.15 3,354.15 5,222.22 -731.34 6,036,951.81 519,880.22 2.23 5,044.85 MWD+IFR-AK-CAZ-SC(4) 7,466.77 81.05 330.18 3,429.70 3,380.70 5,304.33 -778.03 6,037,033.78 519,833.31 2.10 5,13898 MWD+IFR-AK-CAZ-SC(4) 7,561.29 82.67 327.76 3,443.09 3,394.09 5,384.49 -826.27 6,037,113.80 519,784.86 3.06 5,232.00 MWD+IFR-AK-CAZ-SC(4) 7,654.42 83.63 323.12 3,454.20 3,405.20 5,460.62 678.71 6,037,189.77 519,732.21 5.05 5,323.13 MWD+IFR-AK-CAZ-SC(4) 7,749.17 83.29 318.54 3,465.00 3,416.00 5,533.58 -938.15 6,037,262.56 519,672.58 4.82 5,414.33 MWD+IFR-AK-CAZ-SC(4) 7,843.93 83.31 316.31 3,476.05 3,427.05 5,602.88 -1,001.81 6,037,331.68 519,608.72 2.34 5,503.99 MWD+IFR-AK-CAZ-8C(4) 7,937.29 83.12 313.16 3,467.09 3,438.09 5,668.12 -1,067.66 6,037,396.73 519,542.70 3.36 5,590.89 MWD+IFR-AK-CAZSC(4) 5/52017 2..27r23PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3R-101 Project Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101L1PB1 Survey Calculation Method: Minimum Curvature Design: 3R-101L1PB1 Database: OAKEDMP2 Survey Map Map vertical MD Inc /Isi TVD TVDSS +N/ -S +E/ -W Northing Pasting DLS Section (usft) C) (') (usft) (usft) Will) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 7,980.65 82.66 310.87 3,492.45 3,443.45 5,696.91 -1,099.63 6,037,425.43 519,510.66 5.35 5,63047 MWD+IFR-AKCAZSC(4) 8,026.55 82.82 310.75 3,498.26 3,449.26 5,726.67 -1,134.09 6,037,455.09 519,476.12 0.43 5,671.97 MWD+IFR-,U,[-CAZ-SC(4) 8,102.69 84.02 308.30 3,506.98 3,457.98 5,774.80 -1,192.43 6,037,503.06 519,41765 3.56 5,740.18 MWD+IFR-AK-CAZSC(5) 8,196.27 83.30 307.17 3,517.32 3,468.32 5,831.72 -1,265.98 6,037,559.77 519,343.95 1.43 5,822.78 MWD+IFR-AK-CAZSC(5) 8,290.64 80.09 306.79 3,530.94 3,481.94 5,887.89 -1,340.57 6,037,615.72 519,269.22 3.42 5,905.12 MWD+IFR-AK-CAZ-SC(5) 8,385.81 78.59 302.73 3,548.56 3,493.56 5,941.21 -1,417.38 6,037,658.82 519,19226 4.48 5,985.82 MWD+IFR-AK-CAZSC(5) 8,480.48 82.05 294.76 3,564.50 3,51550 5,986.01 -1,499.13 6,037,713.39 519,110.39 9.07 6,060.88 MWD+IFR-AK-GAZSC(5) 8,575.24 86.75 290.20 3,573.75 3,524.75 6,022.04 -1,586.23 6,037,749.17 519,023.20 6.89 6,130.22 MWD+IFR-AK-CAZSC (5) 8,669.02 115.22 286.91 3,579.50 3,530.50 6,051.82 -1,674.96 6,037,778.71 518,934.40 3.55 6,194.58 MWD+IFR-AK-CAZSC(5) 8,763.77 89.34 281.26 3,583,17 3,534.17 6,074.84 -1,766.74 6,037,80147 518,842.56 6.81 6,254.11 MWD+IFR-AKCAZSC(5) 8,859.11 89,82 275.16 3,583.87 3,534.87 6,088.45 -1,861.06 6,037,814.82 518,748.22 6.42 6,306.15 MWD+IFR-AKCAZSC(5) 8,954.08 89.52 271.80 3,584.42 3,535.42 6,094.21 -1,955.84 6,037,820.32 518,653.43 3.55 6,351.28 MWD+IFR-AKCAZSC (5) 9,04767 86.64 271.51 3,587.55 3,538.55 6,096.92 -2,049.33 6,037,822.76 518,559.95 3.09 6,393.08 MWD+IFR-AKCAZSC(5) 9,141.11 8722 269.20 3,592.56 3,643.56 6,097.49 -2,142.63 6,037,823.08 518,466.66 2.55 6,432.88 MWD+IFR-AKCAZSC(5) 9,234.58 88.14 268.86 3,596.34 3,547.34 6,095.91 -2,236.00 6,037,821.24 518,37329 1.05 6,470.75 MWD+IFR-AK-CAZSC(5) 9,327.48 88.28 259.08 3,599.24 3,550.24 6,094.24 -2,328.84 6,037,819.31 518,280.47 0.28 6,508.32 MWD+IFR-AKCAZSC(5) 9,391.00 86.18 269.65 3,602.31 3,553.31 6,093.54 -2,392.28 6,037,818.43 518,217.04 3.42 6,534.38 INC+TREND (6) 8 6/8" s 12.1/4 9,39200 86.15 259.66 3,602.38 3,553.38 6,093.53 -2,393.28 6,037,818.42 518,216.04 3.42 6,534.80 INC+TREND (6) 9,409.59 88.29 268.88 3,60323 3,554.23 6,093.31 -2,410.85 6,037,818.15 518,198.47 12.95 6,541.99 INC+TREND(6) 9,438.00 87.72 270.95 3,604.22 3,555.22 6,093.27 -2,439.24 6,037,818.03 518,170.09 7.55 6,553.90 GYD-GC-SS(7) 9,525.02 85.26 262.99 3,609.56 3,560.% 6,088.69 -2,525.90 6,037,813.21 518,083.45 9.56 6,586.23 GYD-GCSS(7) 9,619.39 88.72 26024 3,614.51 3,565.51 6,074.95 -2,619.11 6,037,799.21 517,990.29 4.68 6,613.00 GYD-GCSS(7) 9,660.00 90.22 258.33 3,614.89 3,565.89 6,067.40 -2,659.00 6,037,791.55 517,950.42 5.99 6,622.94 GYD-GCSS (7) 4-1/2" 9,713.81 92.21 255.79 3,613.74 3,564.74 6,055.35 -2,711.43 6,037,779.36 517,898.03 5.99 6,63408 GYD-GCSS(7) 9,805.00 92.21 255.79 3,61023 3,561.23 6,032.98 -2,799.76 6,037,756.75 517,809.77 0.00 6,650.98 PROJECTED to TO 83/4" OH �inal Detinilive Survey Verified and Signedaff a1 rarpart on4ror umr uwmpn uq.�a'..., n,ve nem n�nM tee. d re: C; no 1 rove cr.rum a au Sea d my aeuuy aur au ronpw;.ia axn ;: �o.�a 7 Sxha Coddnaes U T..1 e6a S Co-recomis p Sorry T..1 Co4ez -A SIB OE &enMn TMryIO Client Reprecenlerve' Ben Td.. tib✓ -" '- °M1tl �ef16 Dde. 51&2017 SIM017 2..27:23PM Page 5 COMPASS 5000.1 Build 74 Cement Detail Report 3R-101 String: CONDUCTOR CEMENT Job: DRILLING ORIGINAL, 3/23/2017 03:30 Cement Details Description CONDUCTOR CEMENT Cementing Start Date 12!16/2016 18:00 Cementing End Date 12/16/2016 18:30 Wellbore Name 3R-101 Comment AFC poured 5-1/2 sacks portland cement down backside to cement conductor. Ambient temperature of -10"F. Cement Stages Stage # 1 Description CONDUCTOR CEMENT Objective Top Depth [19H(B) Cement conductor in 39.0 place Bottom Depth (ftKB) 119.0 Full Retum7 Vol Cement... Top PIug7 Btm Plug? Q Pump ]nit (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip4 Stroke (ft) Rotated? Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment AFC poured 5-1/2 sacks portland cement down backside to cement conductor. Ambient temperature of -1 O°F. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bon (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (Y) Density Ub/gal) Plastic Viscosity (Pa,$) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 5/24/2017 Cement Detail Report 3R-101 String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/23/2017 03:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/26/2017 16:15 3126/2017 1945 3R-101 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? etre Plug? Surface Casing Cement Cement Surface casing 41.6 2,254.0 No 86.0 Yes Yes Q Pump [nit (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 7 7 210.0 476.0 Yes 20.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pump 40.3 bbls of 8.3ppg CW100 at 6.5 bpm, 135 psi, followed by 80 bbls of 10.5ppg Mudpush II spacer at 5.5 bpm, 90 psi. Shut down and drop bottom plug. Pump 316.6 bbis 11.0ppg Litecrete lead cement at 6.5 bpm, ICP 200 psi, FCP 180 psi, 10% F/O, followed by 75.9 bbls 12.Oppg Deeperete tail cement at 6.5 bpm, 200 psi, 8% F/O. Observe hole suddenly get sticky, losing 40k down weight with 50 We of tail pumped so landed pipe for remaining part of job. Shut down and drop top plug. Line up to dg pump and displace cement at 7 bpm, ICP 166 psi, FCP 455 psi, 9% F/O. Slow down to 3 bpm, 290 psi, 5% F/O 10 bbls prior to bumping plug. Bump plug at 3090 strokes and pressure up to 800 psi. Hold for 5 minutes, bleed off and check floats - floats holding. Total of 86 bbls of cement returned to surface. Cement in place @ 19:39 firs. Cement Fluids & Additives Fluid Fluid Type Fluid Description 1 Estimated Top (ftKB) 1 Est Bfm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush CW -100 1 1 1 40.3 Yield m --sack) Mix H2O Ratio (ga9sa... Free Water (%) Density (Iwgal) Plastic Viscosity (Pa•s) Thickening Time (hr) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description 1 Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push II 80.0 Yield (w/sack) Mix H2O Ratio (gausa... Free Water (%) Density (lb/gal)Plastic Viscosity (Pam) Thickening Time (hr) Cmprstr 1 (psi) 10.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB)Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 44.0 1,730.0 932 G 317.0 yield m --sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscos'dy (Pa•s) Thickening Time (hr) cmprstr 1 (psi) 1.91 6.83 11.00 82.0 0.00 Additives Additive Type Concentration Cone Unit label Antifoam D046 0.2 %BWOC Additive Type Concentradon Cone Unit label Retarder D177 0.02 gal/sx Additive TYPO Concentration Cone Unit label Dispersant D185 0.08 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 1,730.0 2,254.0 260 G 1 75.9 Yield (ft /sack) Mix H2O Ratio (gal/ea... Free Water (%) Density (lb/gal)Plastic Vwcosity (Pa•s) Thickening Time (hr) CmprStr 1 (pal) 1.64 5.63 12.00 115.0 0.00 Additives Additive Type Concentration Cone Unit label Antdoam D046 0.2 %BWOC Additive Type Concentration Cone Unit label Retarder D177 0.02 gaVsx Additive Type Concentration Cone Unit label Dispersant D230 0.1 gal/sx Page 7/1 Report Printed: 5/24/2017 Cement Detail Report 3R-101 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3/23/2017 03:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 4/4/2017 18:00 414/2017 23:00 3R-101 Comment "MU hanger and landing joint / pull spiders and RIH to 9,732' MD. Reciprocate casing from 9,732'-9,724' MD conditioning mud. Stage pumps to 7 BPM. 296 GPM = 389 PSI, Up WT = 268K. DWN WT = 54K. Pumped total 22 BBIs. 9.5 PPG in / 10.3 out VIS 250 H2O @ 20. Install cement hose and reciprocate from 9,732'-9,724' MD. Staging pumps up to 8 BPM . 342 GPM = 408 PSI. UP WT = 268K SWN WT = 54K. 9.6 PPG in / 9.8 out Vis 78 H2o @ 10. Challenges working pipe back down after reciprocating this whole time. Setting down to 35k and slowly work through obstruction and land hanger on Ring. Continue to circulate at 8 BPM GPM = 342 PSI=408. 13,844 strokes pumped (1398 bbls). Lost a total of 8 BBLS while RIH with 9 5/8"" casing. Pre job with dg crew and Schlumberger crews for cement program. Included Sim ops with W WT installing SS in pipe shed and loader loading DP. PT all lines to 4,500 PSI ( passed). Pump 60 BBLS 12.5 PPG mud push II @ 5 BPM. 260 PSI, 5% F/O. Drop bottom PLUG (9.34"" OD). Pump 388 BBLS 15.8 PPG Class G cement @ 5.5 BPM. 250 PSI, 7% F/0. Drop top plug (9.16"" OD). Chase with 10 BBLS fresh water @ 4 BPM , 90 PSI, 4% F/0. Changeover to dg pumps to displace cement with 9.5 PPG LSND @ 8 BPM, ICP = 193 6% F/O. Slow to 7 BPM, 192 PSI 9% F/0, @ 1550 Strokes. Observe 175 PSI pressure drop @ 6512 strokes. Slow rate to 5 BPM , 823 PSI @ 6690 Strokes. Slow rate to 4 BPM , 730 PSI @6,785 strokes. Slow rate to 2 BPM 785 PSI @ 7,030 strokes. Bump plug at 7,171 strokes (724 bbls). FCP =839. 3%F/0. Increase psi to 1,400 PSI and hold for 5 min. CIP @2216. Bleed down to 50 PSI and prep for final casing test. Lost a total of 24 BBLS during cement job. Test 9 518"" casing L-80 40# hydril 563 / 521 mix to 3,500 PSIG and charted for 30 min. (PASSED). 10.8 BBLS to pressure up /// 10.7 BBLS bled back. RD Cement hose and blow down. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth(ftKB) Full Return?Vol Cement... Top Plug? Btm Plug? Intermediate Casing 4,943.0 9,743.0 No Yes Cement Q Pump ]nit (bbllm... IQ Pump Final (bbil... IQ Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 7 900.0 1,400.0 Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment MU hanger and landing joint / pull spiders and RIH to 9,732' MD. Reciprocate casing from 9,732'-9,724' MD conditioning mud. Stage pumps to 7 BPM. 296 GPM = 389 PSI, Up WT = 268K. DWN WT = 54K. Pumped total 22 BBis. 9.5 PPG in / 10.3 out VIS 250 H2O @ 20. Install cement hose and reciprocate from 9,732'-9,724' MD. Staging pumps up to 8 BPM . 342 GPM = 408 PSI. UP WT = 268K SWN WT = 54K. 9.6 PPG in / 9.8 out Vis 78 1-12o @ 10. Challenges working pipe back down after reciprocating this whole time. Setting down to 35k and slowly work through obstruction and land hanger on Ring. Continue to circulate at 8 BPM GPM = 342 PSI=408. 13,844 strokes pumped (1398 bbls). Lost a total of 8 BBLS while RIH with 9 5/8" casing. Pre job with rig crew and Schlumberger crews for cement program. Included sim ops with W WT installing SS in pipe shed and loader loading DP. PT all lines to 4,500 PSI ( passed). Pump 60 BBLS 12.5 PPG mud push II @ 5 BPM. 260 PSI, 5% F10. Drop bottom PLUG (9.34" OD). Pump 388 BBLS 15.8 PPG Class G cement @ 5.5 BPM. 250 PSI, 7% F/0. Drop top plug (9.16" OD). Chase with 10 BBLS fresh water @ 4 BPM , 90 PSI, 4% F/O. Change over to rig pumps to displace cement with 9.5 PPG LSND @ 8 BPM, ICP = 193 6% F/O. Slow to 7 BPM, 192 PSI 9% F/O, @ 1550 Strokes. Observe 175 PSI pressure drop @ 6512 strokes. Slow rate to 5 BPM , 823 PSI @ 6690 Strokes. Slow rate to 4 BPM , 730 PSI @ 6,785 strokes. Slow rate to 2 BPM 785 PSI @ 7,030 strokes. Bump plug at 7,171 strokes (724 bbls). FCP =839. 3% F/0. Increase psi to 1,400 PSI and hold for 5 min. CIP @2216. Bleed down to 50 PSI and prep for final casing test. Lost a total of 24 BBLS during cement job. Test 9 5/8" casing L-80 40# hydril 563 / 521 mix to 3,500 PSIG and charted for 30 min. (PASSED). 10.8 BBLS to pressure up /// 10.7 BBLS bled back. RD Cement hose and blow down. Cement Faulds & Addlt(ves Fluid Fluid Type Fluid Description Estimated Top (ftK8) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MutlPush II 4,137.0 4,943.0 1 60.0 yield m7lsack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est tttrn (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 4,943.0 9,743.0 1,878 G 388.0 Yield pV sack) Mix H2O Ratio (gal/sa... Free water (%) Density (Iblgai)Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr t (psi) 1.16 5.11 15.80 6.95 Additives Additive Type ConcentrationConc Unit label D046 Antifoam 0.2 %BWOC Additive Type ConcentrationCo nc Unit label D065 Disspersant 0.3 %BWOC Additive Type Concentration Gone Unit label D255 Fluid Loss 0.4 %BWOC Page 1/2 Report Printed: 5125/2017 Cement Detail Report 3R-101 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3/23/201703:30 Additives Additive Type Concentration Conc Unit label D177 Retarder 0.03 gal/sx Page 212 ReportPrinted: 5/25/2017 RECUVED MAY 10 2017 Schlumberger Y GCC Drilling & Measurements MWD/LWD Log Product Delivery Customer: Conoco Phillips Alaska Dispatched To: Well No: 313-10111 Date Dispatched: Job#: 16AKA0110 Dispatched By: 21 7014 28 18 5 Transmittal #: 10MAY17-SP02 DATA LOGGED %3 /1VJ 12017 M K. BENDER AOGCC: Makana Bender 10 -May -17 hanie 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 i Contents on CD N/A Data: HIS /ASCII x Graphics: pdf/tiff x Surveys: pdf / txt x Please sign and email a copy to: Please sign and email a copy to: Tom. Osterkam p(o)conocophillips.com AlaskaPTSPrintCenter(o)slb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-101 L1 May No b3a PGG,GG Definitive Survey Report 05 May, 2017 21 7014 28 18 5 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R -101L1 Survey Calculation Method: Minimum Curvature Design: 3R -101L1 Database: OAKEDMP2 'reject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Veil 3R-101 Audit Notes: From To Veil Position -NIS 0.00 usft Northing: 6,031,732.16 usft Latitude: 70° 29'52.272 Depth From (TVD) +E/ -W 0.00 usft Easting: 520,625.96 usft Longitude: 149° 49'52.775 V 'osition Uncertainty MWD+IFR-AK-CAZ-SC 0.00 usft Wellhead Elevation: 0.00 ush Ground Level: 9.90 usf Wellbore 3R-101 1_1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) 11 InT) BGGM2016 4/13/2017 17.71 81.04 57,551 Design 3R-1011_1 Date Audit Notes: From To Version: 1.0 Phase: ACTUAL Tie On Depth: 9,619.39 Vertical Section: Depth From (TVD) +N/ -S +EAW Direction Gyrodata gyro single shots (usft) (usft) (usft) (I MWD+IFR-AK-CAZ-SC 39.10 0.00 0.00 303.60 Survey Program Date From To (usft) lush) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 3R-101 Srvy 1 - SLB GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/24/2017 828: 676.74 2,153.783R-101 Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/24/2017 8:31: 2,208.44 2,208.44 3R-101 Srvy 3 - $LB_GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/25/2017 833: 2,297.00 8,026.553R-101 Srvy 4- SLB _MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/29/2017 B:47: 8,102.69 9,327.483R-101 Srvy 5- SLB _MWD+GMAG (3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/1/2017 2:480 9,392.00 9,409.593R-101L1P61 Srvyl- Inc + Trend (3R-10 INC+TREND Inclinometer + known azi trend 4/14/2017 8:59: 9,438.00 9,619.393R-101L1PB1 Srvy2-SLB GWD70(3R- GYD-GC-SS Gyrodata gyro single shots 4/14/2017 9:10: 9,659.83 9,698.07 3R-1011.1 Srvyl- SLB _GWD70 (3R-101 GYD-GC-SS Gyrodata gyro single shots 4/17/2017 933: 9,770.96 15,832.583R-101 Li Srvy2-SLB_MWD+GMAG(3R MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 4/17/2017 9:50: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ush) 19 0 (usft) (usft) (usft) (usft) (R) (ft) (-/WO') (it) Survey Tool Name 39.10 0.00 000 39.10 -9.90 0.00 0.00 6.031,732.16 520,625.98 O.OD 0.00 UNDEFINED 13569 0.74 5162 135.69 86.69 0.39 0.49 6,031,732.55 520,626.47 0.77 -0.19 GYD-GC-SS(1) 169.59 0.74 47.48 169.58 120.58 0.67 0.82 6,031,73283 520,626.80 0.16 -0.31 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 213.71 203 1.24 6,031,734.19 520,627.21 0.95 0.09 GYD-GC-SS(1) 356.57 2.27 336.68 356.51 307.51 4.69 0.47 6,031,736.85 520,626.44 1.34 2,21 GYD-GC-SS(1) 451.76 3.36 327.54 451.58 402.58 879 -178 6,03174095 520,624.17 1.25 6.35 GYD-GC-SS(1) 545.32 3.75 318.73 544.96 495.96 1362 -528 6,031,745.56 520,620.66 0.71 1162 GYD-GC-SS(1) 5/52017 2.21:OBPM Page 2 COMPASS 5000.1 BuiM 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kupamk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-10117 Survey Calculation Method: Minimum Curvature Design: 3R-101111 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (o) (1 (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 63881 5.49 307.39 638.15 589.15 18.43 -10.85 6,031,750.56 520,615.08 2.09 1924. GVD-GC-SS(1) 676.74 8.24 302.09 675.88 626.88 20.63 -14.04 6,031,75275 520,611.88 2.44 23.11 MWD+IFR-AK-CAZ-SC(2) 770.88 7.30 300,95 769.36 720.36 26.42 -23.50 6.031,758.52 520,602.40 1.13 34.20 MWD+1FR-AK-CAZ-SC(2) 86373 9.86 309.12 861.17 812.17 34.47 -34.73 6,031766.53 520,591.15 3.05 48.01 MWD+IFR-AK-CAZ-SC(2) 959.68 9.96 317.32 95569 906.69 45.76 4673 6,031,777.78 520,579.13 1.47 64.25 MWD+1FR-AK-CAZ-SC(2) 1,053.73 12.30 328.76 1,047.98 998.98 60.31 -57.44 6,031,792.30 520,568.37 3.41 81.22 MWD+IFR-AK-CAZ-SC(2) 1,149.13 13.66 34718 1,14098 1,091.98 79.99 -65.22 6,031,811.96 520,56055 4.54 98.59 MWD+IFR-AK-CAZ-SC(2) 1,243.57 14.34 355.31 1,23262 1.183.62 102.52 -68.65 6,031,834.48 520.557.05 2.20 113.91 MWD+IFR-AK-CAZ-SC(2) 1,338.60 1497 357.92 1,324.56 1,275.56 126.52 -70.06 6,031,858.47 520,555.58 0.96 128.36 MWD+IFR-AK-CAZ-SC(2) 1,433.41 15.24 359.78 1,416.09 1,367.09 15121 -70.55 6,031,883.16 520,555.02 0.59 142.44 MWD+1FR-AK-CAZ-SC(2) 1,527.63 14.50 0.11 1,507.16 1,458.16 175.39 -70.57 6,031,907.34 520,554.93 079 155.84 MWD+IFR-AK-CAZ-SC(2) 1,620.81 17.27 0.21 1,596.77 1,547.77 200.89 -70.50 6,031,932.84 520,554.93 2.97 169.89 MWD+IFR-AK-CAZ-SC(2) 1,716.88 16.84 1.37 1,688.62 1,63962 229.07 -70.12 6,031,961.01 520,555.24 0.57 185.16 MWD+IFR-AK-CAZ-SC(2) 1,811.40 1906. 358.74 1,778.53 1729.53 258.19 -70.13 6,031,990.13 520,555.14 2.50 201.28 MWD+IFR-AK-CAZ-SC(2) 1,906.14 2091. 356.99 1,867.56 1,818.56 290.54 -71.36 6.032,02247 520,553.83 2.05 22021 MWD+IFR-AK-CAZ-SC(2) 2,000.30 24.98 355.65 1,954.26 1.90526 327.15 -73.75 6,032,059.08 520,551.33 4.36 242.46 MWD+IFR-AK-CAZ-SC(2) 2,094.43 28.81 355.00 2,038.19 1,989.19 369.59 -77.23 6,032,101.50 520,547.73 4.08 268.84 MWD+1FR-AK-CAZ-SC (2) 2,153.78 30.11 355.47 2,089.86 2,040.86 398.68 -7966 6,032,130.57 520,54523 2.22 286.96 MWD+IFR-AK-CAZ-SC(2) 2,20844 33.91 35204 2,13621 2,087.21 427.58 -81.53 6,032,159.47 520,543.28 7.12 304.51 GVD-GC-SS (3) 2,243.00 34.53 357.36 2,164.78 2,11578 446.99 -8248 6,032,178.88 520,542.27 1.88 316.04 NOT an Aclual5urvey 13 3/8" 2.29T00 35.51 357.84 2,209.00 2,160.00 477.96 -83.77 6,032,209.84 520,540.89 1.88 334.26 MWD+IFR-AK-CAZ-SC(4) 2,353.55 37.24 $58.70 2,254.53. 2,205.53 51148 -8478 6,032,243.35 520,53979 3.19 353.64 MWD+IFR-AK-CAZ-SC(4) 2,448.06 41.35 358.32 2,327.65 2,278.65 571.31 -86.34 6,032,303.17 520,538.06 4.37 388.05 MWD+IFR-AK-CAZ-SC(4) 2,543.56 45.79 0.39 2,39683 2,347.83 637.11 -8704 6.032,368.96 520,53].19 4.87 425.04 MWD+1FR-AK-CAZ-SC(4) 2,637.75 49.08 0.59 2,460.53 2,411.53 706.47 -86.44 6,032,438.31 520,537.59 3.50 462.93 MWD+1FR-AK-CAZ-SC(4) 2,732.27 54.02 1.62 2,519.29 2,470.29 780.45 -84.99 6,032,512.29 520,538.83 5.30 50266 MWD+IFR-AK-CAZ-SC(4) 2,826.93 5892 0.47 2,571.56 2,522.56 859.32 -83.57 6,032,591.16 520,540.03 5.27 545.12 MWD+IFR-AK-CAZ-SC(4) 2,919.52 63.48 0.11 2,616.16 2,567.16 940.43 -83.17 6.032,672.27 520,54021 4.94 589.67 MWD+1FR-AK-CAZ-SC(4) 3,015.11 67.32 358.34 2,655.94 2,606.94 1,027.32 -84.36 6,032,759.14 520,538.77 436 638.74 MWD+IFR-AK-CAZ-SC(4) 3,110.07 71.37 357.59 2,689.43 2,640.43 1,116.10 -87.53 6,032,847.90 520,535.37 4.33 690.50 MWD+IFR-AK-CAZ-SC(4) 3,204.89 75.87 355.15 2,716.17 2,667.17 1,206.86 -93.31 6,032,93863 520,529.33 5.35 745.54 MWD+1FR-AK-CAZ-SC(4) 3,300.84 80.10 354.91 2.736.14 2,687.14 1,300.33 -101.44 6,033,032.07 520,520.95 4.42 804.04 MWD+IFR-AK-CAZ-SC(4) 3,395.53 80.99 355.26 2,751.69 2,702.69 1,39339 -10944 6,033,125.10 520,51269 1.01 862.20 MWD+IFR-AK-CAZ.SC(4) 3,490.19 81.39 356.24 2,766.19 2,717.19 1,486.67 -116.37 6,033,218.36 520,505.50 1.11 919.59 MWD+IFR-AK-CAZ-SC(4) 3,582.99 81.43 356.62 2,780.05 2,731.05 1,578.25 -122.08 6,033,309.91 520,499.53 0.41 97503 MM+IFR-AK-CAZ.SC(4) 3,679.39 81.52 355.69 2,794.34 2,745.34 1,673.38 -128.31 6,033,405.02 520,493.04 075 1,032.85 MWD+IFR-AK-CAZ-SC (4) 3,774.67 81.52 354.32 2,808.39 2,759.39 1,767.28 -136.35 6,033,498.88 520,48414 1.63 1,091.51 MWD+IFR-AK-CAZ-SC(4) 3,869.26 81.14 354.65 2,822.65 2,77365 1,860.35 -145.34 6,033,591.92 520,475.49 0.53 1,150.50 MWD+IFR-AK-CAZ-$C(4) 3,963.62 81.59 354.57 2,836.82 2,787.82 1,953.23 -154.10 6,033,684.76 520,466.47 0.48 1,209.19 MWD+IFR-AK-CAZ-SC(4) 5/52017 2:21:08PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pao MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Welt: 3R-101 North Reference: True Wellbore: 3R-101 L1 Survey Calculation Method: Minimum Curvature Design: 3R-1011-1 Database: OAKEDMP2 Survey Map Map vertical MD Inc Azi TVD TVDSS +N1 -S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,058.18 81.39 354.86 2,850.81 2,801. B1 2.046.35 -162.72 6,033,777,85 520,457.60 0.37 1,267.89 MWD+1FR-AK-CAZ-SC (4) 4,153.32 81.31 35547 2,865.12 2,816.12 2,140.07 -170.64 6,033,871.54 520,449.41 064 1,32636 MWD+IFR-AK-CAZ-SC(4) 4,247.21 81.19 356.30 2,879.41 2,830.41 2,232.63 -177.30 6,033,964.07 520,442.50 0.88 1,383.12 MWD+IFR-AK-CAZ-$C(4) 4,341.81 81.29 357.42 2,89381 2,844.81 2,325.99 -182.42 6,034,05740 520,437.12 1.17 1,439.05 MWD+1FR-AK-CAZ-SC(4) 4,436.87 81.31 358.76 2,908.19 2,859.19 2,419.90 -185.56 6,034,151.29 520,433.73 1.39 1,493.62 MWD+IFR-AK-CAZ-SC(4) 4,532.86 81.46 359.12 2,922.57 2,873.57 2,514.79 -187.31 6,034,246.17 520,431.71 0.40 1,547.59 MWD+1FR-AK-CAZ-SC(4) 4,627.23 81.49 358.61 2,936.56 2,887.56 2,608.10 -189.16 6,034,339.46 520,42960 0.54 1,600.77 MWD+IFR-AK-CAZ-SC(4) 4,722.52 81.62 358.05 2,950.56 2,901.56 2,702.31 -19191 6,034433 .66 520,426.59 060 1,655.19 MWD+IFR-AK-CAZ-SC(4) 4,816.15 81.17 357.64 2,964.57 2,915.57 2,794.82 -195.39 6,034526.15 520,422.86 0.65 170928 MWD+IFR-AK-CAZ-SC(4) 4,910.05 81.65 357.59 2,978.59 2.929.59 2,887.59 -199.25 6.034618 .90 520,418.74 0.51 1,763.83 MWD+IFR-AK-CAZ-SC (4) 5,005.50 81.45 357.34 2,99262 2,943.62 2,981.91 -203.43 6,034713.20 520,414.30 0.33 1,819.50 MWD+1FR-AK-CAZ-SC(4) 5,099.31 80.43 356.19 3,007.39 2,958.39 3,07440 -208.65 6,034,80566 520,408.82 1.63 1,875.03 MWD+IFR-AK-CAZ-SC(4) 5,194.23 7934 356.96 3,02373 2,974.73 3,167.73 -214.24 6,0M,898 97 520,402.97 1.08 1,931.33 MWD+1FR-AK-CAZ-SC(4) 5,288.73 80.17 35741 3,040.22 2,991.22 3,260.67 -218.81 6,034,991.89 520,398.14 065 1,986.57 MWD+IFR-AK-CAZ-SC(4) 5,384.03 80.16 355.86 3,056.49 3,007.49 3,354.41 -224.32 6,035,08560 520,392.37 1.60 2,043.03 MWD+IFR-AK-CAZ-SC(4) 5,478.50 80.16 355.01 3,072.60 3,023.64 3,447.19 -231.73 6,035,17835 520,384.71 0.89 2,100.54 MND+IFR-AK-CAZ-SC(4) 5,574.37 79.88 352.33 3,089.26 3,040.26 3,541.03 -242.14 6,035,272.15 520,374.04 2.77 2,161.13 MWD+IFR-AK-CAZ-SC (4) 5,668.19 80.05 352.29 3,10561 3,056.61 3,632.58 -254.50 6.035,353.66 520,361.43 0.19 2,222.09 MWD+IFR-AK-CAZ-SC(4) 5,762.98 79.70 350.63 3,122.27 3,073.27 3,724.85 -268.36 6,035,45589 520,347.32 1.76 2,284.70 MWD+IFR-AK-CAZ-SC(4) 5.858.90 79.93 35094 3,139.23 3,09023 3,818.04 -283.48 6,035,549.02 520,331.94 0.40 2,348.86 MWD+IFR-AK-CAZ-SC(4) 5,953.58 79.83 352.59 3,155.87 3,106.87 3,910.29 -29683 6,035,64122 520,318.34 1.72 2,411.02 MWD+IFR-AK-CAZ-SC(4) 6,048.38 79.78 353.57 3,17265 3,123.65 4,002.91 308.07 6,035,733.80 520,306.84 1.02 2,47163 MWD+IFR-AK-CAZ-SC(4) 6,142.31 80.65 35182 3,188.61 3,13961 4,09472 -319,84 6,035,825.57 520,294.81 2.06 2,532.24 MWD+IFR-AK-CAZ-SC(4) 6,237.62 80.49 349.06 3,204.23 3,155.23 4,187.42 -335.45 6.035,918.22 520,278.95 2.86 2,5%.55 MWD+IFR-AK-CAZ-SC (4) 6,33289 80.84 348.35 3,219.69 3,170.69 4,279.61 -353.86 6,036,010.35 520,260.28 0.82 2,662.89 MWD+IFR-AK-CAZ-SC(4) 6,427.09 80.50 345.89 3,234.96 3,185.96 4,370.22 -374.58 6,036,100.89 520,239.31 2.60 2,730.29 MWD+IFR-AK-CAZ-SC(4) 6.521.45 80.15 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,035,190.80 520,215.51 123 2,799.70 MWD+IFR-AK-CAZ-SC (4) 6,61587 79.69 343.22 3,267.31 3,218.31 4,549.37 42371 6,03,279.88 520,189.69 1.69 2,870.35 MWD+IFR-AK-CAZ-SC(4) 6,710.05 8009 339.00 3.283.88 3,234.88 4,637.26 45379 6,036,367.68 520,159.37 4.42 2,944.03 MWD+iFR-AK-CAZ-SC(4) 6,802.95 79.71 338.08 3,300.18 3,251.16 4,72238 -487.25 6.0%,452.70 520,125.68 1.06 3,019.00 MWD+IFR-AK-CAZ-SC(4) 8,898.97 79.47 335.69 3,317.53 3,268.53 4,809.23 -524.32 6,036,539.44 520,088.37 2.46 3,097.94 MWD+IFR-AK-CAZ-SC (4) 6,993.80 78.57 33402 3,335.59 3,286.59 4,893.50 -563.87 6,036,623.59 520,048.59 1.97 3,177.52 MWD+IFR-AK-CAZ-SC(4) 7,088.66 77.01 334.51 3,355.65 3,306.65 4,977.01 -604.13 6,036,706.98 520,008.10 1.72 3,257.26 M011)+1FR-AK-CAZ-SC(4) 7,183.15 78.05 332.54 3,376.% 3,327.06 5,059.59 -645.26 6,035,789.44 519,96675 2.31 3,337.22 MWD+IFR-AK-CAZ-SC(4) 7,277.04 78.65 332.66 3,395.02 3,346.02 5,141.23 687.58 6,036,870.95 519,924.21 0.65 3,41764 MWD+IFR-AK-CAZ-SC(4) 7,370.87 79.07 330.57 3,413.15 3,364.15 5.222.22 -731.34 6,036,951.81 519,880.22 2.23 3,498.91 MWD+IFR-AK-CAZ-SC(4) 7,466.77 81.05 330.18 3,429.70 3,380.70 5,304.33 -778.03 6,037,033.78 519,833.31 2.10 3,583.24 MWD+IFR-AK-CAZ-SC (4) 7,561.29 82.67 327.76 3,443.09 3,394.09 5,384.49 -826.27 6,037,113.80 519,784.86 3.% 3,667.77 MWD+IFR-AK-CAZ-SC(4) 7,65442 83.63 323.12 3,454.20 3,405.20 5,460.62 -B78.71 6,037,18977 519,732.21 5.05 3,753.58 MWD+IFR-AK-CAZ-SC(4) 7,749.17 83.29 318.54 3,465.00 3,416.00 5,533.58 -938.15 6,037,262.56 519,672.58 4.82 3,843.46 MWD+IFR-AK-CAZ-SC(4) 5/5/2017 2.2108PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 L7 Survey Calculation Method: Minimum Curvature Design: 3R -101L1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (waft) (ft) (ft) (9100') (ft) Survey Tool Name 7,84393 83.31 316.31 3,476.05 3,42705 5,60288 -1,00181 6,037,331.68 519,60832 2.34 3,934.84 MWD+IFR-AK-CAZ-SC(4) 7,937.29 83.12 313.16 3,487.09 3.438.09 5,658.12 -1,067.66 6,037,396.73 519,542.70 3.36 4,025.79 MWD+IFR-AK-CAZ-SC (4) 7,98065 82.66 310.87 3,492.45 3,44345 5,696.91 -1,099.63 6,037,42543 519,51066 5.35 4,068.35 MWD+IFR-AK-CAZ-SC(4) 8,026.55 82.82 310.75 3,49826 3,44926 5,726.67 -1,134.09 6,037,455.09 519.476.12 0.43 4,113.52 MWD+IFR-AK-CAZ-SG(4) 8,102.69 84.02 308.30 3,506.98 3,457.98 5,774.80 -1,192.43 6,037,50306 519,417.65 3.56 4,188.74 MWD+IFR-AK-CAZ-SC(5) 8,19627 83.30 307.17 3,51].32 3,468.32 5,831.72 -1,265.98 6,037,559.77 519,343.95 1.43 4,281.51 MWD+IFR-AK-CAZ-SC(5) 8,290.64 80.09 306.79 3,530.94 3,48194 5,88789 -1,340.57 6,037,615.72 519,26922 3.42 4,374.71 MWD+IFR-AK-CAZ-SC(5) 8,385.81 78.59 302.73 3,548.56 3,499.56 5,941.21 -1.417.38 6,037,668.82 519,192.26 4.48 4,468.20 MWD+IFR-AK-CAZ-SC (5) 8,48048 8205. 294.76 3,564.50 3,515.50 5,988.01 -1,499.13 6,037,713.39 519,110.39 9.07 4,561.09 MWD+IFR-AK-CAZ-SC(5) 8,575.24 86.75 290.20 3,57375 3.52435 6,022.04 -1,586.23 6,037,749.17 519,023.20 6.89 4,653.57 MWD+IFR-AK-CAZ-SC(5) 8669.02 8622 286.91 3,579.50 3,530.50 6,051.82 -1,674.98 6,037.77871 518,934.40 3.55 4,743.96 MWD+IFR-AK-CAZ-SC(5) 8,76377 89.34 28126 3,583.17 3,534.17 6,0]4.84 -1,766.74 6,037,801.47 518,842.56 6.81 4,833.15 MWD+1FR-AK-CAZ-SC(5) 8,859.11 89.82 275.16 3,583.87 3,534.7 6,088.45 -1,851.06 6,037,814.82 518,74822 6.42 4,919.24 MWD+IFR-AK-CAZ-SC(5) 8,954.08 89.52 271.80 3,584.42 3,53542 6,094.21 -1,955.84 6,037.820.32 518,653.43 3.55 5,001.37 MWD+IFR-AK-CAZ-SC(5) 9,047.67 86.64 271.51 3,587.55 3,538.55 6,096.92 -2,049.33 6,037,822.76 518,559.95 3.09 5,080.74 MWD+IFR-AK-CAZ-SC(5) 9,141.11 87.22 269.20 3,592.56 3,543.56 6,097.49 -2,142.63 6,037,823.08 518.46566 2.55 5,15817 MWD+IFR-AK-CAZ-SC(5) 9,234.58 88.14 268.86 3,596.34 3,54].34 6,095.91 -2,235.00 6,037,821.24 518,373.29 1.05 5,235.68 MWD+IFR-AK-CAZ-SC (5) 9,327.48 8828 269.08 3,599.24 3,550.24 6,09424 -2.328.84 6,037,819.31 518,280.47 0.28 5,312.08 MWD+IFR-AK-CAZ-SC (5) 9,391.00 86.18 269.65 3,602.31 3,553.31 6,093.54 -2,392.28 6,037,818.43 518,217.04 3.42 5,36453 NOT an Actwl Survey 9 6/8" x 12.1/4 9,392.00 86.15 26966 3.602.38 3,553.38 6,093.53 -2,393.28 6,037,818.42 518,216.04 3.42 5.365.36 INC+TREND (6) 9409.59 88.29 268.88 3,603.23 3,554.23 6,093.31 -2,410.85 6,037,818.15 518,198.47 12.95 5,379.87 INC+TREND(6) 9,438.00 8772 270.95 3,604.22 3,555.22 6,093.27 -2,43924 6,037,81803 518,170.09 7.55 5,403.49 GYD-GC-SS(7) 9,525.02 85.26 262.99 3,609.56 3,560.56 6,08869 -2,525.90 6,037,813.21 518,083.45 9.56 5,473.14 GYD-GC-SS(7) 9,619.39 88.72 260.24 3,614.51 3,565.51 6,07495 -2,619.11 6,037,799.21 517,990.29 4.68 5,543.18 GYD-GC-SS(7) 9,65983 87.48 261.82 3,61585 3,565.85 6,068.65 -2,659.03 6,037,792.80 517,950.39 4.96 5,572.94 GYD-GC-SS(8) 9,698.07 86.39 260.08 3,617.90 3,568.90 6,062.64 -2,696]3 6,037,786.69 517,912.70 5.36 5.601.03 GYD-GC-SS (8) 9,77096 90]5 26043 3,619.71 3,570.71 6.050.31 -2,768.53 6,037,774.16 517,840.94 600 5,654.01 MWD+IFR-AK-CAZ-SC (9) 9,86539 93.68 260.64 3616.07 3,567,07 6,034.79 -2,861.60 6,037,758.39 517,747.93 3.11 5,722.94 MWD+IFR-AK-CAZ-SC(9) 9,960.11 90.49 261.23 3,612.62 3,563.62 6,019.88 -2,955.06 6,037,743.22 517,654.52 3.42 5,792.54 MWD+IFR-AK-CAZ-SC(9) 10,054.31 91.77 259.84 3,61076 3,561]6 6,004.40 -3,047.96 6,037,727.48 517,561.66 2.01 5,861.35 MWD+IFR-AK-CAZ-SC (9) 10,149.10 9204. 259.98 3,607.61 3,558.61 5,987.80 -3,141.23 6,037,71062 517,46846 0.32 5,92985 MWD+IFR-AK-CAZ-SC(9) 10,243.91 92.37 261.70 3,603.96 3,554.96 5,972.72 -3,234]6 6,037,695.28 517,374.99 1.85 5,999.41 MWD+IFR-AK-CAZ-SC(9) 10,338.55 90.76 263.17 3,601.38 3,552.38 5,960.26 -3,328.53 6,037,682.57 517,281.25 2.30 6,070.63 MWD+IFR-AK-CAZ-SC(9) 10,433.44 89.14 263.82 3,601.46 3,552.46 5,949.51 -3,422.81 6,037,671.56 517,167.02 1.84 6,14321 MWD+IFR-AK-CAZ-SC (9) 10,528.09 88.04 266.16 3,603.79 3,554.79 5,941.25 -3,51].06 6,037,663.04 517,092.80 2.73 6.217.14 MWD+IFR-AK-CAZ-SC(9) 10,621.7 88.31 270.42 3,6W78 3,557.78 5,938.45 -3,610.83 6,037,659.98 516,999.05 4.54 6,293.70 MWD+IFR-AK-CAZ-SC(9) 10,716.41 90.77 270.79 3,607.54 3,558.54 5,939.45 -3,705.25 6,037,650.71 516,90463 2.63 6,372.90 MWD+IFR-AK-CAZ-SC(9) 10.811.03 90.74 270.18 3,606.29 3,557.29 5,940.25 -3,799.86 6,037,661.25 516,810.03 0.65 6,452.14 MW13+1FR-AK-CAZ-SC(9) 10,905.00 90.00 268.76 3,605.69 3,556.69 5,939.38 -3,893.82 6,037,660.12 516,716.08 1.70 6,529.93 MWD+IFR-AK-CAZ-SC(9) &WO17 2:21 08P Page 5 COMPASS 5000.1 Buil/ 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 31R-101 Project: Kupamk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 31R-1011.1 Survey Calculation Method: Minimum Curvature Design: 3R -101L1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (f!) Survey Tool Name 11,00045 89.81 266.85 3,605.84 3,556.84 5,93572 -3,989.20 6,037,656.20 516,620.73 2.01 6607.35 MWD+IFR-AK-CAZ-SC(9) 11.094.67 8965 267.15 3,606.29 3,557.29 5,930.79 -4,083.29 6,037,651.01 516,526.66 0.36 6,682.99 MWD+IFR-AK-CAZ-SC(9) 11,189.53 90.48 26664 3,606.18 3,557.18 5,925.66 4,178.01 6,037,645.61 516,431.96 1.03 6,759.04 MWD+IFR-AK-CAZ-SC(9) 11,284.13 91.99 266.72 3,604.14 3,555.14 5,920.18 -4,272.42 6,037,639.87 516.337.57 1.60 6,834.66 MWD+IFR-AK-CAZ-SC (9) 11,37889 91.58 267.17 3,601.19 3,552.19 5,915.13 -4,367.00 6,037,634.56 516,24302 0.64 6,910.64 MWD+IFR-AK-CAZ-SC(9) 11471.23 94.01 267.55 3.5%.69 3,547.69 5,910.88 4,459.13 6,037,63006 516,150.91 2.66 6,98503 MWD+IFR-AK-CAZ-SC(9) 11,568.32 92.48 267.57 3,591.19 3,542.19 5,906.76 4,55597 6,037,625.66 516,054.09 1.58 7,06341 MWD+IFR-AK-CAZ-SC(9) 11863.04 93.38 267.37 3,586.35 3,537.35 5,902.58 -4,650.47 6,037,621.23 515,95961 0.97 7,13981 MWD+IFR-AK-CAZ-SC(9) 11,758.11 94.20 268.78 3,580.07 3,531.07 5,899.39 -4,745.28 6,037,617.78 515,864.82 131 7,217.02 MWD+IFR-AK-CAZ-SC(9) 11,852.56 93.15 269.12 3,574.01 3,525.01 5,89767 -4,839.52 6,037,615.79 515,770.60 1.17 7,294.56 MWD+IFR-AK-CAZ-SC(9) 11,946.96 90.90 269.07 3,57088 3,521.68 5,896.18 4,933.84 6,037,614.04 515,676.29 2.38 7,372.30 MWD+IFR-AK-CAZ-SC(9) 12,041.61 89.84 271.14 3,570.07 3,521.07 5,896.35 -5,028.48 6,037,613.95 515,58166 2.46 7,451.23 MWD+IFR-AK-CAZ-SC (9) 12,137.27 91.29 272.42 3,569.12 3,520.12 5,899.32 -5,124.09 6,037,61665 515,486.05 2.02 7,532.50 MWD+IFR-AK-CAZ-SC(9) 12,230.94 91.41 272.83 3,566.92 3,517.92 5,903.61 -5,217.63 6,037,620.68 515,392.51 046 7,612.80 MWD+IFR-AK-CAZ-SC(9) 12,325.71 90.18 271.97 3,565.60 3,516.60 5,907.58 -5,312.31 6.037.624.39 515.297,83 1.58 7,693.85 MWD+IFR-AK-CAZ-SC(9) 12,420.62 89.19 272.10 3,566.12 3,517.12 5,910.95 -5,407.15 6,037,627.49 515,202.98 1.05 7,774.72 MWDHFR-AK-CAZ-SC(9) 12,514.94 89.27 270.81 3,567.39 3,518.39 5,913.34 -5.501.43 6,037,62963 515,108.71 1.37 7,856.57 MWD+IFR-AK-CAZ-SC(9) 12,60947 89.18 27048 3,568.67 3,519.87 5,91441 -5,595.95 6,037,63043 515,014.20 0.36 7,933.89 MWD+IFR-AK-CAZ-SC(9) 12,704.11 89.31 269.89 3,569.92 3,520.92 5,914.71 -5,690.58 6,037,630.47 514,919.58 0.64 8,012,88 MWD+IFR-AK-CAZ-SC (9) 12,799.17 89.98 269.19 3,570.50 3,521.50 5,913.95 -5,785,63 6,037,629.44 514,824.54 1.02 8,091.63 MWD+IFR-AK-CAZ-SC(9) 12,893.33 89.51 26877 3,570.92 3,521.92 5,912.27 -5,879.78 6,037,627.51 514,730.41 0.67 8,169.12 MWD+IFR-AK-CAZ-SC(9) 12,987.54 89.96 268.94 3,571.36 3,522.36 5,910.39 -5,973.97 6,037,625.38 514,636.23 0.51 8,246.53 MWD+IFR-AK-CAZ-SC(9) 13,081.98 90.02 289.39 3,571.38 3,522.38 5,909.01 6,06840 6,037,62372 514,541.81 0.48 8,32443 MWD+IFR-AK-CAZ-SC(9) 13,17896 88.12 269.29 3,572.92 3,523.92 5,907.92 -6,163.35 6,037,622.37 514.446.87 2.00 8.402.91 MWD+IFR-AK-CAZ-SC(9) 13,272.05 89.19 269.04 3,575.15 3,526.15 5,9%.53 -6,258.41 6,037.620.72 514,351.83 1.16 8,48132 MWD+IFR-AK-CAZ-SC(9) 13,366.17 8985 26996 3,575.94 3,526.94 5,905.71 -6,352.52 6,037,61964 514,257,73 1.20 8,559.26 MWD+IFR-AK-CAZ-SC(9) 13,460.80 89.88 270.65 3,576.16 3,527,16 5,9%.22 6,447.14 6,037,619.88 514,163.11 073 8,638.36 MWD+IFR-AK-CAZ-SC(9) 13,555.64 90.63 270.26 3,575.57 3,526.57 5,906.97 -6,541.98 6,037,620.37 514,068.29 1.08 8,717.76 MWD+IFR-AK-CAZ-SC (9) 13,650.19 90.77 271.06 3,574.25 3,525.25 5,908.06 -6,636.51 6,037,621.19 513,973.76 0.85 8,797.11 MWD+1FR-AK-13AZ-SC(9) 13,744.83 8999 271.11 3,573.63 3,52463 5,909.85 6,731.13 6,037,62272 513,879.14 0.83 8,876.91 MWD+IFR-AK-CAZ-SC(9) 13,84007 91.35 273.34 3,57251 3,523.51 5,913.55 -6,82629 6.037,626.15 513,783.99 2.74 8,958.22 MWD+IFR-AK-CAZ-SC(9) 13,93479 91.43 27202 3,570.21 3,52121 5,917.98 6,920.87 6,037,630.32 513,689.40 1.40 9,039.45 MWD+IFR-AK-CAZ.SC(9) 14.029.33 90.71 271.32 3,56845 3,519.45 5,920.73 -7,015.35 6,037,632.81 513,594.92 1.06 9,119.67 MWD+IFR-AK-CAZ-SC(9) 14,12374 90.80 269.47 3,567.20 3,518.20 5,921.38 -7,109.75 6,037,633.20 513,500.53 1.98 9,196.66 MWD+IFR-AK-CAZ-SC(9) 14,218.35 90:13 269.02 3,566.44 3,51744 5,920.13 -7,204.35 8,037,631.69 513,40595 0.85 9,276.77 MWD+IFR-AK-CAZ-SC(9) 14,312.36 9044 268.85 3,565.97 3,516.97 5,918.39 -7,298.34 6,037,629.68 513,311.97 0.38 9,354.09 MWD+IFR-AK-CAZ-SC(9) 14,406.91 90.62 268.39 3,565.09 3,518.09 5,916.11 -7,392.% 6037,627.14 513,217.47 0.52 9,431.56 MWD+IFR-AK-CAZ-SC(9) 14,500.% 9056 268.14 3,564.13 3,515.13 5,913.26 -7,486.86 6,037,624.04 513,12349 0.27 9,508.26 MWD+IFR-AK-CAZ-SC(9) 14,594.71 90.41 267.13 3,563.33 3,514.33 5,909.39 -7,580.53 6,037,619.91 513.029.84 1.09 9,584.16 MWD+IFR-AK-CAZ-SC(9) 14,687.46 WAS 268.25 3,562.61 3,513.61 5,905.86 -7,67320 6,037,615.91 512,937.19 1.21 9,659.28 MWD+IFR-AK-CAZ-SC(9) 5/52017 2:21:08PM Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kupamk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 31R-1011-1 Survey Calculation Method: Minimum Curvature Design: 3R-1011-7 Database: OAKEDMP2 Survey Surface Coordinates p Declination & Convergence O GRS Survey Corrections [, Survey Tool Codes SLB DE Brandon Temple �eiy Client Representative: Digolys bY&n Tolnr Ben Tolman t oJ T",A°+ n° 081Q 1 °b Date: 502017 Map Map Vertical MD Inc Azi TVD TVDSS -NI-S +E/ -W Northing Easting DLS Section (usft) (°) (°) (ustt) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,78045 90.18 269.01 3,56208 3,513.08 5,90343 -7,766.16 6,037,613.43 512,644.24 0.88 9,735.48 MWD+IFR-AK-CAZ-SC(9) 14,873.04 90.00 269.97 3,561.93 3,512.93 5,902.61 -7.858.74 6,037,612.35 512,751.67 1.05 9.812.14 MWD+IFR-AK-CAZ-SC(9) 14,967.31 9045 270.26 3,561.56 3,512.56 5,902.80 -7,953.01 6,037,61228 512,65741 0.57 9,890.77 MWD+IFR-AK-CAZ-SC(9) 15,060.54 9041 270.80 3,560.86 3,511.86 5,903.66 -8,046.23 6,037,612.88 512.564.20 0.58 9,968.89 MWD+IFR-AK-CAZ-SC(9) 15,153.24 90.29 270.41 3,56029 3,511.29 5,904.64 -8,138.93 6,037.613.60 512,471.51 0.44 10,046.64 MWD+IFR-AK-CAZSC(9) 15,246.21 90.24 271.28 3,559.86 3,510.86 5,906.01 -8,231.89 6,037,614.72 512,378.56 0.9d 10,124.83 MWD+IFR-AK-CAZ-SC(9) 15.339.98 91.25 270.36 3,556.65 3.509.65 5,907.35 -8,32564 6,037,615.80 512,284.81 146 10,20366 MWD+IFR-AK-CAZ-SC(9) 15,433.33 92.90 27148 3,555.27 3,506.27 5,908.85 -8,418.91 6,037,617.04 512,191.55 2.14 10,282.18 MWD+IFR-AK-CAZ-SC(9) 15,52598 9179 269.55 3,551.47 3,502.47 5,90968 -8,511.47 6,037,61761 512,098.99 2.40 10,359.74 MWD+IFR-AK-CAZ-SC(9) 15,61948 9171 268.09 3,548.62 3,499.62 5,907.76 -8,604.90 6,037,615.43 512,005.57 1.56 10,436.50 MWD+IFR-AK-CAZ-SC(9) 15,712.68 92.43 268.76 3,545.25 3,496.25 5,905.20 -8,698.01 6,037,612.61 511,912.49 1.05 10,512.64 MWD+IFR-AK-CAZ-SC (9) 15.806.16 91.01 268.04 3,542.45 3,49345 5,902.59 -8,79141 6,037,60974 511.819.10 1.70 10,588.99 MWD+IFR-AK-CAZ-SC 19) 15,832.58 9144 268.47 3,541.88 3,492.88 5,90178 -8,817.81 6,037,608.86 511792.71 2.30 10,610.53 MWD+IFR-AK-CAZ-SC(9) 15,86300 9144 288.47 3,541.12 3,492.12 5,900.97 -8,848.21 6,037,607.97 511,762.31 0.00 10,635.41 NOT en A001el Surrey 4-1/2" 15,696.00 91.44 268.47 3,540.29 3,491.29 5,900.09 -8,881.18 6,037,60700 511,729.34 000 10,662.39 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets and/or well posklon objectives have been achieved. _l Yes n No ! have checked to the best of my ability that the following data is correct: Surface Coordinates p Declination & Convergence O GRS Survey Corrections [, Survey Tool Codes SLB DE Brandon Temple �eiy Client Representative: Digolys bY&n Tolnr Ben Tolman t oJ T",A°+ n° 081Q 1 °b Date: 502017 5/52017 2:21: 08PM Page 7 COMPASS 5000.1 Build 74 21 7014 28185 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad 3R -101L1 3R -101L1 Definitive Survey Report 03 May, 2017 Company: ConDwPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 313 Pad Well: 3R-101 Wellbore: 3R-101 Lt Design: 3R-10111 Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual Q 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 4oject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1983 System Datum: Mean Sea Level iso Datum: North American Datum 1983 Using Well Reference Point lap Zone: Alaska Zone 4 Using geodetic scale factor Well 3R-101 Audit Notes: From Well Position +N/ -S 0.00 usft Northing: 6,031,484.21 usft Latitude: 70° 29'51.231 1 9,619.39 +E/ -W 0.00 usft Elating: 1,660,657.38 usft Longitude: 149° 50'4.099 V osition Uncertainty (usft) 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usf Wellbore 3R-10111 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1 (01 BGGM2016 4/13/2017 17.71 81.04 57,551 Design 3R-1011-1 Date 5/3/2017 Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 9,619.39 Vertical Section: Depth From (TVD) +N/S +EI -W Direction Gymdata gyro single shots (usft) (usft) (usft) (I MWD+IFR-AK-CAZ-SC 39.10 0.00 0.00 303.60 Survey Program Date 5/3/2017 From To Map Vertical MD (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 3R-101 Srvy 1 - SLB GYD-GC-SS (3R-1 GYD-GC-SS Gymdata gyro single shots 3/24/2017 828: 676.74 2,153.783R-101 Srvy 2 - SLB_MWD+GMAG (3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/24/2017 6:31: 2,208.44 2,208.44 3R-101 Srvy 3 - SIB_GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/25/2017 833: 2,297.00 8,026.553R-101 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD -IFR AKCAZSCC 3/29/2017 8:47: 8,102.69 9,327.483R-101 Srvy 5-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2017 2485 9,392.00 9,409.593R-101 L1PB1 Srvyl- Inc + Trend (3R-10 INC+TREND Inclinometer +known azi trend 4/14/2017 8:59: 9,438.00 9,619.393R-101-1 Pet Srvy2- SLB _GWD70(3R- GYD-GC-SS Gymdata gyro single shots 4/14/2017 910: 9,659.83 9,698.07 3R-10111 Srvyl - SLB_GWD70 (3R-101 GYD-GC-SS Gyrodata gyro single shots 4/17/2017 9:33:. 9,770.96 15,832.583R-10111 Srvy2- SLB _MWD+GMAG(3R MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/17/2017 950: Survey &3/2017 3.18:55PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing Easting OLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,484.21 1,660,657.38 0.00 0.00 UNDEFINED 135.69 0.74 51.62 135.69 86.69 D.39 649 6,031,484.60 1,660,65787 0.77 -0.19 GYD-GC-SS(1) 169.59 0.74 47.48 189.58 120.58 067 0.82 6,031,484.89 1,660,658.20 0.16 -0.31 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 21371 2.03 1.24 6,031,486.25 1,660.65841 0.95 0.09 GYD-GC-SS(1) 356.57 2.27 336.68 35651 307.51 4.69 0.47 6,031,48891 1.8W,657 84 1.34 2.21 GYD-GC-SS(1) 451.76 3.38 327.54 451.58 402.56 879 -/]8 6,031,493.00 1,660,655.57 1.25 6.35 GYD-GC-SS (1) 545.32 3.75 318.73 544.96 495.96 13.42 -5.28 6,031,497.62 1,660,652.08 0.71 11.82 GYD-GC-SS(1) &3/2017 3.18:55PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: 3R-101 North Reference: Wellbore: 3R-101 L7 Survey Calculation Method! Design: 3R-101-1 Database: Well 3R-101 3R-101 actual Q 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc AN TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (Usk) (usft) (ft) (ft) (`/100') (ft) Survey Tool Name 638.81 5.49 307.39 638.15 589.15 1643 -10.85 6,031,50262 1,660,64648 2.09 19.24 GYD-GC-SS(1) 676.74 6.24 302.09 675.88 626.88 2063. -14.04 6,031,504.60 1,66.64328 2.44 23.11 MWD+1FR-AK-CAZ-SC(2) 770.88 7.30 300.95 769.36 720.36 26.42 -23.50 6,031,510.57 1,660,633.81 1.13 34.20 MWD+IFR-AK-CAZ-SC(2) 86373 9.86 309.12 861.17 812.17 34.47 -34.73 6,031,518.59 1,660,622.56 3.05 48.01 MWD+IFR-AK-CAZ-SC (2) 959.68 9.96 31732 955.69 906.69 4576 -46.73 6,031,529.84 1,66.610.53 1.47 64.25 MWD+IFR-AK-CAZ-SC(2) 1,05373 12.30 328.76 1,047.98 998.98 60.31 -57.44 6,031,544.36 1,66.599]8 3.41 81.22 MWD+IFR-AK-CAZ-SC(2) 1,149.13 13.66 347.18 1,140.98 1,091.98 7999 65.22 6,031,56402 1,660,591.95 4.54 96.59 MWD+IFR-AK-CAZ-SC(2) 1,243.57 14.34 355.31 1,23262 1,183.62 102.52 58.65 6,031,586.54 1,660,588.46 2.20 113.91 MWD+IFR-AK-CAZ-SC(2) 1,338.60 14.97 357.92 1,324.56 1,275.56 126.52 -70.06 6,031,610.53 1,660,586.99 0.96 128.36 MWD+IFR-AK-CAZ-SC (2) 1,43341 1524 359.78 1,416.09 1,367.09 151.21 -70.55 6,031,635.22 1,660,586.43 0.59 14244 MWD+IFR-AK-CAZ-SC(2) 1.527.63 14.50 0,11 1,507.16 1,458.16 175.39 -70.57 6,031,659.40 1,660,566.34 0.79 155.84 MWD+1FR-AK-CAZ-SC(2) 1,62081 17.27 0.21 1,596.77 1,547.77 200.89 -70.50 6,031,68490 1,660,586.34 2.97 169.89 MWD+IFR-AK-CAZ-SC(2) 1,716.88 16.84 1,37 1,688.62 1,639.62 229.07 -70.12 6,031,71307 1,6W.586 65 0.57 185.16 MWD+IFR-AK-CAZ-SC(2) 1,81140 19.06 358.74 1,778.53 1729.53 258.19 -70.13 6,031,742.18 1,660,586.56 2.50 201.28 MWD+IFR-AK-CAZ-SC(2) 1,906.14 20.91 356.99 1,867.56 1,818.56 290.54 -71,36 6,031,774.53 1,660,585.24 2.05 220.21 MWD+IFR-AK-CAZ-SC(2) 2,000.30 24.98 355.65 1,954.26 1,905.26 327.16 -73]5 6,031,811.14 1,660582]5 4.36 242.46 MWD+IFR-AK-CAZ-SC(2) 2,094.43 28.81 355.00 2,038.19 1.989.19 369.59 -77.23 6,031,853.55 1,660,579.15 4.08 268.84 MWD+IFR-AK-CAZ-$C(2) 2,15378 30.11 355.47 2,089.86 2,040,86 39868 -79.66 6,031,88263 1,660,576.65 2.22 286.96 MWD+IFR-AK-CAZ-SC(2) 2,20644 33.91 357.04 2,13621 2,087.21 427.58 -81.53 6,031,911.53 1,66.574]0 7.12 304.51 GYD-GC-SS(3) 2,243.00 34.53 357.36 2,164.78 2,11638 446.99 -62.48 6,031,930.94 1,660,573:70 1.86 316.04 NOT anAeluel5urvey 13 3/8" 2,297.00 35.51 35]84 2,209.00 2,160.00 477.96 -83.77 6,031,961.89 1,660,572.32 1.88 334.26 MWD+IFR-AK-CAZ-SC(4) 2.353.55 37.24 358.70 2,254.53 2,205.53 511.48 -84.78 6,031,99541 1,660,571.22 3.19 353.64 MWD+IFR-AK-CAZ-SC (4) 2,448.06 41.36 358.32 2,327.65 2.278.65 571.31 -86.34 6,032,055.23 1,650,56949 4.37 388.05 MW0+IFR-AK-CAZ-SC(4) 2,543.56 4579 0.39 2,396.83 2,347.83 637.11 -87.04 6,032,121.02 1,660,56862 4.87 425.04 MWD+IFR-AK-CAZ-SC(4) 2,637.75 49.08 0.59 2.460.53 2.411.53 706.47 -86.44 6,032,19037 1,66.569.03 3.50 462.93 MWD+IFR-AK-CAZ-$C(4) 2,73227 54.02 1.62 2,519.29 2,470.29 780.45 -84.99 6,032,264.35 1,660,570.27 5.30 502.66 MWD+IFR-AWCAZ-SC(4) 2,82693 58.92 0.47 2,571.56 2,522.56 659.32 -83.57 6,032.343.22 1,660,571.47 5.27 545.12 MWD+IFR-AK-CAZ-SC(4) 2,919.52 63.48 0.11 2,616.16 2,567.16 940.43 -83.17 6,032,424.33 1,860,571.66 494 589.67 MWD+IFR-AK-CAZ-SC(4) 3,015.11 67.32 358.34 2,655.94 2,606.94 1,027.32 -84.36 6,032,511.20 1,660,570.23 4.36 638.74 MWD+IFR-AK-CAZ-SC (4) 3,110.07 71.37 357.59 2,68943 2,640.43 1,116.10 -87.53 6032,599.96 1,65.566.82 4.33 690.50 MWD+1FR-AK-CAZ-SC(4) 3,204.89 75.87 355.15 2,716.17 2,667.17 1,20.86 -93.31 6,032,69069 1,660,560,80 5.35 745.54 MWD+IFR-AK-CAZ-SC(4) 3,300.84 60.10 354.91 2,736.14 2,687.14 1,300.33 -101.44 6,032,784.13 1,66.552.41 4.42 804,04 MWD+IFR-AK-CAZ-SC(4) 3,395.53 80.99 355.26 2,751.69 2,702.69 1,393.39 -109.44 6,032,877.16 1,660,544.16 1.01 86220 MWD+IFR-AK-CAZ-SC(4) 3,490.19 61.39 356.24 2,766.19 2,717.19 1,486.67 -116.37 6,032,970.42 1,660,536.97 1.11 919.59 MWDNFR-AK-CAZ-SC(4) 3,582.99 81.43 35662 2,780.05 2,731.05 1,578.25 -122.08 6,033,061.97 1,660,531.01 0.41 975.03 MWD+IFR-AK-CAZ-SC(4) 3,679.39 81.52 355.89 2,794.34 2,745.34 1,673.38 -128.31 6,033,157.08 1,660,524.52 035 1,032.85 MWD+IFR-AK-CAZ-SC (4) 3,774.67 81.52 354.32 2,808.39 2,759.39 1,76728 -136.35 6,033,250.94 1,660,51823 163 1,091.51 MWD+IFR-AK-CAZ-SC(4) 3,869.26 81.14 354.65 2,82265 2,773,65 1,860.35 -145.34 6,033,343.98 1,660,5099 0.53 1,150.50 MWDNFR-AK-CAZ-SC (4) 3,963.62 81.59 354.57 2,836.82 2,787.82 1,953.23 -154.10 6,033,436.82 1,660,497.97 0.48 1,209.19 MWD+IFR-AK-CAZ-SC(4) 573/2017 3:18: 55PM Page 3 COMPASS 5000.1 Build 74 Company: ConomPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3R Pad Well: 3R-101 Wellbore: 3R-101 _1 Design: 3R-101.1 Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TvD TVDSS +Nl-S +E/ -W Northing EasUng DLS Section (usft) V) 0 (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 4,058.18 81.39 35485 2,85081 2,801.81 2,046.35 -16272 6,033,52991 1,660,489.11 0.37 1,267.89 MWD+IFR-AK-CAZ-SC(4) 4,153.32 81.31 35547 2,865.12 2,816.12 2,140.07 -170.64 6,033,623.60 1,660,48093 0.64 1,326.36 MWDHFR-AK-CAZ-SC(4) 4,24721 81.19 356.30 2,87941 2,830.41 2,232.63 -177.30 6,033,716.13 1,660,474.01 0.88 1,383.12 MWD+IFR-AK-CAZ-SC(4) 4,341.81 8129 35742 2,893.81 2,844.81 2,325.99 -182.42 6,033,809.46 1,660,46864 1.17 1,439.05 MWD+IFR-AK-CAZ-SC(4) 4,43687 81.31 358.76 2,908.19 2,859.19 2,419.90 -185.56 6,033,903.36 1,660,46525 1.39 1,49362 MWD+IFR-AK-CAZ-5C(4) 4,532.86 8146 359.12 2,922.57 2,873.57 2,514.79 -187.31 6,033,99823 1,660,463.24 040 1,547.59 MWD+IFR-AK-CAZ-SC(4) 4,62723 8149 358.61 2,936.56 2,887.56 2,608.10 -189.16 6,034,091.53 1,660461,14 0.54 1,60077 MWD+IFR-AK-CAZ-SC(4) 4,722.52 8162 358.05 2,950.56 2,90156 2,702.31 -191.91 6.034,185.73 1,660,458.13 0.60 1,655.19 MWD+IFR-AK-CAZ-SC(4) 4,816.15 81.17 357.64 2,964.57 2,915.57 2,794.82 -195.39 6,034,278.22 1,66,454.40 0.65 1,709.28 MWD+IFR-AKCAZ-SC(4) 4,910.05 8165 357.59 2,978.59 2,92959 2,887.59 -199.25 6.034,370.96 1,660,45028 0.51 1,763.83 MWD+IFR-AK-CAZ-SC (4) 5,005.50 81.45 357.34 2,99262 2,943.62 2,981.91 -20343 6,034,46526 1,660445.85 0.33 1,819.50 MWD+IFR-AK-CAZ-SC(4) 5,099.31 80.43 356.19 3,007.39 2,958.39 3,074.40 -20865 6,034,557.73 1,660,440.37 1.63 1,875.03 MWDHFR-AK-CAZ-SC(4) 5,194.23 7974 356.96 3,02333 2,974.73 3,167.73 -21624 6,03,651.04 1,660,434.53 1.08 1,931.33 MWD+IFR-AK-CAZ-SC(4) 5,28813 80.17 35741 3,040.22 2,991.22 3,260.67 -218.81 6.034,743.95 1,660.429.71 0.65 1,966.57 MWD+IFR-AK-CAZ-SC(4) 5,384.03 8016 355.86 3,056.49 3,00749 3,354.41 -224.32 6,034,83766 1,660,42395 1.60 2,04303 MWD+IFR-AK-CAZ-SC(4) 5478.50 80.16 35501 3,072.64 3,023.64 3,447.19 -231.73 6,034,93042 1,660,416.29 0.89 2,100.54 MWD+IFR-AK-CAZ-SC(4) 5,574.37 79.88 352.33 3,089.26 3,040.26 3,541.03 -242.14 6,035,024.21 1,660,405.62 2.77 2,161.13 MWD+IFR-AK-CAZ-SC(4) 5,668.19 80.05 352.29 3,10561 3,056.61 3,632.58 -254.50 6,035,115.73 1,660,393.01 0.19 2.222.09 MWD+IFR-AK-CAZ-SC(4) 5,762.98 7970 350.63 3,12227 3,073.27 3.724.85 -268.36 6,035,207.95 1,660,378.91 1.76 2,284.70 MWDHFR-AK-CAZ-SC(4) 5.858.90 79.93 350.94 3,139.23 3,090.23 3.818.04 -283.48 6,035,301.09 1,66,363 .54 040 2,348.86 MWD+1FR-AK-CAZ-SC(4) 5,953.58 79.83 352.59 3,155.87 3,106.87 3,910.29 -296.83 6,035.393.29 1,660,349.94 1.72 2,411.02 MWD+IFR-AK-CAZ-SC(4) 6,048.38 79.78 353.57 3,172.65 3,123.65 4,002.91 -308.07 6,035,485.87 1,660,338.44 102 2.471.63 MWD+IFR-AK-CAZ-SC(4) 6,142.31 80.65 351.82 3,18861 3,13961 4,094.72 -319.84 6,035,577.64 1,660,32643 2.06 2,532.24 MWD+IFR-AK-CAZ-SC(4) 6,23762 80.49 349.05 3,204.23 3,155.23 4,187.42 -335.45 6,035,670.29 1,660,310.56 2.86 2,596.55 MWD+IFR-AK-CAZ-SC(4) 6,332.89 80.84 348.35 3.219.69 3,17069 4,27961 -353.86 6,035,76242 1,660,29190 0.82 2,662.89 MWDHFR-AK-CAZ-SG(4) 6,42709 80.50 345.69 3,234.96 3.185.96 4,37022 -374.58 6,035,85296 1,660,270.94 260 2,73029 MWD+IFR-AK-CAZ-SC(4) 6,521.45 80.15 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,035942.87 1,660,247.14 1.23 2,799.70 MWD+IFR-AK-CAZ-SC(4) 6,615.67 79.69 34322 3,267.31 3,21831 4,549.37 -423.71 6,036,031.96 1,660,221.32 1.69 2,870.35 MWD+IFR-AK-CAZ-SC(4) 6,710.05 80.09 339.00 3,283.88 3,234.88 4,637.26 453.79 6,036,119.76 1,660.191.01 4.42 2,944.03 MWD+IFR-AK-CAZ-SC (4) 6,802.95 79.71 338.08 3,300.18 3,251.18 4,722.38 487.25 6,036,20478 1.66,157 32 1.06 3,019.00 MVM+IFR-AK-CAZ-SC(4) 6,898.97 7947 335.69 3,317.53 3,268.53 4,809.23 -524.32 6,036,29152 1,660,12002 246 3,097.94 MWD+IFR-AK-CAZ-SC(4) 6,99380 78.57 334.02 3,335.59 3,286.59 4,893.50 -563.87 6,036,375.67 1,660,080.24 197 3,17752 MWD+IFR-AK-CAZ-SC(4) 7,088.66 77.01 334.51 3,355.65 3,306.65 4,97701 -604.13 6,036,459.07 1,660,039.76 1,72 3,257.26 MWD+IFR-AK-CAZ-SC(4) 7,183.15 78.05 332.54 3,376.06 3,327.06 5,059.59 -645.26 6,036,541.52 1,659,998.41 231 3.337.22 MWD+IFR-AK-CAZ-SC(4) 7,277.04 78.85 332.66 3,395.02 3,346.02 5,141.23 -6B758 6.036,623.04 1,659,95587 0.65 3,417.64 MWDaIFR-AK-CAZ-SC(4) 7,370,87 79.07 330.57 3,413.15 3,364.15 5,222.22 -731.34 6,036,70390 1,659,91189 223 3,49891 MWDHFR-AK-CAZ-SC(4) 7,465.77 81.05 330.18 3,429.70 3,38070 5,304.33 -778.03 6,036,78587 1,659,664.98 2.10 3,583.24 MWD+IFR-AK-CAZ-SC(4) 7,561.29 8267 327.76 3,443.09 3,394.09 5,384.49 -828.27 6,036,865.90 1,659,816.54 3.08 3,667.77 MWD+IFR-AK-CAZ-SC(4) 7,65442 8363 323.12 3,454.20 3,405.20 5,460.62 -878.71 6,036,941,87 1,659,763.90 5.05 3,753.58 MWD+IFR-AK-CAZ-SC(4) 7,749.17 83.29 318.54 3,465.00 3,416.00 5,533.58 -938.15 6,037,01466 1,659,70426 4.82 3,843.46 MWD+IFR-AK-CAZ-SC(4) SWO17 3:18, 55PM Page 4 COMPASS 5000 1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: 3R-101 Wellbore: 3R-1011-1 Design: 3R-1011-1 Survey Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 SWO17 3r18,55PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc AN TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I r) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7.843.93 83.31 316.31 3,476.05 3,427.05 5602.88 -1,001.81 6,037,083.78 1,659,640.41 2.34 3,93484 MWD+IFR-AK-CAZ-SC (4) 7,937.29 83.12 313.16 3487.09 3,438.09 5,668.12 -1,067.66 603714884 1659,574.39 3.36 4,025.79 MWD+IFR-AK-CAZ-SC(4) 7,980.65 8266 310.87 3,492.45 3,44345 5,696.91 -1099.63 6,037,177.55 1,659,542.35 5.35 4,068.35 MWD+1FR-AK-CAZ-SC(4) 8,026.55 82.82 310.75 3,498.26 3,449.26 5,726.67 -1,13409 6,037,20721 1,659,50782 0.43 4,113.52 MWD+IFR-AK-CAZ-$C(4) 8,102.69 84.02 308.30 3,506.98 3,457.98 5,774.60 -1,192.43 6.037,255.17 1,659,44935 3.56 4,188.74 MWD+IFR-AK-CAZ-SC(5) 8,196 27 83.30 307.17 3,517.32 3.468.32 5,831.72 -1,26598 6,037,311.89 1,659,375.65 1.43 4,281.51 MWD+IFR-AK-CAZ-SC(5) 6,29064 80.09 306.79 3,530.94 3,481.94 5,887.89 -1,340.57 6,037,367.84 1,659,300.92 3.42 4,37471 MWD+IFR-AK-CAZ-SC(5) 8,385.81 78.59 302.73 3,548.56 3,499.56 5,941.21 -1,417.38 6,037,420.95 1659223.97 4.48 4,468.20 MWD+IFR-AK-CAZ-SC(5) 8480.48 82.05 294.76 3,564.50 3.515.50 5,986.01 -1,499.13 6,037,465.52 1,659,142.10 9.07 4,561.09 MWD+IFR-AK-CAZ-SC(5) 8,57524 86.75 290.20 3,573.75 3,524.75 6,022.04 -1,586.23 6,037,501.31 1,659,054.91 6.89 4,653.57 MWD+IFR-AK-CAZ-SC(5) 8,669.02 85.22 286.91 3.579.50 3,530.50 6,051.82 -1674.96 6,037,530.85 1.658,966.11 3.55 4,743.96 MWD+IFR-AK-CAZ-SC(5) 8,763.77 89.34 281.26 3,583.17 3,534.17 6,074.84 -1,]66]4 6,037,55362 1,658.874.28 6.81 4,833.15 MWD+IFR-AK-CAZ-SC(5) 8.859.11 69.82 275.16 3,583.87 3,534.87 6,08845 -1861.06 6,037,56697 1,658,779.93 6.42 4,919.24 MWD+IFR-AK-CAZ-SC(5) 8,954.08 89.52 271.80 3,584.42 3,535.42 6,09421 -1,955.84 6,037,57247 1,658,685.15 3.55 5,001.37 MWD+IFR-AK-CAZ-$C(5) 9,04767 86.64 271.51 3,58].55 3,538.55 6,096.92 -2,049.33 6.037,574 92 1,658,591.66 3.09 5,080.74 MWD+IFR-AK-CAZ.SC(5) 9,141.11 87.22 269.20 3,592.56 3,543.56 6,097.49 -2,14263 6,037,575.24 1,658498.37 2.55 5,158.77 MWD+IFR-AK-CAZ-SC(5) 9.234.58 88.14 268.66 3,596.34 3,547.34 6,095.91 -2,23600 6,037,573.41 1,658,405.01 1.05 5,235.68 MWD+IFR-AK-CAZ-SC(5) 9,32748 88.28 269.08 3,599.24 3,550.24 6,094.24 -2,32884 6,037,571.49 1,658,312.18 028 5,312.08 MWD+IFR-AK-CAZ-SC(5) 9,39100 86.18 269.65 3,602.31 3,553.31 6,093.54 -2.392.28 6,037.57061 1,658,248.75 3.42 5,364.53 NOT anAcWalSurvey 9 5/8" x 124/4 9,392.00 WA5 26966 3,602.38 3,553.38 6,093.53 -2,393.28 6037,570.60 1,658,24]]5 342 5.365.36 INC+TREND(6) 9,409.59 88.29 268.88 3,603.23 3,554.23 6,093.31 -2,410.85 6,037,570.33 1,658,230.19 12.95 5,379.87 INC+TREND(6) 9,438.00 8772 270.95 3,60422 3,555.22 6,093.27 -2,439.24 6,037,57021 1,658,201.80 7.55 5,403.49 GVD-GC-SS (7) 9,525.02 85.26 262.99 3,609.56 3,560.56 6,08869 -2,525.90 6,037,565.40 1,658,115.16 9.56 5,473.14 GVD-GC-SS(7) 9,619.39 88.72 260.24 3,614.51 3,565.51 6,074.95 -2,619.11 6,037,551.40 1,658,022.00 468 5,543.18 GVD-GC-SS(7) 9,659.83 8748 261.82 3,615.85 3,566.85 6,878.65 -2,65903 6,037.544.99 1,657,982.10 4.96 5,572.94 GVD-GC-SS(8) 9,698.07 86.39 260.08 3,617.90 3,568.90 6,06264 -2,696.73 6,037,538.88 1,657,944.41 5.36 5,601.03 GVD-GC-SS(8) 9,770.96 9075 260.43 3,619.71 3,570.71 6,050.31 -2,768.53 6,037,52636 1657,87266 6.00 5,654.01 MWD+IFR-AK-CAZ-SC (9) 9,865.39 93.68 260.64 3,616.07 3,567.07 6,03479 -2,861.60 6,037,510.59 1,657,779.64 3.11 5,72294 MWD+IFR-AK-CAZ-8C(9) 9,960.11 9049 261.23 3,612.62 3,56362 6,019.88 -2,955.06 6,037,49543 1,657,68623 3.42 5,792.54 MWD+1FR-AK-CAZ-SC (9) 10,054.31 91.77 259.84 3,610.76 3,561.76 6,004.40 -3,047.96 6,03747969 1,657,59339 2.01 5,861.35 MWD+IFR-AK-CAZ-SC (9) 10,149.10 92.04 259.98 3,607.61 3,558.61 5,987.80 -3,141.23 6,037,462.84 1,657,500.17 0.32 5.929.85 MWD+IFR-AK-CAZ-SC(9) 10,243.91 92.37 261.70 3,603.96 3,554.96 5,972.72 -3,23476 6,037,44751 1,657,406.69 1.85 5,999.41 MWD+IFR-AK-CAZ-SC(9) 10,338.55 90.76 263.17 3,601.38 3,552.38 5.960.26 -3,328.53 6,037,43480 1,657,312.96 2.30 6,070.63 MWD+IFR-AK-CAZ-SC(9) 10,43344 89.14 263.82 3,60146 3,552.46 5,949.51 -3,422.81 6,037,42379 1,657,218.73 1.84 6,143.21 MWD+IFR-AK-CAZ-SC(9) 10,528.09 8804 266.16 3,603.79 3,55479 5,94125 -3,517.06 6,037,415.27 1,657124.51 273 6,217.14 MWD+IFR-AK-CAZ-SC(9) 10,621.97 88.31 270.42 3,606.78 3.557.78 5,938.45 -3,610.83 6,037,412.22 1,657,030.75 4.54 6,293.70 MWD+IFR-AK-CAZ-SC(9) 10,716.41 9077 270.79 3,607.54 3,558.54 5,939.45 -3,70525 6,037,412.96 1,656,936.34 2.63 6,372.90 MWD+IFR-AK-CAZ-SC(9) 10,811.03 90.74 270.18 3,60629 3,557.29 5,940.25 -3,799.86 6,037,413.50 1,6%,84174 0.65 6,452.14 MWD+IFR-AK-CAZ-SC(9) 10,905.00 90.00 268.76 3,605.69 3,55669 5,939.38 -3,893.82 6,037,412.38 1,656,747.79 1.70 6,529.93 MWD+IFR-AK-CAZ.SC(9) SWO17 3r18,55PM Page 5 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: 3R-101 North Reference: Wellbore: 3R-10111 Survey Calculation Method: Design: 3R-10111 Database: Survey Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 5732077 3:18:55PM Page 6 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS -N/.S +Ei-W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,000.45 89.81 266.85 3,605.84 3,556.84 5,935.72 -3,989.20 6,037,408.46 1,656.65243 2.01 6,607.35 MWD+IFR-AK-CAZ-SC(9) 11,094.67 8965 267.15 3,606.29 3,557.29 5,93079 4083.29 6,037,403.28 1,656,558.37 0.36 6,682.99 MWD+IFR-AK-CAZ-SC(9) 11.189.53 9048 266.64 3,606.18 3,557.18 5,925.66 4,178.01 6,037.397.88 1,656,46367 1.03 8,759.04 MWD+IFR-AK-CAZ-SC(9) 11,284.13 9199 266.72 3.604.14 3.555.14 5,920.18 -0,272.42 6,037,392.15 1,656,36928 1.60 6,83466 MWD+IFR-AK-CAZ-SC(9) 11378.89 91.58 267.17 3,601.19 3,552.19 5,915.13 -4,367.00 6,037,386.84 1,656.27472 0.64 6,91064 MWD+IFR-AK-CAZ-SC(9) 11,471.23 94.01 267.55 3,596.69 3,54769 5,910.88 -4,459.13 6,037,382.34 1,656,182.62 266 6,985.03 MWD+IFR-AK-CAZ-SC(9) 11,568.32 92.48 267.57 3,591.19 3,542.19 5.906.76 -4,555.97 6,037,377.95 11656,085.80 1.58 7,06341 MWD+IFR-AK-CAZ-SC(9) 11,663.04 93.38 267.37 3,586.35 3,537.35 5,90258 -4,650.47 6,037,373.52 1,655,991.31 0.97 7,139.81 MWD+1FR-AK-CAZ-SC(9) 11,758.11 94.20 268.78 3,580.07 3,531.07 5,899.39 -4,745.28 6,037,370.08 1,655,896.53 1.71 7,217.02 MWD+IFR-AK-CAZ-SC(9) 11,852.56 93.15 269.12 3,574.01 3,525.01 5,897.67 -4,839.52 6,037,368.09 1,655,80230 1.17 7,294.56 MWD+IFR-AK-CAZ-SC(9) 11,946.96 9090 269.07 3.570.68 3.52168 5,896.18 -4,933.84 6,037,366.35 1655,707.99 2.38 7,372.30 MWD+IFR-AK-CAZ-SC(9) 12.041.61 89.84 271.14 3,57007 3.521.07 5,896.35 -5,02848 6,037,366.26 1,655,61336 2.46 7,451.23 MWD+IFR-AK-CAZ-SC(9) 12,137.27 91.29 272.42 3,569.12 3,520.12 5,899.32 -5,124.09 6,037,368.97 1,655,51776 2.02 7,53250 MWD+IFR-AK-CAZ-SC(9) 12,230.94 91.41 272.83 3,566.92 3,517.92 5.903.61 -5,217.63 6,037,37301 1,655.424.21 0.46 7,612.80 MWD+1FR-AK-CAZ-SC(9) 12,32511 90.18 271.97 3.565.60 3,51660 5.907.58 -5.312.31 6,037,376.72 1,655,329.54 1.58 7,693.85 MWD+1FR-AK-CAZ-SC(9) 1242062 89,19 272.10 3,566.12 3,517.12 5,910.95 -5,407.15 6,037,37963 1,655,234.69 1.05 7,774.72 MWD+IFR-AK-CAZ-SC(9) 12,514.94 89.27 270.81 3,567.39 3,518.39 5,913.34 -5,50143 6,037,38197 1,655,14041 1.37 7,854.57 MWD+IFR-AK-CAZ-SC(9) 12,60947 89.18 270.48 3,568.67 3,519.67 5,91441 -5,595.95 6,037,38277 1,655,045.90 0.36 7,933.89 MWD+IFR-AK-CAZ-SC(9) 12.704.11 69.31 269.89 3,569.92 3,52092 5.914.71 -5,690.58 6.037,382 82 1,654,951.28 0.64 8,012.88 MWD+IFR-AK-CAZ-SC(9) 12,799.17 89.98 269.19 3,570.50 3,521.50 5,913.95 -5,785.63 6,037,381.80 1,6M,856 24 1.02 8,091.63 MWD+IFR-AK-CAZ-SC (9) 12,893.33 89.51 26877 3,570.92 3,521.92 5,912.27 -5,879.78 8,037,379.87 1,654,762.11 0.67 8,169.12 MWD+IFR-AK-CAZ-SC(9) 12,987.54 89.96 268.94 3,571.36 3,522.35 5,910.39 -5,973.97 6,037,377.73 1,654.667.94 0.51 8,246.53 MWDHFR-AK-CAZ-SC(9) 13,081.98 90.02 269.39 3,57138 3,522.38 5,909.01 -6,068.40 6,037,376.09 1,654,573.52 0.48 6,324.43 MWD+IFR-AK-CAZ-SC(9) 13,176.% 88.12 269.29 3,572.92 3,523.92 5,907.92 -6163.35 6,037,374.74 1,654,478.58 2.00 8402.91 MWO+IFR-AK-CAZ-SC (9) 13,272.05 89.19 269.04 3,575.15 3,526.15 5,906.53 -6,258.41 6,037,373.10 1,654,383.54 1.16 8,481.32 MWO+IFR-AK-CAZ-SC (9) 13,366.17 89.M 269.96 3,575.94 3,526.94 5,905.71 -6,352.52 6,037,372.02 1,654,289.44 120 8,559.26 MWD+IFR-AK-CAZ-SC(9) 13,460.80 89.88 270.65 3,576.16 3,527.16 5,906.22 -6447.14 6,037,372.27 1,654,194.82 0.73 8,638.36 MWD+IFR-AK-CAZ-SC(9) 13,55564 90.83 270.26 3,575.57 3,526.57 5,906.97 -6541.98 6,037,372.76 1,654,099.99 1.08 8,717.76 MWO+IFR-AK-CAZ-SC(9) 13,650.19 90.77 271.06 3,574.25 3,525.25 5,908.06 -6,636.51 6,037,373.59 1,654,00546 0.85 8.797.11 MWD+IFR-AK-CAZ-SC (9) 13,744.83 89.99 271.11 3,57363 3,524.63 5,909.85 -6731.13 6,037,375.13 1,653,910.85 0.83 8,876.91 MW0+IFR-AK-CAZ-SC (9) 13,840.07 91.35 273.34 3,572.51 3,523.51 5,913.55 -6,826.29 6,037,378.56 1,653,815.70 2.74 8,958.22 MWD+1FR-AK-CAZ-SC(9) 13,934]9 91.43 272.02 3,570.21 3,521.21 5,917.98 -6,920.87 6,037,382.73 1,653,721.11 1.40 9,039.45 MWD+IFR-AK-CAZ-SC (9) 14,029.33 90.71 271.32 3,568.45 3,519.45 5,92073 -7,015.35 6,037.385.23 1,653.62663 106 9.119.67 MWD+IFR-AK-CAZ-SC (9) 14,12374 90.80 269.47 3,567.20 3,518.20 5,921.38 -7,109.75 6,037,385.62 1,653,532.24 1,% 9,198.66 MWD+IFR-AK-CAZ-SC (9) 14,218.35 90.13 269.02 3,56644 3,517.44 5,920.13 -7,204.35 6,037,384.12 1,653,437.65 0.85 9,276.77 MWD+IFR-AK-CAZ-SC (9) 14,312% 90.44 268.85 3,565.97 3,516.97 5,918.39 -7,298.34 6,037,382.12 1,653,343.68 0.38 9,354.09 MWD+IFR-AK-CAZ-SC (9) 14,406.91 90.62 268.39 3,565.09 3,516.09 5,916.11 -7,39286 6,037,379.58 1,653,249.17 D.52 9,431.56 MWD+IFR-AK-CAZ-SC (9) 14,500.96 90.56 268.14 3,564.13 3,515.13 5,913.26 -7,486.86 6,037,37848 1,653,155.19 0.27 9,508.28 MWD+IFR-AK-CAZ-SC(9) 14,594.71 90.41 267.13 3,563.33 3,514.33 5,909.39 -7,580.53 6,037,372.36 1,653,061.54 1.09 9,584.16 MWD+IFR-AK-CAZ-SC (9) 14,68746 90.48 268.25 3,56261 3,513.61 5,905.66 -7,67320 6,037,368.37 1,652,968.89 1.21 9,659.28 MWD+IFR-AK-CAZ-SC(9) 5732077 3:18:55PM Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: 3R-101 North Reference: Wellbore: 3R-1011_1 Survey Calculation Method: Design: 3R-1011_1 Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) 00 (°1100') (ft) Survey Tool Name 14,780.45 90.18 269.01 3,562.08 3,513.08 5.90343 -7,766.16 6.037.365.89 1,652,875.95 0.88 9735.48 MWD+IFR-AK-CAZ-SC(9) 14.873.04 90.00 269.97 3,561.93 3,512.93 5,902.61 -7,85834 6,037,364.81 1,652,783.38 1.05 9,812.14 MWD+IFR-AK-CAZ-SC (9) 14,967.31 90.45 270.26 3,561.56 3,512.56 5,902.80 -7,953.01 6,037,364.75 1,652,689.12 0.57 9,890.77 MWD+IFR-AK-CAZ-SC (9) 15,060.54 9041 270.80 3,560.86 3,511.86 5,903.66 -8,046.23 6.037,365.35 1,652,595.90 0.58 9,968. Be MWD+IFR-AK-CAZ-SC(9) 15.153.24 90.29 27041 3,560.29 3,511.29 5.90464 -8,138.93 6,037,366.08 1,652,503.21 0.44 10,04664 MWD+1FR-AK-CAZ-SC(9) 15,246.21 9024 271.28 3,559.86 3,510.86 5,906.01 -8,231.89 6,037,36720 1,652,410.26 694 10,124.83 MWD+IFR-AK-CAZ-SC(9) 15,339.98 91.25 270.36 3,558.65 3,50965 5,907.35 -8,325.64 6,037,36828 1,652,316.52 1.46 10,203.66 MWD+IFR-AK-CAZ-SC(9) 15,433.33 92.90 271.48 3,555.27 3.50627 5,908.85 -8,418.91 6,037,W9 53 1,652,223.25 2.14 10,282.18 MWD+IFR-AK-CAZ-SC(9) 15,52598 91.79 269.55 3,551.47 3,502.47 5,909.68 -8,511.47 6.037.370 11 1,652,130.70 2.40 10,359]4 MWD+IFR-AK-CAZ-SC(9) 15,619.48 91]1 26809 3,548.62 3,49962 5,90T76 -8.604.90 6037,367.93 1,652,037.28 1.56 10,436.50 MWD+IFR-AK-CAZ-SC(9) 15,712.68 92.43 268.76 3,545.25 3,496.25 5,905.20 -8,698.01 6,037,365.12 1,651,944.19 1.05 10,51264 MWD+IFR4K-CAZ-SC(9) 15,806.16 91.01 268.04 3,542.45 349345 5,902.59 -8,79141 6,03736225 1,651,850.81 1 7 10,588.99 MWD+IFR-AK-CAZ-SC(9) 15,83258 91.44 268.47 3,541.88 3,492.88 5,901.]8 .8,817.81 6,03],36138 1,651,82441 2.30 10,610.53 MWD+IFR-AK-CAZ-SC(9) 15,863.00 91,44 26847 3,541.12 3,492.12 5,900.97 -8,848.21 6,037,360.48 1,651,794.02 0.00 10,635.41 NOT anAcllwlSurvay 4-1/Y' 15,896,00 9144 268.47 3,540.29 3,491.29 5,900.09 -8.881.18 6,037,359.51 1,651,761.05 0.00 10.66239 PROJECTED to TD Final Definitive Survey Verified and Signed -off All targets andlor well position objectives have been achieved. F1 Yes I No 1 have checked to the best of my ability that the following data is correct: E] Surface Coordinates p Declination & Convergence Q GRS Survey Corrections E] Survey Tool Codes SLB DE: Brandon Temple g�Byi _ DIp161Ns rctlbv Ban Tdnwn Client Representative: Ben Tolman IFN (°wAo °° 001051° Date 5/8/2017 5WO17 3: 18..55PM Page 7 COMPASS 5000.1 Build 74 RECEIVED SchIUMberge;AY 11 2117 AOGC�Drilling &Measurements V WD/LWD Log Product Delivery 2218710816 Transmittal Y: 10MAY17-SP03 DATA LOGGED rj AS/2017 M. K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 3R-101L1PB1 Date Dispatched: 10 -May -17 Job#: 16AKA0110 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' TO 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: Tom.Osterkamp(a)conocophillips.com AlaskaPTSPrintCenter()slb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: L, FINAL NADConversion Kuparuk River Unit Kuparuk 3R Pad 3R-101L1PB1 P►oGGG Definitive Survey Report 05 May, 2017 21 7014 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual Q 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R -101L1 PBI Survey Calculation Method: Minimum Curvature Design: 3RA 01 L1 PB1 Database: OAKEDMP2 Oroject Kuparuk River Unit, North Slope Alaska, United States nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level iso Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point nap Zone: Alaska Zone 04 Using geodetic scale factor well 3R-101 Audit Notes: Well Position +N/ -S 0.00 usft Northing: 6,031,732.16 usft Latitude: 70° 29'52+272 1 ACTUAL +E/ -W 0.00 usft Easting: 520,625.98 usft Longitude: 149' 49'52.775 V oshion Uncertainty Direction 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usf Wellbore 3R-101L1PB1 Magnetics Model Name Sample Date Declination Dlp Angle Field7St;mngth(°) (9 BGGM2016 4/20/2017 17.69 81.04 Design 3R-101L1PB1 Date Audit Notes: To Version: 1.0 Phase: ACTUAL Tie On Depth: 9,327.48 Vertical Section: Depth From (TVD) +N/S +EI -W Direction 676.74 (usft) (usft) (usft) (°) 2,208.44 39.10 0.00 0.00 335.11 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 313-101 Srvy 1 - SLB _GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/24/2017 8:28: 676.74 2,153.783R-101 Srvy 2-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/24/2017 8:31: 2,208.44 2,208.44 3R-101 Srvy 3 - SLB GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/25/2017 833: 2,297.00 8,026.553R-101 SpM ry 4-SLB_WD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/29/2017 8:47: 8,102.69 9,327.483R-101 Spry 5 -SLB MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2017 2:48:0 9,392.00 9,409.593R-1011-1 PB1 Srvyi- Inc + Trend (3R-10 INC+TREND Indinometer + known azi trend 4/14/2017 8:59: 9,438.00 9,713.813R-101 L1 Pet Srvy2-SLBGWD70(3R- GYD-GC-SS Gyrodata gyro single shots 4/14/2017 9:10: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Basting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0 D 0.00 6,031,732.16 520,625.98 0.00 0.00 UNDEFINED 135.69 0.74 51.62 135.69 86.69 0.39 0.49 6,031,732.55 520.62647 0.77 0.15 GYD-GC-SS(1) 169.59 074 47.48 169.58 120.58 0.67 0.82 6,031,732.83 520,626.80 0,16 0.26 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 213.71 2.03 1.24 6,031734.19 520,627.21 0.95 1.32 GYD-GC-SS(1) 356.57 2.27 336.68 356.51 307.51 4.69 0.47 6,031,736.85 520,626.44 134 406 GYD-GC-SS(1) 451.76 3.38 32754 451.58 402.58 8.79 -1.78 6,031,740.95 520,624.17 1.25 8.73 GYD-GC-SS(1) 545.32 3.75 318.73 544.96 495.96 13.42 .5.28 6,031,745.56 520,620.66 0.71 14.39 GYD-GC.SS(1) 63881 5.49 307.39 638.15 589.15 18.43 -10:85 6,031,750.56 520,615.08 2.09 2129 GYD-GC-SS(1) 676.74 6.24 302.09 675.88 626.88 2063. -14.04 6,031,75275 520,611.88 2.44 24.62 MWD+IFR-AK-CAZ-SC(2) 5152017 2:27:23PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kupamk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 L1PB1 Survey Calculation Method: Minimum Curvature Design: 3R-101 11 PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS -NI-S +El -W Northing Easting DLS Section (usft) P) 1°) (usft) (usft) (usft) (usft) (ft) (ft) (.1100') (ft) Survey Tool Name 770.88 7.30 300.95 769.36 720.36 26.42 -23.50 6,031,758.52 520,602.40 1.13 33.86 MWD+1FR-AK-CAZ-SC (2) 863.73 9.66 309.12 861.17 812.17 34.47 -34.73 6,031,766.53 520,591.15 3.05 45.89 MWD+1FR-AK-CAZ-5C (2) 95968 9.96 317.32 955.69 906.69 45.76 -46.73 6,031,777.78 520,579.13 1.47 61.18 MWD+IFR-AK-CAZ-SC(2) 1,053.73 12.30 328.76 1,047.96 998.98 60.31 -5744 6,031,792.30 520,568.37 3.41 78.88 MWD+IFR-AK-CAZ-SC(2) 1,149.13 13.65 347.18 1,140.98 1,091.98 79.99 -65.22 6,031,811.96 520,560.55 4.54 100.01 MM+IFR-AK-CAZ-SC(2) 1,243.57 14.34 355.31 1,232.62 1.183.62 102.52 -68.65 6,031,834.48 520,557.05 2.20 121,89 MWD+1FR-AK-CAZ-SC(2) 1,33860 14.97 357.92 1,324.56 1.275.56 126.52 -70.06 6,031,85847 520,555.58 0.96 144.25 MWD+1FR-AK-CAZ-SC(2) 1,43341 15.24 359.78 1416.09 1,367.09 151.21 -70.55 6.031,883.16 520,555.02 0.59 166.86 MWD+IFR-AK-CAZ-SC(2) 1,527.63 14.50 0.11 1,507.16 1458.16 175.39 40.57 6,031,90734 520,554.93 0.79 188.80 MM+IFR-AK-CAZ-SC(2) 162081 17.27 0.21 1,596.77 1,547.77 200.89 -70.50 6,031,932.84 520,554.93 2.97 211.91 MWD+IFR-AK-CAZ-SC(2) 1716.88 16.84 1.37 1,668.62 1,639.62 229.07 -70.12 6,031,961.01 520,555.24 0.57 237.30 MWD+IFR-AK-CAZ-SC(2) 1,811.40 1906. 35834 1,778.53 1,729.53 258.19 -70.13 6,031,990.13 520,555.14 2.50 263.72 MWD+IFR-AK-CAZ-SC (2) 190.14 20.91 356.99 1,857.56 1,818.56 290.54 -71.36 6,032,022.47 520,553.83 2.05 293.58 MM+IFR-AK-CAZ-SC(2) 2,000.30 24.98 355.65 1,954.26 1905.26 327.16 -73.75 6,032.059.08 520,551 33 4.36 327.80 MWD+)FR-AK-CAZ-SC (2) 2,094.43 28.81 355.00 2,038.19 1,989.19 369.59 -77.23 6,032,101.50 520,547.73 4.08 36776 MWD+IFR-AK-CAZ-SC(2) 2,15378 30.11 35547 2,089.86 2,040.86 398.68 -79.66 6,032,130.57 520,54523 2.22 395.16 MWD+1FR-AK-CAZ-SC(2) 2,208.44 33.91 357.04 2,136.21 2,087.21 427.58 -81.53 6,032,159.47 520,543.28 7.12 422.17 GVD-GC-SS(3) 2,243.0 34.53 357.36 2,16438 2,115.78 446,99 -82.48 6,032,17888 520,542.27 1.88 440.18 q(jT lB$IIA1Jr 13 3l8" 2,297.00 35.51 357.84 2,209.0 2,160.00 477.96 -83.77 6,032,209.84 520,540.89 1.88 468.81 MWD+IFR-AK-CAZ-SC(4) 2,353.55 37.24 358.70 2,25453 2,205.53 51148 -84.78 6,032,243.35 520,539.79 3.19 499.64 MWD+IFR-AK-CAZ-SC(4) 2,448.0 41.36 358.32 2,327.65 2,278.65 571.31 -86.34 6,032,303.17 520,538.06 4.37 554.57 MWD+IFR-AK-CAZ-SC (4) 2,543.56 4539 0.39 2.396.83 2,347,83 637.11 -87.04 6,03$36896 520,537.19 4.87 614.55 MWD+IFR-AK-CAZ-SC(4) 2,637.75 49.08 0.59 2,460.53 2,411.53 706.47 -86.44 6,032,436.31 520,537.59 3.50 677.21 MWD+IFR-AK-CAZ-SC(4) 2.732.27 54.02 1.62 2,519.29 2,470.29 780.45 -84,99 6,032,512.29 520,538.83 530 743.71 MWD+IFR-AK-CAZ-SC(4) 2,826.93 58.92 0.47 2,571.56 2,522.56 859.32 -8157 6,032,591.16 520,540.03 5.27 81466 MWD+1FR-AWCAZ-SC(4) 2,919.52 6348 0.11 2,616.16 2,567.16 940.43 -83.17 6,0K 672.27 520,540.21 494 8880 MWD+IFR-AK-CAZ-SC(4) 3,015.11 67.32 358.34 2,655.94 2,606 94 1027.32 -84.36 6,032,759.14 520,53877 4.35 07.38 MWD+IFR-AK-CAZ-SC(4) 3,110.07 71.37 35759 2,689.43 2,64043 1.116.10 -87.53 6.032,847.90 520,535.37 4.33 1,049.24 MWD+IFR-AK-CAZ-SC(4) 3,20489 75.87 355.15 2,716.17 2,667.17 1,20.86 -93.31 6,032,93863 520,529.33 5.35 1,134.00 MWD+1FR-AK-CAZ-SC(4) 3,300.84 80.10 354.91 2,736.14 2,687.14 1,30.33 -101.44 6,033,032.07 520,520.95 4.42 1,222.21 MWD+1FR-AK-CAZ-SC (4) 3,395.53 8099 355.26 2,75169 2,702.69 1,393.39 -109.44 6,033,125.10 520,51269 1.01 1,309.99 MWD+IFR-AK-CAZ-SC(4) 3,490.19 81.39 356.24 2,766.19 2,717.19 1,486.67 -116.37 6,033,218.36 520,505.50 1.11 1,397.52 MWD+IFR-AK-CAZSC(4) 3,582.99 81.43 35662 2,780.05 2,731.05 1,57825 -122.08 6,033,309.91 520,499.53 0.41 1,483.00 MWD+)FR-AK-CAZ-SC(4) 3,679.39 81.52 355.89 2,794.34 2,745.34 1,673.38 -128.31 6,033,405.02 520,493.04 0.75 1,571.91 MWD+1FR-AK-CAZ-SC(4) 3,774.67 81.52 354.32 2,808.39 2,759.39 1,767.28 -136.35 6,03349888 520,484.74 1,63 1,660.47 MWD+IFR-AK-CAZ-SC (4) 3,869.26 81.14 354.65 2,82285 2,77365 1,860.35 -145.34 6,033,591.92 520,47549 0.53 1,748.68 MWD+IFR-AK-CAZ-SC(4) 3,963.62 81.59 354.57 2836.82 2,767.82 1,953.23 -15,1A0 6,033,684]6 520,466.47 0.48 1,835.61 MWD+IFR-AK-CAZ-SC (4) 4,058.18 81.39 354.86 2,850.81 2,801.81 2,046.35 -162.72 6,033,777.85 520,457.0 0.37 1,924.71 MWD+IFR-AK-CAZ-SC(4) 4,153.32 81.31 355.47 2,865.12 2,816.12 2,140.07 -170.64 6,033,871.54 520,44941 0.64 2,013.06 MWD+IFR-AK-CAZ-SC(4) 5/52017 2:27:23PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pao MD Reference: 3R-101 actual @ 49.00ustt (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101 L1 PBI Survey Calculation Method: Minimum Curvature Design: 3R-101 -1 PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N74 +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Toot Name 4,247.21 81.19 356.30 2,879.41 2830.41 2,232.63 -177.30 6,033,96407 520,442.50 0.88 2,099.82 MWD+IFR-AK-CAZ-SC 14) 4,341.81 81.29 35742 2.893.81 2,844.81 2,325.99 -182.42 8,034,057,40 520,437.12 1.17 2,186.66 MWD+IFR-AK-CAZ-SC(4) 4436.87 81.31 358.76 2,908.19 2,859.19 2,419.90 -185.56 6,034,151.29 520,433.73 1.39 2,273.16 MWD+IFR-AK-CAZ-SC(4) 4,532.86 81.46 359.12 2,922.57 2,873.57 2,514.79 -187.31 6,034,246.17 520,43171 0.40 2,359.97 MWD+IFR-AK-CAZ-SC(4) 4,627.23 81.49 358.61 2,936.56 2,887.56 2,608.10 -189.16 6,034,339.46 520,429.60 0.54 2.445.39 MWD+IFR-AK-CAZ-SC(4) 4,72252 81.62 358.05 2,950.56 2,901.56 2,702.31 -191.91 6,034,433.66 520,42659 0.60 2,532.01 MWD+IFR-AK-CAZ-SC(4) 4,816.15 81.17 357.64 2,964.57 2,915.57 2799.82 -195.39 6,034,526.15 520,422.86 0.65 2,617.39 MWD+IFR-AK-CAZ-SC (4) 4,910.05 81.65 35759 2.978.59 2,929.59 2,887.59 -199.25 6,034618 .90 520,41874 0.51 2,703.16 MWD+IFR-AWCAZ-SC(4) 5,005.50 81.45 357.34 2,99262 2,94362 2,98191 -203.43 6,034,713.20 520,414.30 033 2,790.48 MND+1FR-AK-CAZ-SC(4) 5,099.31 80.43 356.19 3,007.39 2,958.39 3,074.40 -208.65 6,034,80566 520,408.82 1.63 2,876.57 MWD+IFR-AK-CAZ-SC(4) 5,194.23 7974 356.96 3,023.73 2,974.73 3,167.73 -214.24 6,034,898.97 520.402.97 1.08 2,963.59 MWD+IFR-AK-CAZ-SC (4) 5,28873 80.17 357.41 3,040.22 2,99122 3,260.67 -218.81 6,034991 .89 520,398.14 0.65 3,049.81 MWD+IFR-AK-CAZ-SC(4) 5,384.03 80.16 355.86 3, D%A9 3,007.49 3.354.41 -224.32 6,035,085.60 520,392.37 1.60 3,137.16 MWD+IFR-AK-CAZ-SC (4) 5,47850 80.16 355.01 3,072.64 3,023.64 3,447.19 -231.73 6,035,478.35 520,384.71 0.89 3,22444 MWD+IFR-AK-CAZ-SC(4) 5,574.37 79.88 352.33 3,089.26 3.040.26 3,54103 -242.14 6,035,272.15 520,374.04 277 3,313.94 MWD+IFR-AK-CAZ-SC (4) 5,668.19 80.05 352.29 3.105.61 3,05681 3,632.58 -254.50 6,035,36366 520,36143 0.19 3,402.19 MWD+IFR-AK-CAZ-SC(4) 5,762.98 79.70 350.63 3,122.27 3,073.27 3,72485 -268.36 8,035,455.89 520,347.32 176 3,491.72 MND+1FR-AK-CAZ-SC(4) 5,858.90 79.93 350.94 3,139.23 3,090.23 3,818.04 -28348 6,035,54902 520,331.94 040 3,58262 MWD+IFR-AK-CAZ-SC(4) 5,953.58 79.83 352.59 3,155.87 3,106.87 3,910.29 -296.83 6,035,641.22 520,318.34 1.72 3,671.91 MWD+IFR-AK-CAZ-SC(4) 6,048.38 7978 353.57 3,172.65 3,123.65 4,002.91 -308.07 6,035,733.80 520,306.84 1.02 3,760.66 MWD+IFR-AK-CAZ-SC(4) 6,142.31 80.65 351.82 3,188.61 3,139.61 4,094.72 -319.84 6,035,825.57 520,294.81 2.06 3,848.89 MWD+1FR-AK-CAZ-SC (4) 6,237.62 8049 349.06 3,204.23 3,155.23 4,18742 -335.45 6,035,91822 520,278.95 2.86 3,939.56 MWDNFR-AK-CAZ-SC(4) 6,332.89 80.84 348.35 3.219.69 3,170.69 4,279.61 -353.86 6,036,010.35 520,260.28 0.82 4,030.93 MWD+1FR-AK-CAZ-SC(4) 6,427.09 80.50 345.89 3,23496 3,185.96 4,370.22 -374.58 6,036,100.89 520,239.31 2.60 4,121.84 MWD+IFR-AK-CAZ-SC(4) 6,521.45 80.15 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,036,190 80 520,215.51 1.23 4,213.38 MWD+IFR-AK-CAZ-SC(4) 6,615.67 79.69 343.22 3,267.31 3,218.31 4,549.37 -423.71 6,03527988 520,18969 1.69 4,305.02 MWD+IFR-AK-CAZ-SC(4) 6,71005 80.09 339.00 3,283.88 3,234.88 4,637.26 -45379 6.035,367 68 520,159.37 442 4,397.41 MWD+1FR-AK-CAZ-SC(4) 6,802.95 7971 338.08 3,300.18 3,251.18 4,72238 487.25 6,036,452.70 520,125.68 1.06 4488.70 MWD+IFR-AK-CAZ-SC(4) 6,89897 79.47 335.69 3,317.53 3,268.53 4,809.23 -524.32 6,036,539.44 520,088.37 246 4,583.09 MWD+1FR-AK-CAZSC(4) 6,993.80 78.57 334.02 3,335.59 3,286.59 4,893.50 -563.87 6,036,623.59 520,048.59 1.97 4,676.18 MWD+IFR-AK-CAZ-8C (4) 7,088.66 77.01 334.51 3,355.65 3,306.65 4,977.01 -604.13 6,036,706.98 520,006.10 172 4,768.88 MWD+IFR-AK-CAZ-SC(4) 7,183.15 78.05 332.54 3,376.06 3,327.06 5,059.59 -645.26 6,036,78944 519.96675 2.31 4,861.10 MWD+IFR-AK-CAZ-SC(4) 7,27704 78.65 332.66 3,395.02 3,345.02 5,141.23 -687.58 6,036,870.95 519,92421 0,65 4,952.96 MWD+IFR-AK-CAZ-SC(4) 7.370.87 79.07 330.57 3,413.15 3,364.15 5,222.22 -731.34 6,035,95181 519,880.22 2.23 5,044.85 MWD+IFR-AK-CAZ-SC (4) 7,466.77 81.05 330.18 3,429.70 3,380.70 5,304.33 -778.03 6,037,03378 519,833.31 2.10 5,138.98 MWD+IFR-AK-CAZ-SC(4) 7,561.29 82.87 327.76 3,443.09 3,394.09 5,384.49 -82627 6,037,113.80 519,784.86 3.06 5,232.00 MWD+IFR-AK-CAZ-SC(4) 7,654.42 8363 323.12 3,454.20 3,405.20 5,460.62 -878.71 6,037,189.77 519,732.21 5.05 5,323.13 MWD+IFR-AK-CAZ-SC(4) 7,749.17 83.29 318.54 3,465.00 3,416.00 5,533.58 -938.15 6,037,262.56 519,672.58 4.82 5,414.33 MWD+1FR-AK-CAZ-SC (4) 7,843.93 83.31 316.31 3,476.05 3,427.05 5,602.88 -1,001.81 6,037,33168 519,608.72 2.34 5,503.99 MWD+1FR-AK-CAZ-SC l4) 7,937.29 83.12 313.16 3,487.09 3,438.09 5,668.12 -1,067.66 8,037,396.73 519,542.70 3.36 5,590.89 MWD+IFR-AK-CAZ-SC(4) 532017 2:27:23PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3R-101 Project: Kuparuk River Unit TVD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Site: Kuparuk 3R Pad MD Reference: 3R-101 actual @ 49.00usft (Doyon 142) Well: 3R-101 North Reference: True Wellbore: 3R-101L1PB1 Survey Calculation Method: Minimum Curvature Design: 3R-101 L1 PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,980.65 $2.66 310.87 3,492.45 3,443.45 5,696.91 -1,09963 6,037,42543 519.510.66 5.35 5,630.47 MWD+IFR-AK-CAZ-SC(4) 8,026.55 82.82 310.75 3.498.26 3,449.26 5.72667 -1,134.09 6.037,455.09 519,476.12 043 5,671.97 MW0+1FR-AK-CAZ-$C(4) 8,10269 84.02 308.30 3,506.98 3,457.98 5.774.80 -1,19243 6,037,503.06 519,417.65 3.56 5,740.18 MWD+3FR-AK-CAZ-SC(5) 8,196.27 $3.30 307.17 3,517.32 3,468.32 5,831.72 -1,26598 6,037559.77 519,343.95 1.43 5,822.78 MWD+1FR-AK-CAZ-SC(5) 13,29064 80.09 306.79 3,530.94 3,481.94 5,887.89 -1,340.57 6,037,615.72 519,269.22 342 5,905.12 MWD+IFR-AK-CAZ-SC(5) 8,385.81 78.59 302.73 3.548.56 3,499.56 5,94121 -1,417.38 6,037,668.82 519,192.26 4.48 5,985.82 MWD+1FR-AK-CAZ-SC(5) 8,480.48 82.05 2M.76 3,564.50 3,515.50 5.985.01 -1499.13 6,037,713.39 519,110.39 9.07 6.060.88 MWD+IFR-AK-CAZ-SC(5) 8,575.24 86.75 290.20 3.57375 3.52475 6,022.04 -1,586.23 6,037,749.17 519,02320 6.89 6,13022 MWD+IFR-AK-CAZSC(5) 8,669.02 86.22 286.91 3,579.50 3,530.50 6,051.82 -1,674.96 6,037,778.71 518,934.40 3.55 6.194.58 MWD+IFR-AK-CAZ-SC(5) 8,763.77 89.34 281.26 3,583.17 3,534.17 6,074.84 -1,7%,74 6,037,80147 518,842.56 6.81 6,254.11 MWD+IFR-AK-CAZ-SC(5) 6,859.11 89.82 275.16 3,583.87 3,534.87 6,088.45 -1,861.06 6,037,81482 518,748.22 6.42 6306.15 MWD+1FR-AK-CAZ-SC(5) 8,954.08 89.52 271.80 3,584.42 3,535.42 6,094.21 -1,955.84 6,037,820.32 518,65343 3.55 6,35128 MWD+IFR-AK-CAZ-SC(5) 9,047.67 86.64 271.51 3,587.55 3.538.55 6,096.92 -2.049.33 6,037.82276 518,559.95 3.09 6.393.08 MWD+IFR-AK-CAZ-SC(5) 9,141.11 87.22 269.20 3,592.56 3.543.56 6,097.49 -2,142.63 6,037,82308 518,46866 255 6,432.88 MWD+1FR-AK-CAZ-6C(5) 9,234.58 W14 268.86 3,596.34 3,547.34 6,095.91 -2,236.00 6,037,821.24 518,373.29 1.05 6,470.75 MWD+1FR-AK-CAZ-SC(5) 9,327.48 88.28 269.08 3,599.24 3.550.24 6.094.24 -2,328.84 6,037,81931 518,28047 0.28 6,508.32 MWD+IFR-AK-CAZ-SC(5) 9,39100 86.18 269.65 3,602.31 3,553.31 6,093.54 -2.392.28 6,037,81843 518,217.04 342 6,53438 NOT an Actual Survey 9 BIB" x 12.1/4 9,392.00 86.15 26966 3602.38 3,553.38 6,093.53 -2,393.28 6,037,818.42 518,216.04 3.42 6,534.80 INC+TREND(6) 9,409.59 88.29 268.88 3,603.23 3,554.23 6,093.31 -2,410.85 6,037,818.15 518,198.47 12.95 6,541.99 INC+TREND(6) 9,438.00 87.72 270.95 3,604.22 3,555.22 6,093.27 -2,439.24 8037,818.03 518,170.09 7.55 6,553.90 GYD-GC-SS(7) 9,52502 85.26 262.99 3,609.56 3,560.56 6,088.69 -2,525.90 6,037.813.21 518,08345 9.56 6,58623 GYD-GC-SS(7) 9,619.39 88.72 26024 3,614.51 3,565.51 6,074.95 -2,619.11 6,037,799.21 517,990.29 468 6,613.00 GYD-GC-SS(7) 9,66000 90.22 258.33 3,614.89 3,565.89 6,067.40 -2,659.00 6,037,791.55 517,95042 599 6,622.94 NOT an Actual Survey 4-112" 9,71381 92.21 255.79 3,61374 3,564.74 6,055.35 -2,711.43 6,037,779.36 517,898.03 5.99 6,634.08 GYD-GC-SS i71 9,80500 92.21 255.79 3,610.23 3,561.23 6,032.98 -2,79976 6,037,756.75 517,809.77 0.00 6,650.98 PROJECTEDto TD 8.3/4" OH rival Definitive Survey Verified and Signed<ff Aptwpo atlb�ep04apMaWrwew haw eeb adxauxtl. Ll wa nw Ih»e 4hbawlbrMMRdcgahp4y betlbbeevay dleeea 1 7 Straw CIXrdna69 b Gass C0MM9 n59nWrfttRdu'lIG SawY TOJICN% SLBOE amEon TeTle S�/L Gdll RepresaTewe am T.. Doe sacnil 5/52017 2:27:23PM Page 5 COMPASS 5000.1 Build 74 Mph \ � 2011 NGGGG FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad 3R-101L1PB1 Definitive Survey Report 03 May, 2017 21 7014 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: 3R-101 Wellbore: 3R-101 L1 PB1 Design: 3R-101L1PB1 Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 'roject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1983 System Datum: Mean Sea Level iso Datum: North American Datum 1983 Using Well Reference Point lap Zone: Alaska Zone 4 Using geodetic scale factor Well 3R-101 Audit Notes: To Well Position +N/ -S 0.00 usft Northing: 6,031,484.21 usft Latitude: 70° 29'51.231 N 9,327.48 +EI -W 0.00 usft Easting: 1,660,657.38 usft Longitude: 149' 50'4.099 W Position Uncertainty (usft) 0.00 Usti Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Nelibore 3R-101 L1 PB7 Aagnetics Model Name Sample Date Declination Dip Angle Field Strength (°I PI (nT) BGGM2016 4/20/2017 17.69 81.04 57,550 Design 3R-101LIPB1 Audit Notes: To Map Map Version: 1.0 Phase: ACTUAL Tie On Depth: 9,327.48 Vertical Section: Depth From (TVD) +N/ -S +El -W Direction 676.74 lush) (usft) (usft) (') 2,208.44 39.10 0.00 0.00 335.11 Survey Program Date 5/3/2017 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 135.69 638.81 3R-101 Srvy 1 - SLB_GYD-GC-SS (3R-1 GYD-GC-SS Gyrodate gyro single shots 3/24/2017 8:28: 676.74 2,153.783R-101 Srvy 2- SLB _MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 3/24/2017 8:31: 2,208.44 2,208.44 3R-101 Srvy 3 - SLB_GYD-GC-SS (3R-1 GYD-GC-SS Gyrodata gyro single shots 3/25/2017 8:33: 2,297.00 8,026.553R-101 Srvy 4-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/29/2017 847: 8,102.69 9,327.483R-101 Srvy 5-SLB_MWD+GMAG(3R- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2017 248:5 9,392.00 9,409.593R-101 L1 PB1 Srvyl- Inc + Trend (3R-10 INC+TREND Inclinometer + known azi trend 4/14/2017 8:59: 9,438.00 9,713.81 3R-101 L1 PB7 Srvy2 - SLB GWD70 (3R- GYD-GC-SS Gyrodata gyro single shots 4/14/2017 9:10: Survey 5/32017 3:12:57PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc An TVD TVDSS +N/ -S +E/ -W Northing Easing DIS Section (usft) l') (') (usft) (usft) (usft) (usft) (ft) IN (-1100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -9.90 0.00 0.00 6,031,484.21 1.660,657.38 0.00 0.00 UNDEFINED 13569 0.74 51.62 13569 66.69 0.39 0.49 6,031,484.60 1,660,657.87 0.77 0.15 GYD-GC-SS(1) 169.59 034 4748 169.58 120.58 0.67 0.82 6,031,484.89 1,660,65820 0.16 0.26 GYD-GC-SS(1) 262.73 1.17 358.19 262.71 213.71 2.03 1.24 6,031,48625 1,660,658.61 0.95 1.32 GYD-GC-SS(1) 356.57 2.27 336.68 356.51 307.51 469 047 6,031,48891 1,660,657.84 1.34 406 GYD-GC-SS(1) 451.76 3.38 327.54 451.58 402.58 879 -138 6,031493.00 1,660,655.57 1.25 8.73 GYD-GC-SS(1) 545.32 3.75 318.73 544.96 495.96 13.42 -5.28 6,031,497.62 1,660,652.06 0.71 14.39 GYD-GC-55(1) 638.81 549 307.39 638.15 589.15 18.43 -10.85 6,031,502.62 1,660,646.48 2.09 21.29 GYD-GC-SS(1) 67874 6.24 302.09 675.88 626.88 2063 -14.04 6,031,504.80 1,660,643.28 2.44 24.62 MWD-IFR-AK-CAZ-SC (2) 5/32017 3:12:57PM Page 2 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3R Pad Well: 3R-101 Wellbore: 3R-101 Li PBI Design: 3R-101-1 PBI Survey Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3R-101 3R-101 actual @ 49.00usft (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 5/32017 3:12:57PM Page 3 COMPASS 5000.1 Build 74 Map Map vertical MD Inc Azi TVD TVDSS +NI -S +El -W Northing Easting DLS Section (usft) (°) 0 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 770.88 7.30 300.95 769.36 720.36 2642 -2350 6.031,510 57 1,660,633.81 1.13 33.86 MWD+IFR-AK-CAZ-SC(2) 86373 9.86 309.12 861.17 812.17 34.47 -34.73 6,031,518.59 1,660,622.56 305 45.89 MWD+IFR-AK-CAZ-SC(2) 95968 9.96 317.32 95569 906.69 4576 -4673 6,031,529.84 1,660,610.53 1.47 61.18 MWD+IFR-AK-CAZ-SC(2) 1.053.73 12.30 328.76 1,047.98 99898 60.31 -57.44 6,031,544.36 1,660,599.78 3.41 78.88 MWD+1FR-AK-CAZ-SC(2) 1,149.13 13.66 347.18 114098 1,09198 7999 -6522 6,031564.02 1,660,591.95 4.54 100.01 MWD+IFR-AK-CAZ-SC(2) 1,24357 14.34 355.31 1,23262 1,183.62 102.52 -68.65 6,031.586.54 1,6W,588 46 2.20 121.89 MWD+IFR-AK-CAZ-SC(2) 1,33860 14.97 357.92 1,324.56 1,275.56 126.52 -7006 6,031,610.53 1,660,586.99 0.96 144.25 MWD+IFR-AK-CAZ-SC (2) 1,433.41 15.24 359.78 1,41609 1,367.09 151.21 -70.55 6,031,635.22 1,660,58643 0.59 166.86 MWD+IFR-AK-CAZ-SC(2) 1,527,63 14.50 0.11 1,507.16 1458.16 175.39 -70.57 6,031659.40 1,650,586.34 0,79 188.80 MWD+IFR-AK-CAZ-SC(2) 1,620.81 17.27 0.21 1,596.77 1,547.77 200.89 -70.50 6,031,684.90 1,660,586.34 2.97 211.91 MWD+IFR-AK-CAZ-SC(2) 1,716.88 16.64 1.37 1,688.62 1,639.62 22907 -70.12 6,031,713.07 1,660586.65 0.57 237.30 MWD+IFR-AK-CAZ-SC(2) 1,81140 19.06 358.74 1,778.53 1,729.53 258.19 -70.13 6,031,742.18 1,660,586.56 2.50 263.72 MWD+IFR-AK-CAZ-SC(2) 1,905.14 20.91 356.99 1,867.56 1,818.56 290,54 -71.36 6,031,774.53 1,660,585.24 2.05 293.58 MWD+IFR-AK-CAZ-SC(2) 2,000.30 24.98 35565 1,954.26 1,905.26 327.16 -73.75 6,031,811.14 1,660,582.75 4.36 327.80 MWD+IFR-AK-CAZ-SC(2) 2,09443 28.81 355.00 2,038.19 1,989.19 369.59 -77.23 6,031,853.55 1,660,579.15 4.08 367.76 MWD+IFR-AK-CAZ-SC(2) 2,15378 30.11 35547 2,089.86 2,040.86 398.68 -79.66 6,031,88263 1,660.57665 2.22 395.16 MWD+IFR-AK-CAZ-SO(2) 2,20844 33.91 357.04 2,136.21 2,087.21 427.58 -81.53 6,031,911.53 1,660,574.70 7.12 422.17 GVD-GC-SS(3) 2,24300 34.53 357.36 2,16418 2,115.78 446.99 -82.48 6,031,930.94 1,660.57370 1.88 440.1e 1,)pTanAtfualSurvy 13 318" 2,29T00 35.51 357.84 2,209.00 2.160.00 477,96 -8377 6,031,96189 1,660,572.32 1.88 468.81 MWD+IFR-AK-CAZ-SC(4) 2,353.55 37.24 358.70 2,254.53 2,205.53 511.48 -84.78 6,031,995.41 1,660,571.22 3.19 49964 MWD+IFR-AK-CAZ-SC(4) 2,44806 41.36 358.32 2,327.65 2,27865 571.31 -86.34 6,032,055.23 1,660,569.49 4.37 554.57 MWD+IFR-AK-CAZ-SC(4) 2,543.55 45.79 0.39 2.396.83 2,347.83 637.11 -87.04 6,032,121.02 1,660,56862 4.87 614.55 MWD+IFR-AK-CAZ-SC(4) 2,63775 49.08 0.59 2,460.53 2,411.53 706.47 -86.44 6,032,19D.37 1,660,56903 3.50 677.21 MWD+IFR-AKCAZ-SC(4) 2,73227 54.02 162 2,519.29 2,47029 78045 -8499 6,032,26435 1,660,57027 5.30 743.71 MWD+IFR-AKCAZ-SC(4) 2,826.93 58.92 047 2,57156 2,522.56 859.32 -83.57 6,032,343.22 1,660,57147 5.27 814.66 MWD+IFR-AKCAZ-SC(4) 2,919.52 63.48 0.11 2,616.16 2.567.16 94043 -83.17 6,032,424.33 1,660,571.66 4.94 888.05 MWD+IFR-AKCAZ-SC(4) 3,015.11 67,32 35834 2,655.94 2,606.94 1,027.32 -84.36 6,032,511.20 1,660,57023 4.36 967.38 MWD+IFR-AK-CAZ-SC(4) 3,110.07 71.37 357.59 2,689.43 2,640.43 1,116.10 -87.53 6,032,599.96 1,660,566.82 4.33 1,049.24 MWD+IFR-AKCAZ-SC(4) 3,204.89 75.87 355.15 2,716.17 2,667.17 1,206.86 -93.31 6,032,690.69 1,660,56080 5.35 1,134.00 MWD+IFR-AKCAZ-SC(4) 3,300.84 80.10 354.91 2,736.14 2,687.14 1,300.33 -10144 6,032,784.13 1,660,55241 4.42 1,222.21 MWD+IFR-AKCAZ-SC(4) 3,395.53 8099 355.26 2,751.69 2,702.69 1,393.39 -10944 6,032,877.16 1,660,544.16 1.01 1309.99 MWD+IFR-AKCAZ-SC(4) 3,490.19 81.39 356.24 2,766.19 2,717.19 1,486.67 -116.37 6,032,970.42 1,660.536.97 1.11 1.397.52 MWD+IFR-AKCAZ-SC(4) 3,582.99 81.43 356.62 2,780.05 2,73705 1,578.25 -122.08 8,033,061,97 1,660,531.01 041 1,483.00 MWD+IFR-AKCAZ-SC(4) 3,679.39 8152 355.89 2,794.34 2.745.34 1,673.36 -128.31 5.033,157 08 1,660,524.52 0.75 1,571.91 MWD+IFR-AKCAZ-SC(4) 3,774.67 81.52 354.32 2,808.39 2.759.39 1,767.28 -136.35 6,033,250.94 1,660,516.23 1.63 1,660.47 MWD+IFR-AKCAZ-SC(4) 3,869.26 81.14 354.65 2,822.65 2,773.65 1,860.35 -145.34 6,033,343.98 1,660,506.99 0.53 1.748.68 MWD+1FR-AKCAZ-SC(4) 3,96362 81.59 354.57 2,836.82 2,787.82 1,95323 -154.10 6,033,436.82 1,660,497.97 0.48 1.836.61 MWD+IFR-AKCAZSC(4) 4.058.18 81.39 354.86 2,850.81 2.807.81 2,046.35 -162.72 6,033,529.91 1,660,489.11 0.37 1.924.71 MWD+IFR-AKCAZ-SC(4) 4,153.32 81.31 355.47 2,865.12 2,816.12 2,140.07 -170.64 6,033,623.60 1,660,480.93 0.64 2,013.06 MWD+IFR-AKCAZ-SC(4) 5/32017 3:12:57PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 313 Pad MD Reference: Well: 3R-101 North Reference: Wellbore: 3R-101 -1 PBI Survey Calculation Method: Design: 3R-101-1PB1 Database: Survey Well 3R-101 3R-101 actual @ 49.00usti (Doyon 142) 3R-101 actual @ 49.00usft (Doyon 142) True Minimum Curvature OAKEDMP2 5132017 3:12..57PM Page 4 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +PJ -W Northing Easting DLS Section (usft) C) (I Mitt) (usft) (usft) (usft) (ft) (It) (°1100') (ft) Survey Tool Name 4,247.21 81.19 356.30 2,87941 2,830.41 2,232.63 -177.30 6,033,716.13 1,660 474 01 088 2.099.82 MWD+IFR-AK-CAZ-SC(4) 4,34161 81.29 357.42 2,893.81 2,84481 2,325.99 -18242 6.033,80946 1,660,468.64 1.17 2,18666 MWD+IFR-AK-CAZSC(4) 4,436.87 81.31 358.76 2,908.19 2,859.19 2,419.90 -185.56 6.033.903.36 1,660,46525 1.39 2,273.16 MWD+IFR-AK-CAZ-8C(4) 4,532.86 8146 359.12 2,922.57 2,87357 2,514.79 -187.31 6,033,99823 1,660,463.24 0.40 2,359.97 MWD+IFR-AK-CAZ-SC(4) 4.627.23 8149 35861 2,936.56 2,887.56 2,608.10 -189.16 6.034,091 53 1,660,461.14 0.54 2,445.39 MWD+IFR-AK-CAZ-SC(4) 4,72252 $1.62 358.05 2,950.56 2,901.56 2,702.31 -191.91 6,034,18573 1,660,458.13 0.60 2,532.01 MWD+IFR-AK-CAZ-SC(4) 4,816.15 81.17 357.64 2,964.57 2,915.57 2)94.82 -19539 6,034,278.22 1,660,454.40 0.65 2.617.39 MWD+IFR-AK-CAZSC(4) 4,910.05 81.65 357.59 2,978.59 2,929.59 2,887.59 -199.25 6,034,370.96 1,660,450.28 0.51 2,703.16 MWD+IFR-AK-CAZ-SC (4) 5,005.50 81.45 357.34 2,992.62 2,94362 2,981.91 -203.43 6,034,465.26 1,660,445.85 0.33 2,790.48 MWD+IFR-AK-CAZ-SC (4) 5,099.31 8043 356.19 3,007.39 2,958.39 3,07440 -208.65 6,034,557.73 1,660,440.37 1.63 2,876.57 MWDNFR-AK-CAZ-SC(4) 5,194.23 79.74 356.96 3,023.73 2,974.73 3,167.73 -21424 6.034,651.04 1,660,434.53 1.08 2,963.59 MWD+IFR-AK-CAZ-$C(4) 5,28873 80.17 357.41 3,040.22 2,991.22 3,26067 -218.81 6,034,743.95 1,660,42971 0.65 3.04981 MWD+IFR-AK-CAZ-SC(4) 5,384.03 60.16 355.86 3,05649 3.007.49 3,354.41 -224.32 6,034,837.66 1,660,423.95 1.60 3,137.16 MWD+IFR-AK-CAZSC(4) 5,478.50 80.16 355.01 3,07264 3,023.64 3,447.19 -231.73 6,034,930.42 1,660,416.29 0.89 3,22444 MWD+IFR-AK-CAZ-SC(4) 5,574.37 79.88 352.33 3,08926 3,040.26 3,541.03 -242.14 6,035,02421 1,660.405.62 2.77 3,313.94 MWD+IFR-AK-CAZ-SC(4) 5,668.19 80.05 352.29 3,105.61 3,055.61 3,632.58 -254.50 6,035,115]3 1.660,39301 0.19 3,402.19 MWDNFR-AK-CAZ-SC(4) 5,762.98 7970 35063 3,122.27 3,073.27 3,724.85 -268.36 6,035,20195 1,660,378.91 1.76 3.491.72 MWD+IFR-AK-CAZ-SC(4) 5,858.90 79.93 35094 3,139.23 3,090.23 3,81804 -283.48 6,035,301.09 1,660,363.54 0.40 3,582.62 MWD+IFR-AK-CAZ-SC(4) 5,953.58 79.83 352.59 3,155.87 3,106.87 3,910.29 -296.83 6,035,393.29 1,660,349.94 132 3,671 91 MWD+IFR-AK-CAZSC (4) 6,048.38 7978 353.57 3,172.65 3.123.65 4,002.91 -308.07 6,035,485.87 1,660.338.44 1.02 3,760.65 MWD+IFR-AK-CAZ-SC (4) 6,142.31 80.65 351.82 3,188.61 3,139.61 4,094.72 -319.84 6,035,57764 1,660,326.43 2.87 3,848.89 MWD+IFR-AK-CAZ-SC(4) 6,237.62 80.49 34906 3,204.23 3,155.23 4,187.42 -335.45 6,035,670.29 1,660,310.56 2.86 3,939.56 MWD+IFR-AK-CAZ-SC(4) 6,33289 80.84 348.35 3,219.69 3,170.69 4,279.61 -353.86 6,035,76242 1,660,291,90 0.82 4,030.93 MWD+IFR-AK-CAZ-SC(4) 6,427.09 80.50 345.89 3,234.96 3,185.95 4,370.22 -374.58 6,035,852.96 1,660,270.94 260 4,121.84 MWD+IFR-AK-CAZ-SC(4) 6,521.45 80.15 344.77 3,250.82 3,201.82 4,460.20 -398.14 6,035,942.87 1660,247.14 1.23 4,213.38 MWD+IFR-AK-CAZSC (4) 6,615.67 79.69 343.22 3,26731 3.218.31 4,549.37 -42371 6,035,031.96 1,660,221.32 1.69 4,305.02 MWD+IFR-AK-CAZ-SC(4) 6,710.05 80.09 339.00 3,283.88 3,234.88 4,637.28 -453.79 6,03611976 1,660,191.01 4.42 4,397.41 MWD+IFR-AK-CAZ-SC (4) 6,802.95 79.71 338.08 3,300.18 3.251.18 4,722.38 -487.25 6,036,204.78 1,660,157.32 1.06 4,48870 MWD+IFR-AK-CAZ-SC(4) 6,898.97 79.47 335.69 3,317.53 3,268.53 4,809.23 -524.32 6,036,291.52 1,860,120.02 2.46 4,583.09 MWD+IFR-AK-CAZ-SC(4) 6,993.80 78.57 334.02 3,335.59 3,285.59 4,89350 -563.87 6,036,375.67 1,660,080.24 1.97 4,676.18 MWD+IFR-AK-CAZ-SC(4) 7.088.65 77.01 334.51 3,355.65 3,306.65 4,977.01 -604.13 6,036,459.07 1,660.039]6 1.72 4,766.88 MWD+IFR-AK-CAZ-SC(4) 7,183.15 7805 332.54 3,376.06 3,327.05 5,059.59 595.26 6,036541.52 1,659,99841 2.31 4,851.10 MWD+IFR-AK-CAZ-SC(4) 7,277.04 78.65 332.65 3,39502 3,346.02 5,141.23 -6BT58 6,036,623.04 1,659,955.87 0.65 4,95296 MWD+IFR-AK-CAZ-SC(4) 7,370.87 79.07 330.57 3,413.15 3,364.15 5,222.22 -731.34 6,036,703.90 1,659,911,89 2.23 5,044.85 MWD+IFR-AK-CAZ-SC(4) 7,465.77 81.05 330.18 3,42910 3,380.70 5,304.33 -778.03 6,038,785.87 1,659,854.98 2.10 5138.98 MWD+IFR-AK-CAZ-SC (4) 7,561.29 82.67 327.76 3,443.09 3,399.09 5,384.49 -826.27 6,036,86590 1,659,816.54 3.06 5,232.00 MWD+IFR-AWCAZ-SC(4) 7,654.42 83.63 323.12 3,454.20 3,405.20 546062 -87831 6,036,941.87 1,659,763.90 5.05 5,323.13 MWD+IFR-AK-CAZ-SC(4) 7,749.17 83.29 318.54 3,465.00 3,416.00 5,533.58 -938.15 6,037,014.66 1,659,704.26 4.82 5,414.33 MWD+IFR-AK-CAZ-SC (4) 7,843.93 63.31 316.31 3,476.05 3,427.05 5,602.88 -1,001.81 6,037,083]8 1,659,640.41 2.34 5,503.99 MWD+IFR-AK-CAZ-SC(4) 7,937.29 83.12 313.16 3,487.09 3,438.09 5,668.12 -1,067.66 6,037,148.84 1,659,574.39 3.36 5,59089 MWD+IFR-AK-CAZ-SC(4) 5132017 3:12..57PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 3R Pad Well: 3R-101 Wellbore: 3R-101 1.1 PBI Design: 313-1011.1 PB1 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (I (9 (usft) (usft) (usft) 7,98065 8266 310.87 3,49245 3.443.45 5,696.91 8,026.55 82.82 31075 3,498.26 3,449.26 5,726.67 8,10269 84.02 308.30 3,506.98 3,457.98 5,774.80 8,19627 83.30 307.17 3,517.32 3,46832 5831.72 8,29064 80.09 306.79 3,530.94 3,461.94 5,887.89 8,385.81 78.59 302.73 3,548.56 3,49956 5,941.21 8,48048 82.05 294.76 3,564.50 3.515.50 5,986.01 8,57524 86.75 290.20 3,573.75 3,52475 6,022.04 8,669.02 86.22 286.91 3,579.50 3.530.50 6,051.82 8.763.77 89.34 281.26 3,583.17 3,534.17 6.074.84 8,859.11 89.82 275,16 3,583.87 3,534.87 6,088.45 8,954.08 89.52 271.80 3,584.42 3,53542 6,09421 9,047.67 86.64 271.51 3,587.55 3,538.55 6,096.92 9,141.11 87.22 269.20 3,59256 3,543.56 6,097.49 9,234.58 88.14 268.86 3,596.34 3,547.34 6,095.91 9,327.48 88.28 269.08 3,59924 3,550.24 6,094.24 9,391.00 86.18 269.65 3,602.31 3,55331 6,093.54 9 618" x 12-1/4 9,392.00 86.15 269.66 3,602.38 3,553.38 6,093.53 9,409.59 88.29 268.88 3,603.23 3,554.23 6,093.31 9,438.00 87.72 270.95 3,604.22 3,555.22 6,093.27 9,525.02 85.26 262.99 3,609.56 3,560.56 6,08869 9,619.39 88.72 260.24 3,614.51 3,565.51 6,074.95 9,660.00 90.22 258.33 3,614.89 3.565.89 6,06] 40 4.1/2' 9,71381 9221 255.79 3,613.74 3,564.74 6,055.35 9,805.00 9221 255.79 3,61023 3,561.23 6,03298 83/4" OH Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3R-101 3R-101 actual Q 49.00usn (Doyon 142) 3R-101 actual @ 49.00usn (Doyon 142) True Minimum Curvature OAKEDMP2 rival Definitive Survey Verified and Signed -off Allnym artlbrWlpoaalmob/wMws havebarn.hlore . El vas ❑ No Ilnvs chrckatln Ihs MCd my sWllry Con are roll.." dere Is mmtt O Sudaw Coommalas (] Dedrvem 8 Corrvaoence. E ORB survey Corrections C Survey Tool Codes / SLB DE Brandon Targe !/140isscl4yr. %airrs+ce Clial R."lortaim, Ben Tolman De1e WM17 5/3/2017 3, 12:57PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical +E/ -W Northing Easting DLS Section (usft) (ft) (ft) (°/100') (ft) Survey Tool Name -1,09963 6,037,177.55 1,659,542.35 5.35 5,63047 MWD+IFR-AK-CAZ-SC(4) -1,134.09 6,037.207.21 1,659,507.82 0.43 5,67197 MWD+IFR-AK-CAZ-SC(4) -1,192.43 6,037,255.17 1,659,449.35 3.56 5,740.18 MWD+IFR-AK-CAZ-SC(5) -1,265.98 6.037,311.89 1,659,375.65 143 5,822.78 MWD+IFR-AK-CAZ-SC(5) -1,340.57 6,037,367.84 1,659,300.92 342 5,905.12 MWD+IFR-AK-CAZ-SC(5) -1,417.38 6,037,420.95 1,659,223.97 4.48 5,985.82 MWD+IFR-AK-CAZ-SC(5) -1,499.13 6,037,465.52 1.659 142.10 9.07 6,060.88 MWD+IFR-AK-CAZ-SC(5) -1,586.23 6.037,501 31 1059,05491 6.89 6,130.22 MWD+IFR-AK-CAZ-SC(5) -1,674.96 6,037,530.85 1,658966.11 3.55 6,194.58 MWD+IFR-AK-CAZ-SC(5) -1]66.74 6,037,553.62 1,658,874.28 6.81 6,254.11 MWD+IFR-AK-CAZ-SC(5) -1,861.06 6,037,556.97 1,658,779.93 6.42 6,306.15 MWD+IFR-AK-CAZ-SC(5) -1,95584 6,037,57247 1,658.685.15 3.55 6.351.28 MWD+IFR-AK-CAZ-SC(5) -2,049.33 6,037,574.92 1,658,591.66 3.09 6,39308 MWD+IFR-AK-CAZSC(5) -2,14263 6,037,57524 1,658,498,37 2.55 6,432.88 MWD+IFR-AK-CAZ-SC(5) -2,236.00 6,037,57341 1.658.405.01 1.05 6470.75 MWD+IFR-AK-CAZ-SC(5) -2,328.84 6037,57149 1,658.312.18 028 6,508.32 MWD+IFR-AK-CAZ-SC(5) -2,392.28 6,037,57061 1,658,248.75 3.42 6,534.38 NOT anAclualSurvey -2,39328 6,037,570.60 1,658,247.75 3.42 6,534.80 INC+TREND(6) -2,410.85 6,037,570.33 1,658,230.19 12.95 6,541.99 INC+TREND(6) -2,439.24 6,037,570.21 1,658,201.80 7.55 6,553.90 GYD-GC-SS (7) -2,525.90 6,037.565.40 1,658,115.16 9.55 6,586.23 GYD-GC-SS (7) -2,619.11 6,037,55140 1,658,022.00 468 6,61300 GYD-GC-SS(7) -2.659.00 6,037,543.74 1.657,982.13 5.99 6.62294 NOT an Actual Survey -2,711.43 6,037,531.56 1,657,929.74 5.99 6,634.08 GYD-GC-SS (7) -2,799.76 6,037,508.95 1,657,84148 0.00 6,650.98 PROJECTED to TD rival Definitive Survey Verified and Signed -off Allnym artlbrWlpoaalmob/wMws havebarn.hlore . El vas ❑ No Ilnvs chrckatln Ihs MCd my sWllry Con are roll.." dere Is mmtt O Sudaw Coommalas (] Dedrvem 8 Corrvaoence. E ORB survey Corrections C Survey Tool Codes / SLB DE Brandon Targe !/140isscl4yr. %airrs+ce Clial R."lortaim, Ben Tolman De1e WM17 5/3/2017 3, 12:57PM Page 5 COMPASS 5000.1 Build 74 THE STATE 01ALASKA GOVERNOR BILL WALKER Graham Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 3R-101 Ll Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.oloska.gov ConocoPhillips Alaska, Inc. Permit to Drill Number: 217-014 Surface Location: 1630.5' FNL, 2959.2' FEL, Sec. 9, TI 3N, R9E, UM Bottomhole Location: 994.73' FNL, 2209.67' FEL, Sec. 6, TUN, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 217-013, API No. 50-029- 23574-00-00. Production should continue to be reported as a function of the original API number stated above. 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, Cath P. Foerster Chair DATED this Wday of March, 2017. STATE OF ALASKA Ai :A OIL AND GAS CONSERVATION COMM`. ON PERMIT TO DRILL nn n nr Oc nn=. JAN 2 5 2017 AOAM, la. Type of Work: 711b. Proposed Well Class: Exploratory -Gas ❑�VService - WAG ❑ Service - Disp ❑ ❑Y 1c. Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Drill [ Lateral 0� Stratigraphic Test ❑ Development - Oil ❑✓ ' Service- Wnj ❑ Single Zone ❑ Redrill U Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas 2. Operator Name: 5. Bond: Blanket Q ' Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 3R-101 Lt 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16318' • TVD: 3485'. Kuparuk River Field West Salk Oil Pool ' 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 1630.5' FNL, 2959.2' FEL, Sec9, T13N, R9E, UM • ADL 355023, ADL355024 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 909.37' FNL, 63.55' FEL, Secs, T13N, R9E, UM 931933000/931934000 3/1/2017 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 994.73' FNL, 2209.67' FEL, Sec6, T13N, R9E, UM 3255, 1800 995' to ADL391283 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 48.9' - 15. Distance to Nearest Well Open Surface: x-520,625.98' y- 6,031,732.16' Zone -4 GL Elevation above MSL (ft): 9.9' to Same Pool: 1079'toNIKOPI2-01 16. Deviated wells: Kickoff depth: 0 feet 17. Maximum Potential Press res in psig (see 20 AAC 25.035) Maximum Hole Angle: 94.32 degrees, Downhole: 1660 ' ✓ Surface: 1289 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 20" 78.7# H-4oWelded 78' Surf Surf 117' 117' Existing 16 13-3/8" 68# L-80 HYD563 2313' Surf Surf 2351' 2200' 1193 sx 11 ppg / 235 sx 12 ppg 12.25 9-5/8" 40# L-80 HYD563 9150' Surf Surf 9188' 3615' 1605 sx 15.8 ppg Class G 4-1/2" 12.6# L-80 TXP 7438' 8880' 3604' 16318' 3485' N/A Liner 4-1/2" 12.6# L-80 TXP 9082' Surf Surf 9120' 3613' N/A Tubing 19. 01.- 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 Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis El Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 uiremenls❑✓ 21. Verbal Approval: Commission Representative: Date 1 /24/2017 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Scott Brunswick 263-4249 be deviated from without prior written approval. Contact scoff a brunswick(cDcoD.com Email Printed Name Graham (Chip) Alvord Title Alaska Drilling Manager Signature -� Phone 265-6120 Date 1 t(ZAk'(ZvlJ Commission Use Only Permit to Drill API Number: 1� Permit Approval 31 See cover letter for other requirements. Number: 0 50- 9, -eq557 - 6o-ai, Date: U10 Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other. tt��oP tr°s f � rr 5 su r� fo 3 5 LTG 75 1 c, Samples req'd: Yes N4 r5 ✓ H,S Yes No ❑ Mud log req'd: Yes ❑ NOV Directional svy req'd: Yes Ed No El %�-!'1✓1!/�Q ✓- fore t/r1.V rr f"r5 -� measures: 9,�1 Inclination Yes ❑ No -only sv req'd: Yes NOV Y y q ❑ f0 Z 5U 0 rl $-1 '1 Spacing exception req'd: L+� Post initial injection MIT req'd: Yes ❑ NOR' APPROVED BY Date: 3, _ Approved by: COMMISSIONER THE COMMISSION filSubmit Formand Form 10-401 ( evised 11/2015) Stp�risvNwrnths from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)263-4249 Email: scott.a.brunswickCdconocophiHias.com January 24, 2017 Alaska Oil and Gas Conservation Commission 333 West 7`^ Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 3R-101 Li Saved: 1 -Mar -17 ConocoPhillips Re: Application for Permit to Drill Well 311-101 Ll West Sak D Sand Multi -Lateral Producer. Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to re -drill an onshore producer well from the 3R pad. The expected spud date for this well is March 1, 2017. It is planned to use rig Doyon 142. 3R-101 is planned to be a dual lateral horizontal well in the West Sak D sand. 3R-101 (lower lateral) submitted in a separate PTD application will drill a 16" surface hole & run 13-3/8" surface casing to +/-2,35l'MD / 2,200' TVD cemented to surface. The intermediate hole section will drill a 12-1/4" hole to a depth of +/-9,188' MD / 3,615' TVD with 9-5/8" casing run & cemented in place. The 3R-101 lower lateral will be a 8-3/4" hole geo-steered to 16,313' MD / 3,502' TVD in the lower West Sak D sand package & completed with a 4-1/2" slotted liner. This PTD application package is for the upper lateral 3R-101 Ll, also an 8-3/4" hole geo-steered to 16,318' MD / 3,485' TVD in the upper West Sak D sand package & completed with a 4-1/2" slotted liner. A Baker Ram system will be run, followed by the liner & LEM with liner top packer. The liners will be tied back to surface using 4-1/2" tubing with required ESP pump area & GLM as required. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 (scott.a.brunswick(&,conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engineer Application for Permit to Drill Documcnt Kuparuk Well 3R-101 L1 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 311-101 L 1 _ Drilling -� &Wells lOnomVh�Po4 e Location Summary Reauirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each ofthe 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 slate as maintained by the National Geodetic Sun,ey in the National Oceanic and Atmospheric Administration: (C) the proposed depth oj'the well at the top ofeach objective. formation and at total depth; Location at Surface 1630.5' FNL, 2959.2' FEL, Sec 9, T 13N, R009E, UM NGS CoordinatesRKB Northings: 6,031,732.16' Eastings: 520,625.98' Elevation 48.9' AMSL Pad Elevation 9.9' AMSL Location at Surface Casing 1019.38' FNL, 3090.7' FEL, Sec 9, TUN, R009E UM NGS Coordinates Northings: 6,032,342.84' Eastings: 520,491.31' Measured De th, RKB: 2,349' TotalVerticalDe th,RKB: 2,199' Total Vertical De th, SS: 1 2,150' Location at Intermediate Casing Exit NGS Coordinates Northings: 6,037,626.09' Eastings: 510,785.18' 909.37' FNL, 63.55' FEL, Sec 5, T13N, R009E, UM NGS Coordinates Northings: 6,037,725.94' Eastings:518,210.10' Measured Depth, RKB: 8,880' TotalVertical Depth, RKB: 3,604' Total Vertical Depth, SS: 3,555' Location at Total Depth 994.73' FNL, 2209.67' FEL, Sec 6, TUN, R009E, UM NGS Coordinates Northings: 6,037,626.09' Eastings: 510,785.18' iMeasured De th, RKB: 16,318' TotalVerticalDe th,RfB: 3,485' Total Vertical Depth, SS: 3,436' and (D) other information required by 20AAC 25.050(6); Requirements of 20 AAC 25.050(b) /fa 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 200feet of any portion of the proposed well: Please see Attachment: Directional Plan And (2) far all wells within 100 feet ofthe 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. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(e)(3) An applicatiott 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 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each ofthe following items, except./or 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 potential surface pressure (MPSP) while drilling 3R-101 Ll is calculated using an estimated maximum reservoir pressure of 1,660 psi (8.6 ppg, based Kigun 1 MDT pressure at a 3708' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A3 sand at 6,220' TVD: D Sand Estimated. BHP D Sand estimated depth Gas Gradient Hydrostatic of full gas column MPSP = BHP — gas column (B) data on potential gas zones; = 1,660 psi = 3,708' TVD = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) = 371 psi (3,708' TVD * 0.10 psi/ft) =1,289 psi (1,660 psi — 371 psi) The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes ofholeproblems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; See attached 3R-101 L1 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of lbe 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 formalion integrity tests, as required under 20 AAC 25.030f; A procedure is on file with the commission for performing LOT'S. 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,(or 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 Cement Program Casing and Cementing Program Csg?bg Hole S^ Weigh Grade Conn. Length Top MD/TVD Btm MD/TVD Cement Program OD (in) 10 minute Gel t (IbM) API Filtrate < 6 (h) (ft) (h) 20 78.7 H-40 Welded 78 Surf 117/117 Existing Hydril Cement to Surface with 13-3/8 16 68 L-80 563 2,313 Surf 2,351 / 2,200 1,193 sx DeepCRETE Lead 11.0 ppg, 235 sx Dee CRETE Tail Slurry 12.0 Poo 9-5/8 12-1/4 40 L-80 Hydri5631 9,150 Surf 9,188 / 3,615 1605 sx 15.8 ppg Class G 4-1/2 8-3/4 12.6 L-80 TXP 7,193 9,120 / 3,613 16,313 / 3,502 N/A 4-1/2 8-3/4 12.6 L-80 TXP 7,518' 8,800'13,604' 16318'/ 3485' N/A 4-1/2 12.6 L-80 TXP 9082' 38'/ 38' 9120'/ 3613' 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 AAC25.035, unless this requirement is waived by the commission under 10 AAC 15, 035(h)(2); Surface hole has been drilled, BOPE will be installed. 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, ercep! 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 do/ling fluid system, as required by 20 AAC 25.033,• Mud Program Summary Production 8-3/4" Hole Mud System Flo-Thru WBM Density 9.0-9.5 PV 25-30 YP 15-20 Initial Gel 7-10 10 minute Gel 8-16 API Filtrate < 6 HTHP Fluid Loss at 160 F < 10 H 1 9.5 - 10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (e)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) do application for a Permit to Drill must be accompanied by each of'the following items, except (or an item already on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. End PTD for 3R-101 & begin PTD for 3R-101 Ll once on bottom with 8-3/4" drilling assembly. 2. Drill to landing point with motor BHA, flow check the well, & POOH. 3. PU 8-3/4" RSS BHA & TIH. (GR, Res — PeriScope) 4. Directionally drill 8-3/4" hole geosteering though the West Sak D sand to TD —16,318' MD as per directional plan & geology. 5. CBU X1 & BROOH. 6. Once BHA inside casing, circulate hole clean, flow check, & POOH on elevators. 7. Lay down Production BHA. 8. Pick up & make up hook (lug retrieving tool), string magnet, bumper sub, jars, float sub and MWD (directional only). 9. TIH 10. Break circulation & orient whipstock retrieving hook with MWD & hook the whipstock. 11. Pull whipstock free. 12. CBU X2. 13. Monitor well for flow. 14. POOH & lay down BHA & whipstock. 15. RIH & set Baker Seal Bore diverter & production anchor. 16. PU & run 4-1/2" slotted liner with Baker Oil Tools RAM hanger system. 17. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool & POOH. 18. Makeup junction isolation/ re-entry (LEM) & RIH to depth. Orient & set packer atop assembly & release from assembly. POOH. 19. Rig up & run 4-1/2" tubing & gas lift completion as required & RIH to depth. 20. Land hanger & run in lock down screws. 21. Test upper & lower seals to 250 psi & 5000 psi for 10 minutes. 22. Set BPV. 23. Monitor well for flow for 15 minutes 24. Nipple down BOPE, nipple up tree and test. 25. Pull BPV & Freeze protect well with diesel or isotherm and install BPV. 26. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Reauirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each o/'the following items, except for an item already on file with the commission and identified in the application: (14) a general description ofhow the operator plans to dispose ofdrilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080for at, 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 (IR -18 or new facilities at DSI B). All cuttings generated will be hauled 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. Attachments: Attachment 1 Well Schematic Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 1 — Proposed Well Schematic Attachment 2 — 3R-101 L1 Directional Plan Attachment 3 — 311-101 L1 Drilling Hazards Summary 8-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Levei Mitigation Strategy Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight 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 backreamin Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. n 0 0 0 0 TA Inameted Coadaaor 94 Cost., W', #, K55 x 34"03+1/2.8W@ MDn I. 133/8". 689. L80. Hydril-563 @ 2.351 WID / 2,200' TVD —� Wellhead/ Tubing Head /Tree,13-3/6"x 3R-101 Dual Lateral Producer 0.'h", 5,000 psi (W P13) Tubing String: ,: 42"126#LA0, TXP Connexions @ 457 degrees TD 16" hole A oCas Lift Mandrel, 412"x1-12" w/dummy valve ? m Gas Lift Mandrel, 412" x 1-12" w/ SOV (XX deg) R O J Downhole Gauge- Discharge and Intake Back up Conventional ESP- wireline radevable pump/ Whin, conveyed motor. Set@ ),)00'MD, 3,483TVD, -80deg Baker SIMP Packer sa@-8.80DWID, 3603'TVD-87.9de,- $3��1' VT r— Top of West SekD Ll Window Top@8,880'MD/3,604'TVD-88de8 412", 12.6q LB0, TNT, $loved Liner .b 'D sand lateral TO16,318'rom/ength TVD W a 6 (r46,62g'MD /3,603'TVD .• Leve1-3 ML ]unction Sys¢m •••`• 7,343', fl larval length e Iamal Bob, Module POS -1 Sealbore Diveaer (SHD)PDS- 1 ___________ ________________________ �••__________________n____=_________________________ Tsbing Said Assembly ..... ............. YF.JrL-.........................---------------------------------- Oil -&- --Z- Tracer Carvidge yJ. ' x 3.562" Landing nipple profile /4%sa dtaal 6 MLI -0t Prod Anchor �� 41/2",12.6# L80, TXP, Stored Liner `. TD 16, 3'MD/3,502'TVD `'dam MLZ3(P Packer for main bore �- _____________ ),125'RLeteallaugh � ' 9-5/,', 4ol1, LBO, HYdri1563 _______________________________________________ ' ___________________________v== @9.188'MD/2-1/4 TVD � ................................................... TD 12-t/4' hole -'"-" "�""-" Oil &Water Tracer Cartridge .......................' Attachment 2 — 3R-101 Ll Directional Plan 3R-101 L1 Wp13 4 i1 x 6314' Summary ....................................... Checked by °� �. N. Reck B sa+om rz+monm A+TLI I4+PM1Is yNo+u 1L+0+0+15a Pu+o1L+i5+PNf� 1 Wt0+L+3+MM15a 6 9M1+OM1+P1NM�a6 +OM +MOn Se ..7 se 57 ffi sa+ovna mmnse n}h+Ort+i+t +a+01i50 [aR I0.�Otl i12 O+P0oI9 Ac,pted by: E. Stark — Approved 0 9518'x12.26' I 0 6000 4000 2000 10000 Measured De lh Geodetic Datum: 4e.90usit (Doyon142) DWh Refere 9., Doyon 142.9 4-112" x 6-314' 0 sew c Big — 9070 m 0 5070 — sew G3200 13808 1j400 30 9250 — sbsD — • 11400 12900 12600 330 Y ' 9450 9e40 9600 10200 108091 Horizontal Departure 9640 -- 9920 9W0 "� 9wo 60 lomo "i"V III . r' LL 300 two0 to 104W tar 107W .q 60 - tow _ fl y 1i 3P-tOtwpl3 11250 — t1 w— n] no11450 n50 — u9 c ry 950 2 1--3 30 10 6 120 12]2o 1 d 13230 137 16500 13150 142 0 13500 15000 14250 "– u 12000 10500 Suft, Localion ts0 tow 162 9000+ SUPVEV PROGRAM woo I Y: 210 1 1ww - 1 Tool GVD-GC-SS East/X: Pad Elevalmn: 9.90 160 low, �' teal, pth From Dept h To SurveylPlan 38101) -t MWoaiFR-AK-CAZSC SING DETAILS T 39.00 950.00 2350.0 3R 0i,sp12(Plan: MWptIFR-AK-W-SC 3R-1Otxp12 (Plan:3R-101) INC«TPEND MD Name Magnnic Moeel: BGGM2016 Dale: 25Na+n 950.00 2350.00 8880.00 8895.0 3&10,w,ip 3IP1asl ¢3R-1011-1) MWD 3R4p1L1wp ( .388011-1) MWD TVD 9518"x12.25' 3604.34 8881.00 41IY x6-314" µ�pnatic Model Magne9c 0ed9a1ian: tZ]4° to arae O.mcfgn. Add P.]4•Ean 13080.0 9245.00 3R-101Lhvpl3(Plan. 3R -101L1) 3485.30 1631].49 To convene MaOneec DinxLun 8895.00 8845.00 10]45.00 3R-101Ltwp13(PIan: 3R-101`-' p,(Plan: 38-1011-1) MWD+IFR-AK-So-SC 9245.00 1831].49 ....................................... Checked by °� �. N. Reck B sa+om rz+monm A+TLI I4+PM1Is yNo+u 1L+0+0+15a Pu+o1L+i5+PNf� 1 Wt0+L+3+MM15a 6 9M1+OM1+P1NM�a6 +OM +MOn Se ..7 se 57 ffi sa+ovna mmnse n}h+Ort+i+t +a+01i50 [aR I0.�Otl i12 O+P0oI9 Ac,pted by: E. Stark — Approved 0 Spider View casung (ww usTmn) -10 PT 2A -20 -21 Plan View L 1500 313-101 L1 wp13 Plan View O O O O O O O O O O O O O O O LO co — - I O -10500 -9000 -7500 -6000 -4500 -3000 West( -)/East(+) (1500 usff/in) -1500 0 1500 Section View 3R-101 L1 wp13 Section View -1500- 1500 0 0- ------ ------ 01017 S CnD 00 20" x 42" 0 1000 LO 01017 S = 1500 13-3/8" x 16" JT12 ami �®60_--��""- S9 �1017 5/8" x 12.25" 4-1/2'x 6-3/4" 3000 00 B .00 COCO rn oa- ao 01017 rn Ca C:, 0 0\ o ; o o o C', o p o. o 0 4500 r - ' w 6000 3R-1011 T 1101017 S 3R-101 Li T3 101017 S 3R-101 L1 T5 101017 S 3R-101 L1 T7 101017 S 3R-101 Li T9 101017 S 3R-101 L1 T KOP 101017 3R-101 L1 T2 101017 S 3R-101 Li T4 101017 S 3R-101 L1 T6 101017 S 3R-101 L1 T8 101017 S 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 270.000 (1500 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-101 Plan: 3R-101 L1 Plan: 3R-101L1wp13 Report 24 January, 2017 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 3R-101 Project: Kuparuk River Unit TVD Reference: Plan: 39+9.9 @ 48.90usft Doyon -142) Site: Kuparuk 3R Pad MD Reference: Plan: 39+9,9 @ 48.90usft (Doyon142) Well: Plan: 3R-101 North Reference: Tree Wellbore: Plan: 3R-101 -I Survey Calculation Method: Minimum Curvature Design: 3R-101L1wp13 Database: OAKEDMP2 Project Kupamk River Unit, North Slope Alaska, United States MWD+IFR-AK-CAZ-SC Map System: System Datum: Mean Sea Level Geo Datum: MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Using Well Reference Point Map Zone: 8,895.003R-101L1wp13(Plan: 3R-1011-1) Using geodetic scale factor Site Kuperuk 3R Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.16 ° Well Plan: 3R-101 Audit Notes: Well Position +NAS 0.00 usft Northing: Latitude: PROTOTYPE +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty Description 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore Plan: 3R-101 -1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1 (0) BGGM2016 3/25/2017 17.74 81.04 57,551 Design 3R-101 L1wpl3 Audit Notes: From To Version: Phase: PROTOTYPE Tie On Depth: 8,880.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction Description (usft) (usft) (usft) (I 39.00 0.00 0.00 270.00 Survey Tool Program Date 1/24/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 950.00 3R-101wp12 (Plan: 3R-101) GYD-GC-SS Gyrodata gyro single shots 950.00 2,350.00 3R-101wpl2(Plan: 3R-101) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2,350.00 8,880.00 3R-101wp12(Plan: 3R-101) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,880.00 8,895.003R-101L1wp13(Plan: 3R-1011-1) INC+TREND Inclinometer + known azi trend 8,895.00 9,245.00 3R-101L1wp13(Plan: 3R-10111) MWD MWD -Standard 9,245.00 10,745.00 3R-101 L1wpl 3(Plan: 3R-101 L1) MWD MWD -Standard 9,245.00 16,317.49 3R-101L1wp13(Plan: 3R-10111) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC. Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Let Error (usft) (I (I (usft) (usft) ('1100usft) V) (usft) 8,880.00 88.00 270.16 3,604.31 3,555.41 0.00 0.00 13.10 KOP: 13.56°/100' DLS, -20° TF, for 16.6' 8,681.00 88.13 270.11 3,604.34 3,555.44 13.56 -20.00 12.83 9 6/8" x 12.26" 8,898.50 90.10 269.39 3,604.58 3,555.66 13.56 -20.00 12.83 Hold for 20' 8,900.00 90.10 269.39 3,604.57 3,555.67 0.00 0.00 12.86 1242017 6:27:54AM Page 2 COMPASS 5000.1 Build 74 Report Company: ConocrPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-1011-1 Survey Calculation Method: Design: 3R-101L1vtp13 Database: Well Plan: 3R-101 Plan: 39+9,9 @ 48.90usft (Doyon -142) Plan: 39+9,9 @ 48,90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°I (°) Wait) (usft) (°/100usft) (°) Nall) 8,916.50 90.10 269.39 3,604.54 3,555.64 0.00 0.00 12.98 Start 3.6°/100' DLS, -76.93° TF, for 101.37' 9,000.00 90.76 266.54 3,603.91 3,555.01 3.50 -76.93 12.29 9,017.87 90.90 265.93 3,603.65 3,554.75 3.50 -76.95 12.16 Hold for 460.96' 9,100.00 90.90 265.93 3,602.36 3,553.46 0.00 -76.96 12.98 9,200.00 90.90 265.93 3,600.78 3,551.88 0.00 0.00 14.11 9,300.00 90.90 265.93 3,599.20 3,550.30 0.00 0.00 15.16 9,400.00 90.90 265.93 3,597.62 3,548.72 0.00 0.00 16.15 9,478.83 90.90 265.93 3,596.38 3,547.48 0.00 0.00 17.00 Start 0.5.1100' DLS, 114.82' TF, for 168.67' 9,500.00 90.86 266.03 3,596.05 3,547.15 0.50 114.82 17.29 9,600.00 90.65 266.48 3,594.74 3,545.84 0.50 114.82 18.67 9,647.49 90.55 266.70 3,594.24 3,545.34 0.50 114.83 19.35 Adjust TF to 110.090, for 98.62' 9,700.00 90.46 266.95 3,593.78 3,544.88 0.50 110.09 20.12 9,746.11 90.38 267.16 3,593.44 3,544.54 0.50 110.09 20.82 Hold for 778.19' 9,800.00 90.38 267.16 3,593.08 3,544.18 0.00 110.10 21.53 9,900.00 90.38 267.16 3,592.42 3,543.52 0.00 0.00 22.88 10,000.00 90.38 267.16 3,591.75 3,542.65 0.00 0.00 24.28 10,100.00 90.38 267.16 3,591.09 3,542.19 0.00 0.00 25.72 10,200.00 90.38 267.16 3,590.42 3,541.52 0.00 0.00 27.18 10,300.00 90.38 267.16 3,589.76 3,540.86 0.00 0.00 28.68 10,400.00 90.38 267.16 3,589.10 3,540.20 0.00 0.00 30.19 10,500.00 90.38 267.16 3,588.43 3,539.53 0.00 0.00 31.72 10,524.31 90.38 267.16 3,588.27 3,539.37 0.00 0.00 32.10 Start 2.6°1100' DLS, 40.43° TF, for 100.89' 10,600.00 91.82 268.39 3,586.82 3,537.92 2.50 40.43 33.74 10,625.20 92.30 268.80 3,585.91 3,537.01 2.50 40.46 34.28 Adjust TF to 38.340, for 103.21' 10,700.00 93.77 269.96 3,581.95 3,533.05 2.50 38.34 35.87 10,728.41 94.32 270.41 3,579.95 3,531.05 2.50 38.41 36.48 Hold for 206.1' 10,800.00 94.32 270.41 3,574.55 3,525.65 0.00 0.00 22.24 10,900.00 94.32 270.41 3,567.02 3,518.12 0.00 0.00 22.67 10,933.51 94.32 270.41 3,564.49 3,515.59 0.00 0.00 22.82 Start 2.6°1100' DLS, 468.5° TF, for 49.9- 10,983.41 93.10 270.16 3,561.26 3,512.36 2.50 -168.50 22.92 Adjust TF to -180°, for 61.42' 11,000.00 92.69 270.16 3,560.42 3,511.52 2.50 -180.00 22.99 11,034.83 91.81 270.16 3,559.06 3,510.16 2.50 180.00 23.14 Hold for 541.07' 11,100.00 91.81 270.16 3,556.99 3,508.09 0.00 180.00 23.42 11,200.00 91.81 270.16 3,553.82 3,504.92 0.00 0.00 23.87 11,300.00 91.81 270.16 3,550.66 3,501.76 0.00 0.00 24.33 1242017 8:27:54AM Page 3 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-10111 Survey Calculation Method: Design: 3R-101Liwpl3 Database: Well Plan: 3R-101 Pian: 39+9.9 Q 48.90usft (Doyonl42) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Let Error (usft) (1) (°) (usft) (usft) (°1100usft) (') (usft) 11,400.00 91.81 270.16 3,547.49 3,498.59 0.00 0.00 24.79 11,500.00 91.81 270.16 3,544.32 3,495.42 0.00 0.00 25.26 11,575.90 91.81 270.16 3,541.92 3,493.02 0.00 0.00 25.62 Start 2.5°/100' DLS, 180° TF, for 72.58' 11,600.00 91.21 270.16 3,541.28 3,492.38 2.50 180.00 25.73 11,648.48 90.00 270.16 3,540.77 3,491.87 2.50 -180.00 25.95 Adjust TF to 180°, for 61.47' 11,700.00 88.71 270.16 3,541.35 3,492.45 2.50 180.00 26.18 11,709.94 88.46 270.16 3,541.59 3,492.69 2.50 180.00 26.22 Hold for 383.54' 11,800.00 88.46 270.16 3,544.01 3,495.11 0.00 -180.00 26.64 11,900.00 88.46 270.16 3,546.69 3,497.79 0.00 0.00 27.13 12,000.00 88.46 270.16 3,549.37 3,500.47 0.00 0.00 27.62 12,093.48 88.46 270.16 3,551.88 3,502.98 0.00 0.00 28.07 Start 0.6'/100' DLS, 0' TF, for 27.34' 12,100.00 88.50 270.16 3,552.05 3,503.15 0.50 0.00 28.11 12,120.82 88.60 270.16 3,552.58 3,503.68 0.50 0.00 28.21 Adjust TF to 0°, for 19.98' 12,140.79 88.70 270.16 3,553.05 3,504.15 0.50 0.00 28.31 Hold for 480.64' 12,200.00 88.70 270.16 3,554.39 3,505.49 0.00 0.00 28.60 12,300.00 88.70 270.16 3,556.66 3,507.76 0.00 0.00 29.10 12,400.00 88.70 270.16 3,558.93 3,510.03 0.00 0.00 29.60 12,500.00 88.70 270.16 3,561.20 3,512.30 0.00 0.00 30.11 12,600.00 88.70 270.16 3,563.47 3,514.57 0.00 0.00 30.62 12,621.43 88.70 270.16 3,563.96 3,515.06 0.00 0.00 30.73 Start 1.6.1100' DLS, 0° TF, for 46.67' 12,668.11 89.40 270.16 3,564.73 3,515.83 1.50 0.00 30.97 Adjust TF to 0°, for 6829' 12,700.00 69.88 270.16 3,564.93 3,516.03 1.50 0.00 31.13 12,726.40 90.27 270.16 3,564.90 3,516.00 1.50 0.00 31.27 Hold for 514.62' 12,800.00 90.27 270.16 3,564.54 3,515.64 0.00 0.00 31.64 12,900.00 9027 270.16 3,564.06 3,515.16 0.00 0.00 32.16 13,000.00 90.27 270.16 3,563.59 3,514.69 0.00 0.00 32.68 13,100.00 90.27 270.16 3,563.11 3,514.21 0.00 0.00 33.20 13,200.00 90.27 270.16 3,562.63 3,513.73 0.00 0.00 33.73 13,241.02 90.27 270.16 3,562.43 3,513.53 0.00 0.00 33.94 Start 0.5°/100' DLS, 180° TF, for 54.87' 13,295.89 90.00 270.16 3,562.30 3,513.40 0.50 180.00 34.22 Adjust TF to 180°, for 19.76' 13,300.00 89.98 270.16 3,562.30 3,513.40 0.50 -180.00 34.24 13,315.65 89.90 270.16 3,562.32 3,513.42 0.50 180.00 34.32 Hold for 385.31' 13,400.00 89.90 270.16 3,562.46 3,513.56 0.00 0.00 34.75 13,500.00 89.90 270.16 3,562.63 3,513.73 0.00 0.00 35.28 124/2017 8:27..*54AM Page 4 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 31R-1011-1 Survey Calculation Method: Design: 3R-10111wp13 Database: Well Plan: 3R-101 Plan: 39+9,9 @ 48,90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLe9 TFace Let Error (usft) V) (°) (usft) (usft) (°1100usft) (°) (usft) 13,600.00 69.90 270.16 3,562.81 3,513.91 0.00 0.00 35.81 13,700.00 89.90 270.16 3,562.98 3,514.08 0.00 0.00 36.34 13,700.96 89.90 270.16 3,562.98 3,514.08 0.00 0.00 36.34 Start 1°/100' DLS, 0° TF, for 9.88' 13,710.84 90.00 270.16 3,562.99 3,514.09 1.00 0.00 36.40 Adjust TF to 0°, for 72.57' 13,783.41 90.73 270.16 3,562.53 3,513.63 1.00 0.00 36.79 Hold for 413.94' 13,800.00 90.73 270.16 3,562.32 3,513.42 0.00 0.00 36.88 13,900.00 90.73 270.16 3,561.05 3,512.15 0.00 0.00 37.41 14,000.00 90.73 270.16 3,559.79 3,510.89 0.00 0.00 37.95 14,100.00 90.73 270.16 3,558.52 3,509.62 0.00 0.00 38.49 14,197.35 90.73 270.16 3,557.29 3,508.39 0.00 0.00 39.02 Start 0.6°/100' DLS, 0° TF, for 14.87' 14,200.00 90.74 270.16 3,557.25 3,508.35 0.50 0.00 39.03 14,212.22 90.80 270.16 3,557.09 3,508.19 0.50 0.00 39.10 Adjust TF to 0°, for 21.62' 14,233.84 90.91 270.16 3,556.77 3,507.87 0.50 0.00 39.22 Hold for 461.96' 14,300.00 90.91 270.16 3,555.72 3,506.82 0.00 0.00 39.58 14,400.00 90.91 270.16 3,554.13 3,505.23 0.00 0.00 40.12 14,500.00 90.91 270.16 3,552.55 3,503.65 0.00 0.00 40.67 14,600.00 90.91 270.16 3,550.96 3,502.06 0.00 0.00 41.21 14,695.80 90.91 270.16 3,549.45 3,500.55 0.00 0.00 41.74 Start 1°/100' DLS, 0° TF, for 19.19' 14,700.00 90.95 270.16 3,549.38 3,500.48 1.00 0.00 41.76 14,714.99 91.10 270.16 3,549.11 3,500.21 1.00 0.00 41.84 Adjust TF to 0°, for 26.62' 14,740.51 91.35 270.16 3,548.56 3,499.66 0.98 0.00 41.98 Hold for 280.28' 14,800.00 91.35 270.16 3,547.16 3,498.26 0.00 0.00 42.31 14,900.00 91.35 270.16 3,544.81 3,495.91 0.00 0.00 42.86 15,000.00 91.35 270.16 3,542.45 3,493.55 0.00 0.00 43.41 15,020.79 91.35 270.16 3,541.96 3,493.06 0.00 0.00 43.52 Start 1°/100' DLS, 0° TF, for 64.48' 15,085.27 92.00 270.16 3,540.08 3,491.18 1.01 0.00 43.66 Adjust TF to 0°, for 66.07' 15,100.00 92.15 270.16 3,539.55 3,490.65 1.00 0.00 43.96 15,151.34 92.66 270.16 3,537.39 3,488.49 1.00 0.00 44.24 Hold for 332.24' 15,200.00 92.66 270.16 3,535.13 3,486.23 0.00 0.00 44.51 15,300.00 92.66 270.16 3,530.49 3,481.59 0.00 0.00 45.07 15,400.00 92.66 270.16 3,525.85 3,476.95 0.00 0.00 45.62 15,483.58 92.66 270.16 3,521.97 3,473.07 0.00 0.00 46.09 Start 1°/100' DLS, 180° TF, for 14.16' 12412017 8:27:54AM Page 5 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupamk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R -101L1 Survey Calculation Method: Design: 3R-101Ltwp13 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Let Error (usft) (°) (°) (usft) (usft) (°1100use) (°) (usft) 15,497.75 92.52 270.16 3,521.33 3,472.43 1.00 180.00 46.16 Hold for 819.74' 15,500.00 92.52 270.16 3,521.23 3,472.33 0.00 0.00 46.17 15,600.00 92.52 270.16 3,516.64 3,467.94 0.00 0.00 46.73 15,700.00 92.52 270.16 3,512.44 3,463.54 0.00 0.00 47.29 15,800.00 92.52 270.16 3,508.05 3,459.15 0.00 0.00 47.84 15,900.00 92.52 270.16 3,503.65 3,454.75 0.00 0.00 48.40 16,000.00 92.52 270.16 3,499.25 3,450.35 0.00 0.00 48.96 16,100.00 92.52 270.16 3,494.86 3,445.96 0.00 0.00 49.52 16,200.00 92.52 270.16 3,490.46 3,441.56 0.00 0.00 50.08 16,300.00 92.52 270.16 3,486.07 3,437.17 0.00 0.00 50.64 16,317.49 92.52 270.16 3,485.30 3,436.40 0.00 0.00 50.74 TD: 16317.49' MD, 3485.3' TVD -4-112" x 64/4" 124/2017 8:27:54AM Page 6 COMPASS 5000.1 Build 74 Company: ConomPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit She: Kupamk 3R Pad Well: Plan: 3R-101 Wellbore: Plan: 3R -101L1 Design: 3R-101Ltwpl3 Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (usft) (usft) 8,881.00 3,604.34 9 518" x 12.25" 9-5/8 12-1/4 16,317.49 3,485.30 4-1/2"x6-3/4" 4-1/2 6-3/4 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 8,880.00 3,604.31 6,000.92 -2,394.19 KOP: 13.56'/100' DLS, -20" TF, for 16.5' 8,896.50 3,604.58 6,000.86 -2,410.69 Hold for 20' 8,916.50 3,604.54 6,000.65 -2,430.69 Start 3.5"/100' DLS, -76.93° TF, for 101.37' 9,017.87 3,603.65 5,996.51 -2,531.95 Hold for 460.96' 9,478.83 3,596.38 5,963.84 -2,991.70 Start 0.5"/100' DLS, 114.82° TF, for 168.67- 9,647.49 3,594.24 5,953.01 -3,159.99 Adjust TF to 110.09-, for 98.62' 9,746.11 3,593.44 5,947.73 -3,258.47 Hold for 778.19' 10,524.31 3,588.27 5,909.21 4,035.70 Start 2.5°/100' DLS, 40.43° TF, for 100.89' 10,625.20 3,585.91 5,905.66 4,136.49 Adjust TF to 38.34-, for 103.21' 10,728.41 3,579.95 5,904.94 -4,239.51 Hold for 205.V 10,933.51 3,564.49 5,906.39 -4,444.03 Start 2.5°/100'DLS, -168.5°TIF, for 49.9' 10,983.41 3,561.26 5,906.63 4,493.82 Adjust TF to -180-, for 51.42- 11,034.83 3,559.06 5,906.77 4,545.19 Hold for 541.07' 11,575.90 3,541.92 5,908.25 -5,085.99 Start 2.5°/100' DLS, 180° TF, for 72.58- 111,648A8 3,540.77 5,908.44 -5,158.56 Adjust TF to 180% for 61.47- 11,709.94 3,541.59 5,908.61 -5,220.01 Hold for 383.54' 12,093.48 3,551.88 5,909.65 -5,603.41 Start 0.5°/100' DLS, 0° TF, for 27.34' 12,120.82 3,552.58 5,909.73 -5,630.74 Adjust TF to 0°, for 19.98- 12,140.79 3,553.05 5,909.78 -5,650.70 Hold for 480.64' 12,621.43 3,563.96 5,911.09 -6,131.22 Start 1.5°/100' DLS, 0° TF, for46.67' 12,668.11 3,564.73 5,911.22 -6,177.89 Adjust TF to 0*, for 58.29' 12,726.40 3,564.90 5,911.38 -6,236.18 Hold for 514.62' 13,241.02 3,562.43 5,912.78 -6,750.79 Start 0.5°/100' DLS, 180° TF, for 54.87' 13,295.89 3,562.30 5,912.93 -6,805.66 Adjust TF to 180°, for 19.76' 13,315.65 3,562.32 5,912.98 -6,825.42 Hold for 385.31' 13,700.96 3,562.98 5,914.03 -7,210.73 Start 1°/100' DLS, 0° TF, for 9.88' 13,710.84 3,552.99 5,914.06 -7,220.61 Adjust TF to 0`, for 72.57' 13,783.41 3,562.53 5,914.26 -7,293.18 Hold for 413.94' 14,197.35 3,557.29 5,915.38 -7,707.08 Start 0.5°/100' DLS, 0° TF, for 14.87- 14,212.22 3,557.09 5,915.42 -7,721.95 Adjust TF to 0-, for 21.62' 14,233.84 3,556.77 5,915.48 -7,743.57 Hold for 461.96' 14,695.80 3,549.45 5,916.74 -8,205.47 Start 1°/100' DLS, 0- TF, for 19.19' 14,714.99 3,549.11 5,916.79 -8,224.66 Adjust TF to O", for 25.52- 14,740.51 3,548.56 5,916.86 -8,250.77 Hold for 280.28' 15,020.79 3,541.96 5,917.63 -8,530.37 Start 1°/100' DLS, 0 -TF, for 64.48' 15,085.27 3,540.08 5,917.80 -8,594.82 Adjust TF to V. for 66.07' 15,151.34 3,537.39 5,917.98 -8,660.84 Hold for 332.24' 15,483.58 3,521.97 5,918.88 -8,992.72 Start 1°/100' DLS, 180° TF, for 14.16' 15,497.75 3,521.33 5,918.92 -9,006.87 Hold for 819.74' 76,317.49 3,485.30 5,921.15 -9,825.82 TD: 16317.49' MD, 3485.3' TVD Checked By: Approved By: Date: 1242017 8:27:54AM Page 7 COMPASS 5000.1 Build 74 AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-101 Plan: 3R-1011-1 50103xxxxx00 3R-1011-1wp13 Clearance Summary Anticollision Report 24 January, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R -101 -Plan: 3R-101L1-3R-101L1wp13 Well Coordinates: 6,031,484.21 N, 1,660,657.38 E (70° 29' 51.23" N, 149° 50' 04.10" W) Datum Height: Plan: 39+9.9@ 48.90usft(Doyon142) Scan Range: 8,880.00 to 16,317.49 usft. Measured Depth. Scan Radius is 1,827.65 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Anticollision Report for Plan: 3R-101 - 3R-101 L1wp13 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-101 - Plan: 3R-1011_1 - 3R-101 L1wp13 Scan Range: 8,880.00 to 16,317.49 usft. Measured Depth. Scan Radius is 1,827.85 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name - Design Kuparuk 3R Pad Plan: 3R-101 - Plan: 3R-101 - 3R-101wp13 Plan: 3R-102 - Plan: 3R-102 - 3R-102wp09 Plan: 3R-102 -Plan: 3R-102 - 3R-102wp09 Oliktok Point Measured Minimum @Measuretl Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum (usft) (usft) (usft) (usft) usft 10,709.43 1,149.18 10,709.43 942.74 8,925.00 5.567 Centre Distance 13,983.03 1,155.10 13,983.03 920.95 12,200.00 4.933 Clearance Factor Separation Warning Pass - Major Risk Pass - Major Risk 0107-04 - 0107-04 - 0107-04 9,448.59 345.63 9,448.59 248.36 3,900.00 3.553 Centre Distance Pass - Major Risk 0107-04 - 0107-04 - 0107-04 9,441.89 346.04 9,441.89 247.16 3,925.00 3.500 Clearance Factor Pass - Major Risk 0111-01 - 0111-01 - 0111-01 10,954.86 911.75 10,954.86 812.09 3,375.00 9.149 Centre Distance Pass - Major Risk 0111-01 - 0111-01 - 0111-01 10,959.53 912.21 10,959.53 811.61 3,400.00 9.068 Clearance Factor Pass - Major Risk 011 MI -0111-01 PB1- Oil 1-01 PB7 10,954.86 911.75 10,954.86 811.88 3,375.00 9.130 Centre Distance Pass - Major Risk 0111-01-0111-01 PBI -0111-01 PBI 10,959.53 912.21 10,959.53 811.40 3,400.00 9.048 Clearance Factor Pass - Major Risk 0115-54-0115-S4-0115-54 11,496.39 879.01 11,496.39 781.15 3,450.00 8.983 Centre Distance Pass - Major Risk 0115 -S4 -0115 -S4 -0115-S4 11,514.86 860.26 11,514.86 779.84 3,500.00 8.766 Clearance Factor Pass - Major Risk 0120-07 - 0120-07 - 0120-07 16,301.90 820.52 16,301.90 158.58 7,375.00 1.240 Clearance Factor Pass - Major Risk 0120-07-O120.07P81-0120-07PBI 16,301.90 820.52 16,301.90 158.42 7,375.00 1.239 Clearance Factor Pass - Major Risk 0120-07 - 0120-07PB2 - 0120-07PB2 16,301.90 820.52 16,301.90 158.58 7,375.00 1.240 Clearance Factor Pass -Major Risk 0124-08 - 0124-08 - 0124-08 15,695.29 259.81 15,695.29 96.30 7,050.00 1.589 Centre Distance Pass - Major Risk 0124-08 - 0124-08 - 0124-08 15,902.80 274.79 15,902.80 70.07 7,275.00 1.342 Clearance Factor Pass - Major Risk Oliktok Point 1-1 - Oliktok Point 1-1 - Oliktok Point 1-1 8,953.70 1,545.14 8,953.70 1,459.55 2,875.00 18.054 Clearance Factor Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2 - Oliktok Point 1-2 12,867.50 889.02 12,867.50 753.89 4,500.00 6.579 Centre Distance Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2 - Oliktok Point 1-2 12,981.02 893.46 12,981.02 749.48 4,650.00 6.205 Clearance Factor Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2PB1 - Oliktok Point 1 12,949.41 902.66 12,949.41 759.99 4,600.00 6.327 Centre Distance Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2PB1 - Oliktok Point 1 12,987.38 904.15 12,987.38 758.33 4,650.00 6.201 Clearance Factor Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2PB2 - Olidok Point 1 12,867.50 889.02 12,867.50 753.89 4,500.00 6.579 Centre Distance Pass - Major Risk Oliktok Point 1-2 - Oliktok Point 1-2PB2 - Oliktok Point 1 12,981.02 893.46 12,981.02 749.48 4,650.00 6.205 Clearance Factor Pass - Major Risk OP03-P05-OP03-P05-OP03-P05 8,913.37 1,080.90 8,913.37 995.35 3,375.00 12.634 Clearance Factor Pass - Major Risk OP03-P05-OP03-P05L1-OP03-P05L1 8,913.37 1,080.90 8,913.37 995.03 3,375.00 12.587 Clearance Factor Pass - Major Risk OP03-PO5 - OP03-PO5PB1 - OP03-POSP61 8,913.37 1,080.90 8,913.37 995.03 3,375.00 12.587 Clearance Factor Pass - Major Risk 24 January, 2017 - 8:20 Page 2 of COMPASS Anticollision Report for Plan: 311-101 - 3R-1 O1 L1wp13 7ray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R -101 -Plan: 3R-1011-1.3R-101L1wp13 Scan Range: 8,880.00 to 16,317.49 usft. Measured Depth. Scan Radius is 1,827.85 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft OP03-P05-OP03-P05PB2-OP03-P05PB2 8,913.37 1,080.90 8,913.37 995.14 3,375.00 12.603 Clearance Factor Pass - Major Risk OP05-06 - OP05-06 - OP05-06 8,987.87 1,512.62 8,987.87 1,423.44 3,150.00 16.960 Clearance Factor Pass - Major Risk OP05-06 - OP05-061-1 - OPOS-06LI 8,987.87 1,512.62 8,987.87 1,423.36 3,150.00 16.946 Clearance Factor Pass - Major Risk OP05-06-OP05-06PB1-OP05-06PB1 8,987.87 1,512.62 8,987.87 1,423.33 3,150.00 16.940 Clearance Factor _ Pass - Major Risk OP05-06-OP05-06PB2-OP05-06PB2 8,987.87 1,512.62 8,987.87 1,423.44 3,150.00 16.960 Clearance Factor Pass - Major Risk OPOB-04 - OP08-04 - OP08-04 10,448.42 593.63 10,448.42 475.37 3,575.00 5.020 Centre Distance Pass - Major Risk OP08-04 - OP08-04 - OP08-04 10,447.58 595.11 10,447.58 474.87 3,600.00 4.950 Clearance Factor Pass - Major Risk OP08-04 - OP08-04L1 - OP08-0411 10,448.42 593.63 10,448.42 475.37 3,575.00 5.020 Centre Distance Pass - Major Risk OPOB-04-OP08-04L1-OP08-0411 10,447.58 595.11 10,447.58 474.87 3,600.00 4.950 Clearance Factor Pass - Major Risk OPOB-04 - OP08-0411 PB1 - OP08-041-1 PBI 10,448.42 593.63 10,448.42 475.37 3,575.00 5.020 Centre Distance Pass - Major Risk OP08-04-OP08-041-1PB1-OP08-04L1 PB1 10,447.58 595.11 10,447.58 474.87 3,600.00 4.950 Clearance Factor Pass - Major Risk OP0B-04-OP08-04PBI-OP08-04PS1 10,448.42 593.63 10,448.42 475.37 3,575.00 5.020 Centre Distance Pass - Major Risk OPOB-04 - OP08-04PB1 - OP08-04PB1 10,447.58 595.11 10,447.58 474.87 3,600.00 4.950 Clearance Factor Pass- Major Risk OP09-S01-OP09-S01-OP09-S01 10,233.71 1,031.15 10,233.71 936.89 3,200.00 10.939 Centre Distance Pass - Major Risk OP09-S01 - 0P09 -S01 - OP09-S01 10,230.72 1,031.64 10,230.72 936.34 3,225.00 10.825 Clearance Factor Pass - Major Risk OP09-S01-OP09-301 L7-OP09-SO1 L7 10,233.71 1,031.15 10,233.71 936.89 3,200.00 10.939 Centre Distance Pass - Major Risk OP09-S01-OP09S01 L1-OP09-801 LI 10,230.72 1,031.64 10,230.72 936.33 3,225.00 10.825 Clearance Factor Pass - Major Risk OP09-S01-OP09-S01 L1 PBI -OP09-S01LIPB1 10,233.71 1,031.15 10,233.71 936.89 3,200.00 10.939 Centre Distance Pass - Major Risk OP09-S01-OP09-S01L1PB1-OP09-SOIL1PB1 10,230.72 1,031.64 10,230.72 936.33 3,225.00 10.825 Clearance Factor Pass - Major Risk Opt 0-09- Opt 0 -09 -Opt 0-09 11,028.36 1,134.31 11,028.36 1,034.04 3,175.00 11.313 Centre Distance Pass - Major Risk OPIO-09 - OP10-09 - OP10-09 11,053.67 1,135.57 11,053.67 1,033.49 3,225.00 11.125 Clearance Factor Pass - Major Risk OP10-09-Opt 0-091-1-OP10-09LI 11,028.36 1,134.31 11,028.36 1,034.04 3,175.00 11.313 Centre Distance Pass - Major Risk OP10-09-OP70-09LI-OP10-0911 11,053.67 1,135.57 11,053.67 1,033.49 3,225.00 11.125 Clearance Factor Pass - Major Risk OP12-01 - OP12-02 - OP12-02 11,404.93 799.70 11,404.93 672.20 3,700.00 6.272 Centre Distance Pass - Major Risk Opt 2-01-OP12-02-OP12-02 11,421.49 801.24 11,421.49 670.41 3,750.00 6.124 Clearance Factor Pass - Major Risk OP16-03-OP16-03- Opt 6-03 16,304.95 387.69 16,304.95 241.32 7,700.00 2.649 Clearance Factor Pass - Major Risk OP16-03-OP16-0311-OP16-03LI 16,304.23 387.74 16,304.23 241.35 7,700.00 2.649 Clearance Factor Pass - Major Risk OP16-03-OP16-03LIP61-OP16-03L1PB1 16,304.23 387.74 16,304.23 241.57 7,700.00 2.653 Clearance Factor Pass - Major Risk OP17-02 - OP1 7-02 - OP1 7-02 14,004.97 363.49 14,004.97 236.59 5,850.00 2.864 Centre Distance Pass -Major Risk OP17-02- Opt 7-02- Opt 7-02 14,205.80 378.78 14,205.80 223.49 6,075.00 2.439 Clearance Factor Pass - Major Risk 24 January, 2017 - 8:20 Page 3 of COMPASS Anticollision Report for Plan: 3R-101 - 3R-1 O1 L1wp13 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3R Pad - Plan: 3R-101 - Plan: 3R-1011-1 - 3R-101L1Wp13 Scan Range: 8,880.00 to 16,317.49 usft. Measured Depth. Scan Radius is 1,827.85 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 39.00 Comparison Well Name - Wellbore Name - Design Depth (usft) Distance Depth Separation Depth Factor Minimum Separation Warning MWD+IFR-AK-CAZSC (usft) (usft) (usft) usft 8,895.00 9,245.00 3R-101L1wpi3 OP1 7-02 - OP1 7-02PB1 - OP1 7-02PBI 14,004.97 363.49 14,004.97 236.46 5,850.00 2.861 Centre Distance Pass - Major Risk OP17-02-OP17-02PB1-OP17-02PB1 14,205.80 378.78 14,205.80 223.36 6,075.00 2.437 Clearance Factor Pass - Major Risk OP1 9-T1 N - Opt 9 -TI N - OP1 9-T1 N 11,351.95 375.85 11,351.95 280.71 3,976.00 3.950 Centre Distance Pass - Major Risk OP19-TlN - OP19-Tl N - OP19-TIN 11,392.66 379.97 11,392.66 277.36 4,050.00 3.703 Clearance Factor Pass - Major Risk Opt 9-TIN-OP19-T1 NPBI-OP19-TI NPBI 11,351.95 375.85 11,351.95 280.71 3,975.00 3.950 Centre Distance Pass - Major Risk OPi 9-T1N- Opt 9-T1 NPB1-OPI9-T1 NPB1 11,392.66 379.97 11,392.66 277.36 4,050.00 3.703 Clearance Factor Pass - Major Risk OP21-VMMI-OP21-VVVM1-OP21-WVV01 9,768.44 464.03 9,768.44 349.98 4,250.00 4.069 Clearance Factor Pass - Major Risk OP21-WW01-OP21-WW01-OP21-WW01 9,750.91 462.79 9,750.91 351.38 4,300.00 4.154 Centre Distance Pass - Major Risk OP22-WWV03-OP22-WVV03-OP22-WW03 10,972.62 393.81 10,972.62 278.06 4,100.00 3.402 Clearance Factor Pass - Major Risk OP22-WVV03-OP22-WW03-OP22-VWV03 10,980.05 392.69 10,980.05 278.43 4,125.00 3.437 Centre Distance Pass - Major Risk OP23-WW02-OP23-VWV02-OP23-VWV02 10,481.01 382.62 10,481.01 260.62 3,850.00 3.136 Centre Distance Pass - Major Risk OP23-WVV02 - OP23-WV402 - OP23-WA102 10,477.73 384.09 10,477.73 259.10 3,875.00 3.073 Clearance Factor Pass - Major Risk OP26-OSP02 - OP26-DSP02 - OP26-DSP02 10,983.41 727.39 10,983.41 617.12 3,775.00 6.597 Centre Distance Pass - Major Risk OP26-DSP02 - OP26-DSP02 - OP26-DSP02 10,983.41 728.10 10,983.41 616.79 3,800.00 6.541 Clearance Factor Pass - Major Risk Survey fOO/ oroom7/1 From To Survey/Plan SurveyTool (usft) (usft) 39.00 950.00 GYD-GC-SS 950.00 2,350.00 MWD+IFR-AK-CAZ-SC 2,350.00 8,880.00 MWD+IFR-AK-CAZSC 8,880.00 8,895.00 3R-101L1wp13 INC+TREND 8,895.00 9,245.00 3R-101L1wpi3 MWD 9,245.00 10,745.00 3R-10IL1wp13 MWD 9,245.00 16,317.49 3R-101L1wp13 MWD+IFR-AK-CAZ-SC 24 January, 2017 - 8:20 Page 4 of 7 COMPASS Eq Ladder View Ladder View 18:85, January 34 2 3R-101 L1 wp13 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 300 'a C 0 a `m a d U m 150 0 m c N U g eyuiWanl Ma Wjc Djma 0 9000 10500 12000 13500 15000 16500 Displayed interval could be less than entire well:Measured Depth8880.00 To 16317.49 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 950.00 3R-101wpl2 (Plan: 3R-101) GYD-GC-SS 3604.34 8881.00 9 5/8" x 12.25" 950.00 2350.00 3R-10lwp12 (Plan: 3R-101) MWD+IFR-AK-CAZ-SC 3485.30 16317.49 4-1/2" x 6-3/4" 2350.00 8880.00 3R-101wp12 (Plan: 3R-101) MWD+IFR-AK-CAZ-SC 8880.00 8895.00 3R-101L1wpl3 (Plan: 3R-10111) INC+TREND 8895.00 9245.00 3R-101L1wpl3(Plan: 3R -101L1) MWD 9245.00 10745.00 3R-101L1wp13(Plan: 3R -101L1) MWD 9245.00 16317.49 3R-101L1wp13 (Plan: 3R-1011-1) MWD+IFR-AK-CAZ-SC s a so --- 0 - m n 00 T 30- 0 0 m c a1 U egmvaam M.anenc Disunca 0- 9000 9450 9900 10350 10800 11250 11700 1215 Partial Measured Depth TC View w.6 Dx 3R-101L1wp13 �% p o.� o aeso _ 8880 — 9070 8880.00 To 16317.49 .1i y' ; ;; . " ° �: 9070 — 9260 � o ,» ,°,>� 9260 — 9450 70:21. January 24 2017 aeon a '°'°"""°'°"'° 17 =V IMN i m.I°,\+rx,°,°.>ss 9450 9640 w°..°: I. IN:+ : """•• 74 9640 — 9820 ww owo.. s.mwi rro`: zpw.s ami e°ma ia:..�ez.x 'aimnieew. +m' i ""°'° 0t7 9820 — 10010 ® I wm sw.w�.0 'au.m°w»,mu+cmum "°�^�°++..�: »,mwo "az m wan, n+°mnse 10010 10200 +m.+p slsr:xs.+awn i m ,ss,:.e m.,w., 1n.: r+.,mwamws zsc hm.ii i .+°,�, m+°+°„ee sPo° 10200 — 10450 CASING DEfA145 wO,B +°vnmmnv 4 Al 10450 10700 ND MD Nem. Size api.w s.°-� -n n°rti ri° mmnv 3664.34 6681.00 9Wx12.25' 8-SI6 �svaon a ° ieiiii :in°n 10700 10950 9065.30 iWl>A9 4lZx&3+4' 4-12 +i°esn vz si°m mrtrnum°nv 10950 — 11200 V IILI TI. 1011 0. wam s.+°n, T. 1°101m 11200 17450 11450 — 11700 11700 11950 0/360 11950 -- 72200 22 12200— 12720 1 -30/330 30 12720 — 13230 1 ' 13230 13750 13750— 14260 i 5 14260 — 14780 _ 14780 15290 15290 15800 -60/300 60 15800— 16317 ,1 -90/270 I ` 90 4 l `r\ i { 6 Ili 11�vv�II�jNI �liA 75 V11\v IvA' 90 \'�� 10 -120/240 1\Xw �� {ii- 12 120 1, I ; 13 150 16 180 195 -150/210 150 210 225 -180/180 e . m : -mss- X a AC Wells Only -10 AC Flipbook 3R-io7L>wPI3 8880.00 To 9300.00 8880.00 27o.16 8896.50 269.39 8916.50 26939 9017.87 265.93 9478.83 26593 9647.49 266.70 9746.11 267.16 10524.31 267.16 10625.20 268.8o 10728.41 270.41 10933.51 270.41 10983.41 270.16 11034.83 270.16 11575.90 270.16 11648.48 270.16 11709.94 270.16 12093.48 270.16 1212o.82 270.16 12140.79 27o.16 12621.43 270.16 12668.11 270.16 12726.40 27o.16 13241.02 270.16 829589 270.16 13315.65 270.16 1370o.96 27o.16 1371o.84 27o.16 13783.41 270.16 1419735 270.16 14212.22 270.16 14233.84 270.16 14695.80 270.16 14714.99 270.16 14740.51 270.16 15020.79 27o.16 15085.27 270.16 15151.34 270.16 1548358 270.16 15497-75 270.16 16317.49 27o.16 -6o/- 0/270 6o/ 0/270 -120 /: 10:27, January 24 2017 casing Details No Mo 3604.34 888".0 34859- 163049 Name Depth From Depth To Sum"lplan Tool 9518"x n.x5" 39.00 950.00 3R'iotwpa(Plan : 3R 4m) GTDL-55 4112" 6914'• 950.00 3350 ..2 311 (Plam 3R not) MWDe1FRAKUZ-SC I 2350.00 8880.00 3R0'wpa(Plan: 3Rn01) MWD.IFRRK{ ZSC 10700 8880.00 8895.00 3RnOtLIW3(Nan: 31-011-1) INC.TREND 11450 8895.00 9a45..0 311np14wp3(Ptan: 3R -1.'L) MWD 11950 - -12200 924500 10745.00 313n011.fwp9(Plan; 3RipLt) MWD 0/36o -180/18o iwp�3 • e 0 8880 8880 9070 9070 926o 926o 9450 9450 9640 9640 9820 9820 10010 10010 10200 10200 10450 10450 10700 10700 10950 10950 11200 11200 11450 11450 11700 11700 11950 11950 - -12200 12200 12200 12720 12720 13230 13230 13750 13750 1426o 1426o 14780 1478o 15290 15290 15800 15800 16317 CaNng Detaik 5umey Program 3R-�o�L�wp73 Depth From Depth 950.00 SuNeyl3R-101Plan 3R-10+wpta(Plan: 3R -t01) OOI ND MD Name 3685.34 8887.00 q5/e"x3900 348530 663+)A9 4t/x"x4314" 950.00 2350.00 2350.00 880o.DD 30.-totwpn(Plan:3R<a) 3R' tmww,l,(Pl:3&m6) MWD.1FR MWDrIFRAK{BLSC MC.TR 0.DK{pySC 93oo•oo To loomoo 8880.00 8895045 889500 3R9oM16wpt3 (PIan:3RaMl1) 30. ml-l",(Plan: 3R.twLQ (NCrTREND MWD 9x4508 9E95oo +0)4500 f636).q 3R-mM16wpt3(Hen: 3R -101U) R-6DtLtw 6 Plan: 3Ra061-1 MWD MWDHFRAK{ -SC 0 8880 8880.00 270.160/360 888o 9070 8896.50 26939 8916.50 26939 9070 9260 9017.87 265.93 9478.83 265.93 -30/33 I i 0 9260 9450 9647.49 266.70 9746.11 267.16 /1 i 9450 9640 10524.31 267.16 '� 1 9640 9820 1o625.20 268.80 10728.41 270.41 6o '\t 9820 10010 10933.51 270.4160 10010 10200 10983.41 270.16 - , o Q 6 o 11034.83 270.16 '6 10200 10450 11575.90 270.16 11648.48 270.16 10450 10700 11709.94 270.16 10]00 10950 12093.48 27o.16 �; 12120.82 270.16 10950 11200 12140.79 270.16 \ 12621.43 270.16 11200 11450 12668.11 270.16 _ 12726.40 270.16 O / 2]0 go 11450 11700 13241.02 270.16 11700 11950 13295.89 270.16 13315.65 27o.16 11950 - 12200 13700.96 270.16 13710.84 27o.16 30 12200 12720 13783.41 270.16 14197.35 270.16 12720 13-30 14212.22 270.16 13230 13750 14233.84 27o.16 -120 240 14695.80 270.16 120 13750 14260 1471499 27o.16 6 0 14740.51 270.16 14260 14780 15020.79 270.16 14780 15290 15085.27 270.16 15151.34 270.16 15290 - 15800 15483.58 270.16 -150/210 X50 15800 15497.75 270.16 16317 16317.49 270.16 go 180 / 180 10:27,January 24 2017 j0.-101 L1Wp13 10000.00 To • 16317 49 Casing Details 36 MD 3689.3- 888749 348530 +63+799 Survey Program Name Depth Fmm Depth00 Sur,m3R-101 12 9518"x lxx5" 3900 950.00 3R-t0lwptn(Plan! 3A -mi) q-Ilx"x6914" 950.00 2350.00 3R-lotwptx(Plam 38-101) x350.00 8880.00 3R-mmwP'3(Pl:!311'O 8080.09 008500 3R-101L1wpi3(PlIm3R9mLI) 8895.00 8x4500 3R.+O1Llwpt3(Plae 3RamL1) 91950o 10745-00 30.'1-1-1"13(PIan: 30. mo) xq .00 i63+Z.49 3RaotLt t3 Plan: Motb 7001 MD.IFR MWD.IFR-AK{! -SC MC.TRENAKSRZ-SC INGTREND MWD MWD MWDHFR-AK O 8880 pp0o VOO 90,0 Wit) Azi 8880.00 270.160/36o 8896.50 26939 8916.50 26939(] 9070 9260 9017.87 265.93 9478.83 265.93 -30/33 7 0 0 9260 9450 964749 266.70 \ ,, 9450 9640 9746.11 267.16 10524.31 267.16 - - 9640 9820 1o625.20 268.8o ' 9820 10010 10728.41 270.41 y. 10933.51 270.41 10983.41 270.16 -6o/300 \ \. r ��_ 6 0 10010 10200 11034.83 270.16 11575.90 27o.16 i 10200 10450 11648.48 270.16i/ 10450 10700 11709.94 270.16 3 0 10700 10950 12093.48 27o.16 12120.82 27o.16 10950 11200 12140.79 270.16 12621.43 270.16 11200 11450 12668.11 270.16 �7 12726.40 270.16 _ 0 2/ 0 - g o 7 11450 11700 13241.02 270.16 11700 11950 13295.89 27o.16 13315.65 27o.16 11950 -- 12200 13700.96 270.16 13710.84 274.16 30 12200 12720 13783.41 270.16 12720 13230 1419735 270.16 14212.22 27o.16 8230 13750 14233.84 27o.16 -120/240 14695.8o 270.16 120 13750 14260 14714.99 270.16 6 0 14740.51 270.16 14260 14780 15020.79 270.16 14780 15290 15085.27 270.16 15151.34 270.16 15290 - _ 15800 1548358 270.16 -150/210 15 0 15800 1549775 270.16 16317 16317.49 27o.16 go -180/18o 10:28,January 24 2417 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3R Pad Plan: 3R-101 Plan: 3R-101 L1 Plan: 3R-101 L1wp13 Errors Report 24 January, 2017 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 3R-101 Project: Kupamk River Unit TVD Reference: Plan: 39+9.9 @ 48.90usft (Doyon142) Site: Kuparuk 3R Pad MD Reference: Plan: 39+9.9 @ 48.90usft (Doyon142) Well: Plan: 3R-101 North Reference: True Wellbore: Plan: 3R-1011-1 Survey Calculation Method: Minimum Curvature Design: 3R-101 L1wp13 Database: OAKEDMP2 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 Version: Using Well Reference Point Map Zone: Alaska Zone 4 Vertical Section: Using geodetic scale factor Site Kuparok 3R Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: 270.00 Position Uncertainty: 0.00 usft Slot Radius: W Grid Convergence: 0.16 ° Well Plan: 3R-101 Well Position +N/ -S 0.00 usft Northing: Latitude: +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 17.74 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 9.90 usft Wellbore Plan: 3R-10111 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 19 (I (nT) BGGM2016 3/25/2017 17.74 81.04 57,551 Design 3R-10111wp13 Audit Notes: Version: Phase: PROTOTYPE Tie On Depth: 8,880.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 39.00 0.00 0.00 270.00 Survey Tool Program Date 1/24/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 950.00 950.00 3R-101wp12 (Plan: 3R-101) 2,350.00 3R-101wpl2 (Plan: 3R-101) GYD-GC-SS MWD+IFR-AK-CAZ-SC G rodata y gyro single shots MWD+IFRAKCAZ SCC 2,350.00 8,880.00 3R-101wp12(Plan: 3R-101) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,880.00 8,895.00 3R-101L1wpl3(Plan: 3R-10111) INC+TREND Inclinometer + known azi trend 8,895.00 9,245.00 3R-101 L1wpl3(Plan:3R-1011-1) MWD MWD -Standard 9,245.00 10,745.00 3R-101 L1wpl 3(Plan: 3R-101 L7) MWD MWD - Standard 9,245.00 16,317.49 3R-101L1wpl3(Plan: 3R-10111) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD (usft) MD Error Inc Ellipse Inc TVDSS (usft) (°) (") (usft) Vert Error Let Error (usft) (usft) Horz. Error (usft) 8,880.00 31.50 88.00 159.33 3,555.41 11.20 13.10 11.20 KOP: 13.66°1100' DLS, -20° TF, for 16.6' 8,881.00 31.76 88.13 159.15 3,555.44 11.21 12.83 1121 9 5/8" x 12.26" 8,896.50 31.76 90.10 159.15 3,555.68 11.21 12.83 11.21 Hold for 20' 8,900.00 31.76 90.10 159.10 3,555.67 11.21 12.86 1121 1242017 826:11AM Page 2 COMPASS 5000.1 Build 74 Errors Report Company: ConomPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kupawk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellboro: Plan: 3R-1011-1 Survey Calculation Method: Design: 3R-101L1wpl3 Database: Well Plan: 3R-101 Plan: 39+9.9 @ 48.90usft (Doyon142) Plan: 39+9.9 @ 48.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Horz. Error (usft) (usft) P) (1) (usft) (usft) (usft) (usft) 8,916.50 31.76 90.10 158.90 3,555.64 11.21 12.98 11.21 Start 3.5'1100' DLS, -76.93° TF, for 101.37- 9,000.00 32.30 90.76 157.82 3,555.01 11.22 1229 1124 9,017.87 32.41 90.90 157.58 3,554.75 11.22 12.16 11.25 Hold for 460.96' 9,100.00 32.41 90.90 156.47 3,553.46 11.24 12.98 11.27 9,200.00 32.41 90.90 155.05 3,551.88 11.27 14.11 11.30 9,300.00 32.41 90.90 153.63 3,550.30 11.29 15.16 11.32 9,400.00 32.42 90.90 152.26 3,548.72 11.30 16.15 11.33 9,478.83 32.42 90.90 151.12 3,547.48 11.32 17.00 11.35 Start 0.5.1100' DLS, 114.82" TF, for 168.67' 9,500.00 32.39 90.86 150.81 3,547.15 11.32 17.29 11.35 9,600.00 32.28 90.65 149.29 3,545.84 11.36 18.67 11.38 9,647.49 32.23 90.55 148.55 3,545.34 11.38 19.35 11.40 Adjust TF to 110.09', for 98.62' 9,700.00 32.16 90.46 147.70 3,544.88 11.41 20.12 11.42 9,746.11 32.10 90.38 146.94 3,544.54 11.43 20.82 11.44 Hold for 778.19' 9,800.00 32.11 90.38 146.03 3,544.18 11.47 21.53 11A8 9,900.00 32.11 90.38 144.29 3,543.52 11.54 22.88 11.55 10,000.00 32.11 90.38 142.47 3,542.85 11.62 24.28 11.63 10,100.00 32.11 90.38 140.59 3,542.19 11.71 25.72 11.72 10,200.00 32.11 90.38 138.65 3,541.52 11.81 27.18 11.82 10,300.00 32.11 90.38 136.68 3,540.86 11.93 28.68 11.94 10,400.00 32.12 90.38 134.68 3,540.20 12.05 30.19 12.06 10,500.00 32.12 90.38 132.68 3,539.53 12.18 31.72 12.19 10,524.31 32.12 90.38 132.19 3,539.37 12.22 32.10 12.23 Start 2.6°1100' DLS, 40.43° TF, for 100.89' 10,600.00 31.61 91.82 130.69 3,537.92 12.33 33.74 12.39 10,625.20 31.44 92.30 130.20 3,537.01 12.36 34.28 12.46 Adjust TF to 38.34, for 103.21' 10,700.00 30.92 93.77 128.77 3,533.05 12.48 35.87 12.68 10,728.41 30.71 94.32 128.24 3,531.05 12.52 36.48 12.77 Hold for 205.1' 10,800.00 31.13 94.32 147.21 3,525.65 11.62 22.24 11.90 10,900.00 31.13 94.32 146.67 3,518.12 11.67 22.67 11.94 10,933.51 31.13 94.32 146.48 3,515.59 11.68 22.82 11.96 Start 2.6.1100' DLS, -168.5° TF, for 49.9' 10,983.41 31.26 93.10 146.21 3,512.36 11.71 22.92 11.87 Adjust TF to -180°, for 51.42' 11,000.00 31.27 92.69 146.12 3,511.52 11.71 22.99 11.84 11,034.83 31.29 91.81 145.94 3,510.16 11.73 23.14 11.80 Hold for 641.07' 11,100.00 31.29 91.81 145.58 3,508.09 11.76 23.42 11.83 11,200.00 31.29 91.81 145.00 3,504.92 11.82 23.87 11.88 11,300.00 31.30 91.81 144.42 3,501.76 11.87 24.33 11.94 11242017 8:26:11AM Page 3 COMPASS 5000.1 Build 74 A Errors Report Company: ConowPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 L1 Survey Calculation Method: Design: 3R-101Ltwpl3 Database: Well Plan: 3R-101 Plan: 39+9,9 @ 48.90usft (Doyonl42) Plan: 39+9,9 @ 48.90usft (Doyon142) Tme Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Ho¢. Error (usR) (usR) V) (°) (usft) just) (usft) (usR) 11,400.00 31.30 91.81 143.82 3,498.59 11.93 24.79 11.99 11,500.00 31.30 91.81 143.21 3,495.42 11.99 25.26 12.05 11,575.90 31.30 91.81 142.75 3,493.02 12.03 25.62 12.10 Start 2.6°/100' DLS, 180° TF, for 72.68' 11,600.00 31.31 91.21 142.60 3,492.38 12.05 25.73 12.08 11,648.48 31.33 90.00 142.32 3,491.87 12.08 25.95 12.08 Adjust TF to 180°, for 61.47- 11,700.00 31.33 88.71 142.01 3,492.45 12.11 26.18 12.11 11,709.94 31.33 88.46 141.95 3,492.69 12.12 26.22 12.11 Hold for 383.64' 11,800.00 31.33 88.46 141.40 3,495.11 12.18 26.64 12.17 11,900.00 31.34 88.46 140.76 3,497.79 12.24 27.13 12.24 12,000.00 31.34 88.46 140.12 3,500.47 12.32 27.62 12.31 12,093.48 31.34 88.46 139.51 3,502.98 12.38 28.07 12.38 Start 0.6°/100' DLS, 0° TF, for 27.34' 12,100.00 31.34 88.50 139.47 3,503.15 12.39 28.11 12.39 12,120.82 31.34 88.60 139.33 3,503.68 12.40 28.21 12.40 Adjust TF to 0°, for 19.98' 12,140.79 31.34 88.70 139.20 3,504.15 12.42 28.31 12.41 Hold for 480.64' 12,200.00 31.34 88.70 138.81 3,505.49 12.46 28.60 12.46 12,300.00 31.35 88.70 138.15 3,507.76 12.54 29.10 12.53 12,400.00 31.35 88.70 137.48 3,510.03 12.62 29.60 12.61 12,500.00 31.35 88.70 136.81 3,512.30 12.70 30.11 12.69 12,600.00 31.35 88.70 136.13 3,514.57 12.78 30.62 12.78 12,621.43 31.35 88.70 135.99 3,515.06 12.80 30.73 12.80 Start 1.6°1100' DLS, 0° TF, for 46.67' 12,668.11 31.35 89.40 135.67 3,515.83 12.84 30.97 12.83 Adjust TF to 0°, for 68.29' 12,700.00 31.35 89.88 135.45 3,518.03 12.87 31.13 12.87 12,726.40 31.35 90.27 135.27 3,516.00 12.89 31.27 12.90 Hold for 514.62' 12,800.00 31.35 90.27 134.77 3,515.64 12.95 31.64 12.96 12,900.00 31.35 90.27 134.09 3,515.16 13.04 32.16 13.05 13,000.00 31.36 90.27 133.41 3,514.69 13.13 32.68 13.14 13,100.00 31.36 90.27 132.72 3,514.21 13.23 33.20 13.23 13,200.00 31.36 90.27 132.04 3,513.73 13.32 33.73 13.33 13,241.02 31.36 90.27 131.77 3,513.53 13.36 33.94 13.37 Start 0.6°/100' DLS, 160° TF, for 64.87' 13,295.89 31.37 90.00 131.41 3,513.40 13.41 34.22 13.41 Adjust TF to 180°, for 19.76' 13,300.00 31.37 89.98 131.38 3,513.40 13.42 34.24 13.42 13,315.65 31.37 89.90 131.28 3,513.42 13.43 34.32 13.43 Hold for 385.31' 13,400.00 31.37 89.90 130.74 3,513.56 13.52 34.75 13.51 13,500.00 31.37 89.90 130.07 3,513.73 13.61 35.28 13.61 1/242017 8:26:1IAM Page 4 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 3R Pad MD Reference: Well: Plan: 3R-101 North Reference: Wellbore: Plan: 3R-101 L1 Survey Calculation Method: Design: 3R-101L1wp13 Database: Well Plan: 3R-101 Plan: 39+9,9 @ 48.90usft (Doyon142) Plan: 39+9,9 @ 48.90usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert Error Let Error Hors. Error (usft) (waft) (°) (°) (usft) (usft) (usft) (usft) 13,600.00 31.37 89.90 129.40 3,513.91 13.72 35.81 13.71 13,700.00 31.38 89.90 128.74 3,514.08 13.82 36.34 13.82 13,700.96 31.38 69.90 128.74 3,514.08 13.82 36.34 13.82 Start 1°/100' DLS, 0° TF, for 9.68' 13,710.84 31.38 90.00 128.67 3,514.09 13.83 36.40 13.83 Adjust TF to 0°, for 72.57' 13,783.41 31.37 90.73 128.19 3,513.63 13.90 36.79 13.92 Hold for 413.94' 13,800.00 31.37 90.73 128.08 3,513.42 13.92 36.88 13.94 13,900.00 31.37 90.73 127.43 3,512.15 14.03 37.41 14.04 14,000.00 31.38 90.73 126.79 3,510.89 14.14 37.95 14.15 14,100.00 31.38 90.73 126.16 3,509.62 14.24 38.49 14.26 14,197.35 31.38 90.73 125.55 3,508.39 14.35 39.02 14.37 Start 0.5°/100' DLS, 0° TF, for 14.87' 14,200.00 31.38 90.74 125.53 3,508.35 14.35 39.03 14.37 14,212.22 31.38 90.80 125.45 3,508.19 14.37 39.10 14.38 Adjust TF to 0°, for 21.62' 14,233.84 31.38 90.91 125.32 3,507.87 14.39 39.22 14.41 Hold for 461.96' 14,300.00 31.38 90.91 124.91 3,506.82 14.47 39.58 14.49 14,400.00 31.39 90.91 124.30 3,505.23 14.56 40.12 14.60 14,500.00 31.39 90.91 123.70 3,503.65 14.69 40.67 14.71 14,600.00 31.39 90.91 123.11 3,502.06 14.81 41.21 14.83 14,695.80 31.39 90.91 122.56 3,500.55 14.92 41.74 14.94 Start 1°/100' DLS, 0° TF, for 19.19' 14,700.00 31.39 90.95 122.53 3,500.48 14.92 41.76 14.94 14,714.99 31.39 91.10 122.45 3,500.21 14.94 41.84 14.97 Adjust TF to 0°, for 25.52' 14,740.51 31.39 91.35 122.30 3,499.66 14.97 41.98 15.01 Hold for 280.28' 14,800.00 31.39 91.35 121.96 3,498.26 15.04 42.31 15.08 14,900.00 31.39 91.35 121.40 3,495.91 15.16 42.86 15.19 15,000.00 31.39 91.35 120.85 3,493.55 15.28 43.41 15.31 15,020.79 31.40 91.35 120.74 3,493.06 15.31 43.52 15.34 Start 1°/100' DLS, 0° TF, for 64.48' 15,085.27 31.38 92.00 120.40 3,491.18 15.38 43.88 15.44 Adjust TF to 0°, for 66.07' 15,100.00 31.38 92.15 120.32 3,490.65 15.40 43.96 15.47 15,151.34 31.37 92.66 120.04 3,488.49 15.46 44.24 15.55 Hold for 332.24' 15,200.00 31.37 92.66 119.79 3,486.23 15.52 44.51 15.61 15,300.00 31.37 92.66 119.27 3,481.59 15.65 45.07 15.74 15,400.00 31.38 92.66 118.77 3,476.95 15.77 45.62 15.86 15,483.58 31.36 92.66 118.35 3,473.07 15.88 46.09 15.96 Start 1°/100' DLS, 180° TF, for 14.16' 12412017 8:26AIAM Page 5 COMPASS 5000.1 Build 74 Errors Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 3R-101 Project: Kuparuk River Unit TVD Reference: Plan: 39+9.9 @ 48.90usft (Doyon142) Site: Kupawk 3R Pad MD Reference: Plan: 39+9,9 @ 48.90usft (Doyon142) Well: Plan: 3R-101 North Reference: True Wellbore: Plan: 3R-10111 Survey Calculation Method: Minimum Curvature Design: 3R-101 L1wp13 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat Error Horz, Error (usft) (usft) 19 1`I (usft)usft ( ) (usft) (usft) 15,497.75 31.38 92.52 118.29 3,472.43 15.90 46.16 15.98 Hold for 819.74' 15,500.00 31.38 92.52 118.28 3,472.33 15.90 46.17 15.98 15,600.00 31.39 92.52 117.79 3,467.94 16.02 46.73 16.10 15,700.00 31.39 92.52 117.32 3,463.54 16.15 47.29 16.23 15,800.00 31.39 92.52 116.85 3,459.15 16.28 47.84 16.36 15,900.00 31.40 92.52 116.40 3,454.75 16.41 48.40 16.49 16,000.00 31.40 92.52 115.96 3,450.35 16.54 48.96 16.62 16,100.00 31.40 92.52 115.52 3,445.96 16.67 49.52 16.75 16,200.00 31.40 92.52 115.10 3,441.56 16.80 50.08 16.88 16,300.00 31.41 92.52 114.69 3,437.17 16.94 50.64 17.01 16,317.49 31.41 92.52 114.62 3,436.40 16.96 50.74 1704 TD: 16317.49' MD, 3485.3' TVD - 4-1/2" x 63/4" 112412017 8.26'11AM Page 6 COMPASS 5000.1 Build 74 Errors Report Company: ConoccPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 3R-101 Project: Kuparuk River Unit TVD Reference: Plan: 39+9.9 @ 48.90usft (Doyon142) Site: Kupamk 3R Pad MD Reference: Plan: 39+9.9 @ 48.90usft (Doyon142) Well: Plan: 3R-101 North Reference: True Wellbore: Plan: 3R-1011-1 Survey Calculation Method: Minimum Curvature Design: 3R-101L1wpl3 Database: OAKEDMP2 Casing Points Measured Depth (usft) 8,881.00 16,317.49 Vertical Depth (usft) 3,604.34 3,485.30 9 518" x 12.25" 4-1/2"x6-3/4" Name Casing Diameter 9-5/8 4-1/2 Hole Diameter 12-1/4 6-3/4 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -s +E/ -W (usft) (usft) (usft) (usft) Comment 8,880.00 3,604.31 6,000.92 -2,394.19 KOP: 13.56°/100' DLS, -20° TF, for 16.5' 8,896.50 3,604.58 6,000.86 -2,410.69 Hold for 20' 8,916.50 3,604.54 6,000.65 -2,430.69 Start 3.5°/100' DLS, -76.93° TF, for 101.37' 9,017.87 3,603.65 5,996.51 -2,531.95 Hold for 460.96' 9,478.83 3,596.38 5,963.84 -2,991.70 Start 0.5°/100' DLS, 114.82" TF, for 168.67' 9,647.49 3,594.24 5,953.01 -3,159.99 Adjust TF to 110.09°, for 98.62' 9,746.11 3,593.44 5,947.73 -3,258.47 Hold for 778.19- 10,524.31 3,588.27 5,909.21 -4,035.70 Start 2.5'/1 DO' DLS, 40.43° TF, for 100.89' 10,625.20 3,585.91 5,905.66 -4,136.49 Adjust TF to 38.34°, for 103.21' 10,728.41 3,579.95 5,904.94 4,239.51 Hold for 205.V 10,933.51 3,564.49 5,906.39 -4,444.03 Start 2.5-/100' DLS, -168.5° TF, for 49.9' 10,983.41 3,561.26 5,906.63 4,493.82 Adjust TF to -180°, for 51.42' 11,034.83 3,559.06 5,906.77 -4,545.19 Hold for 541.07' 11,575.90 3,541.92 5,908.25 -5,085.99 Start 2.5'/100' DLS, 180° TF, for 72.58' 11,648.48 3,540.77 5,908.44 -5,158.56 Adjust TF to 180°, for 61.47- 11,709.94 3,541.59 5,908.61 -5,220.01 Hold for 383.54' 12,093.48 3,551.88 5,909.65 -5,603.41 Start 0.5*1100' DLS, 0" TF, for 27.34' 12,120.82 3,552.58 5,909.73 -5,630.74 Adjust TF to 0°, for 19.98' 12,140.79 3,553.05 5,909.78 -5,650.70 Hold for 480.64' 12,621.43 3,563.96 5,911.09 -6,131.22 Start 1.5'/100' DLS, 0"TF, for 46.67' 12,668.11 3,564.73 5,911.22 -6,177.89 Adjust TF to 0°, for 58.29' 12,726.40 3,564.90 5,911.38 -6,236.18 Hold for 514.62' 13,241.02 3,562.43 5,912.78 -6,750.79 Start 0.5°1100' DLS, 180° TF, for 54.87' 13,295.89 3,562.30 5,912.93 -5,805.66 Adjust TF to 1B0°, for 19.76' 13,315.65 3,562.32 5,912.98 -6,825.42 Hold for 385.31' 13,700.96 3,562.98 5,914.03 -7,210.73 Start 1-/100' DLS, 0- TF, for 9.88' 13,710.84 3,562.99 5,914.06 -7,220.61 Adjust TF to 0*, for 72.57' 13,783.41 3,562.53 5,914.26 -7,293.18 Hold for 413.94' 14,197.35 3,557.29 5,915.38 -7,707.08 Start 0.5"/100' DLS, 0` TF, for 14.87' 14,212.22 3,557.09 5,915.42 -7,721.95 Adjust TF to 0*, for 21.62' 14,233.84 3,556.77 5,915.48 -7,743.57 Hold for 461.96- 14,695.80 3,549.45 5,916.74 -8,205.47 Start 1°1100' DLS, 0° TF, for 19.19' 14,714.99 3,549.11 5,916.79 -8,224.66 Adjust TF to 0*, for 25.52' 14,740.51 3,548.56 5,916.86 -8,250.17 Hold for 280.28- 15,020.79 3,541.96 5,917.63 -8,530.37 Start 1'11 00'DLS, 0° TF, for 64.48' 15,085.27 3,540.08 5,917.80 -8,594.82 Adjust TF to 0°, for 66.07' 15,151.34 3,537.39 5,917.98 -8,660.84 Hold for 332.24- 15,483.58 3,521.97 5,918.88 -8,992.72 Start V/100' DLS, 180° TF, for 14.16' 15,497.75 3,521.33 5,918.92 -9,006.87 Hold for 819.74' 16,317.49 3,485.30 5,921.15 -9,825.82 TD: 16317.49' MD, 3485.3' TVD Checked By: Approved By: Date: I 1242017 8:26:11AM Page 7 COMPASS 5000.1 Build 74 Pool Report 3R-101 Surface Location I M CPA[Coordinate Converter u O (- From: _ _.__ _. - To Datum INAD83 Region alaska Datum. NADP? j Region: alaska C Latitude/Longitude Degrees Minutes Seconds D, f Latitude/Longitude IDecimal Degrees—� f" UTM Zone:I - r South r UTM Zone: True r South %' State Plana Zane: I' J Units: usft . Units: C State Plane Zone: us -Ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starling Coordinates:------ - --- X: Ending Loordnates: — — X: 1660657.37965123 Y: 6031484.21427894 520625.980000003 Y: 6031732.15999999 i Transform -- Quit Help CPAICoordinate Datum: INAD83 .I Region: lalaska 11 C Latitude/Longitude IDegrees, Minutes Seconds (- UTM Zone: F` r South G State Plane Zone:14 Units: usft C LSnal pe;; nGe�on INa,Ds7 onlvi Starting Coordinates: --- X: 1660657.37965123 Y: 6031484.21427894 -To:.__-- Datum:NAD27 Region alaska i Latitude/Longitude Decimal Degrees C UTM Zone: True T- South !" State Plane Zone:1" J Units: Fu; -It r Legal Description (NAD27 only) Legal Description-----------------� Township: 013 I" J Range: 009 Meridian: I`I—�-] Section: rg - FNL . 1630.4924 FEL . 2959.2486 Transform i Quit Help i..____.._.........._...........___....... P 3R-1-01 Surface Casing M CPAI Coordinate Converter From.. Datum: NAD83 Region: alaska (- Latitude/Longitude IDegfees Minutes Seconds C' UTM Zone. r- r South l: State Plane Zone: Units: us-fi r Legal Description (NAD27 only) -To: — Datum NAD27 .. Region: alaska C' Latitude/Longitude IDecimalDegrees C' UTM Zone: True r South C• State Plane Zone: I q --�-] Units: us -ft C' Legal Description (NAD27 only) r Starting Coordinates: Ending Coordinates. - X: 1660522.71 X 520491.312342821 Y: 16032094.30 Y. 6032342.84109003 --- .---- ..___..._...........___......, Transform Quit Help M CPAI Coordinate Converter Datum:[—NA—D-8-3 . Region: alaska . r Latitude7Longitude Degrees Minutes Seconds + C' UTM Zone: I — r South State Plane Zone: F--] Units: usdt l- L=gal Cl aswohon lNap2r c,r�ba Datum:NAD27 Region: alaska C' Latitude/Longitude IDecimalDegfees, C UTM Zone: True r South f Stale Plane Zone: qUnits: us -Ft L: Legal Description (NAD27 only) j Starling Coordinates:--- - Legal Description--- -----� X: 1660522.71 Township: 013 IN --,l Range: 009 [EF:,] Y: 6032094.90 Meridian: r—� Section:r— FNL1019.3776 FEL . 3090.6855 I Transform Quit Help I 3R-101 Intermediate 1 Casing & Production Horizon M CPAI Coordinate Converter From. Datum: NAD83 . Region: alaska + f Latitude/Longitude IDecimalDegiees r UTM Zone: r— r South G State Plane Zone: rq Units: usft r Legal Description [NAD27 only] Starling Coadnates:-------- — X: 11658241.43 Y: fSO37478.00 FZ CPAI Coordinate �-From: - Dalum: INAD83 . Region: jalaska 11 r Latitude/Longitude IDecimalDegreas r UTM Zone:I — r South G Slate Plane Zone: I" Units: + C Lcgal Dasniiptiot, (t4AtD27 oolv..us-f[j� Starting Coordinates: X: 1658241.43 Y: 6037478.00 -To:—_ Datum NAD27 Region: alaska r Latitude/Longitude Decimal Degrees r UTM Zone: True [— South G State Plane Zone: F_"=] Units: usft r Legal Description [NAD27 only[ Ending X 1518210096916775 Y: 16037725.94824409 Transform .Quit Help Datum:NAD27 . Region: alaska + r Latitude/Longitude IDecimalDegrees J r UTM Zone: True r South Stale Plane Zone:14 Units: us4[ !•" Legal Description [NAD27 only] Legal Description---- ------------- Township: 013 I" J :l Range: 009 I` J Meridian: 1U .SJ Section: s` FNL 909.37433 WE 63.554759 i Transform : Quit Help 3R-101 TD From. --- Datum: JNADB3 I Region: jalaska . C Latitude/Longitude DecimalDegrees f UTM Zone: �" r South G Slate Plane Zone: Units: usft C Legal Description (NAD27 only) E To ---- Datum: lU627 Region: 1.1aska r Latitude/Longitude DecimalDegrees C UTM Zone: True r South fi State Plane Zone: I' =-] Units: us -ft C' Legal Description [NAD27 only] Starting Coordinates:----- - gtes:------- l X: 11650816.45 x' 1510785,17789858 --- Y— 6037378.00 -_- - _-- Y: 6037626.09872079 Transform ) Quit Help f-11 CPAI Coordinate Converter From: - DatumNAD83 Region: aaska l r Latitude/Longitude DecimalDegrees C UTM Zone: r —"- r South F State Plane Zone:4—'usUnits: k . i Lars 1 s_ i � IIV AD 27 on�u: Starting Coordinates: X: 1650816.45 Y: 6037370.00 To: Datum: NAD27 Region: alaska III' Latitude/Longitude DecimalDegrees r UTM Zone:True r South T State Plane Zone:14 J Units: us -Ft r Legal Description (NAD27 only] Township: 013 N--- Range: 009 I Meridian: F--3- Section:16 FNL . 994.73490 FEL . 2209.6718 .__.___................................... Transform :..___..._......................_..._......�.: Quit Help 10:16, JanuatY , 24203R-101L1wpl3 WELLBORE TARGET DETAILS (MAP CO-OROINATES) Name NO Shape 3R-101LI TO 101017 SS 3'85.30 CPIA(Padol 25,001 Quarter Mile View 3R-101 L1 T1 OM101017 017SESB 3'0530 Rtlius 1320.001 sRImu T121m0n s0 3sz1.33 Circle (Radius 25.00) a0-m1u Tv "1019 s0 3s'0.0e Circle (Radius'. 25-00 Q C� ry 3R-"1LI T<1.10n s0 3s'o nC de R tl s 25 oa V �`O` C\ 1`Ory � yo- O^ pv 3R 101LT1111117 x0 3s'P.n c cle (R a x 25001 00 3R 101L1l 7510101950 355258 C' le (Ratl s-25.001 9R 101 L1 T9 101017 SB 355709 C' de (Radius 25.001 3R:l0L T31o10nse 3R-111 LI 77101/758 3561 z6 C le (Ra 25011 P O Y0 O O 3562,30 ``�Cgyple(R tl 25.00) 1 0000 9� OP23- �d`i�T6 RdatRe 010 ee RC400Ynr °t(aae s 25.001 ,Q 3&1QTL1 T 1017x0 3585. Clea(Parse' 2500) 0 3R-101LI TI 107 68 359'2 CImIe(Redms ...001 ��, 3R-101LIC OM 1010175,6 36003 Crtde(Rarlius: 1320.101 3E 101LIT PW1.7SBclmle waalus 2x.001 o� ,p ry 41 Q dI 08-04L P81 O op {�O^,by3i Q o Q1 0 m o Q'L1' w�'07 8000 Oliktok Point 1-1 O OP03-P05PB1 01 krok. o, _ 1nt State 1 C U)6000 3_-- ------- CD O u Nto q a —C4000- 0 M z 3R -10A *o =2000- 09 a Q 0 � y 1 j N N O -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 West( -)/East(+) (2000 usft/in) 3R-101 L1wp13 3-D View �. -.-0 PE 3R I'D 3 7,.Plan: 3R-101, Pim: 3R.101, 3RT L1 112/29/091 AJR I NRB I IPER K090043ACS 1 2 112/18/1 JAH JFC PER K160005ACS NOTES: 1. BASIS OF LOCATION AND ELEVATION IS DS3R MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE N.A.D. 27. .3. ELEVATIONS ARE B,P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRAC SECTION 9, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN, ALASKA 5. DATES OF SURVEY: 12/18/16 FB# L16-40-5 6. ALL DISTANCES SHOWN ARE GROUND DS3R SEE SHEET 2 FOR LOCATION INFORMATION 6 1 5 ml Milm�do U o VICINITY MAP N 1" = 1 MILE a a 4 PROJECT 0 E LEGEND • EXISTING CONDUCTOR LOCATION o AS --BUILT CONDUCTOR LOCATION GRAPHIC SCALE 100 200 400 1 inch = 200 ft. Lu & ASSOCIATES, INC. StIR x"n 6NG1NEns FL Nmm nuups DS3R WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION REV: 2 Attachment 3 — 3R-101 L1 Drilling Hazards Summary 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight 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 Concretions Moderate Use developed best practices for concretion drilling. Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. RECEIVE® JAN 2 5 2017 Post Office Box 100360 /'►o ^ (7 �� Anchorage, Alaska 99510-0360 Phone (907) 263-4249 Email: scott.a.brunswick(cDconocoohillias.com January 24, 2017 Alaska Oil and Gas Conservation Commission 333 West 71' Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 3R-101 L1 Saved: 24 -Jan -17 ConocoPhillips Re: Application for Permit to Drill Well 311-101 Ll West Sak D Sand Multi -Lateral Producer. Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to re -drill an onshore producer well from the 3R pad. The expected spud date for this well is March 1, 2017. It is planned to use rig Doyon 142. ✓ 3R-101 is planned to be a dual lateral horizontal well in the West Sak D sand. 3R-101 (lower lateral) submitted in a separate PTD application will drill a 16" surface hole & run 13-3/8" surface casing to +/-2,351'MD / 2,200' TVD cemented to surface. The intermediate hole section will drill a 12-1/4" hole to a depth of +/-9,188' MD / 3,615' TVD with 9-5/8" casing run & cemented in place. The 3R-101 lower lateral will be a 6-3/4" hole geo-steered to 16,313' MD / 3,502' TVD in the lower West Sak D sand package & completed with a 4-1/2" slotted liner. This PTD application package is for the upper lateral 3R-101 Ll, also a 6-3/4" hole geo-steered to 16,318' MD / 3,485' TVD in the upper West Sak D sand package & completed with a 4-1/2" slotted liner. A Baker Ram system will be run, followed by the liner & LEM with liner top packer. The liners will be tied back to surface using 4-1/2" tubing with required ESP pump area & GLM as required. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 (scoff.a.brunswick@conocoohillips.com) or Chip Alvord at 265-6120. Sincerely, Scott Brunswick Drilling Engine Application for Permit to Drill Document FF Drillinli Kuparuk Well 3R-101 L1 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 3R-101 Ll 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 1630.5' FNL, 2959.2' FEL, Sec 9, T 13N, R009E, UM NGS Coordinates Northings: 6,031,732.16' Eastings: 520,625.98' IRKB Elevation 48.9' AMSL 1Pad Elevation 9.9'AMSL Location at Surface Casing 1019.38' FNL, 3090.7' FEL, Sec 9, TON, R009E, UM NGS Coordinates Northings: 6,032,342.84' Eastings: 520,491.31' Measured Depth, RKB: 2,349' Total Vertical De th, RKB: 2,199' Total Vertical De th, SS: 2,150' Location at Intermediate Casing Exit NGS Coordinates Northings: 6,037,626.09' Eastings: 510,785.18' 909.37' FNL, 63.55' FEL, Sec 5, TON, R009E, UM NGS Coordinates Northings: 6,037,725.94' Eastings: 518,210.10' Measured De th, RKB: 8,880' TO Vertical De th, RKB: 3,604' Total Vertical Depth, SS: 3,555' Location at Total De th 994.73' FNL, 2209.67' FEL, Sec 6, T13N, R009E, UM NGS Coordinates Northings: 6,037,626.09' Eastings: 510,785.18' Measured De t1,RKB: 16,318' Total Vertical De i_ RKB: 3,485' Total Vertical Depth, SS: 3,436' and (D) other information required by 20AAC 25.050(b); Requirements of 20 AAC 25.050(6) 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: Directional 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. 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 blmvout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(41 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 potential surface pressure (MPSP) while drilling 3R-101 L1 is calculated using an estimated maximum reservoir pressure of 1,660 psi (8.6 ppg, based Kigun 1 MDT pressure at a 3708' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A3 sand at 6,220' TVD: D Sand Estimated. BHP = 1,660 psi D Sand estimated depth = 3,708' TVD Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 371 psi (3,708' TVD * 0.10 psi/ft) MPSP = BHP — gas column =1,289 psi (1,660 psi — 371 psi) (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; See attached 3R-101 L1 Drilling Hazards Summary 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 conductingformation integrity tests, as required under 20 AAC 15.0300; A procedure is on file with the commission for performing LOT'S. 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 far 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 Cement Program Casin and Cement in Pro ram Csg?bg Hole S zGrade Density 9.0-9.5 Conn. 25-30 Top MDITVD Btm MD/TVD Cement Program OD (in) 10 minute Gel 8-16 API Filtrate < 6 (ft) (ft) (ft) 20 ILength H-40 Welded 78 Surf 117/117 Existing Hydril Cementto Surface with 13-3/8 16 L-80 563 2,313 Surf 2,351 / 2,200 1,193 sx DeepCRETE Lead 11.0 ppg, 235 sx Dee CRETE Tail Slurry 12.0 DPC 9-5/8 12-1/4 40 L-80 H563'I 9150 Surf 9,188 / 3,615 1605 sx 15.8 ppg Class G 4-1/2 6-3/4 12.6 L-80 TXP 7,193 9,120 / 3,613 16,313 / 3,502 N/A 4-1/2 6-3/4 12.6 L-80 TXP 7,518' 8,800'/3,604' 16318'/ 3485' N/A 4-1/2 12.6 L-80 TXP 9082' 38'/ 38' 9120'/ 3613' 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 dmertersystem as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Surface hole has been drilled, BOPE will be installed. 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,• Mud Program Summary Production 6-3/4" Hole Mud System Flo-Thru (WBM) Density 9.0-9.5 PV 25-30 YP 15-20 Initial Gel 7-10 10 minute Gel 8-16 API Filtrate < 6 HTHP Fluid Loss at 160 F < 10 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application 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 follows. Please refer to attachment for proposed well schematic. 1. End PTD for 3R-101 & begin PTD for 3R-101 LI once on bottom with 6-3/4" drilling assembly. 2. Drill to landing point with motor BHA, flow check the well, & POOH. 3. PU 6-3/4" RSS BHA & TIH. (GR, Res — PeriScope) / 4. Directionally drill 6-3/4" hole geosteering though the West Sak D sand to TD —16,318' MD as per directional plan & geology. 5. CBU XI & BROOK 6. Once BHA inside casing, circulate hole clean, flow check, & POOH on elevators. 7. Lay down Production BHA. 8. Pick up & make up hook (lug retrieving tool), string magnet, bumper sub, jars, float sub and MWD (directional only). 9. TIH 10. Break circulation & orient whipstock retrieving hook with MWD & hook the whipstock. 11. Pull whipstock free. 12. CBU X2. 13. Monitor well for flow. 14. POOH & lay down BHA & whipstock. 15. RIH & set Baker Seal Bore diverter & production anchor. 16. PU & run 4-I/2" slotted liner with Baker Oil Tools RAM hanger system. 17. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool & POOH. 18. Makeup junction isolation/ re-entry (LEM) & RIH to depth. Orient & set packer atop assembly & release from assembly. POOH. 19. Rig up & run 4-1/2" tubing & gas lift completion as required & RIH to depth. 20. Land hanger & run in lock down screws. 21. Test upper & lower seals to 250 psi & 5000 psi for 10 minutes. 22. Set BPV. 23. Monitor well for flow for 15 minutes 24. Nipple down BOPE, nipple up tree and test. 25. Pull BPV & Freeze protect well with diesel or isotherm and install BPV. 26. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music 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 25.080for 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 (1R-18 or new facilities at DS1B). All cuttings generated will be hauled 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. Attachments: Attachment 1 Well Schematic Attachment 2 Directional Plan Attachment 3 Drillin¢ Hazards Summary Attachment I — Proposed Well Schematic Loepp, Victoria T (DOA) From: Sent: To: Subject: Attachments: Follow Up Flag: Flag Status: Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office) (907) 227-8499 ( Cell ) Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Wednesday, March 01, 2017 3:08 PM Loepp, Victoria T (DOA) RE: 3R-101 & 3R-1011-1 PTD Applications Status 311-101 Permit to Drill Hole Size Update.pdf, 3R-101 Ll Permit to Drill Hole Size Update.pdf Follow up Flagged From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, March 01, 2017 3:03 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: 311-101 & 3R-1011-1 PTD Applications Status Please show changes in red or highlight - From: Brunswick, Scott A [mailto Scott A Brunswick@conocophillips com] Sent: Wednesday, March 01, 2017 3:00 PM To: Loepp, Victoria T (DOA) <victoria.loepp(@alask�> Subject: RE: 311-101 & 3R-1011-1 PTD Applications Status Thank you, appreciate this. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp alaska eov] Sent: Wednesday, March 01, 2017 2:53 PM To: Brunswick, Scott A <Scott A Brunswick(@conocophillips com> Subject: [EXTERNAL]RE: 3R-101 & 3R -101L1 PTD Applications Status Email me the first 9 pages of the package(don't include the 10-407 form- I will hand mark) with the changes shown in red. Same for the lateral if it changes also. From: Brunswick, Scott A fmailto:Scott.A.Brunswick@conocophillips.coml Sent: Wednesday, March 01, 2017 2:44 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Tolman, Ben V <Ben.V.Tolman@conocophillips com> Subject: RE: 311-101 & 3R-1011-1 PTD Applications Status I've handed the well to another engineer, the production hole will now change to 8.75" from 6.75", that's the only change. Should we submit updated paperwork for the hole size change? Everything else remains the same. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 (Office) (907) 227-8499 ( Cell ) From: Brunswick, Scott A Sent: Wednesday, March 01, 2017 2:41 PM To:'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.eov> Subject: RE: 311-101 & 3R -101L1 PTD Applications Status Roger that, thx. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp(@alaska.gov) Sent: Wednesday, March 01, 2017 2:38 PM To: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: [EXTERNAL]RE: 3R-101 & 3R-1011-1 PTD Applications Status Should see something early next week - From: Brunswick, Scott A [mailto:Scott A Brunswick@conocophillips comj Sent: Wednesday, March 01, 2017 2:33 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: RE: 311-101 & 3R-1011-1 PTD Applications Status Rig got delayed, so 3 weeks from now. Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office ) (907) 227-8499 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp alaska.govJ Sent: Wednesday, March 01, 2017 2:32 PM To: Brunswick, Scott A <Scott.A.Brunswick(caconocophillips.com> Subject: [EXTERNAL]RE: 311-101 & 3R-1011-1 PTD Applications Status In process. Spud date? From: Brunswick, Scott A [mailto:Scott A Brunswick@conocophillips com] Sent: Wednesday, March 01, 2017 2:26 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Tolman, Ben V <Ben.V.Tolman.@conocophillips.com>; Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haeeerty-Sherrod(cacontractor conocophillips com> Subject: 311-101 & 3R-1011-1 PTD Applications Status Hi Victoria I was wondering about the status of the 311-101 & 3R-1011-1 PTD Application status? Thanks Scott Brunswick Drilling Engineer ConocoPhillips Alaska (907) 263-4249 ( Office) (907) 227-8499 ( Cell ) TRANSMITTAL LETTER CHECKLIST WELL NAME: KAb� ,3A — PTD: gi - oil Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: �&Qgs!R R1V&, POOL: &a./Lk Roa Wim/ &k ©1 - 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. c21 - 0 /.3 API No. 50-�1- A Od - O C) . (If last two digits Production should continue to be reported as a function 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 onpermit). 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 fust caught and 10' sam le 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 (Companv Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CH ECKLIS "Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 ------ PTD#:2170140 _- — - - ---- -DEV Company CONOCOP�LIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RJV UNIT R-1 11_1 Program _ Well bore seg �V / PEND- GeoArea 890_ _ Unit 17 Nonconven. gas conforms to AS31 05.0300A.A),0ZA-D) NA __ 1110 _ On/Off Shore On _ Annular Disposal EJAdministration 1 Permit fee attached _ _ _ NA 2 Lease number appropriate Yes ADL0355023, Surf Loc; ADL0355024, Top Prod Intery & TD. 3 Unique well name and number Yes KRU 3R-1011_1 4 Well located in a defined pool Yes KUPARUK RIVER, WEST SAK OIL - 490150, governed by Conservation Order No, 406C.. :5 Well located proper distance from drilling unit boundary Yes CO 4060 contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells... Yes CO 406C has no interwell spacing. restrictions, 7 Sufficient acreage available in. drilling unit. Yes 8 If deviated, is wellbore plat. included Yes 9 Operator only affected party... Yes _ Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes PKB 1/26/2017 12 Permit can be issued without administrative. approval Yes 13 Can permit be approved before 15 -day wait _ Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in. comments). (For NA 15 All wells within 1/4. mite area of review identified (For service well only) _ NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA Engineering 18 Conductor string. provided _ NA Conductor set in KRU 3R-101 19 Surface casing. protects all known USDWs NA Surface casing set in KRU 3R-101 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing will be fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No Productive interval will. be completed with uncemented slotted production liner 23 Casing designs adequate for C, T, B &. permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 1660 psig(8.6 ppg EMW); will drill w/ 8.5-10.0 ppg EMW VTL 3/14/2017 29 BOPEs, do they meet regulation _ Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 1289 psig; will test BOPs to 3500 psig 31 Choke manifold complies w/API. RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures No H2S measures required.. 36 Data. presented on potential overpressure zones - Yes _Max potential reservoir pressure is 8.6 ppg EMW;. will be drilled using 9.0 to 9.5 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 1/26/2017 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports. [exploratory only] _ NA Development lateral to be drilled from. onshore 3R -Pad. Geologic Engineering Public Date: ate Co mis Date a -7Commissioner: Commj�issioner S 9 al'r� 9� `3 6 �_ > I, t