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Home My WebLink About217-091STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT M-32RD2 JBR 08/01/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2-7/8" & 3-1/2" joints. Test Results TEST DATA Rig Rep:Munoz/MatthewsOperator:Hilcorp Alaska, LLC Operator Rep:Soule/Bordelon Rig Owner/Rig No.:Hilcorp 404 PTD#:2170910 DATE:6/7/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM250613092609 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6.5 MASP: 1205 Sundry No: 325-224 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"P Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1600 200 PSI Attained P13 Full Pressure Attained P106 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P4@1900 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P25 #1 Rams P7 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2       Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govApril 17, 2025 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit M-32RD2 PTD 2170910 Dear Mr. Marlowe: On April 11, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a second no-flow test of Trading Bay Unit M-32RD2 located on the Steelhead Platform in Cook Inlet. The previous test dated March 20, 2025, was unsuccessful in demonstrating a gas flow rate below the allowed limit. For this subsequent test the AOGCC Inspector confirmed that the proper test equipment – as outlined in AOGCC Industry Guidance Bulletin 21-001 – was rigged up on Trading Bay Unit M- 32RD2. The well’s performance was monitored for more than 2 hours consisting of 1-hour pressure build up periods followed by up to 30-minute flow monitoring checks. There was no liquid flow to surface during the no-flow test, however, gas flow rates exceeded the allowed limit. The results witnessed by AOGCC on April 11, 2025, indicate a failed no-flow test. Trading Bay Unit M-32RD2 must be equipped with a fail-safe automatic safety valve system capable of preventing uncontrolled flow – including a surface controlled subsurface safety valve or AOGCC-approved alternate – as required in 20 AAC 25.265. Please retain a copy of this letter on the Steelhead Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2025.04.17 18:25:38 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,023 N/A Casing Collapse Structural Conductor 1,020psi Surface 1,540psi Intermediate Production 6,620psi Liner 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CO 228A McArthur River West Foreland Oil & Middle Kenai G Oil Same 9,958 13,889 9,942 1,205psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,240psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 217-091 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20462-02-00 Hilcorp Alaska, LLC Trading Bay Unit M-32RD2 Length Size Proposed Pools: 981' 981' L-80 TVD Burst 11,562 7,930psi MD 2,630psi 3,090psi 1,347' 3,767' 1,347' 3,767' 6,846'9-5/8" 981' 26" 16" 13-3/8" 1,267' 3,691' 7,209' Perforation Depth MD (ft): 10,369 - 13,790 7,132' 7" 8,687 - 9,930 4/29/2025 14,018'7,062' 3-1/2" & 2-7/8" 9,957' N/A & N/A N/A & N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-224 By Gavin Gluyas at 1:19 pm, Apr 14, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.04.14 12:15:01 - 08'00' Dan Marlowe (1267) * BOPE test to 2500 psi. 48 hour notice. MGR18APR25 A.Dewhurst 16APR25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.18 18:32:13 -08'00'04/18/25 RBDMS JSB 042125 ESP Swap / G Zone Addperf Well: Steelhead M-32RD2 Well Name:M-32RD2 API Number:50-733-20462-02-00 Current Status:ESP Oil Producer Leg:B-1 (NW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:217-091 First Call Engineer:Casey Morse (907) 777-8322 (o) (603) 205-3780 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Current BHP: 2,165 psi @ 9,600’ TVD Shut-in ESP Intake Pressure Max. Potential Surface Pressure: 1205 psi Using 0.1 psi/ft Brief Well Summary M-32RD2 is a West Foreland producer completed with an ESP. The well was sidetracked in 2017, and this is the second ESP swap the well will need. The ESP has failed for a suspected electrical issue and the well has been shut in since early Jan 2025. The objective of this program is to pull ESP, cleanout if needed, add perforations in the G zone, and install a new ESP. After adding the G zone perforations in March 2025, this well failed its no flow test on 4/12/25. The completion needs to be supplemented with a SSSV and packer / vent valve. The goal of this project is to pick up the tubing, install a packer / vent valve and SSSV, then re-land the completion. Pertinent wellbore information: - Inclination: Deviation gets as high as 80 degrees through the West Foreland, with a tangent section ~11,500’ to TD for setting the ESP. - Pertinent History o Well sidetracked in July 2017 and completed in the West Foreland only Casing pressure tested to 3000 psi on 8/21/17 o March 2022: RWO to replace failed ESP Relevant Pool Tops in M-32RD2: x Middle Kenai G Oil Top: ±10,350’ MD / 8,665’ TVD x Middle Hemlock Oil Top: ±10,780’ MD / 9,080’ TVD x West Foreland Top: ±11,850’ MD / 9,650’ TVD x Hilcorp has approval to commingle production from Middle Kenai G and West Foreland Oil Pools in accordance with CO 228 A RWO Procedure: 1. MIRU HAK 404 2. Circulate well: ESP Swap / G Zone Addperf Well: Steelhead M-32RD2 a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume: 59 + 27 = 86bbls d. IA to ESP: 410 + 143 = 553bbls e. Casing to top perf below ESP = 6bbl 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH with tapered 3-1/2” x 2-7/8” ESP completion 7. Contingent cleanout: Discuss with Engineer, and if necessary, PU cleanout BHA on workstring and clean out well to PBTD ~13,800’. 8. MU TCP guns on workstring. TIH to shooting depth per Engineer’s perf table. a. Approximate depths of Middle Kenai G Oil perfs: ±10,350 to ±10,700 b. RU Eline and run gamma correlation pass to confirm depth 9. Actuate firing head to perforate Hemlock zones 10. Circulate well clean, and ensure static, POOH with TCP guns. 11. Pickup new ESP and RIH on tapered 3-1/2” x 2-7/8” completion per attached Proposed Wellbore Schematic. a. Top of ESP to be set at ±11,500’ MD b. Set packer and SSSV per Proposed Wellbore Schematic 12. Set BPV/TWC, ND BOP 13. NU tree and test, pull BPV/TWC 14. RDMO RWO crew and equipment Post-rig Work: 15. Turn well over to production. 16. Conduct SVS testing per AOGCC regulations. 17. Schedule No Flow Test per AOGCC regulations Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current/Proposed Wellhead Diagram (no changes) 4. BOP Drawing 5. 404 Fluid flow diagram 6. RWO Sundry Change Form _____________________________________________________________________________________ Updated By: CDM 04/02/25 CURRENT SCHEMATIC Steelhead Platform Well: M-32RD2 PTD: 217-091 API: 50-733-20462-02 Last Completed: 03/20/22 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status G-0a 10,369 10,390 8,687 8,707 21 6 03/06/25 Open G-1a 10,412 10,433 8,729 8,750 21 6 03/06/25 Open G-2a 10,475 10,517 8,790 8,830 42 6 03/06/25 Open G-3a 10,538 10,576 8,852 8,888 38 6 03/06/25 Open G-5a 10,622 10,700 8,933 9,005 78 6 03/06/25 Open WF-1 11,860 11,881 9,653 9,658 21 6 08/29/17 Open WF-1 11,912 12,094 9,665 9,704 182 6 08/29/17 Open WF-1 12,145 12,401 9,714 9,759 256 6 08/29/17 Open WF-2 12,462 12,558 9,765 9,776 96 6 08/29/17 Open WF-2 12,580 12,650 9,778 9,786 70 6 08/29/17 Open WF-2 12,705 12,920 9,793 9,819 215 6 08/29/17 Open WF-2 12,974 13,146 9,826 9,846 172 6 08/29/17 Open WF-2 13,230 13,264 9,856 9,861 34 6 08/29/17 Open WF-2 13,297 13,790 9,865 9,930 493 6 08/29/17 Open CASING DETAIL Size Wt Grade Conn ID Top Btm 26” Surf 981’ 16” 75 K-55 BTC 15.1 80.1’ 1,347’ 13-3/8” 61 K-55 BTC 12.5 75.58’ 3,767’ 9-5/8” 53.5 L-80 BTC 8.535 77.06’ 7,209’ (TOW) 7” 26 L-80 DWC 6.276 6,956’ 14,018’ TUBING DETAIL 3-1/2” 9.3 L-80 IBT 2.992 Surf 6,779’ 2-7/8” 6.4 8RD EUE 2.441 6,779’ 11,562’ JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 72.75’ 72.75’ 2.992 7.63 11” Tubing Hanger 1 6,779’ X-Over (3-1/2 x 2-7/8) 2 11,562’ 9,564’ N/A 4.500 Discharge Head Bolt on, 2 7/8" 8rnd EUE, 400 Series 11,563’ 9,654’ N/A 4.000 Pumps - 400 Series, SF1750 (x4) & 400 Series, 78 SFNPSH (x1) 11,672’ 9,599’ N/A 4.000 Gas Separator, High Flow, 2 Stage (Upper & Lower) 400X, Vortex 3 11,679’ 9,601’ N/A 4.000 Upper/Lower Seals – 400 Series, BPBSL 11,696’ 9,607’ N/A 4.560 Motor - 456 Series, FMS, 300 HP 11,732’ 9,618’ N/A 4.560 Centralizer / Anode **Note – Straight Hole Pump Tangent Section 11,519.27’ to 11,708.73’ PBTD: 13,889’ (MD) / 9,942’ (TVD) TD: 14,023’ (MD) / 9,958’ (TVD) Max Hole Angle 84.12ȗ @ 13,071’ RKB to TBG Head = 75.15’ (16-3/4”) RKB to Sea Floor = 345’ 2 Hanger 6,956’ 13-3/8” 9-5/8” 7” WF-2 WF-1 TOW 7,209’ 26” TOC @ 3,758’ 16” TOC @ 9,540’ 1 G 0-5Calc TOC @ ~671’ (13-3/8” )assumed 20% loss _____________________________________________________________________________________ Updated By: CDM 04/02/25 PROPOSED SCHEMATIC Steelhead Platform Well: M-32RD2 PTD: 217-091 API: 50-733-20462-02 Last Completed: 03/20/22 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status G-0a 10,369 10,390 8,687 8,707 21 6 03/06/25 Open G-1a 10,412 10,433 8,729 8,750 21 6 03/06/25 Open G-2a 10,475 10,517 8,790 8,830 42 6 03/06/25 Open G-3a 10,538 10,576 8,852 8,888 38 6 03/06/25 Open G-5a 10,622 10,700 8,933 9,005 78 6 03/06/25 Open WF-1 11,860 11,881 9,653 9,658 21 6 08/29/17 Open WF-1 11,912 12,094 9,665 9,704 182 6 08/29/17 Open WF-1 12,145 12,401 9,714 9,759 256 6 08/29/17 Open WF-2 12,462 12,558 9,765 9,776 96 6 08/29/17 Open WF-2 12,580 12,650 9,778 9,786 70 6 08/29/17 Open WF-2 12,705 12,920 9,793 9,819 215 6 08/29/17 Open WF-2 12,974 13,146 9,826 9,846 172 6 08/29/17 Open WF-2 13,230 13,264 9,856 9,861 34 6 08/29/17 Open WF-2 13,297 13,790 9,865 9,930 493 6 08/29/17 Open CASING DETAIL Size Wt Grade Conn ID Top Btm 26” Surf 981’ 16” 75 K-55 BTC 15.1 80.1’ 1,347’ 13-3/8” 61 K-55 BTC 12.5 75.58’ 3,767’ 9-5/8” 53.5 L-80 BTC 8.535 77.06’ 7,209’ (TOW) 7” 26 L-80 DWC 6.276 6,956’ 14,018’ TUBING DETAIL 3-1/2” 9.3 L-80 IBT 2.992 Surf ±6,800 2-7/8” 6.4 8RD EUE 2.441 ±6,800 ±11,600 JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 72.75’ 72.75’ 2.992 7.63 11” Tubing Hanger 1 ±500 ±500 SSSV 2 ±500 ±500 Packer and vent valve 3 ±505 ±505 X Nipple 4 ±6,800 X-Over (3-1/2 x 2-7/8) 5 ±11,500 Discharge Head Bolt on, 2 7/8" 8rnd EUE, 400 Series Pumps - 400 Series, SF1750 (x4) & 400 Series, 78 SFNPSH (x1) Gas Separator, High Flow, 2 Stage (Upper & Lower) 400X, Vortex 3 Upper/Lower Seals –400 Series, BPBSL Motor - 456 Series, FMS, 300 HP Centralizer / Anode **Note – Straight Hole Pump Tangent Section 11,519.27’ to 11,708.73’ PBTD: 13,889’ (MD) / 9,942’ (TVD) TD: 14,023’ (MD) / 9,958’ (TVD) Max Hole Angle 84.12ȗ @ 13,071’ RKB to TBG Head = 75.15’ (16-3/4”) RKB to Sea Floor = 345’ 5 Hanger 6,956’ 13-3/8” 9-5/8” 7” WF-2 WF-1 TOW 7,209’ 26” TOC @ 3,758’ 16” TOC @ 9,540’ 4 1 2 3 G 0-5Calc TOC @ ~671’ (13-3/8” )assumed 20% loss Steelhead Platform M-32RD2 Current 07/21/2017 BOP Stack Rig 404 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30'Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2Spacer spool 13 5/8 5M X 13 5/8 5M HILCORP ALASKA, LLC Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well M-32RD2 (PTD 217-091) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date 2025-0411_No-Flow_TBU_M-32RD2_jh Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4/13/2025 P. I. Supervisor FROM: Josh Hunt SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit M-32RD2 Hilcorp Alaska LLC PTD 217-091 4/11/2025: I traveled to the Steelhead platform from the heliport at OSK dock and met with Brad Blossom representing Hilcorp for a re-test of TBU M-32RD2. This well previously failed my witnessed no-flow test on 3/20/2025 with the following results: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 9:40 13/13/135 Shut in for test 9:55 16/16/135 10:10 19/19/135 10:25 22/22/135 10:40 24/24/135 0 Open to flow 10:45 20/20/135 >1800 0 10:50 19/19/135 >1800 0 End test (FAIL) The ESP was turned off roughly 72 hours prior to today’s test. Normally it is not allowed to flow for more the 48 hours prior to AOGCC witness, this delay was due to bad weather on 4/10/2025. The rig up was the same as for the 3/20/205 test – a 1-inch hose going into and out of the low pressure/flow gauges from the well with the vent to atmosphere. The tubing and IA were in communication at the manifold throughout this test. M-32RD2 gas was flowing at rates of 850 to 900 scf/hr (no liquids) when I arrived. Brad Blossom said it had maintained that flow rate for the 3 days the pump was off. I confirmed all test equipment had current calibrations. The well was shut in to start today’s no-flow test at 8:45 am. Two flow periods preceded by 1 hour pressure build ups were performed today. Both exceeded the acceptance criteria for a passing no flow test. The following table shows test details for today’s no-flow test: 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.17 11:17:03 -08'00' 2025-0411_No-Flow_TBU_M-32RD2_jh Page 2 of 2 Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 08:45 0.09/0.13/134 850 0 Shut in 09:00 1.33/1.33/134 09:15 2.24/2.42/134 09:30 3.28/3.30/134 09:45 4.13/4.12/134 Open to flow 09:50 2.55/2.55/134 >1800 0 09:55 0.96/0.96/134 >1800 0 10:00 0.25/0.25/134 1750 0 10:05 0.09/0.09/134 950 0 10:10 0.07/0.07/134 900 0 Shut in 10:25 1.35/1.36/134 10:40 2.62/2.62/134 10:55 3.68/3.7/134 11:10 4.62/4.62/134 Open to flow 11:15 1.80/1.80/134 >1800 0 11:20 0.75/0.75/134 >1800 0 11:25 0.25/0.25/134 1550 0 11:30 0.10/0.10/134 1000 0 11:35 0.09/0.09/134 950 0 11:40 0.10/0.10/134 1000 0 End Test - FAIL 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: none 9 9 9 9 9 2025-0320_No-Flow_TBU M-32RD2_jh Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/21/2025 P. I. Supervisor FROM: Josh Hunt SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit M-32RD2 Hilcorp Alaska LLC PTD 2170910 3/20/2025: I traveled to the Steelhead platform from the heliport at OSK dock and met with Jeff Williams representing Hilcorp. I was informed at this time that the well likely would not pass a No-Flow test. He described the events leading up to my arrival for the test as follows: The ESP was turned off 40 hours prior to my arrival at which time they opened the IA and tubing to a 2-inch flare stack. They had a ½-inch hose going into and out of the low pressure/flow gauges from the well with the vent to atmosphere. The tubing and IA were in communication at the manifold throughout this test. The well bled down to around 10 psi and consistently maintained this pressure. The well was shut in for my witness of the no-flow test and within the first 15 minutes it built 3 psi and continued that trend of 2-3 psi every 15 minutes for the next hour. At 60 minutes they opened the IA and tubing to the low pressure and low flow gauges. The flow rate exceeded the gauge scale (>1,800 scf/hr) and maintained this rate for the next 10 minutes with a total loss of 5 psi. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 9:40 13/13/135 Shut in for test 9:55 16/16/135 10:10 19/19/135 10:25 22/22/135 10:40 24/24/135 >1800 0 Open to flow 10:45 20/20/135 >1800 0 10:50 19/19/135 >1800 0 End test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr This test was a FAIL, and the well will remain offline. Attachments: none 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.17 09:39:35 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250318 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-51 50733204640000 195004 3/1/2025 READ CAliperSurvey AN-51 50733204640000 195004 3/1/2025 READ CaliperSurvey/SBHPS BCU 18RD 50133205840100 222033 2/25/2025 AK E-LINE Perf BCU 18RD 50133205840100 222033 2/26/2025 AK E-LINE Plug/Perf BRU 212-26 50283201820000 220058 2/28/2025 AK E-LINE PT Survey BRU 221-26 50283202010000 224098 2/27/2025 AK E-LINE PPROF BRU 241-34S 50283201980000 224077 3/1/2025 AK E-LINE PPROF IRU 11-06 50283201300000 208184 2/26/2025 AK E-LINE DepthDetermination IRU 11-06 50283201300000 208184 3/8/2025 AK E-LINE PlugSetting MPU E-42 50029236350000 219082 2/22/2025 AK E-LINE Caliper MRU A-12RD 50733200760100 171029 3/7/2025 AK E-LINE Correlation MRU A-13 (REVISED)50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-32RD2 50733204620200 217091 3/4/2025 AK E-LINE Correlation PBU 13-24B 50029207390200 224087 1/4/2025 HALLIBURTON RBT PBU 16-24A 50029215360100 224158 2/23/2025 HALLIBURTON RBT-COILFLAG PBU F-21 50029219490000 189056 2/25/2025 READ CaliperSurvey SD37-DSP01 50629234510000 211089 2/28/2025 HALLIBURTON WFL-TMD3D Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40221 T40221 T40222 T40222 T40223 T40224 T40225 T40226 T40226 T40227 T40228 T40229 T40230 T40231 T40232 T40233 T40234 MRU M-32RD2 50733204620200 217091 3/4/2025 AK E-LINE Correlation Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.18 15:55:41 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,023 N/A Casing Collapse Structural Conductor 1,020psi Surface 1,540psi Intermediate Production 6,620psi Liner 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Replace ESP CO 228A McArthur River West Foreland Oil Middle Kenai G Oil & West Foreland Oil 9,958 13,889 9,942 1,815psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,240psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 217-091 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20462-02-00 Hilcorp Alaska, LLC Trading Bay Unit M-32RD2 Length Size Proposed Pools: 981' 981' L-80 TVD Burst 11,558 7,930psi MD 2,630psi 3,090psi 1,347' 3,767' 1,347' 3,767' 6,846'9-5/8" 981' 26" 16" 13-3/8" 1,267' 3,691' 7,209' Perforation Depth MD (ft): 11,860 - 13,790 7,132' 7" 9,653 - 9,930 2/12/2025 14,018'7,062' 3-1/2" & 2-7/8" 9,957' N/A & N/A N/A & N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:43 am, Jan 29, 2025 325-039 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.01.29 07:38:09 - 09'00' Dan Marlowe (1267) DSR-1/31/25 Conduct AOGCC-witnessed No-flow test within 14 days of return to production after RWO. A.Dewhurst 03FEB25 X BOP test to 2500 psi. BJM 2/5/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.05 15:42:11 -09'00' RBDMS JSB 020625 ESP Swap / G Zone Addperf Well: Steelhead M-32RD2 Well Name:M-32RD2 API Number:50-733-20462-02-00 Current Status:ESP Oil Producer Leg:B-1 (NW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:217-091 First Call Engineer:Casey Morse (907) 777-8322 (o) (603) 205-3780 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Current BHP:1,800 psi @ 9,850’ TVD Offset WF Reference Pressure Max Expected BHP after Perfs:2,700 psi @ 8,850’ TVD Offset G Reference Pressure Max. Potential Surface Pressure: 1815 psi Using 0.1 psi/ft Brief Well Summary M-32RD2 is a West Foreland producer completed with an ESP. The well was sidetracked in 2017, and this is the second ESP swap the well will need. The ESP has failed for a suspected electrical issue and the well has been shut in since early Jan 2025. The objective of this program is to pull ESP, cleanout if needed, add perforations in the G zone, and install a new ESP. The goal of this project is to swap the ESP, perform a wellbore cleanout, and add perfs in the Middle Kenai G Oil Pertinent wellbore information: - Inclination: Deviation gets as high as 80 degrees through the West Foreland, with a tangent section ~11,500’ to TD for setting the ESP. - Pertinent History o Well sidetracked in July 2017 and completed in the West Foreland only Casing pressure tested to 3000 psi on 8/21/17 o March 2022: RWO to replace failed ESP Relevant Pool Tops in M-32RD2: x Middle Kenai G Oil Top: ±10,350’ MD / 8,665’ TVD x Middle Hemlock Oil Top: ±10,780’ MD / 9,080’ TVD x West Foreland Top: ±11,850’ MD / 9,650’ TVD x Hilcorp has approval to commingle production from Middle Kenai G and West Foreland Oil Pools in accordance with CO 228 A RWO Procedure: 1. MIRU HAK 404 2. Circulate well: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume: 59 + 27 = 86bbls ESP Swap / G Zone Addperf Well: Steelhead M-32RD2 d. IA to ESP: 410 + 143 = 553bbls e. Casing to top perf below ESP = 6bbl 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH with tapered 3-1/2” x 2-7/8” ESP completion 7. Contingent cleanout: Discuss with Engineer, and if necessary, PU cleanout BHA on workstring and clean out well to PBTD ~13,800’. 8. MU TCP guns on workstring. TIH to shooting depth per Engineer’s perf table. a. Approximate depths of Middle Kenai G Oil perfs: ±10,350 to ±10,700 b. RU Eline and run gamma correlation pass to confirm depth 9. Actuate firing head to perforate Hemlock zones 10. Circulate well clean, and ensure static, POOH with TCP guns. 11. Pickup new ESP and RIH on tapered 3-1/2” x 2-7/8” completion per attached Proposed Wellbore Schematic. a. Top of ESP to be set at ±11,500’ MD 12. Set BPV/TWC, ND BOP 13. NU tree and test, pull BPV/TWC 14. RDMO RWO crew and equipment Post-rig Work: 15. Turn well over to production. 16. Conduct SVS testing per AOGCC regulations. 17. Schedule No Flow Test per AOGCC regulations Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current/Proposed Wellhead Diagram (no changes) 4. BOP Drawing 5. 404 Fluid flow diagram 6. RWO Sundry Change Form Crossflow potential after firing guns from higher- pressured Kenai G to lower pressured West Forland. Ensure well is overbalanced to Kenai G before firing guns. Attempt to keep hole full w/ KWF. -bjm _____________________________________________________________________________________ Updated By: JLL 3/30/22 SCHEMATIC Steelhead Platform Well: M-32RD2 PTD: 217-091 API: 50-733-20462-02 Last Completed: 03/20/22 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status WF-1 11,860 11,881 9,653 9,658 21 6 08/29/17 Open WF-1 11,912 12,094 9,665 9,704 182 6 08/29/17 Open WF-1 12,145 12,401 9,714 9,759 256 6 08/29/17 Open WF-2 12,462 12,558 9,765 9,776 96 6 08/29/17 Open WF-2 12,580 12,650 9,778 9,786 70 6 08/29/17 Open WF-2 12,705 12,920 9,793 9,819 215 6 08/29/17 Open WF-2 12,974 13,146 9,826 9,846 172 6 08/29/17 Open WF-2 13,230 13,264 9,856 9,861 34 6 08/29/17 Open WF-2 13,297 13,790 9,865 9,930 493 6 08/29/17 Open CASING DETAIL Size Wt Grade Conn ID Top Btm 26” Surf 981’ 16” 75 K-55 BTC 15.1 80.1’ 1,347’ 13-3/8” 61 K-55 BTC 12.5 75.58’ 3,767’ 9-5/8” 53.5 L-80 BTC 8.535 77.06’ 7,209’ (TOW) 7” 26 L-80 DWC 6.276 6,956’ 14,018’ TUBING DETAIL 3-1/2” 9.3 L-80 IBT 2.992 Surf 6,777’ 2-7/8” 6.4 L-80 8rd EUE 2.441 6,777’ 11,558’ JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 72.75’ 72.75’ 2.441 7.63 11” Tubing Hanger 1 6,777’ 6,512’ 2.437” 4.260” X-Over (3-1/2 x 2-7/8) 2 11,558’ 9,562’ N/A 4.000” Discharge, Bolt-On 11,559 9,563’ N/A 4.000” Ported Pressure Sub, 400 ZENITH PORTED PRESSURE SUB w/flow control valve 11,560’ 9,563’ N/A 4.000” Pumps (X4) - Series, 125 SF1750, 11/16 Inconel Shaft, 1:3 AR 11,647’ 9,591’ N/A 4.000” Gas Pump, 400 Series, 76 SFGH2500, 11/16 Inc Shaft, 1:2 AR 11,669’ 9,598’ N/A 4.000” Gas Separator, Tandem, 400, H2X, SS, Inc Shaft 11,675’ 9,600’ N/A 4.000” Tandem Seals - 400 Series, BPBSL, Prem Seals, AR Bearings 11,692’ 9,605’ N/A 4.560” Motor 456 Series, FMS, 240 HP/2975V/58A 11,727’ 9,616’ N/A 4.560” Centralizer / Anode **Note – Straight Hole Pump Tangent Section 11,519.27’ to 11,708.73’ PBTD: 13,889’ (MD) / 9,942’ (TVD) TD: 14,023’ (MD) / 9,958’ (TVD) Max Hole Angle 84.12ȗ @ 13,071’ RKB to TBG Head = 75.15’ (16-3/4”) RKB to Sea Floor = 345’ 2 1 Hanger 6,956’ 13-3/8” 9-5/8” 7” WF-2 WF-1 TOW 7,209’ 26” TOC @ 3,758’ 16” TOC @ 9,540’Calc TOC @ ~671’ (13-3/8” )assumed 20% loss _____________________________________________________________________________________ Updated By: CDM 1/17/25 PROPOSED SCHEMATIC Steelhead Platform Well: M-32RD2 PTD: 217-091 API: 50-733-20462-02 Last Completed: 03/20/22 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status G ±10,350 ±10,700 ±8,668’ ±9,007’ ±350’ Future Proposed WF-1 11,860 11,881 9,653 9,658 21 6 08/29/17 Open WF-1 11,912 12,094 9,665 9,704 182 6 08/29/17 Open WF-1 12,145 12,401 9,714 9,759 256 6 08/29/17 Open WF-2 12,462 12,558 9,765 9,776 96 6 08/29/17 Open WF-2 12,580 12,650 9,778 9,786 70 6 08/29/17 Open WF-2 12,705 12,920 9,793 9,819 215 6 08/29/17 Open WF-2 12,974 13,146 9,826 9,846 172 6 08/29/17 Open WF-2 13,230 13,264 9,856 9,861 34 6 08/29/17 Open WF-2 13,297 13,790 9,865 9,930 493 6 08/29/17 Open CASING DETAIL Size Wt Grade Conn ID Top Btm 26” Surf 981’ 16” 75 K-55 BTC 15.1 80.1’ 1,347’ 13-3/8” 61 K-55 BTC 12.5 75.58’ 3,767’ 9-5/8” 53.5 L-80 BTC 8.535 77.06’ 7,209’ (TOW) 7” 26 L-80 DWC 6.276 6,956’ 14,018’ TUBING DETAIL 3-1/2” Surf ±6,750’ 2-7/8” ±6,750’ ±11,500’ JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 72.75’ 72.75’ 2.441 7.63 11” Tubing Hanger 1 ±6,750’ ±6,500’X-Over (3-1/2 x 2-7/8) 2 ±11,500’ ±9,550’ XN-Nipple 3 ±11,500’ 9,550’ N/A Discharge, Bolt-On Pumps Gas Separator Tandem Seals Motor Centralizer / Anode **Note – Straight Hole Pump Tangent Section 11,519.27’ to 11,708.73’ PBTD: 13,889’ (MD) / 9,942’ (TVD) TD: 14,023’ (MD) / 9,958’ (TVD) Max Hole Angle 84.12ȗ @ 13,071’ RKB to TBG Head = 75.15’ (16-3/4”) RKB to Sea Floor = 345’ 3 2 Hanger 6,956’ 13-3/8” 9-5/8” 7” WF-2 WF-1 TOW 7,209’ 26” TOC @ 3,758’ 16” TOC @ 9,540’ 1Calc TOC @ ~671’ (13-3/8” )assumed 20% loss Steelhead Platform M-32RD2 Current 07/21/2017 BOP Stack Rig 404 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30'Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2Spacer spool 13 5/8 5M X 13 5/8 5M HILCORP ALASKA, LLC Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well M-32RD2 (PTD 217-091) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MRU M-32RD2 (PTD 217-091) Punch 2/07/2022 Please include current contact information if different from above. PTD:217-091 T36570 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.10 09:54:39 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Replaced ESP Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,023 feet N/A feet true vertical 9,958 feet N/A feet Effective Depth measured 13,889 feet N/A feet true vertical 9,942 feet N/A feet Perforation depth Measured depth 11,860 - 13,790 feet True Vertical depth 9,653 - 9,930 feet Tubing (size, grade, measured and true vertical depth)3-1/2" & 2-7/8" 9.3 / L-80 & 6.4 / L-80 11,558 MD 9,562 TVD Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: 6,620psi 2,630psi 3,090psi 7,930psi Burst Collapse 1,020psi 1,540psi 1,347' 3,767' 6,846' 7" 7,209' 14,018' 9,957' 9-5/8" measuredPlugs Junk measured N/A Length 981' 1,267' 3,691' Size Conductor Surface Intermediate 26" 16" 13-3/8" Production Liner 7,132' 7,062' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-091 50-733-20462-02-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 McArthur River Field / West Foreland Oil Pool 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Trading Bay Unit M-32RD2 Hilcorp Alaska, LLC measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 280 750 0 57 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 81 Gas-Mcf MD 981' 1,347' 3,767' N/A 40 Structural TVD 981' 322-065 Sr Pet Eng: 5,410psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 74 7,240psi Katherine O'Connor Katherine.oconnor@hilcorp.com 907 777-8376Dan Marlowe, Operations Manager L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 8:43 am, Apr 08, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.04.08 07:44:09 -08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Updated By: JLL 3/30/22 SCHEMATIC Steelhead Platform Well: M-32RD2 PTD: 217-091 API: 50-733-20462-02 Last Completed: 03/20/22 CASING DETAIL Size Wt Grade Conn ID Top Btm 26” Surf 981’ 16” 75 K-55 BTC 15.1 80.1’ 1,347’ 13-3/8” 61 K-55 BTC 12.5 75.58’ 3,767’ 9-5/8” 53.5 L-80 BTC 8.535 77.06’ 7,209’ (TOW) 7” 26 L-80 DWC 6.276 6,956’ 14,018’ TUBING DETAIL 3-1/2” 9.3 L-80 IBT 2.992 Surf 6,777’ 2-7/8” 6.4 L-80 8rd EUE 2.441 6,777’ 11,558’ PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status WF-1 11,860 11,881 9,653 9,658 21 6 08/29/17 Open WF-1 11,912 12,094 9,665 9,704 182 6 08/29/17 Open WF-1 12,145 12,401 9,714 9,759 256 6 08/29/17 Open WF-2 12,462 12,558 9,765 9,776 96 6 08/29/17 Open WF-2 12,580 12,650 9,778 9,786 70 6 08/29/17 Open WF-2 12,705 12,920 9,793 9,819 215 6 08/29/17 Open WF-2 12,974 13,146 9,826 9,846 172 6 08/29/17 Open WF-2 13,230 13,264 9,856 9,861 34 6 08/29/17 Open WF-2 13,297 13,790 9,865 9,930 493 6 08/29/17 Open PBTD: 13,889’ (MD) / 9,942’ (TVD) TD: 14,023’ (MD) / 9,958’ (TVD) Max Hole Angle 84.12ȗ @ 13,071’ RKB to TBG Head = 75.15’ (16-3/4”) RKB to Sea Floor = 345’ 2 1 Hanger 6,956’ 13-3/8” 9-5/8” 7” WF-2 WF-1 TOW 7,209’ 26” TOC @ 3,758’ 16” TOC @ 9,540’Calc TOC @ ~671’ (13-3/8” )assumed 20% lossJEWELRY DETAIL No Depth MD Depth TVD ID OD Item 72.75’ 72.75’ 2.441 7.63 11” Tubing Hanger 1 6,777’ 6,512’ 2.437” 4.260” X-Over (3-1/2 x 2-7/8) 2 11,558’ 9,562’ N/A 4.000” Discharge, Bolt-On 11,559 9,563’ N/A 4.000” Ported Pressure Sub, 400 ZENITH PORTED PRESSURE SUB w/flow control valve 11,560’ 9,563’ N/A 4.000” Pumps (X4) - Series, 125 SF1750, 11/16 Inconel Shaft, 1:3 AR 11,647’ 9,591’ N/A 4.000” Gas Pump, 400 Series, 76 SFGH2500, 11/16 Inc Shaft, 1:2 AR 11,669’ 9,598’ N/A 4.000” Gas Separator, Tandem, 400, H2X, SS, Inc Shaft 11,675’ 9,600’ N/A 4.000” Tandem Seals - 400 Series, BPBSL, Prem Seals, AR Bearings 11,692’ 9,605’ N/A 4.560” Motor 456 Series, FMS, 240 HP/2975V/58A 11,727’ 9,616’ N/A 4.560” Centralizer / Anode **Note – Straight Hole Pump Tangent Section 11,519.27’ to 11,708.73’ Rig Start Date End Date HAK 404 3/10/22 3/20/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-32RD2 50-733-20462-02-00 217-091 03/12/2022 - Saturday Install stairs, spot Accumulator, choke manifold, install and pin derrick to carrier. Remove drill line off of derrick, spot pits, spot mud pump. Rig up Mud pump and pits, R/up circulating hose to well M-32, rig up return line from IA to production header. Pump down tbg taking returns from IA to production header at 3.2 bpm at "0" psi returns at 285 bbls pumped away getting oil back in returns. Total 361 bbls pumped. Production screen packed off, shut down pump, well on vacuum, continue to rig up equipment, while cleaning screen. Bring pump back on at 3.2 bpm, at 29 bbl pumped, getting oil back for returns, caught pressure at 39 bbl. pumped. FCP at 450 psi, pump total of 1062 bbl, at 796 bbls pumped, started getting water back with oil. Continue to pump until clean. Rig down, Circ hoses. Install BPV. R/D ESP cable and control lines, nipple down SSV, and flow line, nipple down the 3-1/8 5m x 11" 5m tree and remove same from well head room. Prep hanger and install Blanken sub, nipple up 13-5/8 5m riser and 13-5/8 5m BOPE. Cont. N/U BOPE stack mud cross, double gate, annular, install choke & kill lines, accumulator lines, check accumulator bottle pre-charge, good;Stand mast, string up tugger lines , man rider & drill line. prep & scope up secure same, pin dog house, install stairs to dog house. chain off stack, Derrick inspection, install rig floor.;Make up kill line, standpipe manifold, winterize cellar, hook up heaters, dress rig floor, function test Bops';M/up 2-7/8 test joint, rig up hose to test joint, rig up choke hose to choke manifold, and gas buster, hang light in derrick;Rig up rig floor wind walls, clean rig floor.;Fill stack, fluid pack choke;Koomey remote not working, Trouble shoot same, found loose connection;Attempt to shell test top rams on 2-7/8 test joint, rams leaking on hi test, made Three attempts to test same, drain stack held JSA on removing rams &. changing ram packers. Breaking Bonnet bolts. Removing rams from Bops' 03/10/2022 - Thursday Moving and spotting carrier beams on deck, pull wireline bridge, pull hatches over Northwest upper well bay, install wire line bridge over M32 well. Rig up E-line, test lubricator 2k, RIH with 1-9/16 tbg punch, on 1-11/16 tools string, punch 3 ft. of holes 10 shots f/ 11,515 ft to 11,518 ft. pooh with tbg punch all shots fired. Prep to skid rig 51 drill package, move equipment on deck to make room, skid diverter line 10 ft. to the South, loosen storm clamps, hook up jacks and grippers, skid Rig 51 drill package 12 ft to the south, secure storm clamps, rig down E-line. Service Crown sheaves, shuffle equipment on deck with crane, set wireline bridge, aline with well, set single & double beams, install cross braces, set Carrier, draw works. 03/11/2022- Friday Rig Start Date End Date HAK 404 3/10/22 3/20/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-32RD2 50-733-20462-02-00 217-091 03/15/2022 - Tuesday Continue POOH standing back 2-7/8" completion f/4887' t/171'. L/D perf'd single and P/U single t/replace. Up wt.=8k, 120 total 3.5" cannon clamps, 240 pins, 128 2-7/8" clamps, 256 pins. L/D ESP f/171', R/D Summit equipment, clean and clear rig floor. R/U slick line, RIH w/2" x 4ft DD bailer t/12,030', slow to stop-(deviation), POOH. OOH w/ 1cup dark sludge and scale. R/D slick line. R/U Summit equipment to run ESP. P/U Motor, M/U Tandem seals, gas separator and gas pump. Summit-missing 2ea. small stainless bolt bushings and led gasket for motor lead install. Summit Rep. contacting Summit engineering. Pull ESP from hole and secure well, monitor well. Consulted with Summit engineering, they say it’s ok to run without led gasket and bolt bushings. Cont. P/U ESP and M/U motor leads. 03/14/2022 - Monday Cont. POOH racking back 3 1/2" completion tubing, l/d SSSV, cont POOH l/d packer & vent valve @f/545' & x-nipple assy. Cont. POOH t/9426' up wt 98k. Cont. POOH standing back tubing t/5481'. C/O cable spools, spooler stopped rotating, trouble shoot, had seized cooling fan motor & broken drive shaft. Mobe out replacement spooler from beach, housekeeping & rig maint, organize, clean & inventory sub baskets, service rig. Fill hole 10 bph. Unload boat, setup spooler, cont, POOH standing back 3 1/2" completion t/4887'. 03/13/2022 - Sunday Cont. pull rams from BOPE, clean up blocks & c/o 2 7/8 x 5 1/2" variable packers on ram blocks. Re-install same. Fill surface Eq. with test fluid, re-heat cellar, Shell test variable rams on 2 7/8 TJ, 250 /3500 good, shell test annular 250/2500 good. Housekeeping & rig maint. while mobing Inspector out. Test BOPE as per Hilcorp & AOGCC requirements, test witnessed by inspector Adam Earl, tested with 2 7/8 & 3 1/2" TJ, 250 low /2500 high on Annular, 250/3500 on all other components. Calibrated & tested gas alarms good. Pull Blanking sub, L/dn 3.5 test jt. Pull BPV, (well on vacuum), close Blind rams. Pump down tbg @ 3.3 bpm "0" psi, ICP with returns line up to production header, with 395 bbl. pumped, getting oil back in returns. Tbg pressure 450 / 80 psi on annulus, slow pump to 2 bpm with 100 psi on tbg / 80 psi on annulus, at 440 bbl. pumped, getting a trace of water back in oil. Continue circ pump total of 570 bbl. Returns cleaning up. Pump total of 676 bbl. returns clean. Shut down pump, well on vacuum. Make up landing joint, pull hanger off seat at 110k continue to work up to 155k shearing packer, let packer relax. Pull hanger to floor laying out landing joints at 132 to 128k. Terminate control lines and pump open packer vent & SCSSV, lay out hanger. Pooh racking back 3.5 IBT tbg in derrick. Rig Start Date End Date HAK 404 3/10/22 3/20/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-32RD2 50-733-20462-02-00 217-091 Finish RIH t/11,646'. 149 2-7/8" clamps, 115 3-1/2" clamps, 3 splice clamps, 2 stainless bands, 270 pins. Summit rigged up another sensor tester box and test, consult with town. P/U landing jt. and M/U hanger. M/U penetrator splice, control line penetrator, verified chemical control line, check valve orientation in correct position, dwn wt.=86k. Land hanger, RILDS, Summit meg test, back out landing jt. Safety stand down-review dropped object from derrick. L/D landing jt. and Summit tools. Bleed dwn accumulator, R/D power tong, lights in derrick, clear tools off floor, R/D beaver slide, stairs, cellar tarps, and rig floor. N/D BOPE, risers, DSA. N/U tree and valving. test void t/5000psi stabilized at 4950psi held f/10min. try to test tree, production choke leaking from grease zert, C/O production choke. 03/19/2022 - Saturday Continue N/U new production choke, test tree t/5000psi, no leaks, turn tree over to production. Clean well room. House keeping and maintenance, waiting on production to start ESP. Raise derrick, un-spool tuggers and man rider, remove drill line from drum, lower derrick, prep derrick for un-pinning, un-plug auxiliary equipment and roll up electrical cords. Un-plug super choke from panel, and de-mobe choke and BOP panels. re-move derrick, draw works, scrub and pressure wash the same, cont. R/D equip. Move dog house, koomey, stage carrier, put away and organize equip. 03/16/2022 - Wednesday M/U pump assy per Summit Rep. Test pump rotation, TIH f/surface t/168'. 32 clamps, 64 pins on motor assy. 120bbl loses FIW. Clean and clear rig floor. P/U 1 single from in-string of 2-7/8"EUE 6.4# tbg. and 2 jts 2-7/8"EUE 6.4# tbg f/168' t/263', installing cannon clamps on every connection. Motor lead got mashed in slips while TIH, cut and splice motor lead. Service rig, house keeping and maintenance. TIH w/2-7/8"EUE 6.4# ESP completion f/263' t/3605', meg test @763', 1700', 2700'. Start splice on motor lead @3980'. 03/17/2022 - Thursday TIH w/ 2-7/8" 6.4# EUE tbg ESP completion f/3980' t/4948', XO t/3.5" 9.3# IBT, continue RIH w/ESP t/8080'. Meg test @ 6012', 7015', 8080'. All clamps and pins correlated w/tally. 120bbl loses to hole FIW. C/O motor lead spool, splice motor lead @8080', service rig. Continue RIH w/3.5" IBT tbg ESP completion f/8080' t/11490'. Meg test motor lead, sensor not reading. Re-test leads, good , sensor still not reading. Decision made to RIH to btm-stds and meg test leads and sensors again. 03/18/2022- Friday Rig Start Date End Date HAK 404 3/10/22 3/20/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-32RD2 50-733-20462-02-00 217-091 03/20/2022 - Sunday Pressure washing substructure beams, cellar tarps, HP unit, carrier, assisting crane crew placing equipment on deck. Continue to rig down equipment for move, remove wire line bridge, clean same, remove test pump from upper well room. Install hatches over well bay, secure landings on carrier. Secure Connex's, welder installing handrail gates on carrier& working on safety list. Sent in crew to standby for move to Tyonek plt 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov April 14, 2022 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit M-32RD2 PTD 2170910 Dear Mr. Marlowe: On April 1, 2022 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit M-32RD2 located on the Steelhead Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 10-004. The test was following a rig workover to replace the packerless electric submersible pump completion. The well performance was monitored for 3 hours consisting of flow rate checks each preceded by 1-hour pressure build up periods. The maximum observed gas flow rate was 550 scf/hr. There was no liquid flow to surface during the no-flow test. Trading Bay Unit M-32RD2 may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit M-32RD2 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Steelhead Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2022.04.14 10:43:00 -08'00' 2022-0401_No-Flow_TBU_M-32RD2_ae Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE: 4-02-2022 P. I. Supervisor FROM:Adam Earl SUBJECT:No Flow Test Petroleum Inspector TBU M-32RD2 Hilcorp Alaska LLC PTD 2170910 4-01-22:I traveled out to Steelhead Platform to witness a No-Flow Test on TBU M-32RD2 after they replaced the ESP (packerless) completion. The tubing and inner annulus were connected at surface via ½-inch hose to a calibrated test gauge and SCFH meter. Prior to the test M- 32RD2 was open to bleed pressure for 24 hrs. The following table shows test details: Time Pressures 1 Flow Rate2 Remarks T I/A O/A(psi) Gas – scf/hr Liquid – gal/hr 12:30 0.06 / 0.06 / 130 Shut in @ 12:30pm 12:45 0.26 / 0.26 / 130 1:00 0.35 / 0.35 / 130 1:15 0.44 / 0.44 / 130 1:30 0.51 / 0.51 / 130 300 none Open well through meter 1:35 0.38 / 0.38 / 130 150 none Shut in for build up 1:50 0.52 / 0.52 / 130 2:05 0.59 / 0.59 / 130 2:20 0.66 / 0.66 / 130 2:35 0.73 / 0.73 / 130 500 none Open well through meter 2:40 0.57 / 0.57 / 130 300 none Shut in for build up 2:55 0.70 / 0.70 / 130 3:10 0.78 / 0.78 / 130 3:25 0.85 / 0.85 / 130 3:40 0.91 / 0.91 / 130 550 Open well through meter 3:45 0.58 / 0.58 /130 400 none End test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr After conducting the 3-hour test, bleeding on the hour, three consecutive times, it seemed to meet the passing criteria. Joe Nightingale was the operator on the job. Attachments:Test Equipment Calibration Sheets 9 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 9 9ESP (packerless)completion. James B. Regg Digitally signed by James B. Regg Date: 2022.04.13 20:04:46 -08'00' ERDC SCFH Meter Calibration ERDC SCFH Meter Calibration STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT M-32RD2 JBR 03/31/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 good test. Bag-20secs Rams-8secs HCR-2secs Test Results TEST DATA Rig Rep:Johnson/CastagineOperator:Hilcorp Alaska, LLC Operator Rep:Soule/Hooter Contractor/Rig No.:Hilcorp 404 PTD#:2170910 DATE:3/13/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopAGE220321135632 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 1765 Sundry No: 322-065 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8X5 1/2"P #2 Rams 1 Blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1750 200 PSI Attained P21 Full Pressure Attained P91 Blind Switch Covers:PAll Stations Nitgn. Bottles (avg):P4 @2000 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 999 9 Bag-20secs Rams-8secs HCR-2secs 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov March 10, 2022 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit M-32RD2 PTD 2170910 Dear Mr. Marlowe: On February 28, 2022 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit M-32RD2 located on the Steelhead Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 10-004. The well performance was monitored for 2 hours consisting of flow rate checks each preceded by 1-hour pressure build up periods. The observed gas flow rate was unmeasurable. There was no liquid flow to surface during the no-flow test. Trading Bay Unit M-32RD2 may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit M-32RD2 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Steelhead Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. 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Potential Surface Pressure:2,475 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ***This is a no flow well as of 05/11/2018 ƌŝĞĨtĞůů^ƵŵŵĂƌǇ DͲϯϮZϮŝƐĂtĞƐƚ&ŽƌĞůĂŶĚWƌŽĚƵĐĞƌĐŽŵƉůĞƚĞĚǁŝƚŚĂŶ^W͘dŚĞǁĞůůǁĂƐƐŝĚĞƚƌĂĐŬĞĚŝŶϮϬϭϳĂŶĚƚŚŝƐŝƐƚŚĞ ĨŝƌƐƚ^WƐǁĂƉƚŚĞǁĞůůǁŝůůŶĞĞĚ͘dŚĞǁĞůůďƌŽŬĞĂƐŚĂĨƚĂŶĚƐŚƵƚĚŽǁŶŝŶKĐƚϮϬϮϭ͘KďũĞĐƚŝǀĞŽĨƚŚŝƐƉƌŽŐƌĂŵŝƐ ƚŽƉƵůů^W͕ĐůĞĂŶŽƵƚŝĨŶĞĞĚĞĚ͕ĂŶĚŝŶƐƚĂůůĂŶĞǁ^W͘ >ĂƐƚĂƐŝŶŐWƌĞƐƐƵƌĞdĞƐƚ͗ ϬϴͬϮϯͬϮϬϭϳ;ĂĨƚĞƌĐĞŵĞŶƚŝŶŐĐĂƐŝŶŐͿƚŽϮϳϱϬƉƐŝŐĂŶĚĐŚĂƌƚĞĚĨŽƌϯϬŵŝŶƵƚĞƐ WƌŽĐĞĚƵƌĞ͗ ϭ͘ D/Zh,<ϰϬϰ Ϯ͘ ŝƌĐƵůĂƚĞƚŚĞǁĞůůƚŚƌŽƵŐŚ^WƚŽƉƌŽĚƵĐƚŝŽŶ͘ Ă͘ tŽƌŬŽǀĞƌĨůƵŝĚǁŝůůďĞ&/t͘ ď͘ KW͛ƐǁŝůůďĞĐůŽƐĞĚĂƐŶĞĞĚĞĚƚŽĐŝƌĐƵůĂƚĞƚŚĞǁĞůů͘ ϯ͘ ^ĞƚWs͕EƚƌĞĞ͕EhKWĂŶĚƚĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϯ͕ϱϬϬƉƐŝŚŝŐŚͬϮ͕ϱϬϬƉƐŝŶŶƵůĂƌ Ă͘ EŽƚĞ͗EŽƚŝĨǇK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚ͘ ϰ͘ DŽŶŝƚŽƌǁĞůůƚŽĞŶƐƵƌĞŝƚŝƐƐƚĂƚŝĐ͘ ϱ͘ hŶƐĞĂƚŚĂŶŐĞƌĂŶĚWKK,ǁŝƚŚ^WĐŽŵƉůĞƚŝŽŶ͘ ϲ͘ ZhƐůŝĐŬůŝŶĞĂŶĚƚĂŐĨŝůů ϳ͘ ŽŶƚŝŶŐĞŶƚĐůĞĂŶŽƵƚŝĨĨŝůůŝƐƚĂŐŐĞĚŚŝŐŚ Ă͘ Z/,ǁŝƚŚĐůĞĂŶŽƵƚĂƐƐĞŵďůǇ͕ŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉ͕WKK,͘ ď͘ KWƐǁŝůůďĞĐůŽƐĞĚĂƐŶĞĞĚĞĚƚŽĐŝƌĐƵůĂƚĞƚŚĞǁĞůů ϴ͘ WhĂŶĚƌƵŶ^WĐŽŵƉůĞƚŝŽŶ Ă͘ ŚŝŐŚƐĞƚƉĂĐŬĞƌ͕ƉĂĐŬĞƌǀĞŶƚǀĂůǀĞ͕ĂŶĚ^^^sǁŝůůďĞƌĂŶŝĨǁĞůůŝŶĚŝĐĂƚĞƐƚŚĞĂďŝůŝƚǇƚŽĨůŽǁ ƚŽƐƵƌĨĂĐĞ ϵ͘ >ĂŶĚ^WǁŝƚŚƚŚĞďŽƚƚŽŵŽĨƚŚĞĂƐƐĞŵďůǇĂƚцϭϬϯϬϱ͛͘ ϭϬ͘ /ĨĂƉƉůŝĐĂďůĞʹ^ĞƚĂŶĚƚĞƐƚƉĂĐŬĞƌƚŽϭ͕ϱϬϬƉƐŝĐŚĂƌƚŝŶŐĨŽƌϯϬŵŝŶ ϭϭ͘ ^ĞƚWs͕EKW͕EhƚƌĞĞĂŶĚƚĞƐƚƐĂŵĞ͘ ϭϮ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϭϯ͘ ŽŶĚƵĐƚ^s^ƚĞƐƚŝŶŐƉĞƌK'ƌĞŐƵůĂƚŝŽŶƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ ϯ͘ ƵƌƌĞŶƚͬWƌŽƉŽƐĞĚtĞůůŚĞĂĚŝĂŐƌĂŵ;^ĂŵĞͿ KWĂŶĚƚĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϯ͕ϱϬϬƉƐŝŚŝŐŚͬϮ͕ϱϬϬƉƐŝŶŶƵůĂƌ SVL EMP 3HUIRUP $2*&& ZLWQHVVHG 1R)ORZ WHVW LI FOHDQRXW ZDV SHUIRUPHG DQG SDFNHU ZDV QRW LQFOXGHG LQ WKH FRPSOHWLRQ EMP 7HVW SDFNHU DERYH 0363 WR SVL EMP ŚŝŐŚƐĞƚƉĂĐŬĞƌ͕ƉĂĐŬĞƌǀĞŶƚǀĂůǀĞ͕ĂŶĚ^^^sǁŝůůďĞƌĂŶŝĨǁĞůůŝŶĚŝĐĂƚĞƐƚŚĞĂďŝůŝƚǇƚŽĨůŽǁĨ ƚŽƐƵƌĨĂĐĞ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗DͲϯϮZϮ ϰ͘ KWƌĂǁŝŶŐ ϱ͘ &ůƵŝĚͬ&ůŽǁŝĂŐƌĂŵƐ ϲ͘ ZtK^ƵŶĚƌǇŚĂŶŐĞ&Žƌŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϵͬϮϭͬϭϳ ^,Dd/ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϯϮZϮ Wd͗ϮϭϳͲϬϵϭ W/͗ϱϬͲϳϯϯͲϮϬϰϲϮͲϬϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ ϵͬϬϰͬϮϬϭϳ Wd͗ϭϯ͕ϴϴϵ͛;DͿͬϵ͕ϵϰϮ͛;dsͿ d͗ϭϰ͕ϬϮϯ͛;DͿͬϵ͕ϵϱϴ͛;dsͿ DĂǆ,ŽůĞŶŐůĞϴϰ͘ϭϮȗΛϭϯ͕Ϭϳϭ͛ Z< ƚŽd',ĞĂĚ с ϳϱ͘ϭϱ͛ ;ϭϲͲϯͬϰ͟Ϳ Z<ƚŽ^ĞĂ&ůŽŽƌсϯϰϱ͛ ,ĂŶŐĞƌϲ͕ϵϱϲ͛ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ ϳ͟ t&ͲϮ t&Ͳϭ dKtϳ͕ϮϬϵ͛ Ϯϲ͟ dKΛϯ͕ϳϱϴ͛ ϭϲ͟ dKΛϵ͕ϱϰϬ͛Calc TOC @ ~671’ (13-3/8”)assumed 20% loss; ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ Ϯϲ͟ ^ƵƌĨ ϵϴϭ͛ ϭϲ͟ ϳϱ <Ͳϱϱ d ϭϱ͘ϭ ϴϬ͘ϭ͛ ϭ͕ϯϰϳ͛ ϭϯͲϯͬϴ͟ ϲϭ <Ͳϱϱ dϭϮ͘ϱ ϳϱ͘ϱϴ͛ ϯ͕ϳϲϳ͛ ϵͲϱͬϴ͟ ϱϯ͘ϱ >ͲϴϬ d ϴ͘ϱϯϱ ϳϳ͘Ϭϲ͛ ϳ͕ϮϬϵ͛ ;dKtͿ ϳ͟ Ϯϲ >ͲϴϬ t ϲ͘Ϯϳϲ ϲ͕ϵϱϲ͛ ϭϰ͕Ϭϭϴ͛ dh/E'd/> ϯͲϭͬϮ͟ ϵ͘ϯ >ͲϴϬ /d Ϯ͘ϵϵϮ ^ƵƌĨ ϲ͕ϴϯϵ͛ ϮͲϳͬϴ͟ ϲ͘ϰ >ͲϴϬ ϴƌĚ Ϯ͘ϰϰϭ ϲ͕ϴϯϵ͛ ϭϭ͕ϱϱϳ͛ WZ&KZd/KEd ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &ĞĞƚ ^W& ĂƚĞ ^ƚĂƚƵƐ t&Ͳϭ ϭϭ͕ϴϲϬ ϭϭ͕ϴϴϭ ϵ͕ϲϱϯ ϵ͕ϲϱϴ Ϯϭ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&Ͳϭ ϭϭ͕ϵϭϮ ϭϮ͕Ϭϵϰ ϵ͕ϲϲϱ ϵ͕ϳϬϰ ϭϴϮ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&Ͳϭ ϭϮ͕ϭϰϱ ϭϮ͕ϰϬϭ ϵ͕ϳϭϰ ϵ͕ϳϱϵ Ϯϱϲ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϰϲϮ ϭϮ͕ϱϱϴ ϵ͕ϳϲϱ ϵ͕ϳϳϲ ϵϲ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϱϴϬ ϭϮ͕ϲϱϬ ϵ͕ϳϳϴ ϵ͕ϳϴϲ ϳϬ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϳϬϱ ϭϮ͕ϵϮϬ ϵ͕ϳϵϯ ϵ͕ϴϭϵ Ϯϭϱ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϵϳϰ ϭϯ͕ϭϰϲ ϵ͕ϴϮϲ ϵ͕ϴϰϲ ϭϳϮ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϯ͕ϮϯϬ ϭϯ͕Ϯϲϰ ϵ͕ϴϱϲ ϵ͕ϴϲϭ ϯϰ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϯ͕Ϯϵϳ ϭϯ͕ϳϵϬ ϵ͕ϴϲϱ ϵ͕ϵϯϬ ϰϵϯ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ :t>Zzd/> EŽ ĞƉƚŚ D ĞƉƚŚ ds/ K /ƚĞŵ ϳϮ͘ϳϱ͛ ϳϮ͘ϳϱ͛ Ϯ͘ϰϰϭ ϳ͘ϲϯ ϭϭ͟dƵďŝŶŐ,ĂŶŐĞƌ ϭ ϰϵϭ͛ ϰϵϭ͛ Ϯ͘ϴϭϮ͟ ϱ͘ϯϴϬ͟ ^^^sʹĂŬĞƌdͲϱ Ϯ ϱϰϲ͛ ϱϰϲ͛ ϯ͘ϵϬϬ͟ ϴ͘ϯϮϬ͟ ^WƵĂůWĂĐŬĞƌΘ>KŝůdŽŽůƐǁͬt&d ǀĞŶƚǀĂůǀĞ ϯ ϲϬϰ͛ ϲϬϰ͛ Ϯ͘ϴϭϬ͟ ϯ͘ϱϬϬ͟ yͲŶŝƉƉůĞ ϰ ϲ͕ϴϯϵ͛ ϲ͕ϱϱϵ͛ Ϯ͘ϰϯϳ͟ ϰ͘ϮϲϬ͟ yͲKǀĞƌ;ϯͲϭͬϮǆϮͲϳͬϴͿ ϱ ϭϭ͕ϱϱϳ͛ ϵ͕ϱϲϮ͛ Eͬ ϰ͘ϬϬϬ͟ ŝƐĐŚĂƌŐĞ͕ŽůƚͲKŶ ϭϭ͕ϱϱϴ͛ ϵ͕ϱϲϮ͛ Eͬ ϰ͘ϬϬϬ͟ WƵŵƉƐ;ǆϯͿͲϰϬϬ^ĞƌŝĞƐ͕ϭϭϭ^&ϮϳϬϬ ϭϭ͕ϲϮϵ͛ ϵ͕ϱϴϱ͛ Eͬ ϰ͘ϬϬϬ͟ ^ƚĂŶĚĂƌĚ/ŶƚĂŬĞ ϭϭ͕ϲϯϬ͛ ϵ͕ϱϵϭ͛ Eͬ ϰ͘ϬϬϬ͟ dĂŶĚĞŵ^ĞĂůƐʹϰϬϬ^ĞƌŝĞƐ͕W^> ϭϭ͕ϲϰϳ͛ ϵ͕ϱϵϭ͛ Eͬ ϰ͘ϱϲϬ͟ DŽƚŽƌƐ;ǆϮͿʹϰϱϲ^ĞƌŝĞƐ͕&D^ ϭϲϬ,WͬϭϴϬ,W ϭϭ͕ϲϵϰ͛ ϵ͕ϲϬϲ͛ Eͬ ϰ͘ϱϲϬ͟ ĞŶƚƌĂůŝǌĞƌͬŶŽĚĞ ΎΎEŽƚĞʹ^ƚƌĂŝŐŚƚ,ŽůĞWƵŵƉdĂŶŐĞŶƚ^ĞĐƚŝŽŶϭϭ͕ϱϭϵ͘Ϯϳ͛ƚŽϭϭ͕ϳϬϴ͘ϳϯ͛ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϮͬϭϬͬϮϮ WZKWK^ ^ƚĞĞůŚĞĂĚWůĂƚĨŽƌŵ tĞůů͗DͲϯϮZϮ Wd͗ϮϭϳͲϬϵϭ W/͗ϱϬͲϳϯϯͲϮϬϰϲϮͲϬϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ &hdhZ Wd͗ϭϯ͕ϴϴϵ͛;DͿͬϵ͕ϵϰϮ͛;dsͿ d͗ϭϰ͕ϬϮϯ͛;DͿͬϵ͕ϵϱϴ͛;dsͿ DĂǆ,ŽůĞŶŐůĞϴϰ͘ϭϮȗΛϭϯ͕Ϭϳϭ͛ Z< ƚŽd',ĞĂĚс ϳϱ͘ϭϱ͛ ;ϭϲͲϯͬϰ͟Ϳ Z<ƚŽ^ĞĂ&ůŽŽƌсϯϰϱ͛ ,ĂŶŐĞƌϲ͕ϵϱϲ͛ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ ϳ͟ t&ͲϮ t&Ͳϭ dKtϳ͕ϮϬϵ͛ Ϯϲ͟ dKΛϯ͕ϳϱϴ͛ ϭϲ͟ dKΛϵ͕ϱϰϬ͛Calc TOC @ ~671’ (13-3/8” )assumed 20% loss; ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ Ϯϲ͟ ^ƵƌĨ ϵϴϭ͛ ϭϲ͟ ϳϱ <Ͳϱϱ d ϭϱ͘ϭ ϴϬ͘ϭ͛ ϭ͕ϯϰϳ͛ ϭϯͲϯͬϴ͟ ϲϭ <Ͳϱϱ dϭϮ͘ϱ ϳϱ͘ϱϴ͛ ϯ͕ϳϲϳ͛ ϵͲϱͬϴ͟ ϱϯ͘ϱ >ͲϴϬ d ϴ͘ϱϯϱ ϳϳ͘Ϭϲ͛ ϳ͕ϮϬϵ͛ ;dKtͿ ϳ͟ Ϯϲ >ͲϴϬ t ϲ͘Ϯϳϲ ϲ͕ϵϱϲ͛ ϭϰ͕Ϭϭϴ͛ dh/E'd/> ϯͲϭͬϮ͟ ^ƵƌĨ цϲ͕ϴϰϬ͛ ϮͲϳͬϴ͟ цϲ͕ϴϰϬ͛ цϭϬ͕ϭϳϬ͛ WZ&KZd/KEd ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &ĞĞƚ ^W& ĂƚĞ ^ƚĂƚƵƐ t&Ͳϭ ϭϭ͕ϴϲϬ ϭϭ͕ϴϴϭ ϵ͕ϲϱϯ ϵ͕ϲϱϴ Ϯϭ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&Ͳϭ ϭϭ͕ϵϭϮ ϭϮ͕Ϭϵϰ ϵ͕ϲϲϱ ϵ͕ϳϬϰ ϭϴϮ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&Ͳϭ ϭϮ͕ϭϰϱ ϭϮ͕ϰϬϭ ϵ͕ϳϭϰ ϵ͕ϳϱϵ Ϯϱϲ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϰϲϮ ϭϮ͕ϱϱϴ ϵ͕ϳϲϱ ϵ͕ϳϳϲ ϵϲ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϱϴϬ ϭϮ͕ϲϱϬ ϵ͕ϳϳϴ ϵ͕ϳϴϲ ϳϬ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϳϬϱ ϭϮ͕ϵϮϬ ϵ͕ϳϵϯ ϵ͕ϴϭϵ Ϯϭϱ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϮ͕ϵϳϰ ϭϯ͕ϭϰϲ ϵ͕ϴϮϲ ϵ͕ϴϰϲ ϭϳϮ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϯ͕ϮϯϬ ϭϯ͕Ϯϲϰ ϵ͕ϴϱϲ ϵ͕ϴϲϭ ϯϰ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ t&ͲϮ ϭϯ͕Ϯϵϳ ϭϯ͕ϳϵϬ ϵ͕ϴϲϱ ϵ͕ϵϯϬ ϰϵϯ ϲ ϬϴͬϮϵͬϭϳ KƉĞŶ :t>Zzd/> EŽ ĞƉƚŚ D ĞƉƚŚ ds/ K /ƚĞŵ ϳϮ͘ϳϱ͛ ϳϮ͘ϳϱ͛ Ϯ͘ϰϰϭ ϳ͘ϲϯ ϭϭ͟dƵďŝŶŐ,ĂŶŐĞƌ ϭ цϰϵϬ͛ цϰϵϬ͛ Ϯ͘ϴϭϮ͟ ϱ͘ϯϴϬ͟ ^^^s Ϯ цϱϰϱ͛ цϱϰϱ͛ ϯ͘ϵϬϬ͟ ϴ͘ϯϮϬ͟ ^WƵĂůWĂĐŬĞƌǁͬt&dǀĞŶƚǀĂůǀĞ ϯ цϲϬϱ͛ цϲϬϱ͛ Ϯ͘ϴϭϬ͟ ϯ͘ϱϬϬ͟ yͲŶŝƉƉůĞ ϰ цϲ͕ϴϰϬ͛ цϲ͕ϱϲϬ͛ Ϯ͘ϰϯϳ͟ ϰ͘ϮϲϬ͟ yͲKǀĞƌ;ϯͲϭͬϮǆϮͲϳͬϴͿ ϱ цϭϬ͕ϭϳϬ͛ цϴ͕ϰϵϭ͛ Eͬϰ͘ϬϬϬ͟ ŝƐĐŚĂƌŐĞ͕ŽůƚͲKŶ Eͬ ϰ͘ϬϬϬ͟ WƵŵƉƐ Eͬ ϰ͘ϬϬϬ͟ ^ƚĂŶĚĂƌĚ/ŶƚĂŬĞ Eͬ ϰ͘ϬϬϬ͟ dĂŶĚĞŵ^ĞĂůƐ Eͬ ϰ͘ϱϲϬ͟ DŽƚŽƌƐ цϭϬ͕ϯϬϱ͛ цϴ͕ϲϮϯ͛ Eͬ ϰ͘ϱϲϬ͟ ĞŶƚƌĂůŝǌĞƌͬŶŽĚĞ ΎΎEŽƚĞ ʹ ^ƚƌĂŝŐŚƚ,ŽůĞWƵŵƉdĂŶŐĞŶƚ^ĞĐƚŝŽŶϭϭ͕ϱϭϵ͘Ϯϳ͛ƚŽ ϭϭ͕ϳϬϴ͘ϳϯ͛ 6WHHOKHDG3ODWIRUP 05'&XUUHQW %236WDFN5LJ ^ŚĂĨĨĞƌ^> ϭϯϱͬϴϱD ϮϳͬϴͲϱ͘ϱ ǀĂƌŝĂďůĞƐ ůŝŶĚƐ Ϯ͘ϮϲΖ ZŝƐĞƌ ϭϯϱͬϴϱD&yϭϯϱͬϴϱD& ^ƉĂĐĞƌƐƉŽŽů ϭϯϱͬϴϱD&yϭϭϱD ϰ͘ϱϰΖ Ϯ͘ϴϯΖ ŚŽŬĞĂŶĚ<ŝůůǀĂůǀĞƐ ϮϭͬϭϲϱD 0XG&URVV 0()2 ϰ͘ϯϬΖ ,ǇĚƌŝů '<ϭϯϱͬϴͲϱϬϬϬ ^ϰyϮ^ϰyϮ^ƉĂĐĞƌƐƉŽŽů ϭϯϱͬϴϱDyϭϯϱͬϴϱD +,/&253$/$6.$//& 6ZDFR6XSHUFKRNH%ORRH\/LQH7R*DV%XVWHU/ŶůĞƚ +LOFRUS$ODVND//&+LOFRUS$ODVND//&Changes to Approved Rig Work Over Sundry Procedure6XEMHFW &KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO05'37'6XQGU\;;;;;;$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6HF 3DJH 'DWH 3URFHGXUH&KDQJH 1HZ5HTXLUHG"<1+$.3UHSDUHG%\,QLWLDOV+$.$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO2SHUDWLRQV(QJLQHHU 'DWH • • N 0 o Q Ul Q UI hl o O 0 0 J 0 J N .I-. 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M Z C = o CON W Q CO M m CO Z a) v p p ', ilQ Ilir 'a Q C d Z E CD U 0 z 1 m / 0 rn �/ O 0 m 3 Ndcc w• - co U U 'a c_ E O p o ¢ a 2 v • • Guhl, Meredith D (DOA) From: Cody Dinger <cdinger@hilcorp.com> Sent: Thursday, March 22, 2018 1:16 PM To: Guhl, Meredith D (DOA) Cc: Debra Oudean Subject: RE:TBU M-32 RD2, PTD 217-091, CBL 7/20/2017 Attachments: M 32 RD2 CBL Main Pass.las Hi Meredith, LAS file is attached. From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Thursday, March 22, 2018 1:14 PM To:Cody Dinger<cdinger@hilcorp.com> Cc: Debra Oudean<doudean@hilcorp.com> Subject: RE:TBU M-32 RD2, PTD 217-091, CBL 7/20/2017 Cody, Thank you! I have the log and cd. Can someone please email me the associated LAS file for the log? Thanks, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From:Cody Dinger<cdinger@hilcorp.com> Sent:Thursday, March 22, 2018 7:20 AM To:Guhl, Meredith D (DOA)<meredith.guhl@alaska.gov> Cc: Debra Oudean<doudean@hilcorp.com> Subject: RE:TBU M-32 RD2, PTD 217-091, CBL 7/20/2017 Meredith, I will hand deliver this morning. 1 • . Thanks, Cody From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Wednesday, March 21, 2018 4:00 PM To: Cody Dinger<cdinger@hilcorp.com> Subject: FW:TBU M-32 RD2, PTD 217-091, CBL 7/20/2017 Importance: High Hi Cody, I've twice requested the CBL below from Debra. I haven't heard anything and all data has been checked in. Can you please assist me? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Guhl, Meredith D (DOA) Sent:Tuesday, February 13, 2018 2:46 PM To: 'Debra Oudean' <doudean@hilcorp.com> Subject: RE:TBU M-32 RD2, PTD 217-091, CBL 7/20/2017 Importance: High Debra, Still looking for the CBL referenced below.What's the ETA for delivery to the AOGCC? Thanks, Meredith From:Guhl, Meredith D (DOA) Sent:Thursday,January 4, 2018 1:34 PM To: 'Debra Oudean'<doudean@hilcorp.com> Subject:TBU M-32 RD2, PTD 217-091, CBL 7/20/2017 2 • S Hi Debra, I'm completing the final compliance review on TBU M-32, RD2, completed 9/3/2017.According to the 10-407,two CBLs were completed on this well, one on 7/20/2017 and the other on 8/27/2017.The AOGCC has received the 8/27/2017 CBL but not the 7/20. Please supply the paper CBL log from 7/20 along with the digital data by January 18, 2018. Please send the data to my attention. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 3 • 21 7091 Debra Oudean Hilcorp Alaska, LLC 2 8 REttiVED 3800 Centerpoint Drive, Suite 1400 ` E V Anchorage, AK 99503 Tele: 907 777-8337 lcnrp Alitoka.ij : 7 Fax: 907 777-8510 DATA LOi3GED OCT 1! 2017 E-mail: doudean@hilcorp.com tO 23/2011 , 9r ND'ER AOGCC DATE 10/16/2017 To: Department of Natural Resources Resource Evaluation 550 W 7th Ave, Suite 1100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-32RD2(217-091) CD Data I Daily Reports 10/16/2017 9:18 A... File folder DML Data 10/16/2017 9:18 A... File folder Final Well Report 10/16/2017 9:12 A... File folder t_ LAS Data 10/16/2017 9:12 A... File folder I Log PDFs 10/16/2017 9:13 A... File folder 1, Log TIFFs 10/16/2017 9:14 A... File folder I Sample Photography 10/16/2017 9:14 A... File folder I Show Reports 10/16/2017 9:18 A... File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: 12.9.412-a411.4L. 6 ��/ RECEIVED STATE OF ALASKA OCT 0 4 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT hienee 1 a.Well Status: Oil Q • Gas❑ SPLUG ❑ Other E Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,o45)r1.14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC ti Aband.: 914/2017 , 217-091 /317-344 . 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 July 23,2017 50-733-20462-02-00 . 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 969'FNL,527'FWL,Sec 33,T9N, R13W,SM,AK August 9,2017 TBU M-32RD2 Top of Productive Interval: 9. Ref Elevations: KB: 160' 17. Field/Pool(s): McArthur River Field . 1460'FSL, 1435'FWL,Sec 28,T9N, R13W,SM,AK GL:0 BF:72' West Foreland Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 530'FNL,821'FWL,Sec 33,T9N, R13W,SM,AK 13,889'MD/9,942'TVD . ADL018730 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 214171 y- 2499504 Zone- 4 14,023'MD/9,958'TVD , N/A TPI: x- 215108 y- 2501938 Zone- 4 12.SSSV Depth MDTI VD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 214449 y- 2499964 Zone- 4 491'MD/491'TVD N/A 5.Directional or Inclination Survey: Yes i U (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 183 (ft MSL) 7,209'MD/6,846'TVD 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 ROP DGR EWR-Phase4 CTN ALD MD, DGR EWR-Phase4 CTN ALD TVD,5"&2"FORMATION LOG MD/TVD, LWD COMBO LOG MD/TVD,GAS RATIO LOG MD/TVD, DRILLING DYNAMICS MD/TVD,CBL 7/20/17&8/27/2017 23. CASING, LINER AND CEMENTING RECORD - WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 7" 26# L-80 6,956' 14,018 6,648' 9,797' 8-1/2" 745 sx 15.3 ppg Class G 24.Open to production or injection? Yes Q No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/ND of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 3-1/2"x 2-7/8" 11,694' 546'MD/546'ND **See Attached Schematic for detail** l 61,0 13 7/0 /t1t I i'i-t I, 1i'£ 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. `'' E Was hydraulic fracturing used during completion? Yes❑ No Q 4-� Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 9/5/2017 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 9/13/2017 24 Test Period � -479 130 458.5 N/A 271.4 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 78 50 24-Hour Rate — 479 ' 130 458.5 31 Form 10-407 Revised 5/2017 _%Z_-Zi.. /� �Cf�N,��lJ/F.�ON P�E��t�BdMLA,'s � OCT - 5 20 17 II7 Submit ORIGINIAL on • • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No Q 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 LI Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval WF 11,860' 9,653' information, including reports, per 20 AAC 25.071. D9 9,555' 7,943' Coal 39 10,347' 8,591' G1 10,406' 8,723' G5 10,615' 8,926' H1X 10,748' 9,052' Coal 59 10,777' 9,079' HK2 10,815' 9,113' HK5 11,239' 9,425' HK7 11,719' 9,614' WF 11,843' 9,648' WF2 12,459' 9,765' WF3 13,786' 9,930' Formation at total depth: West Foreland 3 1 31. List of Attachments: Wellbore Schematic, Decomplete, Drilling and Completion Reports, Definitive Directional Surveys,Csg and Cmt Report Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title:Drilling Manager Contact Email: cdlnciert hiIcorp.com Authorized �J Contact Phone: 777-8389 Signature: J/ "( Date: ,O/o3/ ,i 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • Steelhead o Well: M-32RD2Platfr H 0 SCHEMATIC PTD: 217091 API: 50-733-20462-02 Hilcorp Alaska,LL( Last Completed:9/04/2017 RKB to TBG Head=75.15'(16-3/4") RKB to Sea Floor=345' CASING DETAIL jlii;Iin Size Wt Grade Conn ID Top Btm 2 26" Surf 981' 26" F: ? x 3 16" 75 K-55 BTC 15.1 80.1' 1,347' 13-3/8" 61 K-55 BTC 12.5 75.58' 3,767' 52 16" 9-5/8" 53.5 L-80 BTC 8.535 77.06' (TOW) 7" 26 L-80 DWC 6.276 6,956' 14,018' o E TUBING DETAIL -E 3-1/2" 9.3 L-80 IBT 2.992 Surf 6,839' 13-3/8" A 2-7/8" 6.4 L-80 8rd 2.441 6,839' 11,557' TOC @3,758'::, JEWELRY DETAIL No Depth Depth ID OD Item MD ND 72.75' 72.75' 2.441 7.63 11"Tubing Hanger 1 491' 491' 2.812" 5.380" SSSV-Baker TE-5 2 546' 546' 3.900" 8.320" ESP Dual Packer D&L Oil Tools w/WFT vent valve 3 604' 604' 2.810" 3.500" X-nipple ' 4 6,839' 6,559' 2.437" 4.260" X-Over(3-1/2 x 2-7/8) 11,557' 9,562' N/A 4.000" Discharge,Bolt-On 11,558' 9,562' N/A 4.000" Pumps(x3) -400 Series,111 SF2700 5 11,629' 9,585' N/A 4.000" Standard Intake 4 11,630' 9,591' N/A 4.000" Tandem Seals-400 Series,BPBSL 11,647' 9,591' N/A 4.560" Motors (x2)-456 Series,FMS 160HP Hanger 6,956';., 23 11,694' 9,606' N/A 4.560" Centralizer/Anode TOW 7,209' i,A s 9-5/8" **Note-Straight Hole Pump Tangent Section 11,519.27'to 11,708.73' TOC @ 9,540' PERFORATION DATA Zone Top Btm Top Btm Feet SPF Date Status :,:,:. (MD) (MD) (ND) (ND) WF-1 11,860 11,881 9,653 9,658 21 6 08/29/17 Open I Aml WF-1 11,912 12,094 9,665 9,704 182 6 08/29/17 Open WF-1 12,145 12,401 9,714 9,759 256 6 08/29/17 Open WF-2 12,462 12,558 9,765 9,776 96 6 08/29/17 Open pen - WF-2 12,580 12,650 9,778 9,786 70 6 08/29/17 Open i -- WF-1 ,1�� 7 WF-2 12,705 12,920 9,793 9,819 215 6 08/29/17 Open ` f r WF-2 12,974 13,146 9,826 9,846 172 6 08/29/17 Open WF-2 13,230 13,264 9,856 9,861 34 6 08/29/17 Open L. - we-2 WF-2 13,297 13,790 9,865 9,930 493 6 08/29/17 Open PBTD: 13,889'(MD)/9,942'(TVD) TD: 14,023'(MD)/ 9,958'(TVD) Max Hole Angle 84.12°@ 13,071' Updated By:JLL 09/21/17 • • Hilcorp Energy Company CASING &CEMENTING REPORT Lease&Well No. MRF M-32RD2 Date Run 20-Aug-17 County CIO State Alaska Supv. Shane Hauck/Andy Lundale CASING RECORD Liner V' TD 14,023.00 Shoe Depth: 14,018.00 PBTD: 13,891.00 No.Jts.Delivered No.Jts.Run 174 No.Jts.Returned Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top SHOE 7 3/4 DWC/C Davis Lynch 2.54 14,018.00 14,015.46 7"shoe jt 7 26.0 L-80 DWC/C Vam 40.57 14,015.46 13,974.89 7"FC jt 7 26.0 L-80 DWC/C Vam 40.61 13,974.89 13,934.28 Float Collar 7 DWC/C Davis Lynch 1.35 13,934.28 13,932.93 7"LC jt 7 26.0 L-80 DWC/C Vam 40.53 13,932.93 13,892.40 Landing Collar 7 DWC/C Baker 3.39 13,892.40 13,889.01 7 PuP jt 7 26.0 L-80 DWC/C Vam 3.41 13,889.01 13,885.60 7 Liner 7 26.0 L-80 DWC/C Vam 41.09 13,885.60 13,844.51 170 7 Liner 26# 7 26.0 L-80 DWC/C Vam 6,857.79 13,844.51 6,986.72 xo 7 2.43 6,986.72 6,984.29 LTP 7 28.54 6,984.29 6,955.75 Csg Wt.On Hook: Type Float Collar: Antelope No.Hrs to Run: 28 Csg Wt.On Slips: 325 Type of Shoe: Reamer Float Shoe Casing Crew: Rotate Csg Yes X No Recip Csg X Yes No 50 Ft.Min. 9.85 PPG Fluid Description: OBM Liner hanger Info(Make/Model): Baker 7"Uniflex Liner Hanger Liner top Packer?: X Yes No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: Sprial solid body centralizers ran on every joint 5-93. CEMENTING REPORT Shoe @ 14018 FC @ 13,932.00 Top of Liner 6955 Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 12.1 Volume pumped(BBLs) 18 Lead Slurry Type: Primary Class G Sacks: 745 Yield: 1.24 Density(ppg) 15.3 Volume pumped(BBLs) 165 Mixing/Pumping Rate(bpm): 3.5 Tail Slurry w Type: Sacks: Yield: F Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): y Post Flush(Spacer) w Type: Density(ppg) Rate(bpm): Volume: LL Displacement: Type: OBM Density(ppg) 9.85 Rate(bpm): 5 Volume(actual/calculated): 364.7/368.5 FCP(psi): 1623 Pump used for disp: MP#2 Bump Plug? X Yes No Bump press 3000 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 7:46 Date: 8/21/2017 Estimated TOC: 10,000 Method Used To Determine TOC: Calc. "2" l C i3'- 5 i ,�,,j 7 t c_ °I. s-0' At I) Post JolCCalculations: Calculated Cmt Vol @ 0%excess: 96.5 Total Volume cmt Pumped: 165 Cmt returned to surface: 0 Calculated cement left in wellbore: 159.9 OH volume Calculated: 163 OH volume actual: 269 Actual%Washout: 75 www.wellez.net WellEz Information Management LLC ver_102716bf • • Hilcorp Energy Company Composite Report Well Name: MRF M-32RD2 Field: McArthur River Field County/State: CIO,Alaska (LAT/LONG): svation(RKB): API#: Spud Date: Job Name: 1712187P M-32RD2 PreDrill Contractor AFE#: AFE$: 7/12/2017 Finish unhooking all service lines from upper wellbay. Pull up skirting around sub base.Remove handrails&moveable stairs in path of skid.Retracted diverter lines. Unplug rig power&hook up umbilical.Remove earthquake clamps&install guide plates.Install moving cylinders&hydraulic clamps.,Skid rig from M-06 to center deck.,Crane hatch covers from NW wellbay to NE wellbay.Crane all interconnect lines from NE wellbay to NW wellbay.Begin to move jacks from west side to east side. 7/13/2017 Cont Moving Grabbers To Drillers Side Of Rig,Cont Skidding Rig -Pull Upper Wellbay Hatch-Install Guard Rails- Center Up On M-32,Install&Tighten Earthquake Clamps-Install Hand Rails-Hooked Up Air And Water Lines-Hook Up Low Pressure Mud&SaltWater Rebuilt Stand Pipe Valve Installed Flow Line to Flow Line Trough,Well Pressure Tree=0,9 5/8 by 4 1/2 Annulus=650,13 3/8 by 9 5/8 200, 16 by 13 3/8 110,26 by 16 135-Pull Tree Cap-Rig Up Pollard Slick Line-Pressure Test Lubrication-Swab Valve Packing Leaking-Fix Same-Pressure Test Lubricator to 1,500psi,RIH With 3.60 Gage Ring To 7,020 slm(159'Below Packer,805'Above Tubing Tail)-Pick Back Up And Lost Hole to 6,945s1m(84'Below Packer,805'Above Tubing Tail-Trip Wire And Pick Up A 2.85 Gage Ring-RIH With Same And Tagged At 6945 slm-Trip Out With Wire-Close Swab,Hook Up High Pressure Mud Line To Rig-Rigged Up Lines In Wellhead Room For Circulating Well,Continue rigging up lines in wellhead room. Line up high pressure mud line to NW leg with production.Fluid pack all lines&test to 500/2500 psi.,Bullhead down tubing at 1 bpm,catching pressure at 5 bbls away.Continue pumping at 1 bpm,at 17 bbls away observed a pressure drop f/2050 psi to 1650 psi. Pumped 18.3 bbls away&observed pressure drop f/1950 psi to 1750 psi.Shut down pump at 1900 psi,check surface equipment&annulus pressures.Continue pumping to 20.4 bbls away w/2500 psi.Monitor then bleed off pressure.,Run a 2.85 gage ring, RIH and tagged at 7300 slm.Trip out with wire and close swab. Rig down slick line.,Rigging up e-line for tubing punch run.,M-32RD2 wellhead pressures 4-1/2X9-5/8=630psi,9- 5/8X13-3/8=200psi, 13-3/8X16=110psi, 16X26=135psi. 7/14/2017 Continue rig up of e-line. Pressure test lines to 250/2500 psi,good.,RIH with e-line to punch 4.5"tubing.Get on depth&shoot holes in the bottom of the 1st full joint above the packer f/6845-6847'ELMD.Pressure up tubing to 500 psi,IA 150 psi.Confirm shots w/pressure equalize.Attempt to circulate,issue w/ pumps.TON w/e-line&trouble shoot pump issue.,Line up&pump down the tubing taking returns from the IA to production Group Sep-Worked Rate Up to 4Bbl/min With A Slow Increase In Tubing Pressure From 450psi to a Final Press Of 900psi 465Bbl Pumped,Check Shut In Pressures While Rigging Down E Line Lubricatior-Bleed Down From 150psi To OPsi-Tubing&Annulus Dead-,Install Back Pressure Valve,Remove 18"Section From Stand Pipe-Work On Handrail Change In Sub Deck-Repair Hole In Flow Box,Check Hanger Void For Pressure-Nipple Down Production Tree-Dress Hanger For BOP Test- Function Lock Down Screws,Make up 16-3/4"X 20'riser to wellhead.Mobilize gray lock clamp to upper wellbay.Position upper 16-3/4"X 20'riser in upper wellbay.,Continue nipple up of BOPE.Continue to torque bolts on lower riser. Install gray lock clamp on hub connection between risers. Nipple up 16-3/4"5M X 16-3/4"10M DSA&single gate rams.Bolt up manual&HCR valves on mud cross.,M-32RD2 wellhead pressures 4-1/2X9-518=0psi,9-5/8X13-3/8=155psi, 13- 3/8X16=200psi, 16X26=90psi,26x31=135. 7/15/2017 Nipple up BOPE.Make up manual&HCR valves on mud cross.Install mud cross on single gate.Observe obstruction for operation of double gate ram doors. Remove mud cross&single gate.Install 34"spacer spool&set mud cross with single gate.Pick up&install double gate rams.,Continue nipple up of BOPE. Install Koomey hydraulic lines to stack. Install air boot flange to annular. Bolt up Kill&Choke hoses to the valves on the mud cross.,Pick up&make up annular. Continue hooking up Koomey lines to BOPE. Install flow box cover.,Set flow riser.Energize accumulator unit&function BOPE.,Pick up test tools.Air up boots on flow riser.Fold Skate into place. Pick up&make up 4.5"test joints.Flood all lines with water for testing. Function test annular to condition new element.,Shell test BOP's to 250 psi,found leak from choke hose flange.Retighten&test again staging up pressure to 3200 psi. Found leak at top rams at the doors.Begin tightening doors.,M-32RD2 wellhead pressures 4-1/2X9-5/8=0psi,9-5/8X13-3/8=150psi,13-3/8X16=180psi, 16X26=95psi,26X31=130. 7/1 6/201 7 Attempt to shell test BOPE after tightening upper ram doors,still leaking.Open doors,changeout door seals,&tighten doors up.,Attempt to sheel test&door seals not leaking.Observe tail stem packings leaking from choke&kill HCR valves. Blow down stack.Change out stem packing seals.Pressure up again and still bleeding off.Close top rams,kill&choke NCR's valves with pressure still bleeding off.,Remove test sub from hanger&lay down with test joints.,Pull BPV& install TWC.Test blinds to 250/3500 psi for 5 minutes each,good test.,Install4.5"test joint.Attempt to shell test,observe pressure drop&returns from IA. Determine that chemical injection port damaged causing communication.Confer with engineer&notified AOGCC of plans to conduct rolling test on annular& upper 4-1/2"rams as per Sundry requirements.,Rig up&test choke manifold valves 1-10, 12,13,14;upper&lower IBOP;FOSV;dart vavle to 250/3500 psi for 5 minutes each charted.Perform accumulator test Initial System Pressure 2950 psi,After Closure 1100 psi,200 psi Attained in 50 seconds,&Full Pressure Attained in 207 seconds.Nitrogen Bottles:8 averaged at 2460 psi.Test gas alarms,pit level gain/loss,&flow show.,Line up&perform rolling test on the annular to 250 psi @.176 bpm;increase to 3500 psi @.176 bpm for 5 minutes each.No leaks observed at annular.Did see leak from upper ram door seal on ODS.,Open upper ODS ram door.Clean,inspect&change out door seal.Could not find anything to cause leak.Make up ram door.Talk to BOP vendor& reference Cameron spec sheet to determine door bolts need to be torqued to 7331 ft/Ibs.,Wait on wrench to to tighten ram doors.SIMOPS Perform derrick inspection,install guard/softner on kelly hose,&housekeeping.,Torque bolts on all ram doors to 7331 ft/lbs per Cameron spec.'s.,Line up&perform rolling test on the 4-1/2"solid body upper rams to 250 psi®.176 bpm;increase to 3500 psi @.176 bpm for 5 minutes each,charted.No leaks observed at rams or any other part of BOPE.Rig down test equipment.,Pull TWC from hanger.,Rig up handling equipment to pull hanger to the rig floor. BOLDS.,Pull hanger&packer free at 235K PU.Line up to circulate through the gas buster.Close upper rams&circulate at 2-5 bpm,120-650 psi. Experiencing intermittent packing off around the packer.,M-32RD2 wellhead pressures 4-1/2X9-5/8=0psi,9-5/8X13-3/8=150psi,13-3/8X16=180psi, 16X26=95psi,26X31=130. • • 7/17/2017 Continue circulating down the tubing taking returns through the choke manifold,ICP 2 bpm=240 psi,4 bpm=400 psi,6 bpm=600 psi.After pumping 190 bbls experience packing off around the hanger.Rig up high pressure hole from annulus to choke manifold.Continue circulating FCP 3 bpm=170 psi,4 bpm= 330 psi.Monitor well,static.,Pull hanger to the rig floor;PU 150K,SO 140K.Terminate control lines from hanger.Plug control line ports.Change out hanger seals.Blow down circulating line.Rig up power tongs.Check torque on landing joints on the way in to land hanger.,Drain stack,land hanger&RILDS.,Install two way check.,Rig up 4.5"test joints&test equipment.Perform shell test to 250/3500 psi,good.,Test BOPE with 4-1/2"test joint to 250/3500 psi 5 minutes each test,charted.Test annular,upper 4-1/2"pipe rams,blind rams, HCRs kill/choke,manuals kill/choke,and kill line demco.Monitor IA while testing.Test witnessed by AOGCC Adam Earl.Blow down lines&rig down test equipment.,Make up landing joint,change out elevators to 4-1/2".Pull hanger to the rig floor, PU 150K. Lay down hanger&blow down lines.Monitor well,static.,TOH laying down 4-1/2",12.6#,L-80,TCII tubing from 7750'-5340'MD,PU 117K,pulled 456'of 1/4"&2010'of 3/8"control lines,recovered 79 stainless steel clamps.,TOH laying down 4-1/2",12.6#, L-80,TCII tubing from 5340'-2120'MD,PU 75K.,M-32RD2 wellhead pressures 4-1/2X9-5/8=0psi,9-5/8X13-3/8=160psi,13-3/8X16=180psi,16X26=95psi,26X31=130. 7/18/2017 TOH laying down 4-1/2",12.6#,L-80,TCII tubing from 2120'-410'MD.,TOH laying down 4-1/2",12.6#,L-80,TCII tubing from 410'to surface.Tubing full of Poly Plug Clear Gel from previous squeeze job.,Rig down handling equipment&send down to the top deck.Clean rig floor of Poly Plug.,Make up test tools& set test plug.Close blind rams for upper ram change.,Change out upper rams from 4.5"to 4"solid body rams.,Test upper rams&annular w/4"test joint to 250 /3500 psi for 5 minutes,charted. Lay down 4"test joints&make up 5"test joints.Test lower 5"X7"VBR's with 5"test joints to 250/3500 psi for 5 minutes each,charted.,Lay down test equipment&pull test plug.Install 15"ID wear bushing,RILDS.,Test high pressure mud lines from mud pumps to top drive,to 3500 psi.One small leak observed at newly install pop off valve on mud pump.Union tightened&tested good.,Make up clean out assembly BHA 1;8-1/2"Bit, Casing Scraper,Bit Sub w/Float,Pup Joint, Upper Window Mill,1 joint of 5"HWDP.,Repair Iron Roughneck.Hose for backup grabber failed.Made new hose &installed,tested good.,Continue picking up BHA 1, 14 joints of 5"HWDP&XO 4-1/2"IF X 4"HT38.Total length 482.48'MD.,TIH w/cleanout assembly f/ 482'-6000'MD,PU 156K,SO 148K.,M-32RD2 wellhead pressures-9-5/8=0psi,9-518X13-3/8=155psi,13-318X16=190psi,16X26=105psi,26X31=130psi. 7/19/2017 TIH w/BHA 1 f/6000-6065'MD, PU 156K,SO 148K.Tagged up at 6004'MD&went through w/10K drag each way.Worked 2 times&continued in tagging up at 6065'MD,setting 15K WOB.Picked up to 6035'MD to change out saver sub to 4"HT38.,Change out saver sub from 4-1/2 IF to 4"HT38.,Change out grabber lift ram&pin block on Top Drive.,Continue changing out saver sub&inspect top drive.,TIH f/6035-7640'MD,PU 175K,SO 160K,cleaned up tight spot at 6070'MD.,CBU at 7640'MD, PU 175K,SO 160K,5 bpm,360 psi.Shaker screens blinded off with ploy plug gel.Work pump rate 1-3 bpm to keep fluid on the shakers.Transfer poly plug returns to totes.Max gas 550 units.,Wash down f/7640'-7998'MD,tagging TOC w/10K,PU 180K,SO 165K,4 bpm,220 psi,FO 34%.,CBU at 7998'MD,PU 180K,SO 165K,6 bpm,500 psi.Shaker screens blinded off with ploy plug gel.Work pump rate 1-3 bpm to keep fluid on the shakers.Transfer poly plug returns to totes.Stage pumps up to 14 bpm,2430 psi for second BU to ensure casing clean.,Rig up test casing,fluid pack lines &line up to pump.Pressure up to 510 psi,in 11 strokes,1.1 bbls.Shut in&observe pressure,for 10 minutes,decrease to 490 psi.Bled back 1 bbl to the trip tank. Blow down top drive&kill line. SCR @ 7998'MD,FIW 8.5 PPG;MP#1 @ 30=150;©40=240 psi;MP#2 @ 30=160;@ 40=240 psi,Service top drive,drawworks,&ST80.,TOH laying down 4"DP from 7998'-4248'MD, PU 132K,SO 132K.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=160psi,13-3/8X16=180psi, 16X26=95psi, 26X31=135psi. 7/20/2017 TOH laying down 4"DP f/4248'-482'MD.,TIH with 9 stands of 4"DP stood back in the derrick from 482'-1330'MD,PU 95K,SO 95K.,TOH laying down 4"DP f/1330'-482'MD,PU 82K,SO 82K.,TOH standing back 5"HWDP&laying down BHA1, from 482'to surface.,Clear&clean rig floor of 3rd party tools&4" handling equipment.,Rig up a-line&mobilize tools to rig floor.,Run CBL on e-line from 3050'to 7992'ELM.,Log f/7992'-3050'ELM Rig down e-line equipment.,Change saver sub from 4"HT38 to 4-1/2IF.,Make up&TIH with 2-7/8"cement stinger;22 joints of 2-7/8",6.5#,L-80,8RD EUE tubing,&2 XO's to 698'MD, PU 66K,SO 66K.,TIH picking up 5"DP f1698'-1265'MD,PU 70K,SO 70K.,Service drawworks,ST-80&top drive.,TIH picking up 5"DP f/1265'- 4460'MD, PU 130K,SO 130K.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=160psi, 13-3/8X16=180psi,16X26=95psi,26X31=135psi. 7/21/2017 TIH w/cement stinger picking up 5"DP f/4460'-7820'MD.PU 205K,SO 195K.,Service top drive,drawworks,&ST-80.,TIH w/cement stinger picking up 5" DP f/7820'-8021'MD, PU 210K,SO 200K,calculated displacement 64.3,actual 56.5 bbls.,Pick up to 7982'&wash back down to 8021'MD,tagging up w/ 10K,10 bpm,800 psi, FO 58%. No increase in pressure observed.Pick up to 8010'MD.,Rig up E-line&gyro tools.Test tool&monitor weII.,TIH w/gyro in 5" DP,logging in to 7275'ELM&out of the hole.,Lay down logging tools&e-line equipment.,Circulate&condition 5-9 bpm,200-640 psi,FO 37-57%.Rig up cement line on rig floor&flood lines.,PJSM,pump 10 bbls of H2O at 3 bpm,180 psi.Shut in&PT lines to 200/3000 psi,good.Batch up 15.0 ppg cement. Pump 52.1 bbls of 15.1 ppg cement at 3 bpm,310 psi,FO 34%.Pump 5 bbls of H2O at 4.5 bpm,260 psi.Swap to rig pump at 12.5 bpm,catching pressure at 82 bbls away.Reduce rate to 7-8 bpm,300-450 psi,FO 53%.Pump 123 bbls total displacement.Estimated TOC 7262'MD.CIP @ 22:33 hrs.,TOH f/8010'- 6752'MD,at 30-50 fpm,PU 185K,SO 180K.,Load wiper ball in drill pipe&circulate surface to surface at 5-12 bpm,220-860 psi.Had to reduce rate for short time,as small amount of poly plug material returned to shakers.No cement observed at bottoms up.Monitor well,static.,TOH f/6752'-698'MD,PU 66K,SO 66K.,TOH laying down 2-7/8"cement stinger,698'to surface.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=160psi, 13-318X16=180psi, 16X26=100psi,26X31=135psi. 7/22/2017 Rig up a-line w/8.25"gauge ring&junk basket.TIH to 7286'ELM,tagging cement.TOH&lay down same.,WOC,SIMOPS replace track for service loop on skate,service both vac units,service drawworks,service/CO dies on ST-80,rig up GeoSpan w/Sperry&housekeeping.,Rig up equipment to test 9-5/8" casing&cement plug.Flood lines&close blind rams.Pressure to 2500 psi with 5.1 bbls,chart for 30 minutes.Bled back 5 bbls to trip tank. Rig down test equipment&blow down lines.,Rig up a-line equipment&make up 8.125 cast iron bridge plug.,TIH WI Baker CIBP to locate CCL depth at 7223'.Set top of CIBP 12'from CCL at 7235'ELM.Good indicators of set.TOH&rig down a-line equipment.,Remove wear bushing.,Mobilize Whipstock BHA to rig floor. Pick up anchor(3 screws©6630#each,down shear to SET©19890#),Whipstock Slide Gen II,window mill(install brass bolt w/shear at 47K),lower watermelon mill,flex joint,upper watermelon mill,1 HWDP,TM collar,DM collar,float sub,&15 HWDP.BHA 555.49'MD,PU 85K,SO 85K.SHT MWD 350 gpm,450 psi,good test.,TIH w/Whipstock BHA f/555-2827'MD,PU 136K,SO 130K,50-60 fpm.,TIH w/Whipstock BHA f/2827'-3860'MD,50-60 fpm.,Fill pipe, pressure test GeoSpan 250/3000 psi,good.,TIH w/Whipstock BHA f/3860'-7081'MD,50-60 fpm.,Orient&set whipstock.Fill pipe at 411 gpm,825 psi,12L. TIH f/7081'-7229'MD orienting w/left hand turn to 68L,PU 205K,SO 215K.Tag CIBP at 7231'MD w/6K.Turn pumps off,pick up 5'&set down 15K to shear set anchor.PU to 225K(10K over)to confirm anchor set.SO to 165K(40K)to shear brass bolt.PU 5'w/215K to confirm free travel.Top of slide at 7209' MD&bottom of slide at 7226'MD.,Obtain parameters with FIW PU 215K,SO 205K, ROT 210K,30&40 rpm,Tq 5K,425 gpm 890 psi.,Start shipping FIW from pit system to Trading Bay. Prepare to displace well to 8.9 ppg OBM.,M-32RD2 wellhead pressures-9-518=0psi,9-5/8X13-3/8=160psi,13-318X16=190psi, 16X26=95psi,26X31=140psi. • 9 ki•Y' 7/23/2017 Displace well to 8.9 ppg, 110 vis OBM.Pump 25bb1 spacer&chase WI OBM @ 425 gpm, ICP 940 psi, FCP 1420 psi,50 rpm,Tq 5K,reciprocating.Caught 20 bbls of spacer&fully displaced pumping 479 bbls.,Rig up to test BOPE.Rack back 1 stand&pull 2 singles 7060'MD.Make up test plug,space out pups,& valves.Set plug&hang off string.Flood all lines&line up for shell test.,Perform shell test on BOPE to 250/3500 psi.Change out fitting on test hose. Tightened up flange on top of annular.Retest good.,Test BOPE w/4"&5"jts,to 250/3500 psi,for 5 min each,charted.Test annular&upper 4"rams;annular &lower 5"X7";blinds;CV#1-14;upper&lower kelly valves;FOSV;Dart valve;choke line valves,kill line valves,HCR valves;hyd&man chokes.Acc.test: initial system pressure 3000 psi;pressure after closure 1200 psi;200 psi attained in 49 seconds;full pressure attained in 239 seconds.8 bottles at 2500 psi.,Pit level indicators,trip tank,&flow indicators tested.Witness waived by AOGCC Rep.Jim Regg.,Rig down test equpment,blow down lines,drain stack of H2O, &lay down test plug.,TIH f/7060'-7209'MD,PU 215K,SO 200K.,Mill window per Baker Rep ft 7209'-7218'MD,PU 215K,SO 200K,ROT 200K,100 rpm,Tq on 8K,Tq off 5.5K,400 gpm,1270 psi,FO 58%.,Mill window per Baker Rep ft 7218'-7231'MD,PU 215K,SO 200K,ROT 200K,80 rpm,Tq on 5.5K,Tq off • 5.5K,4250 gpm,15600 psi,FO 42%.Milling started slowing 7228'MD.Samples showing a hard large sand conglomerate formation. TOW 7209'MD,6846'TVD;BOW 7226'MD,6859'TVD.,M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=165psi,13-3/8X16=195psi, 16X26=95psi, 26X31=140psi. Fluid loss 24hrs:Obbls Total:0 bbls Metal recovered 24hrs:280 lbs Total:280 lbs 7/24/2017 Mill window per Baker Rep ft 7231'-7233'MD, PU 215K,SO 200K,ROT 200K,70-100 rpm,Tq on 5-8K,Tq off 5.5K,250-450 gpm,550-1540 psi, Fr-58%. Milling started slowing 7228'MD. Formation outside of window-50%Conglomerate sand,30%Conglomerate,10%Sand, 10%Sandstone. TOW 7209'MD,6846'TVD; BOW 7226'MD,6859'TVD.,Monitor well,static.Obtain SCR at 7233'MD,6865'TVD,MW 9.0ppg Pump#1 @ 30=250;@ 40=310 Pump#2 @ 30=240;@ 40=310,TOH f/7233'-533'MD, PU 80K,SO 80K.,TOH w/BHA 2 to surface.Lay down starter mill,flex joint,TM collar&DM oar. Calculated fill 67.9,actual 69.8 bbls.,Make up BHA 3 w/8.5"roller cone,bit 1 RR1,lower watermelon mill,upper watermelon mill,1 HWDP,float sub(ported), 3 NMFC,&15 jts HWDP,597'MD, PU 85K,50 85K.,TIH ft 597'-7186'MD,PU 210K,SO 200K,calculated displacement 89.3,actual 83 bbls.,Wash down at 295 gpm,550 psi,tag up at under gauge hole at 7223'MD.Ream to 7233'at 295 gpm,550 psi,90 rpm,Tq 9-10K. Drill/mill 7233-7237'MD,480 gpm,1200 l psi,90 rpm,Tq 8-9K,off 5K,WOB 15-20K,FO 64%,PU 210K,SO 200K,ROT 205K.,TOH f/7237'-7182'MD&CBU at 506 gpm, 1307 psi,FO 68%,3770 strokes pumped.,Rig up test equipment&flood lines.Perform FIT at 6846'TVD with 9.0Qpg OBM. Pump 3.3 bbls at.5 bpm,pressuring up to 1254 psi,12.52 ppg EMW.Shut in&record,pressure decreased to 1173 psi in 5 minutes.Bled back 2.8 bbls. Rig down test equipment.,Wash down f/7182'-7237'MD,290 gpm,455 psi.Drill ahead 7237'-7256'MD,475 gpm,1170 psi on,1140 psi off,FO 64%,90 rpm,Tq on 8K,off 6K,WOB 20K,PU 210K,SO 200K,ROT 205K,max gas 20,bit 1.24 hrs.,Work through window 2 times,no issues.TOH to 7123'MD.,CBU 2 times at 500 gpm,1230 psi,FO 66%,pump 6600 strokes. Obtain SCR at 7233 MD,6865'TVD,MW 9.0ppg Pump#1 @ 30=240;@ 40=290 Pump#2 @ 30=250;@ 40=300,Cut&slip 142'of drill line.Service drawworks&top drive.,TOH f/7123-139'MD,standing back HWDP&NMFC.,M-32RD2 wellhead pressures-9-5/8=Opsi,9-5/8X13-318=16Opsi,13-3/8X16=205psi,16X26=95psi,26X31=140psi. Fluid loss 24hrs:Obbls Total:0 bbls Metal recovered 24hrs:294 lbs Total:574 lbs �/ • • Hilcorp Energy Company Composite Report Well Name: MRF M-32RD2 Field: McArthur River Field County/State: CIO,Alaska I(LAT/LONG): evation(RKB): API#: Spud Date: 7/26/2017 Job Name: 1712187D M-32RD2 Drilling Contractor Steelhead 51 AFE#: AFE$: 7/25/2017 Cont Laying Down Mills&Bit(TOW=7,209 BOW=7226)-Upper Watermelon In Gage-Clear Rig Floor&Rig For Ram Change.;Change Upper Rams To 5"- Some Trouble Breaking Door Bolts.;Pressure Test Upper Pipe Rams 250psi Low 3,500psi High.;lnstall 15"ID Wear Bushing.;Make Up Sperry RSS BHA#4- Down Load.;Shallow Test MWD -Load Source.;RIH to 748 md.;TIH p/u 5"dp,t/1787',Up/dn wt 120k,;Cont.TIH t/7182', up wt.215k,dn wt.205k.;CBU @450 gpm,2070 psi,rot wt 212k,10 rpm 5ktq,60 rpm 5.5ktq.;RIH U 7248',tag,wash&ream 07256',Drilling With RS f/7256,07283' PU 220k SO 200k R 208 452gpm 2030psi 12 to 15k WOB 30rpm Tq.7k on,6k off.;Drilling With RS f/7283' t/7340'PU 220k SO 200k R 208 452gpm 2030psi 12 to 15k WOB 30rpm Tq.7k on,6k off.;M-32RD2 wellhead pressures-9-5/8=0psi,9-518X13-3/8=165psi,13-3/8X16=200psi,16X26=90psi,26X31=130psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:0, total-574#. 7/26/2017 Directional Drilling With Rotary Steerable 7340 to 7500-Not Getting The DL Out Of Rotary Steerable at this Point To Stay On WP#7 6/100 Plan(Getting 4/100)- PU 223 SO 201 R 208 396gpm 1680ps1.;32k WOB 80rpm 12k torque-Drilling Several Coal Stringers In This Section.;Rotary Drilling w/RS 7500 t 7557(57'/hr PIG)-PU 223 50 201 R 208 396gpm 1680psi 32k WOB 80rpm 12k tor-Getting 4 to 5 DLS.;Work Pipe WithCir&Without Rotation Worked Each Stnd Several Times Pulling Back To 7,386 While Working With Anchorage Engineering to Get A Approved Plan Forward-Run Back To 7,554(3'Of Fill).;Directional Drilling With RS 7557 T 7755 (PIG 66'/hr)PU 223 SO 201 R 212 450gpm 2270psi 100rpm 12k tor 32k WOB-Getting Better Tool Yield.;Dir Dril With RS-7755 T 7876 (121'40'/hr PIG)PU 223 SO 201 R 208 475gpm 2,250psi 80rpm 123k tor 32k WOB.;Dir Dril With RS-f/7876 t/8002(126'42'/hr PIG)PU 223 SO 201 R 212 505gpm 2,470psi 100rpm 12k tor 32k WOB.;Dir Dril With RS-f/8002 T/8142'(140'46'/hr PIG)PU 223 SO 201 R 213 525gpm 2,560psi 125rpm 12k tor 32k WOB.;Dir Dril With RS-f/8142'8312(170'56'/hr PIG)PU 225 SO 198 R 212 525gpm 2,560psi 145rpm 12k tor 30k WOB.;Dir Dril With RS-f/8312 t/8472(160' 53'/hr PIG)PU 225 SO 198 R 212 520gpm 2,610 psi 145rpm 12k tor 30k WOB.;Distance to plan 43.03' 21.07 Low 37.52 Right;M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-318=160psi,13-3/8X16=200psi,16X26=90psi,26X31=135psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:45, total-619#. 7/27/2017 Drilling With Rotary Steerable 8490 T 8691 (201 67'/hr PIG)PU 226 SO 195 R 211 525gpm 2510psi 155rpm 10k tor 20 to 30k WOB.;DrI W RS 8691 t 8830 (139'46'/hr PIG)PU 226 SO 195 R 211 525gpm 2510psi 155rpm 10k tor 20 to 30 WOB.;Dir Drl W RS 8830 T 9030(200'66'/hr PIG)PU 235 SO 197 R 214 525gpm 2560psi 155rpm 12k tor 20 t 30k WOB.;Dir Drl W RS 9030 T 9210(180'60/hr PIG)PU 235 SO 197 R 214 525gpm 2600psi 150rpm 14k Tor 20 to 30k WOB.;Dir Dr!W RS f/9210 09448 (238'79'hr PIG)PU 238 SO 197 R 214 525gpm 2600psi 150rpm 12k Tor 20 to 30k WOB.;Dir Drl W RS f/9448 t/9639' (190'63'/hr PIG)PU 235 SO 197 R 214 525gpm 2700psi 150rpm 12k Tor 20 to 30k WOB.;Saver sub broke at lower IBOP while making connection, CBU 515 GPM, 2520psi,C/O saver sub.;Dir Dr!W RS f/9639'09736 (97' 64'/hr PIG)PU 235 SO 197 R 214 525gpm 2700psi 150rpm 12k Tor 20 to 30k WOB.;Saver sub broke on connection,m/u&install space out shim for grabber.;Dir DrI W RS f/9736 t/9828 (92' 64'/hr PIG)PU 235 SO 197 R 214 525gpm 2700psi 150rpm 12k Tor 20 to 30k WOB.;Distance to plan 17.48' 17.48'High .46' Left;M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=160psi,13-3/8X16=200psi,16X26=90psi,26X31=135psi. Fluid kiss 24hrs•[) Tntal•0 Metal rernvered 74hrs•Rd fatal-RR'i# 7/28/2017 Directional Drilling With Rotary Steerable 9828 T 10075(247'41'/hr PIG)PU 270 SO 217 R 238 527gpm 2,760psi 150rpm 25 to 30K wob 9k tor.;Dir Dril W RS 10075 T 10112(37'37/hr PIG)PU 270 SO 217 R 238 525gpm 2770psi 150rpm 10k tor.;Cir For Trip 4X Btms Up-Started Getting Few 1 Quarter Size Cuttings Towards End Of 2nd Btms Up-Still A Few at End Of Cir-Looked Worn and Blocky.;Flow Check-Trip Out 10,112 to 7,148 Travel Wt 225 to 250 Some 20k Overpulls When Pulling Through Coals But always Moving-at 7770 had a sharp 35k overpull past travel wt of 230-took some Weight.;Break Back Down 20K- Kelly Up And Establish Cir At 170gpm-Worked Up Slowly Through Tight Spot With 5 to 10 k Overpull and No Pack Off-Passed Through Once More With 400gpm-And Once W/Pumps Off.;Cont Out To 7426 Where Bigger Tools Started Across Whipstock-Did Have Some 20K Overpulls Hard To Read If It Was Big Tools Or The Coals-I Think It Was Coals-Did Not See Anything as Bit Cleared.;Service rig,function test BOPE.;Cont.POOH f/7148't/748',up dn wt 100k.;Stand Back&1/d BHA tools,unload sources,&down load MWD data,cont.POOH c/o bit,grade 5-1-RO-C-X-I-BT-PR.;M/U Kymera bit.;Distance to plan 35.3 27.8'High 21.75'Left;M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=180psi,13-3/8X16=220psi,16X26=60psi,26X31=125psi. Fluid[Ass 94hrs•n Tntal.r) Mortal rornvored 24hrs•7n tntal-71Vitt 7/29/2017 Cont.Make Up Sperry RSS BHA#4-Up Load tools,Shallow Test MWD -Load Source.;Trip In Hole With BHA#5 To 4260.;Repair Hose Fitting On Pipe Handler.;Cont RIH to 6899'. 310'Above Top Of Window.;Cir Btms Up To Shear Mud.;RIH With BHA#4 To Top Of Window at 7209-Cont RIH to 7426 Where Bigger Tools Passed The Btm Of The Window-At This Point Do Think The The 10 to 20k Drag We see Is The Big Tools Across The Whipstock;Cont RIH With BHA#4 To 7655 Coal At This Point-Also Same Area That We Started Getting 6&7 deg/100 DLS-Took 50k Set Down At This Point Could Not Work Past- Kelly Up And Establish Cir.;Wash Down Wit Out Rotation Due to 6/100 Build&Turn through a Softer Formation-7655 T 8127 Low DLS area-Establish Rotation And Worked Pipe With 120rpm to Get Cleaned Up.;Cont RIH T 8695-Took Weight-Kelly Up-Wash&Ream Down From 8695 To 9168-Did Get Hung Up At 8789 With a 500psi Pack Off-Had To Work Pipe Hard to Establish Movement And Cir.;Had Lost Communications With Geopilot after Working To Reestablish Pipe Movement-Cir and Attempt To Get Geo Pilot Working With Downlinks And Pump Cycles-No Joy.;Circulate&condition mud,weight up system U 9.2 PPG.;POOH f/9137'U 7151',up wt 235k,dn wt 205k, did get detained @ 8221',worked free, washed&reamed area clean,did see 10-20k drag as tools came into window.;Break circulation,pump dry job.;Cont.POOH UBHA @ 748'.;Distance to plan 35.3 27.8'High 21.75'Left;M-32RD2 wellhead pressures-9-5/8=35psi,9-518X13-3/8=170psi,13-3/8X16=210psi,16X26=60psi,26X31=120psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:0, total-703#. i i 7/30/2017 Work BHA,stand back HWDP&flex collars,unload source&download MWD tools,Ud BHA.;Make Up Sperry RSS BHA#6-Up Load tools,Shallow Test MWD -Load Source.;TIH t/6899',up wt 215k,dn wt 205k.;Warm up mud,circ 478 gpm,2100 psi.;TIH f/6899',t/9263' on elevators,through window w/no issues.;Took Weight-Kelly Up-Wash&Ream Down From 9263'-9453're-wiping hole as needed to clean up.;TIH f/9453 U9832'up wt 265k,dn wt 210k.;Took weight, washed&reamed f/9832't/10112'circ.10 BPM,2100 psi, rot 130 rpm,tq 9-10k,rot wt 235k,up wt 265k,dn wt 215k.;Dir Dril With RS-f/10112',t/10302(190, 63'hr PIG)PU 265 SO 215 R 235, 525gpm 2775psi,150rpm 11k tor 15k WOB.;Distance to plan 35.3 27.8'High 21.75'Left;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=170psi,13-3/8X16=210psi,16X26=60psi,26X31=120psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:12, total-715#. 7/31/2017 Dir Drill With RS-f/10302 U10491'(189,63'hr PIG)PU 304 SO 222 R 250, 455gpm 2300psi,150rpm 12k tor 15-25k WOB.;Dir Drill With RS-f/10491' U10653'(162,54'hr PIG)PU 302 SO 225 R 252, 530gpm 2840psi,150rpm 12k tor 15-25k WOB.;Dir Drill With RS-f/10653'U10776'(162,54'hr PIG)PU 302 SO 225 R 252, 530gpm 2840psi,150rpm 12k tor 15-25k WOB.;Not getting build rate,confer w/town Engineers,decision made to Pull assembly&p/u mud motor assy.CBU clean,530GPM,2850psi,rot,150rpm,;POOH f/10776'U 10116',back reaming @420gpm,2100 psi,150 rpm,tq 9-11 k.;POOH f/10116'U 7088',with no issues.;Pump dry job,cont.POOH U748'.;Work BHA,stand back HWDP&flex collars,unload source&download MWD tools,Ud Geo-pilot BHA.;Clean&clear floor,prep BHA.;P/U BHA#7, -w/8 1/2"Kymera HP524 bit,6 3/4"Sperry Drill lobe 6/7-6stg mud motor w/1.83 deg bend,Down load MWD tools,shallow test mtr good,cont.p/u BHA.;Distance to plan 29.83' 1 29.25'Low 5.87'Left;M-32RD2 wellhead pressures-9-518=35psi,9-5/8X13-3/8=17opsi,13-3/8X16=21 Opsi,16X26=60psi,26X31=120psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:10, total-725#. 8/1/2017 Finish Making Up Mud Motor BHA#7-RIH To 4100 Fill Pipe-Cont RIH to 7,980 Fill Pipe Did Not Have Any Trouble At Window(7209-7226)-Cont RIH To 9,240 where it Took Wt(Coal).;Kelly Up At 9237-Fill Pipe&Establish Cir above Tight Spot-Wash Down 9,237 To 9,3310 with 20 rpm Rotary(Mtr In Hole) 466gpm(11 bbl/min 2600psi-Very Little Diff PSI When We Worked Past 9,240.;Cont RIH Clean To 10,184.;Kelly Up And Fill Pipe-Cir One Open Hole Vol (135bbl)466gpm(11 bbl/min).;Cont RIH to 10,660 Kelly Up Establish Cir Wit Slow Rotary-Wash Down With Slow Rotary to 10,776-Looked Like 6'Of FilI.;Slide Drill 10776 t 10860(74'37'/hr PIG)PU 315 SO 240 R 270 490gpm 3000psi 25 to 40k wob.;Rotary Drill f/10860 U10905',(45'PIG)up wt 315k,dn wt 240k,rot 50 rpm,rot wt 270k,tq 10-12 490gpm,2900psi.;Slide Drill f/10905',U10955'(50',33'/hr PIG)PU 315 SO 240 R 270 490gpm 3000psi 25 to 40k wob.;Rotary Drill f/10955',U11000'(45'PIG)up wt 320k,dn wt 235k,rot 50 rpm,rot wt 275k,tq 10-12k, 480gpm,3000psi.;Slide Drill f/11000',U11055(58',38'/hr PIG)PU 315 SO 240 R 270 490gpm 3000psi 25 to 40k wob.;Rotary Drill f/11058',11100(45'PIG)up wt 320k,dn wt 235k,rot 50 rpm,rot wt 275k,tq 10-12k, 480gpm, 3000psi.;Slide Drill f/11100',U11167'(67',33'/hr PIG)PU 315 SO 240 R 270 490gpm 3000psi 25 to 40k wob.;Rotary Drill f/11167',11185(45'PIG)up wt 320k, dn wt 235k,rot 50 rpm,rot wt 275k,tq 10-12k, 480gpm,3000psi.;Slide Drill f/11185',U11200'(15'PIG)PU 315 SO 240 R 270 490gpm 3000psi 25 to 40k wob.;Rotary Drill f/11200',U11222'(22'PIG)up wt 320k,dn wt 235k,rot 50 rpm,rot wt 275k,tq 10-12k, 480gpm,3000psi.;Shoot Survey,shows 11.5 DL,trough area while circulating clean for trip,488gpm,2750psi.;Distance to plan 38.08' 37.30'Low 7.69'Right;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=180psi,13-3/8X16=215psi,16X26=80psi,26X31=130psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:15, total-740#. 8/2/2017 Cir Well Clean For Trip-Working To Smooth Out 11 deg Dogleg Area.;POH F/11222 U 7378 Just Below Shoe-Had One Spot At 9550(Coal That Overpulled 50K-Broke Back Down And Had 10K Overpull The Second Time Through.;Flow Check And Dry Pipe Below Window Due To Mud Motor.;Cont Trip Out From 7378-No Trouble At Window.;UD BHA#7,bit grade 1-3-BT-T-E-1-CT-BHA.The bit had 1 broken cutter,2 chipped cutters and 7 worn cutters and was 1/16' under gauge.;Respond To Fire Alarm-All Drilling Personnel Muster And Roll Call,good response.;Cont.Ud BHA&clear floor of tools&subs.;Pull wear bushing, t3J i flush stack,r/u test tools,install test plug w/5"TJ,fill stack&surface w/water,shell test U2500 good.;Test BOPE as per Hilcorp&AOGCC requirements.250 5 low/3500 high,witness waived by AOGCC inspector Jim Regg 8-1-17 @ 9:26 am,Gas alarms tested 8-2-17 good.;Finished testing Wl 5"TJ,preformed a /�` successful accumulator drawdown test,(Did have a flange leak below the double gate on the second test,tq.flange&retest good)changing out test jt U7".;Distance to plan 38.08' 37.30'Low 7.69'Right;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=180psi,13-3/8X16=215psi,16X26=80psi,26X31=130psi. Flnirl Inss 74hrs•0 Tntal•(l Mptal rpnovprpd 74hrc•n total-74r1# 8/3/2017 Cont Pressure Testing BOPE-Pressure Test Blinds&Lower Pipe Rams On 7" -250psi Low-3,500Psi High.;Lay Down Test Joint-Install Wear Bushing- Drain Water Out Of Stack-Blow Down Lines.;Make Up BHA#8-Upload-Surface Test&Load Source.;RIH T/6917,up wt 215k,dn 200k.;Establish Cir-Cir While Slip And Cut Drilling line,circ 280gpm,850psi,cut 144'drill line.;Service TDS,DW,c/o SRL in derrick.;Tlh f/6917',U 10685',up wt 305k,dn wt 235,(did have one set down @ 9280',washed through w/o issue.);Wash down U10776',CBU @ 510 gpm,2880 psi, est.parameters,rot wt 250k,@30 rpm,tq-14,@ 40 rpm tq 14,@50 rpm,tq 14.5.;Mad Pass f/10776'U11222',30-35 RPM,tq 13-14k,run 250-300 fph.;Dir Dril With RS-with reduced parameters until we clear BHA f/f/11222',U11240'(10'hr PIG)up wt,315k,dn wt 230k,rot wt 255k, 540gpm 3000psi,30rpm 14k tor 20k WOB.;Distance to plan 38.08' 37.30'Low 7.69'Right;M-32RD2 wellhead pressures-9-5/8=40psi,9-5/8X13-318=170psi,13-3/8X16=210psi,16X26=75psi,26X31=130psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:5, total-745#. 8/4/2017 Dir Dril With RS-with reduced parameters f/11240'U11247(17'PIG)up wt,300k,dn wt 235k,rot wt 260k, 534gpm 2900psi,6orpm 1l k tor 30k WOB.;Dir Dril With RS-with reduced parameters f/11247'U11282',(35'PIG),up wt 300k,dn wt 235k,rw 260k,534gpm,2900psi,60rpm ilk tor 30k WOB.;Dir Dril With RS- f/11282',U 11312',(30'PIG)up wt 300k,dn wt 235k,rw 260k,515gpm,2750psi,12Orpm,tq 13-14k,22-35k WOB.;Dir Dril With RS-f/11312',U11339'(27'PIG) up wt 300k,dn wt 235k,FV/260k,515gpm,2750psi,120rpm,tq 13-14k,22-35k WOB.;Dir Dril With RS-f/11339'U11344'(5'PIG)up wt 300k,dn wt 235k,rw 260k,515gpm,2750psi,120rpm,tq 13-14k,22-35k WOB.;Wipe hole,back ream f/11344',U10970'and back down, rot wt 275k,tq 10-12k, up wt 320 k,dn wt 240k,445 gpm,2100psi.;Dir Dril With RS-f/11344'U11365(21'PIG)up wt 325k,dn wt 240k,rw 280k,515gpm,2750psi,120rpm,tq 13-14k,22-35k WOB.;POOH(due to lack of rop for BHA change)f/11365'U7056'( depths of interest:we wiped back through 9280'&,unable to clean wiping through 7716',we washed&reamed stand f/7813'U7709'.;Monitor hole,Break circ.pump dry job,cont.POOH T/2221'.;Distance to plan 29.02' 27.29'Low 9.89'Right;M-32RD2 wellhead pressures-9-5/8=40psi,9-5/8X13-3/8=170psi,13-3/8X16=210psi,16X26=75psi,26X31=130psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:17, total-762#. 8/5/2017 Cont POH 2221 T 748 Cal Fill 117 Act Fill 123.;Work BHA-Stand Back HWDP&Change Out Jars-Pull Sorce-Down Load Logs-Found Near Bit Stb Bent- Also Looked Like Some Abnormal Wear On Upper Part Of Bit Gage By Up Cutters.;Lay Down Geo-Pilot-Clear&Clean Rig Floor.;Pick Up Motor-Dress Same To 1.5 Deg Bend With Slick Motor Housing-Make Up Bit.;Up Load Sperry&Load Source,cont.P/u BHA.;Rlh p/u agitator 1713'above bit,4 stands HWDP 2668'above bit,cont.RIH U 6919'up wt 215k,dn wt 185k.;Rebuild standpipe valve&test U 3500 psi good.;cont U7494',fill pipe,test tools, good.;Cont.TIH U9060',unable to pass,wash&ream f/9006'U 9097'to clean up,240 GPM,1030 psi,rot 30 rpm,tq 9-10k.;Cont.tih U 11144',up wt 320k,dn wt 235k, unable to pass.;Wash&ream f/11123'U 11186',rot 35 rpm,rot wt 260k,tq 15-17k, 295 gpm,1500 psi.;Tlh V 11280,wash down Ubtm© 11365'.;Rotary drill f/11365' U11370'rot 60 rpm,tg14k,rot wt 260k, 375 GPM,2160 psi.;Slide Drill f/11370'V11415'(45'30/hr PIG)PU 315 SO 240 R 260 450gpm 3100psi 20-25k wob.;Distance to plan 29.02' 27.29'Low 9.89'Right;M-32RD2 wellhead pressures-9-5/8=4opsi,9-5/8X13-3/8=170psi,13-3/8X16=210psi,16X26=75psi,26X31=130psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:0, total-762#. • s 8/6/2017 Directional Drilling With Mud Motor 11,415 T 11,469(54'18'/hr PIG)PU 310 SO 225 R 255 3,175psi 472gpm Slide 15 to 20k WOB.;Dir Drl W/MM 11,469 11,559(90'30'/hr PIG 51'S 39'R)PU 310 SO 225 R 255 3300psi 500gpm 60rpm 12k tor.;Dir DrI W/MM f/11,559 t/11630'(71'23'/hr PIG)PU 315 SO 225 R 265 3300psi 500gpm 12k tq,80 RPM,Mad Passing slides before connections.;Dir DrI W/MM f/11630't/11746'(116'38'/hr PIG)PU 330 SO 230 R 265 3500psi 505gpm 80rpm 12k tq,;Dir Drl W/MM f/11746't/11798'(52',34'/hr PIG)PU 325 SO 225 3500psi 505gpm 12k tq.;Dir Drl W/MM f/11798't/11845' (47',31'/hr PIG)PU 330 SO 230 R 263 3450psi 490gpm 80rpm 12k tq,Mad Passing slides before connections.;Dir DrI W/MM f/11845't/11890'(45',45'/hr PIG)PU 330 SO 230 3450psi 490gpm 12k tq,;Dir DrI W/MM f/11890't/11940(50',/hr PIG)PU 330 SO 230 R 263 3450psi 490gpm 80rpm 12k tq,Mad Passing slides before connections.;Dir DrI W/MM f/11940't/11983'(43'/hr PIG)PU 330 SO 230 3450psi 490gpm 12k tq.;Dir DrI W/MM f/11983' t/12033(50',/hr PIG)PU 330 SO 230 R 263 3400psi 490gpm 80rpm 12k tq,Mad Passing slides before connections.;Dir DrI W/MM f/12033't/12083'(50'PIG) PU 330 SO 230 3450psi 485gpm 12k tq.;Dir Drl W/MM f/12083't/12127'(44'PIG)PU 330 SO 230 R 263 3400psi 490gpm 80rpm 12k tq,Mad Passing slides before connections.;Dir Di W/MM f/12127't/12194'(67'PIG)PU 330 SO 230 3450psi 485gpm 12k tq.;Distance to plan 9.44' 6.12'Low 7.18'Right;M-32RD2 wellhead pressures-9-5/8=40psi,9-5/8X13-3/8=180psi,13-318X16=210psi,16X26=80psi,26X31=130psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:11, total-772#. 8/7/2017 Dir DrI W/MM f/12194't/12200'(6'PIG)PU 330 SO 230 3450psi 485gpm.;Dir Drl W/MM f/12200',U12222'(22'PIG)PU 330 SO 230 R 263 3400psi 490gpm 80rpm 12k tq,Mad Passing slides before connections.;Dir Drl W/MM f/12222'U12267'(45'PIG)PU 325 SO 225 3360psi 485gpm.;Dir Drl W/MM f/12267' V12316(49'PIG)PU 330 SO 228 R 263 3250psi 490gpm 8orpm 12k tq,Mad Passing slides before connections.;Service rig,top drive, SPR.;Rotate& reciprocate while conferring with town on geology/directional plan,rot 40 rpm,12-13 tq,472 gpm,3100 psi.;Dir Drl W/MM f/12316'U 12395'(79'PIG)PU 325 SO 225 3460psi 485gpm.;Dir Drl W/MM f/12395'U12411'(16'PIG)PU 330 SO 228 R 263 3500psi 502gpm 80rpm 12k tq,Mad Passing slides before connections.;Dir Drl W/MM f/12411 U12419'(8'PIG)PU 325 SO 225 3460psi 485gpm.;Had failure on Kelly hose,(contacted proper Agencies through Hilcorp HSE Office for OBM release)Stood back stand,r/u PIS&CMT line circulate&reciprocate up wt 330k,dn wt 230k,;while cleanup start&change out Kelly hose, test same U 4000PSI Good.;R/D PIS,&cmt line,Cont.rotate& reciprocate up wt 330k,dn wt 230k„rack back another stand,cont wk pipe f/12322'U12227'while clean platform/rig.;Distance to plan 9.44' 6.12'Low 7.18'Right;M-32RD2 wellhead pressures-9-5/8=40psi,9-5/8X13-3/8=180psi,13-3/8X16=210psi,16X26=80psi,26X31=130psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:9', total-782#. 8/8/2017 Cont Clean Up Operations From Kelly Hose Failure.;Dir Drilling With Mud Motor 12419 T 12469(50'50'/hr PIG)PU 330 SO 235 3420psi 492gpm Slide Drilling (152 Motor RPM)25 to 30K WOB.;Dir Drilling With MM 12469 T 12475(6'121hr PIG)PU 330 So 235 R 265 3390psi 490gpm 80 Surface RPM(232 total RPM).;Dir DrI W/MM 12475 T 12506(31'20'/hr PIG)PU 335 SO 223 R 258 3,360 492gpm 80rpm 14k Tor 20K WOB.;Dir Drl W/MM 12506 T 12540(34'22'/hr PIG)PU 335 SO 223 3230psi 475gpm Slide(147 M rpm)10 to 15k WOB.;Dir Drl W/MM 12540 T 12579(39'19.5'/hr PIG)PU 330 SO 220 3450psi 490gpm Slide(152 M rpm)20 to 30k WOB.;Dir DrI W/MM 12579 T 12795(216'54'/hr PIG)PU 330 SO 220 ROT 260 3500psi 486gpm 80rpm Tq 16-18k(230 M rpm)25 to 30k WOB.;Dir Drl W/MM 12795 T 12885(90'45'/hr PIG)PU 340 SO 220 ROT 260 3450psi 472gpm 100rpm Tq 16-18k(246 M rpm)25k WOB.;Dir Drl W/MM 12885 T 12940(55/hr PIG)PU 350 SO 220 3450psi 472gpm Slide(146 M rpm)25k WOB.;Dir DrI W/MM 12940 T 13075(135'45'/hr PIG)PU 340 SO 220 ROT 260 3450psi 472gpm 80rpm Tq 16-18k(226 M rpm)25k WOB Mad Pass previous slide Pump HiVis Wtd 40 bbls sweep w/100%increase.;Dir Drl W/MM 13075 T 13130(55'36'/hr PIG)PU 355 SO 215 3310psi 485gpm Slide(150 M rpm)20-30k WOB.;Dir Drl W/MM 13130 T 13325(195'65'/hr PIG)PU 355 SO 215 ROT 262 3320psi 462gpm 80rpm Tq 17-18k(223 M rpm)20k WOB Mad Pass previous slide Pump HiVis Wtd 30 bbls sweep w/100% increase.;Distance to plan 27.38' 16.52'High 21.83'Left;M-32RD2 wellhead pressures-9-5/8=40psi,9-5/8X13-3/8=18opsi,13-3/8X16=220psi,16X26=60psi,26X31=125psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:14, total-796#. 8/9/2017 Directional Drilling With Mud Motor 13,325 to 13,502(177'59'/HR pig)pu 355 SO 210 R 260 3450psi 486gpm 80rpm 15k tor 18 to 25 WOB;Dir DrI W mm 13,502 T 13549(47'47'/hr PIG)PU 355 SO 210 R 260 3,450psi 486gpm 80 rpm 15k tor 18 to 25 WOB;Dir DrI W MM 13549 T 13610(61'61'/hr PIG) PU 355 SO 210 R 260 3,420psi 486gpm Slide 20 t 30 WOB;Dir Drl W MM 13610 T 13643(33'33'/hr PIG) PU 355 SO 210 R 260 3,450psi 486gpm 80rpm 16k tor 20 t 30 WOB;Dir Drl W MM 13643 T 13743(100'33'/hr PIG) PU 355 SO 210 R 260 3,450psi 467gpm 80rpm 16k tor 18-23 WOB;Dir DrI W MM 13743 T 13838 (95'32'/hr PIG) PU 355 SO 210 R 260 3,050psi 440gpm 80rpm 16-17k tor 25 WOB;Dir Drl W MM 13838 T 13980(142'47'/hr PIG) PU 355 SO 210 R 260 3,340psi 440gpm 100rpm 15-16k tor 18-23 WOB;Dir DrI W MM 13980 T 14023(43'29'/hr PIG) PU 345 SO 210 R 260 3,025psi 440gpm 100rpm 15-16k for 25-30 WOB-TD at 14023'MD,9957'TVD.;Circulate&condition at 450 gpm 2900 psi 80 rpm Tq 15-17K pumped 1 bottoms up.;Circulate&condition at 450 _ /<e9 gpm 2900 psi 100 rpm Tq 15K pumped 3 bottoms up.Pump 2,30 bbls HiVis sweeps with 20%&10%increase.Both sweeps came back 60 bbls late.Obtain SCR's&flow check.;SCR©14,023'MD,9957'TVD,MW 9.5 ppg #2 @ 30=480;@ 40=620;TOH f/14023'-12508'MD,PU 325K,few 30-50K over pulls,hole fill for 15 stands calculated 12.3,actual 15.6 bbls.;Distance to plan �/P 7.72 ` �{,� 3.23'High 7.01'Right;M-32R02 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=180psi,13-3/8X16=210psi,16X26=60psi,26X31=120psi. Fluid loss 24hrs:0 Total:0 Metal recovered 24hrs:26, total-822#. 8/10/2017 Cont TOH 12508 T 9124 Pulled Ok Through This Section With a Few Spots Taking 20 to 25K Over Travel Weight;Had To Kelly Up At 9,124-Work Out Of Hole From 9100 Trouble With High Torque&Packing Off-Freed Up At 9,100 Bit Depth;POH With Out Reaming 9100 To 8680 Travel Weight 240 to 260;Had To Kelly Up At 8,680 And Back Ream Out To 8660 Had A Good Deal Of Trouble With High Torque&Packing Off;Trip Out Of Hole With Out Backreaming To 8,400;Had To Kelly Up At 8400 Back Ream T 8343 Had A Good Deal Of Trouble With High Torque&Packing Off;Cont POH F 8343 Up Into Window At 7226- Cont POI-Ito 7115;Work On Mud Pump Throttle&Dry Pipe;TOH f/7115'-1735'MD,PU 112K,SO 112K.;TOH f/1735'-387'MD;TOH laying down BHA 9 racking back HWDP,jars,&NMFC.Remove source&download MWD.;Begin picking up BHA 10 clean out assembly.;M-32RD2 wellhead pressures-9-518=40psi,9- 5/8X13-3/8=170psi,13-3/8X16=220psi,16X26=65psi,26X31=120psi. Fluid loss 24hrs:56.9 Total:56.9 Metal recovered 24hrs:0, total-822# 8/11/2017 Continue picking up BHA 10 clean out assembly to 286'MD.;TIH f/286-7082'MD,PU 205K,SO 205K.;Cut&slip 112'of drill line.Circulate at 4 bpm,230 psi.;TIH f/7082'-8567'MD,PU 225K,SO 200K.;Work through tight spots w/varying parameters f/8567'-9641'MD,PU 230K,SO 215K,ROT 213K,590 gpm, 2100 psi,FO 70%,100 rpm,Tq 6K.;TIH f/9641'-10588'MD,PU 265K,SO 215K.;CBU 10494'-10588'MD,PU 265K,SO 215K,ROT 235K,585 gpm,2300 psi, FO 70%.;TIH V 10588'-12356'MD,PU 297K,SO 234K,fill pipe at 11346'MD.;Work through tight spots w/varying parameters f/12356-12450'MD,PU 300K, SO 200K,ROT 250K,585 gpm,2460 psi,FO 68%,120 rpm,Tq 14K.;Work through tight spots w/varying parameters f/12450'-13682'MD,PU 325K,SO 222K, ROT 265K,590 gpm,2650 psi,FO 70%,120 rpm,Tq 15K.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=175psi,13-3/8X16=210psi, 16X26=70psi,26X31=130psi. Fluid loss 24hrs.0 Total.56 9 Metal recovered 24hrs 15 total-837# • • 8/12/2017 Wash&ream f!13682'-14023'MD,572 gpm,2540 psi,120 rpm,Tq 13.5K,PU 350K,SO 225K,ROT 250K.;C&C mud system,pump 20 bbls low vis sweep followed by 40 bbls high vis sweep at 590 gpm,2680 psi,150 rpm,Tq 14K.Observe 100%increase in cuttings,with sweeps returning 80 bbls late.;Continue circulating to condition mud for a total of 5 bottoms up.PU 350K,SO 225K,ROT 250K.;Monitor well,attempt to TOH on elevators pulling up to 50K over.Pump 10 bpm,1500 psi,PU 350K.Pumps off SO 225K,attempt to pull working up to 50K over with no movement.;Good travel w/pumps on PU 350K.TOH 14018- 13836 MD. SCR's @ 14018'MD,9956 TVD,MW 9.4+ppg. #1 @ 30=270;@ 40=380 #2 @ 30=280;@ 40=370;Backream from 13836-12796'MD,PU 350K,SO 225K,ROT 298K,10 bpm,1550 psi,30 rpm,Tq 15K.Still unable to pull without pumps.;Wash f!12796-14023'MD,PU 350K,SO 225K,380 gpm,1550 psi,FO 52%,unable to TIN wlout pumps.;Weight up mud system from 9.5 to 9.8 ppg, PU 350K,SO 225K,390-300 gpm,1410-830 psi,FO 60% SCR's @ 14023'MD,9957'TVD,MW 9.8 ppg #1 @ 30=340;@ 40=410 #2 @ 30=320;@ 40=430;Attempt to pull on elevators,w/up to 75K over.Pump out of hole f/14023'-12419'MD,PU 300K,SO 245K,115 gpm,215 psi.;Pump 30 bbls HiVis Lube sweep surface to surface,PU 300K,SO 235K,ROT 250K,450 gpm,1750 psi,observed 100%increase in cuttings.;Pump out of hole f/ 12419'-12118'MD,PU 300K,SO 230K,115 gpm,215 psi.;Able to TON w/out pumps f/12116-10143'MD,PU 275K,SO 236K,ream out tight spots at 11220', 11060',10986,10894',10799'MD,450 gpm,1575 psi,90 rpm,Tq 13K.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=180psi,13-3/8X16=220psi, 16X26=70psi,26X31=130psi. Fluid loss 24hrs:44 Total:96 Metal recovered 24hrs:13, total-853# 8/13/2017 TOH f/10143'-7150'MD,PU 225K,SO 205K,ream out tight spots at 8690',8580'&7697'MD,450 gpm,1250 psi,100 rpm,Tq 7K;Circulate casing clean staging up the pumps to 740 gpm,2650 psi,reciprocating.Monitor well,static.Pump dry job&drop 2.41"drift;TOH f/7150'-286'MD,PU 75K,SO 75K, calculated fill 103.4,actual 108.6 bbls.;Lay down BHA 10,clean out assembly,bit grade 1-2-WT-G-E-I-NO-TD.;Mobilize 7"liner handling equipment,shoe equipment,&centralizers to the rig floor.Rig up handling equipment&function test.Pickup cement head&make up pup joint.;Make up WWT 7"Flex Shoe w/ jtc Ream Guide,XO,float collar,spacer joint,float collar joint,&landing collar joint.Check floats,good.TIH w!7",26#,L-80,DWC/C6 liner f/surface to 1677'Mr1.;PU 90K,SO 90K,70 fpm,torqued to 21 ft/lbs,solid body centralizers installed on each joint.;TIH w/7",26#,L-80,DWC/C liner f!1627'-4257'MD,PU 155K,SO /'",r 145K,70 fpm,torqued to 21K ft/lbs,solid body centralizers installed on each joint to#92.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=180psi,13- 3/8X16=220psi,16X26=70psi,26X31=130psi. Losses 24hrs:12.6 Total:108.6 Metal recovered 24hrs:5, total:858# 8/14/2017 TIH w/7",26#,L-80,DWC/C liner f/4257'-7133'MD,PU 215K,SO 195K,70 fpm,torqued to 21K ft/Ibs.;Make up Baker 7"Uniflex liner hanger assembly per Baker Rep.torqued to 20K&install pall mix;CBU at 7164'MD,PU 215K,SO 195K,6 bpm,ICP 800 psi,FCP 990 psi.Wash down&obtain parameters in casing to 7196'MD,3 bpm=350 psi,4 bpm=550 psi,20&30 rpm=Tq 4.5K.;TIH w/7",26#,L-80,DWC/C liner on 5"DP f/7196-9036'MD,PU 243K,SO 210K,70 fpm,torqued to 21K ftllbs.;Work through tight spot with varyingparameters 9036-9058'MD,PU 243K,SO 210K,ROT 225K 1-4 BPM,300-720 psi,5-25 rpm,Tq 7K.While working spot no torque or psi increase observed while taking wt.;TIH f/9058'-9244',work tight spot at 9244'w/varying parameters PU 243K,SO 210K, ROT 225K 1-4 bpm,300-720 psi,5-25 rpm,Tq 7K.While working spot no trq or psi increase observed while taking wt.;Confer w/town&decide to TOH.TOH f/ 9244'-7164',PU 225K,SO 200K,3 bpm,370 psi,calculated fill 18 bbls,actual 20 bbls.Unable to TOH w/out swab,had to pump out of the hole.;Rig up 7'casing handling equipment&prepare lay down liner hanger.;Lay down 7"liner hanger&1 joint of 7"liner to 7091'MD.;Circulate bottoms up to clean up casing at 7 bpm, 1000 psi,reciprocating the string.;Rig up to pump out each joint of liner due to swabbing.Unable to utilize drive sub&head pin due to height.Rig up drive sub w/ 8'DP pup joint.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=180psi,13-3/8X16=220psi,16X26=70psi,26X31=130psi. Losses 24hrs:19 Total:128 Metal recovered 24hrs:0, total:858#" 8/15/2017 Lay down 7"liner f/7091'-5429',PU 185K,SO 180K,pulling at 10 fpm to prevent swab.;Lay down 7"liner f!5429'-3047',PU 130K,SO 128K,pulling at 45 fpm to prevent swab.;Lay down 7"liner ft 3047'-616',PU 76K,SO 76K,pulling at 45 fpm to prevent swab.;Lay down 7"liner f/616-143',to the shoe track,pulling at 45 fpm to prevent swab.;PJSM,use pneumatic reciprocating saw to cut Bakerlok joints of the shoe track,to lay down.The WWT Flex Shoe was broken off below the upper coupler of the tool,leaving 8.74'of junk in the hole.;Rig down casing handling equipment&lay down same.Clear&clean rig floor.;Remove wear bushing, flush the stack,&drain.Rig up to test BOPE w/5"&7"joints.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=180psi,13-3/8X16=220psi, 16X26=70psi,26X31=130psi. Losses 24hrs:6 Total:134 Metal recovered 24hrs:5, total:863# 8/16/2017 Rig up test equipment,blow down all lines,make up test joint&install test plug.Fill stack&flood all lines with water.;Attempt to shell test 250/3500 psi,observe leak at flange between annular&double gate.Torque bolts up&retest good.;Test BOPE to 250/3500 psi,5 min each,charted,test witness waived by AOGCC Rep Jim Regg.Test annular,upper 5"solid body rams&lower 5"X7"VBR's w/5"TJ.Test lower 5"X7"VBR's w/ TJ.;Test choke manifold vavles 1-14, (Loi 7'k, adjustable hydraulic&manual choke valves,HCR&manual choke valves,HCR,manual,Demco& kill line valves,upper&lower IBOP valves,dart valve,& FOSV.;Accumulator system test:Initial system pressure 3000 psi,after closure 1400 psi,200 psi attained in 35 sec,full psi attained in 176 sec.8 bottles avg �t 2425 psi.SIMOPS inspect crown,derrick,&TD;Test gas alarms,pit level indicators,&flow indicator.;Rig down test equipment,pull test plug,drain N20,install 15"ID wear bushing,lay down test joints,blow down all lines.;Moblilize BHA 11 to the rig floor.Make up 8.5 tricone bit,bit sub w/ported float,straight blade reamer,3 NMFC,3 HWDP,JARS,&2 HWDP totaling 284.61'MD.;TIH fl 284.61-3692'MD,PU 140K,SO 135K,;Circulate surface to surface at 7-11 bpm,400- 780 psi,FO 52-65%.;TIH f/3692-7083'MD,PU 210K,SO 200K,;Circulate surface to surface at 11 bpm,1300 psi,FO 65%.;Service&inspect top drive& drawworks.Obtain parameter above TOW.;TIH f/7083'-9248'MD,PU 230K,SO 205K,ROT 220K.Clean up tight spot f!8580'-8690'MD,wash through 5-9 bpm,500-1050 psi.;Tag Flex Shoe left in the hole from liner run at 9248'MD w/10K WOB.Mill up Flex Shoe at 8.5 bpm,1100 psi,90 rpm,Tq 6-15K.Clean up& drift through section w/no pumps.;Circulate hole clean 9259'-9354',12 bpm,1800psi,100 rpm,Tq 7K,PU 240K,SO 205K,ROT 220K.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-318=175psi,13-3/8X16=220psi,16X26=70psi,26X31=130psi. Losses 24hrs:0 Total:134 Metal recovered 24hrs:0, total:863# 8/17/2017 Circulate hole clean 9259'-9354',12 bpm,1800psi,100 rpm,Tq 7K,PU 240K,SO 205K,ROT 220K.;TIH f/9354'-13806'MD,PU 330K,SO 230K,work thru tight spots at 11060',11170',12390',washing w!5 bpm,585 psi.;Wash f/1806-14027'MD,5 bpm,730 psi,tag bottom at 14027'MD.:Circulate hole clean at 450-515 gpm,2100-2350 psi,100 rpm,Tq 14K,PU 340K,SO 230K,ROT 252K,pumped total of 3 bottoms up.Obtain SCR's&monitor well,static.;SCR's @ 14023'MD, 9957'ND,MW 9.9 ppg #1 @ 30=310;@ 40=430 #2 @ 30=320;@ 40=440;TOH f/14023'-11062'MD,PU 340K,SO 230K.;Ream out tight spot w/40K over at 11062'MD,300 gpm,1150 psi,90 rpm,Tq 10K, PU 325K,SO 250K,ROT 260K,work thru 2X&drift clean.;TOH f/11062'-9575'MD,PU 255K,SO 213K.;Circulate hole clean pumping 3 BU at 600 gpm,2270 psi,120 rpm,Tq 8K,PU255K,SO 213K,ROT 225K.;TOH f/9575'-9225'PU 250,SO 213K.;Ream out tight spot w/45K over at 9225'MD,300 gpm,730 psi,100 rpm,Tq 6K,PU 250K,SO 213K,ROT 218K.;TOH f/9226-7115'PU 205,SO 198K.Pull thru window good.;Circulate casing clean at 600 gpm,1900 psi,40 rpm, Tq 4K,PU 205K,SO 198K,ROT 200K.;Cut&slip 94'of drill Iine.;Service TD,drawworks,crown sheaves,adjust brake bands,re-calibrate block height,&hang light in the derrick.;TIH f!7115-9690'MD,PU 260K,SO 220K.Clean up tight spot at 9636'&9690'w/350 gpm,990 psi,90 rpm,Tq 7-8K.;M-32RD2 wellhead pressures-9-518=35psi,9-5!8X13-318=165psi,13-3/8X16=210psi,16X26=75psi,26X31=130psi. Losses 24hrs:10 Total:144 Metal recovered 24hrs:12, total:875# • 8/18/2017 TIH f/9690'-13832'MD,PU 330K,SO 230K,work thru tight spot 9800'-9842',360 gpm,1050 psi,95 rpm,Tq 1 OK.;Wash&ream down f/13832'-14023'MD,4- 9.5 bpm,640-1450 psi,120 rpm,Tq 14K,PU 330K,SO 230K,ROT 260K.;Circulate hole clean at 365 gpm,1350 psi,120 rpm,Tq 13K,PU 365K,SO 230K, 260K.Pump 20 bbl nut plug-lube-HiVis sweep&observe 250%increase in cuttings.;Circulate hole clean at 550-630 gpm,2680-3210 psi,120 rpm,Tq 13K. Pump 20 bbl nutplug-lube-HiVis sweep&observe 125%increase in cuttings.Obtain SCR's.Spot 198 bbls lube bead pill in the annulus;leaving 23 bbls in the pipe.Monitor well,slight drop. SCR's at 14023'MD,9957'TVD,MW 9.85 ppg #1 @ 30=350;@ 40=460 #2 @ 30=340;@ 40=450;TOH f/14023'-10966',PU 300K,SO 230K.Work thru tight spot at 11090',working varying parameters.;CBU at 500 gpm,1893 psi, 120 rpm,Tq 11K,PU 300K,SO 230K,ROT 242K.;TOH f/10966'-10577',PU 300K,SO 230K.Work thru tight spots at 10959',10821',10617'working varying parameters.;Backream f/10577'-9636'MD,at 500 gpm,1750 psi,120 rpm,Tq 8-9K.;Circulate hole clean at 550 gpm,2050 psi,120 rpm,Tq 8K.Pump 25 bbls nutplug-weighted-HiVis sweep,20%increase in cuttings.Spot 106 bbls lube bead pill in the annulus.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13- 3/8=160psi,13-3/8X16=210psi,16X26=80psi,26X31=130psi. I nccpc 9dhrc•1 Tnfal•1.11A Mata'rarnvarad 94hrc•19 total.RR7# 8/19/2017 Continue to spot 106 bbls lube bead pill in the annulus at 355 gpm,975 psi,80 rpm,Tq 6K.;TOH f/9636'-7177'inside TOW,PU 206K,SO 198K.;CBU at 524 gpm,1500 psi,125 rpm,Tq 5K,PU 206K,SO 198K,ROT 204K.Monitor well,static.Pump dry job&obtain SCR's.Drop 2.437" drift.;SCR's at 7177'MD,MW 9.85 ppg #1 @ 30=160;@ 40=180 #2 @ 30=160;@ 40=180;TOH w/clean out assembly f/7177-286'MD,PU 75K,SO 75K,calculated fil 90.3,actual 94.3 bbls.;Lay down BHA 11,3 HWDP, JARS,2 HWDP,3 NMFC,straight blade reamer,bit sub w/ported float,&8.5 tricone bit.Bit graded 2-2-WT-A-E-1-WT-TD.Reamer guaged 1/16-1/8 under.;Rig up to run liner.Mobilize handling equipment to floor&rig up.Make up DP pup to cement head.Make up FOSV to drive sub.;Make up reamer shoe jt,spacer jt, float collar jt,pup jt,&landing collar joint.Check floats,good.TIH w/7",26#,L-80,DWC/C liner f/surface to 2622'MD,PU 120K,SO 114K,50 fph.;Break circulation to warm up mud,staging up rate 125-210 gpm,320-500 psi.;TIH w/7",26#,L-80,DWC/C liner f/2622'-5200'MD,PU 180K,SO 175K,50 fpm, torqued to 20K ft/lbs,fill every 10 joints.Solid body centralizers install on each joint to#93.;M-32RD2 wellhead pressures-9-5/8=35psi,9-5/8X13-3/8=170psi, 13-3/8X16=210psi,16X26=75psi,26X31=130psi. I occas 94hrc•fl Tnfal•145 Mptal rornvorarl 92hrc•(1 Ental•RR7# 8/20/2017 TIH w/7",26#,L-80,DWC/C liner f/5200'-7031'MD,PU 205K,SO 190K,50 fpm,torqued to 20K ft/lbs,fill every 10 joints.;Circulate&condition mud at the window 550 gpm,1380 psi.Reduce rate w/losses to 218 gpm,990 psi,PU 205K,SO 190K,pump surface to surface.;Make up Baker 7"HRD Uniflex liner hanger per BOT rep.SIMOPS rig down casing handling equipment.;Establish parameters inside casing @ 7069',PU 200K,SO 192K,ROT 195K,15/30/40 rpm, Tq 4.5K,141 gpm,530 psi,FO 21%.;TIH w/7",26#,L-80,DWC/C liner on 5"DP f/7069'-14023'MD,PU 350K,SO 200K,40-50 fpm,fill every 10 stands.PU weight w/2bpm,700 psi.Calculated displacement 106,actual 102 bbls.;Circulate&condition for cement job staging up the pump rate 2.5-5.5 bpm,700-1000 psi,PU 350K,SO 202K.;Space out installing 2-5"DP pups,1-5"DP&Baker cement head.;Circulate&condition for cement job staging up the pump rate 2.5-6 bpm,700-1150 psi,PU 310K,SO 200K.;Rig up cement line to Baker cement head.Space out liner to put shoe on depth at 14018'.;Circulate&condition thru cement line,staging up the pump rate 2.5-4 bpm,700-1450 psi,PU 310K,SO 200K.;Line upon HES cement pump.Pump 10 bbls of H2O at 1.5 bpm,80 psi. Pressure test lines to 490/5000 psi,good.Pump 18 bbls of 12.1 ppg Tuned Spacer III w/the rig pump at 2.5 bpm,1450 psi.;Drop Baker pump down plug.Line up to HES&pump 100 bls of 15.3 ppg class G cement at 3 bpm,1300 psi.;M-32RD2 wellhead pressures-9-5/8=40psi,9-5/8X13-3/8=180psi,13-3/8X16=220psi, 16X26=80psi,26X31=130psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs:0, total:887# 8/21/2017 Continue pumping 15.3 ppq,class G cement with HES puma from 100-165 bbls at 3.5 born.ICP 12.40 psi,FCP 1280 psi.Drop#2 pump down plug.HES pump 20 bbls of H2O at 5 bpm,940 psi.;Line up on rig pump&displace w/9.85ppg OBM at 6.5-5 bpm,ICP 665 psi,FCP 1875 psi.Observe both pump down plugs latch up&1st wiper plug land.Bump plug with 364.7 bbls pumped.;Pressure up to 3000 psi&hold for 5 minutes.CIP 07:46 hrs.;Set 7"Uniflex liner hanger.W/ 3000 psi held,set down to 100K&psi up to 4780 psi w/HES pumping 2.7 bbls to set packer.Hold for 5 min&bleed back 5.2 bbls,checking floats.;PU to 200K to observe free travel,confirming release&exposing dog sub.Rotate 10 rpm,Tq 4K&SO to 155K observe tool shift setting packer.SO to 125K.Liner top set at 6955'MD.;Rig down cement lines from Baker cement head.;Pull up circulating bottoms up above liner top at 440 gpm,900 psi,no mud push or cement back to surface.;Lay down space out-1 joint of 5"DP,2-5"pups&cement head 6984'-6907'MD.;Drop wiper ball&circulate surface to surface reciprocating 6907'- 6813'at 390 gpm,600 psi,FO 61%,PU 190K,SO 185K.Obtain SCR's,monitor well,&pump 25 bbl dry job.;SCR's @ 6813'MD,MW 9.90 ppg #1 @ 30=270;40=280 #2 @ 30=260;40=280;TOH f/6813'to surface laying down Baker running tool.Calculated fill 59,actual 59.2 bbls.Remove 5"pup from Baker cement head.;Run in the hole w/5"HWDP.Lay down 15 joints of 5"HWDP.;Clear&clean rig floor.SIMOPS assist with offload of boat.;Remove wear bushing&install test plug. Drain stack of OBM.;Change out upper solid body 5"rams to 4"solid body rams.;Pick up test tools&rig up to test.Make up 4"test joints.;Test annular,upper 4" solid body rams,4"dart vavle,4"FOSV w/4"joint to 250/3500 psi for 5 min each,charted.;Rig down test equipment,remove test plug&install 15"ID wear ring.;Mobilize BHA 12 to the rig floor.;Pick up BHA 12-6"tricone bit,7"casing scraper,XO,7"brush,&XO.;TIH w/BHA 12 picking up 4"DP at 512'MD,PU 65K,SO 65K.;M-32RD2 wellhead pressures-9-5/8=40psi,9-5/8X13-3/8=170psi,13-318X16=210psi,16X26=70psi,26X31=135psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs:0, total:887# 8/22/2017 Cont.RIH f/512',p/u 4"dp t12200'up wt 85k,dn wt 85k,;Cont.RIH f/2200',p/u 4"dp t13450'up wt 110k,dn wt 110k,;Cont.RIH f/3450',p/u 4"dp t/7009'up wt 152k,dn wt 150k,;P/U 9 5/8 scraper assy.=xo,xo,9 5/8 scraper,xo,2 x 9 5/8"brush;Cont.Tih w/5"dp t/13782',tag cmt stringers,up wwt 280k,dn wt 210k,;Wash&ream cmt stringers U 13891' (deep according to tally)tag landing collar,rot 40 rpm,tq,7k,circ 9 BPM 3150 psi;CBU x2 clean, @ 10 bpm,3400 psi, getting rubber&cmt in returns;Rig up&space out test csg,U2750psi f/30 min good,r/d test eq.(pumped 9.3 bbls,bleed back equal amount)R/d test eq.;Displace well U FIW,Line up&pump 40 BBL spacer f/pit 11,chase with FIW from pit 7,9BPM,3260 psi;M-32RD2 wellhead pressures-9-5/8=Opsi,9- 5/8X13-3/8=170psi,13-3/8X16=210psi,16X26=70psi,26X31=130psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs.0. total.887# 8/23/2017 Cont.Displace well f/OBM U FIW,circ.8.5 bpm,3300 psi,rot 40 rpm,tq 7-8k,rot wt 250k,up wt 275k,dn wt 225;Clean out mud system:clean shakers,TT, shaker pits,rig floor,transfer 150BBLS obm U ISO tanks;Stand back first stand,Pump dry job,POOH clean&I/d 5"dp f/13838',U10063'up wt 280k,dn wt 230;Cont POOH clean&I/d 5"dp;Backload Boat w/ISO tanks,bundles 5"dp;Cont POOH clean&I/d 5"dp;Make skate adjustments;Cont.I/d&clean 5"DP U9527';M-32RD2 wellhead pressures-9-518=0psi,9-5/8X13-318=170psi,13-3/8X16=21 Opsi,16X26=70psi,26X31=130psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs:0, total:887# 8/24/2017 Cont.POOH clean&I/d 5"dp,f/9527'U7318',up wt 165k,dn wt 160k;Tlh w/stand of 5"dp from derrick U13892'up wt 275k,dn wt 255k;R/u lines f/annulus U production header,test lines U1500 psi good;Pump 35 bbl Bara-scrub pill,follow with FIW,shipping returns U TRADING BAY,checking returns till clean,(90 NTU)pump 5 BPM,840 psi pump[total 1750 bbls;Circulate well 6.5 BPM 800psi treating fluid bring system U 6%KCL;POOH f/13892',clean&I/d 62 jts 5"dp, cont POOH standing back 5"dp U9116'at report time;M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=170psi,13-3/8X16=210psi,16X26=70psi, 26X31=130psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs:0, total:887# • 8/25/2017 Cont.POOH f/9116't/7009',standing back 52 stands 5"dp in derrick.;L/D 9 5/8 brush&scraper assy.;Pooh stand back 10 stands 4"dp in derrick up wt 144k,dn wt 144k;Service rig while waiting on crane to free up to load tools t/floor;P/U 9 5/8"packer w/storm valve&m/u,rih t/567'w/packer,Bit @ 6648',up dn wt 151 k;Set packer,test upper annulus t/2000psi good(took.9bbls t/psi up);Back out running tool,POOH stand back 5"dp,I/d running tool,r/u pull wear bushing;N/D BOPE,blow down choke&kill line, disconnect same,clean flow box,bleed down accumulator,removed accumulator lines f/annular,install lift beam assy.to BOPE stack,pull flow nipple,n/d chok;N/D BOPE,stump back on ODS,n/d riser, install 11"wellhead conversion spool,n/u riser,BOPE,tq flange breaks;M-32RD2 wellhead pressures-9-5/8=0psi,9-5/8X13-3/8=170psi,13-318X16=200psi,16X26=100psi,26X31=130psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs:0, total:887# 8/26/2017 Finish Tq.BOPE flange breaks,install flow nipple,accumulator,choke&kill lines,install turnbuckles&center stack,grease choke manifold;Pressure up accumulator,function test BOPE components,Good,r/u t/Shell test wellhead/BOPE breaks against storm packer @ 567',close blinds,test 250 low,3500 high hold&chart 5 min each,good;M/U 4"test jt,install test plug,fill surface eq w/water,&shell test,good;Test BOPE as per Hilcorp&AOGCC requirements, witness waived by AOGCC inspector Jim Regg @14:40 on 08-24-17,test with 4"&5"TJ,250 low,3500 high,test gas detection system.Had 2 fp;one w/4"HT- 38 TIW valve,changed out retested good,one fp on CMV#10,serviced&retested good;Flll standpipe&test Kelly hose,250 low,3500 high 5 min each, good;Rig down test eq.clean&clear floor,housekeeping;M/U running tool install wear bushing,POOH I/d running tool,m/u storm packer running tool,rih t/560', sim-ops:housekeeping&rebuilding discharge valve on M/P#2,;Tested 4"discharge valve,had leak on bonnet,repairing same.;M-32RD2 wellhead pressures-9. 5/8=0psi,9-5/8X13-3/8=170psi,13-3/8X16=200psi,16X26=100psi,26X31=130psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs:0, total:887# 8/27/2017 Finish repair on MP#2 discharge valve&test same t/2500 good;M/u running tool t/[packer @ 567',(23 turns)p/u t/open bypass valve monitor well,static,p/u release packer 3k over p/u weight packer released,let element relax,POOH I/d packer,up/dn wt,151 k,;Cut&slip drill line,cut 95',service rig;POOH f/6037' standing back 4"dp,I/d 7"brush&scraper assy.;R/U Schlumberger e-line;Run e-line logging tools,CBL,VDL,GR,CCL,wP'TuffTRAC",able to run in free V 11950',ran in w/TuffTRAC U tag @ 13900',Log up,est.TOC @ 9540';M-32RD2 wellhead pressures-9-5/8=Opsi,9-518X13-3/8=170psi,13-3/8X16=200psi, 16X26=100psi,26X31=130psi. Losses 24hrs:0 Total:145 Metal recovered 24hrs:0, total:887# 0 • 14 Hilcorp Energy Company Composite Report Well Name: MRF M-32RD2 Field: McArthur River Field County/State: CIO,Alaska (LAT/LONG): :Nation(RKB): API#: Spud Date: Job Name: 1712187C M-32RD2 Completion Contractor AFE#: AFE$ (j 8/27/2017 Finish POOH w/Schlumberger e-line,CBL-VDL-GR-CCL,tools,found est.TOC @ 9540',R/D e-line,change drum for work on M-11,spot unit to center deck,support w/I operations on M-10,R/U TCP running eq.,stage tools&subs t/floor,M/U safety jt.preformed drill w/safety jt. load guns on skate,cont. support w/I on M-10 8/28/2017 P/U 4 5/8"TCP gun assembly- 6 SPF,60 deg Phasing,P/U firing head assy&7"champ packer,up wt 95k,do wt 95k,Cont.rih t/4944',up/dn wt 135k„shut down,t/unload&strap 3 1/2&2 7/8 completion ft boat,Cont.tih t/9372',c/o handling eq t/5",Cont.rih on 5"dp from derrick, t/12120'verify fas fill valve closed &top off dp„Cont.tih t/13838',pick up t/13818',up wt149k,dn wt 202k,R/U e-line,rih w/GR,/CCL,t/correlate,TCP gun assembly-bull plug,gun sub,1930' of 4.65"guns 6 SPF,60 deg Phasing, safety spacer,firing head assembly,2-jts 2 7/8 tubing, Below packer vent,7"champ packer,annular pressure xo,fas fil valve,xo, 12 jts 4"DP,xo, RA sub,xo,117 jts 4"dp,xo RA sub, xo, 105 jts 4"dp = 9374.42' 8/29/2017 Tie In Guns With Pollard E-Line-RA Tag 29'Below Required Depth Of 11,388-Confirmed Depth With Hilcorp G&G Anchorage-Trip Out With Wire,Rig Down Wire Line,Top Drive Up And Space Out For Top Shot At 11,860 btm Shot 13,790-1,539'of Perforations 6shpf 60 deg phase 17.5 Gram-Close Annular Preventer-Pressure Up To 2,000psi to Start 5Min Time Delay Firing Hean-After 2 Min Bleed Ann Pressure To 750psi-Had Indication Of Gun Fire 5min 40 seconds After Pressure Up 09:45 Hrs-Line Up To Cir Down D.P.Taking Returns Through Gas Buster-Fill Pipe&Caught Pressure With 30BL,Cont To Build Pressure To 2,500psi with No Fluid Movement-Talked Over Fwd Plan With Halliburton Gun Rep-Looked Like Vent Sub Did Not Open Or Had Become Plugged-Went Through Process To Open Vent a Total Of 4 More Times With No Success-Prep To Tubing Punch D.P.,Mobe Tools To Platform For Tubing Punch-Service Rig-Rig Up Pollard E-Line-,RIH wit 2.5'of Tubing Punch With 10ea.33 Punch Loaded-Tie In And Space Out For D.P.Punch From 11,734 K c, To 11,732-Pressure Up On D.P.To 500psi-Fired Punch And Lost D.P.Presssure Down To Opsi,Cir one D.P.Vol(156Bb1)-Trip Out With Pollard-Rig Down Wire Line,Top Drive Up-Pull Packer Lose With No Overpull-Moved Up Hole 10'-Cir Btms Up With Gun Gas To Surface With 300Bbl Pumped PQf (450Bbl=Btms Up)-Cont Cir A Total of 550Bbl-Did Not See A Lot Of Oil To Surface-Lost 17Bb1 While Cir Btms Up-Check Static Loss Rate 6.6 BPH,POOH f/13791'U11900',l/d 5"DP,up wt,252k,dn wt 202k,Cont.POOH U 9374',1/d 5"dp,Started to get hydrocarbons back,CBU clean 6.5 bpm, 645psi,max gas 663 units 8/30/2017 Cont Cir Well Clean Of Gas&Oil Cut Fluid-D.P.Punch Holes 7,336-Flow Check With 5Bbl/hr Loss Rate When Static,Cont Laying Down D.P.To Get 7" Champ Packer Above Liner Top at 6,956-Lay Down 4"D.P.To a Bull Plug Depth Of 8,896 7"Packer above Liner Top At 6,888 Punch Holes at 6,850,Cir Btms Up From Punch Holes at 6,850-Did Not Get Much Up This Time with A Max Gas Reading of 190-6Bbl/hr Loss Rate While Cir-Flow Check Well With a 5Bbl/hr Loss Rate When Static,Cont Laying Down 4"D.P.to Perf Assembly,up wt 100k,do wt 100k,Ud fas fil valve,annular pressure xo, 7"champ packer, Below packer vent,2-jts 2 7/8 tubing, firing head assembly,Ud 20 each 4 5/8"TCP guns,(note;When breaking down the assembly the id was full of mud/emulsion the last couple feet of lower jt on 4"dp t/top of below packer vent device&the disk was blown to open vent),Cont.l/d 4 5/8"TCP guns all shots fired,clear floor of gun handling eq. 8/31/2017 Clear Rig Floor Of Tools For Perf Assembly,Pull Wear Bushing-Make Up 2 7/8 Test Joint and Land Test Plug-Drain Stack,Change Upper Rams to 3 1/2- p Had Some Trouble Getting Doors To Close -Tighten Doors,Change Lower Rams To 2 7/8-Tighten Doors,Pressure Test Lower 2 7/8 Rams 250psi Low& C3,500psi High-Presssure Test Annular Preventer to 250psi Low&2,500psi High-Change Test Joint To 3 1/2"-Pressure Test 3 1/2"Rams to 250psi Low& V/v7 3,500psi High-5min Each Test-Lay Down 3 1/2 Test Joint-Pressure Test Floor Valves 250psi Low&3,500psi High,P/U Summit ESP handling tools„P/U& service ESP Tandem motor assembly,P/U handling tools,hung sheaves for flat pack&motor lead„P/u seals,install cap lines,&MLE, service seals,install clamps to same,pick up 400 series pumps 9/1/2017 Finish ESP Pump-Service Seals&Install Discharge Head+1 Jnt 2 7/8 Tubing,Start Picking Up 2 7/8"Tubing-Cannon Clamps Would Not Close Correctly With The Cable We Were Running-Worked With Kenai Eng-Mr.Dan Marlow-Mr.Marlow Mobalized Cannon Clamps From The Grayling Platform-They Did Fit Correctly,RIH With 2-7/8",6.4#, L80,8RD EUE, ESP Completion Installing Cannon Clamps On Each Connection&Check Cable each 1000',ft 171'-4855', SO 105K,Tq to 2000 ft/lbs.Used a total of 150 Cannon clamps.,RIH With 3-1/2",9.3#,L80, IBT,ESP Completion Installing Cannon Clamps On Each Connection on the first 5 joints then every other after,ft 4855-5481',SO 110K, Tq to 2400 f tlbs.,Perform ESP splice to new reel&test.Spliced cables on joint #175-5615'.,RIH With 3-1/2",9.3#,L80, IBT,ESP Completion Installing Cannon Clamps on every other joint,f/5481'-7333',SO 125K,Tq to 2400 ft/lbs. 9/2/2017 Cont RIH With 2 7/8 by 3 1/2 ESP Completion F/7,333 T/10,458(520'/hr),Cont RIH With 2 7/8 By 3 1/2 ESP Completion F/10458 T/11130(336'/hr) -Pick Up X Nipple With 1 Jnt Tubing On Top,Pick Up Tripoint Dual Packer-Splice Pass Through Chem Injection Lines-Install Penatrator for Elect Service-Pick up 1 joint of tubing then Baker SSSV-install vent line&control Iine,Cont RIH With 2 7/8 by 3 1/2 ESP Completion F/11206 T/11611 (405'/hr),Make up hanger l &landing joint.Orient hanger&run control lines thru hanger.Terminate ESP&install penetrater at hanger,test good.,Drain stack&continue to run in the hole ,<,\ picking up landing joints,SO 144K,Change out Weatherford tongs hydraulic hose with leak.,Continue picking up landing joints&land hang at 11696',SO 144K. RILDS.,Rig down ESP line&sheeve.Rig up Pollard wireline.SIMOPS rig up to IA&fill back side along with tubing.,Run in the tubing w/a 1.5"ball& t. rod to 603'.Rig up to pump down tubing.,Fluid pack all lines&pressure up to 3550 psi to set Tripoint Dual Packer. Hold pressure for 15 minutes to energize seals.Bleed off pressure.,Rig up&fluid pack all lines to the IA.Test IA between packer&hanger,pressuring up to 1600,pj,.Hold pressure for 30 minutes, charted.Ending pressure bled off was 1570 psi.,Pollard TOH w/ball&rod.TIH&pull plug.Rig down wireline equipment.,Pull landing joints&lay down same. 9/3/2017 Finish Laying Down Landing Joints-Set Back Pressure Valve,Flush All Circulating Lines&Pumps With Citrix Acid-Followed By a Baraclean Soulution to Prep For Water Based Mud-SIMOPS clear rig floor of all equipment not needed.,Bleed down Koomey&remove all hydraulic lines from BOPE.Remove master bushings,clean out rotary box,pull riser,&remove air boot flange under rotary box.,Remove bolts from DSA between the stack&high pressure risers. Unbolt Kill&Choke lines from the stack.Stump back BOP's on ODS.,Remove DSA&high pressure risers from wellhead.,Nipple up tree on 11"wellhead. Check ESP penetrator,good.Terminate control lines on tree.Test tubing head adapter to 500 psi for 5 minutes&5000 psi for 15 minutes,witnessed by Co Rep.,Nipple up valves&production lines to tree.Rig up&PT tree to 5000 psi for 5 min,witnessed by Co.Rep. Rig down test equipment&clean up well bay.,Move mousehole to rotary table&lay down 4 stands of 5"DP. r i 9/4/2017 Remove equipment not needed for upcoming operations.Clean mud pits&shaker pits. Prep upright tanks to be moved. Lay skate ramp over&prep to move. Change out rubber expansion boots on charge pumps.Slide diverter line in for skiddinq.,Last report for M-32RD2. Hilcorp Alaska, LLC McArthur River Field Steelhead M-32RD2 50-733-20462-02-00 Sperry Drilling Definitive Survey Report , 16 August, 2017 HALLIBUR '' ' 11 1 Sperry Drilling • S Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft I Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA Project McArthur River Field Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Trading Bay Unit M-32RD2 Well Position +N/-S 0.00 usft Northing: 2,499,504.41 usft Latitude: 60°49'54.991 N +E/-W 0.00 usft Easting: 214,171.96 usft Longitude: 151°36'6.806 W Position Uncertainty 0.00 usft Wellhead Elevation: 160.00 usft Water Depth: 187.00 usft Wellbore M-32RD2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) : BGGM2017 6/8/2017 _ 16.05 73.71 55,385 Design ''`- M-32RD2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,200.00 Vertical Section: Depth From(TVD) "4, +N/-S1. +E/-W Direction (usft) (usft) (usft) __: (°) w , z 0.00 0.00 0.00 28.11 Survey Program Date 8/16/2017 ' xi:1 From To t (usft) (usft) Survey(Wellbore) Tool Name ;_ Description Survey Date 25.00 7,200.00 SDI Gyro M-32RD2(M-32 PB1) NSG-CT_D/P Continuous north-seeking gyro in drillpipe 07/22/2017 7,209.00 7,430.46 MWD_Interp Azi+sag(M-32RD2) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 07/25/2017 7,469.56 13,985.37 MWD+SC+sag(M-32RD2) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 07/26/2017 1 r., "'�„ Map -` MapVertical _->Inc ;` Azi TVD TVDSS' , +E/-W MD . Northing Easting DLS Section (usft) (°) (°) (usft) (usft) " :-(usft) (ft) (ft) (°/100') (ft) Survey Tool Name 0.00 0.00 0.00 0.00 -160.00 0.00 0.00 2,499,504.41 214,171.96 0.00 0.00 UNDEFINED 25.00 0.12 132.21 25.00 -135.00 -0.02 0.02 2,499,504.39 214,171.98 0.48 -0.01 NSG-CT_D/P(1) 50.00. 0.24 132.21 50.00 -110.00 -0.07 0.08 2,499,504.33 214,172.04 0.48 -0.03 NSG-CT_D/P(1) 75.00 0.36 132.21 75.00 -85.00 -0.16 0.17 2,499,504.24 214,172.13 0.48 -0.06 NSG-CT_D/P(1) 100.00 0.34 174.99 100.00 -60.00 -0.28 0.24 2,499,504.12 214,172.19 1.02 -0.14 NSG-CT_D/P(1) 125.00 0.34 166.03 125.00 -35.00 -0.43 0.26 2,499,503.97 214,172.21 0.21 -0.26 NSG-CT_D/P(1) 150.00 0.33 165.38 150.00 -10.00 -0.57 0.30 2,499,503.83 214,172.25 0.04 -0.36 NSG-CT_D/P(1) 175.00 0.31 157.40 175.00 15.00 -0.70 0.34 2,499,503.69 214,172.29 0.20 -0.46 NSG-CT_D/P(1) 200.00 0.46 131.84 200.00 40.00 -0.83 0.44 2,499,503.56 214,172.38 0.90 -0.53 NSG-CT_D/P(1) 225.00 0.35 141.37 225.00 65.00 -0.96 0.57 2,499,503.43 214,172.50 0.51 -0.58 NSG-CT_D/P(1) 250.00 0.41 117.15 250.00 90.00 -1.06 0.69 2,499,503.33 214,172.63 0.68 -0.61 NSG-CT_D/P(1) 275.00 0.37 121.89 275.00 115.00 -1.14 0.84 2,499,503.24 214,172.77 0.21 -0.61 NSG-CT_D/P(1) 8/16/2017 4:42:47PM Page 2 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 300.00 0.38 140.89 300.00 140.00 -1.25 0.96 2,499,503.13 214,172.89 0.50 -0.65 NSG-CTD/P(1) 325.00 0.61 149.60 324.99 164.99 -1.43 1.08 2,499,502.95 214,173.01 0.97 -0.75 NSG-CT_D/P(1) 350.00 0.96 153.21 349.99 189.99 -1.73 1.24 2,499,502.64 214,173.16 1.41 -0.94 NSG-CT_D/P(1) 375.00 1.15 161.33 374.99 214.99 -2.16 1.42 2,499,502.22 214,173.33 0.97 -1.23 NSG-CT_D/P(1) 400.00 1.22 162.72 399.98 239.98 -2.65 1.58 2,499,501.72 214,173.47 0.30 -1.59 NSG-CT_D/P(1) 425.00 1.27 165.31 424.98 264.98 -3.17 1.73 2,499,501.19 214,173.61 0.30 -1.98 NSG-CT_D/P(1) 450.00 1.29 167.70 449.97 289.97 -3.71 1.86 2,499,500.65 214,173.73 0.23 -2.40 NSG-CT_D/P(1) 475.00 1.03 157.97 474.96 314.96 -4.20 2.00 2,499,500.16 214,173.86 1.30 -2.76 NSG-CT_D/P(1) 500.00 0.93 161.69 499.96 339.96 -4.60 2.15 2,499,499.76 214,174.00 0.47 -3.04 NSG-CT_D/P(1) 525.00 0.57 161.77 524.96 364.96 -4.91 2.25 2,499,499.44 214,174.09 1.44 -3.27 NSG-CT_D/P(1) 550.00 0.97 141.18 549.96 389.96 -5.19 2.42 2,499,499.16 214,174.26 1.92 -3.44 NSG-CT_D/P(1) 575.00 0.63 144.95 574.95 414.95 -5.47 2.64 2,499,498.87 214,174.46 1.38 -3.58 NSG-CT_D/P(1) 600.00 0.74 158.46 599.95 439.95 -5.73 2.77 2,499,498.61 214,174.59 0.78 -3.75 NSG-CT_D/P(1) 625.00 0.64 160.96 624.95 464.95 -6.01 2.88 2,499,498.32 214,174.69 0.42 -3.95 NSG-CT_D/P(1) 650.00 0.67 154.43 649.95 489.95 -6.28 2.99 2,499,498.06 214,174.79 0.32 -4.13 NSG-CT_D/P(1) 675.00 0.65 168.54 674.95 514.95 -6.55 3.08 2,499,497.78 214,174.88 0.65 -4.33 NSG-CT_D/P(1) 700.00 0.90 156.25 699.95 539.95 -6.87 3.19 2,499,497.46 214,174.98 1.20 -4.56 NSG-CT_D/P(1) 725.00 0.76 162.57 724.94 564.94 -7.21 3.32 2,499,497.12 214,175.10 0.67 -4.79 NSG-CT_D/P(1) 750.00 0.94 158.48 749.94 589.94 -7.55 3.44 2,499,496.77 214,175.21 0.76 -5.04 NSG-CT_D/P(1) 775.00 0.79 155.24 774.94 614.94 -7.90 3.59 2,499,496.42 214,175.35 0.63 -5.28 NSG-CT_D/P(1) 800.00 0.93 155.71 799.93 639.93 -8.24 3.74 2,499,496.07 214,175.50 0.56 -5.51 NSG-CT_D/P(1) 825.00 0.97 149.65 824.93 664.93 -8.61 3.93 2,499,495.70 214,175.68 0.43 -5.74 NSG-CT_D/P(1) 850.00 0.80 154.93 849.93 689.93 -8.95 4.11 2,499,495.36 214,175.85 0.75 -5.96 NSG-CT_D/P(1) 875.00 0.92 162.81 874.92 714.92 -9.30 4.25 2,499,495.00 214,175.98 0.67 -6.20 NSG-CT_D/P(1) 900.00 0.67 163.44 899.92 739.92 -9.63 4.35 2,499,494.67 214,176.07 1.00 -6.45 NSG-CT_D/P(1) 925.00 0.77 140.77 924.92 764.92 -9.90 4.50 2,499,494.40 214,176.21 1.20 -6.62 NSG-CT_D/P(1) 950.00 0.51 146.43 949.92 789.92 -10.13 4.66 2,499,494.17 214,176.38 1.07 -6.73 NSG-CT_D/P(1) 975.00 0.48 164.03 974.92 814.92 -10.32 4.75 2,499,493.97 214,176.46 0.62 -6.86 NSG-CT_D/P(1) 1,000.00 0.70 160.46 999.92 839.92 -10.56 4.83 2,499,493.73 214,176.54 0.89 -7.04 NSG-CT_D/P(1) 1,025.00 0.58 177.39 1,024.92 864.92 -10.83 4.89 2,499,493.46 214,176.59 0.89 -7.25 NSG-CT_D/P(1) 1,050.00 0.74 195.14 1,049.91 889.91 -11.12 4.85 2,499,493.17 214,176.54 1.03 -7.52 NSG-CT_D/P(1) 1,075.00 1.01 201.52 1,074.91 914.91 -11.48 4.73 2,499,492.82 214,176.41 1.15 -7.89 NSG-CT_D/P(1) 1,100.00 1.37 198.20 1,099.91 939.91 -11.97 4.56 2,499,492.33 214,176.22 1.47 -8.41 NSG-CT_D/P(1) 1,125.00 1.65 197.35 1,124.90 964.90 -12.59 4.36 2,499,491.71 214,176.01 1.12 -9.06 NSG-CT_D/P(1) 1,150.00 1.96 192.81 1,149.88 989.88 -13.35 4.15 2,499,490.95 214,175.79 1.36 -9.82 NSG-CT_D/P(1) 1,175.00 2.17 188.14 1,174.87 1,014.87 -14.24 3.99 2,499,490.07 214,175.60 1.08 -10.68 NSG-CT_D/P(1) 1,200.00 2.25 187.02 1,199.85 1,039.85 -15.19 3.87 2,499,489.12 214,175.45 0.36 -11.58 NSG-CT_D/P(1) 1,225.00 2.45 179.02 1,224.83 1,064.83 -16.22 3.82 2,499,488.10 214,175.38 1.53 -12.51 NSG-CT_D/P(1) 1,250.00 2.49 180.69 1,249.80 1,089.80 -17.29 3.82 2,499,487.02 214,175.35 0.33 -13.45 NSG-CT_D/P(1) 1,275.00 2.42 183.69 1,274.78 1,114.78 -18.36 3.78 2,499,485.96 214,175.29 0.59 -14.42 NSG-CT_D/P(1) 8/16/2017 4:42:47PM Page 3 COMPASS 5000.1 Build 810 0 • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA 1 Survey 'L a� � Map Map Vertical . ,; MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name "; 1,300.00 2.32 182.13 1,299.76 1,139.76 -19.40 3.72 2,499,484.93 214,175.21 0.48 -15.35 NSG-CT_D/P(1) 1,325.00 2.47 182.68 1,324.74 1,164.74 -20.44 3.68 2,499,483.88 214,175.14 0.61 -16.29 NSG-CT_D/P(1) 1,350.00 2.42 185.55 1,349.72 1,189.72 -21.50 3.60 2,499,482.82 214,175.04 0.53 -17.27 NSG-CT_D/P(1) 1,375.00 2.36 179.39 1,374.69 1,214.69 -22.54 3.56 2,499,481.78 214,174.97 1.05 -18.21 NSG-CT_D/P(1) 1,400.00 2.53 182.42 1,399.67 1,239.67 -23.61 3.54 2,499,480.72 214,174.92 0.85 -19.16 NSG-CT_D/P(1) 1,425.00 2.31 179.20 1,424.65 1,264.65 -24.66 3.52 2,499,479.66 214,174.88 1.03 -20.09 NSG-CT_D/P(1) 1,450.00 2.38 180.34 1,449.63 1,289.63 -25.69 3.53 2,499,478.64 214,174.86 0.34 -20.99 NSG-CT_D/P(1) 1,475.00 2.31 179.87 1,474.61 1,314.61 -26.71 3.53 2,499,477.62 214,174.83 0.29 -21.90 NSG-CT_D/P(1) 1,500.00 2.14 181.50 1,499.59 1,339.59 -27.68 3.52 2,499,476.65 214,174.80 0.73 -22.76 NSG-CT_D/P(1) 1,525.00 1.83 186.12 1,524.57 1,364.57 -28.54 3.46 2,499,475.79 214,174.72 1.39 -23.55 NSG-CT_D/P(1) 1,550.00 1.63 186.45 1,549.56 1,389.56 -29.29 3.38 2,499,475.04 214,174.62 0.80 -24.25 NSG-CT_D/P(1) 1,575.00 1.53 187.25 1,574.55 1,414.55 -29.98 3.30 2,499,474.36 214,174.52 0.41 -24.89 NSG-CT_D/P(1) 1,600.00 1.19 179.85 1,599.55 1,439.55 -30.57 3.25 2,499,473.77 214,174.47 1.53 -25.43 NSG-CT_D/P(1) 1,625.00 0.90 177.06 1,624.54 1,464.54 -31.02 3.27 2,499,473.31 214,174.47 1.18 -25.83 NSG-CT_D/P(1) 1,650.00 0.49 153.98 1,649.54 1,489.54 -31.32 3.32 2,499,473.02 214,174.52 1.95 -26.06 NSG-CT_D/P(1) 1,675.00 0.36 124.28 1,674.54 1,514.54 -31.46 3.43 2,499,472.87 214,174.63 1.01 -26.13 NSG-CT_D/P(1) 1,700.00 0.20 106.24 1,699.54 1,539.54 -31.51 3.54 2,499,472.82 214,174.73 0.72 -26.13 NSG-CT_D/P(1) 1,725.00 0.16 9.43 1,724.54 1,564.54 -31.49 3.59 2,499,472.84 214,174.78 1.08 -26.09 NSG-CT_D/P(1) 1,750.00 0.27 24.28 1,749.54 1,589.54 -31.40 3.62 2,499,472.92 214,174.81 0.49 -25.99 NSG-CT_D/P(1) 1,775.00 0.25 31.61 1,774.54 1,614.54 -31.30 3.67 2,499,473.02 214,174.87 0.16 -25.88 NSG-CT_D/P(1) 1,800.00 0.09 342.61 1,799.54 1,639.54 -31.24 3.69 2,499,473.09 214,174.89 0.81 -25.81 NSG-CT_D/P(1) 1,825.00 0.19 340.15 1,824.54 1,664.54 -31.18 3.67 2,499,473.15 214,174.87 0.40 -25.77 NSG-CT_D/P(1) 1,850.00 0.23 346.32 1,849.54 1,689.54 -31.09 3.65 2,499,473.23 214,174.85 0.18 -25.71 NSG-CT_D/P(1) 1,875.00 0.23 13.94 1,874.54 1,714.54 -30.99 3.65 2,499,473.33 214,174.85 0.44 -25.62 NSG-CT_D/P(1) 1,900.00 0.20 43.25 1,899.54 1,739.54 -30.91 3.69 2,499,473.41 214,174.89 0.45 -25.53 NSG-CT_D/P(1) 1,925.00 0.08 342.54 1,924.54 1,764.54 -30.87 3.72 2,499,473.46 214,174.92 0.70 -25.47 NSG-CT_D/P(1) 1,950.00 0.17 335.92 1,949.54 1,789.54 -30.82 3.69 2,499,473.51 214,174.90 0.36 -25.44 NSG-CT_D/P(1) 1,975.00 0.21 18.34 1,974.54 1,814.54 -30.74 3.69 2,499,473.59 214,174.90 0.57 -25.37 NSG-CT_D/P(1) 2,000.00 0.33 326.83 1,999.54 1,839.54 -30.63 3.67 2,499,473.69 214,174.88 1.03 -25.29 NSG-CT_D/P(1) 2,025.00 0.18 341.17 2,024.54 1,864.54 -30.54 3.62 2,499,473.79 214,174.83 0.65 -25.23 NSG-CT_D/P(1) 2,050.00 0.17 6.49 2,049.54 1,889.54 -30.46 3.61 2,499,473.86 214,174.82 0.31 -25.17 NSG-CT_D/P(1) 2,075.00 0.25 11.91 2,074.54 1,914.54 -30.37 3.62 2,499,473.95 214,174.84 0.33 -25.08 NSG-CT_D/P(1) 2,100.00 0.14 53.88 2,099.54 1,939.54 -30.30 3.66 2,499,474.02 214,174.88 0.69 -25.00 NSG-CT_D/P(1) 2,125.00 0.18 109.27 2,124.54 1,964.54 -30.30 3.72 2,499,474.03 214,174.94 0.61 -24.97 NSG-CT_D/P(1) 2,150.00 0.15 21.02 2,149.54 1,989.54 -30.28 3.77 2,499,474.04 214,174.99 0.92 -24.93 NSG-CT_D/P(1) 2,175.00 0.14 55.89 2,174.54 2,014.54 -30.23 3.81 2,499,474.09 214,175.03 0.35 -24.87 NSG-CT_D/P(1) 2,200.00 0.29 157.85 2,199.54 2,039.54 -30.27 3.86 2,499,474.05 214,175.08 1.39 -24.88 NSG-CT_D/P(1) 2,225.00 0.25 164.41 2,224.54 2,064.54 -30.38 3.90 2,499,473.94 214,175.11 0.20 -24.96 NSG-CT_D/P(1) 2,250.00 0.19 161.96 2,249.54 2,089.54 -30.48 3.92 2,499,473.84 214,175.14 0.24 -25.03 NSG-CT_D/P(1) 2,275.00 0.15 142.09 2,274.54 2,114.54 -30.54 3.96 2,499,473.78 214,175.17 0.28 -25.07 NSG-CT_D/P(1) 8/16/2017 4:42:47PM Page 4 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 2,300.00 0.09 169.23 2,299.54 2,139.54 -30.59 3.98 2,499,473.73 214,175.19 0.32 -25.10 NSG-CT_D/P(1) 2,325.00 0.15 229.15 2,324.54 2,164.54 -30.63 3.96 2,499,473.69 214,175.17 0.52 -25.15 NSG-CT_D/P(1) 2,350.00 0.35 253.79 2,349.53 2,189.53 -30.67 3.86 2,499,473.65 214,175.07 0.89 -25.23 NSG-CT_D/P(1) 2,375.00 0.33 267.65 2,374.53 2,214.53 -30.69 3.72 2,499,473.63 214,174.92 0.34 -25.32 NSG-CT_D/P(1) 2,400.00 0.29 242.32 2,399.53 2,239.53 -30.73 3.59 2,499,473.60 214,174.80 0.57 -25.41 NSG-CT_D/P(1) 2,425.00 0.29 241.45 2,424.53 2,264.53 -30.79 3.48 2,499,473.54 214,174.68 0.02 -25.52 NSG-CT_D/P(1) 2,450.00 0.48 223.69 2,449.53 2,289.53 -30.89 3.35 2,499,473.44 214,174.55 0.89 -25.67 NSG-CT_D/P(1) 2,475.00 0.14 239.92 2,474.53 2,314.53 -30.98 3.25 2,499,473.35 214,174.45 1.39 -25.80 NSG-CT_D/P(1) 2,500.00 0.20 203.55 2,499.53 2,339.53 -31.04 3.20 2,499,473.30 214,174.41 0.48 -25.87 NSG-CT_D/P(1) 2,525.00 0.10 263.62 2,524.53 2,364.53 -31.08 3.17 2,499,473.26 214,174.37 0.69 -25.92 NSG-CT_D/P(1) 2,550.00 0.15 123.67 2,549.53 2,389.53 -31.10 3.17 2,499,473.24 214,174.37 0.94 -25.94 N5G-CT_D/P(1) 2,575.00 0.14 99.38 2,574.53 2,414.53 -31.12 3.23 2,499,473.21 214,174.43 0.25 -25.93 NSG-CT_D/P(1) 2,600.00 0.19 82.17 2,599.53 2,439.53 -31.12 3.30 2,499,473.21 214,174.50 0.28 -25.90 NSG-CT_D/P(1) 2,625.00 0.15 89.52 2,624.53 2,464.53 -31.12 3.37 2,499,473.22 214,174.57 0.18 -25.86 NSG-CT_D/P(1) 2,650.00 0.09 151.33 2,649.53 2,489.53 -31.13 3.42 2,499,473.20 214,174.61 0.53 -25.85 NSG-CT_D/P(1) 2,675.00 0.24 54.69 2,674.53 2,514.53 -31.12 3.47 2,499,473.21 214,174.67 1.06 -25.82 NSG-CT_D/P(1) 2,700.00 0.07 67.11 2,699.53 2,539.53 -31.09 3.52 2,499,473.24 214,174.72 0.69 -25.76 NSG-CT_D/P(1) 2,725.00 0.28 65.74 2,724.53 2,564.53 -31.05 3.59 2,499,473.27 214,174.80 0.84 -25.70 NSG-CT_D/P(1) 2,750.00 0.11 106.19 2,749.53 2,589.53 -31.04 3.67 2,499,473.29 214,174.87 0.84 -25.64 NSG-CT_D/P(1) 2,775.00 0.23 77.97 2,774.53 2,614.53 -31.03 3.75 2,499,473.29 214,174.95 0.57 -25.61 NSG-CT_D/P(1) 2,800.00 0.42 309.29 2,799.53 2,639.53 -30.96 3.72 2,499,473.36 214,174.93 2.37 -25.56 NSG-CT_D/P(1) 2,825.00 0.18 85.56 2,824.53 2,664.53 -30.90 3.69 2,499,473.42 214,174.90 2.26 -25.52 NSG-CT_D/P(1) 2,850.00 0.11 76.49 2,849.53 2,689.53 -30.89 3.75 2,499,473.43 214,174.96 0.29 -25.48 NSG-CT_D/P(1) 2,875.00 0.25 58.24 2,874.53 2,714.53 -30.86 3.82 2,499,473.46 214,175.03 0.60 -25.42 NSG-CT_D/P(1) 2,900.00 0.20 49.36 2,899.53 2,739.53 -30.80 3.90 2,499,473.52 214,175.11 0.24 -25.33 NSG-CT_D/P(1) 2,925.00 0.23 76.27 2,924.53 2,764.53 -30.76 3.99 2,499,473.56 214,175.19 0.42 -25.26 NSG-CT_D/P(1) 2,950.00 0.12 93.88 2,949.53 2,789.53 -30.75 4.06 2,499,473.56 214,175.27 0.48 -25.21 NSG-CT_D/P(1) 2,975.00 0.16 7.89 2,974.53 2,814.53 -30.72 4.09 2,499,473.60 214,175.30 0.77 -25.17 NSG-CT_D/P(1) 3,000.00 0.16 252.46 2,999.53 2,839.53 -30.69 4.06 2,499,473.62 214,175.27 1.08 -25.16 NSG-CT_D/P(1) 3,025.00 0.03 164.65 3,024.53 2,864.53 -30.71 4.03 2,499,473.61 214,175.24 0.65 -25.19 NSG-CT_D/P(1) 3,050.00 0.14 289.34 3,049.53 2,889.53 -30.71 4.00 2,499,473.61 214,175.21 0.64 -25.20 1450-CT_D/P(1) 3,075.00 0.05 132.52 3,074.53 2,914.53 -30.71 3.98 2,499,473.61 214,175.19 0.75 -25.21 NSG-CT_D/P(1) 3,100.00 0.11 220.79 3,099.53 2,939.53 -30.73 3.98 2,499,473.59 214,175.18 0.48 -25.23 NSG-CT_D/P(1) 3,125.00 0.14 287.67 3,124.53 2,964.53 -30.74 3.93 2,499,473.58 214,175.14 0.56 -25.26 NSG-CT_D/P(1) 3,150.00 0.21 178.08 3,149.53 2,989.53 -30.78 3.90 2,499,473.54 214,175.11 1.16 -25.31 NSG-CT_D/P(1) 3,175.00 0.28 249.51 3,174.53 3,014.53 -30.84 3.85 2,499,473.48 214,175.05 1.17 -25.39 NSG-CT_D/P(1) 3,200.00 0.21 241.14 3,199.53 3,039.53 -30.89 3.75 2,499,473.44 214,174.96 0.31 -25.48 NSG-CT_D/P(1) 3,225.00 0.12 253.03 3,224.53 3,064.53 -30.92 3.69 2,499,473.41 214,174.89 0.38 -25.53 NSG-CT_D/P(1) 3,250.00 0.27 208.85 3,249.53 3,089.53 -30.98 3.63 2,499,473.35 214,174.83 0.81 -25.61 NSG-CT_D/P(1) 3,275.00 0.19 258.34 3,274.53 3,114.53 -31.04 3.56 2,499,473.29 214,174.76 0.82 -25.70 NSG-CT_D/P(1) 8/16/2017 4:42:47PM Page 5 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC ,-:„ Local Co-ordinate Reference: ': Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: ` True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: t- Sperry EDM-NORTH US+CANADA Survey Map Map i _ Vertical I MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,300.00 0.26 217.82 3,299.53 3,139.53 -31.09 3.49 2,499,473.24 214,174.69 0.68 -25.78 NSG-CT_D/P(1) 3,325.00 0.18 249.83 3,324.53 3,164.53 -31.15 3.42 2,499,473.18 214,174.61 0.57 -25.86 NSG-CT_D/P(1) 3,350.00 0.16 194.42 3,349.53 3,189.53 -31.19 3.37 2,499,473.14 214,174.57 0.64 -25.93 NSG-CT_D/P(1) 3,375.00 0.20 297.59 3,374.53 3,214.53 -31.21 3.32 2,499,473.13 214,174.52 1.13 -25.96 NSG-CT_D/P(1) 3,400.00 0.27 225.44 3,399.53 3,239,53 -31.23 3.24 2,499,473.11 214,174.44 1.13 -26.02 NSG-CT_D/P(1) 3,425.00 0.21 193.23 3,424.53 3,264.53 -31.32 3.19 2,499,473.02 214,174.38 0.58 -26.12 NSG-CT_13/P(1) 3,450.00 0.22 251.39 3,449.53 3,289.53 -31.38 3.13 2,499,472.96 214,174.33 0.84 -26.20 NSG-CT_D/P(1) 3,475.00 0.22 204.33 3,474.53 3,314.53 -31.43 3.07 2,499,472.91 214,174.26 0.70 -26.28 NSG-CT_D/P(1) 3,500.00 0.28 249.15 3,499.53 3,339.53 -31.50 2.99 2,499,472.84 214,174.18 0.79 -26.37 NSG-CT_D/P(1) 3,525.00 0.32 216.37 3,524.53 3,364.53 -31.58 2.89 2,499,472.77 214,174.08 0.69 -26.49 NSG-CT_D/P(1) 3,550.00 0.11 207.64 3,549.53 3,389.53 -31.66 2.84 2,499,472.69 214,174.03 0.85 -26.58 NSG-CT_D/P(1) 3,575.00 0.26 236.90 3,574.53 3,414.53 -31.71 2.78 2,499,472.64 214,173.97 0.69 -26.66 NSG-CT_D/P(1) 3,600.00 0.19 221.94 3,599.53 3,439.53 -31.77 2.71 2,499,472.58 214,173.89 0.36 -26.75 NSG-CT_D/P(1) 3,625.00 0.24 270.34 3,624.53 3,464.53 -31.80 2.63 2,499,472.55 214,173.81 0.73 -26.81 NSG-CT_D/P(1) 3,650.00 0.33 222.88 3,649.53 3,489.53 -31.85 2.53 2,499,472.50 214,173.71 0.97 -26.91 NSG-CT_D/P(1) 3,675.00 0.14 159.68 3,674.53 3,514.53 -31.93 2.49 2,499,472.42 214,173.67 1.18 -27.00 NSG-CT_D/P(1) 3,700.00 0.19 85.53 3,699.53 3,539.53 -31.96 2.54 2,499,472.39 214,173.72 0.81 -26.99 NSG-CT_D/P(1) 3,725.00 0.29 51.97 3,724.53 3,564.53 -31.92 2.63 2,499,472.43 214,173.81 0.67 -26.91 NSG-CT_D/P(1) 3,750.00 0.51 52.20 3,749.53 3,589.53 -31.81 2.77 2,499,472.54 214,173.95 0.88 -26.75 NSG-CT_D/P(1) 3,775.00 0.80 27.39 3,774.52 3,614.52 -31.59 2.94 2,499,472.76 214,174.12 1.60 -26.48 NSG-CT_D/P(1) 3,800.00 1.21 27.89 3,799.52 3,639.52 -31.20 3.14 2,499,473.14 214,174.34 1.64 -26.04 NSG-CT_D/P(1) 3,825.00 1.51 28.45 3,824.51 3,664.51 -30.68 3.42 2,499,473.66 214,174.63 1.20 -25.45 NSG-CT_D/P(1) 3,850.00 1.89 22.27 3,849.50 3,689.50 -30.00 3.73 2,499,474.32 214,174.96 1.69 -24.71 NSG-CT_D/P(1) 3,875.00 2.52 31.57 3,874.48 3,714.48 -29.15 4.18 2,499,475.16 214,175.42 2.89 -23.75 NSG-CT_D/P(1) 3,900.00 2.96 19.67 3,899.46 3,739.46 -28.08 4.68 2,499,476.22 214,175.96 2.87 -22.56 NSG-CT_D/P(1) 3,925.00 3.51 21.44 3,924.42 3,764.42 -26.76 5.18 2,499,477.53 214,176.48 2.24 -21.16 NSG-CT_D/P(1) 3,950.00 3.79 21.41 3,949.36 3,789.36 -25.28 5.76 2,499,479.00 214,177.10 1.12 -19.58 NSG-CT_D/P(1) 3,975.00 4.11 22.21 3,974.30 3,814.30 -23.68 6.40 2,499,480.58 214,177.78 1.30 -17.87 NSG-CT_D/P(1) 4,000.00 4.60 21.57 3,999.23 3,839.23 -21.92 7.11 2,499,482.32 214,178.53 1.97 -15.98 NSG-CT_D/P(1) 4,025.00 4.92 23.04 4,024.15 3,864.15 -20.00 7.90 2,499,484.22 214,179.37 1.37 -13.92 NSG-CT_D/P(1) 4,050.00 5.17 24.82 4,049.05 3,889.05 -17.99 8.79 2,499,486.21 214,180.31 1.18 -11.73 NSG-CT_D/P(1) 4,075.00 5.48 22.85 4,073.94 3,913.94 -15.87 9.72 2,499,488.31 214,181.29 1.44 -9.41 NSG-CT_D/P(1) 4,100.00 5.69 24.04 4,098.82 3,938.82 -13.63 10.69 2,499,490.51 214,182.32 0.96 -6.99 NSG-CT_D/P(1) 4,125.00 6.07 23.78 4,123.69 3,963.69 -11.29 11.73 2,499,492.83 214,183.41 1.52 -4.43 NSG-CT_D/P(1) 4,150.00 6.19 25.09 4,148.55 3,988.55 -8.86 12.84 2,499,495.23 214,184.58 0.74 -1.77 NSG-CT_D/P(1) 4,175.00 6.52 27.40 4,173.39 4,013.39 -6.38 14.06 2,499,497.68 214,185.86 1.67 1.00 NSG-CT_D/P(1) 4,200.00 6.74 26.72 4,198.23 4,038.23 -3.81 15.37 2,499,500.22 214,187.24 0.93 3.88 NSG-CT_D/P(1) 4,225.00 6.95 27.60 4,223.05 4,063.05 -1.16 16.73 2,499,502.84 214,188.66 0.94 6.86 NSG-CT_D/P(1) 4,250.00 7.31 27.85 4,247.86 4,087.86 1.59 18.18 2,499,505.55 214,190.17 1.45 9.96 NSG-CT_D/P(1) 4,275.00 7.64 28.04 4,272.64 4,112.64 4.46 19.70 2,499,508.38 214,191.76 1.32 13.22 NSG-CT_D/P(1) 8/16/2017 4 42:47PM Page 6 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.O0usft Well: Trading Bay Unit M-32RD2 North Reference: True I Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA ,w .- . +++.. - - -- 'Ws Survey I Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,300.00 7.97 27.51 4,297.41 4,137.41 7.46 21.28 2,499,511.35 214,193.42 1.35 16.61 NSG-CT_0/P(1) 4,325.00 8.36 26.33 4,322.16 4,162.16 10.63 22.89 2,499,514.47 214,195.10 1.70 20.16 NSG-CT_D/P(1) 4,350.00 8.90 25.55 4,346.88 4,186.88 14.00 24.53 2,499,517.81 214,196.82 2.21 23.91 NSG-CT_D/P(1) 4,375.00 9.38 24.74 4,371.56 4,211.56 17.60 26.22 2,499,521.36 214,198.60 1.99 27.87 NSG-CT_D/P(1) 4,400.00 9.93 23.85 4,396.20 4,236.20 21.42 27.94 2,499,525.14 214,200.42 2.28 32.06 NSG-CT_D/P(1) 4,425.00 10.38 23.41 4,420.81 4,260.81 25.46 29.71 2,499,529.13 214,202.28 1.83 36.45 NSG-CT_D/P(1) 4,450.00 10.96 22.27 4,445.38 4,285.38 29.72 31.50 2,499,533.35 214,204.18 2.47 41.06 NSG-CT_D/P(1) 4,475.00 11.23 22.08 4,469.91 4,309.91 34.18 33.32 2,499,537.76 214,206.10 1.09 45.85 NSG-CT_D/P(1) 4,500.00 11.79 21.21 4,494.41 4,334.41 38.82 35.16 2,499,542.35 214,208.05 2.35 50.80 NSG-CT_D/P(1) 4,525.00 11.99 21.60 4,518.87 4,358.87 43.61 37.04 2,499,547.10 214,210.05 0.86 55.92 NSG-CT_D/P(1) 4,550.00 12.40 20.75 4,543.31 4,383.31 48.54 38.94 2,499,551.98 214,212.08 1.79 61.16 NSG-CT_D/P(1) 4,575.00 12.73 20.76 4,567.71 4,407.71 53.62 40.87 2,499,557.01 214,214.13 1.32 66.55 NSG-CT_D/P(1) 4,600.00 12.98 20.53 4,592.08 4,432.08 58.83 42.83 2,499,562.17 214,216.22 1.02 72.07 NSG-CT_D/P(1) 4,625.00 13.20 20.80 4,616.43 4,456.43 64.12 44.83 2,499,567.42 214,218.34 0.91 77.68 NSG-CT_D/P(1) 4,650.00 13.54 20.97 4,640.76 4,480.76 69.53 46.89 2,499,572.77 214,220.54 1.37 83.42 NSG-CT_D/P(1) 4,675.00 13.71 21.63 4,665.05 4,505.05 75.01 49.03 2,499,578.20 214,222.81 0.92 89.27 NSG-CT_D/P(1) 4,700.00 13.89 21.95 4,689.33 4,529.33 80.55 51.25 2,499,583.68 214,225.16 0.78 95.19 NSG-CT_D/P(1) 4,725.00 14.25 21.67 4,713.58 4,553.58 86.19 53.50 2,499,589.27 214,227.55 1.47 101.23 NSG-CT_D/P(1) 4,750.00 14.25 21.80 4,737.81 4,577.81 91.91 55.78 2,499,594.92 214,229.97 0.13 107.35 NSG-CT_D/P(1) 4,775.00 14.51 21.67 4,762.03 4,602.03 97.68 58.08 2,499,600.63 214,232.41 1.05 113.52 NSG-CT_D/P(1) 4,800.00 14.79 21.83 4,786.22 4,626.22 103.55 60.42 2,499,606.45 214,234.89 1.13 119.80 NSG-CT_D/P(1) 4,825.00 15.07 21.55 4,810.37 4,650.37 109.53 62.80 2,499,612.37 214,237.42 1.16 126.21 NSG-CT_D/P(1) 4,850.00 15.26 21.29 4,834.50 4,674.50 115.62 65.19 2,499,618.40 214,239.96 0.81 132.70 NSG-CT_D/P(1) 4,875.00 15.53 21.74 4,858.60 4,698.60 121.80 67.63 2,499,624.51 214,242.54 1.18 139.29 NSG-CT_D/P(1) 4,900.00 15.85 21.47 4,882.67 4,722.67 128.08 70.12 2,499,630.74 214,245.18 1.31 146.01 NSG-CT_D/P(1) 4,925.00 16.18 21.43 4,906.70 4,746.70 134.50 72.64 2,499,637.09 214,247.86 1.32 152.86 NSG-CT_D/P(1) 4,950.00 16.36 21.60 4,930.70 4,770.70 141.02 75.21 2,499,643.54 214,250.59 0.74 159.82 NSG-CT_D/P(1) 4,975.00 16.61 21.77 4,954.67 4,794.67 147.61 77.83 2,499,650.07 214,253.37 1.02 166.87 NSG-CT_D/P(1) 5,000.00 17.05 21.90 4,978.60 4,818.60 154.33 80.52 2,499,656.72 214,256.22 1.77 174.06 NSG-CT_D/P(1) 5,025.00 17.22 21.73 5,002.49 4,842.49 161.17 83.26 2,499,663.49 214,259.13 0.71 181.38 NSG-CT_D/P(1) 5,050.00 17.38 21.70 5,026.36 4,866.36 168.07 86.01 2,499,670.33 214,262.05 0.64 188.77 NSG-CT_D/P(1) 5,075.00 17.59 21.69 5,050.21 4,890.21 175.05 88.79 2,499,677.24 214,264.99 0.84 196.24 NSG-CT_D/P(1) 5,100.00 18.06 21.59 5,074.01 4,914.01 182.17 91.61 2,499,684.28 214,267.99 1.88 203.84 NSG-CT_D/P(1) 5,125.00 18.15 21.60 5,097.77 4,937.77 189.39 94.47 2,499,691.43 214,271.02 0.36 211.56 NSG-CT_D/P(1) 5,150.00 18.27 21.56 5,121.52 4,961.52 196.65 97.34 2,499,698.62 214,274.07 0.48 219.32 NSG-CT_D/P(1) 5,175.00 18.73 21.74 5,145.22 4,985.22 204.03 100.27 2,499,705.92 214,277.18 1.85 227.20 NSG-CT_D/P(1) 5,200.00 18.93 21.56 5,168.89 5,008.89 211.53 103.24 2,499,713.35 214,280.34 0.83 235.22 NSG-CT_D/P(1) 5,225.00 19.34 21.42 5,192.51 5,032.51 219.15 106.25 2,499,720.90 214,283.52 1.65 243.36 NSG-CT_D/P(1) 5,250.00 19.77 21.38 5,216.06 5,056.06 226.94 109.30 2,499,728.61 214,286.77 1.72 251.67 NSG-CT_D/P(1) 5,275.00 20.06 21.26 5,239.57 5,079.57 234.88 112.40 2,499,736.47 214,290.05 1.17 260.13 NSG-CT_D/P(1) 8/16/2017 4:42:47PM Page 7 COMPASS 5000.1 Build 81D • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: r Well Trading Bay Unit M-32RD2 Project: 'McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: `Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: r `= True j Wellbore: M-32RD2 Survey Calculation Method: '.� Minimum Curvature Design: a M-32RD2 Database: t Sperry EDM-NORTH US+CANADA Survey Map Map Vertical .5 : MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting DLS Section 1411:: (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,300.00 20.46 21.14 5,263.02 5,103.02 242.95 115.53 2,499,744.46 214,293.38 1.61 268.72 NSG-CT_DIP(1) 5,325.00 20.77 20.73 5,286.42 5,126.42 251.17 118.67 2,499,752.60 214,296.73 1.37 277.46 NSG-CT_D/P(1) 5,350.00 21.48 20.86 5,309.74 5,149.74 259.59 121.87 2,499,760.94 214,300.13 2.85 286.39 NSG-CT_D/P(1) 5,375.00 21.71 20.83 5,332.99 5,172.99 268.19 125.14 2,499,769.46 214,303.61 0.92 295.52 NSG-CT_D/P(1) 5,400.00 21.94 20.47 5,356.19 5,196.19 276.89 128.42 2,499,778.07 214,307.10 1.06 304.74 NSG-CT_D/P(1) 5,425.00 22.59 20.22 5,379.33 5,219.33 285.77 131.71 2,499,786.87 214,310.61 2.63 314.12 NSG-CT_D/P(1) 5,450.00 22.99 20.07 5,402.38 5,242.38 294.86 135.05 2,499,795.88 214,314.17 1.62 323.71 NSG-CT_D/P(1) 5,475.00 23.33 20.02 5,425.36 5,265.36 304.10 138.42 2,499,805.03 214,317.76 1.36 333.45 NSG-CT_D/P(1) 5,500.00 23.62 19.92 5,448.29 5,288.29 313.46 141.82 2,499,814.31 214,321.39 1.17 343.30 NSG-CT_D/P(1) 5,525.00 24.10 19.85 5,471.16 5,311.16 322.97 145.26 2,499,823.73 214,325.06 1.92 353.31 NSG-CT_D/P(1) 5,550.00 24.38 19.90 5,493.95 5,333.95 332.62 148.75 2,499,833.29 214,328.78 1.12 363.47 NSG-CT_D/P(1) 5,575.00 24.65 20.07 5,516.70 5,356.70 342.37 152.29 2,499,842.95 214,332.57 1.12 373.74 NSG-CT_D/P(1) 5,600.00 25.03 20.09 5,539.39 5,379.39 352.23 155.90 2,499,852.72 214,336.41 1.52 384.14 NSG-CT_D/P(1) 5,625.00 25.52 20.10 5,561.99 5,401.99 362.26 159.57 2,499,862.66 214,340.32 1.96 394.71 NSG-CT_D/P(1) 5,650.00 26.05 20.12 5,584.50 5,424.50 372.47 163.31 2,499,872.77 214,344.31 2.12 405.48 NSG-CT_D/P(1) 5,675.00 26.72 20.18 5,606.90 5,446.90 382.90 167.13 2,499,883.11 214,348.39 2.68 416.48 NSG-CT_D/P(1) 5,700.00 26.88 20.31 5,629.21 5,469.21 393.47 171.03 2,499,893.58 214,352.55 0.68 427.65 NSG-CT_D/P(1) 5,725.00 27.30 20.24 5,651.47 5,491.47 404.15 174.98 2,499,904.16 214,356.75 1.68 438.93 NSG-CT_D/P(1) 5,750.00 27.54 20.42 5,673.66 5,513.66 414.95 178.98 2,499,914.86 214,361.01 1.02 450.33 NSG-CT_D/P(1) 5,775.00 27.94 20.51 5,695.79 5,535.79 425.85 183.05 2,499,925.66 214,365.35 1.61 461.87 NSG-CT_D/P(1) 5,800.00 28.41 20.69 5,717.83 5,557.83 436.90 187.20 2,499,936.60 214,369.77 1.91 473.57 NSG-CT_D/P(1) 5,825.00 28.64 20.57 5,739.79 5,579.79 448.07 191.41 2,499,947.67 214,374.25 0.95 485.41 NSG-CT_D/P(1) 5,850.00 29.18 20.55 5,761.68 5,601.68 459.39 195.65 2,499,958.88 214,378.77 2.16 497.39 NSG-CT_D/P(1) 5,875.00 29.39 20.67 5,783.48 5,623.48 470.84 199.96 2,499,970.22 214,383.35 0.87 509.51 NSG-CT_D/P(1) 5,900.00 29.61 20.66 5,805.24 5,645.24 482.35 204.30 2,499,981.62 214,387.97 0.88 521.72 NSG-CT_D/P(1) 5,925.00 29.96 20.48 5,826.94 5,666.94 493.98 208.66 2,499,993.14 214,392.62 1.44 534.03 NSG-CT_D/P(1) 5,950.00 30.65 20.43 5,848.52 5,688.52 505.80 213.07 2,500,004.85 214,397.32 2.76 546.53 NSG-CT_D/P(1) 5,975.00 30.89 20.34 5,870.00 5,710.00 517.79 217.53 2,500,016.73 214,402.06 0.98 559.20 NSG-CT_D/P(1) 6,000.00 31.51 20.06 5,891.39 5,731.39 529.94 222.00 2,500,028.77 214,406.83 2.55 572.03 NSG-CT_D/P(1) 6,025.00 31.74 19.86 5,912.67 5,752.67 542.26 226.47 2,500,040.98 214,411.60 1.01 585.01 NSG-CT_D/P(1) 6,050.00 32.10 19.82 5,933.89 5,773.89 554.70 230.96 2,500,053.30 214,416.39 1.44 598.09 NSG-CT_D/P(1) 6,075.00 32.86 19.91 5,954.98 5,794.98 567.32 235.52 2,500,065.81 214,421.26 3.05 611.38 NSG-CT_13/P(1) 6,100.00 33.44 19.86 5,975.91 5,815.91 580.18 240.17 2,500,078.55 214,426.22 2.32 624.91 NSG-CT_D/P(1) 6,125.00 33.57 19.75 5,996.76 5,836.76 593.16 244.85 2,500,091.41 214,431.21 0.57 638.56 NSG-CT_D/P(1) 6,150.00 33.81 19.59 6,017.56 5,857.56 606.22 249.52 2,500,104.35 214,436.20 1.02 652.28 NSG-CT_D/P(1) 6,175.00 34.32 19.47 6,038.27 5,878.27 619.42 254.20 2,500,117.43 214,441.20 2.06 666.13 NSG-CT_D/P(1) 6,200.00 34.69 19.60 6,058.87 5,898.87 632.77 258.93 2,500,130.66 214,446.26 1.51 680.13 NSG-CT_D/P(1) 6,225.00 35.37 19.71 6,079.34 5,919.34 646.28 263.76 2,500,144.05 214,451.42 2.73 694.32 NSG-CT_D/P(1) 6,250.00 36.05 19.94 6,099.64 5,939.64 660.01 268.71 2,500,157.65 214,456.70 2.77 708.76 NSG-CT_D/P(1) 6,275.00 36.31 20.21 6,119.82 5,959.82 673.87 273.77 2,500,171.39 214,462.10 1.22 723.38 NSG-CT_D/P(1) 8/16/2017 4:42:47PM Page 8 COMPASS 5000.1 Build 81D • S Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature I Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (`/100') (ft) Survey Tool Name 6,300.00 36.21 20.37 6,139.98 5,979.98 687.74 278.90 2,500,185.13 214,467.57 0.55 738.02 NSG-CT0/P(1) 6,325.00 36.71 20.33 6,160.09 6,000.09 701.67 284.07 2,500,198.92 214,473.07 2.00 752.74 NSG-CT_D/P(1) 6,350.00 37.66 20.43 6,180.00 6,020.00 715.83 289.33 2,500,212.96 214,478.68 3.81 767.72 NSG-CT_D/P(1) 6,375.00 38.18 20.48 6,199.73 6,039.73 730.23 294.70 2,500,227.21 214,484.40 2.08 782.94 NSG-CT_D/P(1) 6,400.00 38.59 20.51 6,219.32 6,059.32 744.77 300.13 2,500,241.62 214,490.18 1.64 798.33 NSG-CT_D/P(1) 6,425.00 38.60 20.69 6,238.86 6,078.86 759.37 305.62 2,500,256.08 214,496.03 0.45 813.79 NSG-CT_D/P(1) 6,450.00 39.27 20.76 6,258.31 6,098.31 774.06 311.18 2,500,270.63 214,501.94 2.69 829.37 NSG-CT_D/P(1) 6,475.00 38.70 20.81 6,277.74 6,117.74 788.76 316.76 2,500,285.20 214,507.88 2.28 844.97 NSG-CT_D/P(1) 6,500.00 39.28 20.71 6,297.17 6,137.17 803.47 322.34 2,500,299.76 214,513.81 2.33 860.57 NSG-CT_D/P(1) 6,525.00 39.38 20.53 6,316.51 6,156.51 818.30 327.92 2,500,314.45 214,519.75 0.61 876.28 NSG-CT_D/P(1) 6,550.00 39.45 20.43 6,335.82 6,175.82 833.17 333.47 2,500,329.18 214,525.67 0.38 892.01 NSG-CT_D/P(1) 6,575.00 39.56 20.47 6,355.11 6,195.11 848.07 339.03 2,500,343.94 214,531.59 0.45 907.78 NSG-CT_D/P(1) 6,600.00 39.07 20.41 6,374.46 6,214.46 862.92 344.56 2,500,358.65 214,537.48 1.97 923.47 NSG-CT_D/P(1) 6,625.00 38.99 20.41 6,393.88 6,233.88 877.67 350.05 2,500,373.26 214,543.33 0.32 939.08 NSG-CT_D/P(1) 6,650.00 38.82 20.50 6,413.33 6,253.33 892.38 355.54 2,500,387.83 214,549.17 0.72 954.64 NSG-CT_D/P(1) 6,675.00 39.37 20.57 6,432.73 6,272.73 907.14 361.07 2,500,402.46 214,555.06 2.21 970.26 NSG-CT_D/P(1) 6,700.00 39.33 20.68 6,452.07 6,292.07 921.98 366.65 2,500,417.15 214,561.01 0.32 985.98 NSG-CT_13/P(1) 6,725.00 39.56 20.83 6,471.37 6,311.37 936.83 372.28 2,500,431.86 214,567.00 1.00 1,001.73 NSG-CT_D/P(1) 6,750.00 39.48 20.80 6,490.66 6,330.66 951.70 377.93 2,500,446.59 214,573.01 0.33 1,017.51 NSG-CT_D/P(1) 6,775.00 39.30 20.71 6,509.98 6,349.98 966.54 383.55 2,500,461.29 214,578.99 0.76 1,033.25 NSG-CT_D/P(1) 6,800.00 39.80 20.86 6,529.25 6,369.25 981.42 389.20 2,500,476.03 214,585.00 2.04 1,049.04 NSG-CT_D/P(1) 6,825.00 39.85 20.85 6,548.45 6,388.45 996.38 394.90 2,500,490.84 214,591.07 0.20 1,064.92 NSG-CT_D/P(1) 6,850.00 39.59 20.80 6,567.68 6,407.68 1,011.31 400.58 2,500,505.63 214,597.11 1.05 1,080.77 NSG-CT_D/P(1) 6,875.00 39.20 20.82 6,587.00 6,427.00 1,026.15 406.22 2,500,520.32 214,603.11 1.56 1,096.50 NSG-CT_D/P(1) 6,900.00 39.39 20.78 6,606.35 6,446.35 1,040.95 411.84 2,500,534.98 214,609.09 0.77 1,112.21 NSG-CT_D/P(1) 6,925.00 39.42 20.83 6,625.67 6,465.67 1,055.78 417.48 2,500,549.67 214,615.09 0.17 1,127.95 NSG-CT_D/P(1) 6,950.00 39.44 20.78 6,644.98 6,484.98 1,070.63 423.12 2,500,564.38 214,621.09 0.15 1,143.70 NSG-CT_D/P(1) 6,975.00 39.55 20.82 6,664.27 6,504.27 1,085.49 428.77 2,500,579.10 214,627.09 0.45 1,159.47 NSG-CT_D/P(1) 7,000.00 39.61 20.67 6,683.54 6,523.54 1,100.39 434.41 2,500,593.85 214,633.10 0.45 1,175.27 NSG-CT_D/P(1) 7,025.00 39.72 20.34 6,702.78 6,542.78 1,115.33 440.00 2,500,608.66 214,639.05 0.95 1,191.08 NSG-CT_D/P(1) 7,050.00 39.21 19.87 6,722.08 6,562.08 1,130.25 445.46 2,500,623.44 214,644.88 2.36 1,206.82 NSG-CT_D/P(1) 7,075.00 38.95 19.54 6,741.49 6,581.49 1,145.09 450.77 2,500,638.14 214,650.55 1.33 1,222.41 NSG-CT_D/P(1) 7,100.00 38.86 19.29 6,760.94 6,600.94 1,159.90 455.99 2,500,652.82 214,656.13 0.72 1,237.93 NSG-CT_D/P(1) 7,125.00 38.63 18.96 6,780.44 6,620.44 1,174.68 461.12 2,500,667.47 214,661.62 1.24 1,253.39 NSG-CT_D/P(1) 7,150.00 38.38 18.61 6,800.01 6,640.01 1,189.42 466.13 2,500,682.08 214,666.99 1.33 1,268.74 NSG-CT_D/P(1) 7,175.00 37.89 18.57 6,819.67 6,659.67 1,204.05 471.05 2,500,696.59 214,672.26 1.96 1,283.97 NSG-CT_D/P(1) 7,200.00 38.14 18.74 6,839.37 6,679.37 1,218.64 475.98 2,500,711.05 214,677.54 1.08 1,299.16 NSG-CT_D/P(1) 7,209.00 38.15 18.83 6,846.44 6,686.44 1,223.90 477.77 2,500,716.27 214,679.46 0.63 1,304.64 MWD_Interp Azi+sag(2) 7,240.44 39.80 17.87 6,870.89 6,710.89 1,242.67 483.99 2,500,734.88 214,686.14 5.59 1,324.13 MWD_Interp Azi+sag(2) 7,334.80 41.00 15.17 6,942.75 6,782.75 1,301.29 501.36 2,500,793.06 214,704.93 2.25 1,384.02 MWD_Interp Azi+sag(2) 8/16/2017 4:42:47PM Page 9 COMPASS 5000.1 Build 81D 110 • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature > Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA Survey -...,,---y,...-..7--...,-.-:, ..-4,-::,,,:;:,:7.- . _.,. . ,.� . .; s ,•fir "n Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,430.46 43.93 12.70 7,013.31 6,853,31 1,363.97 516.87 2,500,855.34 214,721.97 3.52 1,446.61 MWDInterp Azi+sag(2) 7,469.56 45.24 11.76 7,041.16 6,881.16 1,390.79 522.68 2,500,882.01 214,728.44 3.75 1,473.01 MWD+SC+sag(3) 7,523.24 47.38 10.24 7,078.24 6,918.24 1,428.89 530.08 2,500,919.92 214,736.76 4.48 1,510.10 MWD+SC+sag(3) 7,619.96 53.22 9.28 7,140.00 6,980.00 1,502.20 542.66 2,500,992.90 214,751.13 6.09 1,580.69 MWD+SC+sag(3) 7,719.90 60.24 9.90 7,194.79 7,034.79 1,584.54 556.59 2,501,074.87 214,767.06 7.04 1,659.88 MWD+SC+sag(3) 7,809.35 65.47 8.77 7,235.59 7,075.59 1,663.06 569.48 2,501,153.05 214,781.87 5.95 1,735.21 MWD+SC+sag(3) 7,901.90 70.02 7.33 7,270.63 7,110.63 1,747.84 581.45 2,501,237.52 214,795.91 5.12 1,815.64 MWD+SC+sag(3) 7,998.98 70.19 3.81 7,303.67 7,143.67 1,838.68 590.31 2,501,328.12 214,806.98 3.41 1,899.93 MWD+SC+sag(3) 8,090.81 71.70 3.35 7,333.65 7,173.65 1,925.31 595.73 2,501,414.58 214,814.51 1.71 1,978.90 MWD+SC+sag(3) 8,185.51 70.06 1.63 7,364.67 7,204.67 2,014.69 599.62 2,501,503.85 214,820.58 2.44 2,059.57 MWD+SC+sag(3) 8,280.08 70.32 1.13 7,396.72 7,236.72 2,103.64 601.77 2,501,592.71 214,824.90 0.57 2,139.04 MWD+SC+sag(3) 8,375.06 71.23 1.01 7,426.00 7,268.00 2,193.31 603.44 2,501,682.31 214,828.76 0.97 2,218.91 MWD+SC+sag(3) 8,470.45 71.43 0.68 7,458.53 7,298.53 2,283.67 604.77 2,501,772.61 214,832.30 0.39 2,299.24 MWD+SC+sag(3) 8,566.52 70.58 2.75 7,489.81 7,329.81 2,374.46 607.49 2,501,863.31 214,837.23 2.22 2,380.61 MWD+SC+sag(3) 8,658.89 70.34 2.59 7,520.70 7,360.70 2,461.41 611.54 2,501,950.14 214,843.41 0.31 2,459.21 MWD+SC+sag(3) 8,754.31 70.12 2.53 7,552.98 7,392.98 2,551.12 615.55 2,502,039.72 214,849.60 0.24 2,540.23 MWD+SC+sag(3) 8,808.94 68.54 1.08 7,572.26 7,412.26 2,602.20 617.17 2,502,090.75 214,852.46 3.81 2,586.05 MWD+SC+sag(3) 8,848.07 67.25 358.99 7,586.99 7,426.99 2,638.45 617.19 2,502,126.99 214,853.37 5.95 2,618.03 MWD+SC+sag(3) 8,942.80 67.35 359.16 7,623.54 7,463.54 2,725.84 615.78 2,502,214.38 214,854.10 0.20 2,694.44 MWD+SC+sag(3) 8,998.89 67.21 359.01 7,645.21 7,485.21 2,777.57 614.95 2,502,266.11 214,854.53 0.35 2,739.68 MWD+SC+sag(3) 9,036.41 66.99 359.77 7,659.81 7,499.81 2,812.13 614.59 2,502,300.67 214,855.01 1.96 2,769.99 MWD+SC+sag(3) 9,089.58 64.89 0.68 7,681.48 7,521.48 2,860.67 614.77 2,502,349.20 214,856.38 4.25 2,812.90 MWD+SC+sag(3) 9,132.04 63.65 1.09 7,699.92 7,539.92 2,898.92 615.36 2,502,387.42 214,857.91 3.05 2,846.91 MWD+SC+sag(3) 9,226.75 60.32 1.27 7,744.40 7,584.40 2,982.50 617.08 2,502,470.93 214,861.67 3.52 2,921.45 MWD+SC+sag(3) 9,321.76 57.85 3.22 7,793.21 7,633.21 3,063.94 620.26 2,502,552.27 214,866.83 3.14 2,994.78 MWD+SC+sag(3) 9,417.01 51.29 4.66 7,848.40 7,688.40 3,141.32 625.55 2,502,629.50 214,874.01 7.00 3,065.53 MWD+SC+sag(3) 9,510.94 45.26 7.51 7,910.89 7,750.89 3,211.00 632.89 2,502,698.97 214,883.05 6.81 3,130.44 MWD+SC+sag(3) 9,605.30 40.42 10.86 7,980.07 7,820.07 3,274.31 643.04 2,502,762.02 214,894.74 5.67 3,191.07 MWD+SC+sag(3) 9,703.98 34.11 14.36 8,058.57 7,898.57 3,332.60 655.95 2,502,819.98 214,909.07 6.74 3,248.56 MWD+SC+sag(3) 9,796.52 28.63 16.36 8,137.56 7,977.56 3,379.05 668.64 2,502,866.10 214,922.89 6.03 3,295.51 MWD+SC+sag(3) 9,890.95 22.55 23.14 8,222.70 8,062.70 3,417.45 682.14 2,502,904.16 214,937.32 7.14 3,335.74 MWD+SC+sag(3) 9,986.71 18.35 41.02 8,312.49 8,152.49 3,445.74 699.28 2,502,932.03 214,955.14 7.81 3,368.77 MWD+SC+sag(3) 10,081.87 14.19 61.42 8,403.90 8,243.90 3,462.65 719.37 2,502,948.43 214,975.65 7.37 3,393.15 MWD+SC+sag(3) 10,176.70 10.34 81.52 8,496.59 8,336.59 3,469.47 738.01 2,502,954.80 214,994.45 6.01 3,407.95 MWD+SC+sag(3) 10,270.49 9.90 110.08 8,588.98 8,428.98 3,467.94 753.92 2,502,952.88 215,010.31 5.32 3,414.10 MWD+SC+sag(3) 10,365.11 9.81 129.63 8,682.23 8,522.23 3,460.00 767.77 2,502,944.61 215,023.97 3.52 3,413.63 MWD+SC+sag(3) 10,459.82 11.75 150.47 8,775.30 8,615.30 3,446.46 778.75 2,502,930.80 215,034.60 4.56 3,406.85 MWD+SC+sag(3) 10,554.63 15.18 163.44 8,867.51 8,707.51 3,426.15 787.05 2,502,910.30 215,042.41 4.80 3,392.85 MWD+SC+sag(3) 10,649.44 17.51 168.87 8,958.48 8,798.48 3,400.25 793.34 2,502,884.25 215,048.07 2.94 3,372.97 MWD+SC+sag(3) 10,743.24 20.42 171.02 9,047.18 8,887.18 3,370.24 798.62 2,502,854.12 215,052.61 3.19 3,348.98 MWD+SC+sag(3) 8/16/2017 4:42:47PM Page 10 COMPASS 5000.1 Build 81D i 9 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA max, r,41 _,,,,:,,, Survey k Map Map Vertical ' . MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,803.06 23.01 172.05 9,102.75 8.942.75 3,348.35 801.86 2,502,832.16 215,055.32 4.38 3,331.20 MWD+SC+sag(3) 10,900.68 31.72 172.20 9,189.37 9,029.37 3,303.94 808.00 2,502,787.61 215,060.37 8.92 3,294.92 MWD+SC+sag(3) 10,995.11 38.45 172.65 9,266.59 9,106.59 3,250.17 815.13 2,502,733.68 215,066.19 7.13 3,250.85 MWD+SC+sag(3) 11,090.38 46.07 172.17 9,337.05 9,177.05 3,186.71 823.61 2,502,670.04 215,073.11 8.01 3,198.87 MWD+SC+sag(3) 11,184.09 56.53 172.74 9,395.56 9,235.56 3,114.30 833.17 2,502,597.42 215,080.90 11.17 3,139.52 MWD+SC+sag(3) 11,216.71 57.79 173.22 9,413.25 9,253.25 3,087.10 836.52 2,502,570.15 215,083.59 4.06 3,117.10 MWD+SC+sag(3) 11,310.80 59.74 175.78 9,462.05 9,302.05 3,007.04 844.21 2,502,489.91 215,089.32 3.12 3,050.10 MWD+SC+sag(3) 11,330.35 59.64 177.52 9,471.91 9,311.91 2,990.19 845.20 2,502,473.05 215,089.90 7.70 3,035.71 MWD+SC+sag(3) 11,424.42 65.86 177.80 9,514.96 9,354.96 2,906.67 848.60 2,502,389.47 215,091.26 6.62 2,963.64 MWD+SC+sag(3) 11,519.27 70.89 177.16 9,549.91 9,389.91 2,818.61 852.49 2,502,301.34 215,093.00 5.34 2,887.80 MWD+SC+sag(3) 11,615.36 71.54 177.12 9,580.85 9,420.85 2,727.75 857.03 2,502,210.40 215,095.32 0.68 2,809.80 MWD+SC+sag(3) 11,708.73 71.47 176.32 9,610.47 9,450.47 2,639.35 862.09 2,502,121.90 215,098.22 0.82 2,734.21 MWD+SC+sag(3) 11,748.38 71.77 175.09 9,622.97 9,462.97 2,601.83 864.91 2,502,084.33 215,100.12 3.04 2,702.44 MWD+SC+sag(3) 11,806.43 74.11 175.21 9,640.00 9,480.00 2,546.54 869.60 2,502,028.94 215,103.46 4.04 2,655.88 MWD+SC+sag(3) 11,900.12 77.47 175.63 9,663.00 9,503.00 2,456.01 876.85 2,501,938.27 215,108.50 3.61 2,579.46 MWD+SC+sag(3) 11,992.77 77.65 178.04 . 9,682.96 9,522.96 2,365.69 881.84 2,501,847.84 215,111.29 2.55 2,502.14 MWD+SC+sag(3) 12,087.22 77.79 181.22 9,703.05 9,543.05 2,273.41 882.44 2,501,755.58 215,109.63 . 3.29 2,421.03 MWD+SC+sag(3) 12,182.27 78.64 185.68 9,722.47 9,562.47 2,180.56 876.84 2,501,662.89 215,101.76 4.68 2,336.49 MWD+SC+sag(3) 12,274.76 78.34 189.60 9,740.94 9,580.94 2,090.75 864.79 2,501,573.41 215,087.53 4.17 2,251.60 MWD+SC+sag(3) 12,373.15 83.92 191.76 9,756.10 9,596.10 1,995.27 846.77 2,501,478.40 215,067.18 6.07 2,158.89 MWD+SC+sag(3) 12,467.47 83.49 195.61 9,766.45 9,606.45 1,904.20 824.60 2,501,387.89 215,042.79 4.08 2,068.11 MWD+SC+sag(3) 12,564.67 83.70 200.43 9,777.30 9,617.30 1,812.37 794.72 2,501,296.82 215,010.69 4.93 1,973.04 MWD+SC+sag(3) 12,656.61 83.23 199.98 9,787.76 9,627.76 1,726.65 763.18 2,501,211.90 214,977.05 0.71 1,882.56 MWD+SC+sag(3) 12,753.49 83.17 199.19 9,799.23 9,639.23 1,636.02 730.93 2,501,122.08 214,942.61 0.81 1,787.43 MWD+SC+sag(3) 12,847.69 82.94 197.63 9,810.62 9,650.62 1,547.30 701.40 2,501,034.11 214,910.92 1.66 1,695.26 MWD+SC+sag(3) 12,940.70 82.70 200.31 9,822.25 9,662.25 1,460.04 671.40 2,500,947.61 214,878.80 2.87 1,604.16 MWD+SC+sag(3) 13,038.45 83.68 199.93 9,833.64 9,673.84 1,368.90 638.02 2,500,857.31 214,843.20 1.07 1,508.04 MWD+SC+sag(3) 13,130.59 83.12 203.24 9,844.44 9,684.44 1,283.80 604.35 2,500,773.06 214,807.47 3.62 1,417.12 MWD+SC+sag(3) 13,225.06 82.87 202.90 9,855.96 9,695.96 1,197.54 567.61 2,500,687.72 214,768.63 0.44 1,323.72 MWD+SC+sag(3) 13,320.60 81.68 201.82 9,868.80 9,708.80 1,109.98 531.59 2,500,601.07 214,730.49 1.68 1,229.52 MWD+SC+sag(3) 13,413.90 81.81 200.40 9,882.20 9,722.20 1,023.85 498.34 2,500,515.78 214,695.14 1.51 1,137.88 MWD+SC+sag(3) 13,508.95 80.56 199.44 9,896.76 9,736.76 935.55 466.34 2,500,428.28 214,660.99 1.65 1,044.92 MWD+SC+sag(3) 13,605.68 83.31 203.56 9,910.34 9,750.34 846.47 431.24 2,500,340.09 214,623.73 5.09 949.81 MWD+SC+sag(3) 13,701.06 84.12 204.06 9,920.78 9,760.78 759.73 392.96 2,500,254.31 214,583.35 1.00 855.27 MWD+SC+sag(3) 13,796.33 83.32 204.10 9,931.20 9,771.20 673.28 354.33 2,500,168.83 214,542.61 0.84 760.81 MWD+SC+sag(3) 13,890.95 83.47 203.23 9,942.08 9,782.08 587.19 316.60 2,500,083.69 214,502.80 0.93 667.10 MWD+SC+sag(3) 13,985.37 82.91 202.40 9,953.28 9,793.28 500.77 280.25 2,499,998.18 214,464.34 1.06 573.74 MWD+SC+sag(3) 14,023.00 82.91 202.40 9,957.92 9,797.92 466.25 266.02 2,499,964.02 214,449.28 0.00 536.59 PROJECTED to TD 8/16/2017 4:42:47PM Page 11 COMPASS 5000.1 Build 81D 1 • S Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-32RD2 Project: McArthur River Field TVD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead MD Reference: TBU M-32 revised @ 160.00usft Well: Trading Bay Unit M-32RD2 North Reference: True Wellbore: M-32RD2 Survey Calculation Method: Minimum Curvature Design: M-32RD2 Database: Sperry EDM-NORTH US+CANADA mitchell.laird@halliburton.com Michael Calkins Checked By: 2ov.08.1614:O5:27-08'00' Approved By: Date: 8/16/2017 8/16/2017 4:42:47PM Page 12 COMPASS 5000.1 Build 810 410 • 21 7091 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 RECEIVED Tele: 907 777-8337 Hilenrp Fax: 907 777-8510 E-mail: doudean@hilcorp.com SEP 21 2017 DATE 09/21/2017 AOGCC DATA LOGGED To: Alaska Oil & Gas Conservation Commission 9 11/2011 K BENDER Makana Bender Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-32RD2 E log data 2 8 6 1 0 Prints: DGR EWR-Phase4 CTN ALD TVD ROP DGR EWR-Phase4 CTN ALD MD CD Data: Final Well Data 1 8 6 1 1 _Log Viewers 9/8/2017 12:33 PM File folder CGM 9/8/2017 12:33 PM File folder Definitive Survey 9/8/2017 12:33 PM File folder EMF 9/8/2017 12:34 PM File folder 1. LAS 9/8/2017 12:34 PM File folder PDF 9/8/2017 12:34 PM File folder TIFF 9/8/2017 12:34 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: //ff �QJj Date: Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Hik?nfp Ala k®, Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 9/21/2017 RECEIVED To: Alaska Oil & Gas Conservation Commission SEP 2 2017 Meredith Guhl, Petroleum Geology Assistant ®^^^ 333 W. 7th Ave. Ste#100 GCC Anchorage, AK 99501 DATA TRANSMITTAL M-32RD2 (217-091) Transmitted herewith are cuttings WELL $pX ;.,. 1 ? PTS 4 ,3 M-32RD2 BOX 1 OF 7 7209' - 8580' BOX 2 OF 7 8580' - 10110' BOX 3 OF 7 10110' - 11730' BOX 4 OF 7 11730' — 12465' BOX 5 OF 7 12465' — 13005' BOX 6 OF 7 13005' — 13590' BOX 7 OF 7 13590' — 14023' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Rec-"ved : . 410Date: 12- 2-11 ti OF Ttp (bi) II/7: THE STATE Alaska Oil and Gas F `- 7 Of Conservation Commission is = LAsKA 333 West Seventh Avenue r I. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rR Main: 907.279.1433 ,`,gi Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, West Foreland Oil Pool, TBU M-32RD2 Permit to Drill Number: 217-091 Sundry Number: 317-344 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, jaza Hollis S. French Chair DATED this ZZ day of August, 2017. RBDMS U" ',;'_''? Z 3 2017 • • RECEIVED ,JUL. 2 4 2017 STATE OF ALASKA O �/GC ALASKA OIL AND GAS CONSERVATION COMMISSION d•� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0• Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Completion . Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0' 217-091 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-733-20462-02• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No El/ Trading Bay Unit M-32RD2 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 ' McArthur River Field/West Foreland Oil Pool(Proposed) . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ±13,722(proposed,) ±9,951 (proposed), ±13,600(proposed). ±9,943(proposed), 3,117 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 981' 26" 981' 981' Surface 1,347' 16" 1,347' 1,347' 2,630 psi 1,020 psi Intermediate 3,767' 13-3/8" 3,767' 3,766' 3,090 psi 1,540 psi Production 7,209' 9-5/8" 7,209' 6,841' 7,930 psi 6,620 psi Liner ±6,662(proposed) 7" ±13,722(proposed) ±9,951 (proposed) 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary I Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/15/2017 Commencing Operations: OIL 0• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe©hilcorp.com Contact Phone:5907)283-1329 Authorized Signature: ,„5-kw. 1.0.3Date: U S"� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test tj Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 50Ci p 5 , a 0 r 7--;c RBDMS L" -,,-., c 4 2017 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ii Subsequent Form Required: /0 '-LIQ•7 /f 6,4c't. p w{t: " Xeirt�/�, APPROVED BY D Approved by: COMMISSIONER THE COMMISSION Date: ' 1 ZL ( l uo 17- r 1 l 1- ag,, (o r C eF / / 8"147 • (� I Submit Form and Form 10-4033 R ised 4/2017 QR16NALp1ifor 12 months from the date of approval. Attachments in Duplicate • • • Well Work Prognosis Well: M-32rd2 Date: 07/11/2017 Hileorp Alaska,LLC Well Name: M-32rd2 API Number: 50-733-20462-02 Current Status: Sidetracked Gas Producer Leg: B-1 Estimated Start Date: August 15, 2017 Rig: Steelhead Rig#51 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 217-091 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 4,100 psi @ 9,196'TVD 0.425 lbs/ft(8.16 ppg)based on offset producers Maximum Expected BHP: 4,100 psi @ 9,196'TVD 0.425 lbs/ft(8.16 ppg)based on offset producers Maximum Potential Surface Pressure:3,117 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary M-32rd2 is a West Foreland only producer that will be completed with an ESP. This new well was side tracked from the current M-32rd is a depleted gas producer plugged. This workover will perforate and run the completion string in the new well. J Last Casing Test: Casing and liner tested to 2,500 psi under PTD 217-091 Procedure: 1. ***Take over operations from the Drilling Sidetrack Program*** 2. Test BOP's every 14 days continued from last test date from PTD 217-029.Test to 250psi low/3,500psi high/2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Workover fluids will be 6% KCL. BOP's will be closed as needed to circulate the well. 4��G�l 4. Rig up E-Line and run gamma/ccl/cbl. POOH. C.Gi 6v, 5. PU TCP guns, RIH and perforate per program. 6. After detonation, circulate out any perf gas, confirm well is static, POOH. • PU and run ESP completion w/a high set packer, packer vent valve, and SSSV. 7. Set and test packer to 1500 psig charting for 30 minutes. ✓ 8. Set BPV. NU tree,test same,turn well over to production. 9. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • • . 11 PROPOSED Trading Bay Unit/Steehead Platform Well #: M-32RD2 Hilcorn Alaska.LLC Completed: FUTURE RKB=75.15'Rig Floor to TBG Head CN Size Type Wt Grade Thrd ID Top Btm Hole 26" Conductor Surf 981' Driven 16" Surf Csg 75 K-55 BTC 15.1 Surf 1,347' 22" Eg "�,a., F 13-3/8" Csg 61 K-55 BTC 12.5 Surf 3,767' 17.5" o 9-5/8" Prod Csg 54 L-80 BTC 8.535 Surf 10,588' 12.25" 2 `t E8 $', 41 ~E^ le a 0, ,s°61 1rS 0 0 Al JEWELRY DETAIL 4. NO. Depth (MD) Depth (TVD) ID Item 1 ±7,100' ±6,755' SDD Baker Liner Hanger 2 ±7,300' ±6,912' KOP r! 3 ±7,100'—13,722 9,961' 7" 29# L-80 DWC/C g , 1 14 2 Window @ 7,300' ' 3 kia o s<„,/' 1. CEMENT DETAIL No TOC Depth TOC Depth Volume Item (MD) (ND) t" 4 ±9,000' ±7,765' 160 bbls 15.3 ppg Class G cement w/1/2 bbl ' Fibrous LCM 4, I.. I iso PBTD=13,600'MD/9944'TVD TD=13,722'MD/9661'TVD Updated By MMM 06/13/17 0 • Steelhead Platform II Well: M-32RD2 Proposed PTD:217 091 API: 50-733-20462-02 hump tI:ra.;r.1.1.4 Last Completed: Future RKB to TBG Head-75.15' CASING DETAIL J1 Size Wt Grade Conn ID Top Btm Malail 2 [[ 26" Surf 981' z6 X 3 16" 75 K-55 BTC 15.1 80.1' 1,347' 13-3/8" 61 K-55 BTC 12.5 75.58' 3,767' Eo 9-5/8" 53.5 L-80 BTC 8.535 77.06' 7'209 ey" 16" (TOW) E °m i" 29 L-80 _.. 14,023' TUBING DETAIL 3-1/2" 9.2 L-80 _ IBT Surf ±7,050' 133/8" 2-7/8" 6.4 L-80 8rd ±7,050' ±11,562' . 'TOC @ 3,758' JEWELRY DETAIL No Depth Depth ID OD Item MD TVD Tubing Hanger 1 ±450 ±45, 5.380" SSS\, -Baker TE-5 2 ±480' ±480' ESP Dual Packer D&L Oil Tools w/WFT vent valve 3 ±510' ±510' X-nipple 1 ±7,050' ±6,716' X-Over(3-1/2 x 2-7/8) 4.000" Discharge,Bolt-On N/A 4.000" Pump N/A 4.000" Intake ', t + 4 N/A 4.000" Seals 4.560" Motors Hanger±7 ,.,Z Y, . ±11,685' ±9,602' 4.560" Gauge(Zenith)/Centralizer/Anode ' 'A 1'' TOW 7,209' 9-5/8" PERFORATION DATA p Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Feet SPF Date Status WF-1 ±11, ±; ±9,653 Future Proposed WF-1 ±1' ±1 ±9,665 ±1s_ Future Proposed WF-1 ±1. +9,714 ±256 Future pose 5 WF-2 ±12,462 ±12,55. 765 ±9,776 ±96 Future d WF-2 ±12,580 ±12,6'" '3 ±9,786 ±70 Future ed WF-2 ±12,705 319 ±215 Ft tposed WF-2 ±12,974 ±13,145 ±9,826 ±9,846 ±172 Futur, Proposed WF-2 ±13,230 ±13,264 ±9,856 ±9,861 ±34 FuturE Proposed 297 ±13,790 ±9,865 ±9,930 ±493 Proposed TD: 14,023'(MD)/ 9,957'(ND) Updated By:1 LL 08/11/17 • H . • Steelhead Platform Well: M-32RD2 Proposed PTD: 217-091 API: 50-733-20462-02 Ll:ilcurp Alaska,LL( Last Completed: Future RKB to TBG Head-75.15' CASING DETAIL C', 1 Size Wt Grade Conn ID Top Btm 2 26" Surf 981' 26x 3 13 163/"8" 75 K-55 BTC 15.1 80.1' 1,347 61 K-55 BTC 12.5 75.58' 3,767' ', 9-5/8" 53.5 L-80 BTC 8.535 77.06' 7,209' �a 16„ (TOW) o� 7" 29 L-80 DWC/C ±7,100' ±13,722' ha` TUBING DETAIL hal!31/2" 9.2 L-80 IBT 2.998 Surf ±7,050' 13-3/8" jz ll. " 2-7/8" 6.4 L-80 8rd 2.441 ±7,050' ±11,285' ` 'tTOC @ 3,758' -' JEWELRY DETAIL • No Depth Depth ID OD Item MD ND Tubing Hanger ' 1 ±450' ±450' SSSV-Haliburton TSB24 TRSV NE ' 2 ±480' ±480' ESP Dual Packer D&L Oil Tools w/WFT t- R.e vent valve .' " " 3 ±510' ±510' X-nipple "` `i•' 4 ±7,050' ±6,716' X-Over(3-1/2 x 2-7/8) .� 4F/ N/A 4.000" Discharge,Bolt-On N/A 4.000" Pump 5 N/A 4.000" Intake N/A 4.000" Seals C." Ta N/A 4.560" Motors Hanger+7,100'cf. 14* tel' ; ±11,485' ±9,570' N/A 4.560" Gauge(Zenith)/Centralizer/Anode '',A1 TOW 7,209' 9-5/8" PERFORATION DATA IP Zone Top Btm Top Btm Feet SPF Date Status (MD) (MD) (TVD) (TVD) WF-1 ±11,787' ±9,658' li WF-2 ±12,405' ±9,782' .„ 4 t. 1 7',*atilt J.:,1► PBTD: ±13,600'(MD) ±9,944'(TVD) TD: ±13,722(MD) ±9,661'(ND) Updated By:JLL 07/24/17 • • . ii Steelhead Platform M-32RD2 Current 07/21/2017 Ili[carp?113t6ka,Ii.( Steelhead Platform Tbg hanger,FMC-TC-1A-EN- M-32RD2 EC-CCL,11 SM%3%TC-2 lift 26X16 X 133/8X 95/8 X and susp,w/3'Type H BPV 3 1/2 profile,4-1/4 continuous control line ports BHTA,Bowen, 3 1/8 5M FE X 21/2 Bowen top • WAP iE ''' • Valve,Swab,WKM-M, ilt ' 31/85M FE,HWO,DD pp��!¢ Valve,wing,SSV, ',.1 J.,._ 3 1/8 5M FE,w/15"Safeco operator,EE i/ 1104. 'awl I O =II r Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DO - Adapter,FMC A-3-EC, 11 5M X 3 1/8 5M,prepped for BIW electro sub,4-34 npt X4 corgi _ continuous control line exits di i I � t,_a:. Attachment spool,FMC-TC, 11 11 5M FE btm 0 11 5M FE top,12"in length,10.00" min bore � r I OSA 16%5M x115 • Tubing head,FMC-TC-60,spec for n IIi I„IE z unihead,16%SM FE top X16%5M lip stdd bottom,w/2-21/16 5M SSimi I. O '— H. = • Valve,FMC-120, 21/165M FE,HWO,AA Unihead,FMC Type 2,16%5M II -- ID FEFE top X 21%2M FMC speedlock _ bottom,w/4-21/165M SSO ii,' 111-Awe' I � . 401.11 I li��,i� ��.;.,,, i ic4 Adapter spool,FMC-A-5-S 30”MSS ~ it 5 1 1'I stdd bottom X21%2M FMC 1 i, `ti speedlock top,w/2-2"LPO f Starting head,FMC,30"MSS I O - .rC FE X 26"butt weld .. J rpi 26" 16" 13 3/8' 9 5/8" 3 1/2 • • Steelhead Platform 16'/4 SM BOP (Oil Leg) M-32 Frikorp Ala'ka,r.u: 06/09/2017 r410., Betteme11111. 11 3 9.43 m rVmoxk 1hIll!,II 5.10' Hy lril II II 111,1 5.46' ..n.,a m.mm%1e s.ss 1st Irl I(IIt1111 KiII Side w 31/85M .7 r Irl lel 111 s cl Choke side Manual and HCR ,• ii .i ,U 3,pp 31/85M ! • -Iti lal 1 1l el 111 1.1k Manual and HCR Irl Irl ail Ifl 111 - - v 3.58' Ii1111 II111I IV OSA 16%10M X16%5M .66' Uco.w.l. wsyw.c.,r1,e vn 111 III lit ay 111 1'��n6.bonaiml V.�I _ sl,mno.n.s Riser,16 3/45M API hub X 16 3/4 10M FE 22. Riser,16 DIM FE X16%5M API hub Wellhead@ 8.15' V 0 • (H;!sfl SYD U U 7, C �7:LICI:i WUY2 aoI''� U U UV CC CC WQ a a _ 0 �/ 1./11 0 o —J O LL U Z#>INVI dIH1 M _ U U I� _1 LLJ Ln ,• #NNHl dlHl Q = U N 2 CC Cli in 0 \�Q`��' a = LL F" co F- QF��vNE a_ Q Oa O = (D m rill ii — Alit Q it �' ISI I+Iy w w - ® .—� I f--h CI 3 2 a _ LL1of J `� �� W Y Hi �� rl m��' 3 �' W v Z N W 0 W CO F- U S CO U l^ o W J m n_ Is U) w CXR 0 U O U aw n O 41 p4 ' • • Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Steelhead Rig # 51 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Production Vessel that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static Monitoring for any pressure Build Up Or if Well Is Still On A Strong Vacuum ( I do not think that We Often Shoot Fluid Levels) Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV, ND Tree 2) Clean/Inspect/And Confirm By Screwing Into Lift Threads (Counting Turns) Remove Sub—Check all Lock Down Pins to Ensure they Will Back Out Far Enough To Clear Hanger—Plug Penetrations Through Hanger—Put a Sealing Cap On Penetrator—Leave BPV Installed & If Needed Install Adaptor to Test Joint, Might Be Using a Left Hand Blank Ported Sub or a Combo Tool Of Various Types NU BOP. 3) MU landing joint With On/Off Tool Adaptor. 4) Set slips, mark same. Test per standard Steelhead Rig#51 Test Procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) MU Left Hand Blanking Plug d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC-guy.schwartz@alaska.gov) and Mr. • • Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Jim Regg (AOGCC-jim.regg@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Pull Wear Bushing, Make up Test Plug and Test Joint—Land Same Measuring in the hole getting a Good Mark when Landed . a) Use inverted test plug to pull wear busing. MU to 1 jt.of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after Isolation Plug is Set) 1) Make up Test Joint as per diagram. Insure all connections above test plug are torque. 2) Pull Wear Bushing and install Test Plug 3) Make up Side-Entry Sub, (2)TIW valves and IBOP to top of Test Jt. 4) Make up Test Hose#1 to Side-Entry Sub and Test Hose#2 to Top Drive Test Sub. 5) Verify Annulus valve is open and monitored. 6) Fill BOP and Choke Manifold with water. Purge air from system through Choke manifold top valve and IBOP. • 11 Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 7) Close Annular and set closing pressure to 800 psi. (pressure can be increased as necessary to seal element) Perform full body BOP test to check integrity of system. Note: When testing, pressure up with pump to desired pressure, close MP1 and/or MP2 to trap pressure and read same with chart recorder. 8) Referencing the attached schematics test BOP as per Permit and Regulations as follows. a) Close W1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Open W1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high, for 5 minutes each,as follows: (Valve numbers are in reference to Flow Diagram) d) Test#1-Annular, IBOP, Upper TD Valve, Kill Line Demco, Cl, C2, C3,C12, C13,C14. e) Test#2—Test VBRs,Top TIW, Lower TD valve, HCR2, C4, C5, C6. f) Test#3—Test VBRs, W2, C7, C8, C9 g) Test#4.—Test Lower Pipe Rams, Bottom TIW. h) STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (I.E. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. j) Back out Test joint and pull to rig floor. Connect test hose to C13. Pressure up on Manual and Hydraulic Chokes to 1,000 psi. Function Chokes to bleed pressure and verify operation. k) Test#5. —Test Blinds and C10, C11. I) Make up 2nd Test Joint if running two string sizes m) RIH with 2nd Test Joint and test plug. Make up Side-Entry Sub, (1)TIW valve and IBOP to Test Joint. Connect#1 Test Hose to Side-Entry Sub and#2 Test Hose to suspended TIW w/test sub. • 11 Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Purge air from system. (always verify lengths needed when compared to RKB and add pups if necessary) n) Test#6-Test Annular, IBOP, suspended TIW and HCR1. o) Test#7-Test VBRs, Upper TIW and Manual Choke. p) Rig down test equipment. Blow down lines. Close Annulus valve. Pull test plug. Install Wear Bushing. Rig down,or stand back Test Stand. q) Back out test joint& pull, close blinds,dose valves C7, C8, C9, open HCR1, and W1 r) Open all rams and annular and close HCR2 to place BOPE back into operating position for well work. s) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. ` 0 • � R / � � 2 2 Q _ e 6 > 8 \ E 022 U k ° § ) < a 2 E E c St 2 E [ 1 0 m.E f ? \ / $ 2 \ >. > = faok \.§ Q_ / / % / ® � ..... a o e et 6. 2 as e CI CI % c 2 �Z C0 zI ¢ _c c r. Ua L. � ± -0 I- \ > @ 0. = m U \ k o p> m LL. fY 2 § NI E & E \ 2 cO q \ C) k0 k sy 2 E G ° G 2 0 2 -0 a. L. / / C) P / § .� a 2 / 2 a) Cl) G0 . co w k2 ct k47. co co c0 CZt Q. Q / § 0. § 0 x E 0 _ 2 » e ® Ct % & 9 � .� C ® 0 2 q § = as ° ci S x / u . . m C / / / / •_ Jo c �O u CL 2 2 Cl) \ 9cu ¢ / 1,of rit, 0,1\� 1�j,-c* THE STATE Alaska Oil and Gas ti ALASKA Conservation Commission _, C ft ., 333 West Seventh Avenue +S ,,r,_,_ .„z GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w�,.� + OA,.;+•,_ P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, West Foreland Oil Pool, TBU M-32RD2 Hilcorp Alaska, LLC Permit to Drill Number: 217-091 Surface Location: 969' FNL, 527' FWL, Sec. 33, T9N, R13W, SM, AK Bottomhole Location: 418' FNL, 848' FWL, Sec. 33, T9N, R13W, SM, AK Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, i' -f,/ it--- Cathy P. oerster Commissioner DATED this 3011 -of June, 2017. RECEIVED STATE OF ALASKA J(JN 1 Z01� AL . N OIL AND GAS CONSERVATION COMMIS O PERMIT TO DRILL 20 AAC 25.005 AOGCC la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Specify if well is proposed for: Drill 0 Lateral 0 Stratigraphic Test 0 Development-Oil Q ,Service- Winj 0 Single Zone ❑✓ ' Coalbed Gas 0 Gas Hydrates 0 Redrill 0‘ Reentry 0 Exploratory-Oil 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Geothermal 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q, Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 , TBU M-32RD2 . 3.Address: 6.Proposed Depth: 12.Field/Pool(s): I 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 13,722' '4 TVD: 9,961' McArthur River Field .. 4a. Location of Well(Governmental Section): 7.Property Designation: West Foreland Oil Pool • Surface: 969'FNL,527'FWL,Sec 33,T9N,R13W,SM,AK ADL018730 r Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: 2348'FSL, 1386'FWL,Sec 28,T9N,R13W,SM,AK N/A 7/16/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 418'FNL,848'FWL,Sec 33,T9N,R13W,SM,AK 3840 Acres . 9,465'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 160' 15.Distance to Nearest Well Open Surface: x-214171 y- 2499504 Zone-4 • GL/BF Elevation above MSL(ft): to Same Pool: 3280'from M-28RD 16.Deviated wells: Kickoff depth: 7,300 feet. ' 17.Maximum Potential Pressures in psig(see 20 AAC 25.035)A' c',qL� Maximum Hole Angle: 82.2 degrees r Downhole: 4765 Surface: 2512 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8-1/2" 7" 29# L-80 DWC/C 6,622' 7,100' 6,750' 13,722' 9,961' 683 sx 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft):. Effect.Depth TVD(ft): Junk(measured): 13,835' 9,667' 8,001' 8,001' 7,460' NA Casing Length Size Cement Volume MD TVD Conductor/Structural 981' 26" Driven 981' 981' Surface 1,347' 16" 1933 sx 1,347' 1,347' Intermediate 3,767' 13-3/8" 2244 sx 3,767' 3,766' Production 10,588' 9-5/8" 2607 sx 10,588' 9,206' Liner 1,430' 7" 72 bbls 10,731' 9,266' Liner 3,141' 4-1/2"(slotted) 13,835' 9,668' Perforation Depth MD(ft): See attached schematic Perforation Depth TVD(ft): See attached schematic Hydraulic Fracture planned? Yes 0 No 0 20. Attachments: Property Plat 0 BOP Sketch 7 Drilling Program 7 Time v.Depth Plot 7 Shallow Hazard Analysis— Diverter Sketch _ Seabed Report _ Drilling Fluid Program 7 20 AAC 25.050 requirements 7 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Monty Myers Authorized Name:Paul Mazzolini Contact Email: mmyers Ct hilcorp.com Authorized Title:Drilling Manager Contact Phone: 777-8431 Authorized Signature: ar Date: --72•6#( ff Commission Use Only Permit to Drill i API Number: p��, Permit Approval See cover letter for other Number: a 17.– �9 I 50- 733-d,01 G 02 -n' -W Date: (•Q–3 U – f 7 requirements. Conditions of approval: If box is checked,well may not be used-'too explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: 36-00 psi ©, ,,,_.5 t Samples req'd: Yes 0 No[? Mud log req'd:Yes 0 No[a H2S measures: Yes No 0 Directional svy req'd:Yes['No 0 m / A I-I: /'143P C<<:I4,4L...,*.f b-. RI• Spacing exception req'd: Yes 0 No Inclination-only svy req'd:Yes 0 No dile)rti' p... ¢re Z 04,4t` 2.5,1 0(__'-)' -1X4) Post initial injection MIT req'd:Yes❑ No❑ 1 4--- APPROVED BY // /Approved by: . • COMMISSIONER THE COMMISSION Dates'bmn and7 -or 1 -4U1 K. s wzu I i Ar:, ali rtGibr rtnuriltlb rfr n Lire date of approval per 20 AAC 25.°°5(g) Attachments in Duplicate Hilcorp Alaska, LLC P.O. Box 244027 Monty Myers • Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Energy Company 6/15/2017 RECEIVED Commissioner Alaska Oil & Gas Conservation Commission JUN 1 5 2017 333 W. 7th Avenue Anchorage, Alaska 99501 AOGCC Re: M-32RD2 Dear Commissioner, Attached is the application for permit to drill M-32RD2. M-32RD2 is an oil production well planned to be re-drilled in a North-easterly direction from M-32RD utilizing the existing casing program down to 7300' MD/6912'TVD. �otR S u yn 1/7-a y( At 7300' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets and ultimately penetrating the West Foreland 1 and 2."A 6422' x 8-1/2" open hole section is planned. A 7" 29# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8" ESP completion. Drilling operations are expected to commence approximately July 16th, 2017. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, rpoi,ternevrireLL rag/ Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • • RECEIVED JUN 15 2017 AOGCC H Hilcorp Alaska, LLC M-32RD2 Drilling Program McArthur River i ro dby: M• IliMilit Revision 0 June 13, 2017 • M-32RD2 Drilling Procedure Rev 0 HiIcorp %Li.ka,LLf. Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program 4 4.0 Drill Pipe Information 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 BOP NAT and Test 11 11.0 Mud Program and Density Selection Criteria 12 12.0 Whipstock Running Procedure 13 13.0 Whipstock Setting Procedure 16 14.0 Drill 8-1/2"Hole Section 19 15.0 Run 7"Production Liner 22 16.0 Cement 7"Production Liner 25 17.0 Wellbore Clean Up &Displacement 29 18.0 Run Completion Assembly 30 19.0 RD 30 20.0 BOP Schematic 31 21.0 Wellhead Schematic 32 22.0 Days vs Depth 33 23.0 Geo-Prog 34 24.0 Anticipated DrillingHazards 35 P 25.0 FIT Procedure 36 26.0 Choke Manifold Schematic 37 27.0 Offset MW vs.Depth TVD 38 28.0 Casing Design Information 39 29.0 8-1/2"Hole Section MASP 40 30.0 Plot(NAD 27) (Governmental Sections) 41 31.0 Slot Diagram (As Built) (NAD 27) 42 32.0 Directional Program (wp04) 44 • • M-32RD2 Drilling Procedure Rev 0 flilcorp Alaska,l,Ll: 1.0 Well Summary Well M-32RD2 Pad&Old Well Designation Sidetrack of existing well M-32RD(PTD#199-097) Planned Completion Type 7"29#L-80 Liner,2-7/8 Tubing w/ESP Target Reservoir(s) West Foreland / Planned Well TD,MD/TVD 13722' MD/9961' TVD PBTD, MD/TVD 13600' MD/9944' TVD Surface Location(Governmental) 969' FNL, 527' FWL, Sec 33, T9N,R13W, SM,AK Surface Location(NAD 27) X=214171.96,Y=2499504..41 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 2348'FSL, 1386'FWL, Sec 28,T9N, R13W, SM,AK TPH Location(NAD 27) X=215079.64,Y=2502827.61 TPH Location(NAD 83) BHL(Governmental) 418'FNL, 848'FWL, Sec 33, T9N,R13W, SM,AK BHL(NAD 27) X=214479.14,Y=2500075.25 BHL(NAD 83) AFE Number 1712187D AFE Drilling Days AFE Drilling Amount $5.7 MM Work String 5" 19.5# S-135 NC-50(Rental string from Weatherford) RKB 160' Water Depth 187' BOP Equipment 16-3/4"5M Hydril Annular BOP 16-3/4" 5M Cameron Type U Double Ram 16-3/4" 5M Cameron Type U Single Ram Page 2 Revision 0 June, 2017 ! ! M-32RD2 Drilling Procedure Rev 0 Iideorp:va.ka. 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp l:nct y Company Changes to Approved Permit to Drill Date: June 13, 2017 Subject: Changes to Approved Permit to Drill for M-32RD2 File#: M-32RD2 Drilling Program Any modifications to M-32RD2 Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Monty M Myers 06.13.2017 Drilling Engineer Date Page 3 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 3.0 Tubular Program Hole Section OD (in) Wt(#/ft) Coupl OD ID (in) Drift(in) Grade Conn Top Bottom 8-1/2" 7" 29 7.656 6.184 6.059 L-80 DWC/C 7100 13722 4.0 Drill Pipe Information Hole OD ID (in) TJ ID TJ Wt Grade Conn Burst Collapse Tension Section (in) (in) OD (#/ft) (psi) (psi) (k-lbs) (in) 8-1/2" 5" 4.276 3-1/4 6-5/8 19.5 S-135 NC-50 17,105 15,638 560 All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 June, 2017 I M-32RD2 Drilling Procedure Rev 0 Itilcorp Alaska,1.1A 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates v. Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp.com and cdinger@hilcorp.com 5.3 5am Weekend Update vi. Submit a short operations update each weekend and holiday to whoever is assigned weekend or vacation duty. Details will be sent before each weekend or holiday. vii. Copy pmazzolini@hilcorp.com, and mmyers@hilcorp.com 5.4 EHS Incident Reporting viii. Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 b. Leonard Dickerson: 0: (907) 777-8317 C: (907)252-7855 2. Spills: Keegan F: 0:907-777-8477 C:907-350-9439 ix. Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 x. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally xi. Send final"As-Run"Casing tally to mmyers@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cmt report xii. Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp.com Page 5 Revision 0 June, 2017 • M-32RD2 Drilling Procedure Rev 0 IIilrorp:\la.k:,.1,1.(: 6.0 Planned Wellbore Schematic PROPOSED trading Bay Unit/Steehead Platform Well#:M-32RD2 11$14 wit 114.44 I I I Completed:FUTURE RKB=75.151Rig Floor to TBG Head Q eE Size Type Wt Grade Thrd ID Top Btm Hole ite i" 26" Conductor Surf 981' Driven 16" Surf Csg 75 K-55 BTC 15.1 Surf 1,347' 22" 13-3/8" Csg 61 K-55 BTC 12.5 Surf 3,767' 17.5" !,,It 9-5/8" Prod Csg 54 L-80 BTC 8.535 Surf 10,588' 12.25" e N;. Bag to 0 4`. ♦ i JEWELRY DETAIL • NO. Depth(MD) Depth ID Item ,� (TVD) ±7,100 SDD Baker Liner Hanger '' ±7,300' ±6,912 KOP "'' ±7,100'—13,722 9,961' 7"29#L-80 DWC/C R y' a ^ CEMENT DETAIL /3* (7-0 ,. TOC Depth TOC Depth No Volume Item 1, y (MD) (TVD) 1 41 P 4 ±9,000' ±7,765' 160 bbls 15.3 ppg Class G cement w/34 bbl eFibrous LCM 14 a PBT:=13.600'6D,9944'TVD TO=13,7221.10,9661'TVD Page 6 Revision 0 June, 2017 1 • 1 H • 1 M-32RD2 Drilling Procedure Rev 0 Mem")Alaska,I.I.1: ' 7.0 Drilling Summary M-32RD2 is an oil production well planned to be re-drilled in a North-easterly direction from M-32RD utilizing the existing casing program down to 7300' MD/6912' TVD. At 7300' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets and ultimately penetrating the West Foreland 1 and 2. A 6422' x 8-1/2"open hole section is planned. A 7"29#L-80 DWC/C prod liner will be run, cemented,and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8"ESP completion. Drilling operations are expected to commence approximately July 16th,2017. ,v, All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. A' a 3 A4i A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and for running the completion assembly L—,7 1u,04.. s,..„—i. General sequence of operations pertaining to this approved drilling procedure: / 1. Steelhead Rig 51 will be over slot 2 Leg B-1 (M-32RD)to de-complete and P&A well under separate sundry 317-.2'11 0 2. DP should be stood back in derrick 3. PU whipstock, and mills and TIH to CIBP 4. Orient whipstock and set at 65 deg left of highside. 5. Mill 8-1/2"window and 35' of new formation at 7300'. 6. POOH and LD mills. PU directional BHA and TIH to window. 7. Swap well to 8.9 ppg oil based drilling mud 11^_''' ,..1 S8. Perform FIT to 12.5 ppg EMW 9. Drill 8-1/2" production hole from 7335' to 13722' MD,performing short trips as needed 10. Perform short trip and condition mud. POOH 11. LD Directional Tools. RIH w 7" liner. Set liner and cement. Circ wellbore clean. 12. POOH, laying down DP and liner running tools, 13. PU 7"casing scraper assembly and TIH to landing collar. 14. Circ casing clean. POOH laying down DP. 15. Run 2-7/8" completion. (Covered under separate sundry) 16. Land hanger and test. 17. ND BOPE,NU tree and test void Page 7 Revision 0 June,2017 • M-32RD2 Drilling Procedure Rev 0 Ilil•orp la.ka. 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance j Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2)week intervals during the drilling of M-32RD2. Ensure to provide AOGCC 48 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test ALL BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: o The calculated MASP for this wellbore when completely evacuated to gas is 3272 psi. However, for Cook Inlet Operations, we assume that the well can never flow 100% gas, due to the water in the reservoir. We reduce this MASP calculation to 2501 psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to 9.2 ppg reservoir fluid. ,elf µ4SP Page 8 Revision 0 June, 2017 • S M-32RD2 Drilling Procedure Rev 0 I Iih orp. I8-ka.I,I.1: Hole Section Equipment Test Pressure (psi) • 16-3/4" Hydril 5M annular • 16-3/4"5M Cameron U Double gate Initial Test:250/3500 o 2-7/8"X 5"VBR in upr cavity (Annular 2500 psi) o Blind ram in btm cavity 8-1/2 •• Mud cross • 16-3/4"5M Cameron U single gate Subsequent Tests: • 3-1/16"5M Choke Manifold 250/3500 • Standpipe,floor valves,etc (Annular 2500 psi) Note:7"casing ram in lower ram for 8-1/2"hole section. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back- up is an air pump, and tertiary emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 48 hours notice prior to spud. • 48 hours notice prior to testing BOPs. • 48 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236 (During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Revision 0 June, 2017 S s M-32RD2 Drilling Procedure Rev 0 Ililcorp Alaska,1A.1: 9.0 R/U and Preparatory Work 9.1 Separate sundries will be submitted that will include the following: • Pull tubing • P&A lower perfs with a cement plug • Set CIBP 9.2 Mix oil based mud for 8-1/2" hole section. Page 10 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 Ilikorp Alaska,LI E 10.0 BOP N/U and Test 10.1 * BOPE was NU and tested on prior decompletion sundry. We will test BOPE on 7 day cycle until the window is milled, at that point we will switch to the 14 day test cycle. Continue on to step 11. 10.2 N/U 16-3/4"x 5M BOP as follows (top down): • 16-3/4"x 5M Shaffer annular BOP. • 16-3/4" Shaffer Type "CIW-U"Double ram. (2-7/8"X 5"VBR in top cavity, blind ram in btm cavity) • 16-3/4"mud cross • 16-3/4" Shaffer Type "CIW-U" single ram. (2-7/8"X 5"VBR) • N/U pitcher nipple, install flowline. • Install (2)manual valves on kill side of mud cross. Manual valve used as inside or"master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 10.3 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test VBRs on 5"test joint. • Ensure gas monitors are calibrated and tested in conjunction w/BOPE. 10.4 R/D BOP test assy. 10.5 Continue mixing mud for 8-1/2"hole section. 10.6 Set wearbushing in wellhead. Ensure ID of wearbushing> 7". Page 11 Revision 0 June, 2017 • S M-32RD2 Drilling Procedure Rev 0 llilcorp Alaska,LLC 11.0 Mud Program and Density Selection Criteria 11.1 8-1/2"Production hole mud program summary: Primary weighting material to be used for the hole section will be barite to minimize solids. We will have enough barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. Canrig PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 80/20 Enviromul MOBM Properties: MD Mud Weight Viscosity PV YP HTHP WPS ES (pPg) 7,300—13,722' (8.9-9.5 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration`s "66r64 1466, LVT 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.2 ppg(as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROL PLUS 4 ppb 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Revision 0 June,2017 • • M-32RD2 Drilling Procedure Rev 0 lIllcorp Alaska,LL(: 12.0 Whipstock Running Procedure Section 12.1 through 12.5 is covered under decompletion sundry, drilling proceed to 12.6 12.1 M/U window milling assembly and TIH w/4-1/2" DP out of derrick. • Use an 8-1/2"taper mill and an 8-1/2" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (7300' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the # of joints picked up so we know where we are. 12.3 Pressure test casing to 2500 psi /30 min. Chart record casing test & keep track of the amount of fluid pumped. Stage up to 2500 psi in 500 psi increments. 12.4 CBU & circ at least (1) hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.5 TOH. 12.6 Make up mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Leave assembly hanging in the elevators, and stand back on floor. 12.10 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.11 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Note: Attach mills to Whipstock with (1) 35k mill shear bolt. 12.12 If needed, open BOP Blinds. Page 13 Revision 0 June, 2017 M-32RD2 Drilling Procedure Rev 0 Ililcorp Alaska,1,1,C 12.13 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.14 Release pick up system at this point, Make up mills. 12.15 With the top drive,pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up, the shear bolt then can be made up by the Baker Rep. 12.16 The assembly can now be picked up to ensure that the shear bolt is tight. 12.17 Remove the handling system. 12.18 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP &wear bushing. 12.19 Run in hole at 1 1/2 to 2 minutes per stand. 12.20 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.21 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.22 Orient at least 30' —45' above the CIBP. Page 14 Revision 0 June,2017 0 14M-32RD2 Drilling Procedure Rev 0 Hilcorp Alaska.LAA: oww Window Master G2 Whipstock MNBAKER .... With Torque Master Bottom Trip Anchor HUGHES 404i� 9.625 53.5#Non Special Drift Casing Baker Oil Tools • • • Upper Watermelon Mill ■ OD: 8.500 8.500 --► / `i t— 6.25 Length: 6.25 • Flex Joint 1 OD: 6.375 In Length: 9.00 W 6.375 —* I 4— 9.00 Lower Watermelon Mill OD: 8.375 Length: 5.66 III A Window Mill 40.6 - OD: 8.500 8.250 —it. 4— 5.66 Length: 1.13 — l \I Whipstock • OD: 8.000 8.500 —r n �_ t Length: 18.54 67771, A A if� 1 1.13 Face Angle: 1.9 rFace Length: 17.08 I Retrieval BTA OD: 8.357 17.08 Length: 3.41 18.54 1.9 Overall length —o. Length: 44' WELL INFORMATION CUSTOMER • FIELD —► ME 4-- 8.000 LEASE v 7nomWELL NO. SHEAR BOLT 25,000 3.41 �i _35,000 8.357 —÷ •F 4- 45,000 +i 55,000 65,000 II 75,000 NOTE DM ENSIONSAR BAD ON THUNFI DATA.ACTUAL DUA ENSK)NS MAY VARY Page 15 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 Ilileorp Alaska,I.1,4 13.0 Whipstock Setting Procedure 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using highside MWD. 13.2 Orient Whipstock to desired direction by turning DP in '/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 45 L HS 65 L HS Vir Desired orientation of the Whipstock face is 65 degrees left of high side. Hole Angle at window interval (7300' MD) is 54 deg. The wellbore trajectory is planned to kick off at low and at 37 degrees azimuth. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). PEA 13.5 P/U 5-10' above top of Whipstock. f 13.6 Displace to 8.9 ppg 80/20 Enviromul MOBM. 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light we ght and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. S Page 16 Revision 0 June, 2017 H • M-32RD2 Drilling Procedure Rev 0 Hilcorp Alaska,LLC 13.10 Estimated metal cuttings volume from cutting window: Wieght of Cuttings For Milled Casing Exit O.D. Of Casing (in) 9.625 I.D. Of Casing (in) 8.535 Whipstock Face Length (Ft) 16.00 0 Percent of Casing Removed (/o) ' 38 Milled Area (in^12) 5.908 Volume of Cuttings(in^3) 1134.272 Density of Casing (Ib.lin^3) " 0.283 Weight of Cutting Generated (lbs) 321.0 ' Calculated Average of Casing Removed Based on Drift Mills (38%) • Density of Steel= .283 ____ 13.11 Drill approx. 35' rat hole to accommodate the rotary steerable drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in=MW out. 13.13 Conduct FIT to 12.5 ppg EMW. • (12.5 —8.9) * 0.052 * 6912' tvd= 1294 psi 13.14( icoieance � '` • (12.5 - 8.9) * (6912/9961) =2.5 Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 12.5 ppg FIT results in a 4.09 ppg kick tolerance while drilling the interval with a 8.9 ppg fluid density. 13.15 Slug pipe and POOH. Gauge Mills for wear. 13.16 Should a second run be required pick up the following BHA. Page 17 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 Ililcorp:11a4ca, Back Up Mills Connection Length O.D. WINDOW MILL 4 % REG-P X MILL 2.25 8.5 NEW LOWER WATERMELON MILL 4 '/ REG-P X 4 1/2 REG-B 5.5 8.5 FLEX JOINT 4 '/ REG-P X 4 % REG-B 9.0 6.375 STRING MILL 4 1/2 REG-P X 4 '/ REG-B 5.5 8.5 FLOAT SUB 4 %" REG-P X 5 1/2" NC50-B 3.0 6.375 30 jts-HWDP 5 '/" NC50-B X 5 %" NC50-P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY.! Page 18 Revision 0 June, 2017 H • M-32RD2 Drilling Procedure Rev 0 Ililcorp Ala.ka.1,1.1: 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2" rotary steerable drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.51 -0.61 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 450-550 gpm. 14.6 Primary bit will be the Halliburton 8-1/2" MM75DC PDC bit. Ensure to have a back up bit available on location. COMPONENT DATA Item Description ... M :Bede Number t OD ID Gauge Weight Top Length Cumulative # (in) (in) (in) (Ibpf) Connection (tt) Length (tt) ME MMB PDC 6.360 2.750 8.500 88.03 P 4-1'2"REG 0.95 0.95 © Dingo 7600 Rotary Steerable System - 7.625 2.000 144.91 B 4-1 2"IF 23.16 24.11 _ Stabilizer -__ 8.250 _--- © 6-3 4"DGR(Gammai / 6.760 1.920 97.80 B 4-1 2'IF 8.22 32.33 0 Inline Stabilizer(ILS) 6.750 1.920 8.250 112.09 B 4.1 2"IF 2.20 34.53 © 6-34"PWD(Pressure} 6.750 1.920 96.30 B 4.1'2"IF 4.43 38.96 0 6-3'4"ADR Collar(Resistivity) / 6.690 1.920 109.40 B 4.1 2'IF 24.32 63.28 WM6.3'4"DM Collar(Directional) 6.760 3.125 103.40 B 4-1 2"IF 9.16 72.44 In 6-3 4"TM Collar(Mud Pulse 6.770 3.250 103.60 B 4-1'2'IF 10.38 82.82 Teleme I 9 6 3'4"Float Sub 6.810 2.875 102.01 B 4-1 2"IF 2.99 85.81 10 6 3'4"Non Mag Flex Collar 6.850 2.875 103.47 B 4.1 2"IF 31.09 116.90 MI 6 3 4"Non Mag Flex Collar 6.670 2.938 95.98 8 4-1'2'IF 30 68 147.58 ® 6 3'4'Non Mag Flex Collar 6.590 2.813 95.07 B 4.1'2"IF 30.78 178.36 ® 4 1:2'IF P x XT-39 B 6.500 2.500 96.36 8 4"XT39 1.51 179.87 EX 6 jts 4"XT-39 HWDP 4.000 2.652 24.00 181.40 361.27 ® XT-39 P x 4 1 2"IF B 6.500 2.875 90.96 B 4-1.2'IF 1.30 362.57 ILI 6-1:'4"Jar 6.500 2.500 Call B 4-1 2"IF 30.00 392.57 ® 4 1 2'IF P x XT-39 B 6.500 2.500 96.36 P 4'XT39 1.62 394.1 9 Ell 9 jts 4"XT-39 HWDP 4.000 2.562 25.26 274.50 668.69 TOW:..i,a 668.69 Page 19 Revision 0 June, 2017 • M-32RD2 Drilling Procedure Rev 0 tlarvmp:1Ja-kit.t.I.t: HALLIBURTON 8-1/2" (216mm) MMD75DC PRODUCT SPECIFICATIONS Cutter Type Select Cutter tio IA DC Code M422 Body Type MATRIX Total Cutter Count 72 s>y..r Cutter Distribution 13mm 10mm " " /Face 0 4b Gauge 7 12 Up Drill 7 0 Number of Large Nozzles 0 0°' Number of Medium Nozzles 0 Number of Small Nozzles 7 40• Number of Micro Nozzles 0 Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 - Junk Slot Area(sq in) 13.06 Normalized Face Volume 37.82% 100° API Connection 4-1/2 REG.PIN Recommended Make-Up Torque* 12.461 17.766 Ft*lbs. Nominal Dimensions** �►'. Make-Up Face to Nose 10.90 in-278 mm **0 Gauge Length 3 in-76 mm *' Sleeve Length 00 m- mm Shank Diameter 0 in- 152 mm Break Out Plate(Mat..= LegacyF-) 181954'44040 Approximate Shipping Weight I 80Lbs.-82Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads. 1'10"Stepped Gage.Carbide Impact Arrestor.Optimized Dual Row-"D"Feature Material #846097 *Bit specific recommended make-up torque is a function of the hit I.D.and actual bit sub O.D.utilized as specified in API RP7G Section A.8.2. **Design dimensions are nominal and may vary slightly on manufactured product.Halliburton Drill Bits and Services models are continuously reviewed and refined. Product specifications may change without notice. r 2010 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.com Page 20 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 llileurp Alaska,LAA 14.7 TIH to window. Shallow test MWD on trip in. 14.8 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.9 Drill 8-1/2"hole to 13722' MD using rotary steerable assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See mud program for hole cleaning and LCM strategies. • Ensure solids control equipment is functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss <6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.10 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.11 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.12 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 June,2017 M-32RD2 Drilling Procedure Rev 0 Ilileorp AIa.ka. 15.0 Run 7" Production Liner 15.1 R/U Weatherford 7" casing running equipment. • Ensure 7" DWC/C x 5"NC-50 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total #of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor & model info. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • No centralizers to be installed on shoe joint, FC joint, and LC joint. • Install volant or equivalent solid body centralizers, one per joint to +/- 9,000' TMD, and leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe & FC. 15.4 Continue running 7"production liner • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 9,000' MD. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7" DWC/C M/U torques Casing OD Minimum Maximum Yield Torque 7" 19,200 ft-lbs 22,100 ft-lbs 25,000 ft-lbs Page 22 Revision 0 June,2017 • M-32RD2 Drilling Procedure Rev 0 I I Ie orp:Ua..ka,1.1.1 Technical Specifications Connection Type: Size(O.D.): Weight (Wall): Grade: DWC/C Casing 7 in 29.00 lb/ft (0.408 in) L-80 2012 API Spec 5CT Coupling O.D. Material L-80 Grade wog; 80.000 Minimum Yield Strength (psi) 11/801111//////!'USA 95.000 Minimum Ultimate Strength (psi) VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Pipe Dimensions HoustPhone:713-479-3200 7.000 Nominal Pipe Body O.D. (in) Fax:713.479-3234 6.184 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesRvam•usa.com 0.408 Nominal Wall Thickness (in) 29.00 Nominal Weight (lbs/ft) 28.75 Plain End Weight (lbs/ft) 8.449 Nominal Pipe Body Area (sq in) � Pipe Body Performance Properties 676,000 Minimum Pipe Body Yield Strength (lbs) 7,030 Minimum Collapse Pressure (psi) 8.160 Minimum Internal Yield Pressure (psi) 7.500 Hydrostatic Test Pressure (psi) Connection Dimensions 7.875 Connection 0.D. (in) 6.184 Connection I.D. (in) 6.125 Connection Drift Diameter(in) 4.50 Make-up Loss (in) 8.449 Critical Area (sq in) • +i 100.0 Joint Efficiency (%) Connection Performance Properties 676.000 Joint Strength (lbs) 16,650 Reference String Length (ft) 1.4 Design Factor 718,000 API Joint Strength (lbs) 338,000 Compression Rating (lbs) 7.030 API Collapse Pressure Rating (psi) 8.160 API Internal Pressure Resistance (psi) 26.2 Maximum Uniaxial Bend Rating [degrees/100 ft] 1 • • Appoximated Field End Torque Values 19.200 Minimum Final Torque (ft-lbs) 22.100 Maximum Final Torque (ft-lbs) 25.000 Connection Yield Torque (ft-lbs) Page 23 Revision 0 June, 2017 • M-32RD2 Drilling Procedure Rev 0 Hileorp Alaska,IAA; 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 15.8 Before picking up Baker SDD liner hanger/packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker SDD liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/liner on DP no faster than 1 min/stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 9-5/8"window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. • 15.19 Reciprocate &rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 June,2017 • M-32RD2 Drilling Procedure Rev 0 I lik or1,:�Iaska.1.1.1: 16.0 Cement 7" Production Liner • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 15 bbls 12.5 ppg spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Mix and pump 163 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl of loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to bring cement up to a minimum of 500' above hemlock in annulus of 7" casing and 8- 1/2" open hole. Est TOC 9000' TMD. 16.6 Displacement fluid will be drilling mud. --126 bbls of displacement fluid in drill pipe and—243 bbls of displacement fluid inside liner. Total of—369 bbls Cement Calculations 8-1/2"OH x 7"Liner: (13722' —9000') x 0.02259 x 1.5 = 160 bbls Shoe Track: 80' x 0.03715 = 3 bbls Total Volume(bbls): 160 +3 = 163 bbls Total Volume(ft3): 163 bbls x 5.615 ft3/bbl= 915 ft3 Total Volume(sx): 915 ft3 / 1.34 ft3/sk= 683 sx y Page 25 Revision 0 June,2017 • • M-32RD2 Drilling Procedure Rev 0 ffilcorp Alaska,11.1: Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk V/ Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF/ 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2%BWOC Additives D202 Dispersant 1.5% BWOC D400 Gas Control Agent 0.8%BWOC D154 Extender 8.0% BWOC 16.7 Drop DP dart and displace with drilling mud. 16.8 Pump cement at max rate of 8 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point 16.9 If elevated displacement pressures are encountered,position liner at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.10 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger(15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.11 Slack off total liner weight plus 30k to confirm hanger is set. 16.12 Do not overdisplace by more than 1/2 shoe track(-1 bbls). Shoe track volume is 1.8 bbls. 16.13 Pressure up to 4200 psi to release the running tool(HRD-E) from the liner Page 26 Revision 0 June, 2017 S 14 11M-32RD2 Drilling Procedure Rev 0 Ililcarp Alaska,LLC 16.14 Bleed pressure to zero to check float equipment. 16.15 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.16 Rotate slowly and slack off 50k downhole to set ZXP. 16.17 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS profile. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area(ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 16.18 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.19 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 16.20 Watch for cement returns and record the estimated volume. Rotate& circulate to clear cmt from DP. 16.21 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.22 If the HRD-E tool still does not release hydraulically, left-hand(counterclockwise)torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.23 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 16.24 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 June,2017 • M-32RD2 Drilling Procedure Rev 0 ITilcorp Alaska,TIC Ensure to report the following on Wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Note: Send Csg& cmt report+ "As Run"liner tally to mmyers(aIhilcorp.com Page 28 Revision 0 June,2017 • M-32RD2 Drilling Procedure Rev 0 Ililcor1,Alaska.LLC. 17.0 Wellbore Clean Up & Displacement 17.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 6"bit or mill • Casing scraper&brush for 7"29# casing • +/- 6622' of 4"workstring. • Casing scraper&brush for 9-5/8"47# casing • (2000') 5"DP • Casing scraper&brush for 9-5/8" 47#casing • 5"DP to surface. 17.2 TIH & clean out well to landing collar(+/- 13,322' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 6"bit is worked down to the landing collar. • Space out the cleanout BHA so that the 6"bit reaches the 7" landing collar when crossover is +/- 30' above the 7" liner top. C45/kE, -1-- 17.3 After wellbore has been cleaned out satisfactorily using mud, test casing to 2500 psi/30 min. Ensure to chart record casing test. "� 7/I 17.4 Displace drilling fluid in wellbore with a hi-vis pill followed by filtered inlet water. • Circulate 3 to 4 B/U until clean-up is satisfactory. Do not recirculate fluid, pump and dump • After a couple circulations using FIW, short trip the assy to bring the upper 9-5/8"multi-back assy to surface. • RIH again&tag landing collar w/6"bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Pump a chemical train followed by FIW. Target NTU's are 80-100 17.5 TOH w/clean out assy. Page 29 Revision 0 June, 2017 ! • M-32RD2 Drilling Procedure Rev 0 Ili!carp Alaska,LLC 18.0 Run Completion Assembly 18.1 Run 2-7/8"tubing completion assembly as per separate Approved Completion Sundry 19.0 RD te - - 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE,NU tree, test void 19.3 Prep to skid rig Page 30 Revision 0 June, 2017 • S M-32RD2 Drilling Procedure Rev 0 Ilileorp Alaska,I,1A 20.0 BOP Schematic la1. 111 III 1.11.11.1 Iu NYdail 1.11.11.11. 5.46' wmw,e.ee.earxsr1.1 1111.11./ nl an • K;II Side 31/8 SM 1.$I.1 I.1 1.1 I Choke side m Naaland NCR 3.W . 31/85M II{'.w�}I1I I.i 1.11.11.1 11 ®I{�r}lIOI00' Manwiand NCR Ute- 1.11.11811.1 I. 3.58' .I 1.1 .1 .1 I OSA 16%10MX16%SM i.,. _.....I 1.11.11.11,1 il, Amer,16%SM API hub X 16 3/4 IOM FE 114.u.,1 se..Icor V -on.we.w.a Poor Ike Riser,16%SM FE X16%SM API hub 141 101 Page 31 Revision 0 June, 2017 • M-32RD2 HDrilling Procedure Rev 0 IIi corp:\Ia,ka.I,I.I: 21.0 Wellhead Schematic Slecihe4d Natform Tba?ungcr,FM(IC IA.EN. M•32 CCS,16%5M X 411 Hydnt 26036%13318%95/8X 563 Mt and sump,w/4"Type 4 1/2 H 60V profle,2-3/K Cpnc,nuous Control line, 41055 malenal PITA,Bowen, 4 1/16 5M f E 6 T-SSA Bowen "'IT' afamc Valve,Swab•WKM-M, p^^,•r 41/165M FE,HWO,OO 7 �� Valve.Wog,WKM.44, li 4 1/16 3M FE.IMO,00 u�. II :nilP - Valve,upper mater,SW. E' 41/16 SM FE,w/15'Safecc operator,EE ® /�V a -4tm V41ye,Master,WKM-M, r VaWe,wen, WS 41/16SM FE.HWO,OO /" ^ 41/1b SM FE,w/I5"Safeco ;r; operator,EE Tutting head,FMC.TC-60,spec for a:; r I.9 , .a tniMad 16%SM FE top X 16%SM stdd bottom,w/2.2 1/16 SM 550 �� -11.- 'T_ 9 — Valve,FMC-120, Un:head.CMC Type 2,16%5M 21/16 SM FE,HWO,AA FE top X21%2M FMC speedlork t bottom,w/4-2 1/16 SM S5O ll I AM /7-_' SEA: •:-,� f • i. f i• til' f; �. mom(4 .� ,I t Adapt,spool,FMC A 5 5 30'MS5 rte-7.' IF 1b stdd bottom X 21%2M CMC Fi d 41 spet�ock top,w/2 2'10O Al9 i lit MINN MI Starting head.FMC,30"Mss FE x 26"butt weld ' i I MINN �I ■ Page 32 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 llilcorp Alaska,LLC 22.0 Days vs Depth Days Vs Depth 0 M-3 ARD2 2000 4000 _.._.... 6000 .)._.. 8000 r � v N a) 10000 11111 12000 14000 16000 18000 0 5 10 15 20 25 30 35 40 45 Days Page 33 Revision 0 June, 2017 HM e M-32RD2 Drilling Procedure Rev 0 lliIcorp,11a.ka,Ilk 23.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: M-32RD2 FIELD: MCARTHUR RIVER M-32RD, SURFACE X: 214171.96 As-Built Survey STATE Alaska SURFACE Y: 2499504.411 BOTTOM HOLE X 1 214479.14; TVD REF DATUM KB BOTTOM HOLE Y 2500075.25 TVD REF ELEV 160 COORD REF.SYSTEM NAD27 AK4 True North GROUND ELEV 0.0 , PROPOSED TD: 13722 MD WATER DEPTH 187.0 PROPOSED TD. 9961 TVD Drill a sidetrack out of the M-32RD (Steelhead)to test and complete the Westforland WF1 thru WF2 benches. Objective: Geo Summary/ Based on subsurface evaluation Justification: M-32RD2 TARGETS,ANTICIPATED FORMATION TOPS& GEOHAZARDS ORMAT/O*" MD 0 t.Pressur• El FLUID R,.. KOP 7300 6,913 3100 8.6 0.45 COAL39 Coal i 10203 8,651 3300 7.3 0.38 HIX_FW Sand/Conglomerate Oil Sand 10609 9,044 3553 7.6 0.39 HTKE-FW Sand/Conglomerate Oil Sand 10659 9,089 3570 7.6 0.39 HK2T Sand/Conglomerate Oil Sand 10699 9,123 3600 7.6 0.39 HK3T Sand/Conglomerate Oil Sand 10858 9,252 3700 7.7 0.40 HK5T I Sand/Conglomerate Oil Sand 1 11181 9,455 3500 7.1 0.37 HK6T Sand/Conglomerate Oil Sand 11402 i 9,544 3585 7.2 0.38 Sand/Conglomerate Oil Sand 11787 9,658 4250 8.5 " 0.44 WF_2 Sand/Conglomerate Oil Sand 12405 9,782 4282 8.4 0.44 TD 13722 9,661 4200 8.4 0.43 . =Primary Objective =Secondary Objective rP_laei4IF:iN 50 FT DATA COLLECTION REQUIREMENTS: Mud Logging 4 man Crew below KOP LWD Data. Rotary Steerable, Gamma Res with Triple combo Mad Pass at TD E-Line Log Data: COMPLETION TYPE ESP Completion ANTICIPATED RATES —500-3000 bpd gross fluid ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE OTHER COMMENTS Well will TD in WF2 zone and will run from 12384lVD to 13911 MD in WF2 zone. Page 34 Revision 0 June,2017 4 M-32RD2 Drilling Procedure Rev 0 Iti'carp Alaska,II 24.0 Anticipated Drilling Hazards Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual-composition carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 35 Revision 0 June, 2017 S M-32RD2 Drilling Procedure Rev 0 Hilcorp Ala.ku.III: 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure.Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 36 Revision 0 June, 2017 • M-32RD2 HDrilling Procedure Rev 0 ltilcorp Alaska,LLC. 26.0 Choke Manifold Schematic • TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS .1 'I Ate' . m -- 1 I 111C •,• , , : 4; • t:1/4) ' T.Mill pi rims, Vit./ kat Illga li •i: ICA., _-_----n I--- -------�• 1 1 — I • 1101,1. •�t a`, rime 1110.1111 'I I t_a. y* .. )(I MIA, 11) V •' ✓ •p1 PI '41 v 461, , .r• !,.±._.! 111111111111 ' [, UR I SWACO JI. I F il +► CHOKE LINE { ' A---I SECTION AA * ALL VALVES IN FLOW PATH ARE 3-1/16' 5000 PSI CAMERON GATE TYPE l l.. Page 37 Revision 0 June,2017 • s M-32RD2 Drilling Procedure Rev 0 orp ‘1.1-1.i.I I 27.0 Offset MW vs. Depth TVD MW vs TVD Offsets 0 , A-15RD2(2002) 1,000 — —G-28RD(2000) G-15RD(1998) 2,000 -K-13RD2 (2001) 3,000 ---- D-4$(1999) -- M29A(2012, 1700 ft @ 4,000 — — — 75 deg) -M31B(2013, 1500 ft @ 70 deg) 5,000 6,000 7,000 1 8,000 - i 9,000 "MIN ►' 10,000 11,000 - -- 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 Mud Weight(PPG) Page 38 Revision 0 June, 2017 • M-32RD2 Drilling Procedure Rev0 Ililcurp Alaska,LLC, 28.0 Casing Design Information Calculation & Casing Design n Factors Cook Inlet Offshore DATE: 6/13/2017 WELL: M-32RD2 FIELD: McArthur River DESIGN BY: Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 2512 psi (See attached MASP determination& calculation) Al Production Mode MASP: 4765 psi (See attached MASP determination & calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.43 psi/ft) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 7" Top(MD) 7,100 Top(TVD) 6,755 Bottom (MD) 13,722 Bottom (TVD) 9,961 Length 6,622 Weight(ppf) 29 Grade L-80 Connection DWC/C Weight w/o Bouyancy Factor(lbs) 192,038 Tension at Top of Section (lbs) 192,038 Min strength Tension(1000 lbs) 676 Worst Case Safety Factor(Tension) 3.52 Collapse Pressure at bottom (Psi) 3,905 Collapse Resistance w/o tension (Psi) 7,030 Worst Case Safety Factor(Collapse) 1.80 MASP (psi) 2,512 Minimum Yield(psi) 8,160 Worst case safety factor(Burst) 3.25 Page 39 Revision 0 June, 2017 iii • • M-32RD2 Drilling Procedure Rev 0 I lileorp Alaska,L1.l. 29.0 8-1/2" Hole Section MASP 11 Maximum Anticipated Surface Pressure Calculation Hilcorp 8-1/2"Hole Section M-32RD2 Cook Inlet,Alaska MD al____ ND Planned Top: 7300 6912 Planned ID: 13722 9961 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad COAI39 8651 3300 Coal 7.3 0.38 H1X_FW 9044 3553 Sand/Conglomerate 7.6 0.39 HTKE-FW 9089 3570 Sand/Conglomerate 7.6 0.39 HK2T 9123 3600 Sand/Conglomerate 7.6 0.39 HK3T 9252 3700 Sand/Conglomerate 7.7 0.40 HK5T 9455 3500 Sand/Conglomerate 7.1 0.37 HK6T 9544 3585 Sand/Conglomerate 7.2 0.38 WFT 9658 4250 Sand/Conglomerate 8.5 0.44 WF_2 9782 4282 Sand/Conglomerate 8.4 0.44 TD 9661 4200 Sand/Conglomerate 8.4 0.43 Offset Well Mud Densities t_____ Well MW range Top(ND) Bottom(ND) Date M-31B 9.6-9.7 7,755 9,718 2013 G-28RD 8.6-9.5 8,100 9,600 2000 -_ G-15RD 8.6-9.4 8,500 9,550 1998 M-29A 9.2-9.5 8,050 9,800 2012 Assumptions: -._ 1. Anticipated fracture gradient at 7300'TMD(6912'ND)=0.7=14.9 ppg EMW 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assumes 9.2 ppg reservoir contains 2/3 gas,1/3 water. Fracture Pressure at window considering a full column of gas from window to surface: 6912(ft)x 0.7(psi/ft)= 4838 4838(psi)-[0.1(psi/ft)*6912(ft)]= 4147 psi MASP from pore pressure;normal gradient at TD,(0.43 psi/ft) 9961(ft)x 0.43(psi/ft)= 4283 psi 4283(psi)-(0.1(psi/ft)*9961(ft))= 3287 psi MASP from pore pressure;unknown gas sand at TD,at 9.2 ppg(0.4784 psi/ft) _ 1 9961(ft)x 0.4784(psi/ft)= 4765 psi Downhole 4765(psi)-[(2/3)*0.1(psi/ft)*9961(ft)]+[(1/3)*0.4784(psii/ft)**9A9961(ft))]= 2512 psi Drilling MASP '1/4I )]1.. ____._ _-_._._ ., Summary: 1. MASP while drilling8-1/2"hole isgovemed by pore pressure minus C-4 LC. ' 2/3 of wellbore evacuated to gas(remaining 1/3 remains 9.2 ppg drilling fluid) Page 40 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 Hileorp Alaska,L1A 30.0 Plot (NAD 27) (Governmental Sections) ,I, I /,'t/)L1421130 etc \ I _ ' Il_JJ i// `\ - --r-Ly- --- -I,/7 11t \-- f \ _ / /rMQ,Lt BML G-05RD 8HL -„ , 4 r M3 BM \ • - / `, //�`� Rt K-21 BFL \\\ 1, /1///4,4/1 //! I1/ • I 1 ADL017594 ,' _L 4_ a GnaerL ' \ ,,, ,n t r,- // cos� 1 ,,//t,,, , I/ -• Y/// 1/ I \ /II � r 2� t /, / G761 iL 258FL G1BOPN BH G01 BHL \ / -'- I 1 -- $ti• __-=-[a01RD 8HL r _7-_ / X/ / -- _ \I\ // - - ____---"----r,- -I , ,// //\ / / AI-Q7 HFR.-` l' 1 / , ^^ \1-32RD_' TPI ' \\ S009N013Wz-/';----- '' :. 5009N0,1 --------- 'riF' GRAYLING-):11.A)11-4.6'/-"' --' ,--, _-'- - ---7-- /1// 4G04RD Mu/ - M-04 BHL ---,,,,,,..„,...,,,,,..2_, rayling yam— — _ �_ lir --,7// f , —-"=:34 r.. ' _- _ ``` I o /1 ii /'T'-^^f7•G.243 at // 11/,/11 \\\\ .\- \\1`_ C •/ q %// ^�'' �'` ', `4 w'' `�\\ „ t�\,�-91- :.: '__ /1/' ADL018730`--, ,- ,, /14R4 BM' \ 5 . r 0/ 4: I / • / -- , \\\ `•1 � • / , /// / / ^-^ , o /. l1 , ,7� , \ \\ , /: S / /II 1 � \ �\ \,\�I /o;/r9 1 / W411 , ,- I I 5 \‘‘ T. / •, 9i /'a\ , / , /1 TRADING':AY i 'T \\\\ ' •••,(..: � s' '/,'' >a' ' / // 1 1, \\ `I '.:,•/,f ,,/ ,�' w. ' G-O6RD BHL / / I \9RD1 7. It,\\ Ro BtL \\ I, I/ •At-10 BHI,'' ` \ ',M-03 BHL 1 , I 61 74/\ y-„ G12IRD BHL \ G06 8HL I 11 ,i,\ \ i, fi 3M-32RD2_BHL ``., - • , I t , \ \. '';1,-----11/\, �\*1a�i°PB'Br�L\ ADL018730 I I \\ \�` I �'r' 't 1 1r \\\\ ,I I 1 11G-22BtL \\\' M-32RD2_SHL 1 I t t r i_ _L—..— Steelhead.„,r.c p° `�Gr21 BtL 1 1 \ / , .� L 1 ` \ • 11 t - I • - IIS Ir 1,1. 5 %G�3QB L fl ‘v vv • �` • -7'-S009N013W'- i \\ J/ ' 4`11 1\\\ 6”'SOO9N013W �` - /l _09?8�''� I I\?< '/ 1`11\`1 ,t s-c.C.CJ \\ \. G14ARDBHy / I 1 / 1 \i / \ ,. I , I 1 / \ \ / I . \ _, / \ ,u ` 1.G-0880 BHL`, \` r1 1 / ,' , , e1*,1 ; �y,;% Legend 1 r M2 ,IZ •1G-34 BK. / / \`\ `1 N. • M-32RD2_SHL Other Surface Hole Locator G-o4 eta. C \ fD-428tt J ,/1r • `, •X M-32RD2_TPH • Other Bottom Hole Location /I r ,/ ' 1 r 1 ,I \\ M-32RD2_BHL Well Paths / ' t I I / \ ' I , 1 / \ //' // IG-268HLI,• / \ }, - 14 0 1,000 2.000 Trading Bay Unit Feet M-32RD2 Alaska State Plane Zone 4,NAD27 A Hilcorp:11a4u.1.1.1: Map Date:6/13/2017 Page 41 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 IIiI orp:Ua,k:r.I.I.1: 31.0 Slot Diagram (As Built) (NAD 27) 29 28 SECTION LINE NOT TO SCALE(NTS) 32 SECTION CORNER (PROTRACTED) N.2500506.898' E 213654.958 994'FM.(N Sy u CENTER LEG 8.1 '-', LAT 60'49'54 939'N —ti 538'FWL(NTS) t LON 151'36'6 89514 C N 2499499 257 (n -,y�••• E.214167 458' F- �r ASP ZONE 4 NAD 27 Z 1068'FNL(NTS) L.EG 8-1 1062 FNI.!Nis: W J Q U (n 0 I- 1- - 1- 11k;Fhit.:NTS: 0 z W z z -:r',. 0 '•- 611.FWL:NTS) r _.L'•'. • i .5 470'11'.'1 INTSi • r 0 LEG A-1 STEELHEAD PLATFORM LEG B-2 • ,'�� ', (w „,.vC, ASBUILT WELL LOCATIONS �.,, r, r. SECTION 33 T9N R13W CENTER LEG A-1 LEG 8-2 LAT 60'49'54 213'N LAT.60'49'54 270"N LON 151`36'8 25TN1 LON.151'36'5 415V N.2499427.187 N.2499429.534' E:214098,135' E 214239.i3T ASP ZONE 4 NAD 27 ASP ZONE 4 NAL)27 CENTER LEG A-2 LAT 60'49'53 544'N *70LON 151'36'6 77714 N:2499357.463' "—'_,\„ 5.44'Mt(NT$y • 1' • E.214169.815' Lq• •• ASP ZONE 4 RAD 27 • • • LEG A•2 NOTES 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION ``"�44 j (EPOCH 2010)AND VERTICAL CONTROL(NAVD88)IS AN OPUS `. OFA 14 f SOLUTION FROM NGS STATIONS KENS,AC51 AND ANC2 TO p. .-""""�4._. .")S, ESTABLISH CP-1. THE ALASKA STATE PLANE COORDINATES NAD .. co: 7 Z, 83 ZONE 4 IN FEET ARE: N=2499331.366 11/1111 �'A(� *: SH '•*i E.1354193.305 i��r i V�ZClJ.:Ff1E71R... ELEV .150436(NAVD88) "'• "••' 2.SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED VALUES SCALE off �•''•1•!�_11.' 3 DATUM TRANSFORMATIONS(NAD83 ASPZ4 TO NAD27 ASPZ4) 0 '-0 (0 f I I I `.. WERE DONE USING CORPSCON SOFTWARE VERSION 6 0.1. I 1 tIt r r i HILLCORP ALASKALLC ��^ A `++..1o' s STEELHEAD PLATFORM WELLS 7 E °°"" • COOK INLET ALASKA `"""g AS BUILT SURFACE, LOCATION '9' " 1 ' NAD 27 PROXC-ra s,o t,.-,.4410.0:11.I1,040,S RA M6;TESTriG BCC.NO 1310 P r°oon :. M43s2SI.a.leT)2.».TIs PROTRACTED SEC.33 TO9N R13W &R[, CVol w.rCwA`.4 LAUCIC0C0v Ililc•ur11:tIlI LL 1.I•(. 1 a3 SEWARD MERIDIAN,ALASKA Page 42 Revision 0 June, 2017 • • M-32RD2 Drilling Procedure Rev 0 Ilik"rp:‘Ia.ka. NAD 27 Slot# Well # Northing Easting Latitude Longitude Center Leg B-1 2499499.259 214167.458 60'49' 54.939" -151°36'6.895" 1 M-26 2499505.978 214167.640 60'49' 55.006" -151°36'6.894" 2 M-32RD 2499504.406 214171.960 60°49'54.991" -151°36'6.806" 3 M-28 2499500.316 214174.375 60°49'54.951" -151°36'6.756" 4 M-27 2499495.577 214173.610 60°49'54.905" -151°36'6.769" 5 Empty 2499492.381 214170.029 60°49'54.872" -151°36'6.839" Leg B-1 6 Empty 2499492.362 214165.235 60°49'54.871" -151°36'6.936" 7 M-29A 2499495.452 214161.556 60°49'54.900" -151°36'7.012" 8 Empty 2499500.052 214160.609 60°49'54.946" -151°36'7.033" 9 M-30 2499504.087 214162.790 60°49'54.986" -151°36'6.991" 10 N/A 2499500.729 214170.099 60°49' 54.954" -151°36'6.842" 11 M-25 2499495.774 214167.855 60°49'54.905" -151°36'6.885" 12 M-31B 2499500.204 214164.607 60°49'54.948" -151°36'6.952" Center Leg 8-2 2499429.534 214239.137 60°49'54.270" -151°36'5.415" 1 M-9 2499429.705 214246.421 60°49'54.274" -151°36'5.268" 2 M-18 2499425.538 214245.127 60°49' 54.232" -151°36'5.292" 3 M-2 2499422.705 214240.766 60°49'54.203" -151°36'5.378" 4 M-21 2499423.448 214236.029 60°49'54.210" -151°36'5.474" 5 Empty 2499427.060 214232.883 60°49'54.244" -151°36'5.540" Leg B-2 6 M-6 2499431.832 214232.798 60°49' 54.291" -151°36'5.544" 7 M-7 2499435.552 214235.847 60°49'54.329" -151°36'5.484" 8 M-1 2499436.452 214240.494 60°49'54.339" -151°36'5.391" 9 M-4 2499433.752 214245.008 60°49'54.313" -151°36'5.298" 10 M-3 2499426.614 214240.677 60°49'54.242" -151°36'5.382" 11 M-5 2499429.508 214236.227 60°49' 54.269" -151°36'5.473" 12 Empty 2499432.482 214240.507 60°49' 54.300" -151°36'5.388" HILLCORP ALASKA.LLC PEvl: . - STEELHEAD PLATFORM WELLS cwTe: naav» L COOK INLET ALASKA CRAY. v iICE AS BUILT SURFACE LOCATION NAD 27 ERC E.&NQ,`\NPNNG(9ltli'.EYNG:TESTN0 P °`148 DOINA `"T""' PROTRACTED SEC.33 TO9N R13W EwL TaA1CM .W NEWACLECOCOY t!ilrorp Alaska,I.I,C <: •3 '.r 3 SEWARD MERIDIAN.ALASKA Page 43 Revision 0 June, 2017 • ! M-32RD2 Drilling Procedure Rev 0 IIihorp Alaska, 32.0 Directional Program (wp04) Page 44 Revision 0 June, 2017 Hilcorp Alaska, LLC I McArthur River Field Steelhead Plan: TBU M-32RD2 Plan: M-32RD2 .7 7" Plan: M-32RD2 WP04 Standard Proposal Report - - 12 June, 2017 HALLIBURTON Sperry Drilling Services HALLIBURTON Hilcorp Alaska,LLC • REFERENCE INFORMATION j� / l llleorp Calculation Method: Minimum Curvature Co-ordinate(N/E)Reference:Well Plan:TBU M-32RD2,True North Sperry Drifting I Error System: ISCWSA Vertical(TVD)Reference:TBU M-32 revised @ 160.O0usft Scan Method: Closest Approach 3D Measured Depth Reference:TBU M-32 revised @ 160.00usft Error Surface: Elliptical Conic Warning Method: Error Ratio Calculation Method: Minimum Curvature Project: McArthur River Field SECTION DETAILS Site: Stee/head Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Well: Plan: TBU M-32RD2 1 7300.00 37.72 17.78 6912.57 1293.85 481.62 0.00 0.00 1371.79 Wellbore: Plan:M-32RD2 2 7318.00 38.82 20.88 6926.70 1304.37 485.31 12.30 60.00 1382.84 3 7368.00 38.82 20.88 6965.65 1333.66 496.49 0.00 0.00 1414.02 Design: M-32RD2 WP04 4 7828.17 64.00 6.00 7251.32 1680.85 570.96 6.00 -29.86 1757.36 5 9078.17 64.00 6.00 7799.28 2798.19 688,39 0,00 0.00 2807.02 6 9120.06 61.55 5.15 7818.44 2835.26 692.01 6.12 -163.05 2841.72 7 9259,52 61.55 5.15 7884.88 2957.38 703.02 0.00 0.00 2955.62 , 8 11281.76 67.50 180.00 9498.05 2866.87 851.23 6.37 173.89 2941.92 M-32RD2 WP04 TOPT Tgt 9 11481.76 67.50 180.00 9574.59 2682.10 851.23 0.00 0.00 2777.12 DDI = 6.394 10 11623.43 76.00 180.00 9618.91 2547.68 851.23 6.00 0.00 2657.23 11 11973.43 76.00 180.00 9703.58 2208.08 851.23 0.00 0.00 2354.34 12 12332.06 82.20 201.00 9772.11 1864.17 786.80 6.00 75.46 2018.47 13 13722.41 82.20 201.00 9960.80 578.18 293.16 0.00 0.00 648.26 M-32RD2 WP02 WF_3 Tgt3 CASING DETAILS _ WELL DETAILS: Plan:TBU M-32RD2 TVD TVDSS MD Size Water Depth: 187.00 9960.80 9800.80 13722.41 8 1/2"x 7" -NI-S +EI-W Northing Easting Latittude Longitude 0.00 0.00 2499504.41 214171.96 60°49'54.991 N 151°36'6.806 W 5950- - 0h00 FORMATION TOP DETAILS Start Dir 12.3°/100':7300'MD,6912.57'TVD:60°RT TF 6300- TVDPath TVDssPath MDPath Formation 8651.10 8491.10 10203.41 COAL39 - End Dir :7318'MD,6926.7'TVD 9043.60 8883.60 10609.35 H1X FW 9088.78 8928.78 10659.92 HTKE-FW - 000 Start Dir 6°/100':7368'MD,6965.65'TVD 9123.11 8963.11 10699.37 HK2T 6650- 1 -- 9251.93 9091.93 10858.23 HK3T -'� 9322.01 9162.01 10955.33 HK4T End Dir :7828.17'MD,7251.32'TVD 9454.52 9294.52 11181.27 HK5T - - 9544.16 9384.16 11402.25 HK6T 9658.62 9498.62 11787.57 WFT 7000- 1h° 9782.11 9622.11 12405.76 WF 2 '5°0 oo° Start Dir 6.12°/100':9078.17'MD,7799.28'TVD 7350- p ° 'ID , $° °oo End Dir :9120.06'MD,7818.44'TVD 7700-- 00 cb,' Start Dir 6.37°/100':9259.52'MD,7884.88'TVD . '8 94, O 8050- - o SURVEY PROGRAM °O° - - Date:2017-06-08T00:00:00 Validated:Yes Version: n CD 7 Depth From Depth To Survey/Plan Tool o 8400 24.75 926.75 BHI RGMS(M-32 PB1) CB-Gyro-MS 1Cp00 • __ 986.75 1272.75 BHI GSS(M-32 P81) CB-Gyro-SS COAL39 1385.75 7300.00 M-32 PB1 MWD MWD 7300.00 7650.00 M-32RD2 WP04 MWD Interp Azi+sag O 8750 7650.00 13722.41 M-32RD2 WP04 MWD+SC+sag O �� ~ o, • - M-32 PB - 105 0co 0 H 0 0 0 .- - M-32RD2 WP04 TOPT Tgt H1X_ - so : M-32RD PB1 9100- M-32RD2 WP04 BOPT Tgt HK2T HTKE-FW_ ori o= o HK3T o o 0 to o HK5T HK4T S' N - M-32RD2 WP02 WFT Tgt1 HK6T yo M-32 PB � . 9450- p M-32RD2 WP02 WF 2 T9 t2 WFT - ----- °° M-32RD2 WP02 WF 3 Tgt3 WF - End Dir :11281.76'MD,9498.05'TVD ^^h M-32RD ` M-32RD2 WP04 - on -_ 9800- 8 1/2"x 7" a Start Dir 6°/100':11481.76'MD,9574.59'TVD °o° WF_3 _ (.7o- o - ----0 End Dir :11623.43'MD,9618.91'TVD ^ry 0 - 0 0 M-32 10150- ro o Start Dir 6°/100':11973.43'MD,9703.58'TVD M-32 PB3 - Total Depth:13722.41'MD,9960.8'TVD End Dir :12332.06'MD,9772.11'TVD 10500-- - - 111111111111111111 [ m IIIFIIIIIIFIIIIIIIIIIIIIIIIIIIIIIIIIIIIIiImIIIIIIII1 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 Vertical Section at 26.89°(700 usft/in) • HALLIBURTON Project: McArthur River Field WELL DETAILS: Plan:TBU M-32RD2 Site: Steelhead Water Depth: 187.00 Sporry orlu r Well: Plan:TBU M-32RD2 +NI-S +E/-W Northing Easting Latittude Longitude Wellbore: Plan: M-32RD2 0.00 0.00 2499504.41 214171.96 60°49'54991 N 151°36'6.806 W Hilcor�� Plan: M-32RD2 WP04 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Plan:TBU M-32RD2,True North Vertical(TVD)Reference:TBU M-32 revised(8 160.O0usft Measured Depth Reference:TBU M-32 revised 160.00usft 4050— CASING DETAILS Calculation Method:Minimum Curvature 1.. TVD TVDSS MD Size Name 9960.80 9800.80 13722.41 7 8 1/2"x 7" 95 M72�PB7 3825- - 3600- - 1250 9r5p b�50 _3432082 89 3375— 9000 q2 82 , /900 9250 3150— o00 - Start Dir 6.37°/100':9259.52'MD,7884.88TVD 8000 / 9000 \' M-32RD2 •t OPT T8t 2925— End Dir:9120.06'MD,7818.44'TVD / pp 2 __ --`1 3 Pe! Start Dir 6.12°/100':9078.17 MD,7799.28TVD- 0 - \ M-3211D2 WP04 BOPTTBt 2700— 7750 ' #= ts0 Start Dir 6°/100':11481.76 MD,9574.59TVD • •500 2475- - WP02 WFT Tgtl C _ 0250 2250- 0 7500 Start Dir 6°/100':11973.43'MD,9703.58TVD 80 r 2025- 7 - 9750 C _ 775r _-M-32RD2 WP02 WF_2 Tgt2 - c 1800- - End Dir:12332.06'MD,9772.11'TVD 75ir - 7050 1575— _ Start Dir 6°/100':7368'MD,6965.65TVD 725r End Dir:7318'MD,6936:7 TVD 7000 1350— ;` 70,7 Start Dir 12.3°/100':7300'MD,6912.57TVD:60°RT TF 6750 1125— 6500 900- - LJ32R0 6250 04 675— M-32RD2 WP02 WF_3 Tgt3 6000 j 8"1/2"x 7'_--- Total Depth:13722.41'MD,9960.8'TVD 450— 57,-0 550o 225— 5250 A 5000 -675 -450 -225 0 225 450 675 900 1125 1350 1575 1800 2025 2250 West(-)/East(+)(450 usft/in) II I Halliburton HALLIBIJRTON Standard Proposal Report . n Sperry EDM-NORTH US+CANADA a. *a Well Plan:TBU M-32RD2 r Hilcorp Alaska,LLC ®' TBU M-32 revised @ 160.00usft z McArthur River Field ® TBU M-32 revised @ 160.00usfl Steelhead ;. "True ;Ran:TBU M-32RD2 Minimum Curvature Plan:M-32RD2 Design ',311,.:, ...':',Ei M-32RD2 WP04 5ZiligiWgielikiiitaitaii1:".f:Tikkilktbe ,. -. Project McArthur River Field 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 Site Steelhead Site Position: Northing: 2,499.453.95usft Latitude: 60°49'54.473 N From: Map Easting: 214,083.78 usft Longitude: 151°36'8.560 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.40 ° Well Plan:TBU M-32RD2 Well Position +N/-S 0.00 usft Northing: 2,499,504.41 usft Latitude: 60°49'54.991 N +El-W 0.00 usft Easting: 214,171.96 usft Longitude: 151°36'6.806 W Position Uncertainty 0.00 usft Wellhead Elevation: 160.00 usft Water Depth: 187.00 usft We II bore Plan:M-32RD2 . Magnetics AIi., Model Narver J ±:e . - r a , r, d's BGGM2017 6/8/2017 16.05 73.71 55,385 Design M-32RD2 WP04 3 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,300.00 Vertical Section . s a +E/-W usft 0.00 0.00 0.00 26.89 Plan Sections Measured Vertical TVD Y ® . :Li t ,r, -- Depth Inclination Azimuth Depth Systema + +E(-W Rate Y (usft) (a) (a) (usft) usft �' (usft (usft) ( i (°/100usft) €3 '` .ilk 7,300.00 37.72 17.78 6,912.57 6,752.57 1,293.85 481.62 0.00 0.00 0.00 0.00 7,318.00 38.82 20.88 6,926.70 6,766.70 1,304.37 485.31 12.30 6.15 16.99 60.00 7,368.00 38.82 20.88 6,965.65 6,805.65 1,333.66 496.49 0.00 0.00 0.00 0.00 7,828.17 64.00 6.00 7,251.32 7,091.32 1,680.85 570.96 6.00 5.47 -3.23 -29.86 9,078.17 64.00 6.00 7,799.28 7,639.28 2,798.19 688.39 0.00 0.00 0.00 0.00 9,120.06 61.55 5.15 7,818.44 7,658.44 2,835.26 692.01 6.12 -5.85 -2.03 -163.05 9,259.52 61.55 5.15 7,884.88 7,724.88 2,957.38 703.02 0.00 0.00 0.00 0.00 11,281.76 67.50 180.00 9,498.05 9,338.05 2,866.87 851.23 6.37 0.29 8.65 173.89 11,481.76 67.50 180.00 9,574.59 9,414.59 2,682.10 851.23 0.00 0.00 0.00 0.00 11,623.43 76.00 180.00 9,618.91 9,458.91 2,547.68 851.23 6.00 6.00 0.00 0.00 11,973.43 76.00 180.00 9,703.58 9,543.58 2,208.08 851.23 0.00 0.00 0.00 0.00 I 12,332.06 82.20 201.00 9,772.11 9,612.11 1,864.17 786.80 6.00 1.73 5.86 75.46 13,722.41 82.20 201.00 9,960.80 9,800.80 578.18 293.16 0.00 0.00 0.00 0.00 6/12/2017 2:14:24PM Page 2 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:TBU M-32RD2 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-32 revised @ 160.00usft Project: McArthur River Field MD Reference:' -'7''''''''',.''Z', TBU M-32 revised @ 160.00usft Site: Steelhead North Reference: True Well: Plan:TBU M-32RD2 Survey Calculation Method Minimum Curvature Wellbore: Plan:M-32RD2 Design: M-32RD2 WP04 y,: .. Planned Survey Measured ` r.'::14'1,-..-.'= . ' Vertical ' .� . .. Map Map 7-177,,11,.1-:,„..z.2- '. Depth Inclination Azimuth Depth TVDss, , +N/-S +El-W Northing r Easting DLS Vert Section (usft) (°) (°) (usft) usft 'I' (usft) (usft) (usft) ,: (usft) -160.00 sl 0.00 0.00 0.00 0.00 -160.00 0.00 0.00 2,499,504.41 214,171.96 0.00 0.00 24.75 0.30 192.02 24.75 -135.25 -0.06 -0.01 2,499,504.34 214,171.94 1.21 -0.06 49.75 0.25 234.87 49.75 -110.25 -0.16 -0.07 2,499,504.25 214,171.88 0.82 -0.17 74.75 0.10 10.92 74.75 -85.25 -0.17 -0.11 2,499,504.24 214,171.84 1.32 -0.20 99.75 0.20 100.13 99.75 -60.25 -0.15 -0.07 2,499,504.25 214,171.89 0.89 -0.17 124.75 0.15 185.75 124.75 -35.25 -0.20 -0.03 2,499,504.21 214,171.93 0.96 -0.19 149.75 0.08 142.25 149.75 -10.25 -0.24 -0.02 2,499,504.16 214,171.94 0.43 -0.22 174.75 0.37 138.87 174.75 14.75 -0.32 0.05 2,499,504.09 214,172.00 1.16 -0.26 199.75 0.18 149.28 199.75 39.75 -0.41 0.12 2,499,503.99 214,172.07 0.78 -0.31 224.75 0.20 155.87 224.75 64.75 -0.48 0.16 2,499,503.92 214,172.10 0.12 -0.36 249.75 0.17 146.28 249.75 89.75 -0.55 0.20 2,499,503.85 214,172.14 0.17 -0.41 274.75 0.17 183.75 274.75 114.75 -0.62 0.21 2,499,503.78 214,172.16 0.44 -0.46 299.75 0.25 189.25 299.75 139.75 -0.71 0.20 2,499,503.69 214,172.14 0.33 -0.55 • 324.75 0.47 176.25 324.75 164.75 -0.87 0.20 2,499,503.53 214,172.14 0.93 -0.69 349.75 0.82 151.30 349.75 189.75 -1.13 0.29 2,499,503.27 214,172.23 1.76 -0.87 374.75 1.22 145.22 374.74 214.74 -1.50 0.53 2,499,502.89 214,172.45 1.66 -1.10 399.75 1.35 156.33 399.74 239.74 -1.99 0.80 2,499,502.39 214,172.71 1.12 -1.42 424.75 1.47 159.83 424.73 264.73 -2.56 1.03 2,499,501.82 214,172.93 0.59 -1.82 449.75 1.48 172.35 449.72 289.72 -3.18 1.18 2,499,501.19 214,173.06 1.29 -2.31 474.75 1.53 171.27 474.71 314.71 -3.83 1.28 2,499,500.54 214,173.14 0.23 -2.84 481.75 1.55 170.08 481.71 321.71 -4.02 1.31 2,499,500.36 214,173.17 0.54 -2.99 499.75 0.68 171.60 499.71 339.71 -4.37 1.36 2,499,500.01 214,173.22 4.84 -3.28 524.75 0.60 161.45 524.70 364.70 -4.64 1.43 2,499,499.74 214,173.27 0.55 -3.49 549.75 0.58 160.33 549.70 389.70 -4.88 1.51 2,499,499.49 214,173.35 0.09 -3.67 574.75 0.57 150.35 574.70 414.70 -5.11 1.62 2,499,499.26 214,173.45 0.40 -3.82 599.75 0.43 151.67 599.70 439.70 -5.30 1.72 2,499,499.07 214,173.55 0.56 -3.95 624.75 0.43 154.23 624.70 464.70 -5.46 1.81 2,499,498.90 214,173.63 0.08 -4.06 649.75 0.55 164.78 649.70 489.70 -5.66 1.88 2,499,498.70 214,173.70 0.60 -4.20 674.75 0.68 164.00 674.70 514.70 -5.92 1.95 2,499,498.44 214,173.77 0.52 -4.40 699.75 1.00 160.60 699.69 539.69 -6.27 2.07 2,499,498.09 214,173.87 1.29 -4.66 724.75 1.10 159.95 724.69 564.69 -6.70 2.22 2,499,497.65 214,174.02 0.40 -4.97 749.75 1.05 147.13 749.69 589.69 -7.12 2.43 2,499,497.23 214,174.21 0.98 -5.25 774.75 0.92 143.32 774.68 614.68 -7.47 2.67 2,499,496.87 214,174.45 0.58 -5.46 799.75 0.93 154.25 799.68 639.68 -7.82 2.88 2,499,496.52 214,174.65 0.71 -5.67 824.75 1.08 150.85 824.68 664.68 -8.21 3.08 2,499,496.13 214,174.84 0.65 -5.93 849.75 0.72 149.18 849.67 689.67 -8.55 3.28 2,499,495.78 214,175.03 1.44 -6.14 874.75 0.85 156.75 874.67 714.67 -8.85 3.43 2,499,495.47 214,175.17 0.66 -6.34 899.75 0.87 153.33 899.67 739.67 -9.19 3.59 2,499,495.13 214,175.32 0.22 -6.58 926.75 0.57 170.00 926.66 766.66 -9.51 3.70 2,499,494.81 214,175.43 1.34 -6.80 986.75 0.75 125.00 986.66 826.66 -10.03 4.08 2,499,494.28 214,175.79 0.89 -7.10 1,081.75 1.25 210.00 1,081.65 921.65 -11.28 4.07 2,499,493.03 214,175.75 1.47 -8.22 1,177.75 2.00 175.00 1,177.61 1,017.61 -13.86 3.69 2,499,490.46 214,175.31 1.26 -10.69 1,272.75 3.00 185.00 1,272.52 1,112.52 -17.98 3.62 2,499,486.34 214,175.14 1.14 -14.40 1,346.75 2.74 183.94 1,346.43 1,186.43 -21.68 3.33 2,499,482.65 214,174.76 0.36 -17.83 16" 6/12/2017 2:14:24PM Page 3 COMPASS 5000.1 Build 81 • 0 Halliburton I-IALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: - Well Plan:TBU M-32RD2 Company: ''-:-V Hilcorp Alaska,LLC TVD Reference:, , oglor TBU M-32 revised @ 160.00usft Project: McArthur River Field MD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead North Reference: True Well: Plan:TBU M-32RD2 Survey Calculation Method: iiillit Minimum Curvature Wellbore: Plan:M-32RD2 Design: M-32RD2 WP04 , Planned Survey .,. , , ',''',-24- ; `xkt iMeasured „', , , Vertical a , , _ '„,r Map . Map Depth Inclination Azimuth Depth TVDss +N/.-S +E/-W Northing Fasting DLS (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 1,225.39 . .. 1,385.75 2.60 183.30 1,385.39 1,225.39 -23.49 3.21 2,499,480.85 214,174.60 0.36 -19.50 1,476.75 2.40 189.00 1,476.30 1,316.30 -27.43 2.80 2,499,476.91 214,174.09 0.35 -23.20 1,567.75 1.40 192.50 1,567.25 1,407.25 -30.40 2.26 2,499,473.96 214,173.48 1.11 -26.09 1,661.75 0.50 119.30 1,661.24 1,501.24 -31.72 2.37 2,499,472.64 214,173.55 1.43 -27.22 1,849.75 0.20 327.80 1,849.24 1,689.24 -31.84 2.91 2,499,472.50 214,174.09 0.36 -27.09 2,035.75 0.20 346.50 2,035.23 1,875.23 -31.25 2.66 2,499,473.10 214,173.86 0.03 -26.67 2,227.75 0.40 114.80 2,227.23 2,067.23 -31.21 3.19 2,499,473.13 214,174.39 0.28 -26.39 2,406.75 0.40 255.10 2,406.23 2,246.23 -31.63 3.15 2,499,472.71 214,174.34 0.42 -26.79 2,597.75 0.30 107.40 2,597.23 2,437.23 -31.95 2.99 2,499,472.39 214,174.17 0.35 -27.15 2,693.75 0.10 94.00 2,693.23 2,533.23 -32.03 3.31 2,499,472.30 214,174.49 0.21 -27.07 2,883.75 0.30 44.10 2,883.23 2,723.23 -31.69 3.82 2,499,472.63 214,175.01 0.13 -26.54 3,076.75 0.20 247.70 3,076.23 2,916.23 -31.45 3.86 2,499,472.87 214,175.05 0.25 -26.31 3,262.75 0.20 196.00 3,262.23 3,102.23 -31.89 3.47 2,499,472.44 214,174.65 0.09 -26.87 3,450.75 0.20 226.90 3,450.23 3,290.23 -32.43 3.14 2,499,471.91 214,174.31 0.06 -27.50 3,635.75 0.30 209.70 3,635.22 3,475.22 -33.07 2.67 2,499,471.28 214,173.82 0.07 -28.29 3,734.75 0.40 26.90 3,734.22 3,574.22 -32.99 2.69 2,499,471.36 214,173.85 0.71 -28.20 3,766.75 0.73 24.71 3,766.22 3,606.22 -32.70 2.83 2,499,471.65 214,173.99 1.04 -27.89 13 3/8" 3,792.75 1.00 24.00 3,792.22 3,632.22 -32.34 2.99 2,499,472.00 214,174.16 1.04 -27.49 3,922.75 3.40 18.50 3,922.11 3,762.11 -27.65 4.68 2,499,476.65 214,175.96 1.85 -22.55 4,016.75 5.00 20.20 4,015.86 3,855.86 -21.16 6.97 2,499,483.08 214,178.42 1.71 -15.72 4,113.75 6.00 22.00 4,112.41 3,952.41 -12.49 10.33 2,499,491.66 214,181.99 1.05 -6.47 4,208.75 7.10 26.50 4,206.79 4,046.79 -2.64 14.81 2,499,501.41 214,186.70 1.28 4.35 4,302.75 8.30 26.20 4,299.94 4,139.94 8.65 20.40 2,499,512.56 214,192.57 1.28 16.94 4,396.75 10.00 22.70 4,392.74 4,232.74 22.27 26.55 2,499,526.02 214,199.04 1.90 31.87 4,488.75 11.70 22.00 4,483.09 4,323.09 38.29 33.12 2,499,541.87 214,206.01 1.85 49.13 4,583.75 13.00 19.20 4,575.89 4,415.89 57.31 40.25 2,499,560.72 214,213.59 1.51 69.32 4,678.75 13.80 19.90 4,668.31 4,508.31 78.06 47.62 2,499,581.27 214,221.47 0.86 91.15 4,773.75 14.80 20.90 4,760.36 4,600.36 100.04 55.80 2,499,603.06 214,230.19 1.08 114.47 4,867.75 15.60 20.60 4,851.07 4,691.07 123.09 64.53 2,499,625.89 214,239.48 0.86 138.97 4,960.75 16.80 20.20 4,940.38 4,780.38 147.41 73.57 2,499,649.98 214,249.11 1.30 164.75 5,054.75 17.80 20.90 5,030.13 4,870.13 173.58 83.39 2,499,675.90 214,259.56 1.09 192.53 5,150.75 18:60 20.60 5,121.32 4,961.32 201.62 94.01 2,499,703.67 214,270.87 0.84 222.34 5,244.75 20.00 20.20 5,210.04 5,050.04 230.74 104.84 2,499,732.52 214,282.40 1.50 253.21 5,337.75 21.30 20.60 5,297.06 5,137.06 261.48 116.27 2,499,762.97 214,294.58 1.41 285.80 5,430.75 22.90 19.50 5,383.22 5,223.22 294.35 128.26 2,499,795.54 214,307.36 1.78 320.53 5,525.75 24.30 18.80 5,470.28 5,310.28 330.28 140.73 2,499,831.15 214,320.71 1.50 358.22 5,617.75 25.90 19.50 5,553.59 5,393.59 367.14 153.53 2,499,867.69 214,334.41 1.77 396.89 5,711.75 27.40 20.20 5,637.60 5,477.60 406.80 167.86 2,499,906.98 214,349.70 1.63 438.73 5,805.75 28.90 20.60 5,720.48 5,560.48 448.36 183.32 2,499,948.15 214,366.17 1.61 482.80 5,901.75 30.00 20.60 5,804.07 5,644.07 492.54 199.92 2,499,991.92 214,383.85 1.15 529.71 5,990.75 31.60 19.50 5,880.52 5,720.52 535.35 215.54 2,500,034.33 214,400.50 1.91 574.95 6,082.75 33.00 19.20 5,958.28 5,798.28 581.73 231.82 2,500,080.30 214,417.91 1.53 623.69 6,177.75 34.80 18.80 6,037.13 5,877.13 631.83 249.07 2,500,129.97 214,436.38 1.91 676.17 6,271.75 36.50 19.90 6,113.51 5,953.51 683.52 267.23 2,500,181.19 214,455.80 1.93 730.48 6/12/2017 2:14:24PM Page 4 COMPASS 5000.1 Build 81 0 • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:TBU M-32RD2 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-32 revised @ 160.00usft ., Project: McArthur River Field MD Reference:". TBU M-32 revised @ 160.00usft Site: =.,i.‘.4 Steelhead North Reference: True Well: litit,61 Plan:TBU M-32RD2 Survey Calculation Method: AV, Minimum Curvature Wellbore:' Plan:M-32RD2 Design: f'aiiiit4i M-32RD2 WP04 Planned Survey a a Measured '' Vertical Map Map _T " Depth P Inclination Azimuth Depth TVDss +/4/-s +E/-W Northing h Easn9c. DLS Section Vert Sti (usft) (°) (°) (usft) usft (usft) (usft) (usft) =r (usft) 6,027.49 6,364.75 38.10 19.90 6,187.49 6,027.49 736.51 286.41 2,500,233.70 214,476.27 1.72 786.42 6,457.75 39.50 20.20 6,259.96 6,099.96 791.25 306.39 2,500,287.93 214,497.58 1.52 844.28 6,549.75 39.70 19.20 6,330.85 6,170.85 846.46 326.16 2,500,342.64 214,518.69 0.73 902.46 6,614.75 39.60 19.90 6,380.90 6,220.90 885.54 340.04 2,500,381.38 214,533.51 0.70 943.59 6,708.75 39.80 20.60 6,453.22 6,293.22 941.87 360.82 2,500,437.18 214,555.67 0.52 1,003.23 6,801.75 39.50 19.90 6,524.83 6,364.83 997.55 381.36 2,500,492.34 214,577.56 0.58 1,062.18 6,896.75 39.60 19.50 6,598.08 6,438.08 1,054.50 401.75 2,500,548.77 214,599.33 0.29 1,122.19 6,988.75 39.60 19.90 6,668.97 6,508.97 1,109.71 421.52 2,500,603.49 214,620.44 0.28 1,180.38 7,082.75 38.90 18.10 6,741.76 6,581.76 1,165.93 440.89 2,500,659.22 214,641.18 1.42 1,239.28 7,177.75 38.10 17.40 6,816.11 6,656.11 1,222.26 458.92 2,500,715.09 214,660.58 0.96 1,297.67 7,272.75 37.80 17.70 6,891.02 6,731.02 1,277.96 476.54 2,500,770.34 214,679.55 0.37 1,355.32 7,300.00 37.72 17.78 6,912.57 6,752.57 1,293.85 481.62 2,500,786.10 214,685.02 0.36 1,371.79 Start Dir 12.3°/100':7300'MD,6912.577VD:60°RT TF 7,318.00 38.82 20.88 6,926.70 6,766.70 1,304.37 485.31 2,500,796.53 214,688.97 12.30 1,382.84 End Dir :7318'MD,6926.7'TVD 7,368.00 38.82 20.88 6,965.65 6,805.65 1,333.66 496.49 2,500,825.54 214,700.85 0.00 1,414.02 Start Dir 6°/100':7368'MD,6965.65'TVD 7,400.00 40.50 19.41 6,990.28 6,830.28 1,352.83 503.51 2,500,844.53 214,708.35 6.00 1,434.30 7,450.00 43.15 17.30 7,027.54 6,867.54 1,384.48 513.99 2,500,875.91 214,719.60 6.00 1,467.26 7,500.00 45.84 15.39 7,063.21 6,903.21 1,418.10 523.84 2,500,909.29 214,730.26 6.00 1,501.70 7,550.00 48.55 13.65 7,097.18 6,937.18 1,453.61 533.02 2,500,944.56 214,740.31 6.00 1,537.52 7,600.00 51.29 12.05 7,129.37 6,969.37 1,490.90 541.52 2,500,981.64 214,749.71 6.00 1,574.63 7,650.00 54.05 10.57 7,159.69 6,999.69 1,529.89 549.30 2,501,020.42 214,758.44 6.00 1,612.92 7,700.00 56.82 9.18 7,188.06 7,028.06 1,570.45 556.35 2,501,060.79 214,766.48 6.00 1,652.28 7,750.00 59.61 7.89 7,214.39 7,054.39 1,612.47 562.65 2,501,102.65 214,773.81 6.00 1,692.62 7,800.00 62.42 6.66 7,238.62 7,078.62 1,655.86 568.18 2,501,145.89 214,780.39 6.00 1,733.81 7,828.17 64.00 6.00 7,251.32 7,091.32 1,680.85 570.96 2,501,170.80 214,783.78 6.00 1,757.35 End Dir :7828.17'MD,7251.32'TVD 7,900.00 64.00 6.00 7,282.80 7,122.80 1,745.05 577.70 2,501,234.82 214,792.09 0.00 1,817.67 8,000.00 64.00 6.00 7,326.64 7,166.64 1,834.44 587.10 2,501,323.95 214,803.66 0.00 1,901.65 8,100.00 64.00 6.00 7,370.48 7,210.48 1,923.83 596.49 2,501,413.08 214,815.24 0.00 1,985.62 8,200.00 64.00 6.00 7,414.31 7,254.31 2,013.21 605.89 2,501,502.22 214,826.81 0.00 2,069.59 8,300.00 64.00 6.00 7,458.15 7,298.15 2,102.60 615.28 2,501,591.35 214,838.39 0.00 2,153.56 8,400.00 64.00 6.00 7,501.99 7,341.99 2,191.99 624.68 2,501,680.48 214,849.96 0.00 2,237.54 8,500.00 64.00 6.00 7,545.83 7,385.83 2,281.38 634.07 2,501,769.61 214,861.53 0.00 2,321.51 8,600.00 64.00 6.00 7,589.66 7,429.66 2,370.76 643.47 2,501,858.74 214,873.11 0.00 2,405.48 8,700.00 64.00 6.00 7,633.50 7,473.50 2,460.15 652.86 2,501,947.87 214,884.68 0.00 2,489.46 8,800.00 64.00 6.00 7,677.34 7,517.34 2,549.54 662.26 2,502,037.00 214,896.26 0.00 2,573.43 8,900.00 64.00 6.00 7,721.17 7,561.17 2,638.92 671.65 2,502,126.13 214,907.83 0.00 2,657.40 9,000.00 64.00 6.00 7,765.01 7,605.01 2,728.31 681.05 2,502,215.26 214,919.41 0.00 2,741.38 9,078.17 64.00 6.00 7,799.28 7,639.28 2,798.18 688.39 2,502,284.93 214,928.45 0.00 2,807.02 Start Dir 6.12°/100':9078.17'MD,7799.28'TVD 9,100.00 62.72 5.56 7,809.07 7,649.07 2,817.60 690.36 2,502,304.29 214,930.89 6.12 2,825.22 ' 9,120.06 61.55 5.15 7,818.44 7,658.44 2,835.25 692.01 2,502,321.90 214,932.98 6.12 2,841.72 End Dir :9120.06'MD,7818.44'TVD 6/12/2017 2:14:24PM Page 5 COMPASS 5000.1 Build 81 • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: A, Well Plan:TBU M-32RD2 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-32 revised @ 160.00usft Project: a McArthur River Field MD Reference: TBU M-32 revised @ 160.00usft Site: Steelhead North Reference: True Well: Plan:TBU M-32RD2 Survey Calculation Method: Minimum Curvature Wellbore. Plan:M-32RD2 Design: i M-32RD2 WP04 Planned Survey Measured Vertical - '7'; Map Map Vkr Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing k Easting ;'£ DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 7,696.52 9,200.00 61.55 5.15 7,856.52 7,696.52 2,905.26 698.32 2,502,391.73 214,941.00 0.00 2,907.01 9,259.52 61.55 5.15 7,884.88 7,724.88 2,957.38 703.02 2,502,443.72 214,946.96 0.00 2,955.62 Start Dir 6.370/100':9259.52'MD,7884.88'TVD 9,300.00 58.99 5.47 7,904.95 7,744.95 2,992.37 706.27 2,502,478.63 214,951.07 6.37 2,988.30 9,350.00 55.82 5.89 7,931.89 7,771.89 3,034.29 710.44 2,502,520.42 214,956.26 6.37 3,027.57 9,400.00 52.66 6.34 7,961.10 7,801.10 3,074.62 714.76 2,502,560.64 214,961.56 6.37 3,065.50 9,450.00 49.50 6.84 7,992.51 7,832.51 3,113.26 719.22 2,502,599.16 214,966.96 6.37 3,101.98 9,500.00 46.34 7.38 8,026.02 7,866.02 3,150.08 723.80 2,502,635.86 214,972.45 6.37 3,136.89 9,550.00 43.18 7.98 8,061.52 7,901.52 3,184.97 728.50 2,502,670.62 214,977.99 6.37 3,170.13 9,600.00 40.03 8.66 8,098.90 7,938.90 3,217.81 733.30 2,502,703.34 214,983.59 6.37 3,201.60 9,650.00 36.88 9.43 8,138.05 7,978.05 3,248.52 738.18 2,502,733.91 214,989.22 6.37 3,231.19 9,700.00 33.74 10.32 8,178.85 8,018.85 3,276.98 743.12 2,502,762.25 214,994.86 6.37 3,258.81 9,750.00 30.60 11.38 8,221.17 8,061.17 3,303.13 748.12 2,502,788.26 215,000.49 6.37 3,284.39 9,800.00 27.48 12.64 8,264.88 8,104.88 3,326.86 753.16 2,502,811.87 215,006.11 6.37 3,307.84 9,850.00 24.37 14.21 8,309.84 8,149.84 3,348.12 758.22 2,502,833.00 215,011.68 6.37 3,329.09 9,900.00 21.28 16.20 8,355.93 8,195.93 3,366.84 763.28 2,502,851.58 215,017.20 6.37 3,348.07 9,950.00 18.22 18.83 8,402.98 8,242.98 3,382.95 768.33 2,502,867.57 215,022.65 6.37 3,364.73 10,000.00 15.21 22.46 8,450.87 8,290.87 3,396.41 773.36 2,502,880.90 215,028.00 6.37 3,379.00 10,050.00 12.28 27.81 8,499.43 8,339.43 3,407.18 778.35 2,502,891.54 215,033.25 6.37 3,390.86 10,100.00 9.52 36.30 8,548.53 8,388.53 3,415.22 783.28 2,502,899.46 215,038.38 6.37 3,400.26 10,150.00 7.13 50.97 8,598.00 8,438.00 3,420.50 788.14 2,502,904.63 215,043.36 6.37 3,407.18 10,200.00 5.58 76.52 8,647.70 8,487.70 3,423.02 792.91 2,502,907.03 215,048.20 6.37 3,411.58 10,203.41 5.52 78.69 8,651.10 8,491.10 3,423.10 793.24 2,502,907.09 215,048.52 6.37 3,411.79 COAL39 10,250.00 5.62 109.60 8,697.48 8,537.48 3,422.77 797.59 2,502,906.66 215,052.86 6.37 3,413.47 10,300.00 7.24 134.50 8,747.17 8,587.17 3,419.74 802.14 2,502,903.52 215,057.34 6.37 3,412.83 10,350.00 9.66 148.73 8,796.63 8,636.63 3,413.94 806.57 2,502,897.62 215,061.63 6.37 3,409.66 10,400.00 12.43 157.00 8,845.70 8,685.70 3,405.40 810.85 2,502,888.97 215,065.70 6.37 3,403.98 10,450.00 15.36 162.23 8,894.23 8,734.23 3,394.13 814.98 2,502,877.61 215,069.55 6.37 3,395.79 10,500.00 18.38 165.80 8,942.08 8,782.08 3,380.18 818.93 2,502,863.56 215,073.16 6.37 3,385.14 10,550.00 21.44 168.38 8,989.09 8,829.09 3,363.59 822.71 2,502,846.88 215,076.53 6.37 3,372.05 10,600.00 24.53 170.35 9,035.11 8,875.11 3,344.40 826.29 2,502,827.61 215,079.64 6.37 3,356.55 10,609.35 25.11 170.66 9,043.60 8,883.60 3,340.53 826.94 2,502,823.73 215,080.20 6.37 3,353.39 H1X_FW 10,650.00 27.64 171.89 9,080.01 8,920.01 3,322.68 829.67 2,502,805.82 215,082.49 6.37 3,338.71 10,659.92 28.26 172.16 9,088.78 8,928.78 3,318.07 830.31 2,502,801.20 215,083.02 6.37 3,334.89 HTKE-FW 10,699.37 30.73 173.13 9,123.11 8,963.11 3,298.82 832.79 2,502,781.88 215,085.03 6.37 3,318.84 HK2T 10,700.00 30.77 173.15 9,123.65 8,963.65 3,298.49 832.83 2,502,781.56 215,085.06 6.37 3,318.57 10,750.00 33.90 174.19 9,165.89 9,005.89 3,271.92 835.77 2,502,754.92 215,087.35 6.37 3,296.19 10,800.00 37.05 175.08 9,206.61 9,046.61 3,243.03 838.47 2,502,725.98 215,089.35 6.37 3,271.65 10,850.00 40.19 175.84 9,245.67 9,085.67 3,211.93 840.93 2,502,694.82 215,091.05 6.37 3,245.02 10,858.23 40.71 175.96 9,251.93 9,091.93 3,206.60 841.32 2,502,689.49 215,091.30 6.37 3,240.44 HK3T 6/12/2017 2:14:24PM Page 6 COMPASS 5000.1 Build 81 1110 • Halliburton FlALLIBURTON Standard Proposal Report Database Sperry EDM-NORTHUS+CANADA - Well Plan:TBU M-32RD2 H Company': HilcorpAlaska,LLC ® 'TBU M-32 revised 160.00usft ` p Y•4... : @ Project: .i'McArthur River Field ® TBU M-32 revised @ 160.00usft Site: s Steelhead = True Well: Plan:TBU M-32RD2 Minimum Curvature Wellbore;, Plan:M-32RD2t" Design: .,,, i M-32RD2 WP04 : Planned Survey Measured ,., ,..... Vertical !! L! !E;w , .Inclination Azimuth th Eastmg DLS 4 fre o (usft) (°) (°) (usft) usft' (usft) (usft) ,. u ft (usft) 9,122.96 10,900.00 43.35 176.52 9,282.96 9,122.96 3,178.70 843.15 2,502,661.55 215,092.45 6.37 3,216.38 10,950.00 46.50 177.11 9,318.35 9,158.35 3,143.45 845.10 2,502,626.26 215,093.54 6.37 3,185.83 10,955.33 46.84 177.17 9,322.01 9,162.01 3,139.58 845.30 2,502,622.39 215,093.64 6.37 3,182.46 HK4T 11,000.00 49.66 177.65 9,351.75 9,191.75 3,106.28 846.80 2,502,589.07 215,094.33 6.37 3,153.45 11,050.00 52,83 178.14 9,383.05 9,223.05 3,067.32 848.22 2,502,550.09 215,094.81 6.37 3,119.35 11,100.00 55.99 178.59 9,412.15 9,252.15 3,026.69 849.38 2,502,509.44 215,094.97 6.37 3,083.62 11,150.00 59.15 179.01 9,438.95 9,278.95 2,984.50 850.25 2,502,467.24 215,094.81 6.37 3,046.39 11,181 27 61.13 179.26 9,454.52 9,294.52 2,957.39 850.66 2,502,440.12 215,094.56 6.37 3,022.39 HK5T 11,200.00 62.32 179.41 9,463.39 9,303.39 2,940.89 850.85 2,502,423.63 215,094.35 6.37 3,007.77 11,250.00 65.49 179.77 9,485.38 9,325.38 2,895.99 851.17 2,502,378.74 215,093.57 6.37 2,967.87 11,281.76 67.50 180.00 9,498.05 9,338.05 2,866.87 851.23 2,502,349.62 215,092.92 6.37 2,941.92 End Dir :11281.76'MD,9498.05'TVD 11,300.00 67.50 180.00 9,505.03 9,345.03 2,850.02 851.23 2,502,332.78 215,092.51 0.00 2,926.89 11,400.00 67.50 180.00 9,543.30 9,383.30 2,757.63 851.23 2,502,240.42 215,090.25 0.00 2,844.49 11,402.25 67.50 180.00 9,544.16 9,384.16 2,755.55 851.23 2,502,238.34 215,090.20 0.00 2,842.64 HK6T 11,481 76 67.50 180.00 9,574.59 9,414.59 2,682.10 851.23 2,502,164.90 215,088.41 0.00 2,777.12 Start Dir 6°/100':11481.76'MD,9574.59'TVD 11,500.00 68.59 180.00 9,581.41 9,421.41 2,665.18 851.23 2,502,147.99 215,087.99 6.00 2,762.03 11,550.00 71.59 180.00 9,598.43 9,438.43 2,618.17 851.23 2,502,101.00 215,086.85 6.00 2,720.10 11,600.00 74.59 180.00 9,612.97 9,452.97 2,570.34 851.23 2,502,053.18 215,085.68 6.00 2,677.44 11,623.43 76.00 180.00 9,618.91 9,458.91 2,547.67 851.23 2,502,030.52 215,085.13 6.00 2,657.23 End Dir :11623.43'MD,9618.91'TVD 11,700.00 76.00 180.00 9,637.44 9,477.44 2,473.38 851.23 2.501,956.25 215,083.31 0.00 2,590.96 11,787.57 76.00 180.00 9,658.62 9,498.62 2,388.41 851.23 2,501,871.31 215,081.24 0.00 2,515.18 WFT 11,800.00 76.00 180.00 9,661.63 9,501.63 2,376.35 851.23 2,501,859.25 215,080.94 0.00 2,504.42 11,900.00 76.00 180.00 9,685.82 9,525.82 2,279.32 851.23 2,501,762.25 215,078.57 0.00 2,417.88 11,973.43 76.00 180.00 9,703.58 9,543.58 2,208.07 851.23 2,501,691.02 215,076.83 0.00 2,354.33 Start Dir 6°/100':11973.43'MD,9703.58'TVD 12,000.00 76.41 181.59 9,709.92 9,549.92 2,182.27 850.87 2,501,665.24 215,075.85 6.00 2,331.16 12,050.00 77.20 184.56 9,721.34 9,561.34 2,133.67 848.26 2,501,616.72 215,072.05 6.00 2,286.63 12,100.00 78.02 187.51 9,732.07 9,572.07 2,085.11 843.12 2,501,568.30 215,065.73 6.00 2,241.00 12,150.00 78.87 190.45 9,742.09 9,582.09 2,036.73 835.47 2,501,520.12 215,056.90 6.00 2,194.39 12,200.00 79.75 193.37 9,751.37 9,591.37 1,988.66 825.33 2,501,472.31 215,045.59 6.00 2,146.93 12,250.00 80.66 196.27 9,759.87 9,599.87 1,941.04 812.73 2,501,425.01 215,031.83 6.00 2,098.76 12,300.00 81.59 199.16 9,767.59 9,607.59 1,893.98 797.70 2,501,378.34 215,015.65 6.00 2,049.99 12,332.06 82.20 201.00 9,772.11 9,612.11 1,864.17 786.80 2,501,348.80 215,004.03 6.00 2,018.48 End Dir :12332.06'MD,9772.11'TVD 12,400.00 82.20 201.00 9,781.33 9,621.33 1,801.33 762.68 2,501,286.57 214,978.38 0.00 1,951.52 12,405.76 82.20 201.00 9,782.11 9,622.11 1,796.01 760.64 2,501,281.30 214,976.21 0.00 1,945.85 WF_2 12,500.00 82.20 201.00 9,794.90 9,634.90 1,708.84 727.18 2,501,194.97 214,940.63 0.00 1,852.97 6/12/2017 2:14:24PM Page 7 COMPASS 5000.1 Build 81 • Halliburton I-IALLIBURTONJ Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:TBU M-32RD2 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-32 revised @ 160.00usft Project: McArthur River Field MD Reference: '° TBU M-32 revised @ 160.00usft Site: Steelhead North Reference: True f=: Well: Plan:TBU M-32RD2 Survey Calculation Method: FMinimum Curvature Wellbore Plan:M-32RD2 Design: 3 M 32RD2 WP04 : ..�. ..„ Planned Survey Measured ,,,, - Vertical 17, `' Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E1-W Northing Easting DLS Vert Section =: (usft) s(°) (°) (usft) uft (usft) (usft) (usft) (usft) 9,648.47 12,600.00 82.20 201.00 9,808.47 9,648.47 1,616.35 691.67 2,501,103.37 214,902.88 0.00 1,754.42 12,700.00 82.20 201.00 9,822.04 9,662.04 1,523.85 656.17 2,501,011.77 214,865.13 0.00 1,655.86 12,800.00 82.20 201.00 9,835.61 9,675.61 1,431.36 620.66 2,500,920.17 214,827.37 0.00 1,557.31 12,900.00 82.20 201.00 9,849.19 9,689.19 1,338.86 585.16 2,500,828.58 214,789.62 0.00 1,458.76 13,000.00 82.20 201.00 9,862.76 9,702.76 1,246.37 549.65 2,500,736.98 214,751.87 0.00 1,360.21 13,100.00 82.20 201.00 9,876.33 9,716.33 1,153.87 514.15 2,500,645.38 214,714.12 0.00 1,261.65 13,200.00 82.20 201.00 9,889.90 9,729.90 1,061.38 478.64 2,500,553.78 214,676.37 0.00 1,163.10 13,300.00 82.20 201.00 9,903.47 9,743.47 968.89 443.13 2,500,462.18 214,638.61 0.00 1,064.55 13,400.00 82.20 201.00 9,917.04 9,757.04 876.39 407.63 2,500,370.58 214,600.86 0.00 966.00 13,500.00 82.20 201.00 9,930.62 9,770.62 783.90 372.12 2,500,278.98 214,563.11 0.00 867.44 13,600.00 82.20 201.00 9,944.19 9,784.19 691.40 336.62 2,500,187.38 214,525.36 0.00 768.89 13,700.00 82.20 201.00 9,957.76 9,797.76 598.91 301.11 2,500,095.78 214,487.60 0.00 670.34 13,722.41 82.20 201.00 9,960.80 9,800.80 578.18 293.16 2,500,075.25 214,479.14 0.00 648.26 Total Depth:13722.41'MD,9960.8'TVD .. ,. i Targets -hit/miss target Dip Angle Dip Dir TVD +N/-S +EI-W Northing Easting -Shape ' (°) (°) (usft) (usft) (usft) (usft) (usft) ztzieZz M-32RD2 WP02 WFTTgt1 0.00 0.00 9,654.88 2,457.80 891.11 2,501,939.70 215,122.80 -plan misses target center by 41.99usft at 11719.34usft MD(9642.11 TVD,2454.62 N,851.23 E) -Circle(radius 50.00) M-32RD2 WP02 WF_3 Tgt3 0.00 0.00 9,960.80 573.34 306.24 2,500,070.10 214,492.10 -plan misses target center by 13.94usft at 13722.24usft MD(9960.78 TVD,578.34 N,293.22 E) -Point M-32RD2 WP02 WF_2 Tgt2 0.00 0.00 9,778.79 1,877.13 809.56 2,501,361.20 215,027.10 -plan misses target center by I9.25usft at 12313.22usft MD(9769.49 TVD,1881.66 N,793.33 E) -Point M-32RD2 WP04 TOPT Tgt 0.00 0.00 9,498.05 2,866.87 851.23 2,502,349.62 215,092.92 -plan hits target center -Circle(radius 50.00) M-32RD2 WP04 BOPT Tgt 0.00 0.00 9,573.62 2,681.81 850.23 2,502,164.64 215,087.40 -plan misses target center by 1.42usft at 11481.65usft MD(9574.55 TVD,2682.19 N,851.23 E) -Circle(radius 50.00) 13,722.41 9,960.80 8 1/2"x 7" 7 8-1/2 6/12/2017 2::14.24PM Page 8 COMPASS 5000.1 Build 81 • S 1 Halliburton -IALLIBURTON Standard Proposal Report Database: it:Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:TBU M-32RD2 Company: Hilcorp Alaska,LLC TVD Reference:. . TBU M-32 revised @ 160.00usft Project: , McArthur River Field MD Reference: TBU M-32 revised @ 160.00usft Site: 4', ma Steelhead North Reference: - True Well: Plan:TBU M-32RD2 Survey Calculation Method: ': Minimum Curvature Wellbore: Plan:M-32RD2 z Design: M-32RD2 WP04 ;: ., Formations l' Measured Vertical Vertical v;3 ' Dip e Depth Depth Depth SS ` Dip Direction (USft) (USft) () s 11,402.25 9,544.16 HK6T 10,858.23 9,251.93 HK3T 12,405.76 9,782.11 WF_2 10,699.37 9,123.11 HK2T 11,181.27 9,454.52 HK5T 10,955.33 9,322.01 HK4T 10,203.41 8,651.10 COAL39 11,787.57 9,658.62 WFT 10,659.92 9,088.78 HTKE-FW 10,609.35 9,043.60 H1X_FW Plan Annotations Measured Vertical Local Coordinates Depth w Depth y, +N/-s +E/-W (usft) , (usft) (usft) (usft) Comment 7,300.00 6,912.57 1,293.85 481.62 Start Dir 12.3°/100':7300'MD,6912.57'TVD:60°RT TF 7,318.00 6,926.70 1,304.37 485.31 End Dir :7318'MD,6926.7'TVD 7,368.00 6,965.65 1,333.66 496.49 Start Dir 6°/100':7368'MD,6965.65'TVD 7,828.17 7,251.32 1,680.85 570.96 End Dir :7828.17'MD,7251.32'TVD 9,078.17 7,799.28 2,798.18 688.39 Start Dir 6.12°/100':9078.17'MD,7799.28'TVD 9,120.06 7,818.44 2,835.25 692.01 End Dir :9120.06'MD,7818.44'TVD 9,259.52 7,884.88 2,957.38 703.02 Start Dir 6.37°/100':9259.52 MD,7884.88'TVD 11,281.76 9,498.05 2,866.87 851.23 End Dir :11281.76'MD,9498.05'TVD 11,481.76 9,574.59 2,682.10 851.23 Start Dir 6°/100':11481.76'MD,9574.59'TVD 11,623.43 9,618.91 2,547.67 851.23 End Dir :11623.43'MD,9618.91'TVD 11,973.43 9,703.58 2,208.07 851.23 Start Dir 60/100':11973.43'MD,9703.58'TVD 12,332.06 9,772.11 1,864.17 786.80 End Dir :12332.06'MD,9772.11'TVD 13,722.41 9,960.80 578.18 293.16 Total Depth:13722.41'MD,9960.8'TVD 6/12/2017 2:14:24PM Page 9 COMPASS 5000.1 Build 81 • S Hilcorp Alaska, LLC McArthur River Field Steelhead Plan: TBU M-32RD2 Plan: M-32RD2 M-32RD2 WP04 Sperry DrillingServices P �/ Clearance Summary Anticollision Report 12 June,2017 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Steelhead-Plan:TBU M-32RD2-Plan:M-32RD2-M-32RD2 WP04 Well Coordinates:2.499,504.41 N,214,171.96 E(60°49'54.99"N,151.3V 06.81"W) Datum Height:TBU M.32 revised @ 160.00usft Scan Range: 7,300.00 to 13,722.41 usft.Measured Depth. Scan Radius Is 1,572.24 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version:5000.1 Build:81 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 111111111. HALLIBURTON Sperry Drilling Services • • Hilcorp Alaska,LLC HALLI B U RTO N McArthur River Field Anticollision Report for Plan:TBU M-32RD2 -M-32RD2 WP04 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:Steelhead-Plan:TBU M-32RD2-Plan:M-32RD2-M-32RD2 WP04 Scan Range: 7,300.00 to 13,722.41 usft.Measured Depth. Scan Radius is 1,572.24 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Grayling G-04-G-04-G-04 10,254.83 965.05 10,254.83 802.46 9,123.83 5.936 Ellipse Separation Pass- G-04-G-04-G-04 10,275.00 965.19 10,275.00 802.54 9,143.58 5.934 Clearance Factor Pass- G-04-G-04RD-G-04RD - - - - - -., FAIL- G-04-G-04RD-G-04RD FAIL- G-06-G-06-G-06 7,400.00 803.37 7,400.00 556.37 7,843.48 3.252 Clearance Factor Pass- G-06-G-06-G-06 7,625.00 738.91 7,625.00 527.51 7,939.01 3.495 Ellipse Separation Pass- G-06-G-06-G-06 7,790.56 722.35 7,790.56 552.86 7,981.42 4.262 Centre Distance Pass- G-06-G-06RD-G-06RD 7,400.00 803.37 7,40000 556.37 7,843.48 3.252 Clearance Factor Pass- G-06-G-O6RD-G-06RD 7,625.00 738.91 7,625.00 527.51 7,939.01 3.495 Ellipse Separation Pass- G-06-G-O6RD-G-06RD 7,790.56 722.35 7,790.56 552.86 7,981.42 4.262 Centre Distance Pass- G-07-G-07-G-07 - - - Er -221.16 10,4M r 0.484 Ellipse Set G-07-G-07-G-07 - - ll -220.23 _10,49. .: 0.480 Clearance FAN= G-07-G-07-G-07 - - llll, -216.1 maim . 0.481 Centre Distance ' G-08-G-08-G-08 7,300.00 1,151.95 7,300.00 1,061.06 7,400.00 12.673 Ellipse Separation Pass- G-08-G-08-G-08 7,700.00 1,476.48 7,700.00 1,349.89 7,500.00 11.664 Clearance Factor Pass- G-08-G-08RD-G-08RD 7,300.00 1,151.95 7,300.00 1,061.06 7,400.00 12.673 Ellipse Separation Pass- G-08-G-08RD-G-08RD 7,700.00 1,476.48 7,700.00 1,349.89 7,500.00 11.664 Clearance Factor Pass- 0-20-G-20-G-20 - - 11111 -169.39 - r 0.505 Clearance Factor' G-20-G-20-G-20 - _ - ® -17279 - •, 0.522 Ellipse Separation' IiM 1111111.1. G-21RD-G-21-G-21 - ■ 93.80 - III -162.39 - . 0.366 Ellipse Separation FAIL G-21RD-0-21-0-21 MN= 1111 83.77 - • -149.39 ME= II 0.359 Clearance Factor FAIL G-21 RD-G-21-G-21 - Ill 78.84 - 111 -100.49 - .. 0.440 Centre Distance ,AN FAIL G-21RD-G-21RD-G-21RD - III 93.12 - III -161.39 - . 0.366 Ellipse Separatiop_ IL G-21RD-G-21RD-G-21RD - •, 82.79 • A. - .,, 0.359 ctor,,_ 0-21RD-G-2IRD-G-21RD - IL__,TLA - Illy AM - IR_ 0.443 •e ' G-24-G-24-G-24 13,700.00 1,184.83 13,700.00 655.04 10,400.00 2.236 Clearance Factor Pass- G-30-0-30-G-30 7,300.00 631.94 7,300.00 298.79 7,600.71 1.897 Centre Distance Pass- G-30-G-30-G-30 7,400.00 642.48 7,400.00 293.41 7,650.82 1.841 Ellipse Separation Pass- 12 Jute,2017-14:45 Page 2 of 7 COMPASS 411 0 Hilcorp Alaska,LLC HALLI B U RTO N McArthur River Field Anticollision Report for Plan:TBU M-32RD2-M-32RD2 WP04 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:Steelhead-Plan:TBU M-32RD2-Plan:M-32RD2-M-32RD2 WP04 Scan Range: 7,300.00 to 13,722.41 usft.Measured Depth. Scan Radius is 1,572.24 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft G-30-G-30-0J0 13,700.00 721.93 13,700.00 294.76 10,547.00 1.690 Clearance Factor Pass- G-32-G-32-G-32 10,263.53 1,063.93 10,263.53 619.36 9,478.22 2.393 Centre Distance Pass- G-32-G-32-G-32 10,275.00 1,064.01 10,275.00 619.11 9,488.68 2.392 Ellipse Separation Pass- G-32-G-32-G-32 10,300.00 1,064.74 10,300.00 619.16 9,511.33 2.390 Clearance Factor Pass- G-33-G-33-G-33 11,769.46 396.05 11,769.46 58.68 10,234.05 1.174 Clearance Factor Pass- G-34RD-G-34RD-G-34RD 13,300.00 1,306.05 13,300.00 965.03 10,310.00 3.830 Clearance Factor Pass- G-34RD-G-34RD-G-34RD 13,550.00 1,261.19 13,550.00 940.17 10,310.00 3.929 Ellipse Separation Pass- G-34RD-G-34RD-G-34RD 13,655.35 1,256.78 13,655.35 945.27 10,310.00 4.034 Centre Distance Pass- King Salmon K-25(K-16)-K-25-K-25 10,709.84 903.18 10,709.84 773.28 13,710.01 6.953 Centre Distance Pass- K-25(K-16)-K-25-K-25 10,750.00 903.87 10,750.00 772.94 13,747.64 6.903 Ellipse Separation Pass- K-25(K-16)-K-25-K-25 10,850.00 911.08 10,850.00 778.08 13,845.81 6.850 Clearance Factor Pass- Steelhead Plan:TBU M-32RD2-M-32-M-32 7,600.00 31.25 7,600.00 27.74 7,597.97 8.900 Ellipse Separation Pass- Plan:TBU M-32RD2-M-32-M-32 10,650.00 315.86 10,650.00 246.81 10,298.71 4.575 Clearance Factor Pass- Plan:TBU M-32RD2-M-32 PB1-M-32 PB1 7,600.00 31.25 7,600.00 27.58 7,597.97 8.515 Clearance Factor Pass- Plan:TBU M-32RD2-M-32 PB2-M-32 PB2 7,600.00 31.25 7,600.00 27.58 7,597.97 8.521 Ellipse Separation Pass- Plan:TBU M-32RD2-M-32 PB2-M-32 PB2 10,700.00 420.92 10,700.00 351.65 10,295.49 6.076 Clearance Factor Pass- Plan:TBU M-32RD2-M-32 PB3-M-32 PB3 7,600.00 31.25 7,600.00 27.74 7,597.97 8.900 Ellipse Separation Pass- Plan:TBU M-32RD2-M-32 PB3-M-32 PB3 10,650.00 315.86 10,650.00 246.81 10,298.71 4.575 Clearance Factor Pass- Plan:TBU M-32RD2-M-32RD-M-32RD 7,600.00 31.25 7,600.00 27.73 7,597.97 8.893 Ellipse Separation Pass- Plan:TBU M-32RD2-M-32RD-M-32RD 10,650.00 342.55 10,650.00 274.00 10,272.09 4.997 Clearance Factor Pass- Plan:TBU M-32RD2-M-32RD PB1-M-32RD PB1 7,600.00 31.25 7,600.00 27.58 7,597.97 8.513 Ellipse Separation Pass- Plan:TBU M-32RD2-M-32RD PB1-M-32RD PB1 10,575.00 350.84 10,575.00 280.88 10,263.97 5.015 Clearance Factor Pass- RIG:Trading Bay Unit M-06RD-RIG:M-06RD-M-06R 11,612.66 276.41 11,612.66 200.87 14,929.02 3.659 Centre Distance Pass- RIG:Trading Bay Unit M-06RD-RIG:M-06RD-M-06R 11,775.00 282.45 11,775.00 195.02 15,083.67 3.230 Ellipse Separation Pass- RIG:Trading Bay Unit M-06RD-RIG:M-06RD-M-06R , 12,300.00 313.01 12,300.00 208.95 15,594.35 3.008 Clearance Factor Pass- TBU M-11-M-11-M-11 12,050.00 951.85 12,050.00 886.53 10,290.00 14.572 Clearance Factor Pass- TBU M-11-M-11-M-11 12,275.00 919.88 12,275.00 857.71 10,290.00 14.795 Ellipse Separation Pass- 12 June,2017-14:45 Page 3 of 7 COMPASS II 0 Hilcorp Alaska,LLC H ALL I B U RTO N McArthur River Field Anticollision Report for Plan:TBU M-32RD2-M-32RD2 WP04 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:Steelhead-Plan:TBU M-32RD2-Plan:M-32RD2-M32RD2 WP04 Scan Range:7,300.00 to 13,722.41 usft.Measured Depth. Scan Radius is 1,572.24 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft TBU M-11-M-11-M-11 12,281.25 919.86 12,281.25 857.74 10,290.00 14.807 Centre Distance Pass- TBU M-12-M-12-M-12 10,250.00 1,319.66 10,250.00 1,144.38 10,715.00 7.529 Clearance Factor Pass- TBU M-12-M-12-M-12 10,265.04 1,319.47 10,265.04 1,144.24 10,715.00 7.530 Ellipse Separation Pass- TBU M-14-M-14-M-14 7,300.00 913.29 7,300.00 837.87 7,459.07 12.109 Ellipse Separation Pass- TBU M-14-M-14-M-14 12,550.00 1,120.12 12,550.00 1,024.49 9,190.00 11.713 Clearance Factor Pass- TBU M-25-M-25-M-25 7,910.49 539.25 7,910.49 353.75 7,704.32 2.907 Centre Distance Pass- TBU M-25-M-25-M-25 8,250.00 566.71 8,250.00 324.49 7,991.13 2.340 Ellipse Separation Pass- TBU M-25-M-25-M-25 8,600.00 639.35 8,600.00 350.91 8,295.87 2.217 Clearance Factor Pass- TBU M-29-M-29-M-29 7,300.00 402.51 7,300.00 365.38 7,307.94 10.839 Centre Distance Pass- TBU M-29-M-29-M-29 11,975.00 433.94 11,975.00 327.55 10,253.20 4.079 Clearance Factor Pass- TBU M-29-M-29-M-29 12,000.00 431.51 12,000.00 325.96 10,248.91 4.088 Ellipse Separation Pass- TBU M-29-M-29A-M-29A - - - - - - TBU M-31-M-31-M-31 9,434.79 569.79 9,434.79 466.66 8,714.20 5.525 Centre Distance Pass- TBU M-31-M-31-M-31 9,475.00 570.31 9,475.00 465.89 8,749.92 5.462 Ellipse Separation Pass- TBU M-31-M-31-M-31 9,625.00 580.03 9,625.00 471.87 8,886.03 5.363 Clearance Factor Pass- TBU M-31-M-31A-M-31A 8,582.68 362.57 8,582.68 274.80 8,365.16 4.131 Centre Distance Pass- TBU M-31-M-31A-M-31A 8,600.00 362.98 8,600.00 27441 8,364.23 4.098 Ellipse Separation Pass- TBU M-31-M-31A-M-31A 8,625.00 365.02 8,625.00 275.57 8,362.95 4.080 Clearance Factor Pass- TBU M-31-M-31B-M-318 7,300.00 873.92 7,300.00 818.13 7,218.19 15.665 Clearance Factor Pass- TBU M-31-M-31 L1-M-31 L1 9,434.79 569.79 9,434.79 466.66 8,714.20 5.525 Centre Distance Pass- TBU M-31-M-31 L1-M-31L1 9,475.00 570.31 9,475.00 465.89 8,749.92 5.462 Ellipse Separation Pass- TBU M-31-M-31 L1-M-31L1 9,625.00 580.03 9,625.00 471.87 8,886.03 5.363 Clearance Factor Pass- Trading Bay Unit M-28RD-M-28RD-M-28RD 10,100.00 1,338.72 10,100.00 1,258.07 9,955.60 16.599 Clearance Factor Pass- Trading Bay Unit M-28RD-M-28RD-M-28RD 10,136.41 1,338.09 10,136.41 1,257.56 9,988.02 16.617 Ellipse Separation Pass- 12 June,2017-14:45 Page 4 of 7 COMPASS 1110 S Hilcorp Alaska,LLC HALLI B U RTO N McArthur River Field Anticollision Report for Plan: TBU M-32RD2 -M-32RD2 WP04 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 24.75 926.75 CB-Gyro-MS 986.75 1,272.75 CB-Gyro-SS 1,385.75 7,300.00 MWD 7,300.00 7,650.00 M-32RD2WP04 MWD_Interp Azi+sag 7,650.00 13,722.41 M-32RD2 WP04 MWD+SC+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 12 June,2017-14:45 Page 5 of 7 COMPASS • 0 Hilcorp Alaska,LLC HALLI B U RTO N McArthur River Field Anticollision Report for Plan: TBU M-32RD2-M-32RD2 WP04 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to TBU M-32 revised @ 160.O0usft. Northing and Easting are relative to Plan:TBU M-32RD2. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150,00°,Grid Convergence at Surface is:-1.40°. -A-_-Ian'Saelhead La-Virte<Steelhead to-Vne to-Vine WP1 0 VQ M-32 VO Ladder Plot -N- PIan:TBUM32RD2,M-3 2 PB1,M-32PB1V0 # Plan:TBU M-32RD2,M-32PB2,M-32PB2VU r r---- r � - i # Plan:TBU M-32RD2,M-32P83,M1-32PB3V0 I I I ,11 I ii1\ 1. �� i \\��'-,� -B- Plan:TBU M-32RD2,M-32RD,M-32RDV0 1350 ,l i, ti \• Tj ,; ,tti�•.a -�- Plan:TBU M-32RD2,M-32RDPB1,M-32RDPBIVS �/ �V'- flititiyi� $ Plan:TBU M-35,M-35,M-35 WP1 V0 O 1014►'�b'�i $ PIan:TBUM-36,M-36,M-36WP1 V0 Lo Plan:TBU M-37,M-37,M-37 1 V0 o 1q�•�t ,� ��',� $ RIG:TradingBayUnitM-O6RD,M-06,M-O6V0 -� 4ti t • # RIG:TradingBayUnitM-06RD,RIG:M-O6RD,M-06RDVO ILI • RIG:TradingBayUnitM-O6RD,RIG:M-06RD,M-O6RDWPCS' N _ t r -;-�' -N- TBUM-02,M-02,M-02V3 C ---- $ TBUM-03,M-03,M-03V0 -1 # TBUM-04,M-04,M-04V0 U450 -6- TBUM-05,M-05,M-D5V0 o �/ - - TBUM-07,M-07,M-07V0 t ( # TBU M-09,M-09,M-09 VO i____ L L $ TBU M-I0,M-10,M-10 V0 N Vii -- - $ TBU M-10,M-10PB1,M-10PB1V0 U } $ TBUM-11,M-11,M-11VO 0 ' a' # TBUM-12,M-12,M-12V0 0 2500 5000 7500 10000 12500 4- TBU M-13,M-13,M-13 VO -le- TBUM-14,M-14,M-14V0 Measured Depth(2500 usft/in) -)(- TBU M-14,M-14RD,M-14RDVO $'IHUM-ID,IVI-ID,M-ID VU 12 June,2017-14::45 Page 6 of COMPASS • • Hilcorp Alaska,LLC HALL I B U RTO N McArthur River Field Anticollision Report for Plan:TBU M-32RD2 -M-32RD2 WP04 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor Nan.b elnead La-vine,uteemead La-vine,La-vine w8'1.0 VU I `� -- ... ...- = PIan:TBUM-32RD2,M-32,M-32V0 J Plan:TBU M-32RD2,M-32 PB1,M-32 PB1 VO 10.00 .... I - '�l Plan:TBUM-32RD2,M-32 PB2,M-32 PB2 V0 111) Plan:TBUM-32RD2,M-32 PB3,M-32 PB3 V0 875- { = PIan:TBUM-32RD2,M-32RD,M-32RDV0 lei { _ - Plan:TBUM-32RD2,M-32RDPBI,M-32RDPB1V0 � I - PIan:TBU M-35,M-35,M-35 WP1 V0 1 ii , ' 750- .. .._...I PIan:TBUM-36,M-36,M-36WP1V0 Iii Plan:TBU M-37,M-37,M-37 Wp1 VO 1 ii I i..: f1 RIG:Trading Bay Un it M-06RD,M-06,M-06 V0 m 6.25 ----- ----- - -- --- -- '�--- --- - RIG:TradingBayUnitM-06RD,RIG:M-06RD,M-06RDV0 1� - RIG:TradingBayUnitM-O6RDRIG:M-06RDM-06RDWP05b TBUM-01,M-01,M-01 VO /1114 Jhl fil i 1 f.._...n o TBU M-02,M-02,M-02 V0 TBU M-03,M-03,M-03 V0 CI) 3 75 ! TBU M-04,M-04 M-04 V0 ....... -- --- - -- �� iiip, �' 11, - TBU M-05,M-05,M-05 V0 1 ,e - TBUM-07 M-07 M-07 V0 2.50 --.. ......... 1 Q,l, _... .---- --- TBU M-09,M09,M-09 V0 i i - = TBUM-10,M-10,M-10V0 Collision Avoidance Req I - No-Go Zone-Sto Drillin '�� = TBUM-I0,M-10PB1,M-10PB1 V0 1.25 - p"-- -. .___ I ....., .. - - -- '.......... ._ - TBUM-11,M-11,M-11 V0 TBU M-12,M-12,M-12 VO i 1 TBUM-13,M-13,M-13V0 0.00 iiiliiiii iiiiIiiii i i i i r I I I I I Ii i 1 1 i 1 i - TBU M-14,M-14,M-14 V0 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 TBU M-14,M-14RD,M-14RD V0 Meast>iDepth(2500tsftln) = TBUM-15,M-15,M-15V0 12 June,2017-14:45 Page 7 o1 7 COMPASS O Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Wednesday,June 28,2017 3:35 PM To: Schwartz, Guy L(DOA) Subject: RE: M-32RD2 (PTD 217-091) Follow Up Flag: Follow up Flag Status: Flagged Good afternoon Guy, The status of the wells are listed below: G-04RD—Shut in Injector. Open down to 10,330'. G-07—Shut in Injector. Open down to 9,850'. G-20—Active Producer.Open to 10,162'. G-21RD—Active Producer. Open to 10,662'. G-33—Active Producer. Open to 10,212'. M-29A—Active Producer. Open to 11,592. All of the producers are oil wells. We will be overbalanced if we drill into them.We will monitor the wellhead pressures while drilling and look for any changes.Also,we'll be looking for magnetic interference with our surveys. The only risk we have is to equipment and damaging wellbores. Thanks Guy! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Wednesday,June 28,2017 1:35 PM To: Monty Myers<mmyers@hilcorp.com> Subject: RE: M-32RD2 (PTD 217-091) Did I hear back from you on this??Can't find an email. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 1 recipient of this e-mail,please delete it,with rst saving or forwarding it,and,so that the AO�is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Tuesday,June 20,2017 4:03 PM To: mmyers@hilcorp.com Subject: M-32RD2(PTD 217-091) Monty, I was reviewing the collision data..what is going on with all the Grayling wells? They are several that are failing the tolerance standard. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 • TRANSMITTAL LETTER CHECKLIST WELL NAME: / U(,L M _ 3��1� 'Z PTD: 117-071 /Development Service _Exploratory _Stratigraphic Test Non-Conventional FIELD: ',i C-J4AD-E-(AA ,��/�Af" POOL: NCAA,--TRAA Aived- kfv Arejoid Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. 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',N m m CT o '°' , , , Z Z o , y 9 - co ,. �K � 0 3 m a D ro W "' 'O ' K CD , .: , SO y ,0i ,S ,N (D n. dA ,r W y fD = ,a cr a ,n Dpi p -On o ,� < y ,u , F , u a) 7-7 'a Qo , -. , ,o ;� -CI(0 � 0 ' '0 ,c ro o o a p � a 0 3 0 ,a , , , , , , ,5.1:4 ro ,a O , , , , ,, ,, , , , , , , , , , , , , op , , °- , ,D , P 7 ro , , y 0 m 21I CD , , 0 , 0C TBU M-32RD2 50-733-20462-02-00 McArthur River Field Kenai Peninsula Borough, Alaska July 23, 2017 – August 9, 2017 Provided by: Approved by: John Serbeck Compiled by: Allen Odegaard Eric Andrews Distribution Date: September 18, 2017 M-32RD2 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............................................................................................ 2 1.1 Equipment Summary ................................................................................................................. 2 1.2 Crew.......................................................................................................................................... 2 2 GENERAL WELL DETAILS .............................................................................................................. 3 2.1 Well Objectives .......................................................................................................................... 3 2.2 Hole Data .................................................................................................................................. 3 2.3 Daily Activity Summary .............................................................................................................. 4 3 GEOLOGICAL DATA ........................................................................................................................ 6 3.1 Lithostratigraphy ........................................................................................................................ 6 3.2 Lithology Details ........................................................................................................................ 7 3.2.1.1 Tyonek Formation ........................................................................................................... 8 3.2.1.2 Hemlock Formation ....................................................................................................... 16 3.2.1.3 Hemlock H1X_FW ......................................................................................................... 16 3.2.1.4 Hemlock HTKE-FW ....................................................................................................... 17 3.2.1.5 Hemlock HK2T .............................................................................................................. 17 3.2.1.6 Hemlock HK2T_LOWER ............................................................................................... 18 3.2.1.7 Hemlock HK3T .............................................................................................................. 18 3.2.1.8 Hemlock HK4T .............................................................................................................. 19 3.2.1.9 Hemlock HK5T .............................................................................................................. 19 3.2.1.10 Hemlock HK6T .............................................................................................................. 20 3.2.1.11 Hemlock HK7T .............................................................................................................. 20 3.2.1.12 West Foreland Formation .............................................................................................. 21 3.2.1.13 West Foreland H1X_FW ................................................................................................ 21 3.2.1.14 West Foreland WF_2 .................................................................................................... 22 3.2.1.15 West Foreland WF_3 .................................................................................................... 25 3.3 Sampling Program ................................................................................................................... 26 4 Drilling Data .................................................................................................................................... 27 4.1 Surveys ................................................................................................................................... 27 4.2 Bit Record ............................................................................................................................... 37 4.3 Mud Record ............................................................................................................................. 38 4.4 Drilling Progress ...................................................................................................................... 39 5 SHOW REPORTS .......................................................................................................................... 40 6 DAILY REPORTS ........................................................................................................................... 41 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) Final Data CD M-32RD2 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 hrs. -- Effective Circulating Density (ECD) Halliburton 0 hrs. — Hook Load / Weight on bit RigWatch 0 hrs. — Mud Flow In RigWatch 0 hrs. — Mud Flow Out RigWatch 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & RigWatch) 0 hrs. — Pit Volumes, Pit Gain/Loss RigWatch 0 hrs. — Pump Pressure RigWatch 0 hrs. — Pump stroke counters RigWatch 0 hrs. — Rate of Penetration RigWatch 0 hrs. — RPM RigWatch 0 hrs. — 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Allen Odegaard 20 20 Robert Bales 1 18 Eric Andrews 5 21 Joshua Dubowski 16 4 Britten Adams 5 6 Brendan Schmidt 1 1 Eli Callan 3 11 *1 Years’ experience as Logging Geologist *2 Days at wellsite between rig up and rig down of logging unit. M-32RD2 3 2 GENERAL WELL DETAILS 2.1 Well Objectives M-32RD2 is an oil production well planned to be re-drilled in a south-we sterly direction from the existing M-06 utilizing the existing casing program down to 7,209’ MD / 6,487.25’ TVD. At 7,209’ MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock and West Foreland targets. A 6,513’ x 8-1/2” open hole section is planned. A 7” 29# L-80 DWC/C production liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 3-1/2” ESP completion. The well very closely followed the planned directional path. The kickoff point was 7,209’ MD at 54.3° and began immediately bringing the angle up to 70.0° by 7,901’ MD. Held inclination at 67°-70° until 9,036’ MD. Began to drop angle down to 10° by 10,177’. Continue drilling while building angle to 84° at 12,373’ MD. Held ~84° to 14,023’ (TD). 7” liner was hung from the 9-5/8” casing at 7,209’ MD and ran down to 14,018’ MD. Operator: HILCORP ALASKA, LLC Well Name: M-32RD2 Field: McArthur River Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Harold Soule, Andy Lundale, Location: Surface Coordinates 969' FNL, 527' FWL, Sec 33, T9N, R13W, SM, AK Mud Line Elevation 160’ AMSL Rotary Table Elevation 187’ AMSL Classification: Development - Oil API #: 733-20462-02-00 Permit #: 217-091 Rig Name/Type: Steelhead / Triple Spud Date July 18, 2017 Total Depth Date: August 9, 2017 Total Depth 14,023’ MD / 9,957.32’ TVD Primary Targets West Foreland Total Depth Formation: West Foreland 3 Completion Status: — LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service — 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth LOT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 8 ½” 14,023’ 9,957.32’ WF3 9.45 82.91 7 5/8” 14,018’ 9,956’ N/A M-32RD2 4 2.3 Daily Activity Summary 7/23/2017: Ran into the hole with whip-stock from 2,826', and set at 7,226'. Displaced well to 8.9 ppg oil based mud, Tested BOP's, laid down test equipment, and milled out window to 7,218’. 7/24/2017: Continued milling out window from 7,218' to 7,233'. Due to slow ROP, we pulled out of the hole to change out the bit. Picked up a roller cone bit, ran into the hole, and drilled ahead from 7,233’ to 7,237'. At 7,237’, circulated bottoms up, performed FIT test to 12.5 ppg, drilled ahead from 7,237' to 7256', and circulated bottoms up. 7/25/2017: Slip and cut drilling line, pulled out of the hole from 7,119’ to surface, installed 5” rams, picked up directional tools, and ran into the hole to 7,135’. 7/26/2017: Continued running into the hole from 7,135’ to 7,256’, circulated on bottom, and drilled ahead from 7256’ to 8148’. 7/27/2017: Continued drilling ahead from 8,148' to 9,615’. 7/28/2017: Drilled ahead from 9,615’ to 10,112’. Decided to pull out of hole for a bit change. Circulated and pulled out of hole from 10,112’ to 715’. 7/29/2017: Finish pulling out of the hole from 715', changed bit, and downloaded tools. Ran back into the hole from surface to 9,127'. Lost communication with Geo-Pilot and pulled back out of the hole from 9,127' to 8,351’. 7/30/2017: Continued pulling out of the hole from 8,351’ to surface, Changed out MWD tools and bit before running back into the hole from surface to 9,952’. 7/31/2017: Continued running into the hole from 9,952' to 10,112'. Drilled from 10,112' to 10,776'. Decided to pull out of hole at 10,776' for a mud motor. Pulled out of hole from 10,776' to surface. 8/01/2017: Finished pulling out of the hole, laid down tools, picked up mud motor and BHA, and ran back into the hold from surface to 10,776'. Circulated on bottom and drilled ahead from 10,776' to 11,127'. 8/02/2017: Continued drilling from 11,127’ to 11,222’, circulated mud, and began pulling out of hole to change BHA. Pulled out of hole from 11,222’ to surface. Laid down BHA and rigged up to test BOP’s. 8/03/2017: Completed testing BOP’s, picked up BHA, tested MWD tools, and began running into the hole from surface to 6917'. Slip and cut drill line while circulating and continued running into the hole from 6,917' to 10,244'. 8/04/2017: Continued running into the hole from 10,244’ to 11,222’. Drilled ahead from 11,222’ to 11,365’. Decided to pull out of hole from 11,365’ due to slow drill rate. 8/05/2017: Finished pulling out of the hole from 9,979’ to surface, made up mud motor and BHA. Began running back into the hole from surface to 7,499’. 8/06/2017: Continued running into the hole from 7,499’ to 11,365’. Drilled ahead from 11,365’ to 11,975’. 8/07/2017: Drilled ahead from 11,975' to 12,419'. Encountered problems with the Kelly Hose. M-32RD2 5 8/08/2017: Fixed Kelly Hose and drilled ahead from 12,419’ to 13,007’. 8/09/2017: Drilled ahead from 13,007’ to TD at 14,023’ and began circulating mud. 8/10/2017: Finished circulating mud and began tripping out of the hole from 14,023’ to 1,711’. 8/11/2017: Continued tripping out of the hole from 1,711’ to surface. Pick up clean out assembly and run into the hole from surface to 12,451’. 8/12/2017: Continued running into the hole from 12,451 to bottom 14,023’, circulate and condition. Began tripping out of the hole from bottom to 12796’. Unable to complete TOH without pumps. Tripped back into hole from 12796’ to 14023’. After raising mud weight, began tripping out of hole from 14023’ to 12308’. 8/13/2017: Finished pulling out of the hole from 12308’ to surface. Rig up, prepare to run 7” liner. Began running 7” liner from surface to 1,630’. 8/14/2017: Continued running 7” liner into the hole from 1,630’ to 9,241’. M-32RD2 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geologists FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) KOP 7,300’ 6,913’ -6,753’ 7,209’ 7,668 -7,508 D9_UPPER_COAL - - - 9,056 7,943 -7,783 D9_COAL - - - 9,555 8,137 -7,977 D10_COAL - - - 9,796 8,445 -8,285 DG2 - - - 10,124 8,514 -8,354 DG1 - - - 10,194 8,591 -8,431 G_STRAY - - - 10,273 8,665 -8,505 COAL_39 10,203’ 8,651’ -8,481’ 10,347 8,680 -8,520 COAL_39_BASE - - - 10,363 8,723 -8,563 G1 - - - 10,406 8,787 -8,627 G2 - - - 10,471 8,833 -8,673 G3 - - - 10,519 8,907 -8,747 G4 - - - 10,596 8,926 -8,766 G5 - - - 10,615 9,052 -8,892 H1X_FW 10,609’ 9,044’ -8,884’ 10,748 9,079 -8,919 COAL_59 - - - 10,777 9,084 -8,924 COAL_59_BASE - - - 10,783 9,084 -8,924 HTKE_FW 10,659’ 9,089’ -8,929’ 10,783 9,113 -8,953 HK2T 10,699’ 9,123’ -8,963’ 10,815 9,163 -9,003 HK2T_LOWER - - - 10,871 9,261 -9,101 HK3T 10,858’ 9,252’ -9,092’ 10,988 9,358 -9,198 HK4T - - - 11,124 9,425 -9,265 HK5T 11,181’ 9,455’ -9,295’ 11,239 9,542 -9,382 HK6T 11,402’ 9,544’ -9,384’ 11,497 9,614 -9,454 HK7T - - - 11,719 9,648 -9,488 WFT 11,787’ 9,658’ -9,498’ 11,843 9,765 -9,605 WF_2 12,405’ 9,782’ -9,622’ 12,459 9,930 -9,770 WF_3 - - - 13,786 7,668 -7,508 M-32RD2 7 3.2 Lithology Details Lithology descriptions of all Kenai Group and Mesozoic rock cuttings samples started immediately after drilling out the surface conductor, then continued as per pre-set plans and procedures, and modified when directed by the Hilcorp operations geologist. The Kenai Group of Alaska’s Cook Inlet Basin, which includes the Sterling, Beluga, Tyonek, Hemlock and West Foreland Formations, was deposited by a variable-energy fluvial system within a large closed fore- arc basin. The characteristic sedimentary stratigraphy consists of dominant massive to thinly bedded sandstone and claystone-siltstone, generally abundant thin inter-beds of air fall and re-deposited volcanic ash, minor beds of basal or modal conglomerate and extensively-distributed thin beds of coal and carbonaceous rocks. Gradational upward-fining sequences and bi-modal distribution zones are abundant within sandstone sections. Note that in Canrig’s Lithology Descriptions, the special modifying term “tuffaceous” was created to address the pervasive presence and div ersity of soft -sediment volcanogenic- origin rocks in the Cook Inlet area. Though generally applied to significantly ash-rich clay-silt-sand lithologies, its wide use in descriptions may include discernible micro-shard concentrations of disaggregated volcanic glass to vitric air fall volcanic ash to smectite-bentonite clays derived from devitrified ash to rare layers of vitric ignimbrite. M-32RD2 8 3.2.1.1 Tyonek Formation The Tyonek formation is a series of alternating tuffaceous sandy siltstones, tuffaceous siltstones, sand and clay with occasional coal and carbonaceous shales. The tuffaceous siltstones are typically medium gray with pale brown and olive hues to medium dark gray with pale olive to very pale brown hues. They are easily friable to friable with a crumbly to pulverulent tenacity and often display bit curled to a rare platy cuttings habit. Typically have a dull to earthy luster with a silty to gritty texture and have a massive structure The sands are typically medium gray to medium gray with pale olive hues to yellowish brown to grayish brown. Grain size is typically lower medium to lower fine to occasionally lower coarse and trace 2-4mm grains. They are typically sub rounded to rounded to sub angular with moderate to poor sorting and are sub spherical to trace sub discoidal. The sands are typically comprised of translucent smoky gray to transparent quartz and trace lithics. Ranges from unconsolidated to easily friable to trace amounts of firm clasts. The coals are typically black to very dark gray to occasionally matte black. They display brittle to crumbly to dense tenacity with hackly to conchoidal to irregular fracture. They usually display flakey to an occasional wedge-like cuttings habit. Luster is often vitreous to earthy to slightly waxy with a matte texture. 7,209’ to 10,748' MD (-6,687' to -8,892' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 651 0.43 93.9 376 0.25 43.9 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 7,240 6,871 71 17,383 7,320 6,931 70 19,167 7,335 6,943 83 22,698 7,373 6,971 84 22,441 7,409 6,997 158 39,062 0 10 7,551 7,096 169 45,365 0 10 7,606 7,131 177 46,023 0 15 7,785 7,224 109 23,048 31 12 7,807 7,234 98 26,516 28 14 7,976 7,296 93 23,517 0 9 7,991 7,301 134 35,189 0 13 8,031 7,314 95 36,995 0 14 8,292 7,400 185 48,542 8,391 7,433 168 40,312 0 12 8,578 7,493 345 90,211 0 30 8,619 7,507 376 87,242 0 26 5 8,837 7,583 134 32,294 0 14 8,874 7,597 174 33,890 0 12 8,897 7,606 122 18,035 0 8 9,027 7,656 273 68,303 0 17 9,061 7,670 186 37,623 0 13 9,178 7,721 220 58,910 0 10 M-32RD2 9 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 9,374 7,823 113 26,837 0 11 9,403 7,840 105 19,958 0 8 9,439 7,863 355 95,704 0 29 9,554 7,942 214 50,271 0 17 9,632 8,001 207 45,590 0 14 9,648 8,014 104 25,844 0 10 9,667 8,028 84 20,356 0 10 9,685 8,043 102 24,797 33 12 9,702 8,057 80 19,047 32 11 9,801 8,142 210 45,962 0 17 9,832 8,170 143 43,063 47 20 9,914 8,244 127 31,025 0 11 9,981 8,307 100 24,073 57 16 10,092 8,414 84 16,043 207 35 10,127 8,448 201 45,759 0 13 10,201 8,521 117 29,593 0 8 10,257 8,576 164 40,997 0 12 10,276 8,595 196 47,583 0 14 10,361 8,678 240 56,852 94 24 10,380 8,697 345 92,796 356 267 43 56 12 10,522 8,836 85 18,817 517 270 43 73 15 19 10,598 8,909 142 31,040 514 94 15 24 8 10,598 10,617 8,927 133 30,884 503 151 16 30 Conglomerate Sand/Conglomerate (7220' - 7255') = medium dark gray to dark gray with brownish black secondary hues; dominantly quartz; coarse to very coarse grains, common 2-4mm pebbles; poorly sorted; very angular to sub- angular; very low to moderate sphericity; trace sandstone; trace black carbonaceous fragments. Tuffaceous Siltstone (7260 - 7290') = brownish black to olive black; hard; tough tenacity; earthy fracture; wedge- like and platy cuttings habit; earthy luster; silty texture; trace micro-thin carbonaceous laminae; trace conglomerate. Coal (7290' - 7370') = matte black to grayish black to very dark brownish black; tough to brittle tenacity; occasionally slightly crumbly; irregular to splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub- platy cuttings habit; waxy to matte luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no oil indicators. Tuffaceous Claystone / Tuffaceous Siltstone (7370'-7420') = light gray to pinkish gray; mushy, clotted, crumbly; hydrophilic, very slightly cohesive; slightly adhesive; no fracture; massive cuttings; dull, earthy luster; matte to silty texture; interbedded with tuffaceous sand/sandstone. Sand (7420'-7480') = very light gray; clast size range coarse lower to medium lower and minor fines with depth; sub- rounded; moderate developed sphericity; impacted medium grains to polished and chipped coarse grains; sub-mature; very weak siliceous cement; slight to moderate silt and clay matrix increasing with depth; silt and clay structured matrix; loosely attached; 90% quartz, 10% lithic fragments; fair to poor porosity and permeability. M-32RD2 10 Tuffaceous Claystone / Tuffaceous Siltstone (7480'-7540') = light gray to pale yellowish brown to medium gray, trace pinkish gray; mushy to clumpy to crumbly; hydrophilic, slightly cohesive to slightly adhesive; no fracture; massive cuttings habit; dull, earthy luster; matte to silty texture; often interbedded with minor coals and tuffaceous sand. Coal (7540' - 7600') = matte black to grayish black to very dark brownish gray; hard; tough to brittle tenacity; occasionally slightly crumbly; irregular to splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub- platy cuttings habit; waxy to matte luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no oil indicators; often interbedded with tuffaceous sand, siltstone and claystone. Tuffaceous Sand / Conglomerate Sand / Conglomerate Sandstone (7600' - 7690') = clear to translucent to light gray to medium gray, trace red-orange, rare trace pale green; predominantly unconsolidated; lower fine to upper very coarse grained, occasionally grading to pebbles; poorly to fairly sorted; sub- rounded to sub-angular to very angular; minor amounts light gray to light brown sandstone with slightly calcareous cement, very fine grained, subrounded to sub-angular, well sorted, interbedded with and occasionally grades to tuffaceous siltstone; occasionally interbedded with thin coal seams. Tuffaceous Claystone / Siltstone (7690' - 7760') = overall brownish gray to light to medium olive gray; crumbly to slight crunchy tenacity; irregular to earthy fracture; dominantly sub- planar to common PDC buttercurl cuttings; dull, earthy luster, occasionally sub-waxy; silty to slightly smooth clayey texture; no visible structure; non calcareous; no petroleum odor or sample fluorescence; no other oil indicators. Tuffaceous Sand / Conglomerate Sand / Conglomerate Sandstone (7760' - 7830') = clear to translucent to light gray to medium gray, trace red-orange, rare trace pale green; predominantly unconsolidated; lower fine to upper very coarse grained, occasionally grading to pebbles; poorly to fairly sorted; sub- rounded to sub-angular to very angular; minor amounts light gray to light brown sandstone with slightly calcareous cement, very fine grained, sub-rounded to sub-angular, well sorted, interbedded with and occasionally grades to tuffaceous siltstone; often interbedded with coal seams. Sand (7830' - 7900') = medium dark gray to dark gray with olive gray and brownish black secondary hues; strong salt and pepper appearance; dominantly clear to translucent quartz framework; lower medium to upper coarse grains; poor to fairly sorted; very angular to angular, and subangular; unconsolidated; common carbonaceous material; trace reddish pink, red, white, and yellow lithics; no reaction to 10% HCL in bulk sample; no sample fluorescence; no petroleum odor; no other oil indicators. Tuffaceous Siltstone (7900' - 7960') = blackish brown to olive black and olive gray; tough and brittle, occasionally crumbly tenacity; earthy fracture; wedge-like to tabular cuttings habit; dull, earthy luster; dominantly silty but common slightly gritty texture observed; trace micro thin carbonaceous laminae; no sample fluorescence; no petroleum odor; no other oil indicators. Coal (7970' - 7990') = black to brownish black; brittle to crunchy; blocky, earthy fracture; PDC disaggregated; wedge-like cuttings habit; resinous to a dull luster; matte to abrasive texture; thin structure; weak to moderate outgassing observed. Tuffaceous Siltstone (7990' - 8060') = brownish gray to olive gray and olive black; tough, brittle, and occasionally crumbly; earthy fracture; PDC aggregated; wedge-like to curved cuttings habit; dull, earthy luster; smooth, silty texture, occasionally slightly gritty; no visible structure; common thin to moderately thick coal beds throughout interval; moderate outgassing observed; no reaction to 10% HCL in sample; no visual fluorescence; no petroleum odor; no other oil indicators. M-32RD2 11 Sand / Tuffaceous Sandstone (8060' - 8130') = brownish gray to medium dark gray and olive gray with traces of yellowish gray; clear to translucent quartz framework; lower fine to upper coarse grains; very poor to poorly sorted; angular to subangular, commonly very angular; very low to moderate sphericity; unconsolidated; common black carbonaceous fragments; trace reddish orange and pinkish red lithics; grayish yellow to off white tuffaceous sandstone; upper very fine to upper medium grains; moderate to well sorted; subangular to subrounded; moderate to high sphericity; weak reaction to 10% HCL in crushed sample; no visual fluorescence; no petroleum odor; no other oil indicators. Tuffaceous Siltstone (8130' - 8240') = medium gray to medium dark gray with olive gray and brownish gray secondary hues; brittle tenacity; earthy fracture; PDC disaggregated; wedge-like to tabular and platy; dull, earthy and often waxy luster; silty to slightly gritty texture; no visible structure; non calcareous; trace coal in sample; no out- gassing observed; no sample fluorescence; no petroleum odor; no other hydrocarbon indicators. Tuffaceous Sandstone (8240' - 8300') = light olive gray to olive gray and brownish gray; clear to translucent quartz framework; upper very fine to upper fine grains; moderate to well sorted; angular to subangular; moderate to low sphericity; firm friable to moderately hard; calcite cement; tuffaceous matrix support; floating contact fabric; trace suspended carbonaceous fragments; common coal beds throughout interval; moderate to high outgassing observed; strong reaction to 10% HCL; no sample fluorescence; no petroleum odor; no other hydrocarbon indicators. Tuffaceous Siltstone (8300' - 8400') = olive black to olive gray and brownish black; brittle and tough; earthy fracture; PDC disaggregated; wedge-like to curved, and platy cuttings habit; dull, earthy luster; silty to slightly gritty and abrasive texture; trace carbonaceous fragments in sample; trace micro thin black carbonaceous laminae; no reaction to 10% HCL in bulk sample; no sample fluorescence; no petroleum odor; no other hydrocarbon indicators. Tuffaceous Siltstone / claystone (8400' - 8490') = medium dark gray to brownish gray to grayish black; soft to moderate to semi-poor induration; crumbly to semi-brittle to semi-tough; irregular to earthy to blocky to planar fracture; tabular to platy cuttings habit; dull to waxy luster; silty to gritty texture; traces of unconsolidated very coarse sand to very easily friable sandstone, lower medium to upper coarse, occasional upper fine to lower very coarse, poorly to moderately sorted, sub-angular to sub-rounded, sub- spherical to sub-discoidal, quartz dominated, dark lithics common, no hydrocarbon indicators. Tuffaceous Sandstone (8490' - 8570') = light olive gray to olive gray to brownish gray; clear to translucent quartz framework; upper very fine to upper fine grained; moderate to well sorted; angular to sub-angular to sub-rounded; moderate to low sphericity; firm friable to moderately hard; calcite cement; tuffaceous matrix support; floating contact fabric; trace suspended carbonaceous fragments; common coal beds throughout interval; moderate to high outgassing observed; slight reaction to 10% HCL; no sample fluorescence; no petroleum odor; no other hydrocarbon indicators. Coal (8570'-8620') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub-platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no other oil indicators. Tuffaceous Sandstone (8620' - 8700') = light olive gray to olive gray to brownish gray; clear to translucent quartz framework; upper very fine to upper fine grained; moderate to well sorted; angular to sub-angular to sub-rounded; moderate to low sphericity; firm friable to moderately hard; calcite cement; tuffaceous matrix support; trace black carbonaceous material scattered through -out sample; often interbedded with thin coal seams; moderate to high outgassing observed; slight reaction to 10% HCL; no sample fluorescence; no petroleum odor; no hydrocarbon indicators. M-32RD2 12 Tuffaceous Siltstone / Claystone (8700' - 8800') = medium dark gray to brownish gray to grayish black; soft to moderate to semi-poor induration; soft to crumbly to semi-brittle to semi-tough; irregular to earthy to blocky to planar fracture; tabular to platy cuttings habit; dull to waxy luster; silty to slightly gritty to gritty texture; traces of unconsolidated very coarse sand to very easily friable sandstone, lower medium to upper coarse, occasional upper fine to lower very coarse, poorly to moderately sorted, angular to sub- angular to sub-rounded, sub-spherical to sub-discoidal, quartz dominated, dark lithics common, no oil indicators. Coal / Carbonaceous Shale (8800' - 8860') = predominantly black to brownish black to grayish black; mottled dark yellowish brown carbon clays in micro-laminations; firm in coals to soft in clays; resinous, mottled earthy luster; hackly coal fracture to sub-planar shale fracture; composed of sub- bituminous to lignitic coal with micro- laminae of very carbonaceous clay; no oil odor, fluorescence or other oil indicators. Tuffaceous Siltstone / Claystone (8860' - 8950') = medium dark gray to brownish gray to grayish black; soft to moderate to semi-poor induration; crumbly to semi-brittle to semi-tough; irregular to earthy to blocky to planar fracture; tabular to platy cuttings habit; dull to waxy luster; silty to gritty texture; traces of unconsolidated very coarse sand to very easily friable sandstone, lower medium to upper coarse, occasional upper fine to lower very coarse grained, poorly to moderately sorted, sub-angular to sub- rounded, sub-spherical to sub-discoidal, quartz dominated, dark lithics common, no oil indicators. Sand /Tuffaceous Sandstone (8950'- 8880') = pale yellow-brown to light gray to medium gray; predominantly clear to smoky colored quartz with lesser black, pink, light blue, and brown lithic fragments; upper fine to lower coarse grained, with trace upper coarse grains; poor to fair sorting; angular to sub- angular to sub-rounded; moderate sphericity; trace to common larger rounded black and tan clasts of fine to medium grained sandstone; minor medium gray sub-angular clasts of tuffaceous siltstone; very minor coal fragments and individual grains of bit broken quartz up to granule conglomerate sized; no hydrocarbon indicators. Coal (9030' - 9060') = crumbly to crunchy; irregular fracture; PDC bit aggregated; fine cuttings; flaky scaly, tabular and wedge-like cuttings habit; dull luster; matte and abrasive texture; thick structure; moderate outgassing observed. Tuffaceous Siltstone / Claystone (9060' - 9170') = olive gray to brownish gray and brownish black; tough and brittle to crumbly tenacity; earthy fracture; PDC disaggregated; tabular to wedge-like and often platy; dull to a waxy luster; observed in firm samples; smooth and silty, occasionally gritty and abrasive textures; trace to common micro thin carbonaceous laminae and suspended fragments; brownish gray tuffaceous claystone; pasty consistency; pulverulent to crumbly tenacity; earthy fracture; wedge-like cuttings habit; greasy luster; clayey to silty texture; no reaction to 10% HCL in bulk sample; no visual fluorescence; no petroleum odor; no other hydrocarbon indicators. Tuffaceous Sandstone (9180' - 9230') = olive gray to brownish gray with olive black secondary hues; quartz frame- work; lower very fine to lower fine sand grains; well sorted; subangular to subrounded; moderate to high sphericity; firm friable to moderately hard, occasionally easily friable; calcite cement; tuffaceous matrix; floating con- tact; trace suspended carbonaceous fragments; trace medium gray to brownish gray sandstone; fine grained; well sorted; subangular to subrounded; high sphericity; moderately hard; grain support; calcareous; common coal beds throughout interval; moderate outgassing; no visual fluorescence; no petroleum odor; no other hydrocarbon indicators. Sand (9230' - 9340') = brownish gray to brownish black with olive gray secondary hues; clear to translucent quartz framework; weak salt and pepper appearance; upper fine to lower coarse, trace upper coarse grains; moderately sorted; subrounded to subangular; moderate to high sphericity; unconsolidated sand grains; trace carbonaceous material; trace pink, reddish orange, and grayish purple lithics; no visual sample fluorescence; no petroleum odor; no other hydrocarbon indicators. M-32RD2 13 Tuffaceous Siltstone (9340' - 9400') = medium dark gray to dark gray with olive gray and brownish black secondary hues; PDC bit disaggregated; brittle to crumbly tenacity; irregular, earthy fracture; wedge-like, platy, and often curled cuttings habit; dull, earthy luster; silty to a slightly gritty texture; common micro thin carbonaceous laminae; common thin coal beds throughout interval; weak outgassing observed; no visual fluorescence; no petroleum odor; no other hydrocarbon indicators. Coal (9400' - 9440') = black to brownish black; brittle to crunchy tenacity; irregular fracture; flaky, tabular to wedge-like cuttings habit; dull luster; matte and abrasive textures, occasion- al smooth faces; thin structure; weak to moderate outgassing observed. Tuffaceous Sandstone (9440' - 9520') = dark gray to brownish gray and brownish black; clear to translucent quartz framework; lower fine to lower medium sand grains; well to very well sorted; subangular to subrounded; moderate to high sphericity; friable to firm friable; clay mineral cement; tuffaceous matrix; floating and point contact fabric observed, occasionally long contact; trace suspended carbonaceous fragments; non calcareous; no visual fluorescence; no petroleum odor; no other hydrocarbon indicators. Sand (9530' - 9600') = medium dark gray to dark gray with brownish black secondary hues; strong salt and pepper appearance; clear to translucent quartz framework; lower very fine to lower coarse grains; poor to moderately sorted; subangular to subrounded; moderate to high sphericity; common black carbonaceous fragments free in sample; trace orange, red, and grayish purple lithics; no reaction to 10% HCL in bulk sample; no fluorescence; no petroleum odor; no other hydrocarbon indicators. Coal (9630' - 9650') = black; brittle to crunchy tenacity; blocky, irregular fracture; wedge-like cuttings habit; resinous luster; smooth to matte texture; thin structure; mild outgassing observed. Tuffaceous Siltstone (9650' - 9720') = dark gray to medium dark gray with brownish black secondary hues; brittle, occasionally crumbly tenacity; PDC disaggregated; tabular, wedge-like, platy and often curved cuttings habit; dull, earthy luster; smooth and silty to slightly gritty and abrasive texture; trace black carbonaceous laminae; common thin to moderately thick coal throughout interval; mild outgassing; no reaction to 10% HCL in bulk sample; no visual fluorescence; no petroleum odor; no other hydrocarbon indicators. Tuffaceous Siltstone (9720' - 9800') = olive gray to brownish gray and brownish black with dark gray secondary hues; clear to translucent quartz framework; upper very fine to lower medium grains; well sorted; subangular to subrounded; moderate sphericity; PDC disaggregated; firm friable; clay mineral cement; tuffaceous matrix support; suspended and trace point contact observed; common suspended carbonaceous fragments; trace conglomerates grading to 3mm; non-calcareous; no oil odor; no oil indicators over oil based mud. Coal (9800' - 9840') = black; brittle to crunchy tenacity; blocky, irregular fracture; wedge-like cuttings habit; resinous luster; smooth to matte texture; thin structure; mild outgassing observed. Sand (9840'-9910') = tan to medium gray sand rich in clear quartz with lesser milky feldspar and black, pink, and blue lithics; lower medium to upper very coarse grained with a few conglomerate clasts; fair sorting; angular to sub- rounded; with small clusters of fine to medium-grained tuffaceous sandstone and larger fragile clumps of tuffaceous claystone and siltstone; non-calcareous; no oil odor; no hydrocarbon indicators over oil based mud. M-32RD2 14 Tuffaceous Sandstone (9910' - 10010') = pale yellow-orange to pale yellow brown with some dusky yellow to light olive brown; friable to easily friable to unconsolidated; lower coarse to very fine grained, trace to common very coarse to 2-3mm quartz grains; poorly sorted; round to sub-rounded to sub- angular to angular; sub-spherical to sub-discoidal; individual grains transparent to translucent, polished to frosted surface abrasion; predominantly matrix supported with some grain supported; tuffaceous matrix; non-calcareous; carbonaceous sediment and dark lithics are common; interbedded with siltstone; also occasionally interbedded with claystone; often interbedded with thin coal seams; no hydrocarbon indicators over oil based mud. Tuffaceous Siltstone (10010'-10080') = medium light gray to light bluish gray; stiff; crumbly; blocky to earthy fracture; massive cuttings habit; dull, earthy luster; gritty sucrosic texture; thinly bedded with ashy clay, and thin sand lenses; locally pale brown to grayish red carbonaceous siltstone; slightly to moderately calcareous; no oil odor, fluorescence or other oil indicators; often interbedded with thin coal seams. Note: 10% - 20% off white ash observed in 10080' sample. Tuffaceous Siltstone (10120' - 10240') = olive gray to olive black and brownish gray to brownish black; clear to opaque quartz framework; upper very fine to upper medium sand grains; poor to moderately sorted; subangular to sub- rounded, trace angular; moderate to high sphericity; firm friable to moderately hard; clay mineral cement; tuffaceous matrix support; floating fabric; trace carbonaceous fragments suspended; common thin coals throughout interval; weak outgassing observed; no reaction to 10% HCL in bulk sample; no visual fluorescence; no petroleum odor; no other hydrocarbon indicators. Tuffaceous Sandstone / Sand (10240' - 10330') = pale yellow-orange to pale yellow brown with some dusky yellow to light olive brown; friable to easily friable to unconsolidated; lower coarse to very fine grained, trace to scattered very coarse to 2-3mm quartz grains; poorly sorted; round to sub-rounded to sub-angular to angular; sub-spherical to sub-discoidal; individual grains trans- parent to translucent, polished to frosted surface abrasion; predominantly matrix supported with some grain supported; tuffaceous matrix; non-calcareous; carbonaceous sediment and dark lithics are common; interbedded with siltstone and/or carbonaceous shale; often interbedded with coal seams; no hydrocarbon indicators over oil based drilling fluid. Coal (10330'-10390') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub-platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no other oil indicators. Note: Coal 39 was from 10,347’ to 10,363’ MD (-8,505’ to -8,520’ TVDSS) Tuffaceous Sandstone / Sand (10390' - 10490') = light gray to light brownish gray, some pale yellow- orange and light olive brown; friable to easily friable to unconsolidated; lower coarse to very fine grained, trace to scattered very coarse to 2-3mm quartz grains; poorly sorted; rounded to sub-rounded to sub- angular to angular; sub-spherical to sub-discoidal; individual grains trans- parent to translucent, polished to frosted surface abrasion; predominantly matrix supported with some grain supported; tuffaceous matrix; very slightly calcareous; carbonaceous sediment and dark lithics are common; interbedded with and occasionally grades to tuffaceous; siltstone; often interbedded with carbonaceous shale; often interbedded with coal seams; no hydrocarbon indicators over oil based mud. Tuffaceous Siltstone (10490' - 10580') = olive gray to olive black and brownish gray to brownish black; clear to opaque quartz framework; upper very fine to upper medium sand grains; poor to moderately sorted; subangular to sub-rounded, trace angular; moderate to high sphericity; firm friable to moderately hard; clay mineral cement; tuffaceous matrix support; floating fabric; trace carbonaceous fragments suspended; common thin coals throughout interval; weak outgassing observed; very slightly calcareous; no visual fluorescence; no petroleum odor; no other hydro- carbon indicators over oil based mud. M-32RD2 15 Coal (10580'-10640') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub-platy cuttings habit; greasy to waxy luster; earthy to abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence over oil based mud; no other hydrocarbon indicators. Carbonaceous Shale (10640' - 10700') = black to brownish black to brownish gray; fine disseminated carbonaceous material interbedded in shale; shale grades to and interbedded with a less indurated carbonaceous claystone/ siltstone; moderate to low density; crumbly to firm friable; tabular to platy to massive cuttings habit; often massive PDC bit buttercurl cuttings present; dull luster; matte texture; non- calcareous; no hydrocarbon indicators over oil based mud. Tuffaceous Sandstone / Conglomerate Sand / Tuffaceous Sand (10700' - 10780') = light gray, olive gray, som e pink and pale yellow-orange; medium to coarse grained with some scattered very coarse; sub-angular to sub-rounded; minor bit broken grains/pebbles; poorly to moderately sorted; interbedded and grading to a light brown tuffaceous siltstone; slightly calcareous; scattered firm sandstone clusters which produce moderate bright yellow streaming and cut fluorescence; no other indicators over oil based drilling fluid. M-32RD2 16 3.2.1.2 Hemlock Formation The Hemlock formation is comprised mainly of conglomeratic and tuffaceous sandstone with occasional tuffaceous siltstones and trace coal beds. The tuffaceous sandstones are often medium gray to medium dark gray with a slight light olive gray to olive gray. Grain size is typically lower fine to upper fine with occasional coarse grading to lower medium to upper medium and occasional coarse grained. Often spherical to sub discoidal with sub rounded to rounded, rare sub angular grains. Typically well to moderately well sorted and often friable or unconsolidated. Overall the clasts have a tuffaceous matrix and are grain supported. They appear to be texturally sub mature to immature and dominated by translucent or transparent quartz with pitted or etched facies. Mafic and green lithics are also semi common. The conglomeratic sands observed are typically medium dark gray to medium gray with pale olive to moderate brown to black secondary hues. They are unconsolidated to easily friable with lower medium to upper fine grains and 3-5mm bit broken quartz grains being semi common. Often display poor to moderate sorting, sub angular to sub rounded to angular with sub spherical to trace sub discoidal sphericity. The tuffaceous siltstones can often grade to a sandy siltstone and are typically poorly indurated. Overall tenacity ranges from crumbly to brittle with an irregular to earthy fracture. Cuttings are commonly “bit stacked to slightly tabular with a dull to earthy luster and a silty to gritty texture. Carbonaceous banding is common but not abundant. 3.2.1.3 Hemlock H1X_FW 10,748’ to 10,783' MD (-8,892' to -8,924' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 271 19 149 43 11 26 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Tuffaceous Sandstone / Conglomerate Sand / Tuffaceous Sand (10700' - 10780') = light gray, olive gray, some pink and pale yellow-orange; medium to coarse grained with some scattered very coarse; sub-angular to sub-rounded; minor bit broken grains/pebbles; poorly to moderately sorted; interbedded and grading to a light brown tuffaceous siltstone; slightly calcareous; scattered firm sandstone clusters which produce moderate bright yellow streaming and cut fluorescence; no other indicators over oil based drilling fluid. Sand (10780'-10920') = light gray to olive gray quartz rich sand with lesser black lithics; lower medium to lower very coarse grained with occasional grains up to granule sized; very poor to fair sorting; angular to rounded; low to medium to high sphericity, with larger sub-rounded nodules of consolidated salt-and- pepper tuffaceous sandstone, which is fine to medium grained, and sub-angular fragments of tuffaceous siltstone often showing black/brown fine planar laminations of carbonaceous material; often interbedded with thin coal seams; trace to 5% dull yellow sample fluorescence over oil based mud; trace moderately dull yellow cut fluorescence. Note: Coal 59 was from 10,777’ to 10,783’ MD (-8,919’ to -8,924’ TVDSS) M-32RD2 17 3.2.1.4 Hemlock HTKE-FW 10,783’ to 10,815' MD (-8,924' to -8,953' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 174 2 62 32 16 20 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand (10780'-10920') = light gray to olive gray quartz rich sand with lesser black lithics; lower medium to lower very coarse grained with occasional grains up to granule sized; very poor to fair sorting; angular to rounded; low to medium to high sphericity, with larger sub-rounded nodules of consolidated salt-and- pepper tuffaceous sandstone, which is fine to medium grained, and sub-angular fragments of tuffaceous siltstone often showing black/brown fine planar laminations of carbonaceous material; often interbedded with thin coal seams; trace to 5% dull yellow sample fluorescence over oil based mud; trace moderately dull yellow cut fluorescence. 3.2.1.5 Hemlock HK2T 10,815’ to 10,871' MD (-8,953' to -9,003' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 223 2 72 45 7 29 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand (10780'-10920') = light gray to olive gray quartz rich sand with lesser black lithics; lower medium to lower very coarse grained with occasional grains up to granule sized; very poor to fair sorting; angular to rounded; low to medium to high sphericity, with larger sub-rounded nodules of consolidated salt-and- pepper tuffaceous sandstone, which is fine to medium grained, and sub-angular fragments of tuffaceous siltstone often showing black/brown fine planar laminations of carbonaceous material; often interbedded with thin coal seams; trace to 5% dull yellow sample fluorescence over oil based mud; trace moderately dull yellow cut fluorescence. M-32RD2 18 3.2.1.6 Hemlock HK2T_LOWER 10,871’ to 10,988' MD (-9,003' to -9,101' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 717 1 92 53 10 33 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand (10780'-10920') = light gray to olive gray quartz rich sand with lesser black lithics; lower medium to lower very coarse grained with occasional grains up to granule sized; very poor to fair sorting; angular to rounded; low to medium to high sphericity, with larger sub-rounded nodules of consolidated salt-and- pepper tuffaceous sandstone, which is fine to medium grained, and sub-angular fragments of tuffaceous siltstone often showing black/brown fine planar laminations of carbonaceous material; often interbedded with thin coal seams; trace to 5% dull yellow sample fluorescence over oil based mud; trace moderately dull yellow cut fluorescence. Sand (10920' - 11000') = olive gray to brownish gray and brownish black; clear to translucent and opaque quartz framework; upper fine to lower coarse grains; moderate to well sorted; sub- angular to subrounded, trace angular; moderate to high sphericity; unconsolidated sand grains; common carbonaceous material in sample; trace hard reddish orange and orange lithics; no petroleum odor over oil based mud; trace, very weak, very pale yellow sample fluorescence; very pale yellow, very weak, very slow cut sample fluorescence; weak, pale yellow residual cut; pale straw visible cut. 3.2.1.7 Hemlock HK3T 10,988’ to 11,124' MD (-9,101' to -9,198' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 269 1 65 67 14 30 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Tuffaceous Sandstone (11000' - 11050') = olive gray to olive black and brownish gray to brownish black; clear to trans- lucent and opaque quartz framework; upper fine to lower medium grains; moderately sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; friable to firm friable, often easily friable; tuffaceous matrix; floating to point contact fabric; no odor above oil based mud; trace, weak to moderate, pale yellow fluorescence; slow to moderately fast pale yellow sample cut fluorescence; weak, light yellow residual cut; clear to pale straw visible cut ring; other hydrocarbon indicators possibly masked by oil based mud. ‘ Sand / Tuffaceous Sandstone (11100' - 11200') = brownish black to olive black; quartz framework; upper fine to lower coarse grains; poor to moderately sorted; subangular to subrounded; moderate to high sphericity; unconsolidated sand grains; tuffaceous sandstone; friable to firm friable; clay mineral cement; tuffaceous matrix; floating fabric; common black carbonaceous fragments suspended in sample; non calcareous; no reaction to 10% HCL in bulk sample; no petroleum odor above oil based mud; trace, weak to moderate, pale yellow sample fluorescence; slow to moderately fast, weak to moderate, pale to light yellow sample cut fluorescence; pale to light yellow residual visual cut; clear to pale straw visible cut. M-32RD2 19 3.2.1.8 Hemlock HK4T 11,124’ to 11,239' MD (-9,198' to -9,265' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 299 2 38 34 9 23 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand / Tuffaceous Sandstone (11100' - 11200') = brownish black to olive black; quartz framework; upper fine to lower coarse grains; poor to moderately sorted; subangular to subrounded; moderate to high sphericity; unconsolidated sand grains; tuffaceous sandstone; friable to firm friable; clay mineral cement; tuffaceous matrix; floating fabric; common black carbonaceous fragments suspended in sample; non calcareous; no reaction to 10% HCL in bulk sample; no petroleum odor above oil based mud; trace, weak to moderate, pale yellow sample fluorescence; slow to moderately fast, weak to moderate, pale to light yellow sample cut fluorescence; pale to light yellow residual visual cut; clear to pale straw visible cut. 3.2.1.9 Hemlock HK5T 11,239’ to 11,497' MD (-9,265' to -9,382 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 429 1 50 59 14 29 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand (11250' - 11360') = olive gray to brownish gray and brownish black; dominantly clear and translucent quartz; upper fine to lower coarse, trace 1-3mm pebbles observed; poor to moderately sorted; dominantly angular to subangular, often subrounded; low to moderate sphericity; unconsolidated sand grains; trace red, reddish orange, white, green, and grayish purple lithics; common hard black carbonaceous fragments; strong reaction to 10% HCL in bulk sample with tuffaceous sandstone; no petroleum odor above oil based mud; trace, weak, light yellow to orange sample fluorescence; slow to very slow, weak, pale yellow cut sample fluorescence; weak very pale yellow residual cut; clear to pale straw visi ble cut; other hydrocarbon indicators possibly masked by oil based mud. Tuffaceous Sandstone / Conglomerate Sand / Sand (11360' - 11500') = olive gray to brownish gray and brownish black; dominantly clear and translucent quartz; upper fine to lower coarse, trace 1-3mm pebbles observed; poor to moderately sorted; dominantly angular to sub-angular, often sub-rounded; low to moderate sphericity; often unconsolidated sand grains; trace red, reddish orange, white and green and grayish purple lithics; common hard black carbonaceous fragments; strong reaction to 10% HCL in bulk sample with tuffaceous sandstone; no petroleum odor above oil based mud; trace, weak, light yellow to orange sample fluorescence; slow to very slow, weak, pale yellow cut sample fluorescence; weak very pale yellow residual cut; clear to pale straw visible cut; other hydrocarbon indicators possibly masked by oil based drilling fluid. M-32RD2 20 3.2.1.10 Hemlock HK6T 11,497’ to 11,719' MD (-9,382' to -9,454 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maxim um Minimum Average Maximum Minimum Average 255 1 58 109 9 39 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,674 9,599 109 23,900 1,086 285 34 62 12 36 Tuffaceous Sandstone / Conglomerate Sand / Sand (11500' - 11620') = olive gray to brownish gray and brownish black to light greenish gray with trace red/pink; dominantly clear and translucent quartz; upper fine to lower coarse, trace 1-3mm pebbles observed; poor to moderately sorted; dominantly angular to sub-angular, often sub-rounded; low to moderate sphericity; often unconsolidated sand grains; trace red, reddish orange, white ,green, and grayish purple lithics; common hard black carbonaceous fragments; strong reaction to 10% HCL in bulk sample with tuffaceous sandstone; no petroleum odor above oil based mud; trace, weak, light yellow to orange sample fluorescence; slow to very slow, weak, pale yellow cut sample fluorescence; weak very pale yellow residual cut; clear to pale straw visible cut; other hydrocarbon indicators possibly masked by oil based mud. Coal (11660' - 11700') = black to brownish black; moderately hard to hard; brittle to crunchy; irregular to blocky fracture; PDC disaggregated; wedgelike, tabular, and bladed cuttings habit; dull to resinous luster; trace smooth but dominantly matte and abrasive textures; thin structure; weak to moderate out- gassing observed. 3.2.1.11 Hemlock HK7T 11,719’ to 11,843' MD (-9,454' to -9,488 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 465 1 105 83 10 38 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,734 9,618 82 17,280 819 492 55 137 31 44 Sand / Tuffaceous Sandstone (11700' - 11800') = brownish gray to brownish black and dark gray; clear and translucent to opaque quartz framework; strong salt and pepper appearance; upper very fine to lower coarse grain size, trace 1-2mm pebbles; poor to moderately sorted; dominantly subangular to subrounded, but also well to very well rounded and angular to very angular; poor to moderate and high sphericity throughout; unconsolidated sand grains; common black carbonaceous material; trace orange, amber, yellow, and red lithics; brownish gray to brownish black tuffaceous sandstone; find to course grained; poorly sorted; subangular to subrounded; moderate sphericity; firm friable; calcite cement; tuffaceous matrix; floating grain fabric; trace suspended black carbonaceous fragments; severe reaction to 10% HCL; no petroleum odor; trace to spotty, very weak, pale yellow sample fluorescence; very slow, very weak, very pale yellow sample cut fluorescence; pale yellow and weak residual cut; straw to amber visible cut. M-32RD2 21 3.2.1.12 West Foreland Formation The West Foreland formation is comprised mainly of tuffaceous sand, tuffaceous sandstone, and tuffaceous siltstones and occasional tuffaceous claystone and coal beds. The tuffaceous sand/sandstones are medium gray to pale yellowish brown to light olive gray, with lesser white to buff -colored feldspar and black lithic constituents; upper fine to medium to lower coarse grained, with occasional very coarse grains; poor to fair sorting; angular to sub-angular to sub-rounded to rounded; moderate to high sphericity; often interbedded with tuffaceous siltstone/claystone, sometimes micro- laminated; often interbedded with thin coals and carbonaceous shale. The tuffaceous siltstones are light olive gray to pale yellowish brown, also light olive gray to medium gray; they often contain platy and fissile fragments of tuffaceous siltstone and smaller milky pale grains of tuffaceous claystone; occasional clasts of fine to medium grained tuffaceous sandstone and minor coal pieces; a few sub-angular fine to medium sized clear to light blue quartz sand grains; often interbedded with tuffaceous claystone, tuffaceous sandstone, loose sand, and occasional coals and carbonaceous shale. 3.2.1.13 West Foreland H1X_FW 11,843’ to 12,469' MD (-9,488' to -9,605 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 541 1 77 82 16 32 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,963 9,676 76 15,468 653 422 54 132 32 39 12,017 9,687 82 16,488 792 467 63 147 36 46 Tuffaceous Siltstone (11800 - 11860') = olive gray to brownish gray and brownish black; dense and crumbly; earthy fracture; PDC disaggregated; fine cuttings; tabular to platy cuttings habit; dull, earthy luster; smooth to silty texture; thin structure; bedded with tuffaceous sandstone and sand; no reaction to 10% HCL; strong reaction to 10% HCL in bulk sample. Sand (11860' - 11970') = olive gray to brownish gray to brownish black with dark gray secondary hues; clear to translucent quartz framework; strong salt and pepper appearance; upper very fine to upper medium grains, common lower coarse grains; very trace 1-2mm pebbles; poor to moderately sorted; subangular to subrounded, trace to common angular to very angular; moderate to high sphericity; unconsolidated sand grains; mild to strong reaction to 10% HCL in bulk sample; no petroleum odor; trace, very weak, very pale yellow sample fluorescence; slow to moderately fast, pale yellow to pale orange; sample cut fluorescence; moderate to weak light yellow, residual cut; clear to pale straw visible cut; other hydrocarbon indicators possibly masked by oil based mud. Tuffaceous Sandstone (11970' - 12080') = olive gray to brownish gray and brownish black; clear to translucent and opaque quartz framework; upper very fine to upper fine grains, trace medium grains; moderate to well sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix support; floating grain fabric; no reaction to 10% HCL on crushed sample; no petroleum odor above oil based mud; trace, very weak, pale yellow sample fluorescence; slow, weak to moderate, light yellow sample cut fluorescence; moderate to strong, bright yellow to yellow residual cut; straw to amber visible cut. M-32RD2 22 Tuffaceous Sandstone (12080' - 12190') = olive gray to brownish gray and brownish black, with some red and reddish orange; clear to translucent and opaque quartz framework; upper very fine to upper fine grains, trace medium grains, rare trace lower very coarse grains; poorly to moderately sorted; sub-angular to sub- rounded; moderate to high sphericity; PDC bit disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix support; floating grain fabric; no reaction to 10% HCL on crushed sample; no petroleum odor above oil based mud; trace, very weak, pale yellow sample fluorescence; moderate light yellow sample cut fluorescence increasing with depth; moderate to strong, bright yellow to yellow residual cut; straw to amber visible cut. Tuffaceous Sandstone (12190' - 12300') = olive gray to brownish gray and brownish black, red and red- orange, trace bluish green; clear to translucent quartz framework; upper very fine to upper fine grains, trace medium grains, rare trace lower very coarse grains; poorly to moderately sorted; sub-angular to sub- rounded; moderate to high sphericity; PDC bit disaggregated; friable to firm friable; clay mineral cement; occasionally inter-bed with siltstone; tuffaceous matrix support; floating grain fabric; no reaction to 10% HCL on crushed sample; no petroleum odor above oil based mud; trace, very weak, pale yellow sample fluorescence; moderate to faint light yellow sample cut fluorescence decreasing with depth; moderate to strong, bright yellow to yellow residual cut; straw to amber visible cut. Tuffaceous Sandstone (12300' - 12400') = olive gray to brownish gray and brownish black; clear and translucent to opaque quartz framework; moderate to weak salt and pepper appearance; lower fine to lower coarse grains; moderately sorted; subangular to subrounded; moderate to high sphericity; friable to firm friable; clay mineral cement; floating grain fabric; common black carbonaceous material; trace amber, green, red, orange, and yellow lithics; no petroleum odor over oil based mud; trace, very weak, very pale yellow sample fluorescence; very slow, very weak, very pale yellow sample cut fluorescence; very weak, very pale residual cut; clear to pale straw visible cut. 3.2.1.14 West Foreland WF_2 12,469’ to 13,786' MD (-9,605' to -9,770 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 645 1 108 82 10 32 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 12,645 9,786 79 18,095 774 457 98 129 37 32 12,764 9,800 77 15,305 712 360 81 103 36 36 12,869 9,812 81 16,292 997 342 90 104 30 42 Carbonaceous Shale / Tuffaceous Siltstone / Claystone (12400' - 12490') = medium brown tuffaceous siltstone medium brown tuffaceous claystone and many intermediate brownish black colors; dominantly slightly to moderately hard, but ranges to almost soft; irregular to platy cuttings habit; hackly to splintery fracture; laminated with a brittle, moderately tough black coal; smooth to dense matte to earthy to silty texture; resinous to dull luster; no petroleum odor; no other hydro- carbon indicators over oil based mud. Tuffaceous Sandstone (12490' - 12570') = olive gray to brownish gray and brownish black; clear and translucent to opaque quartz framework; moderate to weak salt and pepper appearance; lower fine to lower coarse grains; moderately sorted; subangular to subrounded; moderate to high sphericity; friable to firm friable; clay mineral cement; floating grain fabric; common black carbonaceous material; trace amber, green, red, orange, and yellow lithics; no petroleum odor over oil based mud; no fluorescence over oil based mud. M-32RD2 23 Sand (12570' - 12660') = brownish gray to brownish black with olive gray secondary hues; dominantly clear to translucent quartz framework; upper fine to lower quartz grains; moderate to well sorted; subangular to sub- rounded, trace very angular to angular; dominantly high to moderate sphericity, trace poor sphericity; unconsolidated sand grains; common carbonaceous fragments; trace orange and red lithics; trace 1mm pebbles; no petroleum odor over oil based mud; trace to spotty, moderate to weak, pale yellow sample fluorescence; very slow to slow, very weak, very pale yellow sample cut fluorescence; moderate, bright yellow residual visual cut; straw to amber visible cut. Tuffaceous Sandstone (12660' - 12770') = brownish gray to brownish black with olive gray and olive black secondary hues; clear to translucent and opaque framework; lower fine to upper coarse; moderate to well sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; friable to firm friable, sometimes easily friable; clay mineral cement trace calcite cement; tuffaceous matrix support; floating to point contact fabric; trace suspended black to brownish black carbonaceous fragments; no petroleum odor over oil based mud; grading from scattered trace through- out, moderate to weak pale yellow to yellow sample fluorescence; fast to very slow, light yellow to bright yellow sample cut fluorescence; very pale yellow residual cut; pale straw to straw visible cut; other hydrocarbon indicators possibly masked by oil based mud. Sand (12770' - 12860') = brownish gray to brownish black with olive gray and olive black secondary hues; dominantly clear and translucent quartz framework; upper fine to lower coarse grains; moderate to well sorted; angular to subangular, but also subrounded; low to moderate sphericity; unconsolidated; common black carbonaceous material throughout sample; trace reddish orange lithics; no petroleum odor over oil based mud; trace to spotty, weak, very pale yellow sample fluorescence; mostly very slow, but trace fast, moderate to weak, light to pale yellow sample cut fluorescence; straw to amber visible cut; other hydro- carbon indicators possibly masked by oil based mud. Tuffaceous Sandstone (12860' - 12980') = brownish gray to brownish black with medium dark gray and dark gray secondary hues; clear and translucent dominant framework; lower fine to lower medium grains sizes; well sorted; angular to subangular; moderate to high sphericity; firm friable to friable; clay mineral cement; tuffaceous matrix support; floating and point contact fabric; trace black carbonaceous material suspended; trace medium gray, hard sandstone in sample; trace to moderate reaction to 10% HCL in bulk sample; no petroleum odor; trace to spotty, very pale yellow sample fluorescence; slow, moderate to very weak, very pale to pale yellow sample fluorescence; weak to very weak light yellow residual cut; pale straw to amber visible cut; other hydrocarbon indicators possibly masked by oil based mud. Sand (12980' - 13100') = olive gray to brownish gray and brownish black to dark gray; clear, transparent, and trace opaque quartz framework; upper very fine to upper coarse; poor to moderately sorted; dominantly angular to sub- angular, common subrounded; moderate to high sphericity, larger grains with poor to very poor sphericity; unconsolidated sand grains; common black carbonaceous material; trace reddish orange, pink, amber, and orange lithics; very trace 1mm pebbles; no reaction to 10% HCL in bulk sample; no petroleum odor; trace to spotty, very weak, very pale yellow sample fluorescence; very slow to slow, moderate to weak, pale yellow sample cut fluorescence; pale straw to clear visible cut; other hydrocarbon indicators possibly masked by oil based mud. Tuffaceous Sandstone (13100' - 13220') = brownish gray to brownish black with olive gray and dark gray secondary hues; clear to translucent quartz framework; upper fine to lower very fine grains; well to very well sorted; subangular to subrounded; moderate to high sphericity; PDC disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix; floating and point contact fabric observed; common black carbonaceous material; trace orange lithics; no petroleum odor over oil base mud; trace to spotty, pale yellow to slightly orange sample fluorescence; very slow to slow, moderate to very weak, very pale yellow to pale orange, sample cut fluorescence; moderate to very weak, very pale yellow residual visual cut; pale straw to amber and trace dark brown visible cut; other possible hydrocarbon indicators masked by oil based mud. M-32RD2 24 Sand (13220' - 13330') = olive gray to brownish gray and brownish black to dark gray; clear, transparent, and trace opaque quartz framework; upper very fine to upper coarse; poor to moderately sorted; dominantly angular to sub-angular, common sub-rounded; moderate to high sphericity, larger grains with poor to very poor sphericity; unconsolidated sand grains; common black carbonaceous material; trace reddish orange, pink, amber, and orange lithics; very trace 1mm pebbles; no reaction to 10% HCL in bulk sample; no petroleum odor; trace to spotty, very weak, very pale yellow sample fluorescence; very slow to slow, moderate to weak, pale yellow sample cut fluorescence; pale straw to clear visible cut; other hydrocarbon indicators possibly masked by oil based drilling fluid. Tuffaceous Sandstone (13330' - 13450') = brownish gray to brownish black with olive gray and dark gray secondary hues; clear to translucent quartz framework; upper fine to lower very fine grains; well to very well sorted; sub-angular to sub-rounded; moderate to high sphericity; PDC disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix; floating and point contact fabric observed; common black carbonaceous material; trace orange lithics; no petroleum odor over oil base mud; trace to spotty, pale yellow to slightly orange sample fluorescence; very slow to slow, moderate to very weak, very pale yellow to pale orange, sample cut fluorescence; moderate to very weak, very pale yellow residual visual cut; pale straw to amber and trace dark brown visible cut; other possible hydrocarbon indicators masked by oil based mud. Tuffaceous Sandstone (13450' - 13570') = brownish gray to brownish black with olive gray and dark gray secondary hues; clear to translucent quartz framework; upper fine to lower very fine grains; well to very well sorted; sub-angular to sub-rounded; moderate to high sphericity; PDC bit disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix; floating and point contact fabric observed; common black carbonaceous material; trace orange lithics; no petroleum odor over oil base mud; pale yellow sample fluorescence; moderate to fast bright yellow white sample cut fluorescence; moderate very pale yellow to amber residual visual cut; pale straw to amber and trace dark brown visible cut; other possible hydrocarbon indicators masked by oil based mud. Tuffaceous Sandstone (13570' - 13680') = brownish gray to brownish black with olive gray and dark gray secondary hues; clear to translucent quartz framework; upper fine to lower very fine grains; common to trace upper coarse grains; moderately/poorly sorted; sub-angular to sub-rounded; moderate to high sphericity; PDC bit disaggregated; loose grains transparent to translucent; friable to firm friable; clay mineral cement; tuffaceous matrix; floating and point contact fabric observed; common black carbonaceous material; trace red, orange lithics; no petroleum odor over oil base mud; pale yellow sample fluorescence; moderate to fast bright yellow white sample cut fluorescence; moderate very pale yellow to amber residual visual cut; pale straw to amber and trace dark brown visible cut; other hydrocarbon indicators masked by oil based drilling fluid. Sand / Conglomerate (13680' - 13800') = medium dark gray to brownish black to medium dark gray and dark gray with olive gray and brownish gray secondary hues; clear to translucent quartz frame- work; upper fine to lower coarse grains; poor to moderately sorted; subangular to subrounded and common angular; moderate to high sphericity; unconsolidated sand grains; clear to translucent and opaque conglomerate quartz; grading from upper coarse to 2mm sized pebbles; poorly sorted throughout sample; dominantly very angular to angular but common subangular to subrounded; grading from irregular shards to moderate and high sphericity; trace orange, grayish purple, and yellow lithics; no reaction to 10% HCL in bulk sample; no petroleum odor over oil based mud; very weak to weak, pale yellow sample fluorescence; slow to very slow, very weak, pale yellow sample cut fluorescence; very weak pale yellow residual visual cut; pale straw to straw visible cut. M-32RD2 25 3.2.1.15 West Foreland WF_3 13,786’ to 14,023' MD (-9,770' to -9,797 TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 383 2 74 43 21 27 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Tuffaceous Sandstone (13800' - 13900') = olive gray and olive brown to olive black and dark gray secondary hues; clear and translucent quartz framework; dominantly upper fine to upper medium grains, common upper very coarse to 2mm pebbles; angular to subangular, common subrounded; low to moderate sphericity; firm friable to moderately hard; clay mineral cement; tuffaceous matrix; floating contact, point contact, and trace long contact observed; common black carbonaceous fragments; trace hard, medium dark gray sandstone; no reaction to 10% HCL in bulk sample; no petroleum odor over oil based mud; trace, very weak, very pale yellow sample fluorescence; very slow, very weak, very pale yellow sample cut fluorescence; no residual cut; no visible cut; other hydrocarbon indicators possibly masked by oil based mud. Tuffaceous Sandstone (13900' - 14023') = medium dark gray to dark gray with olive gray and brownish gray secondary hues; dominantly clear and translucent quartz framework; upper very fine to upper medium grains; moderately sorted; sub- angular to subrounded; moderate to high sphericity; friable to firm friable; clay mineral cement; floating and point contact fabric; common carbonaceous material; no reaction to 10% HCL in sample; no petroleum odor over oil based mud; trace, very pale yellow sample fluorescence; very slow, very pale yellow sample cut fluorescence; no residual visual cut; no visible cut. M-32RD2 26 3.3 Sampling Program Set Type and Purpose Interval Frequenc y Distribution A Washed and Dried Reference 7,209’ – 11,760’ 11,760’ – 13,260’ 13,260’ – 14,023’ 30’ 15’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference 7,209’ – 11,760’ 11,760’ – 13,260’ 13,260’ – 14,023’ 30’ 15’ 30’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Box 1: 7,209’ – 8,580’ Box 2: 8,580’ – 10,110’ Box 3: 10,110’ – 11,730’ Box 4: 11,730’ – 12,465’ Box 5: 12,465’ – 13,005’ Box 6: 13,005’ – 13,590’ Box 7: 13,590’ – 14,023’ *15’ samples from box 3 to box 6* *Note: 15’ samples were caught as the drill rate allowed; if the drilling rate was faster than 60’/hour, 30’ samples were caught. M-32RD2 27 4 DRILLING DATA 4.1 Surve ys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 25.0 0.12 132.21 25.00 -0.01 -0.02 0.02 0.48 50.0 0.24 132.21 50.00 -0.04 -0.07 0.08 0.48 75.0 0.36 132.21 75.00 -0.08 -0.16 0.18 0.48 100.0 0.34 174.99 100.00 -0.18 -0.29 0.24 1.02 125.0 0.34 166.03 125.00 -0.30 -0.43 0.26 0.21 150.0 0.33 165.38 150.00 -0.42 -0.57 0.30 0.02 175.0 0.31 157.40 175.00 -0.53 -0.71 0.35 0.20 200.0 0.46 131.84 200.00 -0.62 -0.84 0.45 0.89 225.0 0.35 141.37 225.00 -0.69 -0.96 0.57 0.52 250.0 0.41 117.15 250.00 -0.74 -1.06 0.70 0.68 275.0 0.37 121.89 275.00 -0.76 -1.15 0.84 0.20 300.0 0.38 140.89 299.99 -0.82 -1.25 0.97 0.50 325.0 0.61 149.60 324.99 -0.94 -1.43 1.09 0.95 350.0 0.96 153.21 349.99 -1.16 -1.73 1.25 1.40 375.0 1.15 161.33 374.99 -1.50 -2.16 1.42 0.98 400.0 1.22 162.72 399.98 -1.90 -2.65 1.58 0.30 425.0 1.27 165.31 424.98 -2.33 -3.17 1.73 0.31 450.0 1.29 167.70 449.97 -2.79 -3.72 1.86 0.22 475.0 1.03 157.97 474.96 -3.19 -4.20 2.01 1.30 500.0 0.93 161.69 499.96 -3.51 -4.60 2.15 0.48 525.0 0.57 161.77 524.96 -3.76 -4.91 2.26 1.43 550.0 0.97 141.18 549.96 -3.96 -5.19 2.43 1.95 575.0 0.63 144.95 574.95 -4.14 -5.47 2.64 1.40 600.0 0.74 158.46 599.95 -4.34 -5.73 2.78 0.79 625.0 0.64 160.96 624.95 -4.56 -6.02 2.88 0.43 650.0 0.67 154.43 649.95 -4.77 -6.28 2.99 0.31 675.0 0.65 168.54 674.95 -4.99 -6.55 3.08 0.65 700.0 0.90 156.25 699.95 -5.24 -6.87 3.19 1.20 725.0 0.76 162.57 724.94 -5.51 -7.21 3.32 0.65 750.0 0.94 158.48 749.94 -5.79 -7.56 3.44 0.73 775.0 0.79 155.24 774.94 -6.06 -7.90 3.59 0.61 800.0 0.93 155.71 799.93 -6.32 -8.24 3.75 0.54 825.0 0.97 149.65 824.93 -6.60 -8.61 3.94 0.43 850.0 0.80 154.93 849.93 -6.85 -8.95 4.12 0.72 M-32RD2 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 875.0 0.92 162.81 874.92 -7.13 -9.30 4.25 0.66 900.0 0.67 163.44 899.92 -7.40 -9.63 4.35 0.99 925.0 0.77 140.77 924.92 -7.60 -9.90 4.50 1.20 950.0 0.51 146.43 949.92 -7.74 -10.13 4.67 1.08 975.0 0.48 164.03 974.92 -7.89 -10.32 4.76 0.62 1,000.0 0.70 160.46 999.92 -8.09 -10.57 4.84 0.86 1,025.0 0.58 177.39 1,024.92 -8.32 -10.84 4.89 0.88 1,050.0 0.74 195.14 1,049.91 -8.60 -11.12 4.86 1.03 1,075.0 1.01 201.52 1,074.91 -8.98 -11.48 4.73 1.14 1,100.0 1.37 198.20 1,099.91 -9.50 -11.97 4.56 1.46 1,125.0 1.65 197.35 1,124.90 -10.15 -12.59 4.36 1.15 1,150.0 1.96 192.81 1,149.88 -10.94 -13.36 4.16 1.35 1,175.0 2.17 188.14 1,174.87 -11.82 -14.24 4.00 1.09 1,200.0 2.25 187.02 1,199.85 -12.76 -15.20 3.87 0.34 1,225.0 2.45 179.02 1,224.83 -13.73 -16.22 3.82 1.53 1,250.0 2.49 180.69 1,249.80 -14.73 -17.29 3.82 0.33 1,275.0 2.42 183.69 1,274.78 -15.74 -18.36 3.78 0.57 1,300.0 2.32 182.13 1,299.76 -16.72 -19.40 3.73 0.50 1,325.0 2.47 182.68 1,324.74 -17.71 -20.44 3.68 0.62 1,350.0 2.42 185.55 1,349.72 -18.73 -21.50 3.61 0.52 1,375.0 2.36 179.39 1,374.69 -19.72 -22.54 3.56 1.06 1,400.0 2.53 182.42 1,399.67 -20.72 -23.61 3.54 0.83 1,425.0 2.31 179.20 1,424.65 -21.70 -24.66 3.53 1.01 1,450.0 2.38 180.34 1,449.63 -22.66 -25.69 3.53 0.32 1,475.0 2.31 179.87 1,474.61 -23.61 -26.71 3.53 0.30 1,500.0 2.14 181.50 1,499.59 -24.52 -27.68 3.52 0.72 1,525.0 1.83 186.12 1,524.57 -25.34 -28.54 3.46 1.37 1,550.0 1.63 186.45 1,549.56 -26.07 -29.29 3.38 0.80 1,575.0 1.53 187.25 1,574.55 -26.74 -29.98 3.30 0.41 1,600.0 1.19 179.85 1,599.55 -27.31 -30.57 3.26 1.53 1,625.0 0.90 177.06 1,624.54 -27.73 -31.03 3.27 1.18 1,650.0 0.49 153.98 1,649.54 -27.98 -31.32 3.33 1.95 1,675.0 0.36 124.28 1,674.54 -28.07 -31.46 3.44 1.01 1,700.0 0.20 106.24 1,699.54 -28.09 -31.52 3.55 0.75 1,725.0 0.16 9.43 1,724.54 -28.05 -31.50 3.59 1.06 1,750.0 0.27 24.28 1,749.54 -27.96 -31.41 3.62 0.50 1,775.0 0.25 31.61 1,774.54 -27.84 -31.31 3.67 0.15 1,800.0 0.09 342.61 1,799.54 -27.77 -31.24 3.70 0.82 M-32RD2 29 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 1,825.0 0.19 340.15 1,824.54 -27.73 -31.19 3.68 0.38 1,850.0 0.23 346.32 1,849.54 -27.66 -31.10 3.65 0.22 1,875.0 0.23 13.94 1,874.54 -27.56 -31.00 3.65 0.45 1,900.0 0.20 43.25 1,899.54 -27.47 -30.92 3.70 0.46 1,925.0 0.08 342.54 1,924.54 -27.42 -30.87 3.72 0.70 1,950.0 0.17 335.92 1,949.54 -27.38 -30.82 3.70 0.37 1,975.0 0.21 18.34 1,974.54 -27.31 -30.74 3.70 0.57 2,000.0 0.33 326.83 1,999.54 -27.22 -30.64 3.67 1.02 2,025.0 0.18 341.17 2,024.54 -27.15 -30.54 3.62 0.64 2,050.0 0.17 6.49 2,049.54 -27.08 -30.47 3.61 0.31 2,075.0 0.25 11.91 2,074.54 -27.00 -30.38 3.63 0.34 2,100.0 0.14 53.88 2,099.54 -26.92 -30.31 3.67 0.69 2,125.0 0.18 109.27 2,124.54 -26.89 -30.30 3.73 0.61 2,150.0 0.15 21.02 2,149.54 -26.85 -30.29 3.78 0.91 2,175.0 0.14 55.89 2,174.54 -26.80 -30.24 3.81 0.34 2,200.0 0.29 157.85 2,199.54 -26.82 -30.28 3.86 1.37 2,225.0 0.25 164.41 2,224.54 -26.91 -30.39 3.90 0.20 2,250.0 0.19 161.96 2,249.54 -26.98 -30.48 3.93 0.22 2,275.0 0.15 142.09 2,274.54 -27.03 -30.55 3.96 0.29 2,300.0 0.09 169.23 2,299.54 -27.07 -30.59 3.98 0.34 2,325.0 0.15 229.15 2,324.54 -27.11 -30.63 3.96 0.53 2,350.0 0.35 253.79 2,349.53 -27.19 -30.68 3.86 0.89 2,375.0 0.33 267.65 2,374.53 -27.26 -30.70 3.72 0.34 2,400.0 0.29 242.32 2,399.53 -27.34 -30.73 3.59 0.57 2,425.0 0.29 241.45 2,424.53 -27.43 -30.79 3.48 0.03 2,450.0 0.48 223.69 2,449.53 -27.58 -30.90 3.35 0.87 2,475.0 0.14 239.92 2,474.53 -27.70 -30.99 3.25 1.40 2,500.0 0.20 203.55 2,499.53 -27.77 -31.04 3.21 0.47 2,525.0 0.10 263.62 2,524.53 -27.82 -31.09 3.17 0.68 2,550.0 0.15 123.67 2,549.53 -27.84 -31.11 3.18 0.93 2,575.0 0.14 99.38 2,574.53 -27.84 -31.13 3.23 0.24 2,600.0 0.19 82.17 2,599.53 -27.81 -31.13 3.30 0.28 2,625.0 0.15 89.52 2,624.53 -27.78 -31.12 3.38 0.17 2,650.0 0.09 151.33 2,649.53 -27.78 -31.14 3.42 0.54 2,675.0 0.24 54.69 2,674.53 -27.75 -31.13 3.47 1.06 2,700.0 0.07 67.11 2,699.53 -27.69 -31.09 3.53 0.67 2,725.0 0.28 65.74 2,724.53 -27.64 -31.06 3.60 0.83 2,750.0 0.11 106.19 2,749.53 -27.59 -31.04 3.68 0.84 M-32RD2 30 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2,775.0 0.23 77.97 2,774.53 -27.56 -31.04 3.75 0.56 2,800.0 0.42 309.29 2,799.53 -27.51 -30.97 3.73 2.36 2,825.0 0.18 85.56 2,824.53 -27.46 -30.91 3.70 2.24 2,850.0 0.11 76.49 2,849.53 -27.43 -30.90 3.76 0.29 2,875.0 0.25 58.24 2,874.53 -27.37 -30.86 3.83 0.60 2,900.0 0.20 49.36 2,899.53 -27.29 -30.81 3.90 0.25 2,925.0 0.23 76.27 2,924.53 -27.23 -30.77 3.99 0.41 2,950.0 0.12 93.88 2,949.53 -27.19 -30.76 4.06 0.48 2,975.0 0.16 7.89 2,974.53 -27.15 -30.73 4.09 0.76 3,000.0 0.16 252.46 2,999.53 -27.14 -30.70 4.06 1.09 3,025.0 0.03 164.65 3,024.53 -27.16 -30.72 4.03 0.66 3,050.0 0.14 289.34 3,049.53 -27.17 -30.71 4.00 0.64 3,075.0 0.05 132.52 3,074.53 -27.18 -30.71 3.98 0.76 3,100.0 0.11 220.79 3,099.53 -27.20 -30.74 3.97 0.48 3,125.0 0.14 287.67 3,124.53 -27.23 -30.75 3.93 0.55 3,150.0 0.21 178.08 3,149.53 -27.27 -30.78 3.90 1.13 3,175.0 0.28 249.51 3,174.53 -27.35 -30.85 3.84 1.16 3,200.0 0.21 241.14 3,199.53 -27.43 -30.89 3.75 0.31 3,225.0 0.12 253.03 3,224.53 -27.48 -30.92 3.68 0.37 3,250.0 0.27 208.85 3,249.53 -27.56 -30.98 3.63 0.81 3,275.0 0.19 258.34 3,274.53 -27.64 -31.04 3.56 0.83 3,300.0 0.26 217.82 3,299.53 -27.71 -31.09 3.48 0.67 3,325.0 0.18 249.83 3,324.53 -27.79 -31.15 3.41 0.57 3,350.0 0.16 194.42 3,349.53 -27.85 -31.20 3.37 0.63 3,375.0 0.20 297.59 3,374.53 -27.88 -31.21 3.32 1.12 3,400.0 0.27 225.44 3,399.53 -27.93 -31.23 3.24 1.12 3,425.0 0.21 193.23 3,424.53 -28.03 -31.32 3.19 0.57 3,450.0 0.22 251.39 3,449.53 -28.11 -31.38 3.13 0.85 3,475.0 0.22 204.33 3,474.53 -28.19 -31.44 3.06 0.70 3,500.0 0.28 249.15 3,499.53 -28.27 -31.50 2.99 0.80 3,525.0 0.32 216.37 3,524.53 -28.38 -31.58 2.89 0.70 3,550.0 0.11 207.64 3,549.53 -28.48 -31.66 2.83 0.84 3,575.0 0.26 236.90 3,574.53 -28.55 -31.71 2.77 0.68 3,600.0 0.19 221.94 3,599.53 -28.63 -31.77 2.70 0.37 3,625.0 0.24 270.34 3,624.53 -28.69 -31.80 2.62 0.72 3,650.0 0.33 222.88 3,649.53 -28.77 -31.86 2.52 0.97 3,675.0 0.14 159.68 3,674.53 -28.86 -31.94 2.48 1.17 3,700.0 0.19 85.53 3,699.53 -28.87 -31.96 2.53 0.80 M-32RD2 31 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 3,725.0 0.29 51.97 3,724.53 -28.79 -31.92 2.62 0.68 3,750.0 0.51 52.20 3,749.53 -28.64 -31.81 2.76 0.87 3,775.0 0.80 27.39 3,774.52 -28.38 -31.59 2.93 1.60 3,800.0 1.21 27.89 3,799.52 -27.94 -31.20 3.13 1.65 3,825.0 1.51 28.45 3,824.51 -27.35 -30.68 3.42 1.18 3,850.0 1.89 22.27 3,849.50 -26.61 -30.01 3.73 1.70 3,875.0 2.52 31.57 3,874.48 -25.66 -29.16 4.17 2.88 3,900.0 2.96 19.67 3,899.46 -24.47 -28.08 4.68 2.86 3,925.0 3.51 21.44 3,924.42 -23.06 -26.76 5.17 2.23 3,950.0 3.79 21.41 3,949.36 -21.47 -25.28 5.76 1.14 3,975.0 4.11 22.21 3,974.30 -19.75 -23.68 6.40 1.29 4,000.0 4.60 21.57 3,999.23 -17.85 -21.92 7.10 1.96 4,025.0 4.92 23.04 4,024.15 -15.78 -20.00 7.89 1.37 4,050.0 5.17 24.82 4,049.05 -13.58 -18.00 8.78 1.18 4,075.0 5.48 22.85 4,073.94 -11.27 -15.87 9.72 1.45 4,100.0 5.69 24.04 4,098.82 -8.84 -13.64 10.69 0.95 4,125.0 6.07 23.78 4,123.69 -6.28 -11.30 11.72 1.55 4,150.0 6.19 25.09 4,148.55 -3.61 -8.87 12.83 0.73 4,175.0 6.52 27.40 4,173.39 -0.85 -6.39 14.05 1.67 4,200.0 6.74 26.72 4,198.23 2.02 -3.82 15.37 0.93 4,225.0 6.95 27.60 4,223.05 4.98 -1.17 16.73 0.96 4,250.0 7.31 27.85 4,247.86 8.07 1.58 18.17 1.43 4,275.0 7.64 28.04 4,272.64 11.30 4.46 19.70 1.34 4,300.0 7.97 27.51 4,297.41 14.67 7.46 21.28 1.33 4,325.0 8.36 26.33 4,322.16 18.21 10.63 22.89 1.70 4,350.0 8.90 25.55 4,346.88 21.94 14.00 24.53 2.19 4,375.0 9.38 24.74 4,371.56 25.91 17.60 26.21 2.00 4,400.0 9.93 23.85 4,396.20 30.09 21.42 27.94 2.27 4,425.0 10.38 23.41 4,420.81 34.50 25.46 29.70 1.85 4,450.0 10.96 22.27 4,445.38 39.12 29.72 31.50 2.46 4,475.0 11.23 22.08 4,469.91 43.93 34.18 33.31 1.07 4,500.0 11.79 21.21 4,494.41 48.92 38.81 35.15 2.35 4,525.0 11.99 21.60 4,518.87 54.07 43.61 37.03 0.88 4,550.0 12.40 20.75 4,543.31 59.35 48.53 38.94 1.79 4,575.0 12.73 20.76 4,567.71 64.79 53.62 40.87 1.33 4,600.0 12.98 20.53 4,592.08 70.36 58.83 42.83 1.00 4,625.0 13.20 20.80 4,616.43 76.02 64.12 44.83 0.91 4,650.0 13.54 20.97 4,640.76 81.80 69.52 46.89 1.38 M-32RD2 32 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4,675.0 13.71 21.63 4,665.05 87.69 75.01 49.03 0.92 4,700.0 13.89 21.95 4,689.33 93.65 80.55 51.24 0.78 4,725.0 14.25 21.67 4,713.58 99.73 86.19 53.50 1.45 4,750.0 14.25 21.80 4,737.81 105.88 91.91 55.78 0.13 4,775.0 14.51 21.67 4,762.03 112.09 97.67 58.08 1.05 4,800.0 14.79 21.83 4,786.22 118.41 103.55 60.42 1.11 4,825.0 15.07 21.55 4,810.37 124.85 109.53 62.80 1.16 4,850.0 15.26 21.29 4,834.50 131.39 115.62 65.19 0.80 4,875.0 15.53 21.74 4,858.60 138.03 121.79 67.62 1.21 4,900.0 15.85 21.47 4,882.67 144.79 128.08 70.11 1.31 4,925.0 16.18 21.43 4,906.70 151.69 134.50 72.63 1.31 4,950.0 16.36 21.60 4,930.70 158.69 141.02 75.20 0.74 4,975.0 16.61 21.77 4,954.67 165.78 147.61 77.82 1.03 5,000.0 17.05 21.90 4,978.60 173.02 154.33 80.52 1.77 5,025.0 17.22 21.73 5,002.49 180.39 161.17 83.25 0.69 5,050.0 17.38 21.70 5,026.36 187.82 168.07 86.00 0.65 5,075.0 17.59 21.69 5,050.21 195.33 175.05 88.78 0.81 5,100.0 18.06 21.59 5,074.01 202.98 182.16 91.60 1.89 5,125.0 18.15 21.60 5,097.77 210.75 189.39 94.46 0.36 5,150.0 18.27 21.56 5,121.52 218.56 196.65 97.33 0.51 5,175.0 18.73 21.74 5,145.23 226.50 204.02 100.26 1.84 5,200.0 18.93 21.56 5,168.89 234.56 211.52 103.24 0.85 5,225.0 19.34 21.42 5,192.51 242.76 219.15 106.24 1.65 5,250.0 19.77 21.38 5,216.06 251.13 226.94 109.29 1.71 5,275.0 20.06 21.26 5,239.57 259.64 234.87 112.39 1.18 5,300.0 20.46 21.14 5,263.02 268.30 242.94 115.52 1.59 5,325.0 20.77 20.73 5,286.42 277.10 251.16 118.66 1.40 5,350.0 21.48 20.86 5,309.74 286.11 259.59 121.86 2.83 5,375.0 21.71 20.83 5,332.99 295.31 268.19 125.13 0.93 5,400.0 21.94 20.47 5,356.19 304.61 276.89 128.41 1.06 5,425.0 22.59 20.22 5,379.33 314.08 285.77 131.70 2.60 5,450.0 22.99 20.07 5,402.38 323.76 294.86 135.04 1.63 5,475.0 23.33 20.02 5,425.36 333.59 304.09 138.41 1.34 5,500.0 23.62 19.92 5,448.30 343.54 313.45 141.81 1.18 5,525.0 24.10 19.85 5,471.16 353.65 322.96 145.25 1.95 5,550.0 24.38 19.90 5,493.95 363.92 332.62 148.74 1.11 5,575.0 24.65 20.07 5,516.70 374.29 342.36 152.29 1.12 5,600.0 25.03 20.09 5,539.39 384.79 352.23 155.89 1.50 M-32RD2 33 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 5,625.0 25.52 20.10 5,561.99 395.46 362.25 159.56 1.97 5,650.0 26.05 20.12 5,584.51 406.33 372.46 163.30 2.13 5,675.0 26.72 20.18 5,606.90 417.44 382.89 167.13 2.68 5,700.0 26.88 20.31 5,629.21 428.71 393.47 171.03 0.68 5,725.0 27.30 20.24 5,651.47 440.09 404.15 174.97 1.69 5,750.0 27.54 20.42 5,673.66 451.60 414.94 178.97 1.00 5,775.0 27.94 20.51 5,695.79 463.24 425.85 183.04 1.61 5,800.0 28.41 20.69 5,717.83 475.04 436.89 187.19 1.91 5,825.0 28.64 20.57 5,739.79 486.98 448.07 191.40 0.97 5,850.0 29.18 20.55 5,761.68 499.06 459.38 195.64 2.15 5,875.0 29.39 20.67 5,783.48 511.29 470.83 199.95 0.89 5,900.0 29.61 20.66 5,805.24 523.60 482.35 204.29 0.88 5,925.0 29.96 20.48 5,826.94 536.02 493.98 208.66 1.43 5,950.0 30.65 20.43 5,848.52 548.63 505.80 213.06 2.76 5,975.0 30.89 20.34 5,870.00 561.42 517.79 217.52 0.98 6,000.0 31.51 20.06 5,891.39 574.37 529.94 221.99 2.54 6,025.0 31.74 19.86 5,912.67 587.48 542.26 226.47 1.02 6,050.0 32.10 19.82 5,933.89 600.69 554.70 230.95 1.45 6,075.0 32.86 19.91 5,954.98 614.12 567.32 235.52 3.05 6,100.0 33.44 19.86 5,975.91 627.78 580.18 240.17 2.29 6,125.0 33.57 19.75 5,996.76 641.58 593.16 244.84 0.61 6,150.0 33.81 19.59 6,017.56 655.44 606.22 249.51 0.99 6,175.0 34.32 19.47 6,038.27 669.44 619.42 254.19 2.09 6,200.0 34.69 19.60 6,058.87 683.59 632.77 258.93 1.49 6,225.0 35.37 19.71 6,079.34 697.94 646.28 263.75 2.73 6,250.0 36.05 19.94 6,099.64 712.52 660.01 268.70 2.77 6,275.0 36.31 20.21 6,119.82 727.27 673.87 273.77 1.22 6,300.0 36.21 20.37 6,139.98 742.06 687.73 278.89 0.53 6,325.0 36.71 20.33 6,160.09 756.91 701.66 284.06 2.01 6,350.0 37.66 20.43 6,180.00 772.02 715.83 289.32 3.80 6,375.0 38.18 20.48 6,199.73 787.38 730.22 294.69 2.06 6,400.0 38.59 20.51 6,219.32 802.91 744.76 300.13 1.66 6,425.0 38.60 20.69 6,238.86 818.50 759.36 305.62 0.47 6,450.0 39.27 20.76 6,258.31 834.21 774.06 311.18 2.69 6,475.0 38.70 20.81 6,277.74 849.94 788.76 316.76 2.27 6,500.0 39.28 20.71 6,297.17 865.67 803.47 322.33 2.32 6,525.0 39.38 20.53 6,316.51 881.51 818.30 327.91 0.60 6,550.0 39.45 20.43 6,335.82 897.38 833.17 333.47 0.37 M-32RD2 34 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 6,575.0 39.56 20.47 6,355.11 913.29 848.07 339.02 0.46 6,600.0 39.07 20.41 6,374.46 929.12 862.91 344.55 1.98 6,625.0 38.99 20.41 6,393.88 944.86 877.67 350.04 0.32 6,650.0 38.82 20.50 6,413.33 960.56 892.38 355.53 0.72 6,675.0 39.37 20.57 6,432.73 976.33 907.14 361.06 2.24 6,700.0 39.33 20.68 6,452.07 992.18 921.98 366.64 0.33 6,725.0 39.56 20.83 6,471.37 1,008.06 936.83 372.27 0.99 6,750.0 39.48 20.80 6,490.65 1,023.97 951.70 377.92 0.33 6,775.0 39.30 20.71 6,509.98 1,039.83 966.54 383.55 0.77 6,800.0 39.80 20.86 6,529.25 1,055.75 981.42 389.19 2.05 6,825.0 39.85 20.85 6,548.45 1,071.76 996.38 394.89 0.18 6,850.0 39.59 20.80 6,567.68 1,087.74 1,011.31 400.57 1.03 6,875.0 39.20 20.82 6,587.00 1,103.61 1,026.15 406.21 1.56 6,900.0 39.39 20.78 6,606.35 1,119.44 1,040.95 411.83 0.74 6,925.0 39.42 20.83 6,625.66 1,135.31 1,055.78 417.47 0.19 6,950.0 39.44 20.78 6,644.97 1,151.19 1,070.63 423.11 0.16 6,975.0 39.55 20.82 6,664.27 1,167.09 1,085.49 428.76 0.46 7,000.0 39.61 20.67 6,683.53 1,183.02 1,100.39 434.40 0.44 7,025.0 39.72 20.34 6,702.78 1,198.97 1,115.34 439.99 0.94 7,050.0 39.21 19.87 6,722.08 1,214.86 1,130.26 445.45 2.34 7,075.0 38.95 19.54 6,741.49 1,230.61 1,145.09 450.76 1.34 7,100.0 38.86 19.29 6,760.94 1,246.30 1,159.90 455.98 0.71 7,125.0 38.63 18.96 6,780.44 1,261.94 1,174.68 461.11 1.25 7,150.0 38.38 18.61 6,800.00 1,277.49 1,189.42 466.12 1.32 7,175.0 37.89 18.57 6,819.67 1,292.91 1,204.05 471.04 1.98 7,200.0 38.14 18.74 6,839.37 1,308.29 1,218.64 475.97 1.09 7,209.0 38.15 18.83 6,846.44 1,223.90 477.77 1,304.64 0.63 7,240.44 39.80 17.87 6,870.89 1,242.67 483.99 1,324.13 5.58 7,334.80 41.00 15.17 6,942.75 1,301.29 501.36 1,384.02 2.25 7,430.46 43.93 12.70 7,013.31 1,363.96 516.87 1,446.61 3.52 7,469.56 45.24 11.76 7,041.17 1,390.79 522.68 1,473.01 3.75 7,523.24 47.38 10.24 7,078.24 1,428.89 530.08 1,510.10 4.49 7,619.96 53.22 9.28 7,139.99 1,502.20 542.66 1,580.69 6.08 7,719.90 60.24 9.90 7,194.79 1,584.54 556.59 1,659.88 7.04 7,809.35 65.47 8.77 7,235.59 1,663.06 569.47 1,735.21 5.95 7,901.90 70.02 7.33 7,270.64 1,747.84 581.44 1,815.63 5.12 7,998.98 70.19 3.81 7,303.69 1,838.68 590.30 1,899.92 3.41 8,090.81 71.70 3.35 7,333.67 1,925.31 595.71 1,978.89 1.71 M-32RD2 35 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 8,185.51 70.06 1.63 7,364.69 2,014.69 599.61 2,059.56 2.44 8,280.08 70.32 1.13 7,396.74 2,103.63 601.75 2,139.02 0.57 8,375.06 71.23 1.01 7,428.03 2,193.30 603.43 2,218.91 0.97 8,470.45 71.43 0.68 7,458.57 2,283.66 604.76 2,299.23 0.39 8,566.52 70.58 2.75 7,489.84 2,374.44 607.48 2,380.59 2.22 8,658.89 70.34 2.59 7,520.74 2,461.40 611.55 2,459.20 0.30 8,754.31 70.12 2.53 7,553.02 2,551.10 615.56 2,540.22 0.24 8,808.94 68.54 1.08 7,572.30 2,602.19 617.17 2,586.03 3.81 8,848.07 67.25 358.99 7,587.03 2,638.44 617.20 2,618.02 5.94 8,942.80 67.35 359.16 7,623.59 2,725.82 615.79 2,694.43 0.19 8,998.89 67.21 359.01 7,645.25 2,777.55 614.96 2,739.67 0.35 9,036.41 66.99 359.77 7,659.85 2,812.12 614.59 2,769.98 1.98 9,089.58 64.89 0.68 7,681.53 2,860.66 614.78 2,812.89 4.25 9,132.04 63.65 1.09 7,699.96 2,898.90 615.37 2,846.90 3.03 9,226.75 60.32 1.27 7,744.44 2,982.48 617.09 2,921.43 3.52 9,321.76 57.85 3.22 7,793.25 3,063.92 620.26 2,994.76 3.14 9,417.01 51.29 4.66 7,848.44 3,141.31 625.55 3,065.51 7.00 9,510.94 45.26 7.51 7,910.93 3,210.98 632.90 3,130.43 6.80 9,605.30 40.42 10.86 7,980.11 3,274.30 643.05 3,191.06 5.67 9,703.98 34.11 14.36 8,058.61 3,332.58 655.96 3,248.55 6.74 9,796.52 28.63 16.36 8,137.60 3,379.04 668.65 3,295.50 6.03 9,890.95 22.55 23.14 8,222.74 3,417.43 682.15 3,335.74 7.14 9,986.71 18.35 41.02 8,312.54 3,445.73 699.28 3,368.77 7.81 10,081.87 14.19 61.42 8,403.94 3,462.63 719.38 3,393.14 7.37 10,176.70 10.34 81.52 8,496.62 3,469.45 738.02 3,407.94 6.00 10,270.49 9.90 110.08 8,589.01 3,467.93 753.93 3,414.09 5.32 10,365.11 9.81 129.63 8,682.26 3,459.99 767.78 3,413.62 3.52 10,459.82 11.75 150.47 8,775.34 3,446.44 778.76 3,406.84 4.56 10,554.63 15.18 163.44 8,867.55 3,426.13 787.06 3,392.84 4.80 10,649.44 17.51 168.87 8,958.53 3,400.24 793.35 3,372.96 2.93 10,743.24 20.42 171.02 9,047.22 3,370.23 798.62 3,348.97 3.20 10,803.06 23.01 172.05 9,102.80 3,348.33 801.87 3,331.19 4.37 10,900.68 31.72 172.20 9,189.41 3,303.93 808.00 3,294.91 8.93 10,995.11 38.45 172.65 9,266.63 3,250.15 815.13 3,250.84 7.13 11,090.38 46.07 172.17 9,337.09 3,186.69 823.60 3,198.86 8.00 11,180.57 56.32 174.21 9,393.54 3,116.99 831.83 3,141.25 11.50 11,184.09 56.53 172.74 9,395.60 3,114.29 833.16 3,139.50 11.18 11,216.71 57.79 173.22 9,413.29 3,087.08 836.51 3,117.08 4.05 M-32RD2 36 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 11,310.80 59.74 175.78 9,462.08 3,007.01 844.20 3,050.08 3.12 11,330.35 59.64 177.52 9,471.95 2,990.17 845.19 3,035.69 7.74 11,424.42 65.86 177.80 9,515.00 2,906.65 848.59 2,963.63 6.61 11,519.27 70.89 177.16 9,549.95 2,818.60 852.48 2,887.79 5.35 11,615.36 71.54 177.12 9,580.90 2,727.73 857.02 2,809.78 0.67 11,708.73 71.47 176.32 9,610.52 2,639.34 862.09 2,734.20 0.82 11,806.43 74.11 175.21 9,639.43 2,546.27 868.99 2,655.36 2.91 11,900.12 77.47 175.63 9,662.42 2,455.76 876.23 2,578.94 3.62 11,992.77 77.65 178.04 9,682.38 2,365.42 881.23 2,501.61 2.55 12,087.22 77.79 181.22 9,702.46 2,273.15 881.82 2,420.50 3.30 12,182.27 78.64 185.68 9,721.88 2,180.30 876.21 2,335.96 4.68 12,274.76 78.34 189.60 9,740.35 2,090.49 864.16 2,251.07 4.17 12,373.15 83.92 191.76 9,755.51 1,995.00 846.14 2,158.35 6.08 12,467.47 83.49 195.61 9,765.85 1,903.93 823.96 2,067.58 4.09 12,564.67 83.70 200.43 9,776.70 1,812.11 794.09 1,972.51 4.93 12,656.61 83.23 199.98 9,787.17 1,726.38 762.54 1,882.03 0.71 12,753.49 83.17 199.19 9,798.64 1,635.75 730.30 1,786.90 0.81 12,847.69 82.94 197.63 9,810.03 1,547.03 700.77 1,694.73 1.66 12,940.70 82.70 200.31 9,821.66 1,459.77 670.77 1,603.63 2.87 13,035.09 83.68 199.93 9,832.85 1,371.77 638.54 1,510.82 1.11 13,038.45 83.68 199.93 9,833.25 1,368.64 637.39 1,507.52 1.07 13,130.59 83.12 203.24 9,843.84 1,283.54 603.72 1,416.59 3.62 13,225.06 82.87 202.90 9,855.37 1,197.27 566.98 1,323.19 0.44 13,320.60 81.68 201.82 9,868.21 1,109.72 530.97 1,229.00 1.68 13,413.90 81.81 200.40 9,881.60 1,023.58 497.71 1,137.35 1.51 13,508.95 80.56 199.44 9,896.16 935.28 465.71 1,044.39 1.65 13,605.68 83.31 203.56 9,909.73 846.20 430.61 949.28 5.08 13,701.06 84.12 204.06 9,920.17 759.47 392.34 854.74 1.00 13,796.33 83.32 204.10 9,930.59 673.01 353.70 760.28 0.84 13,890.95 83.47 203.23 9,941.48 586.92 315.98 666.57 0.93 13,985.37 82.91 202.40 9,952.67 500.50 279.62 573.22 1.06 14,023.00 82.91 202.40 9,957.32 465.98 265.39 536.06 0 Note: Survey @ 14,023.00 is a projection to bit depth. M-32RD2 37 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drilled HRS AVE ROP (Ft/HR) CONDITION 1 8.5” Window Mill 12885084 — 7,209’ 7,233’ 24’ 16.0 4.28 7/16" UNDER-GUAGE RR 8.5” Roller Cone 5016722 — 7,233’ 7,256’ 23’ 3.0 20.65 2-2-WT-A-E-I-NO-BHA 2 8.5” HDBS MMD75DC 12896068 7x12 / 0.7731 7,256’ 10,112 2,856’ 43.0 90.53 5-1-RO-C-X-I-BT-PR 3 8.5” Hughes Kymera KMX524 5269766 2x18, 2x16 / 0.8897 10,112’ 10,112’ — — — 0-2-BT-S-E-I-NO -DTF 4 8.5” HDBS MMD75DC 12931974 4x12, 3x14 / 0.8928 10,112’ 10,776’ 664’ 7.5 117.04 2-1-BT-C-X-I-CT-BHA 5 8.5” Hughes Kymera KMX524 7046452 2x18, 2x14 / 0.7977 10,776’ 11,222’ 446’ 10.4 42.2 1-3-BF-T-E-I-CT-BHA 6 8.5” Varel V711PDG1HRU 4007887 8x12 / 0.8836 11,222’ 11,365’ 143’ 7.1 45.97 1-2-CT-T-X-I-SD-PR 7 8.5” Hughes Kymera KMX524 5266639 2x18, 2x16 / 0.8897 11,365’ 14,023’ 2,658’ 50.9 90.23 2-3-CT-T-E-1-WT-TD 8 8.5” Schlumberger / Smith XR+PS RJ1472 3x28 / 1.8040 14,023’ 14,023’ — — — 1-2-WT-G-E-I-NO-TD M-32RD2 38 4.3 Mud Record Contractor: Halliburton Baroid Date Depth MD TVD MW (ppg) VIS (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) ASG AgN O3 CaCl2 (ppbl) Lime (ppb) Sea Water 7/18/2017 — — 8.5 — — — — — — — — — — — — — 7/19/2017 — — 8.5 — — — — — — — — — — — — — ENVIROMUL 7/20/2017 — — 8.9 — 31 15 10/18/20 - - 8.1 75.6/24.4 - 2.863 — — — 7/21/2017 — — 8.9 — 31 15 10/18/20 - - 8.1 75.6/24.4 - 2.863 — — — 7/22/2017 — — 8.9 132 29 14 9/16/22 4.0 0/3 7.9 80.0/20.0 0.05 2.927 — — — 7/23/2017 7,212 6,846 9.0 104 30 17 9/18/24 3.2 0/3 8.4 77.7/22.3 0.05 2.877 1.9 21.79 5.05 7/24/2017 7,239 6,850 9.0 92 31 14 9/19/22 3.4 0/3 7.9 77.8/22.2 0.05 3.020 1.8 19.85 6.99 7/25/2017 7,256 6,886 9.0 92 31 14 9/18/21 3.4 0/3 8.2 77.7/22.3 0.05 2.910 1.9 18.88 6.22 7/26/2017 7,981 7,295 9.0 86 32 17 10/19/29 3.4 0/3 8.9 77.5/22.5 0.05 2.812 1.7 15.49 5.05 7/27/2017 9,427 7,854 9.0 67 28 13 8/16/22 3.4 0/3 9.2 77.2/22.5 0.01 2.761 1.7 15.97 7.77 7/28/2017 10,112 8,433 9.05 77 29 11 7/15/22 3.4 0/3 10.2 81.8/18.2 0.01 2.702 1.9 17.91 4.40 7/29/2017 10,112 8,433 9.12 83 28 14 8/17/24 3.4 0/3 10.2 81.8/18.2 0.01 2.793 1.8 16.46 3.88 7/30/2017 10,112 8,433 9.38 99 29 13 8/17/23 3.4 0/3 11.2 81.6/18.4 0.01 2.894 1.8 16.46 7.25 7/31/2017 10,776 9,078 9.30 78 29 12 8/18/26 3.0 0/3 10.6 82.9/17.1 0.01 2.950 1.8 17.91 4.40 8/01/2017 11,070 9,323 9.3 79 31 16 10/24/35 3.2 0/3 10.8 83.4/16.6 0.01 2.921 1.8 17.43 7.25 8/02/2017 11,222 9,415 9.3 110 28 12 8/21/28 3.2 0/3 11.2 83.3/16.7 0.01 2.867 1.7 16.94 7.12 8/03/2017 11,222 9,415 9.35 115 31 14 10/23/28 3.1 0/3 11.2 82.8/17.2 0.10 2.935 1.5 13.06 6.22 8/04/2017 11,365 9,486 9.25 77 35 15 9/22/30 3.2 0/3 10.7 82.9/17.1 0.10 2.916 1.6 14.03 6.47 8/05/2017 11,365 9,486 9.1 94 23 10 8/19/24 3.4 0/3 9.30 84.3/15.7 0.10 3.075 1.6 14.03 7.38 8/06/2017 11,867 9,654 9.25 65 35 10 7/17/23 3.4 0/3 12.0 85.5/14.5 0.10 2.801 1.2 9.66 6.22 8/07/2017 12,412 9,759 9.35 65 33 13 7/17/23 3.4 0/3 9.40 85.4/14.6 0.10 3.420 1.6 13.54 6.22 8/08/2017 13,073 9,839 9.4 64 41 16 9/20/30 3.0 0/3 10.3 84.1/15.9 0.10 3.221 1.4 12.28 7.25 8/09/2017 14,023 9,957 9.45 68 38 15 9/21/26 2.5 0/3 10.3 84.1/15.9 0.10 3.269 1.4 13.54 3.88 8/10/2017 14,023 9,957 9.45 135 32 12 10/20/26 2.5 0/2 10.4 85.2/14.8 0.01 3.287 1.5 13.06 4.53 8/11/2017 14,023 9,957 9.5 94 31 12 9/19/23 2.7 0/2 10.9 85.1/14.9 0.01 3.228 1.6 13.06 5.18 8/12/2017 14,023 9,957 9.85 100 32 16 10/20/26 2.7 0/2 11.4 85.1/14.9 0.01 3.490 1.4 13.06 5.18 8/13/2017 14,023 9,957 9.85 92 37 18 8/16/22 2.5 0/2 14.5 84.9/15.1 0.01 3.318 1.4 14.03 5.44 8/14/2017 14,023 9,957 9.90 111 39 16 12/15/30 2.7 0/2 12.8 84.8/15.2 0.01 3.301 1.3 3.35 5.44 Abbreviations: MW = Mud Weight VIS = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded M-32RD2 39 4.4 Drilling Progress 7,000 8,000 9,000 10,000 11,000 12,000 13,000 14,000 15,000 Days Vs. Depth M-32RD2 40 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 10760'MD 11220'MD Country:20 9063'TVD 9415'TVD ROP (fph)183 ft/hr 72 ft/hr 16 ft/hr 717 ft/hr WOB 27 klbs 28 klbs 15 klbs 58 klbs RPM 139 rpm 26 rpm 40 rpm 151 rpm PP 2845 psi 3011 psi 2984 psi 3272 psi Mud Weight 9.3 lbs/gal 9.3 lbs/gal 9.3 lbs/gal 9.4 lbs/gal Chlorides Total Gas 34 29 15 67 C1 (ppm)7,030 4,685 2,288 12,586 C2 (ppm)108 367 48 981 C3 (ppm)52 142 14 515 C4 (ppm)38 68 3 206 C5 (ppm)8 27 2 68 Intensity None Amount 0%Opacity Clear Amount 30% At Shakers No Color None-Gray Color None-Gray Color Pale Straw Type None Amount 10%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Patchy Opacity Opaque Color pale yel Outgassing No Intensity Weak-Dull Intensity Weak-Dull Mud Type Oil-LVT Color v pl yel-wht Color v pl yel Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Eric Andrews / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska LLC. 733-20462-02-00M-32RD2 McArthur River Steelhead 8/9/2017 2:31 AM Sand (10920' - 11000') = olive gray to brownish gray and brownish black; clear to translucent and opaque quartz framework; upper fine to lower coarse grains; moderate to well sorted; sub- angular to subrounded, trace angular; moderate to high sphericity; unconsolidated sand grains; common carbonaceous material in sample; trace hard reddish orange and orange lithics. Petroleum Odor Before During After Maximum No petroleum odor over OBM. No free oil in mud or oil stain over OMB. Trace 5-10%, very weak, very pale yellow sample fluorescence. No visible cut observed. Very pale yellow, very weak, very slow cut sample fluorescence; weak, pale yellow residual cut; pale straw visible cut. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 0.8 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #2 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 11241'MD 12015'MD Country:20 9426'TVD 9687'TVD ROP (fph)16 ft/hr 69 ft/hr 113 ft/hr 465 ft/hr WOB 15 klbs 22 klbs 14 klbs 40 klbs RPM 40 rpm 54 rpm 65 rpm 157 rpm PP 2984 psi 3163 psi 3332 psi 3599 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal Chlorides Total Gas 15 36 49 109 C1 (ppm)2,288 6,485 9,348 23,900 C2 (ppm)48 252 393 1,225 C3 (ppm)14 105 242 492 C4 (ppm)3 53 120 201 C5 (ppm)2 18 53 79 Intensity None Amount 0%Opacity Clear Amount 10% At Shakers No Color None-Gray Color Pale Straw Color Pale Straw Type None Amount 10%Speed Quick Intensity Moderate Fluor Color None Distribution Spotty Opacity Translu Color lt yel Outgassing No Intensity Weak-Dull Intensity Weak-Dull Mud Type Oil-LVT Color pale yel Color pl yel-org Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Eric Andrews / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska LLC. 733-20462-02-00M-32RD2 McArthur River Steelhead 8/9/2017 2:31 AM Sand (11860' - 11970') = olive gray to brownish gray to brownish black with dark gray secondary hues; clear to translucent quartz framework; strong salt and pepper appearance; upper very fine to upper medium grains, common lower coarse grains; very trace 1-2mm pebbles; poor to moderately sorted; subangular to subrounded, trace to common angular to very angular; moderate to high sphericity; unconsolidated sand grains; mild to strong reaction to 10% HCL in bulk sample. Petroleum Odor Before During After Maximum No petroleum odor over OBM; No free oil in mud. No oil stain observed over OBM. 10% trace, very weak, very pale, yellow sample fluorescence; slow to moderately fast,pale yellow to pale orange; sample cut fluorescence; moderate to weak light yellow, residual cut; clear to pale straw visible cut. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.1 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #3 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12030'MD 12340'MD Country:20 9690'TVD 9750'TVD ROP (fph)98 ft/hr 77 ft/hr 59 ft/hr 312 ft/hr WOB 16 klbs 18 klbs 29 klbs 28 klbs RPM 77 rpm 29 rpm 0 rpm 85 rpm PP 3373 psi 3241 psi 3444 psi 3444 psi Mud Weight 9.4 lbs/gal 9.5 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chlorides Total Gas 58 33 19 75 C1 (ppm)11,581 5,566 2,431 15,021 C2 (ppm)521 179 23 708 C3 (ppm)307 132 10 451 C4 (ppm)142 83 8 218 C5 (ppm)59 44 2 90 Intensity None Amount 0%Opacity Clear Amount 50% At Shakers No Color None-Gray Color Pale Straw Color Dk Straw Type None Amount 10%Speed Slow Intensity Moderate Fluor Color None Distribution Spotty Opacity Translu Color lt yel Outgassing No Intensity Weak-Dull Intensity Moderate Mud Type Oil-LVT Color pale yel Color lt yel Report by: Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain Eric Andrews / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska LLC. 733-20462-02-00M-32RD2 McArthur River Steelhead 8/10/2017 7:31 PM Tuffaceous Sandstone (12080' - 12190') = olive gray to brownish gray and brownish black, with some red and reddish orange; clear to translucent and opaque quartz framework; upper very fine to upper fine grains, trace medium grains, rare trace lower very coarse grains; poorly to moderately sorted; sub-angular to sub- rounded; moderate to high sphericity; PDC bit disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix support; floating grain fabric; no reaction to 10% HCL on crushed sample. Petroleum Odor Before During After Maximum No petroleum odor above oil based mud; No free oil in mud; No oil stain over OBM; 10% trace, very weak, pale yellow sample fluorescence; moderate light yellow sample cut fluorescence increasing with depth; moderate to strong, bright yellow to yellow residual cut; straw to amber visible cut. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.3 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #4 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12640'MD 12700'MD Country:20 9785'TVD 9792'TVD ROP (fph)142 ft/hr 137 ft/hr 125 ft/hr 220 ft/hr WOB 13 klbs 13 klbs 25 klbs 24 klbs RPM 84 rpm 84 rpm 82 rpm 90 rpm PP 3312 psi 3340 psi 3393 psi 3413 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chlorides Total Gas 38 36 16 80 C1 (ppm)7,821 6,785 2,313 18,095 C2 (ppm)229 214 12 774 C3 (ppm)149 136 12 459 C4 (ppm)77 74 6 229 C5 (ppm)25 21 - 70 Intensity None Amount 0%Opacity Clear Amount 40% At Shakers No Color None-Gray Color Pale Straw Color Dk Straw Type None Amount 40%Speed Slow Intensity Moderate Fluor Color None Distribution Spotty Opacity Translu Color brt yel Outgassing No Intensity Weak-Dull Intensity Weak-Dull Mud Type Oil-LVT Color pale yel Color pale yel Report by: No petroleum odor over oil based mud; No free oil in mud; No oil stain above OBM. Trace to spotty, moderate to weak, pale yellow sample fluorescence; very slow to slow, very weak, very pale yellow sample cut fluorescence; moderate, bright yellow residual visual cut; straw to amber visible cut. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.4 8/10/2017 7:31 PM Sand (12570' - 12660') = brownish gray to brownish black with olive gray secondary hues; dominantly clear to translucent quartz framework; upper fine to lower quartz grains; moderate to well sorted; subangular to subrounded, trace very angular to angular; dominantly high to moderate sphericity, trace poor sphericity; unconsolidated sand grains; common carbonaceous fragments; trace orange and red lithics; trace 1mm pebbles. Petroleum Odor Before During After Maximum Eric Andrews / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska LLC. 733-20462-02-00M-32RD2 McArthur River Steelhead Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #5 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12700'MD 13000'MD Country:20 9792'TVD 9828'TVD ROP (fph)150 ft/hr 135 ft/hr 154 ft/hr 540 ft/hr WOB 13 klbs 24 klbs 23 klbs 36 klbs RPM 86 rpm 74 rpm 85 rpm 106 rpm PP 3345 psi 3331 psi 3400 psi 3576 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal 9.4 lbs/gal Chlorides Total Gas 23 36 41 81 C1 (ppm)4,053 6,201 8,859 16,292 C2 (ppm)58 321 275 1,202 C3 (ppm)43 134 175 392 C4 (ppm)26 79 102 203 C5 (ppm)1 32 42 80 Intensity None Amount 0%Opacity Clear Amount 40% At Shakers No Color None-Gray Color Pale Straw Color Dk Straw Type None Amount 40%Speed Slow Intensity Weak-Dull Fluor Color None Distribution Spotty Opacity Translu Color pale yel Outgassing No Intensity Weak-Dull Intensity Moderate Mud Type Oil-LVT Color pale yel Color pale yel Report by: No petroleum odor over oil based mud; No free oil in mud; No oil stain over OBM. 30-40% trace to spotty, weak, very pale yellow sample fluorescence; mostly very slow, but trace fast, moderate to weak, light to pale yellow sample cut fluorescence; straw to amber visible cut; other hydro- carbon indicators possibly masked by oil based mud. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.3 8/10/2017 7:31 PM Sand (12770' - 12860') = brownish gray to brownish black with olive gray and olive black secondary hues; dominantly clear and translucent quartz framework; upper fine to lower coarse grains; moderate to well sorted; angular to subangular, but also subrounded; low to moderate sphericity; unconsolidated; common black carbonaceous material throughout sample; trace reddish orange lithics. Petroleum Odor Before During After Maximum Eric Andrews / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska LLC. 733-20462-02-00M-32RD2 McArthur River Steelhead Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas Hydrocarbon Show Report #6 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 13015'MD 13933'MD Country:20 9830'TVD 9946'TVD ROP (fph)161 ft/hr 91 ft/hr 71 ft/hr 646 ft/hr WOB 22 klbs 21 klbs 26 klbs 36 klbs RPM 85 rpm 75 rpm 98 rpm 109 rpm PP 3396 psi 3241 psi 3004 psi 3674 psi Mud Weight 9.4 lbs/gal 9.4 lbs/gal 9.5 lbs/gal 9.5 lbs/gal Chlorides Total Gas 30 32 24 60 C1 (ppm)6,196 5,413 3,011 11,986 C2 (ppm)152 342 304 952 C3 (ppm)107 125 49 393 C4 (ppm)69 68 31 168 C5 (ppm)32 33 4 70 Intensity None Amount 0%Opacity Clear Amount 40% At Shakers No Color None-Gray Color Pale Straw Color Dk Amber Type None Amount 40%Speed Fast Intensity Moderate Fluor Color None Distribution Spotty Opacity Translu Color pale yel Outgassing No Intensity Moderate Intensity Moderate Mud Type Oil-LVT Color pale yel Color brt yel Report by: No petroleum odor over oil base mud; no free oil in mud; no oil stain over OBM; pale yellow sample fluorescence; moderate to fast bright yellow white sample cut fluorescence; moderate very pale yellow to amber residual visual cut; pale straw to amber and trace dark brown visible cut; other possible hydrocarbon indicators masked by oil based mud. Residual Cut (Ring) (Ring) Cut FluorSample Fluorescence Cut Fluorescence Oil Show Rating 1.6 8/10/2017 7:31 PM Tuffaceous Sandstone (13450' - 13570') = Brownish gray to brownish black with olive gray and dark gray secondary hues; clear to translucent quartz framework; upper fine to lower very fine grains; well to very well sorted; sub-angular to sub-rounded; moderate to high sphericity; PDC bit disaggregated; friable to firm friable; clay mineral cement; tuffaceous matrix; floating and point contact fabric observed; common black carbonaceous material; trace orange lithics. Petroleum Odor Before During After Maximum Eric Andrews / Allen Odegaard Show Summary Oil Indicators Lithology Averages Hilcorp Alaska LLC. 733-20462-02-00M-32RD2 McArthur River Steelhead Kenai Peninsula Borough Alaska USA Free Oil in Mud Visible CutOil Stain 1.0 10.0 100.0 1000.0 10000.0 1 2 3 4ppmPixler Plot C1/C2 C1/C3 C1/C4 C1/C5 Non Productive Oil Window Condensate Dry Gas M-32RD2 41 6 DAILY REPORTS Hilcorp Alaska, LLC MacArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Harold Soule, Andy Lundale DATE Jul 23, 2017 DEPTH 7218' PRESENT OPERATION Milling Window TIME 23:59:59 YESTERDAY 7209' 24 HOUR FOOTAGE 9' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8.5" Window MIll 12885084 7209' 9' 9:22 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 4.3 @ 7214' 0.4 @ 7212' 2.0 0 FT/HR SURFACE TORQUE 9671 @ 7212' 8277 @ 7218' 8949.0 8277.20313 AMPS WEIGHT ON BIT 0 @ 7218' 0 @ 7218' 0.0 0 KLBS ROTARY RPM 106 @ 7211' 88 @ 7217' 93.3 93.91943 RPM PUMP PRESSURE 1610 @ 7211' 1255 @ 7215' 1379.8 1268.81091 PSI DRILLING MUD REPORT DEPTH 7212' MW 9.0 VIS 104 PV 30 YP 17 FL - Gels 9/18/24 CL- - FC 0/3 SOL 8.4 SD 0.05 OIL 77.7/22.3 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ 7215' 0 @ 7214' 2.4 TRIP GAS 0 CUTTING GAS 0 @ 7218' 0 @ 7218' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 315 @ 7216' 87 @ 7213' 135.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 7218' 0 @ 7218' 0.0 AVG 0 PROPANE (C-3) 0 @ 7218' 0 @ 7218' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 7218' 0 @ 7218' 0.0 CURRENT BACKGROUND/AVG 3u/2u PENTANE (C-5) 0 @ 7218' 0 @ 7218' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Note: We are only seeing metal shavings and cement at this time. DAILY ACTIVITY SUMMARY Ran into the hole with whip-stock from 2826', and set at 7226'. Displaced well to 8.9 ppg OBM, Tested BOP's, laid down test equipment, and milled out window to 7218’. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3,675.00 REPORT BY Eric Andrews Hilcorp Alaska LLC MacArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Harold Soule, Andy Lundale DATE Jul 24, 2017 DEPTH 7256' PRESENT OPERATION Circulating TIME 23:59:59 YESTERDAY 7218' 24 HOUR FOOTAGE 38' CASING INFORMATION 9.625' @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Roller Cone 5016722 7233' 7256' 23' 1:12 Mill Complete 2 8.5" Window Mill 12885084 7209 7233' 24' 15:55 Slow ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 42.0 @ 7248' 0.5 @ 7234' 14.7 19.75058 FT/HR SURFACE TORQUE 9549 @ 7219' 7916 @ 7227' 9069.1 9136.17871 AMPS WEIGHT ON BIT 18 @ 7255' 15 @ 7246' 8.5 17.93770 KLBS ROTARY RPM 106 @ 7230' 71 @ 7227' 90.7 85.37867 RPM PUMP PRESSURE 1299 @ 7226' 558 @ 7231' 1050.4 1173.60791 PSI DRILLING MUD REPORT DEPTH 7239' MW 9.0 VIS 92 PV 31 YP 14 FL - Gels 9/19/22 CL- - FC 0/3 SOL 7.9 SD 0.05 OIL 77.8/22.2 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 70 @ 7240' 2 @ 7236' 6.5 TRIP GAS 20u CUTTING GAS 0 @ 7256' 0 @ 7256' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 17383 @ 7240' 21 @ 7234' 1247.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 10 @ 7237' 10 @ 7237' 0.3 AVG 0 PROPANE (C-3) 0 @ 7256' 0 @ 7256' 0.0 CURRENT 0 BUTANE (C-4) 0 @ 7256' 0 @ 7256' 0.0 CURRENT BACKGROUND/AVG 2u/2u PENTANE (C-5) 0 @ 7256' 0 @ 7256' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 60% Sand, 20% Conglomerate sand, 10% Conglomerate, 10% Sandstone DAILY ACTIVITY SUMMARY Continued milling out window from 7218' to 7233'. Due to slow ROP, we pulled out of the hole to change out the bit. Picked up a roller cone bit, ran into the hole, and drilled ahead from 7233’ to 7237'. At 7237’, circulated bottoms up, performed FIT test to 12.5 ppg, drilled ahead from 7237' to 7256', and circulated bottoms up. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3,675.00 REPORT BY Eric Andrews Hilcorp Alaska LLC MacArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Jul 25, 2017 DEPTH 7256' PRESENT OPERATION Circulating TIME 23:59:59 YESTERDAY 7256' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 12896068 7x12 7256' 3 8.5" Roller Cone 5016722 7233' 7256' 23' 1:12 2-2-WT-A-E-1-NO-BHA Mill Complete DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7256' MW 9.0 VIS 92 PV 31 YP 14 FL - Gels 9/18/21 CL- - FC 0/3 SOL 8.2 SD 0.05 OIL 77.7/22.3 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 36u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2u/2u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Slip and cut drilling line, pulled out of the hole from 7119’ to surface, installed 5” rams, picked up directional tools, and ran into the hole to 7135’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Jul 26, 2017 DEPTH 8148' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 7256' 24 HOUR FOOTAGE 892' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8090.81' 71.70 3.35 7333.83' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 12896068 7x12 7256' 892' 17:48 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 636.9 @ 7465' 0.9 @ 7292' 84.5 79.95996 FT/HR SURFACE TORQUE 18556 @ 7735' -118 @ 8032' 12472.3 12109.14941 AMPS WEIGHT ON BIT 71 @ 7559' 3 @ 7657' 25.2 24.35896 KLBS ROTARY RPM 132 @ 7443' 0 @ 7657' 84.8 117.09738 RPM PUMP PRESSURE 2656 @ 8147' -2 @ 8032' 2044.0 2654.40576 PSI DRILLING MUD REPORT DEPTH 7981' MW 9.0 VIS 86 PV 32 YP 17 FL - Gels 10/19/29 CL- - FC 0/3 SOL 8.9 SD 0.05 OIL 77.5/22.5 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 177 @ 7606' 2 @ 7343' 24.9 TRIP GAS 0 CUTTING GAS 0 @ 8148' 0 @ 8148' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 48698 @ 7603' 239 @ 7257' 6204.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 205 @ 7736' 6 @ 7824' 18.4 AVG 0 PROPANE (C-3) 16 @ 7737' 0 @ 7560' 2.2 CURRENT 0 BUTANE (C-4) 0 @ 8148' 0 @ 8148' 0.0 CURRENT BACKGROUND/AVG 17u/12u PENTANE (C-5) 0 @ 8148' 0 @ 8148' 0.0 HYDROCARBON SHOWS No hydrocarbon indicators INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand, Tuffaceous Sandstone, Tuffaceous Siltstone, Tuffaceous Claystone, Coal, Carbonaceous Shale, Conglomerate Sand PRESENT LITHOLOGY 60% Sand, 30% Tuffaceous Sandstone, 10% Conglomerate Sand DAILY ACTIVITY SUMMARY Continued running into the hole from 7135’ to 7256’, circulated on bottom, and drilled ahead from 7256’ to 8148’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Jul 27, 2017 DEPTH 9615' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 8148' 24 HOUR FOOTAGE 1467' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9605.3' 40.42 10.86 7980.11' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 12896068 7x12 7256' 2359' 34:38 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 404.3 @ 8507' 5.1 @ 8154' 98.4 52.99068 FT/HR SURFACE TORQUE 15900 @ 8826' 9130 @ 8219' 13213.8 12478.79102 AMPS WEIGHT ON BIT 31 @ 8908' 1 @ 8219' 24.7 30.92420 KLBS ROTARY RPM 171 @ 8549' 112 @ 8165' 148.4 151.26041 RPM PUMP PRESSURE 2753 @ 9299' 1826 @ 8876' 2559.1 2681.83276 PSI DRILLING MUD REPORT DEPTH 9427' MW 9.0 VIS 67 PV 28 YP 13 FL - Gels 8/16/22 CL- - FC 0/3 SOL 9.2 SD 0.01 OIL 77.5/22.5 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 376 @ 8619' 7 @ 8194' 51.3 TRIP GAS 0 CUTTING GAS 0 @ 9615' 0 @ 9615' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 100978 @ 8616' 812 @ 8236' 11412.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 144 @ 9316' 4 @ 8809' 7.5 AVG 0 PROPANE (C-3) 34 @ 8575' 0 @ 8885' 4.5 CURRENT 0 BUTANE (C-4) 4 @ 8617' 3 @ 8569' 0.0 CURRENT BACKGROUND/AVG 33u/30u PENTANE (C-5) 0 @ 9615' 0 @ 9615' 0.0 HYDROCARBON SHOWS No hydrocarbon Indicators INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Siltstone, Tuffaceous Sandstone, Tuffaceous Claystone, Sand, Conglomerate Sand, Carbonaceous Shale, Coal PRESENT LITHOLOGY 50% Sand, 40% Tuffaceous Sandstone, 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Continued drilling ahead from 8148' to 9615’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Jul 28, 2017 DEPTH 10112' PRESENT OPERATION Pulling out of hole for bit change TIME 23:59:59 YESTERDAY 9615' 24 HOUR FOOTAGE 497' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10081.87' 14.19 61.42 8403.94' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 12896068 7X12 7256' 10112' 2856' 42:58 Bit Change DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 381.3 @ 9738' 2.6 @ 10105' 77.9 63.18279 FT/HR SURFACE TORQUE 15279 @ 9755' 10252 @ 10082' 12788.1 11686.70215 AMPS WEIGHT ON BIT 37 @ 9889' 1 @ 9738' 26.7 31.15233 KLBS ROTARY RPM 177 @ 9867' 136 @ 10106' 150.4 142.33144 RPM PUMP PRESSURE 2834 @ 9829' 2044 @ 9639' 2687.8 2761.30347 PSI DRILLING MUD REPORT DEPTH 10112' MW 9.05 VIS 77 PV 29 YP 11 FL - Gels 7/15/22 CL- - FC 0/3 SOL 10.2 SD 0.01 OIL 81.8/18.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 209 @ 9801' 9 @ 9901' 40.6 TRIP GAS 22u CUTTING GAS 0 @ 10112' 0 @ 10112' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 54543 @ 9800' 1611 @ 10062' 8772.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 249 @ 9868' 6 @ 9677' 43.7 AVG 0 PROPANE (C-3) 34 @ 10092' 1 @ 9900' 7.9 CURRENT 0 BUTANE (C-4) 0 @ 10112' 0 @ 10112' 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 10112' 0 @ 10112' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 40% Tuffaceous Sandstone, 20% Sand, 10% Conglomerate, 10% Tuffaceous Siltstone, 10% Carbonaceous Shale, 10% Tuff DAILY ACTIVITY SUMMARY Drilled ahead from 9615’ to 10,112’. Decided to pull out of hole for a bit change. Circulated and pulled out of hole from 10,112’ to 715’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Jul 29, 2017 DEPTH 10112' PRESENT OPERATION Pulling out for MWD tool TIME 23:59:59 YESTERDAY 10112' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 1296068 7X12 7256' 10112' 2856' 42:58 5-1-RO-C-X-I-BT-PR Bit Change 3 8.5" KMX524 5269766 2X18,2X16 10112' 10112' 0'MWD tool fail DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10112' MW 9.05 VIS 108 PV 108 YP 29 FL - Gels 8/15/22 CL- - FC 0/3 SOL 9.0 SD 0.01 OIL 82.0/18.0 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 268u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish pulling out of hole from 715', changed bit, and downloaded tools. Ran back into the hole from surface to 9127'. Lost communication with Geo-Pilot and pulled out of hole from 9127' to 8351’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Jul 30, 2017 DEPTH 10112' PRESENT OPERATION Running into hole TIME 23:59:59 YESTERDAY 10112' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 12931974 4X12,3X14 10112' 3 8.5" KMX524 5269766 2X18,2X16 10112' 10112' 0' 0 0-2-BT-S-E-I-NO-DTF MWD tool fail DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.20 VIS 110 PV 31 YP 13 FL - Gels 8/18/24 CL- - FC 0/3 SOL 10.0 SD 0.01 OIL 81.8/18.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 348u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 82u/25u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued pulling out of the hole from 8351’ to surface, Changed out MWD tools and bit before running back into the hole from surface to 9952' CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Jul 31, 2017 DEPTH 10776' PRESENT OPERATION Laying down tools TIME 23:59:59 YESTERDAY 10112' 24 HOUR FOOTAGE 664' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10743.24' 20.42 171.02 9047.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 12931974 4X12,3X14 10112' 10776' 664'7:30 Mud motor DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 651.4 @ 10593' 2.0 @ 10189' 117.1 200.59753 FT/HR SURFACE TORQUE 17680 @ 10579' 11686 @ 10112' 14777.3 16615.25 AMPS WEIGHT ON BIT 47 @ 10688' 2 @ 10717' 20.7 23.59673 KLBS ROTARY RPM 164 @ 10454' 92 @ 10310' 143.3 246.11436 RPM PUMP PRESSURE 2971 @ 10704' 1753 @ 10450' 2561.7 2833.91382 PSI DRILLING MUD REPORT DEPTH MW 9.30 VIS 9.30 PV 31 YP 15 FL - Gels 10/20/26 CL- - FC 0/3 SOL 10.2 SD 0.01 OIL 83.0/17.0 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 345 @ 10380' 5 @ 10167' 57.8 TRIP GAS 34u CUTTING GAS 0 @ 10776' 0 @ 10776' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 94212 @ 10378' 1019 @ 10171' 14224.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 631 @ 10593' 4 @ 10341' 151.1 AVG 0 PROPANE (C-3) 320 @ 10430' 3 @ 10321' 90.2 CURRENT 0 BUTANE (C-4) 137 @ 10430' 4 @ 10370' 43.0 CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) 56 @ 10708' 3 @ 10482' 11.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand, carbonaceous shale, tuffaceous siltstone, tuffaceous sandstone, conglomerate, coal, tuff PRESENT LITHOLOGY 30% sand, 20% carbonaceous shale, 20% tuffaceous siltstone, 20% tuffaceous sandstone, 10% conglomerate DAILY ACTIVITY SUMMARY Continued running into the hole from 9952' to 10112'. Drilled from 10112' to 10776'. Decided to pull out of hole at 10776' for a mud motor. Pulled out of hole from 10776' to surface. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Aug 01, 2017 DEPTH 11127' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 10776' 24 HOUR FOOTAGE 351' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11090.38' 46.07 172.17 9337.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" MMD75DC 12931974 4x12,3x14 10112' 10776' 664'7:30 2-1-BT-C-X-I-CT-BHA Mud Motor 5 8.5" Kymera KMX524 7046452 2x18,2x14 10776' 351' 6:58 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 716.8 @ 10911' 0.9 @ 10929' 76.6 40.25148 FT/HR SURFACE TORQUE 17134 @ 10778' -92 @ 11036' 5614.4 71.17012 AMPS WEIGHT ON BIT 116 @ 11036' 2 @ 11101' 27.6 39.73890 KLBS ROTARY RPM 144 @ 10779' 0 @ 11054' 21.7 0.35930 RPM PUMP PRESSURE 3272 @ 10841' -1 @ 11036' 3038.8 3099.43652 PSI DRILLING MUD REPORT DEPTH 11070' MW 9.3 VIS 79 PV 31 YP 16 FL 3.2 Gels 10/24/35 CL- - FC 0/3 SOL 10.8 SD 0.01 OIL 83.4/16.6 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 67 @ 10998' 7 @ 10822' 29.9 TRIP GAS 211u CUTTING GAS 0 @ 11127' 0 @ 11127' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 12586 @ 10996' 1373 @ 10822' 5089.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 980 @ 10996' 11 @ 10809' 379.1 AVG 0 PROPANE (C-3) 515 @ 10996' 6 @ 10808' 156.4 CURRENT 0 BUTANE (C-4) 206 @ 10997' 3 @ 10822' 71.1 CURRENT BACKGROUND/AVG 11u/20u PENTANE (C-5) 68 @ 10998' 0 @ 10943' 26.8 HYDROCARBON SHOWS Trace to Moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10780-10920 10920-11000 11000-11050 - Sand/Tuff. Sandstone - Sand - Tuff. Sandstone 52u 45u 67u TUFFACEOUS SANDSTONE(11000'-11050')=OLIVE GRAY TO OLIVE BLACK AND BROWNISH GRAY TO BROWNISH BLACK;CLEAR TO TRANSLUCENT AND OPAQUE QUARTZ FRAMEWORK;UPPER FINE TO LOWER MEDIUM GRAINS; MOD-ERATELY SORTED;SUBANGULAR TO SUBROUNDED;MODERATE TO HIGH SPHERICITY;PDC DIS-AGGREGATED;FRIABLE TO FIRM FRIABLE,OFTEN EASILY FRIABLE;TUFFACEOUS MATRIX; FLOATING TO POINT CONTACT FABRIC; NO ODOR ABOVE OBM; TRACE, WEAK TO MODERATE, PALE YELLOW FLUORESCENCE; SLOW TO MODERATELY FAST PALE YELLOW SAMPLE CUT FLU- OURESCENCE; WEAK, LIGHT YELLOW RESIDUAL CUT; CLEAR TO PALE STRAW VISIBLE CU T RING;OTHER HYDROCARBON INDICATORS POSSIBLY MASKED BY OIL BASED MUD. LITHOLOGY Tuffaceous Siltstone, Tuffaceous Sandstone, Sand, Coal, Carbonaceous Shale, Conglomerate PRESENT LITHOLOGY 50% Sand, 30% Tuffaceous Sandstone, 10% Carbonaceous Shale, 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Finished pulling out of the hole, laid down tools, picked up mud motor and BHA, and ran back into the hold from surface to 10776'. Circulated on bottom and drilled ahead from 10776' to 11127'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Aug 02, 2017 DEPTH 11222' PRESENT OPERATION Testing BOP's TIME 23:59:59 YESTERDAY 11127' 24 HOUR FOOTAGE 95' CASING INFORMATION 9.625"@7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11184' 56.53 172.74 93.95' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" Kymera KMX524 7046452 2X18,2X14 10776' 11222' 446' 10:27 1-3-BT-T-E-I-CT-BHA Completed Build DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 299.0 @ 11187' 1.8 @ 11168' 42.1 30.78408 FT/HR SURFACE TORQUE 15273 @ 11181' 9 @ 11200' 5799.4 13436.33691 AMPS WEIGHT ON BIT 57 @ 11162' 10 @ 11129' 31.5 28.91100 KLBS ROTARY RPM 53 @ 11171' 0 @ 11193' 21.8 53.04169 RPM PUMP PRESSURE 3099 @ 11127' 2825 @ 11187' 2964.4 2846.57837 PSI DRILLING MUD REPORT DEPTH 11222' MW 9.3 VIS 110 PV 28 YP 12 FL 3.2 Gels 8/21/28 CL- - FC 0/3 SOL 11.2 SD 0.10 OIL 83.3 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 34 @ 11157' 9 @ 11222' 24.9 TRIP GAS 30u CUTTING GAS 0 @ 11222' 0 @ 11222' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 5403 @ 11156' 1501 @ 11189' 3202.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 542 @ 11204' 115 @ 11131' 372.4 AVG 0 PROPANE (C-3) 181 @ 11156' 55 @ 11194' 101.7 CURRENT 0 BUTANE (C-4) 85 @ 11156' 38 @ 11194' 59.1 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 44 @ 11156' 22 @ 11192' 33.9 HYDROCARBON SHOWS Trace to Moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11100-11200 Sand/Tuff. Sandstone 34u SAND/TUFFACEOUS SANDSTONE (11100'-11200')=BROWNISH BLACK TO OLIVE BLACK;QUARTZ FRAMEWORK;UPPER FINE TO LOWER COARSE GRAINS;POOR TO MODERATELY SORTED; SUBANGULAR TO SUBROUNDED; MODERATE TO HIGH SPHERICITY;UNCONSOLIDATED SAND GRAINS;TUFFACEOUS SANDSTONE;FRIABLE TO FIRM FRIABLE;CLAY MINERAL CEMENT;TUFFACEOUS MATRIX; FLOATING FABRIC;COMMON BLACK CARBONACEOUS FRAG- MENTS SUSPENDED IN SAMPLE; NON CALCCAREOUS;NO REACTION TO 10% HCL IN BULK SAMPLE; NO PETROLEUM ODOR ABOVE OBM; TRACE, WEAK TO MODERATE,PALE YELLOW SAMPLE FLUORESCENCE;SLOW TO MODERATELY FAST,WEAK TO MODERATE,PALE TO LIGHT YELLOW SAMPLE CUT FLUOR- ESCENCE; PALE TO LIGHT YELLOW RESIDUAL VISUAL CUT; CLEAR TO PALE STRAW VISIBLE CUT. LITHOLOGY Tuffaceous Sandstone, Sand, Coal, Carbonaceous Shale, Conglomerate PRESENT LITHOLOGY 60% Sand, 30% Tuffaceous Sandstone, 10% Conglomerate DAILY ACTIVITY SUMMARY Continued drilling from 11127’ to 11222’, circulated mud, and began pulling out of hole to change BHA. Pulled out of hole from 11222’ to surface. Laid down BHA and rigged up to test BOP’s. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Aug 03, 2017 DEPTH 11222' PRESENT OPERATION Running into the hole TIME 23:59:59 YESTERDAY 11222' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8.5" V711PDG1HRU 4007887 8X12 11222' 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11222' MW 9.30 VIS 1132 PV 29 YP 13 FL 3.1 Gels 13 CL- - FC 0/3 SOL 10.7 SD 0.01 OIL 84.0 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 7u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Completed testing BOP’s, picked up BHA, tested MWD tools, and began running into the hole from surface to 6917'. Slip and cut drill line while circulating and continued running into the hole from 6917' to 10244'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Aug 04, 2017 DEPTH 11365' PRESENT OPERATION Pulling out of hole TIME 23:59:59 YESTERDAY 11222' 24 HOUR FOOTAGE 143' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11310.8' 59.74 175.78 9462.08' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8.5" V711PDG1HRU 4007887 8X12 11222' 11365' 143' 7:05 Slow drill rate DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2404.5 @ 11331' 1.0 @ 11311' 66.3 3.17082 FT/HR SURFACE TORQUE 22907 @ 11305' 11257 @ 11301' 16032.0 11892.64551 AMPS WEIGHT ON BIT 39 @ 11336' 1 @ 11223' 22.9 24.39768 KLBS ROTARY RPM 156 @ 11325' 28 @ 11243' 92.6 103.32289 RPM PUMP PRESSURE 3077 @ 11228' 1804 @ 11334' 2747.0 2903.93384 PSI DRILLING MUD REPORT DEPTH 11365' MW 9.30 VIS 75 PV 32 YP 16 FL 3.2 Gels 10/23/32 CL-- FC 0/3 SOL 10.2 SD 0.001 OIL 82.4 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 38 @ 11280' 9 @ 11222' 23.4 TRIP GAS 11u CUTTING GAS 0 @ 11357' 0 @ 11357' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 6759 @ 11280' 26 @ 11340' 3520.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 623 @ 11298' 6 @ 11236' 176.6 AVG 0 PROPANE (C-3) 176 @ 11276' 4 @ 11233' 47.6 CURRENT 0 BUTANE (C-4) 80 @ 11277' 4 @ 11243' 21.9 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 32 @ 11277' 4 @ 11309' 2.4 HYDROCARBON SHOWS Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11250-11330 Sand 37u SAND(11250'-11330')=OLIVE GRAY TO BROWNISH GRAY AND BROWNISH BLACK;DOMINANTLY CLEAR AND TRANSLUCENT QUARTZ;UPPER FINE TO LOWER COARSE,TRACE 1-3mm PEBBLES OBSERVED;POOR TO MODERATELY SORTED;DOMINANTLY ANGULAR TO SUBAN-GULAR,OFTEN SUBROUNDED;LOW TO MODERATE SPHERICITY;UNCONSOLIDATED SAND GRAINS;TRACE RED, REDDISH ORANGE,WHITE, GREEN,AND GRAYISH PURPLE LITHICS;COMMON HARD BLACK CARBONACEOUS FRAGMENTS; STONG REACTION TO 10% HCL IN BULK SAMPLE WITH TUFFACEOUS SANDSTONE;NO PETROLEUM ODOR ABOVE OBM; TRACE, WEAK, LIGHT YELLOW TO ORANGE SAMPLE FLUORES- CENCE; SLOW TO VERY SLOW, WEAK, PALE YELLOW CUT SAMPLE FLUORESCENCE;WEAK VERY PALE YELLOW RESIDUAL CUT;CLEAR TO PALE STRAW VISIBLE CUT;OTHER HYDROCAR- BON INDICATORS POSSIBLY MASKED BY OBM. LITHOLOGY Sand, Tuffaceous Silstone, Tuffaceous Sandstone, Conglomerate, Coal, 6 PRESENT LITHOLOGY 60% Sand, 30%Tuffaceous Sandstone, 10% Tuffaceous Siltsone DAILY ACTIVITY SUMMARY Continued running into the hole from 10244’ to 11222’. Drilled ahead from 11222’ to 11365’. Decided to pull out of hole from 11365’ due to slow drill rate. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Aug 05, 2017 DEPTH 11365' PRESENT OPERATION Running into hole TIME 23:59:59 YESTERDAY 11365' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" KMX524 5266639 2X18,2X16 11,365' 6 8.5" V711PDG1HRU 4007887 8X12 11222' 11365' 143' 7:05 1-2-CT-T-X-I-SD-PR Slow drill rate DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11365' MW 9.10 VIS 94 PV 23 YP 10 FL 3.4 Gels 8/19/24 CL- - FC 0/3 SOL 9.3 SD 0.01 OIL 84.3 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished pulling out of the hole from 9,979’ to surface, made up mud motor and BHA. Began running back into the hole from surface to 7,499’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Aug 06, 2017 DEPTH 11975' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 11365' 24 HOUR FOOTAGE 610' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11900.12' 77.47 175.63 9662.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" Kymera KMX524 5266639 2x18,2x16 11365 610' 20:31 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 465.3 @ 11825' 0.6 @ 11375' 72.5 45.92934 FT/HR SURFACE TORQUE 21008 @ 11833' -96 @ 11374' 9321.8 48.28757 AMPS WEIGHT ON BIT 39 @ 11782' 0 @ 11750' 21.9 26.00242 KLBS ROTARY RPM 93 @ 11365' 0 @ 11376' 44.1 0.3593 RPM PUMP PRESSURE 3599 @ 11670' 2109 @ 11373' 3248.3 3469.80615 PSI DRILLING MUD REPORT DEPTH 11867' MW 9.25 VIS 65 PV 35 YP 10 FL 3.4 Gels 7/17/23 CL- - FC 0/3 SOL 12.0 SD 0.10 OIL 85.5/14.5 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 108 @ 11674' 9 @ 11706' 36.9 TRIP GAS 356u CUTTING GAS 0 @ 11975' 0 @ 11975' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 23899 @ 11674' 2843 @ 11866' 6865.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 1225 @ 11673' 16 @ 11943' 256.3 AVG 0 PROPANE (C-3) 491 @ 11734' 17 @ 11375' 108.2 CURRENT 0 BUTANE (C-4) 192 @ 11734' 10 @ 11375' 54.4 CURRENT BACKGROUND/AVG 30u/20u PENTANE (C-5) 79 @ 11736' 4 @ 11718' 19.4 HYDROCARBON SHOWS Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand, Tuffaceous Sandstone, Tuffaceous Siltstone, Conglomerate, Coal PRESENT LITHOLOGY 60% Sand, 30% Tuffaceous Sandstone, 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Continued running into the hole from 7499’ to 11365’. Drilled ahead from 11365’ t o 11975’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Harold Soule DATE Aug 07, 2017 DEPTH 12419' PRESENT OPERATION Problem solving Kelly Hose TIME 23:59:59 YESTERDAY 11976' 24 HOUR FOOTAGE 443' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12373.15' 83.92 191.76 9755.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" Kymera KMX524 5266639 2x8,2x16 11365' 1054' 28:52 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 541.5 @ 12412' 1.8 @ 12074' 76.7 118.62785 FT/HR SURFACE TORQUE 19824 @ 12404' -111 @ 12128' 6700.9 71.17012 AMPS WEIGHT ON BIT 38 @ 12391' 0 @ 11976' 19.5 30.91393 KLBS ROTARY RPM 85 @ 12306' 0 @ 12077' 31.3 0.40244 RPM PUMP PRESSURE 3497 @ 12410' 3006 @ 12316' 3296.5 3331.14404 PSI DRILLING MUD REPORT DEPTH 12412' MW 9.35 VIS 65 PV 33 YP 13 FL 3.4 Gels 7/17/23 CL- - FC 0/3 SOL 9.4 SD 0.10 OIL 85.4/14.6 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 81 @ 12017' 16 @ 12419' 32.9 TRIP GAS 0 CUTTING GAS 0 @ 12419' 0 @ 12419' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 16751 @ 12016' 2041 @ 12419' 5565.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 819 @ 12016' 13 @ 12341' 177.5 AVG 0 PROPANE (C-3) 472 @ 12016' 4 @ 12414' 123.3 CURRENT 0 BUTANE (C-4) 217 @ 12052' 1 @ 12397' 73.3 CURRENT BACKGROUND/AVG 7u/13u PENTANE (C-5) 90 @ 12052' 4 @ 12370' 37.4 HYDROCARBON SHOWS Trace to Moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone, Tuffaceous Siltstone, Sand, Conglomerate PRESENT LITHOLOGY 50% Sand, 30% Tuffaceous Sandstone, 20% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drilled ahead from 11975' to 12419'. Encountered problems with the Kelly Hose. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Andy Lundale DATE Aug 08, 2017 DEPTH 13007' PRESENT OPERATION Drilling Ahead TIME 23:59:59 YESTERDAY 12419' 24 HOUR FOOTAGE 588' CASING INFORMATION 9.625" @ 7206' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13035.09' 83.68 199.93 9832.85' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" Kymera KMX524 5266639 2x8,2x16 11365' 1642' 36:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 539.9 @ 12917' 1.4 @ 12900' 120.3 19.16082 FT/HR SURFACE TORQUE 22626 @ 12763' -103 @ 12441' 13441.1 19186.89648 AMPS WEIGHT ON BIT 38 @ 12578' 0 @ 12890' 21.4 21.92597 KLBS ROTARY RPM 106 @ 12839' 0 @ 12428' 60.7 86.65835 RPM PUMP PRESSURE 3659 @ 12569' 2591 @ 12961' 3350.1 3355.5752 PSI DRILLING MUD REPORT DEPTH 13073' MW 9.4 VIS 64 PV 41 YP 16 FL 3.0 Gels 9/20/30 CL- - FC 0/3 SOL 10.3 SD 0.10 OIL 84.1/15.9 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 81 @ 12870' 10 @ 12715' 30.9 TRIP GAS 0 CUTTING GAS 0 @ 13007' 0 @ 13007' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 18094 @ 12645' 1562 @ 12715' 5564.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 1201 @ 12871' 2 @ 12712' 213.6 AVG 0 PROPANE (C-3) 459 @ 12646' 1 @ 12712' 98.9 CURRENT 0 BUTANE (C-4) 228 @ 12646' 0 @ 12712' 56.4 CURRENT BACKGROUND/AVG 18u/20u PENTANE (C-5) 80 @ 12783' 4 @ 12980' 21.0 HYDROCARBON SHOWS Trace to Moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Siltstone, Tuffaceous Sandstone, Sand, Conglomerate, Coal, Sandstone PRESENT LITHOLOGY 40% Tuffaceous Sandstone, 30% Sand, 20% Tuffaceous Siltstone, 10% sandstone DAILY ACTIVITY SUMMARY Fixed Kelly Hose and drilled ahead from 12419' to 13007'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Andy Lundale DATE Aug 09, 2017 DEPTH 14023' PRESENT OPERATION Circulating mud TIME 23:59:59 YESTERDAY 13007' 24 HOUR FOOTAGE 1016' CASING INFORMATION 9.625" @ 7206' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 14023' 82.91 202.40 9957.32' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" Kymera KMX524 5266639 2x8,2x16 11365' 14023' 2658' 50:55 Reached total depth DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 645.8 @ 13744' 0.6 @ 13791' 89.7 58.11543 FT/HR SURFACE TORQUE 22291 @ 13632' 39 @ 13611' 16781.7 18394.80859 AMPS WEIGHT ON BIT 36 @ 13757' 2 @ 13551' 21.3 29.59329 KLBS ROTARY RPM 109 @ 13740' 0 @ 13554' 77.3 98.40548 RPM PUMP PRESSURE 3674 @ 13686' 2377 @ 13657' 3223.7 3045.12158 PSI DRILLING MUD REPORT DEPTH 14023' MW 9.45 VIS 68 PV 38 YP 15 FL 2.5 Gels 9/21/26 CL- - FC 0/3 SOL 10.3 SD 0.10 OIL 84.1/15.9 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 59 @ 13526' 10 @ 13232' 31.8 TRIP GAS 0 CUTTING GAS 0 @ 14023' 0 @ 14023' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 11986 @ 13018' 1443 @ 13232' 5251.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 951 @ 13694' 9 @ 13088' 341.5 AVG 0 PROPANE (C-3) 393 @ 13525' 13 @ 13090' 119.5 CURRENT 0 BUTANE (C-4) 168 @ 13525' 6 @ 13080' 65.2 CURRENT BACKGROUND/AVG 0/22u PENTANE (C-5) 69 @ 13526' 4 @ 13195' 29.6 HYDROCARBON SHOWS Moderate to Trace INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone, Tuffaceous Siltstone, Sand, Conglomerate, Carbonaceous Shale PRESENT LITHOLOGY 60% Tuffaceous Sandstone, 30% Sand, 10% Conglomerate DAILY ACTIVITY SUMMARY Drilled ahead from 13007’ to TD at 14023’ and began circulating mud. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Andy Lundale DATE Aug 10, 2017 DEPTH 14023' PRESENT OPERATION Tripping out of the hole TIME 23:59:59 YESTERDAY 14023' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7206' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 7 8.5" Kymera KMX524 5266639 2x8, 2x16 11365' 14023' 2658' 50:55 Total depth DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 14023' MW 9.45 VIS 135 PV 32 YP 12 FL 2.5 Gels 10/20/26 CL- - FC 0/2 SOL 10.4 SD 0.01 OIL 85.2/14.8 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 72u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished circulating mud and began tripping out of the hole from 14,023’ to 1,711’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Andy Lundale DATE Aug 11, 2017 DEPTH 14023' PRESENT OPERATION Clean out run TIME 23:59:59 YESTERDAY 14023' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 8.5" Schlumberger / Smith XR+PS RJ1472 3x28 / 1.8040 14023' 7 8.5" Kymera KMX524 5266639 2x8,2x16 11365' 14023' 2658' 50:55 2-3-CT-T-E-1-WT-TD Reached total depth DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 14023' MW 9.5 VIS 94 PV 31 YP 12 FL 2.7 Gels 9/19/23 CL- - FC 0/2 SOL 10.9 SD 0.01 OIL 85.1/14.9 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 259u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/12u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued tripping out of the hole from 1,711’ to surface. Pick up clean out assembly and run into the hole from surface to 12,451’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,570.00 REPORT BY Eric Andrews Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Andy Lundale DATE Aug 12, 2017 DEPTH 14023' PRESENT OPERATION Clean out run TIME 23:59:59 YESTERDAY 14023' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 8.5" Schlumberger RJ1472 3x28 / 1.8040 - - - - DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 14023' MW 9.85 VIS 100 PV 32 YP 16 FL 2.7 Gels 10/20/26 CL- - FC 0/2 SOL 11.4 SD 0.01 OIL 85.1/14.9 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 193u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 12u/11u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued running into the hole from 12, 451’to bottom 14,023’, circulate and condition. Began tripping out of the hole from bottom to 12796’. Unable to complete TOH without pumps. Tripped back into hole from 12796’ to 14023’. After raising mud weight, began tripping out of hole from 14023’ to 12308’. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4,520.00 REPORT BY Robert Bales Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Andy Lundale DATE Aug 13, 2017 DEPTH 14023' PRESENT OPERATION Running 7" liner TIME 23:59:59 YESTERDAY 14023' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' 7" @ xxxx' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 8 8.5" Schlumberger RJ472 3x28/1.8040 14023' 14023' 0' 00:00 1-2-WT-G-E-I-NO-TD Cleanout complete DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 14023' MW 9.90 VIS 97 PV 37 YP 16 FL 2.7 Gels 9/18/23 CL- - FC 0/2 SOL 12.4 SD 0.01 OIL 84.9/15.1 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 91u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished pulling out of the hole from 12308’ to surface. Rig up, prepare to run 7” liner. Began running 7” liner from surface to 1,630’. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3,675.00 REPORT BY Robert Bales Hilcorp Alaska LLC McArthur River DAILY WELLSITE REPORT TBU M-32RD2 REPORT FOR Evan Harness, Andy Lundale DATE Aug 14, 2017 DEPTH 14023' PRESENT OPERATION Pulling 7" liner out of hole TIME 23:59:59 YESTERDAY 14023' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 7209' 7" @ xxxx' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 14023' MW 9.90 VIS 111 PV 39 YP 16 FL 2.7 Gels 12/25/30 CL- - FC 0/2 SOL 12.8 SD 0.01 OIL 84.6/15.2 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 29u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 8u/8u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued running 7” liner into the hole from 1,630’ to 9,240'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3,675.00 REPORT BY Robert Bales