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217-029
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops 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 13,448 feet N/A feet true vertical 9,864 feet N/A feet Effective Depth measured 13,311 feet N/A feet true vertical 9,799 feet N/A feet Perforation depth Measured depth 12,244 - 13,293 feet True Vertical depth 9,333 - 9,761 feet 4-1/2" L-80 8,897 (MD) 6,595 (TVD) Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 11,061 (MD) 8,454 (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: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Hemlock Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4,750psi 3,090psi 6,870psi 2,506 2,348 Burst Collapse 1,540psi Production Liner 9,570 4,239 Casing Structural 7,088 7" 9,570 13,443 9,862 394 2,506 394Conductor Surface Intermediate 24" 8,160psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-029 50-733-20074-02-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0017594 / ADL0018777 McArthur River / Hemlock Oil Trading Bay Unit K-03RD2 Plugs Junk measured Length measured TVD true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 19 Gas-Mcf MD N/A 259 Size 394 3715 6326 83 2583711 13-3/8" Other: Replaced ESP 260 324-281 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 50 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A measured Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:00 pm, Aug 22, 2024 Digitally signed by Trudi Hallett (1231) DN: cn=Trudi Hallett (1231) Date: 2024.08.22 13:46:04 - 08'00' Trudi Hallett (1231) _____________________________________________________________________________________ Updated By: JLL 08/01/24 SCHEMATIC McArthur River Field Well: TBU K-03RD2 PTD: 217-029 API: 50-733-20074-02 Last Completed: 07/26/24 PBTD= 13,311 MD TD = 13,488 MD 1 HK-7 7 HK-4 Max Hole Angle = 65.23 @12,682° 13-3/8 9-5/8 TOC 10,230 24 8-1/2 TOW 9,570 HK-1 HK-2 HK-3 HK-5 HK-6 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24 - - - Surf 394' 13-3/8" 61 K-55 Butt LT&C 12.515 Surf 2,506' 9-5/8" 47 S-95 BTC (170 jts) 8.681 Surf - N-80 8rnd LTC 8.681 - 9,570 TOW 7" 29 L-80 DWC/C 6.184 9,204' 13,443' TUBING DETAIL 4-1/2 12.6 L-80 Supermax D 3.958" Surf 8,897' 3-1/2" 9.3 L-80 RTS-8 R2 2.992 8,897' 11,061 JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 48.65 48.65 - - Tubing Hanger 1 11,061' 9,733' - 4.000 Discharge, Bolt-On 11,063' 9,734' - 4.000 Pump, 67 Stg SF5800 (x5) 11,172' 9,822' - 4.000 Intake Sub-Assy 11,173' 9,823' - 4.000 Seals - 400Series, BPBSL 11,189' 9,836' - 4.560 Motors (x2) - 465 FMSLT & FMSUT 11,246' 9,881' - 4.560 Centralizer Anode PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-1&2 12,244' 12,404' 9,333' 9,403' 160 06/24/17 Open HK-2 12,417' 12,552' 9,408' 9,467' 135 06/24/17 Open HK-3 12,590' 12,776' 9,483' 9,561 186 06/24/17 Open HK-4 12,791' 12,904' 9,568' 9,617' 113 06/24/17 Open HK-5 12,953' 13,065' 9,638' 9,688' 112 06/24/17 Open HK-6 13,083' 13,195' 9,696' 9,746' 112 06/24/17 Open HK-6 13,209' 13,223' 9,753' 9,759' 14 06/24/17 Open HK-7 13,250' 13,293' 9,771' 9,761' 43 06/24/17 Open Well Name:MRF K-03RD2 API #:50733200740200 Field:McArthur River Start Date:7/10/2024 Permit #:217029 Sundry #:324-281 End Date:8/10/2024 7/10/2024 7/11/2024 7/12/2024 7/13/2024 7/14/2024 7/15/2024 Daily Operations: Make up landing joints, pull hanger of seat at 140, shear packer at 190k string traveling at 184k, rig up and pump 670 bbls FIW down tbg, well static, Pooh laying down SCSSV and packer, continue pooh to 3574 ft. change out spools Well Operations Summary R/U circulationg lines, Pump & pits to wellhead, check well pressures, tubing 20psi, annulus 140psi, Send crew to Grayling, unload boat & load with remaining rig Eq. bring crews back, unload boat, spot Eq. pump Tubing volume, went on vac. Bullhead 800 bbls down annulus, shut down monitor pressure bled to 0 install BPV, n/d tree, prep wellhead, install blanking sub, install adaptor spool, N/U riser. NU BOPS, install choke and kill lines, raise mast secure same, hook up power, install rig floor and stairs, MU 3-1/2" test joint. spot test pump, accumulator remote panel, superchoke panel. organize deck. Mobe rig crews to platform & orientate same. R/U to circulate well, send crew to Grayling platform to Rig down 404 rig package & put on boat. Unload beam package from boat & assemble over well center, pump 1000bbls fresh water ('drill water') at 8.33ppg down K-03rd2. spot carrier, install Draworks, "A"-leg, walkways & Mast while pulling components off boat. Weld base beams and restring drill line. unload boat & backload. P/U 3 1/2" TJ, r/u super choke panel & remote accumulator panel. Shell test BOPE 250/3000 good. Work on punch list while bringing out inspector, Test BOPE as per Hilcorp & AOGCC expectations, test 250/3000, tested 3 1/2" & 4 1/2" TJ, Test witnessed by AOGCC inspector Adam Earl, Had 2 FP, Tested gas alarms good. R/D test Eq., L/D test joint. Ran lines for inlet water from pump to filter pod on drill deck. Switched from using fresh water at 8.33ppg to Filtered Inlet water (FIW) at 8.4ppg. Pump tubing volume @2bpm, 0psi, monitor tubing & annulus on vac. Pull BPV, Continue r/u for pulling 4 1/2"completion. Page 1 of 4 Well Name:MRF K-03RD2 API #:50733200740200 Field:McArthur River Start Date:7/10/2024 Permit #:217029 Sundry #:324-281 End Date:8/10/2024 7/16/2024 7/17/2024 7/18/2024 7/19/2024 7/20/2024 7/21/2024 Well Operations Summary Daily Operations: Swivel in hole to 12,985 call clean out depth, temporarily detained for 4hrs, pump high vis sweep and lube pill, circulate. POOH t/12,310. Hang off and test BOPEs. Pump salt pill, PU power swivel, installed circ head, KIH f/ 11,682-12,552 no weight seen a few pressure spikes. Continue pooh, lay down excess 4-1/2 supermax tbg, lay out Esp pump, missing 10 clamps, Rig up and Run slick line ops to recover clamps. Continue RIH picking up 3.5", 12.95#, PH6, P110, work string to 9203', pump 75bbls salt pill, circ well, pumped lube pill, RIH to 11,683', mix 25bbl salt pill. Continue with slick line operations attempting to recover lost cannon clamps, recovered 2 more cannon clamps, made it to 9,208' slm, clear deck off load and back load boat, strap and making up BHA on deck, pick up and torque with tongs, tongs stopped biting connections on drill collars, trouble shoot McCoy tongs, change McCoy tong with Gill tongs. Trouble shoot tongs issues, off loading work string from boat,Continue RIH picking up 3.5", 12.95#, PH6, P110, work string to 4,058 ft pick up 8-1/8 string mill and torque x/overs, continue in hole picking up 3.5 work string to 9000 ft depth at rpt time. Page 2 of 4 Well Name:MRF K-03RD2 API #:50733200740200 Field:McArthur River Start Date:7/10/2024 Permit #:217029 Sundry #:324-281 End Date:8/10/2024 7/22/2024 7/23/2024 7/24/2024 7/25/2024 7/26/2024 Rig down Carrier, scope down and lay down derrick nipple down BOPE & Riser, NIpple up tree, test void to 5000 psi, remove BPV, install two way check, install flowline, test breaks to 5000 psi, pull two way check, Turn well over to production, Crews departed to Beluga to rig 401 Daily Operations: Continue testing BOPE as per Hilcorp & AOGCC specs to 250 lo & 3000 hi, test made with 3-1/2 & 4-1/2 test joints, Witness waived by AOGCC Jim Regg via Email, R/d test equipment. Pooh on elevators, laying down 3-1/2 work string f/ 12,302' to 4,900' continue Pooh laying down 3-1/2 PH 6 work string f/ 4,900 ft to BHA, change handling tools, continue Pooh laying down Drill collars, magnets and boot baskets, clean out same, Pickup Summit pump assembly Trip in hole picking up 3-1/2, 9.3#, RTS 8, L-80, tbg.To 377 FT. Continue in hole with ESP assembly f/ 377 ft to 9.819 ft. testing cable every 1000 ft. on 3-1/2, 9.3# RTS 8 TBG & 4-1/2 12.96#, Supermax D TBG Made splice in cable at 5150 ft. Total fluid pumped in hole 3,930 bbls Well Operations Summary Well Operations Summary Continue in hole with ESP assembly f/ 9819 ft to 11,193 ft. testing cable every 1000 ft. on 3-1/2, 9.3# RTS 8 TBG & 4-1/2 12.96#, Supermax D TBG. Made splice in cable at 10,060 ft. Installed TBG hanger, spliced and tested hanger connection and installed penetrator. Landed TBG hanger at 112k lbs string weight. Pump bottom landed at 11,246ft RKB w/pump intake landed at 11,173ft RKB. Ensured correct orientation of hanger and installed hanger tie down bolts. Installed BPV and removed landing string. Rig down ESP equipment and backload ESP equipment to Titan supply vessel. Total fluid pumped in hole 3,957 bbls. Rig down floor, flushed surface lines, rig out koomy hoses, choke and kill lines and prepare for N/D BOP stack. Prepare surface equipment for rigging down the mast. Page 3 of 4 Well Name:MRF K-03RD2 API #:50733200740200 Field:McArthur River Start Date:7/10/2024 Permit #:217029 Sundry #:324-281 End Date:8/10/2024 8/7/2024 8/10/2024 SD ESP for noflow at 0923hrs Passed witnessed no flow with AOGCC inspector Guy Cook, ESP restarted at 01:30hrs. Daily Operations: Page 4 of 4 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov August 22, 2024 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 K-03RD2 PTD 2170290 Dear Mr. Marlowe: On August 9, 2024, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit K-03RD2 located on the King Salmon 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 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated two additional times. There was no oil flow rates observed during the no-flow test. Gas rates were less than the allowed 900 scf per hour during all flow rate checks. Trading Bay Unit K-03RD2 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 K-03RD2 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 King Salmon Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2024.08.22 08:48:04 -08'00' 2024-0809_No-Flow_TBU_K-03RD2_gc Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 8/12/2024 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit K-03RD2 Hilcorp Alaska LLC. PTD 2170290; Sundry 324-281 8/09/2024: I arrived on the King Salmon platform and met with Tom Buchholz (Hilcorp). We talked about the well and the options for testing. I ended up testing with his relief Kyle Essert later in the day as I was also on the King Salmon platform for a BOPE test on Hilcorp Rig 404. The well looked to be in good shape with no obvious issues. The no-flow test equipment was rigged up as per our guidelines. The pressure gauge and flowmeter had current calibrations. After testing the well I informed Mr. Essert the well passed and he could put the well online. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 20:15 0 / 0 / 30 Well was shut in for buildup. 20:30 0.01 / 0.01 / 30 20:45 0.02 / 0.02 / 30 21:00 0.03 / 0.03 / 30 21:15 0.04 / 0.04 / 30 300 0 Open to bleed. Bled to 0 psi in 7 minutes. 21:22 0 / 0 / 30 Shut in for pressure build up 21:37 0.01 / 0.01 / 30 21:52 0.02 / 0.02 / 30 22:07 0.03 / 0.03 / 30 22:22 0.03 / 0.03 / 30 250 0 Open to bleed. Bled to 0 psi in 4 minutes. 22:26 0 / 0 / 30 Shut in for pressure build up 22:41 0.01 / 0.01 / 30 22:56 0.02 / 0.02 / 30 23:11 0.03 / 0.03 / 30 23:26 0.03 / 0.03 / 30 200 0 Open to bleed. Bled to 0 psi in 3 minutes. 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: Test Equipment Certifications 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.21 13:50:10 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT K-03RD2 JBR 08/28/2024 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:2 CMV #9 failed at the grease fitting, changed out w new, passed re-test. Choke HCR slow leak, serviced and passed re-test. Test Results TEST DATA Rig Rep:D. Schutze/R. ChapreOperator:Hilcorp Alaska, LLC Operator Rep:Harold Soule/Ed Hooter Rig Owner/Rig No.:Hilcorp 404 PTD#:2170290 DATE:7/14/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopAGE240717103410 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5.5 MASP: 2638 Sundry No: 324-281 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 2 P Inside BOP 2 P FSV Misc 0 NA 11 FPNo. 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 Blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 P HCR Valves 2 2 1/16 FP Kill Line Valves 2 2 1/16 P Check Valve 0 2 1/16 NA BOP Misc 0 NA System Pressure P3075 Pressure After Closure P1875 200 PSI Attained P24 Full Pressure Attained P119 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1900 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 Annular Preventer P13 #1 Rams P7 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9 9 9999 9 9 9 FP FP CMV #9 failed Choke HCR slow leak 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: 6/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240627 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 43-07Y 50133206250000 214019 6/6/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/10/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/12/2024 AK E-LINE Perf MPU F-6650029226970ϭ00 1961ϲϮ 5/17/2024 AK E-LINE Perf MRU K-03RD2 50733200740200 217029 5/25/2024 AK E-LINE TubingPunch PAXTON 2 50133205730000 207164 5/16/2024 AK E-LINE Pref PAXTON 2 50133205730000 207164 5/30/2024 AK E-LINE TubingPatch PAXTON 11 50133207040000 221114 5/20/2024 AK E-LINE Perf SCU 13-09 50133203430000 181098 6/2/2024 AK E-LINE Cement/JetCut SDI 3-07A 50029219110100 198147 5/28/2024 AK E-LINE Pkr/Poglm SRU 14B-27 50133206040000 212089 6/15/2024 AK E-LINE JewelryLog SRU 32C-15 50133206130000 213070 6/13/2024 AK E-LINE TubingCut Revision Explanation: There are additional images added to the final report and a few new .las files. In the Emeraude folder there are 2 new .las files and in the Field Data folder the RIH and POOH are new .las files Please include current contact information if different from above. T39076 T39076 T39076 T39077 T39078 T39079 T39079 T39080 T39081 T39082 T39083 T39084 MRU K-03RD2 50733200740200 217029 5/25/2024 AK E-LINE TubingPunch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.27 13:09:17 -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): 13,448 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 4,750psi Liner 7,020psi 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: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 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 McArthur River Hemlock Oil Same 9,864 13,311 9,799 2,638psi 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 8,160psi 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 ADL0017594 / ADL0018777 217-029 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20074-02-00 Hilcorp Alaska, LLC Trading Bay Unit K-03RD2 Length Size Proposed Pools: L-80 TVD Burst 9,013 6,870psi MD 3,090psi 394' 2,348' 394' 2,506' 7,088'9-5/8" 24" 13-3/8" 394' 2,506' Perforation Depth MD (ft): 12,244 - 13,293 9,570' 7" 9,333 - 9,761 Other: Replace ESP N/A 5/22/2024 13,443'4,239' 4-1/2" 9,862' See schematic See schematic 9,570' 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 2:25 pm, May 08, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.05.08 13:57:00 - 08'00' Dan Marlowe (1267) DSR-5/8/24SFD 5/13/2024 BOP test to 3000 psi. Annular test to 2500 psi. 10-404 X BJM 5/23/24*&:JLC 5/23/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.05.24 12:02:10 -08'00'324-281 RBDMS JSB 052824 ESP Swap RWO Well: K-03RD2 Well Name:K-03RD2 API Number:50-733-20074-02-00 Current Status:ESP Oil Producer Leg:Leg #4 (NW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:217-029 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:3,614 psi @ 9,761’ TVD (7.2ppg) Highest offset pressure Max. Potential Surface Pressure: 2638 psi Using 0.1 psi/ft Brief Well Summary K-03RD2 is a Hemlock only oil producer that was sidetracked to its current bore in 2017. The ESP currently downhole was the original one installed after drilling and has lasted almost 7 years. The last casing test was associated with that sidetrack in 2017. No cleanout nor perfs are planned as part of this RWO The goal of this project is to pull and replace the ESP Pertinent wellbore information: - June-2017 sidetrack / completion o Drilling rig cleaned out liner to PBTD with 6” bit, and 9-5/8” casing scraper behind (no issues) o 6/21/17: MIT of 7” liner and 9-5/8” casing PASSED to 2600psi (before any perfs shot) o ESP landed with 120k up weight / 70k down - 2/27/22: No Flow test PASSED per letter dated 3/7/22 ESP Swap RWO Well: K-03RD2 RWO Procedure: 1. MIRU Hilcorp Rig #404 2. Circulate well to production: a. Work over fluid will be fresh water (8.33ppg) or heavier b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 140bbls d. IA + Liner volume ~645bbls 3. Set BPV/TWC, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low / 3,000psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well d. Hilcorp’s 13-5/8” RWO BOP stack will be used. This stack has been in service recently with both rig #401 and rig #404 RWO’s 4. BOLDS and unseat hanger 5. Pull up to release packer 6. POOH with 4-1/2” tubing string, packer, and ESP completion 7. PU, RIH with new ESP completion a. No packer nor SSSV is planned 8. Land ESP completion 9. Set BPV/TWC, ND BOP, NU tree and test, pull BPV/TWC 10. Turn well over to production Contingency if evidence of excessive fill 1. PU 3-1/2” workstring 2. MU 7” liner cleanout assembly 3. RIH and mill/cleanout 7” liner to target depth = 13,311’ MD (PBTD) 4. POOH and lay down cleanout BHA and workstring Note: If cleanout is performed, a new NFT will be required Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current and Proposed Wellhead Diagram (no changes) 4. BOP Drawing 5. Fluid/Flow Diagrams 6. RWO Sundry Change Form _____________________________________________________________________________________ Updated By: CJD 07/27/17 SCHEMATIC McArthur River Field Well: TBU K-03RD2 PTD: 217-029 API: 50-733-20074-02 Last Completed: 06/28/17 PBTD= 13,311’ MD TD = 13,488’ MD 2 1 3 HK-7 7” 4 HK-4 Max Hole Angle = 65.23 @12,682° 13-3/8” 9-5/8” TOC 10,230’ 24” X 8-1/2” TOW 9,570’ HK-1 HK-2 HK-3 HK-5 HK-6 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24” - - - Surf 394' 13-3/8" 61 K-55 Butt LT&C 12.515” Surf 2,506' 9-5/8" 47 S-95 BTC (170 jts) 8.681” Surf - N-80 8rnd LTC 8.681” - 9,570’ TOW 7" 29 L-80 DWC/C 6.184” 9,204' 13,443' TUBING DETAIL 4-1/2” 12.6 L-80 Supermax 3.958” Surf 9,013’ JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 48.65’ 48.65’ - - Tubing Hanger 1 363’ 363’ 3.810” 6.910” Superior SSSV w/3.81 Profile 2 396’ 396’ 3.900” 8.320” ESP Dual Packer w/ WFT vent valve 3 443’ 443’ 3.810” 5.560” X-nipple w/ 3.81 Profile 4 9,013’ 6,677’ N/A 6.750” Discharge, Bolt-On 9,014’ 6,677’ N/A 6.750” Pumps 45 Stg SH16000 (x2) 9,052’ 6,704’ N/A 6.750” Intake 9,054’ 6,706’ N/A 5.130” Seals 9,071’ 6,718’ N/A 5.620” (2) 562 500HP Motors (1,000HP/3600V/165.5A) 9,138’ 6,766’ N/A 5.620” Centralizer Anode PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-1&2 12,244' 12,404' 9,333' 9,403' 160 06/24/17 Open HK-2 12,417' 12,552' 9,408' 9,467' 135 06/24/17 Open HK-3 12,590' 12,776' 9,483' 9,561’ 186 06/24/17 Open HK-4 12,791' 12,904' 9,568' 9,617' 113 06/24/17 Open HK-5 12,953' 13,065' 9,638' 9,688' 112 06/24/17 Open HK-6 13,083' 13,195' 9,696' 9,746' 112 06/24/17 Open HK-6 13,209' 13,223' 9,753' 9,759' 14 06/24/17 Open HK-7 13,250' 13,293' 9,771' 9,761' 43 06/24/17 Open _____________________________________________________________________________________ Updated By: JLL 05/07/24 PROPOSED McArthur River Field Well: TBU K-03RD2 PTD: 217-029 API: 50-733-20074-02 Last Completed: Future PBTD= 13,311’ MD TD = 13,488’ MD 1 HK-7 7” HK-4 Max Hole Angle = 65.23 @12,682° 13-3/8” 9-5/8” TOC 10,230’ 24” 8-1/2” TOW 9,570’ HK-1 HK-2 HK-3 HK-5 HK-6 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24” - - - Surf 394' 13-3/8" 61 K-55 Butt LT&C 12.515” Surf 2,506' 9-5/8" 47 S-95 BTC (170 jts) 8.681” Surf - N-80 8rnd LTC 8.681” - 9,570’ TOW 7" 29 L-80 DWC/C 6.184” 9,204' 13,443' TUBING DETAIL 4-1/2” Surf ±8,900' 3-1/2" ±8,900' ±11,100' JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 48.65’ 48.65’ - - Tubing Hanger 1 ±11,100 Discharge, Bolt-On Pump Intake Seals Motors ±11,250' N/A Centralizer Anode PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-1&2 12,244' 12,404' 9,333' 9,403' 160 06/24/17 Open HK-2 12,417' 12,552' 9,408' 9,467' 135 06/24/17 Open HK-3 12,590' 12,776' 9,483' 9,561’ 186 06/24/17 Open HK-4 12,791' 12,904' 9,568' 9,617' 113 06/24/17 Open HK-5 12,953' 13,065' 9,638' 9,688' 112 06/24/17 Open HK-6 13,083' 13,195' 9,696' 9,746' 112 06/24/17 Open HK-6 13,209' 13,223' 9,753' 9,759' 14 06/24/17 Open HK-7 13,250' 13,293' 9,771' 9,761' 43 06/24/17 Open King Salmon Platform K-03RD2 Current 07/05/2017 BOP Stack HAK 404 HILCORP ALASKA, LLC SwacoSuperchokeBlooey LineTo Gas BusterInlet Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well K-03RD2 (PTD 217-029)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC 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 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov March 7, 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 K-03RD2 PTD 2170290 Dear Mr. Marlowe: On February 27, 2022, an Alaska Oil and Gas Conservation Commission (AOGCC) petroleum inspector witnessed a no-flow test of Trading Bay Unit K-03RD2 located on the King Salmon 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 two hours consisting of flow rate checks each preceded by one-hour pressure build up periods. The maximum observed gas flow rate was 180 scf per hour, decreasing to an unmeasurable rate within one minute. There was no liquid flow to surface during the no-flow test. Trading Bay Unit K-03RD2 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 K-03RD2 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 King Salmon Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2022.03.07 14:15:25 -09'00' 2022-0227_No-Flow_TBU_K-03RD2_am Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/02/2022 P. I. Supervisor FROM: Austin McLeod SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit K-03RD2 Hilcorp Alaska LLC PTD 2170290 2/27/2022: I traveled to the King Salmon platform and met up with Tom Buchholz to witness the No Flow Test on well K-03RD2, an ESP completion. The well pressures had been bled just shy of 48 hours. I was told the platform has not been injecting water since September 2, 2021 with no plans to near-term plans to resume. I looked over the rig up and found no issues. The tubing and inner annulus (IA) were in communication with a “C” line at surface. I verified the SSSV and packer vent valve control lines were pressured up and no flow control devices were in the well. Calibrations on pressure gauges and flow meter were current. They shut in the well and documented pressures every 15 minutes then opened to the meter every hour. Could feel a slight blow but meter did not register any flow rate. Flow for two minutes then shut in. Second flow period registered but no where near rate limit. No liquids. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 09:00 0.02/0.50/70 09:15 0.02/0.50/70 09:30 0.05/0.52/70 09:45 0.07/0.60/70 10:00 0.09/0.67/70 0 0 Open to meter. S/I at 10:02 10:17 0.07/0.78/70 10:32 0.11/0.87/70 10:47 0.16/0.98/70 11:02 0.20/1.06/70 180 0 Open to meter. ~ 175-180 scfh then quickly back to zero. 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr I found no issues during this inspection. The well is incapable of unassisted flow. Attachments: Pressure Gauge and Meter Certifications Meter Certificate J. Regg; 3/4/2022 Tubing Pressure Gauge J. Regg; 3/4/2022 IA Pressure Gauge J. Regg; 3/4/2022 • so O o o N N C N n o o c N Z C a) a) a) a) a) a) a) O cv, 0Co _ NI I.7 } (0i . 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I re o c ` 1. > N a I 4? a) 0o E ZO w as Z •� v N Z U w F m o 0 c I a) 0 v 1 I- c Z c ca 0 a 0 o a) Q O CO a o O C U ., U U U C 2 N •V -� N a) •d a) co 0 1 1 Ir a 3 O a -a a) o E a O d o 0 0 °' OLL E (15 O o Ti) °' o c d a z `n in J _I I ? 0 0- 0 10 0 ° 0 0 * 21 7029 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 IfilctarpA1iika,1.1A RECEIVE Fax: 907777-8510 E-mail: doudean@hilcorp.com DATE: 7/31/2017 AUG 2017 To: AOGCC AOGCC DATA LOGGED Makana Bender $/8/201'7 333 W. 7th Ave. Ste#100 ^ K.BENDER Anchorage, AK 99501 RECEIVFP DATA TRANSMITTAL , 2017 TBU K-03RD2 217-029 AGC CANRIG FINAL MUDLOG DATA CD 28454 DML Data 7/31/2017 3:33 PM File folder Final Well Report 7/31/2017 3:33 PM File folder LAS Data 7/28/2017 1:07 PM File folder Log PDFs 7/28/20171:07 PM File folder Log TIFFs 7/31/2017 3:35 PM File folder Sample Photography 7/31/2017 3:37 PM File folder Show Reports 7/31/2017 3:39 PM File folder Daily Reports 7/31/2017 3:40 PM File folder HALLIBURTON FINAL WELL DATA CD _Log Viewers 7/6/2017 8:21 AM File folder 2 8 4 5 5 CGM 7/6/2017 8:21 AM File folder Definitive Survey 7/6/2017 8:21 AM File folder EMF 7/6/2017 8:21 AM File folder LAS 7/6/2017 8:21 AM File folder PDF 7/6/2017 8:21 AM File folder TIFF 7/6/2017 8:21 AM File folder Prints: ROP DGR EWR-Phase4 CTN ALD MD DGR EWR-Phase 4 CTN ALDTVD POLLARD E-LINE CBL DATA CD 2 8 4 5 6 13 K 03RD2 CBL Final.pdf 6/23/2017 2:40 PM PDF Document 2,525 KB Warrior Well Lo a K 03RD2 CBL Final_edited.pdf 7/25/2017 2:10 PM PDF Document 10,130 KB K 03RD2 Main Pass.las 6/23/2017 2:40 PM LAS File 1,396 KB Prints: GAMMA RAY / SECTOR BOND LOG 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 Received By: 6,sitDate: 0 STATE OF ALASKA . RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 7 2017 la.Well Status: Oil CO, Gas MPLETION ORR❑ECOMPLEAbandoned ❑ Suspended❑ lb.Well c � TION REPORT AND SPLUG ❑ Other 20AAC 25.105 20MC 25.110 Development E. Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 6/28/2017 . 217-029/317-218 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 May 23,2017 50-733-20074-02-00• 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 729'FSL, 130'FEL,Sec 17,T9N, R13W,SM,AK June 15,2017 TBU K-03RD2 Top of Productive Interval: 9. Ref Elevations: KB: 122' 17. Field/Pool(s):McArthur River Field 2050'FSL,502'FEL,Sec 19,T9N, R13W,SM,AK GL: N/A BF: 73.4' Hemlock Oil Pool- Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1100'FSL, 1006'FEL,Sec 19,T9N, R13W, SM,AK 13,311'MD/9,799'TVD- ADL017594/ADL018777(TPH/BHL)- 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MDITVD: 19. DNR Approval Number: Surface: x- 213767 y- 2511793 Zone- 4 13,448'MD/9,864'TVD + N/A TPI: x- 208026 y- 2507985 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 207500 y- 2507048 Zone- 4 363'MD/363'TVD N/A 5. Directional or Inclination Survey: Yes ❑., (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 73 (ft MSL) 9,570'MD/7,090'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(Dual Gamma Ray)/EWR-Phase 4/CTN(Compensated Thermal Neutron)/ALD(Azmuthal Lithodensity)MD and TVD;GR/Sector Bond Log; Mudlogs.CBL 6/23/17. 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 7" 29# L-80 9,204' 13,443' 6,817' 9,861' 8-1/2" 469.4 sx Class G 15.3 ppg , 24.Open to production or injection? Yes ❑✓ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 4-1/2" 9,138' 396'MD/396'TVD 12,244'-12,404'MD/9,333'-9,403'TVD 12,417'-12,552'MD/9,408'-9,467'TVD ;ii'',..t..1;;,lid 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 12,590'-12,776'MD/9,483'-9,561'TVD ,.E Was hydraulic fracturing used during completion? Yes❑ No ❑✓ 12,791'-12,904'MD/9,568'-9,617'TVD 12,953'-13,065'MD/9,638'-9,688'TVD (pi it Per 20 AAC 25.283(i)(2)attach electronic and printed information 13,083'-13,195'MD/9,696'-9,746 TVD VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 13,209'-13,223'MD/9,753'-9,759'NDli" _ 13,250'-13,293'MD/9,771'-9,761'ND 6 SPF 6/24/2017 4-1/2" 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 6/28/2017 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 7/18/2017 24 Test Period �..188.4 0 10017 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 70 75 24-Hour Rate i � 188.4 �` 0 10017 36 Form 10-407 Revised 5/2017 - .31417-- SZ. 9 iN/TI;JUUED ON PAGE 2 RBDMS v/ "'".. 3 1 2017 Submit ORIGINIAL o • • 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top N/A N/A 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 Hemlock 1 12,244' 9,333' information, including reports, per 20 AAC 25.071. Coal 39 11,555' 8,894' G1 11,698' 9,006' G5 11,981' 9,201' Coal 59 12,225' 9,324' Hemlock 12,242' 9,332' H2 12,336' 9,373' H3 12,584' 9,480' H4 12,791' 9,567' H5 12,933' 9,629' H6 13,081' 9,695' H7 13,244' 9,768' WF Top 13,326' 9,806' WF 2 13,463' 9,872' Formation at total depth: WF 2 31. List of Attachments: Wellbore Schematic, Decomplete, Drilling and Completion Reports, Definitive Directional Surveys,Casing and Cement Report, Surveillance Graph. 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: cdinger4-'‘ - Authorized ` r/ Contact Phone: 777-8389 Signature: Date: / 7--7 lzo(7 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 . McArthur River Field 11 411 Well:TBU K-03RD2 SCHEMATIC APD 217-029 50 733220074-02 Hilcorp Alaska,1.L€ Last Completed:06/28/17 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. Lj24" - - Surf 1 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2,506' 2 S-95 BTC(170 jts) 8.681" Surf 9-5/8" 47 3 N-80 8rnd LTC 8.681" - 9,570'TOW 7" 29 L-80 DWC/C 6.184" 9,204' 13,443' TUBING DETAIL 4-1/2" 12.6 L-80 Supermax 3.958" Surf 9,013' JEWELRY DETAIL Depth No DMDh TVD ID OD Item 48.65' 48.65' - - Tubing Hanger 1 363' 363' 3.810" 6.910" Superior SSSV w/3.81 Profile 13-3/8" 2 396' 396' 3.900" 8.320" ESP Dual Packer w/WFT vent valve z' 3 443' 443' 3.810" 5.560" X-nipple w/3.81 Profile 9,013' 6,677' N/A 6.750" Discharge,Bolt-On 9,014' 6,677' N/A 6.750" Pumps 45 Stg SH16000(x2) 4 9,052' 6,704' N/A 6.750" Intake 9,054' 6,706' N/A 5.130" Seals 9,071' 6,718' N/A 5.620" (2)562 500HP Motors(1,000HP/3600V/165.5A) 9,138' 6,766' N/A 5.620" Centralizer Anode dr 4 II PERFORATION DETAIL Ilk 9-5/8" Top Btm Top Btm 8-1/2°TOW Zone (MD) (MD) (TVD) (TVD) FT Date Status 9,570' HK-1&2 12,244' ' 12,404' 9,333' 9,403' 160 06/24/17 Open TOC 10,23 , HK-2 12,417' 12,552' 9,408' 9,467' 135 06/24/17 Open + HK-3 12,590' 12,776' 9,483' 9,561' 186 06/24/17 Open 0/4HK-1 HK-4 12,791' 12,904' 9,568' 9,617' 113 06/24/17 Open K-c / 14,.:61 e'4' •.:-., HK-2 HK-5 12,953' 13,065' 9,638' 9,688' 112 06/24/17 Open as HK-6 13,083' 13,195' 9,696' 9,746' 112 06/24/17 Open "" HK-3 h' ::.*: HK-6 13,209' 13,223' 9,753' 9,759' 14 06/24/17 Open I. + HK-7 13,250' 13,293' 9,771' 9,761' 43 06/24/17 Open V, W. HK-4 1 i- e - HK-5 '24 c3 1t 4/17 3'v: / HK-7 PBTD=13,311'MD TD.13,488'MD Max Hole Angle=65.23 @12,682' Updated By:CJD 07/27/17 i • Hilcorp Energy Company Composite Report Well Name: MRF K-03RD2 Field: County/State: ,Alaska (LAT/LONG): ovation(RKB): API#: Spud Date: Job Name: 1711118P K-03RD2 PreDrill Contractor AFE#: 1711118P AFE$: :.. ..........:.:.::.:.:.. . .. :. tit :�lJii1.M�' ... 5/17/2017 No activity on this well during this time.,Prep to move rig to K-03rd2. Remove flowline and earthquake clamps from sub.Pull Hydril annular and replace with Shaffer annular.Trolly BOP back into sub.RU hyd pump to jacks. Pull down stairs and landings.Mix 25 bbl LCM pill and rig up all the lines to pump it.Load out boat w/extra equip.,Skid rig over well K-03RD2.,R/D jacking unit.Install stairs and landings.,Pump 25 bbl. LCM pill and displace with 149 bbl FIW down tubing.Saw pressure after—5 bbl pumped.(ICP=1850 psi @ 5 bpm.FCP=2200 psi @ 3 bpm.Shut down and pressure bled to 800 psi after 15 min.)Bleed off pressure and R/D circ lines. Continued to rig up during pumping operations.,Continue rigging upon K-03RD2. Install earthquake clamp,handrails,stairs,landings and flow lines.Run lite water line to sub and tighten panic line.Change out DSA on riser to GrayLock clamp and swap spools.,lnstall BPV and nipple down tree. 5/18/2017 Nipple dn tree and components.Clean up wellhead and check hanger threads.Screw in blanking sub.,Nipple up riser.PU BOPs and slide 2'spool under and MU on riser. Nipple up BOPs.MU choke lines and tighten flanges from rams down.,MU Shaffer annular bolts. Install flow box and turn buckles.[Unload boat while nippling up]Hook up flowline.Install drip pan and seal off same.Install beaver slide and catwalk.,Modify drip pan for rotary pin installation.Circulate - through flow lines to check for leaks(GOOD)Get RKB measurements Bag=8.48',UPR=12.30', BR=12.30', LPR=15.24', LDS=48.65'.,Build test jt.fill system with water and purge air from system.,Test BOPE with 4 1/2"pipe. Test annular with 250/2500 psi for 5 min ea.Test Rams and valves with 250/3500 psi for 5 min ea. Upper pipe ram test failed on initial attempts to test. Cycled valves and rams and retested (GOOD)Tested gas alarms all good,tested PVT and flow show all good.,Performed accumulator draw down test, pressure after function 1400 psi,200 psi recovery 27 seconds,full recovery 3000 psi 132 seconds.2500 psi N2 bottle average.Note:AOGCC witness of test waived by Jim Regg.,Pull test joint and break down same.,Pick up T-bar and pull BPV.,Make up landing joint and screw into hanger.P/U 55K to unseat hanger. Pick up tubing string 20'to unseat seals(PUW=90K).,Pump 15 bbl clean FIW to get returns.Rig up to test lines for shipping well bore fluids to production shipping line. 5/19/2017 Test shipping lines to production pipeline to 1500 psi.Pump FIW dn tbg w/#1 pump at 5 BPM,340 psi,taking returns to pit 5 and pumping to production pipeline w/#2 pump.at 4 to 5 BPM and 380 psi. Pumped 721 bbls FIW and pumped 728 bbls to production pipeline.,Pull hanger to rig floor and LD hanger and landing jt.,RU to cmt,MU XOs and tag top of packer w/pump on at 1 bpm,Observed pressure increase and flow decrease.Shut pump down and stab seal in 6'into packer.Establish injection rate.2 BPM=1900 psi,3 BPM=1950 psi,4 BPM=2145 psi.Shut down and press bled down to 1600 psi in 5 min.,RU Schlumberger lines.and have PJSM.,Prime up Schlumberger pumps.Pump 5 bbls water.Test lines to 800 and 4500 psi.Good test.Pump 10 more bbls water. Batch up and mix 15.8 ppg cmt. Pump 41.5 bbls of cmt and chase w/5 bbls water.Swap to rig pump and Chase with 141 bbls of FIW.Starting pressure of 450 psi and a final pressure of 2153 psi.Squeezed 30 bbls into pkr and left 10 bbls on top.,RD circ equip.Pull 6 stds and stand them back in the derrick.,Put wiper plug in the pipe and circ clean.8 BPM,680 psi.About 25 bbls from bottoms up we started getting cmt contaminated fluid back.Got back about 1 bbl of contaminated cmt.,R/D circ equipment(TIW,X/O,Side Entry,Pup Jts of tbg)Well out of balance.,Circulate to balance fluids in well.,POOH laying down 51 jts of 4 1/2"tbg. (PUW=89K)Well out of balance again.,RIH with 6 std tbg out of derrick, Rig up to circulate.,Circ well to ballance.Mix and pump dry job.,Continue to POOH laying down tbg.,Wellhead pressures:24"=60 psi, 13 3/8"=62 psi Fluid loss to well today:140 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 0.0 lbs. Total:0.0 lbs. 5/20/2017 POH laying down 4 1/2 injection tbg. Lay dn seals.,RD Weatherford tongs and clear floor.,Test csg to 2600 psi.for 30 min on a chart. Lost 50 psi over the first 15 min then it held like a rock.Good test.,Break down tbg floor safety valves and PU BHA#1:8 1/2 bit,9 5/8 csg scrapper,bit sub,flex jt,8 1/2 upper string mill,xo,1 jt HWDP,xo,bumper sub,oil jars,xo,&18 jts HWDP=632.89'.,Cut 150'drilling line.,Service blocks,top drive and drawworks.,RIH with BHA#1 picking up 4 1/2" DP.,Wellhead pressures:24"=58 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 0.0 lbs. Total:0.0 lbs. 5/21/2017 Continue RIH with scraper assem while PU 4 1/2 CDS40 DP to 9,860'.,Circ hole clean at 414 GPM,967 psi.Got back black sledge and black tar balls. Had just a slight increase at bottoms up.,RU e-line and MU gyro tools.[Took 1 1/2 hrs to get tools headed in the hole.]RIH with gyro 9,715'.,POH w/Gyro slow. Break dn tools and RD e-line.,Pump dry job.POH w/scraper assembly from 9895'(PUW=130K)to 4545'(PUW=75K).,Service Drawworks,Top Drive, Blocks and Crown.,Continue POOH to BHA.,UD BHA and clear floor.,RU e-line to Bridge Plug(Bridge Plug has wrong upper slip segment for running on e-line).,Wait on correct slip segment to be delivered to heliport by Baker and flown out to platform.,Finish making up Bridge Plug and RIH on wireline.Set plug @ 9591' WLM(5'above collar @ 9596').,POH with wireline.,Wellhead pressures:24"=60 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 0.0 lbs. Total:0.0 lbs. • i 5/22/2017 POH w!e-line after setting the BP.RD e-line and clear floor.,Service rig and TD.,PU whipstock BHA#2=9 5/8 bottom trip anchor,9 5/8 gen II whipstock slide, 8 1/2 window mill,lower string mill,flex joint,upper string mill,XO sub, 1 jt HWDP,XO sub,float sub,DM collar,TM HOC,XO sub,18 jts HWDP=654.38, BHA to window mill=632.66,RIH BHA and one std of DP to 685'.Test MWD and we got a good signal.,RIH w!whipstock U 3136'.,Continue RIH w/whipstock U 9534'.,MU TD and orientate whipstock to 58 deg left by working pipe.Tag top of BP at 9593'DPM on down stroke. PU another sng to give us room to set wt on whipstock.,Set down and see shear @ 12K down.PU to check for over pull,none observed,PUW=125K. Slack back off and set down 30K.Appears that the anchor and shear bolt both sheared at the same time.,Check rotation,10 rpm=8K free torque.Adjust TD torque to 10K.Slack off rotating and observe window mill stall out on the whipstock slide.Take a check shot with MWD and verify that the whipstock is still oriented at 58 deg left.,RU to displace well and lay down single.(reset the TD torque to 18K drilling and 21K max).,PJSM for displacing well.PT lines to production to 1500 psi.,Begin pumping FIW to production 3 bpm 310 psi.Pump 25 bbl spacer down drill pipe followed by OBM at 3 bpm 180 psi.,Continue displacing well to OBM @ 5 bpm FCP 610 psi. Shipping FIW down pipeline to Trading Bay.Total pumped 679 bbl @ 4 bpm 250 psi.,Suck out remaining FIW in pits,transfer OBM form ISO and upright tanks to pits. Remove blind flange from charge pump line,blow down shipping line and line up pumps to circulate downhole.,Circulate and condition mud while transferring OBM to pits.,Tag top of whipstock at 9569'and start milling window.,Wellhead pressures:24"=58 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. 3 , Metal recovered today: 0.0 lbs. Total:0.0 lbs. (Cs.A K AD 5/23/2017 Mill 8 1/2 window f/9570'U 9588.410 GPM,2500 psi,90 RPM,6 to 13k Tq.,Mill formation f/9588'U 9613'.Mill 25'new hole to ensure we had gauge hole for drilling assem.,Circulate and condition mud to 9.0+ ppg in and out.,Perform FIT to 12.5 ppg EMW.God test.,Pump dry job.POOH with window milling assembly from 9568'to 2375'.,Service Drawworks,Crown,Blocks and Top Drive.,Continue to POH with window milling assembly to BHA.,UD Window Milling BHA(BHA#2).,Change to Drilling AFE @ 2400 hours.,Wellhead pressures:24"=60 psi,13 3/8"=26 psi pry- Code Fluid loss to well today:0.0 bbls. Total:315 bbls. Z 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 300 lbs. Total:300 lbs. Hilcorp Energy Company Composite Report Well Name:MRF K-03RD2 Field: County/State: ,Alaska (LAT/LONG): avation(RKB): API#: 01-41 Spud Date: n `I Job Name: 1711118D K-03RD2 Drilling O Contractor '2 1 i,,,) AFE#: 1711118D AFE$: 5/23/2017 No Activity on Drilling AFE at this time;Laydown Window Milling BHA(BHA#2).Inspect mills with Baker tool hand(In gauge).;Clean and clear floor, Stage BHA #3 components on catwalk.;Make up Drilling BHA as per Sperry DD and MWD/LWD.Upload tools.;Perform shallow hole test of Sperry tools @ 114'. (GOOD).;PJSM with Sperry and load sources.Continue picking up BHA.;Wellhead pressures:24"=60 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 0.0 lbs. Total:300 lbs. 5/24/2017 Finish picking up BHA#3,8 1/2"drilling assembly.;RIH with BHA#3 filling pipe every 2500'to 9592'.Did not see window.;Establish parameters:P/U 110,S/O 75,RT 89 at 40 RPM/8 K torque.385 GPM/2850 psi. Directional drill 9611'to 9638'.Hard drilling start @ 9634' WOB 5-30K.;Pull up and drift window to make sure BHA not hanging up.No drag seen through window.;Attempt to drill @ 9638'.;Ream from 9640'to 9638'.Stalled rotary(TQ=20K)at 9637'.;Drilling @ 9638'.Unable to make hole.No noticeable differences observed between on and off bottom rotary torque or differential pressure.;Mix and pump dry job.;POOH with BHA#3.;Wellhead pressures:24"=62 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 7.0 lbs. Total:307 lbs. 5/25/2017 POOH with BHA#3 to 798'.;Work BHA#3.Bit cored out and 4 blades broke off. Missing 2 complete jets.Bit was 1/16"under gauge.(Bit only drilled 27'). Photos in o-drive.;Consult with engineer.Mobilize boot baskets and string magnet for junk run.Laydown smart iron,clear and clean rig floor.;Slip and cut 125' drilling line.;P/U BHA#4 (Junk Clean Out Assembly)to 2584'.;Fill pipe and service rig.;Continue to RIH with BHA#4 PU=60K,SO=52K(filled pipe @ 5070' and 7567').;Continue to RIH to 9538'.PU=60K,SO=52K.;Wash and ream to 9641'. No drag through window.;Clean off bottom and drill from 9641'to 9651'. 415 gpm=2050psi,TQ=7-8K w/40 rpm,WOB=2K.;Circulate and condition hole.;Wellhead pressures:24"=64 psi,13 3/8"=28 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 0.0 lbs. Total:307 lbs. 5/26/2017 Wash and ream through 9611'to 9651'several times to clean up area.Pull back into window 9560'.;Pump dry job.POOH with BHA#4.;Lay down BHA.Clean magnet(31 lbs)and boot baskets(6 lbs).Clear rig floor.;Pick up BHA#5 directional drilling assembly.Performed shallow pulse test of MWD.;PJSM.PU and load nukes.;RIH with BHA#5 to 7939'.Filling pipe every+/-2500'.;Service Rig.;Continue to RIH from 7939'to 9555'.;Fill pipe and get parameters.PU=96K, SO=67K,2797 psi@ 400 gpm.;RIH to 9613'.Cycle pumps and log in the hole with MWD to bottom @ 9651'.Worked pipe several times to get past 9641' without stalling motor.;Orient tool face to 125°L and slide drill from 9651'to 9691'.;Drawworks failure.Unable to lower the blocks after making a connection. (Loose wire to hoisting sensor).;Wellhead pressures:24"=62 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 1.5 hrs Total:1.5 hrs. Metal recovered today: 47 lbs. Total:354 lbs. 5/27/2017 Directional drill from 9691'to 9700'.;Control/time drill from 9700'to 9709'to obtain separation from casing.P/U 97 K,S/O 67 K. 400 GPM/2750 psi.;Control/time drill from 9709'to 9716'. At 9713'10%sand,90%cement.;Control/Time drill from 9716'to 9720'.1.25 FPH,391 GPM/2624 psi.;Control/Time drill from 9720'to 9725'. 1.75 FPH,400 GPM/2760 psi.;Control/Time drill from 9725'to 9730'.2.5 FPH,405 GPM/2800 psi.;Control/Time drill from 9730'to 9738'.5 FPH,405 GPM/2800 psi.;Directional Drill from 9738'to 9792'. 10%sand,90%cement.Unable to achieve desired separation from original well bore. Discuss options with town.;Wellhead pressures:24"=64 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 11 lbs. Total:365 lbs. 5/28/2017 POOH with BHA#5 from 9792'to 9555'.Pump dry job.POOH to 3351'.;Continue POOH to BHA.;Work BHA.Lay down 2 stands HWDP.Remove nukes. Download MWD.Lay down remaining BHA.;Clear/clean floor from trip.;Service rig.;Strap and pick up 2 7/8"stinger assembly.(Mule shoe,10 Its.2 7/8"tubing, 2 X/O's=325.59').;RIH with stinger assembly on 4 1/2"drill pipe to 8706'.;Strap and pick up 10 jts of 4 1/2"DP.;Continue to RIH out of the derrick to 9705'.;Wash down to 9889'(97'below bit depth on last trip out of hole)PIU=84,S/0=62.;Circulate and condition mud,Discuss plan forward with town.;Strap and pick up DP.Wash in the hole to 10,012'.;Wellhead pressures:24"=64 psi,13 3/8"=31 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 0.0 lbs. Total:365 lbs. 5/29/2017 Circulate bottoms up at 10,012'with no noticeable change in mud properties.Monitor well(static).;POOH to 9509'.;Attempt injection test for possible cement squeeze.Pump at.5 BPM up to 2480 psi (8.7 bbls).Bleed back to 2400 psi in 5 minutes.Bled back 8.5 bbls.Injection test failed.;Service rig and clear rig floor while discussing options with drilling team.;Mix and pump dry job.POOH to 7217'.;Continue POOH standing back.;Lay down cement stinger.;R/D 2 7/8 handling equipment.Clear and clean rig floor.Rig maintenance while waiting on work boat.;Strap and pick up polish/gauge assembly(BHA#7).RIH on 4 1/2" drill pipe to 1722'.;Continue to RIH with BHA#7 to 9508'(Fill pipe every+/-2500').;Fill pipe,Wash and Ream to 9712'-Tight hole encountered at 9642',had to ream through several times to clean up this section.PUW 94K,SOW 68K,ROT 84K, TO 7K @ 95 RPM.;Wellhead pressures:24"=58 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 0.0 lbs. Total:365 lbs, • 5/30/2017 Wash and ream from 9712'to 9855',tight hole encountered at 9642',ream through several times to clean up this section.UW 94K,DW 68K,ROT 84K, TQ 7K @ 95 RPM.;Circulate 20 bbl sweep with no noticeable change at shakers.9 BPM,1955 PSI.;Pump dry job,trip out of hole with polish mill assembly to BHA.;Lay down BHA#7.;Clear and clean rig floor.;Rig up Pollard E-line,with Baker bridge plug assembly.;Run in hole with bridge plug,correlate on depth,set Baker bridge plug ton at 9788'WLM,had good indication of setting tool stroking,picked up and had lost string weight,set down and confirmed;plug set. Pulled out of hole with setting tool to 9620'WLM,pulled tight,was able to go back down continued to work tools pulling a max of 6500,pulled out of rope socket,and continued to pull;out of hole,appears that we recovered all wire leaving the setting tool,setting sleeve,firing head,quick connect,CCL,and rope socket in the hole,for a total of 10.40'of tools.Rig down E-line.;Clean and clear rig floor change out elevators to 2 7/8",pick up cement stinger.;Continue to trip in hole with cement stinger to 8500'.;Wellhead pressures:24"=58 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 0.0 lbs. Total:365 lbs. 5/31/2017 Run in hole with cement stinger from 8500'to 9779',no indication of wire line fish at 9622',tagged and set down 5K at 9779'.;Space out string,rigged up Schlumberger cementers,while circulating and conditioning mud.;Hold PJSM,pressure test lines to 550-2500 PSI. Pump 10 BBL,12.1 PPG,Mud-Push 2 spacer,followed by 20 BBL 15.8 PPG class G cement,with.1 GPS D047 Antifoam,0.1 GPS D080 Dispersant,and;.02 GPS D177 Retarder,followed by 3 BBL,12.1 PPG,Mud-Push 2 spacer,displacing with 123 BBL OBM at 8 BPM to balance plug. Estimated TOC 9515,with CIBP set at 9788',CIP at 11:45 HRS.;Pull out of hole to 9500'at 20 FPM.;Drop wiper ball,circulate at 10 BPM,1900 PSI while rotating at 25 RPM,with 5K torque.Seen slight amount of mud push back at surface with cement.;Slip and cut 205'of drill line.;Trip out of hole with BHA#8 cement stinger from 9500'to 5010'.;Service top drive,draw works and blocks and all travelling equipment.;Continue to trip out of hole from 5010'to cement stinger BHA at,325'.;Change elevators to 2 7/8"YT,break out and lay down 2 7/8"EUE tubing.;Clean and clear rig floor,rig up Pollard E-Line,run in hole with CCL and a junk basket with a 8.35"gauge ring on bottom to 9508', picked up logging found collar at 9480',POOH for CIBP.;Make up Baker CIBP and run in hole and set at 9475'(5'above casing collar at 9480'),had good indication of set,picked up and set back down to verify same,pull out of hole with setting tool,;rigged down Pollard E-line equipment.;Wellhead pressures:24" =58 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 0.0 lbs. Total:365 lbs. 6/1/2017 Change out(2)9 5/8"annulus valves.;Make up BHA#9,Baker whip stock window milling assembly,with Sperry MWD,and shallow test same,all OK.;Run in hole with Baker whip stock assembly BHA#9 to 9370',UW 122K,DW80K,orientate to 51R work down and tag top of CIBP at 9470',confirmed orientation of 51R,slacked off to 70K and tripped;anchor with 10K DW,picked up to 130K,(8K above original UW)and verified anchor set,slacked off to 55K(25K below original DW)and attachment bolt sheared. Picked up to original UW 122K and had;pipe movement,set down and tagged top of slide at 9448'. (NOTE:TOW 9448'BOW'9465').;Mill window from 9448'to 9453',GPM 340,SPP 1750PSI,RPM 80-90,TO 6-12K,WOB 1-2K.;Mill window from 9453'to 9465',(Starter mill exiting casing),GPM 340,SPP 1620PSI,RPM 90-95,TQ 6-12K,WOB 2-5K.;Continue to mill window and new formation from,9465 to 9470,GPM 344,SPP 1725PSI,RPM 95-103,TQ 6-8K,WOB 3-7K.;Wellhead pressures:24"=58 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 263.0 lbs. Total:263 lbs. 6/2/2017 Drill new formation from 9470'to 9487',reamed through and drifted window with and without pumps several times without issue. GPM 344,SPP 1725PSI, RPM 95-103,TQ 6-8K,WOB 3-12K.;Circulate high viscosity sweep while working pipe,recovered 338 lbs of metal.;Pull above window to 9416'.Perform FIT to 12.5 PPG EMW.Good test.;Pump dry job,pull out of hole with BHA#9 window milling assembly to BHA.;Rack back HWDP,lay down MWD tools,break out and lay down window milling assembly,window mill and lower watermelon mills were 1/4"under gauge,upper watermelon mill was in gauge.;Flush BOP stack with wash tool,drain stack,run and set test plug with 3 stands of HWDP below,and make up test joint.;Shell test BOPE and choke to 1600 PSI,test annular to 250-2500PSI on 4 1/2"pipe for 5 minutes each test,test remainder of BOPE to 250-3500 PSI on 4 1/2"pipe for 5 minutes each.;Had 2 fail pass tests,upper VBR had to cycle to get to test and,valve#9 on choke had to lube. Performed accumulator draw down test,accumulator PSI pre-test 3000 PSI, after cycling BOPE 1450 PSI.;200 PSI 21 seconds,full recovery of 3000 PSI 138 seconds. Currently having issues with getting blinds to hold at report time.;Wellhead pressures:24"=58 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 75.0 lbs. Total:338 lbs. 6/3/2017 Finish testing BOPE as per sundry,AOGCC waived witness of test.;Break down test joint,drain stack,stand back 3 stands of HWDP.;Make up BHA#10, upload MWD and pulse test at 8.5 BPM,load RA sources,and pick up remainder of BHA.;Trip in hole with BHA#10 from 796 to 7002'.;Service draw works, top drive and travelling equipment.;Continue to trip in hole with BHA#10 from 7002'to 9369',orientate bit to 51R,slack off with pump on to 9440',continued to slack off passing through window without any drag encountered,slack off;to 9470'.;Establish parameters and slide from 9470 to 9510,rotated to 9520'putting stabilizer on ALD collar at top of window. Slide from 9520'to 9551. UW 122K,DW 80K,ROT 100K,GPM 390,SPP 2710 PSI.;Continue directional drilling from 9551'to 9630',UW 122K,DW 80K,ROT 100K,RPM 40,GPM 400,SPP 2770 PSI.;Lost a swab and liner in#1 mud pump cylinder#2,pull 3 stands to get above window,while changing swab and liner,trip back to bottom and resume drilling.;Orientate and continue directional drilling from 9630'to 9640',UW 122K,DW 80K,ROT 100K,RPM 40,GPM 400,SPP 2770 PSI.;Wellhead pressures:24"=58 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 0.0 lbs. Total:338 lbs.;Note:Currently do not have sufficient separation to get quality surveys. K-Revs on bottom 4.03 K-Revs off bottom 2.66 6/4/2017 Directional drill from 9640'to 9770'. UW 122K,DW 80K,ROT 100K,RPM 60,WOB 8-12K,GPM 400,SPP 3090 PSI.Mad-Pass all slides.;Directional drill from 9770'to 9969'. UW 122K,DW 80K,ROT 100K,RPM 60,WOB 8-12K,GPM 400,SPP 3090 PSI.Mad-Pass all slides.;Directional drill from 9969'to 10116'. UW 140K,DW 88K,ROT 106K,RPM 60,WOB 8-12K,GPM 400,SPP 2850 PSI.Mad-Pass all slides.;Directional drill from 10116'to 10234'. UW 140K,DW 86K,ROT 107K,RPM 72,WOB 6-12K,GPM 400,SPP 2950 PSI.Mad-Pass all slides.;Wellhead pressures:24"=58 psi,13 3/8"=30 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:1.5 hrs. Metal recovered today: 16.0 lbs. Total:354 Ibs.;Last survey:MD 10136.80',INC 22.33,AZM 243.21,TVD 7478.02 Distance to plan 46.56',19.52'Low,42.27'Left K-Revs on bottom 30.23 K-Revs off bottom 15.89 • • 6/5/2017 Troubleshoot#1 HPU tripping issue,replace failed wiring to injectors.;Directional drill from 10,234'to 10,300'. UW 140K,DW 86K,ROT 107K,RPM 72,WOB 6-12K,GPM 400,SPP 2950 PSI.Mad-Pass all slides.;Directional drill from 10,300'to 10,414'. UW 140K,DW 86K,ROT 107K,RPM 72,WOB 6-12K,GPM 400,SPP 2950 PSI.Mad-Pass all slides.;Directional drill from 10,414'to 10,528'. UW 142K,DW 93K,ROT 112K,RPM 72,WOB 6-12K,GPM 400,SPP 2850 PSI.Mad-Pass all slides. Pumped high viscosity weighted sweep while rotating had a 10-15%.;Increase in fine cuttings with sweep coming back,however did have a significant increase in cuttings at bottoms up after beginning rotation. (Rotation is cleaning better than sweeps).;Directional drill from 10,528'to 10,673'. UW 142K,DW 93K,ROT 112K,RPM 72,WOB 6-12K,GPM 400,SPP 2850 PSI.Mad-Pass all slides.;Wellhead pressures:24"=24 psi,13 3/8"=32 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 2.0 hrs Total:3.5 hrs. Metal recovered today: 17.0 lbs. Total:371 lbs.;Last survey:MD 10509.42',INC 16.97,AZM 207.17,TVD 7931.17 Distance to plan 14.52',6.13'Low,13.16'Left K-Revs on bottom 50.06 K-Revs off bottom 32.49. 6/6/2017 Directional drill from 10,673'to 10,820'. UW 149K,DW 92K,ROT 114K,RPM 72,TQ 9.8K,WOB 6-12K,GPM 400,SPP 3005 PSI.Mad-Pass all slides. Pumped a high viscosity weighted sweep at 10700';while rotating had a 20%increase in cuttings with sweep coming back.;Directional drill from 10,820'to 10,945'. UW 149K,DW 92K,ROT 114K,RPM 72,TQ 10.5K,WOB 6-12K,GPM 400,SPP 2925 PSI.Mad-Pass all slides.;Directional drill from 10,945'to 11086'. UW 156K,DW 95K,ROT 116K,RPM 70,TO 10.5K,WOB 6-12K,GPM 400,SPP 2850 PSI.Mad-Pass all slides.;Directional drill from 11086'to 11245'. UW 156K,DW 95K,ROT 116K,RPM 70,TQ 10.5K,WOB 6-12K,GPM 400,SPP 2850 PSI.Mad-Pass all slides.;Wellhead pressures:24"=22 psi, 133/8"=25 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 2.0 hrs Total:3.5 hrs. Metal recovered today: 29.0 lbs. Total:400 Ibs.;Last survey:MD 11131.25',INC 22.02,AZM 203.14,TVD 8518.33 Distance to plan 11.29',2.01'High,11.11'Right K-Revs on bottom 96.8 K-Revs off bottom 50.6 6/7/2017 Directional drill 8 1/2"hole section from 11,245'to 11,348',100%slide UW 157K,DW 95K,ROT 116K, WOB 4-10,400 GPM,2950 psi. MAD-Pass all slides while back reaming at 40 RPMs.;Directional drill 8 1/2"hole section from 11,348'to 11,355'.100%slide MAD-Pass all slides while back reaming at 40 RPMs.;Perform clean up cycle to aid with hole cleaning,bottoms up rotation began with MAD-Passing. Note had a 50%increase in cuttings from where we started rotating.;Directional drill 8 1/2"hole section from 11,355'to 11,417',83%slide.UW 158K,DW 95K,ROT 118K,WOB 5-10K,400 GPM,3,000 PSI;Complete bottoms up circulation while Mad-Passing,70 RPM DN,40 RPM UP.400 GPM 2815 PSI. Note had a 20%increase while rotating,with no increase at bottoms up.;Directional drill 8 1/2 hole section from 11,417'to 11,516',82%slide,UW 158K,DW 95K,ROT 118K,WOB 5-11K,410 GPM,3,940 PSI,pumping sweeps as needed.;Service top drive,draw works,HPU's and travelling equipment.;Directional drill 8 1/2 hole section from 11,516'to 11,604', 100%slide,UW 158K,DW 95K,ROT 118K,WOB 5-11K,410 GPM,3,940 PSI,pumping sweeps as needed.;Wellhead pressures:24"=22 psi,13 3/8"=25 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:3.5 hrs. Metal recovered today: 16.0 lbs. Total:416 Ibs.;Last survey:MD 11504.64',INC 33.73,AZM 204.02,TVD 8853.24 Distance to plan 25.46',16.89'High,19.06'Right K-Revs on bottom 101.22 K-Revs off bottom 68.52 6/8/2017 Finish Mad-Pass from 11,603'to 11541',rack back 1 stand to get above Coal 39. Pumped a high viscosity weighted sweep,circulating hole clean,with no increase in cuttings at bottoms up.;When sweep came back the size of the cuttings increased slightly,monitored fluid level,well was static,and we pumped a dry job.;Pull out of hole from 11541'to above window at 9448'with proper displacement,and minimal over pulls. Pulled 3-10K over,in a couple spots in open hole,;and 4K over when flex collars entered window at 9465'.;Monitor fluid level,well was static,continue to pull out of hole to MWD tools.;Conduct PJSM with Sperry and crew on removal of radioactive sources from LWD,removed sources and secured same,down loaded MWD,continued to lay down BHA,drain motor,and remove bit.;Bit appeared to be in good condition,graded at 1-1-WT-A-E-1-CT-HR, (Bit made 2115',65 HRS on bottom,575 K-Revs) Bit was pulled due to max K-Revs.;Clean and clear rig floor while monitoring well on trip tank,with well static,and no fluid losses.;Service draw works,top drive and travelling equipment.;Pick up BHA#11,make up bit and motor,pick up MWD and LWD tools,upload MWD data,shallow test MWD,have a PJSM on loading nuclear sources,and load same,make up flex collars,HWDP and jars.;Continue to trip in hole with BHA#11 from 796'to 5300'.;Wellhead pressures:24"=22 psi,13 3/8"=25 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:3.5 hrs. Metal recovered today: 10.0 lbs. Total:426 Ibs.;Last survey:MD 11565051',INC 35.68,AZM 205.20,TVD 8903.28 Distance to plan 26.26',18.04'High,19.08'Right K-Revs on bottom 6/9/2017 Continue to trip in hole with BHA#11,to 9382'.;Cut and slip 98'of drilling line.;Replace air boot on flow nipple,and stage an additional boot,that was slid over flow nipple for spare.;Run in hole from 9382'to 11,545',encountered 10K drag,going through bottom of window at 9465'.;Fill pipe,wash and ream to bottom at 11,603'.RPM 40,TQ 10-12.5K,GPM 375,SPP 2850 PSI. Note:mud is continuing to shear,staging pump rates up.;Orientate tool face to slide,make connection,and directional drill 8 1/2 hole section from 11,603'to11,661',100%slide,having issues holding tool face,GPM 385,SPP 2750 PSI,WOB 4K.;Directional drill 8 1/2 hole from 11,661'to 11762',30%slide,adding NXS lube to system in sweeps to a concentration of 1%,RPM 40,TQ 10-12.5K,GPM 400,SPP 2890 PSI,WOB 3-7K.;Perform rig service,service top drive,draw works,and HPU's.;Directional drill 8 1/2 hole from 11,762'to 11852',61%slide, adding NXS lube to system in sweeps to a concentration of 2%,RPM 80,TQ 10-12.5K,GPM 400,SPP 2890 PSI,WOB 3-15K.;Wellhead pressures:24"=22 psi,13 3/8"=25 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:3.5 hrs. Metal recovered today: 26.0 lbs. Total:452 Ibs.;Last survey:MD 11753.93',INC 43.50,AZM 205.36,TVD 9047.50 Distance to plan 26.98'.17.35'High.20,66'Right 6/10/2017 Directional drill 8 1/2 hole section,from 11,852'to 11,868',having issues with weight transfer and holding tool face.;Decision made to pull out of hole for BHA change,mix and pump dry job.;Pull out of hole to window at 9448',had a 20K overpull at 11,736',worked back through it and it was gone,pulled 2K over when BHA came through window.;Continue to pull out of hole to 7192',when draw works started making an odd grinding sound.;Shut down and inspected draw works gear box,found metal and bearing debris in bottom of gear box,screwed in top drive,secured well,hung blocks,unstrung drilling line,and removed gear box.;Disassembled gear box found idler gear bearings and shaft damaged,the gear itself showed minimal damage on teethe,with the bearing area showing signs of wear. The gear box was flushed,;and cleaned,along with the input,output gears and bearings,all components were prepped for reassembly,while waiting on new parts. At 22:00 HRS a new idler shaft and 2 of the 4 bearings arrived.;Continue to clean and prep gear box for installation of new parts when they arrive. Crew power washing cellar and sub base,cleaning wind walls,painting roof caps,general maintenance.;Wellhead pressures:24" =10 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 11.0 hrs Total:14.5 hrs. Metal recovered today: 6.0 lbs. Total:458 lbs.;Last survey:MD 11816.69',INC 44.78,AZM 204.04,TVD 909254 Distance to plan 24.39'.14.36'High.19.72'Right • • 6/11/2017 Rig on down time,waiting on parts for draw works. The idler gear was sent to Dukowitz Machine for repair,continued with cleaning,Inspecting rig components,painting,working on rig projects,;and housekeeping. The crane crew and 3 hands went to the Dillon Platform,to prep HAK-1 pipe racks for load out,for use on GPP drilling project.;The Idler gear was returned from Dukowitz Machine. Continuing to wait on 2 bearings,while cleaning,and inspecting rig components,painting,working on rig projects,and housekeeping.;Bearings arrived on platform at 18:00 HRS,Kuukpik Mechanic is assembling gear box with the new bearings,new shaft and the repaired idler gear.;lnstall repaired gear box on draw works,install hydraulic motor and hook up hydraulic lines,encoder, fill with oil,and test run same,reinstall drilling line and spool up draw works.;Trip out of hole with BHA#11 from 7188'to 2870'.;Wellhead pressures:24"=10 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 21.0 hrs Total:35.5 hrs. Metal recovered today: 0.0 lbs. Total:458 lbs.;Last survey:MD 11816.69',INC 44.78,AZM 204.04,TVD 909254 Distance to plan 24.39',14.36'Hiah,19.72'Right 6/12/2017 Pull out of hole with BHA#11,from 2870'to MWD tools.;Remove nuclear sources,down load MWD,pick up and inspected bit,found the upper bit gauge was grooved and the side cutters were chipped,drained motor and broke bit. Picked up BHA#12,made up.;Security 8.5"HDBS MMD75DC(7)blade bit,made up MWD tools with a new pulser and installed a new battery in same,Sperry uploaded data to MWD.;Tested MWD tools,received a good pulse,loaded nuclear sources in LWD tools,made up flex collars,moved HWDP up hole 869',made up agitator at 1270',ran 1 stand of drill pipe to 1384',;tested MWD with the agitator,and was able to receive a good signal.;Continue to trip in hole with directional drilling BHA#12,filling pipe at 5462'and at top of widow at 9422', orientate tool face 52R prior to entering window.;Perform rig service,lube swivel packing,serviced top drive and draw works.;Enter and exit window with bit, had a 2-3K bobble while travelling through widow,and we did have a 8K bobble when stabilizer on ALD collar entered window,and continue to trip in hole to 11869'.;Directional drill 8.5"hole section per WP07 from 11869'to 11980',MAP-Pass all slides, RPM 85,TQ 11-12.5K,GPM 400,SPP 3150 PSI,WOB 3-7K, UW 190K,DW 120K,ROT 145K.;Wellhead pressures:24"=10 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0 HRS Total:35.5 HRS. Metal recovered today: 0.0 lbs. Total:458 lbs.;Last survey:MD 11874.12',INC 47.23,AZM 203.61,TVD 9132.43 Distance to plan 20.66',10.72'High,17.66'Right 6/13/2017 Directional drill 8 1/2 hole f/11,869'to 12,099.390 GPM,3100 Psi, 250 Psi Diff,3 U 9k WOB,Max Gas 53 units.;Packing went out of TD washpipe,Stand back std we were drilling with and pull one stand.Change our washpipe packing,Screw into TD and test,Still leaking,Change out WP again and test.Good test.;MU std and orientate tool.Make connection bring on pumps and check orientation.;Directional drill 8 1/2 hole f/12,099't/12,190'.385 GPM,3,000 Psi,Diff press 165 Psi.4 U 10k WOB,Max Gas 60 units.;Directional drill 8 1/2 hole f/12,190't112,409'.369 GPM,2800 PSI,80 RPM,15 TQ,7-10K WOB,Max Gas 114 units(MAD pass slide intervals).;Service Rig Drawworks,Top Drive,Traveling equipment and HPU's. Take Slow Pump Rates(#1=262psi@30spm,320 psi@40spm and #2=318psi@30spm,403psi@40spm).;Directional drill 8 1/2 hole f/12,409'V12,441'.369 GPM,2800 PSI,80 RPM,15.5 TQ,12K WOB,Max Gas 169 units.;Directional drill 8 1/2 hole f/12,441'U 12,730'. 381 GPM,3037 PSI,95 RPM,13.8K TQ,9.5K WOB, SOW=144K,PUW=196K, RT=146K.;Wellhead pressures:24"=14 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 2.5 HRS Total:38.0 HRS. Metal recovered today: 9.0 lbs. Total:467 lbs.;Last survey:MD 12,681',INC 65.22,AZM 205.58,TVD 9521 Distance to elan 3.95'.0.87'Low.3.85'Left 6/14/2017 Directional drill 8 1/2 hole f/12,730'U 12,807'.Pumped sweep while drilling this dn.Sweep came back on time with a 50%increase of heavy fines and 1/2"t/ 3/4"flakes of coal.380 GPM,2960 psi,;90 RPM,15k TQ. At 12,807 we started loosing pump press.We tested all the surface equip and it was good.;POH Looking for washout.Pulled up to 40k over several times f/12,288'U 12,150'where we finished build&started rotating.Had to work all the BHA through this area then it pulled free.Found;WO 1983'down hole-'1'below the box end tool joint. Change out jt and RIH.Had to work thru spots from 12,160'U 12,280', with set downs of 20k.Wash last 20 foot to bottom and got slow pump rates.;Slide drill f/12,807'U 12,819'to make a slight correction.380 GPM.3000 Psi.;Directional drill 8 1/2 hole f/12,819 t/12,915'.370 GPM,2975 Psi,150 Diff,14k TQ,90 RPM,6 U 11k WOB,Max gas 90 units,Mud wt 9.1+,ECD 9.53 ppg,No losses to well.;Directional drill 8 1/2 hole f/12,915'U13,028'. 375 GPM,2993 Psi,177 Diff,14k TQ,83 RPM,12.2k WOB,Max gas 65 units,Mud wt 9.1+,ECD 9.56 ppg,No Losses to well.;Pumped 20 bbl High Vis/High Wt.Sweep around while drilling ahead @ 12,968'.Sweep came back on time with a 10%increase in cuttings(fines&1/2"flakes of coal)across shakers for—10 minutes.;Service Drawworks,Top Drive,Traveling Equipment and HPU's.;Directional drill 8 1/2 hole U 13,028'U13,216'. 381 GPM,2989 Psi,128 Diff,13k TQ,98 RPM,10 k WOB,Max gas 29 units,Mud wt 9.0,ECD 9.53 ppg, No Losses to well.;Wellhead pressures:24"=14 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:38.0 HRS. Metal recovered today: 6.0 lbs. Total:473 lbs.;Last survey:MD 13,115.77,INC 63.45,AZM 209.99,TVD 9710.92' Distance to plan 5.54',0.06'Low,5.54'Left 6/15/2017 Directional drill 8 1/2"hole U 13,216 t113,340',390 GPM,3100 Psi,85 RPM,12-14k TQ,8-12 WOB,Up 205,Dn 120,Rt 147.Pumped High wt,High vis, Nutplug,and Lube sweep.;New TD is 13,448 as per Hilcorp geologist.;Directional drill 8 1/2"hole f/13,340'U 13,427'.Sweep came back on time with a 50% increase in granular size coal cuttings.Sweep kept coming back for about 15 min.;Lost a liner gasket on#1 mud pump.Pump with#2 pump while working on #1 pump.Have a small wash in the#1 pump mud end.Brought#2 pump up to 300 GPM and got a good signal.;Directional drill 8 1/2"hole w/#2 pump U 13,427'U 13,448'.300 GPM,2030 psi,90 RPM,13k TQ.;Circulate and condition well.Pumped 20 bbl high vis high wt sweep.Sweep came back on time with no visual increase in cuttings.;Monitor well(static).Pull first 5 stands wet PUW 208K,tight spot at 13340'with 14K overpull.;Pump Dry Job and install pipe wiper.;POOH, Tight spots observed at 13072'(12K),12246'(16K),12140'-12196'(40K). Worked areas and cleaned up.No noticeable overpull entering window.;Wellhead pressures:24"=18 psi,13 3/8"=24 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 1.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs.;Last survey:MD 13,448.00,INC 61.35,AZM 211.95,TVD 9864.34 Distance to plan 10.19'.6.72'Low.7.66'Right 6/16/2017 POH V 1678'laying dn DP.Lay dn the agitator at 1292',and continue LD DP to XO above jars.;LD jars and stand back HWDP.Stand back flex collars. Remove sources.Download MWD tools.Lay dn all the smart iron.Pull motor and break bit.Bit grade=3-2-RO-C-X-I-BT-TD.Pic in O-drive.;Clear and clean floor.Get measurements for links to attach new TD to blocks.;Service rig.Changed out accumulator air pump while servicing rig.;PU mud motor and set at 0 degrees.MU Smith mill tooth bit.Run the rest of the BHA and RIH PU 58 jts of DP.Run HWDP,fill pipe, and continue RIH to 3600'.;Continue RIH fill pipe every 3000'to 9441'. PUW=110, SOW=80.;Cut/Slip 150'drill line.;Continue to RIH to 12,175' where string took 15k above down weight(filled pipe 11,9931;Attempt to work through tight hole f/12,175'-12,190'. Sat down 40k and unable to go through,pulled up and had overpull of 40K.Kelly up, wash and ream from 12,180'to 12,242'.;Back ream to 12,163'where motor stalled.Sat back std#185,back ream std#184 f/12,180'to 12,118',reamed back down and was then able to pull up and run back down V 12,118'to 12,180'dry;without overpull or taking weight. PUW=146,SOW=90,ROT=120,300 gpm/1500 psi,70 rpm/12k tq.;RIH to bottom @ 13,448'.;Break circulation and pump 20 bbl High Vis/High WT Nutplug,and Lube Sweep.Sweep came back on time and we observed apx.100%increase in cuttings for the next 100 bbl.Mix and pump second sweep.;Wellhead pressures:24"=16 psi,13 3/8"=24 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs.;Last survey:MD 13,448.00,INC 61.35,AZM 211.95,TVD 9864.34 Distance to plan 10.19',6.72'Low,7.66'Right S • 6/17/2017 Circ second sweep around.came back on time with a 50%increase in cuttings.Circ until clean at 430 GPM,and 3000 Psi.Monitor well.Pump dry job.;POH to 12,326'and started to encounter overpulls.Pulled up to 35k over on several spots up to 12234.Worked pipe back through until pipe pulled free.At 12,136 it started to get tighter and had;to start pulling up to 45k over working through tight spots to 12,067'.;Pulled w/no overpulls f/12,067'to window.Pulled up to 9350'.No over pull coming through window.;RU to test BOPs,MU test jt with hanger to DP string,Hang string off on test jt.Pre test annular while waiting on state man.;Test BOP w/state inspector Lou Laubenstein Witnessing the test.Tested annular to 250 and 2500 psi.Test upper pipe rams to 250 psi and attempt to test to 3500 psi.At 3000 psi it started to;bleed off fast.Check all equip and narrowed it down to the test plug.Pulled test plug and found sections of the test plug rubber gone.Replace rubber and attempt 2 more times w/same results.;Test gas alarms while trying to get test plug to hold.;Pull test plug again and replace a different type of rubber and the plug held.Test all other BOP equip 250 low and 3500 psi high.;Rig down test equipment,drain stack,break down test joint and plug.Blow down lines.;RIH from 9350'to 11,993'and fill pipe.No additional weight taken going through window @ 9448'.;RIH working tight spots from 12,048'to 12,279'took 5-25k down with no overpull picking up. Continue RIH from 12,279'to 12,551'.;Circulate and condition hole at 435 gpm w/ 2949 psi,rotate at 115 rpm and reciprocate pipe.Pump High WT/High Vis sweeps.Observed increase in cuttings at shakers apx 50 bbl ahead of bottoms up.;tst sweep back on time with 100%increase in cuttings across shakers.2nd sweep back on time with 50%increase in cuttings across shakers. Monitor well and pump dry job.;POH f/12,551'to 11,806' (18k overpull at 12,006'-worked twice and hole cleaned up).;Wellhead pressures:24"=16 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs.;Last survey:MD 13,448.00,INC 61.35,AZM 211.95,TVD 9864.34 Distance to plan 10.19',6.72'Low,7.66'Right 6/18/2017 POH f/11,806 to window w/no over pull.Continue POH laying down extra DP not needed to run 7"liner.Vac football through each jt to clean out OBM.;Continue PON laying do DP U 5465'.POH standing back DP and HWDP.POH to Flex collars.;Lay down BHA#13,Clean rig floor and remove Halliburton transducers from mud line.;Make up test joint and test plug,seat test plug in well head.;Change lower pipe rams to 7"fixed bore rams.;Fill stack with water and attempt to test lower rams.Test plug leaked.Pull test plug and replace seal.Test 7"rams with 250/3500 psi-GOOD.;Pull test joint and test plug,rig down test equipment and secure well.;Rig up to run 7"liner.;PJSM with Weatherford,Baker and rig crews on running 7"liner.;P/U and run 7"liner as per program.Made up and thread locked shoe track assembly,checked float equip.for proper operation.Filling every jt.with fill up line.Torque connections to 19,500 ft/lbs.;Wellhead pressures:24"=18 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. 6/19/2017 RIH PU 7"liner to 4209'Installing centralizers on every other jt up to 3,341'.This will put centralizers up to 10,016'when on bottom.;PU Baker liner hanger. Mix pal and fill tieback sleeve.Let mix set up for 30 min.;Run one std of DP and circ liner vol of 157 bbls. Up wt 72k.;RIH filling every ten stands while lowering the pipe.Stop just inside the window at 9395'.;Fill pipe and continue circ while cutting drilling line.;Service Drawworks,Top Drive and Blocks.;Make up cement head and lay down same.Get parameters prior to exiting window.PUW=125k,SOW=88k,RT=108,TQ=7-8.5k @ 14,20&30 rpm,127gpm=418 psi.;RIH filling pipe every ten stands while lowering.Started taking weight @ 12,235'.Work pipe down to 12,288'with 10k to 20k additional down weight.Free movement of pipe up to 12,261'where we;overpulled up to 45k.Circ @ 1 bpm w/350 psi attempted to rotate and stalled out w/21k of torque. UP wt=180k, DN Wt.=90 k (maximum set down=50k,maximum pull=260k).;Work pipe down to 12,288'while rotating w/56 rpm-15/16k tq.,circulating @ 97 gpm w/ 430 psi(max allowable psi on liner hanger is 1200 psi).Unable to get past 12,288'going down.Back ream;up to 12,261' with 53 rpm-16k tq,97 gpm-394 psi.Work pipe multiple times before gaining movement up to 12,234'.Wash and ream down to 12,288'.Work through tight hole and down to 12,309'.;Pick up std of DP,wash and ream down to 12,372'with 58 rpm-16/18k tq,82 gpm-300psi.;RIH washing down 7"liner from 12,372'to 13,400'.;Wellhead pressures: 24"=20 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. 6/20/2017 Finish washing to bottom f/13,345',to 13,432'.PU crnt head and finish washing to bottom at 13,448'.;Circ and condition mud,Stag pump up to 5 BPM and reciprocating pipe,Up wt 200k,Dn wt 100k,575 Psi.Mixing 25 bbls MudPUSH and shipping extra OBM to uprights while circ.;Hold PJSM for cementing w/ everyone involved.Test lines at 5600 psi.Pump 15 bbl 12.2 ppq mud push,drop bottom plug..SLB had issues with batch mixer. Pump 112 bbls Class G cement,4.5 bbls;water.Drop dart and chase with 10 bbls mud push,247 bbls OBM.Bumped plug 10 bbls early with 500 psi over.Check floats(good).Set C'� liner hanger/packer as per Baker hand.Good indication of set;and release.New TOL at 9204'. Break and lay down cement head.;Drop pipe wiper.Circulate surface to surface at 6.3 BPM/800 psi.No cement seen at surface.;Pump dry job.POOH with running tool to 2250',PUW=92k.;Service TD,Drawworks and IX Pipe spinners.;Continue to POOH with running tool.Make service breaks on running tool,Dog sub sheared as required indicating a good set of packer.;Lay down liner running tool and clean floor.;Make up test plug to test joint and set test plug in well head.Change lower pipe rams to 2-7/8"X 5"variables.;Rig up and test lower pipe rams on 4 1/2"test joint.250/3500 psi for 5 minutes each and charted.;Rig down test equipment,lay down test joint and plug.;Pick up 6" bit,7"casing scraper and RIH for liner clean out.Spaceout 9-5/8"casing scraper to be—30'above liner top with bit at 7"landing collar.;Wellhead pressures: 24"=20 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs 6/21/2017 RIH with 7"x 9 5/8"clean out assembly from 4100'to 9471'with pipe out of derrick.Did not see TOL at 9204';RIH with clean out assembly picking up drill pipe from 9471'to 13,286'. Wash down.Tag landing collar at 13,311'.P/U 140,,S/O 92,Rot 115/40 RPM:Circulate and condition mud.7.8 BPM/2450 psi.Had trace of cement and mud push at bottoms up.;Test casing at 2600 psi on chart for 30 minutes.Bled off to 2500 psi.Pumped 9 bbls with 8.6 bbls returned. Good test.;Transfer OBM from rig pits to 400 bbl uprights while waiting on boat with ISO tanks.;Offload 5 each 130 bbl ISO tanks from boat.Transfer OBM from upright tanks to the ISO tanks and load ISO tanks on boat.;PJSM on displacing well from OBM to FIW.Pump 18 bbl spacer and displace OBM with FIW. 5 bpm /1250 psi.Rotate(40 rpm/9-10k tq.)and reciprocate pipe(115 up/110 dn);Continue displacing well from OBM to FIW while rotating and reciprocating.Clean FIW back to surface @ 0200 hours.Mud out of balance,continue circulating until balanced.;Short Trip to 9839'(PUW=152k)and start back in the hole to 13,311';Wellhead pressures:24"=22 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today, 0.0 lbs. Total:473 lbs. 6/22/2017 Short trip RIH to 13,311'.;Circulate and prepare to displace well to 6%KCL.;Circulate well with FIW to production at 4.5 BPM/680 psi.Displace with 6%KCL to production at same rate.;Continue cleaning pits and rig components.Received and filled 3 each 130 bbl ISO tanks with OBM from pits and uprights.Loaded ISO tanks back on boat.;Lay down 17 jt.4-1/2"DP and POOH with dual scraper assembly standing back DP.;Wellhead pressures:24"=21 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. • Hilcorp Energy Company Composite Report Well Name: MRF K-03RD2 Field: County/State: ,Alaska (LAT/LONG): avation(RKB): API#: Spud Date: Job Name: 1711118C K-03RD2 Completion Contractor AFE#: 1711118C AFE$: 6/23/2017 POOH laying down HWDP and BHA.,Flush stack with'johnny whacker'.Clear rig floor.,Rig Pollard E-line. Run CCUCBUGR. Tag landing collar at 13,311'. Log up to 9100'. Rig down Pollard E-line.,Rig up to run perf guns.Hold PJSM with all involved.,RIH picking up Expro TCP perf guns.(1049'of 4 1/2"perf guns,6 SPF).,Make up perf guns on 4-1/2"DP and RIH to 9175'. PUW=80k,SOW=64k.,Slip and cut 184'drill line.,Continue to RIH with perf guns to 11,046', SOW=62k inside 7"liner.,Wellhead pressures:24"=22 psi,13 3/8"=23 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. 6/24/2017 Continue to RIH with pert guns from 11.046'to 13.294'. Space out to place guns on depth. P/U 109,S/0 72.,R/U Pollard E-line.Correlate gun depth and determine RA marker putting depth 2 feet too high. POOH and R/D Pollard.,Adjust string 2'down hole. Set packer and rig up'bubble hose'.,Pressure up annulus to 2000 psi and fire guns.Good indication of detonation.Top of perfs @ 12,244',bottom of perfs @ 13,293'.,Pick up to open by-pass.Circulate through gas buster at 3 BPM/200 psi to vacate gun gas.Took 24 bbls to catch fluid.,Release packer.Monitor well and establish loss rate of 14 bbls./hr.,POOH laying down DP from 13,293'to 11,354'.,Service Top Drive, Blocks and Drawworks.,Misalignment of valve while transferring OBM to ISO tanks from upright tanks resulted in contamination of fluids in mud pits.Transferred contaminated mud out and cleaned pit 5.Build volume to resume POOH. Hole taking 4.8 bbl/hr.,Resume POOH laying down DP from 11,354'to 4946'. Avg.fluid loss to hole=8 bbl/hr.,Wellhead pressures:24"=22 psi, 13 3/8"=23 psi ,/� Fluid loss to well today:84.0 bbls. Total:399 bbls. • �` Code 8 today: 0.0 HRS Total:39.0 HRS. I Metal recovered today: 0.0 lbs. Total:473 lbs. 1-114 6/25/2017 Resume POOH laying down DP from 4946' to perforation gun assembly. Avg.fluid loss to hole=8 bbl/hr.,Hold PJSM.Make up safety joint.POOH laying down perf guns. All shots fired. (11.4 BPH loss rate).,Clear and clean rig floor,catwalk,etc.Spot Summit ESP equipment.,Picking up ESP equipment to 160'. Picked up 2 motors,lower and upper tandem seals, gas separator/intake,2 pumps,ported pressure sub,discharge,X/O and 1 joint of 4-1/2"tubing.(8.4 BPH loss rate).,Rig up Weatherford tongs,PJSM and conduct a cable cutting drill.(11 BPH loss rate).,Run in hole with ESP f/160'to 1549'picking up 4-1/2"tubing. Installing cannon clamps on every joint for first 60 joints,and checking continuity every 1000'.(8.4 BPH loss rate).,Wellhead pressures:24"=26 psi,13 3/8"= 23 psi Fluid loss to well today:84 bbls. Total:584 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. 6/26/2017 Run in hole with ESP f/1549'to 5075'picking up 4-1/2"tubina,, Installing cannon clamps on every joint for first 60 joints,and checking continuity every 1000'. (8.4 BPH loss rate).,Make cable splice at 5075'.Back load work boat.,Resume runing in hole with ESP f/5075'to 8692'picking up 4-1/2"tubing. Installing cannon clamps on every other joint,and checking continuity every 1000'.(11.4 BPH loss rate).,Pick up X-Nipple, one joint of 4-1/2"tubing and Packer assembly. Position packer for splice.,Make splice into packer and tie in control lines.Unstring cable and change out spools.String new cable through sheave. Tie up through the bottom of packer plug and into top of Packer.Test for continuity.Good test,MU control line to vent valve and test.Valve opened at 3500 psi. Pick up SSSV.Tie in control line to SSSV and test.Valve opened at 1500 psi.(10 BPH loss rate).,Resume running in hole with ESP f/8787'to 9085'picking up 4-1/2"tubing(5 BPH loss rate).,Make up tubing hanger.,Wellhead pressures:24"=28 psi,13 3/8"=23 psi Fluid loss to well today:200 bbls. Total:784 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. 6/27/2017 Complete capillary terminations in tubing hanger,and land same,UW 120K, DW 70K.,Engage lock down screws,deploy setting bar,and make up circulating lines. Pressure tubing up to 3800 PSI to set Tri-point 9.625 dual ESP hydraulic packer holding pressure for 30 minutes. Rig up Pollard slick line,and retrieve setting tool and RHC plug.,Attempt to test packer to 1500 PSI,and was unable to obtain passing test after 8 attempts. Note:best test lost 200 psi in 15 minutes. Consult with engineer,and decision was made to proceed with nipple down and retest with tree on.,Laid down landing joint,and set BPV.,Rig down Weatherford equipment,clean and clear rig floor of all excess equipment.,Blow down top drive,clean pill pit and mix 20 BBL of hot soapy water,pump through mud lines,mud pumps#1 and#2,along with charge pumps,rig down rig tongs,and remove choke and kill lines.,Pull rotary table,clean same,along with drip pan and rotary beams. Pick up a 5'pup joint and cycled annular while washing top of element and inside of annular. Rig up lines to pump FIW W/6%KCL& soap to TBPF,while hot bolting riser and spacer spool.,Pump 90 BBLS of FIW 6%KCL with soap from pit cleaning and equipment flushing to TBPF,rig down circulating equipment while continuing to nipple down BOPE.,Nipple down BOPE,setting BOP on trolley,and rolling back,remove riser.,Clean and inspect top of tubing hanger found one of the hanger body seals had rolled off and was cut while landing same. Nipple up tree components orientating same per production,while removing rams from BOP's. Tested hanger void to 250 PSI low and 5000 PSI high.,Wellhead pressures:24"=28 psi,13 3/8"=23 psi Fluid loss to well today:51 bbls. Total:835 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. • S 6/28/2017 Test Tri-point packer to 1700 PSI on chart for 30 minutes. Assist production with flow lines on tree. Pull 4"CIW Type"H"BPV and install TWC,and test tree connections to,250 PSI low,3500 PSI high. Removed TWC and handed well over to production.,Continue removing rams from BOP and cleaning same, while cleaning shaker area and rigging down gas buster.,No further activity on this AFE.,Wellhead pressures:24"=28 psi,13 3/8"=23 psi Fluid loss to well today:51 bbls. Total:835 bbls. Code 8 today: 0.0 HRS Total:39.0 HRS. Metal recovered today: 0.0 lbs. Total:473 lbs. • • Hilcorp Alaska, LLC McArthur River Field King Salmon K-03RD2 50733200740200 Sperry Drilling Definitive Survey Report 20 June, 2017 HALLIBURTON Sperry Drilling • • Halliburton Definitive Survey Report .....� ��...>,... .. .... . ....AFS..;; Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft S Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 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 K-03RD2 Well Position +N/-S 0.00 usft Northing: 2,511,793.12 usft Latitude: 60°51'55.870 N +E/-W 0.00 usft Easting: 213,767.53 usft Longitude: 151°36'21.030 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Water Depth: 73.00 usft Wellbore K-03RD2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1 (nT) BGGM2016 5/31/2017 16.06 73.75 55,434 Design K-03RD2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,422.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 231.79 ,Survey Program Date 6/20/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 25.00 2,500.00 K-03RD2 SDI Gyro(1)(K-03 PB1) NSG-CT_D/P Continuous north-seeking gyro in drillpipe 05/22/2017 2,525.00 5,800.00 K-03RD2 SDI Gyro(2)(K-03RD) NSG-CT_D/P Continuous north-seeking gyro in drillpipe 05/22/2017 5,822.00 9,422.00 K-03RD(K-03RD) CB-Gyro-MS Camera based gyro multishot 06/13/2014 9,448.00 9,825.31 MWD_Interp Azi+sag-BLIND(K-03RD2 BLIND OWSG BLIND-Sperry Recommended 06/01/2017 9,887.53 13,407.63 MWD+SC+sag(K-03RD2) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 06/05/2017 ., vas. ac* s a ss•�" n s rxsar u^*ss ss a ,rz+,x . .,...,, .,,,,,,, ,p,mt xsa c ^..X. 1 �u��Y ° ! � � � '��� s Baa, 1 Map ---- Map Map 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 0.00 0.00 0.00 0.00 -122.00 0.00 0.00 2,511,793.12 213,767.53 0.00 0.00 UNDEFINED 25.00 0.11 173.23 25.00 -97.00 -0.02 0.00 2,511,793.10 213,767.53 0.44 - 0.01 NSG-CT_D/P(1) 50.00 0.22 173.23 50.00 -72.00 -0.10 0.01 2,511,793.03 213,767.54 0.44 0.05 NSG-CT_D/P(1) 75.00 0.29 120.70 75.00 -47.00 -0.18 0.07 2,511,792.95 213,767.60 0.94 0.05 NSG-CT_D/P(1) 100.00 0.28 147.51 100.00 -22.00 -0.26 0.16 2,511,792.86 213,767.68 0.53. 0.04 NSG-CT_D/P(1) 125.00 0.09 163.73 125.00 3.00 -0.33 0.20 2,511,792.79 213,767.72 0.78 0.05 NSG-CT_D/P(1) 150.00 0.17 274.30 150.00 28.00 -0.35 0.17 2,511,792.77 213,767.69 0.87 0.08 NSG-CT_D/P(1) 175.00 0.35 146.48 175.00 53.00 -0.41 0.17 2,511,792.71 213,767.69 1.89 0.12.NSG-CT_D/P(1) 200.00 0.39 113.59 200.00 78.00 -0.50 0.29 2,511,792.61 213,767.81 0.85 0.08 NSG-CT_D/P(1) 225.00 0.25 84.65 225.00 103.00 -0.53 0.42 2,511,792.58 213,767.94 0.84 0.00 NSG-CT_D/P(1) 6/20/2017 6:54:21PM Page 2 COMPASS 5000.1 Build 81 • 0 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 Database: Sperry EDM-NORTH US+CANADA Survey ! Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (H100') (ft) Survey Tool Name 250.00 0.18 93.91 250.00 128.00 -0.53 0.52 2,511,792.58 213,768.03 0.31 -0.08 NSG-CT_D/P(1) 1 275.00 0.26 117.46 275.00 153.00 -0.56 0.61 2,511,792.55 213,768.12 0.48 -0.13 NSG-CT_D/P(1) 300.00 0.60 122.91 300.00 178.00 -0.66 0.77 2,511,792.45 213,768.28 1.37 -0.20 NSG-CT_D/P(1) 325.00 0.61 110.15 325.00 203.00 -0.77 1.00 2,511,792.32 213,768.51 0.54 -0.31 NSG-CT_D/P(1) 350.00 0.40 107.23 349.99 227.99 -0.85 1.21 2,511,792.25 213,768.72 0.85 -0.43 NSG-CT_D/P(1) 375.00 0.85 108.39 374.99 252.99 -0.93 1.47 2,511,792.16 213,768.98 1.80 -0.58 NSG-CT_D/P(1) 400.00 0.83 117.39 399.99 277.99 -1.07 1.81 2,511,792.01 213,769.31 0.53 -0.76 NSG-CT_D/P(1) 425.00 0.96 119.57 424.99 302.99 -1.26 2.15 2,511,791.81 213,769.65 0.54 -0.91 NSG-CT_D/P(1) 450.00 1.51 120.29 449.98 327.98 -1.53 2.61 2,511,791.53 213,770.11 2.20 -1.11 NSG-CT_D/P(1) 475.00 2.00 124.05 474.97 352.97 -1.94 3.26 2,511,791.11 213,770.74 2.01 -1.36 NSG-CT_D/P(1) 500.00 2.13 120.04 499.95 377.95 -2.41 4.02 2,511,790.61 213,771.49 0.78 -1.67 NSG-CT_D/P(1) 525.00 2.06 116.64 524.94 402.94 -2.85 4.83 2,511,790.16 213,772.29 0.57 -2.03 NSG-CT_D/P(1) 550.00 2.07 119.84 549.92 427.92 -3.28 5.62 2,511,789.71 213,773.07 0.46 -2.39 NSG-CT_D/P(1) 575.00 1.96 116.78 574.91 452.91 -3.69 6.39 2,511,789.28 213,773.83 0.62 -2.74 NSG-CT_D/P(1) 600.00 1.80 118.91 599.89 477.89 -4.07 7.12 2,511,788.88 213,774.55 0.70 -3.07 NSG-CT_D/P(1) 625.00 2.10 126.00 624.88 502.88 -4.53 7.83 2,511,788.40 213,775.25 1.54 -3.35 NSG-CT_D/P(1) 650.00 2.16 118.94 649.86 527.86 -5.03 8.62 2,511,787.88 213,776.02 1.08 -3.66 NSG-CT_D/P(1) 675.00 2.07 121.16 674.84 552.84 -5.49 9.42 2,511,787.40 213,776.81 0.49 -4.00 NSG-CT_D/P(1) 700.00 2.08 123.58 699.83 577.83 -5.98 10.18 2,511,786.90 213,777.56 0.35 -4.30 NSG-CT_D/P(1) 725.00 2.06 125.73 724.81 602.81 -6.49 10.92 2,511,786.37 213,778.29 0.32 -4.57 NSG-CT_D/P(1) 750.00 2.21 139.09 749.79 627.79 -7.12 11.60 2,511,785.72 213,778.96 2.07 -4.72 NSG-CT_D/P(1) 775.00 2.41 148.63 774.77 652.77 -7.93 12.19 2,511,784.90 213,779.53 1.73 -4.68 NSG-CT_D/P(1) 800.00 2.67 163.41 799.75 677.75 -8.94 12.63 2,511,783.88 213,779.94 2.81 -4.40 NSG-CT_D/P(1) 825.00 2.93 171.43 824.72 702.72 -10.13 12.89 2,511,782.68 213,780.17 1.88 -3.87 NSG-CT_D/P(1) 850.00 3.13 180.31 849.68 727.68 -11.44 12.99 2,511,781.37 213,780.23 2.04 -3.13 NSG-CT_D/P(1) 875.00 3.48 189.13 874.64 752.64 -12.87 12.86 2,511,779.94 213,780.07 2.47 -2.14 NSG-CT_D/P(1) 900.00 3.96 197.48 899.59 777.59 -14.45 12.48 2,511,778.38 213,779.66 2.89 -0.87 NSG-CT_D/P(1) 925.00 4.51 204.60 924.52 802.52 -16.16 11.81 2,511,776.68 213,778.94 3.04 0.72 NSG-CT_D/P(1) 950.00 5.42 212.03 949.43 827.43 -18.06 10.78 2,511,774.81 213,777.86 4.45 2.70 NSG-CT_D/P(1) 975.00 6.26 215.87 974.30 852.30 -20.16 9.35 2,511,772.74 213,776.39 3.70 5.12 NSG-CT_D/P(1) 1,000.00 7.27 219.76 999.12 877.12 -22.48 7.54 2,511,770.46 213,774.52 4.43 7.98 NSG-CT_D/P(1) 1,025.00 8.30 221.85 1,023.89 901.89 -25.04 5.33 2,511,767.96 213,772.24 4.27 11.30 NSG-CT_D/P(1) 1,050.00 9.19 224.00 1,048.60 926.60 -27.82 2.74 2,511,765.24 213,769.58 3.79 15.06 NSG-CT_D/P(1) 1,075.00 10.40 225.86 1,073.24 951.24 -30.83 -0.27 2,511,762.31 213,766.51 5.00 19.28 NSG-CT_D/P(1) 1,100.00 11.28 226.85 1,097.79 975.79 -34.08 -3.67 2,511,759.15 213,763.02 3.60 23.96 NSG-CT_D/P(1) 1,125.00 11.91 226.90 1,122.28 1,000.28 -37.51 -7.34 2,511,755.80 213,759.27 2.52 28.97 NSG-CT_D/P(1) 1,150.00 12.81 226.62 1,146.70 1,024.70 -41.18 -11.24 2,511,752.23 213,755.29 3.61 34.30 NSG-CT_D/P(1) 1,175.00 13.40 226.28 1,171.05 1,049.05 -45.08 -15.35 2,511,748.43 213,751.08 2.38 39.94 NSG-CT_D/P(1) 1,200.00 13.86 225.87 1,195.35 1,073.35 -49.17 -19.59 2,511,744.45 213,746.74 1.88 45.81 NSG-CT_D/P(1) 1,225.00 14.52 225.88 1,219.58 1,097.58 -53.44 -23.99 2,511,740.29 213,742.24 2.64 51.90 NSG-CT_D/P(1) 6/20/2017 6:54:21PM Page 3 COMPASS 5000.1 Build 81 0 I Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 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 1,250.00 14.90 225.84 1,243.76 1,121.76 -57.86 -28.54 2,511,735.98 213,737.58 1.52 58.22 NSG-CT_D/P(1) 1,275.00 15.35 225.84 1,267.90 1,145.90 -62.40 -33.22 2,511,731.55 213,732.79 1.80 64.70 NSG-CT_D/P(1) 1,300.00 16.09 225.69 1,291.96 1,169.96 -67.13 -38.08 2,511,726.95 213,727.82 2.96 71.44 NSG-CT_D/P(1) 1,325.00 16.67 225.93 1,315.95 1,193.95 -72.04 -43.13 2,511,722.16 213,722.65 2.34 78.45 NSG-CT_D/P(1) 1,350.00 17.27 225.84 1,339.86 1,217.86 -77.12 -48.37 2,511,717.21 213,717.29 2.40 85.71 NSG-CT_D/P(1) 1,375.00 17.74 225.90 1,363.70 1,241.70 -82.36 -53.77 2,511,712.11 213,711.76 1.88 93.19 NSG-CT_D/P(1) 1,400.00 18.32 226.03 1,387.47 1,265.47 -87.73 -59.33 2,511,706.87 213,706.07 2.33 100.89 NSG-CT_D/P(1) 1,425.00 18.97 226.07 1,411.16 1,289.16 -93.28 -65.09 2,511,701.46 213,700.18 2.60 108.84 NSG-CT_D/P(1) 1,450.00 19.50 226.23 1,434.77 1,312.77 -98.99 -71.02 2,511,695.91 213,694.10 2.13 117.04 NSG-CT_D/P(1) 1,475.00 20.12 226.25 1,458.29 1,336.29 -104.85 -77.14 2,511,690.20 213,687.84 2.48 125.47 NSG-CT_D/P(1) 1,500.00 20.73 226.62 1,481.71 1,359.71 -110.86 -83.47 2,511,684.34 213,681.38 2.49 134.15 NSG-CT_D/P(1) 1,525.00 21.27 226.75 1,505.05 1,383.05 -117.01 -89.98 2,511,678.36 213,674.71 2.17 143.08 NSG-CT_D/P(1) 1,550.00 22.00 226.78 1,528.29 1,406.29 -123.32 -96.70 2,511,672.21 213,667.84 2.92 152.26 NSG-CT_D/P(1) 1,575.00 22.66 226.92 1,551.42 1,429.42 -129.81 -103.63 2,511,665.88 213,660.75 2.65 161.72 NSG-CT_D/P(1) 1,600.00 23.45 227.02 1,574.42 1,452.42 -136.50 -110.79 2,511,659.38 213,653.44 3.16 171.48 NSG-CT_D/P(1) 1,625.00 23.94 227.26 1,597.31 1,475.31 -143.33 -118.15 2,511,652.73 213,645.91 2.00 181.49 NSG-CT_D/P(1) 1,650.00 24.32 227.37 1,620.13 1,498.13 -150.26 -125.66 2,511,645.99 213,638.23 1.53 191.68 NSG-CT_D/P(1) 1,675.00 24.91 227.60 1,642.86 1,520.86 -157.29 -133.34 2,511,639.14 213,630.38 2.39 202.07 NSG-CT_D/P(1) 1,700.00 25.55 227.79 1,665.47 1,543.47 -164.47 -141.22 2,511,632.16 213,622.33 2.58 212.69 NSG-CT_D/P(1) 1,725.00 26.26 228.10 1,687.96 1,565.96 -171.78 -149.33 2,511,625.05 213,614.04 2.89 223.59 NSG-CT_D/P(1) 1,750.00 26.91 228,45 1,710.32 1,588.32 -179.23 -157.68 2,511,617.81 213,605.51 2.67 234.76 NSG-CT_D/P(1) 1,775.00 27.30 228.55 1,732.57 1,610.57 -186.78 -166.21 2,511,610.47 213,596.80 1.57 246.13 NSG-CT_D/P(1) 1,800.00 28.06 228.63 1,754.71 1,632.71 -194.46 -174.92 2,511,603.01 213,587.90 3.04 257.73 NSG-CT_D/P(1) 1,825.00 28.81 228.68 1,776.69 1,654.69 -202.32 -183.86 2,511,595.36 213,578.78 3.00 269.61 NSG-CT_D/P(1) 1,850.00 29.41 228.77 1,798.53 1,676.53 -210.34 -193.00 2,511,587.57 213,569.44 2.41 281.76 NSG-CT_D/P(1) 1,875.00 30.33 228.47 1,820.21 1,698.21 -218.58 -202.34 2,511,579.57 213,559.90 3.73 294.19 NSG-CT_D/P(1) 1,900.00 30.79 228.47 1,841.74 1,719.74 -227.00 -211.86 2,511,571.38 213,550.18 1.84 306.88 NSG-CT_D/P(1) 1,925.00 31.34 228.47 1,863.15 1,741.15 -235.56 -221.51 2,511,563.06 213,540.32 2.20 319.76 NSG-CT_D/P(1) 1,950.00 31.96 228.25 1,884.44 1,762.44 -244.27 -231.32 2,511,554.59 213,530.30 2.52 332.85 NSG-CT_D/P(1) 1,975.00 32.68 228.17 1,905.56 1,783.56 -253.18 -241.28 2,511,545.93 213,520.12 2.89 346.19 NSG-CT_D/P(1) 2,000.00 33.09 228.26 1,926.56 1,804.56 -262.22 -251.40 2,511,537.13 213,509.78 1.65 359.74 NSG-CT_D/P(1) 2,025.00 33.54 228.33 1,947.45 1,825.45 -271.36 -261.66 2,511,528.25 213,499.31 1.81 373.44 NSG-CT_D/P(1) 2,050.00 33.63 228.40 1,968.28 1,846.28 -280.55 -271.99 2,511,519.32 213,488.75 0.39 387.25 NSG-CT_D/P(1) 2,075.00 33.82 228.32 1,989.07 1,867.07 -289.77 -282.37 2,511,510.35 213,478.16 0.78 401.10 NSG-CT_D/P(1) 2,100.00 33.91 228.42 2,009.83 1,887.83 -299.02 -292.78 2,511,501.36 213,467.52 0.42 415.01 NSG-CT_D/P(1) 2,125.00 33.85 228.39 2,030.58 1,908.58 -308.28 -303.20 2,511,492.36 213,456.88 0.25 428.92 NSG-CT_D/P(1) 2,150.00 33.65 228.53 2,051.37 1,929.37 -317.49 -313.60 2,511,483.41 213,446.26 0.86 442.79 NSG-CT_D/P(1) 2,175.00 33.69 228.54 2,072.18 1,950.18 -326.66 -323.98 2,511,474.49 213,435.65 0.16 456.63 NSG-CT_D/P(1) 2,200.00 33.65 228.48 2,092.98 1,970.98 -335.85 -334.36 2,511,465.56 213,425.05 0.21 470.46 NSG-CT_D/P(1) 2,225.00 33.76 228.48 2,113.78 1,991.78 -345.04 -344.75 2,511,456.63 213,414.44 0.44 484.31 NSG-CT_D/P(1) 6/20/2017 6:54:21PM Page 4 COMPASS 5000,1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 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 2,250.00 33.59 228.40 2,134.58 2,012.58 -354.24 -355.12 2,511,447.69 213,403.84 0.70 498.15 NSG-CT_D/P(1) 2,275.00 33.60 228.39 2,155.41 2,033.41 -363.42 -365.47 2,511,438.76 213,393.28 0.05 511.96 NSG-CT_D/P(1) 2,300.00 33.63 228.47 2,176.23 2,054.23 -372.61 -375.82 2,511,429.83 213,382.70 0.21 525.78 NSG-CT_D/P(1) 2,325.00 33.69 228.50 2,197.04 2,075.04 -381.79 -386.20 2,511,420.90 213,372.10 0.25 539.61 NSG-CT_D/P(1) 2,350.00 33.67 228.35 2,217.84 2,095.84 -390.99 -396.57 2,511,411.96 213,361.51 0.34 553.45 NSG-CT_D/P(1) 2,375.00 33.65 228.27 2,238.65 2,116.65 -400.21 -406.92 2,511,403.00 213,350.94 0.19 567.28 NSG-CT_D/P(1) 2,400.00 33.41 228.30 2,259.49 2,137.49 -409.40 -417.22 2,511,394.07 213,340.41 0.96 581.06 NSG-CT_D/P(1) 2,425.00 33.56 228.30 2,280.34 2,158.34 -418.57 -427.52 2,511,385.14 213,329.89 0.60 594.83 NSG-CT_D/P(1) 2,450.00 33.46 228.22 2,301.18 2,179.18 -427.76 -437.82 2,511,376.21 213,319.37 0.44 608.61 NSG-CT_D/P(1) 2,475.00 33.57 228.17 2,322.03 2,200.03 -436.96 -448.11 2,511,367.26 213,308.86 0.45 622.38 NSG-CT_D/P(1) 2,500.00 33.32 227.98 2,342.89 2,220.89 -446.17 -458.36 2,511,358.31 213,298.39 1.08 636.13 NSG-CT_D/P(1) 2,525.00 32.59 227.06 2,363.86 2,241.86 -455.35 -468.39 2,511,349.38 213,288.13 3.54 649.70 NSG-CT_D/P(2) 2,550.00 32.60 226.79 2,384.93 2,262.93 -464.55 -476.23 2,511,340.42 213,278.07 0.58 663.11 NSG-CT_D/P(2) 2,575.00 32.93 227.12 2,405.95 2,283.95 -473.78 -488.12 2,511,331.43 213,267.96 1.50 676.60 NSG-CT_D/P(2) 2,600.00 33.53 227.66 2,426.86 2,304.86 -483.06 -498.20 2,511,322.41 213,257.66 2.66 690.26 NSG-CT_D/P(2) 2,625.00 34.09 228.16 2,447.63 2,325.63 -492.38 -508.52 2,511,313.34 213,247.11 2.50 704.13 NSG-CT_D/P(2) 2,650.00 34.68 228.67 2,468.27 2,346.27 -501.75 -519.09 2,511,304.23 213,236.32 2.63 718.23 NSG-CT_D/P(2) 2,675.00 35.77 229.04 2,488.69 2,366.69 -511.24 -529.94 2,511,295.01 213,225.23 4.44 732.63 NSG-CT_D/P(2) 2,700.00 36.51 229.27 2,508.68 2,386,88 -520.88 -541.10 2,511,285.65 213,213.85 3.01 747.36 NSG-CT_D/P(2) 2,725.00 37.53 229.42 2,528.84 2,406.84 -530.69 -552.52 2,511,276.12 213,202.19 4.10 762.40 NSG-CT_D/P(2) 2,750.00 38.55 229.45 2,548.53 2,426.53 -540.71 -564.22 2,511,266.39 213,190.25 4.08 777.79 NSG-CT_D/P(2) 2,775.00 39.34 229.65 2,567.97 2,445.97 -550.90 -576.18 2,511,256.49 213,178.04 3.20 793.49 NSG-CT_D/P(2) 2,800.00 39.97 229.74 2,587.22 2,465.22 -561.22 -588.35 2,511,246.48 213,165.63 2.53 809.43 NSG-CT_D/P(2) 2,825.00 41.03 229.73 2,606.23 2,484.23 -571.72 -600.73 2,511,236.29 213,152.98 4.24 825.66 NSG-CT_D/P(2) 2,850.00 42.19 229.73 2,624.92 2,502.92 -582.45 -613.40 2,511,225.87 213,140.06 4.64 842.25 NSG-CT_D/P(2) 2,875.00 43.48 229.57 2,643.25 2,521.25 -593.45 -626.35 2,511,215.19 213,126.84 5.18 859.23 NSG-CT_D/P(2) 2,900.00 44.22 229.39 2,661.28 2,539.28 -604.70 -639.52 2,511,204.26 213,113.40 3.00 876.54 NSG-CT_D/P(2) 2,925.00 45.15 229.34 2,679.05 2,557.05 -616.15 -652.86 2,511,193.14 213,099.79 3.72 894.10 NSG-CT_D/P(2) 2,950.00 46.22 229.30 2,696.52 2,574.52 -627.81 -666.43 2,511,181.82 213,085.94 4.26 911.97 NSG-CT_D/P(2) 2,975.00 47.32 229.15 2,713.64 2,591.64 -639.71 -680.22 2,511,170.26 213,071.86 4.42 930.17 NSG-CT_D/P(2) 3,000.00 48.24 228.96 2,730.44 2,608.44 -651.84 -694.20 2,511,158.47 213,057.58 3.72 948.66 NSG-CT_D/P(2) 3,025.00 49.44 228.83 2,746.90 2,624.90 -664.22 -708.39 2,511,146.45 213,043.10 4.82 967.46 NSG-CT_D/P(2) 3,050.00 50.41 228.70 2,762.99 2,640.99 -676.83 -722.77 2,511,134.20 213,028.41 3.90 986.56 NSG-CT_D/P(2) 3,075.00 50.66 228.53 2,778.88 2,656.88 -689.59 -737.25 2,511,121.80 213,013.62 1.13 1,005.84 NSG-CT_D/P(2) 3,100.00 51.58 228.48 2,794.57 2,672.57 -702.48 -751.83 2,511,109.26 212,998.73 3.68 1,025.26 NSG-CT_D/P(2) 3,125.00 52.03 228.44 2,810.03 2,688.03 -715.51 -766.54 2,511,096.60 212,983.71 1.80 1,044.88 NSG-CT_D/P(2) 3,150.00 52.19 228.45 2,825.38 2,703.38 -728.60 -781.30 2,511,083.88 212,968.63 0.64 1,064.58 NSG-CT_D/P(2) 3,175.00 52.43 228.40 2,840.67 2,718.67 -741.73 -796.10 2,511,071.11 212,953.52 0.97 1,084.32 NSG-CT_D/P(2) 3,200.00 52.41 228.39 2,855.92 2,733.92 -754.88 -810.91 2,511,058.33 212,938.39 0.09 1,104.10 NSG-CT_D/P(2) 3,225.00 52.70 228.37 2,871.12 2,749.12 -768.06 -825.75 2,511,045.51 212,923.23 1.16 1,123.92 NSG-CT_D/P(2) 6/20/2017 6:54:21 PM Page 5 COMPASS 5000.1 Build 81 • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft a Well: K-03RD2 North Reference: True r Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical j MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,250.00 52.84 228.32 2,886.24 2,764.24 -781.29 -840.62 2,511,032.65 212,908.04 0.58 1,143.79 NSG-CT_D/P(2) 3,275.00 52.77 228.22 2,901.35 2,779.35 -794.55 -855.49 2,511,019.76 212,892.86 0.42 1,163.66 NSG-CT_D/P(2) 3,300.00 52.55 228.23 2,916.52 2,794.52 -807.79 -870.31 2,511,006.89 212,877.71 0.88 1,183.50 NSG-CT_D/P(2) 3,325.00 52.36 228.21 2,931.75 2,809.75 -821.00 -885.09 2,510,994.04 212,862.61 0.76 1,203.28 NSG-CT_D/P(2) 3,350.00 52.79 228.12 2,946.95 2,824.95 -834.24 -899.88 2,510,981.17 212,847.50 1.74 1,223.10 NSG-CT_D/P(2) 3,375.00 52.99 228.04 2,962.03 2,840.03 -847.56 -914.72 2,510,968.22 212,832.34 0.84 1,242.99 NSG-CT_D/P(2) 3,400.00 52.76 227.90 2,977.12 2,855.12 -860.90 -929.52 2,510,955.24 212,817.22 1.02 1,262.88 NSG-CT_D/P(2) 3,425.00 52.95 227.95 2,992.21 2,870.21 -874.26 -944.32 2,510,942.25 212,802.10 0.78 1,282.76 NSG-CT_D/P(2) 3,450.00 53.00 227.88 3,007.27 2,885.27 -887.64 -959.13 2,510,929.24 212,786.97 0.30 1,302.68 NSG-CT_D/P(2) 3,475.00 53.33 227.86 3,022.26 2,900.26 -901.06 -973.97 2,510,916.18 212,771.80 1.32 1,322.64 NSG-CT_D/P(2) 3,500.00 53.63 227.75 3,037.13 2,915.13 -914.55 -988.85 2,510,903.06 212,756.59 1.25 1,342.68 NSG-CT_D/P(2) 3,525.00 53.49 227.68 3,051.98 2,929.98 -928.08 -1,003.73 2,510,889.90 212,741.39 0.60 1,362.74 NSG-CT_D/P(2) 3,550.00 53.24 227.65 3,066.90 2,944.90 -941.60 -1,018.56 2,510,876.75 212,726.23 1.00 1,382.75 NSG-CT_D/P(2) 3,575.00 52.91 227.50 3,081.92 2,959.92 -955.08 -1,033.31 2,510,863.63 212,711.15 1.40 1,402.68 NSG-CT_D/P(2) 3,600.00 53.45 227.45 3,096.90 2,974.90 -968.60 -1,048.06 2,510,850.47 212,696.08 2.17 1,422.64 NSG-CT_D/P(2) 3,625.00 54.08 227.44 3,111.68 2,989.68 -982.24 -1,062.92 2,510,837.20 212,680.89 2.52 1,442.75 NSG-CT_D/P(2) 3,650.00 54.36 227,41 3,126.30 3,004.30 -995.96 -1,077.85 2,510,823.85 212,665.63 1.12 1,462.97 NSG-CT_D/P(2) 3,675.00 54.44 227.29 3,140.85 3,018.85 -1,009.74 -1,092.80 2,510,810.45 212,650.34 0.50 1,483.24 NSG-CT_D/P(2) 3,700.00 54.31 227.25 3,155.41 3,033.41 -1,023.52 -1,107.73 2,510,797.03 212,635.08 0.54 1,503.49 NSG-CT_D/P(2) 3,725.00 54.13 227.20 3,170.03 3,048.03 -1,037.30 -1,122.62 2,510,783.62 212,619.86 0.74 1,523.71 NSG-CT_D/P(2) 3,750.00 54.47 227,13 3,184.62 3,062.62 -1,051.10 -1,137.51 2,510,770.19 212,604.64 1.38 1,543.95 NSG-CT_D/P(2) 3,775.00 54.46 227.08 3,199.15 3,077.15 -1,064.95 -1,152.41 2,510,756.71 212,589.40 0.17 1,564.22 NSG-CT_D/P(2) 3,800.00 54.55 227.01 3,213.66 3,091.66 -1,078.82 -1,167.31 2,510,743.21 212,574.17 0.43 1,584.51 NSG-CT_D/P(2) 3,825.00 54.34 227.01 3,228.20 3,106.20 -1,092.69 -1,182.18 2,510,729.71 212,558.96 0.84 1,604.78 NSG-CT_D/P(2) 3,850.00 54.69 226.96 3,242.71 3,120.71 -1,106.57 -1,197.07 2,510,716.19 212,543.74 1.41 1,625.06 NSG-CT_D/P(2) 3,875.00 55.40 226.94 3,257.04 3,135.04 -1,120.56 -1,212.04 2,510,702.58 212,528.43 2.84 1,645.48 NSG-CT_D/P(2) 3,900.00 55.37 226.93 3,271.24 3,149.24 -1,134.61 -1,227.07 2,510,688.90 212,513.06 0.12 1,665.98 NSG-CT_D/P(2) 3,925.00 55.25 226.85 3,285.47 3,163.47 -1,148.66 -1,242.08 2,510,675.22 212,497.71 0.55 1,686.46 NSG-CT_D/P(2) 3,950.00 55.07 226.88 3,299.75 3,177.75 -1,162.69 -1,257.05 2,510,661.57 212,482.40 0.73 1,706.90 NSG-CT_D/P(2) 3,975.00 55.23 226.75 3,314.03 3,192.03 -1,176.73 -1,272.01 2,510,647.90 212,467.10 0.77 1,727.34 NSG-CT_D/P(2) 4,000.00 55.42 226.75 3,328.26 3,206.26 -1,190.82 -1,286.99 2,510,634.18 212,451.79 0.76 1,747.82 NSG-CT_D/P(2) 4,025.00 55.82 226.70 3,342.37 3,220.37 -1,204.96 -1,302.01 2,510,620.41 212,436.42 1.61 1,768.37 NSG-CT_D/P(2) 4,050.00 55.63 226.68 3,356.45 3,234.45 -1,219.13 -1,317.04 2,510,606.61 212,421.05 0.76 1,788.95 NSG-CT_D/P(2) 4,075.00 55.54 226.81 3,370.58 3,248.58 -1,233.26 -1,332.06 2,510,592.85 212,405.68 0.56 1,809.50 NSG-CT_13/P(2) 4,100.00 55.96 226.82 3,384.65 3,262.65 -1,247.40 -1,347.13 2,510,579.08 212,390.28 1.68 1,830.08 NSG-CT_D/P(2) 4,125.00 56.40 226.79 3,398.57 3,276.57 -1,261.62 -1,362.27 2,510,565.24 212,374.79 1.76 1,850.77 NSG-CT_D/P(2) 4,150.00 56.18 226.87 3,412.44 3,290.44 -1,275.85 -1,377.44 2,510,551.39 212,359.28 0.92 1,871.49 NSG-CT_D/P(2) 4,175.00 55.75 226.93 3,426.43 3,304.43 -1,290.00 -1,392.57 2,510,537.60 212,343.81 1.73 1,892.13 NSG-CT_D/P(2) 4,200.00 56.03 226.98 3,440.45 3,318.45 -1,304.13 -1,407.69 2,510,523.85 212,328.34 1.13 1,912.76 NSG-CT_D/P(2) 4,225.00 55.82 226.91 3,454.46 3,332,46 -1,318.27 -1,422.82 2,510,510.09 212,312.87 0.87 1,933.39 NSG-CT_D/P(2) 6/20/2017 6:54:21PM Page 6 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 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 4,250.00 56.21 226.92 3,468.43 3,346.43 -1,332.43 -1,437.96 2,510,496.30 212,297.39 1.56 1,954.05 NSG-CT_D/P(2) 4,275.00 56.28 226.86 3,482.33 3,360.33 -1,346.64 -1,453.14 2,510,482.47 212,281.87 0.34 1,974.76 NSG-CT_D/P(2) 4,300.00 56.20 226.85 3,496.22 3,374.22 -1,360.85 -1,468.30 2,510,468.64 212,266.36 0.32 - 1,995.46 NSG-CT_D/P(2) 4,325.00 55.76 226.91 3,510.21 3,388.21 -1,375.01 -1,483.43 2,510,454.85 212,250.90 1.77 2,016.11 NSG-CT_D/P(2) 4,350.00 55.97 226.88 3,524.23 3,402.23 -1,389.15 -1,498.54 2,510,441.08 212,235.45 0.85 2,036.73 NSG-CT_D/P(2) 4,375.00 56.29 226.82. 3,538.17 3,416.17 -1,403.35 -1,513.68 2,510,427.26 212,219.96 1.30 2,057.41 NSG-CT_D/P(2) 4,400.00 56.69 226.88 3,551.97 3,429.97 -1,417.60 -1,528.89 2,510,413.38 212,204.41 1.61 2,078.17 NSG-CT_D/P(2) 4,425.00 56.28 226.91 3,565.77 3,443.77 -1,431.85 -1,544.11 2,510,399.51 212,188.85 1.64 2,098.94 NSG-CT_D/P(2) 4,450.00 55.84 227.01 3,579.73 3,457.73 -1,446.00 -1,559.26 2,510,385.73 212,173.34 1.79 2,119.61 NSG-CT_D/P(2) 4,475.00 55.22 227.03 3,593.88 3,471.88 -1,460.05 -1,574.34 2,510,372.06 212,157.93 2.48 2,140.15 NSG-CT_D/P(2) 4,500.00 56.15 227.01 3,607.97 3,485.97 -1,474.13 -1,589.45 2,510,358.35 212,142.48 3.72 2,160.73 NSG-CT_D/P(2) 4,525.00 56.12 226.91 3,621.90 3,499.90 -1,488.30 -1,604.62 2,510,344.56 212,126.97 0.35 2,181.41 NSG-CT_D/P(2) 4,550.00 55.98 226.94 3,635.87 3,513.87 -1,502.46 -1,619.77 2,510,330.77 212,111.48 0.57 2,202.07 NSG-CT_D/P(2) 4,575.00 56.27 226.92 3,649.80 3,527.80 -1,516.64 -1,634.93 2,510,316.98 212,095.97 1.16 2,222.76 NSG-CT_D/P(2) 4,600.00 56.73 226.94 3,663.60 3,541.60 -1,530.87 -1,650.16 2,510,303.12 212,080.40 1.84 2,243.53 NSG-CT_D/P(2) 4,625.00 56.66 226.93 3,677.33 3,555.33 -1,545.14 -1,665.43 2,510,289.23 212,064.79 0.28 2,264.35 NSG-CT_D/P(2) 4,650.00 56.20 226.91 3,691.15 3,569.15 -1,559.37 -1,680.64 2,510,275.38 212,049.23 1.84 2,285.10 NSG-CT_D/P(2) 4,675.00 55.61 226.91 3,705.16 3,583.16 -1,573.51 -1,695.76 2,510,261.61 212,033.77 2.36 2,305.73 NSG-CT_D/P(2) 4,700.00 55.88 226.89 3,719.24 3,597.24 -1,587.63 -1,710.85 2,510,247.86 212,018.34 1.08 2,326.32 NSG-CT_D/P(2) 4,725.00 56.11 226.84 3,733.22 3,611.22 -1,601.80 -1,725.97 2,510,234.07 212,002.88 0.93 2,346.97 NSG-CT_D/P(2) 4,750.00 56.69 226.80 3,747.05 3,625.05 -1,616.05 -1,741.16 2,510,220.19 211,987.35 2.32 2,367.71 NSG-CT_D/P(2) 4,775.00 57.10 226.79 3,760.71 3,638.71 -1,630.39 -1,756.42 2,510,206.24 211,971.74 1.64 2,388.57 NSG-CT_D/P(2) 4,800.00 56.82 226.68 3,774.34 3,652.34 -1,644.75 -1,771.68 2,510,192.25 211,956.13 1.18 2,409.45 NSG-CT_D/P(2) 4,825.00 56.58 226.69 3,788.06 3,666.06 -1,659.08 -1,786.88 2,510,178.29 211,940.58 0.96 2,430.26 NSG-CT_D/P(2) 4,850.00 56.24 226.85 3,801.89 3,679.89 -1,673.35 -1,802.06 2,510,164.40 211,925.06 1.46 2,451.01 NSG-CT_D/P(2) 4,875.00 55.79 227.24 3,815.87 3,693.87 -1,687.47 -1,817.23 2,510,150.65 211,909.55 2.22 2,471.66 NSG-CT_D/P(2) 4,900.00 54.86 228.00 3,830.09 3,708.09 -1,701.33 -1,832.42 2,510,137.17 211,894.03 4.48 2,492.17 NSG-CT_D/P(2) 4,925.00 53.64 228.96 3,844.70 3,722.70 -1,714.78 -1,847.61 2,510,124.10 211,878.51 5.79 2,512.42 NSG-CT_D/P(2) 4,950.00 52.28 230.31 3,859.76 3,737.76 -1,727.71 -1,862.81 2,510,111.55 211,863.00 6.94 2,532.36 NSG-CT_D/P(2) 4,975.00 51.21 231.47 3,875.24 3,753.24 -1,740.09 -1,878.04 2,510,099.54 211,847.47 5.62 2,551.99 NSG-CT_D/P(2) 5,000.00 50.49 232.37 3,891.02 3,769.02 -1,752.05 -1,893.30 2,510,087.96 211,831.92 4.01 2,571.38 NSG-CT_D/P(2) 5,025.00 50.28 232.90 3,906.96 3,784.96 -1,763.74 -1,908.61 2,510,076.65 211,816.33 1.84 2,590.64 NSG-CT_D/P(2) 5,050.00 50.57 232.99 3,922.89 3,800.89 -1,775.35 -1,923.98 2,510,065.42 211,800.67 1.19 2,609.90 NSG-CT_D/P(2) 5,075.00 50.34 232.83 3,938.81 3,816.81 -1,786.97 -1,939.36 2,510,054.17 211,785.02 1.04 2,629.18 NSG-CT_D/P(2) 5,100.00 50.16 232.78 3,954.79 3,832.79 -1,798.59 -1,954.67 2,510,042.93 211,769.43 0.74 2,648.39 NSG-CT_D/P(2) 5,125.00 50.39 232.78 3,970.77 3,848.77 -1,810.22 -1,969.98 2,510,031.68 211,753.83 0.92 2,667.62 NSG-CT_D/P(2) 5,150.00 50.76 232.75 3,986.65 3,864.65 -1,821.91 -1,985.36 2,510,020.38 211,738.18 1.48 2,686.93 NSG-CT_D/P(2) 5,175.00 50.75 232.74 4,002.46 3,880.46 -1,833.63 -2,000.77 2,510,009.04 211,722.49 0.05 2,706.29 NSG-CT_D/P(2) 5,200.00 50.75 232.70 4,018.28 3,896.28 -1,845.36 -2,016.17 2,509,997.69 211,706.80 0.12 2,725.64 NSG-CT_D/P(2) 5,225.00 50.63 232.59 4,034.12 3,912.12 -1,857.09 -2,031.55 2,509,986.33 211,691.14 0.59 2,744.98 NSG-CT_D/P(2) 6/20/2017 6:54:21PM Page 7 COMPASS 5000.1 Build 81 i ! Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 4 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.O0usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 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 5,250.00 50.88 232.55 4,049.93 3,927.93 -1,868.86 -2,046.92 2,509,974.95 211,675.48 1.01 2,764.34 NSG-CT_D/P(2) 5,275.00 51.34 232.47 4,065.63 3,943.63 -1,880.70 -2,062.36 2,509,963.48 211,659.76 1.86 2,783.80 NSG-CT_D/P(2) 5,300.00 51.12 232.66 4,081.28 3,959.28 -1,892.55 -2,077.84 2,509,952.02 211,644.00 1.06 2,803.29 NSG-CT_D/P(2) 5,325.00 49.87 233.29 4,097.19 3,975.19 -1,904.17 -2,093.24 2,509,940.78 211,628.32 5.36 2,822.58 NSG-CT_D/P(2) 5,350.00 49.00 234.07 4,113.45 3,991.45 -1,915.42 -2,108.54 2,509,929.91 211,612.74 4.21 2,841.56 NSG-CT_D/P(2) 5,375.00 48.41 234.51 4,129.94 4,007.94 -1,926.38 -2,123.79 2,509,919.33 211,597.23 2.71 2,860.32 NSG-CT_D/P(2) 5,400.00 48.54 235.03 4,146.52 4,024.52 -1,937.18 -2,139.08 2,509,908.91 211,581.68 1.64 2,879.01 NSG-CT_D/P(2) 5,425.00 47.58 235.88 4,163.23 4,041.23 -1,947.72 -2,154.40 2,509,898.74 211,566.11 4.60 2,897.57 NSG-CT_D/P(2) 5,450.00 46.90 236.22 4,180.20 4,058.20 -1,957.97 -2,169.62 2,509,888.86 211,550.64 2.90 2,915.87 NSG-CT_D/P(2) 5,475.00 46.92 236.33 4,197.28 4,075.28 -1,968.11 -2,184.81 2,509,879.10 211,535.21 0.33 2,934.08 NSG-CT_D/P(2) 5,500.00 46.42 236.39 4,214.43 4,092.43 -1,978.18 -2,199.95 2,509,869.40 211,519.83 2.01 2,952.20 NSG-CT_D/P(2) 5,525.00 46.90 236.38 4,231.59 4,109.59 -1,988.25 -2,215.09 2,509,859.71 211,504.45 1.92 2,970.33 NSG-CT_D/P(2) 5,550.00 46.59 236.47 4,248.72 4,126.72 -1,998.32 -2,230.26 2,509,850.01 211,489.03 1.27 2,988.48 NSG-CT_D/P(2) 5,575.00 46.54 236.48 4,265.91 4,143.91 -2,008.35 -2,245.39 2,509,840.36 211,473.66 0.20 3,006.57 NSG-CT_D/P(2) 5,600.00 46.78 236.46 4,283.07 4,161.07 -2,018.39 -2,260.55 2,509,830.69 211,458.26 0.96 3,024.69 NSG-CT_D/P(2) 5,625.00 46.72 236.39 4,300.20 4,178.20 -2,028.46 -2,275.72 2,509,821.00 211,442.85 0.31 3,042.84 NSG-CT_D/P(2) 5,650.00 46.39 236.35 4,317.39 4,195.39 -2,038.51 -2,290.83 2,509,811.32 211,427.49 1.33 3,060.93 NSG-CT_D/P(2) 5,675.00 46.16 236.43 4,334.67 4,212.67 -2,048.51 -2,305.88 2,509,801.69 211,412.21 0.95 3,078.94 NSG-CT_D/P(2) 5,700.00 46.03 236.37 4,352.01 4,230.01 -2,058.48 -2,320.88 2,509,792.09 211,396.97 0.55 3,096.90 NSG-CT_D/P(2) 5,725.00 45.73 236.40 4,369.41 4,247.41 -2,068.42 -2,335.83 2,509,782.52 211,381.78 1.20 3,114.78 NSG-CT_D/P(2) 5,750.00 45.90 236.35 4,386.83 4,264.83 -2,078.34 -2,350.76 2,509,772.97 211,366.61 0.69 3,132.65 NSG-CT_D/P(2) 5,775.00 45.02 236.41 . 4,404.37 4,282.37 -2,088.21 -2,365.60 2,509,763.47 211,351.54 3.52 3,150.42 NSG-CT_D/P(2) 5,800.00 44.64 236.37 4,422.10 4,300.10 -2,097.97 -2,380.27 2,509,754.07 211,336.63 1.52 3,167.98 NSG-CT_D/P(2) 5,822.00 44.75 239.00 4,437.74 4,315.74 -2,106.23 -2,393.35 2,509,746.12 211,323.35 8.42 3,183.37 CB-Gyro-MS(3) 5,922.00 44.25 240.00 4,509.07 4,387.07 -2,141.81 -2,453.74 2,509,712.04 211,262.11 0.86 3,252.83 CB-Gyro-MS(3) 6,022.00 43.50 243.00 4,581.16 4,459.16 -2,174.88 -2,514.63 2,509,680.47 211,200.43 2.21 3,321.13 CB-Gyro-MS(3) 6,122.00 43.00 248.00 4,654.02 4,532.02' -2,203.29 -2,576.93 2,509,653.59 211,137.45 3.46 3,387.66 CB-Gyro-MS(3) 6,222.00 43.25 249.00 4,727.00 4,605.00 -2,228.34 -2,640.53 2,509,630.10 211,073.26 0.73 3,453.13 CB-Gyro-MS(3) 6,322.00 44.25 248.00 4,799.24 4,677.24 -2,253.69 -2,704.87 2,509,606.34 211,008.32 1.22 3,519.36 CB-Gyro-MS(3) 6,422.00 45.50 248.00 4,870.10 4,748.10 -2,280.12 -2,770.28 2,509,581.52 210,942.28 1.25 3,587.11 CB-Gyro-MS(3) 6,522.00 44.00 250.00 4,941.12 4,819.12 -2,305.36 -2,835.99 2,509,557.89 210,875.97 2.06 3,654.35 CB-Gyro-MS(3) 6,622.00 45.00 250.00 5,012.45 4,890.45 -2,329.34 -2,901.86 2,509,535.54 210,809.54 1.00 3,720.93 CB-Gyro-MS(3) 6,722.00 45.50 252.00 5,082.85 4,960.85 -2,352.45 -2,969.00 2,509,514.08 210,741.85 1.51 3,787.99 CB-Gyro-MS(3) 6,822.00 45.00 251.00 5,153.26 5,031.26 -2,374.98 -3,036.35 2,509,493.20 210,673.97 0.87 3,854.84 CB-Gyro-MS(3) 6,922.00 46.00 251.00 5,223.35 5,101.35 -2,398.20 -3,103.79 2,509,471.64 210,605.99 1.00 3,922.19 CB-Gyro-MS(3) 7,022.00 46.00 250.00 5,292.81 5,170.81 -2,422.21 -3,171.59 2,509,449.29 210,537.61 0.72 3,990.33 CB-Gyro-MS(3) 7,122.00 47.50 250.00 5,361.33 5,239.33 -2,447.12 -3,240.04 2,509,426.07 210,468.58 1.50 4,059.51 CB-Gyro-MS(3) 7,222.00 47.50 251.00 5,428.89 5,306.89 -2,471.74 -3,309.53 2,509,403.17 210,398.50 0.74 4,129.34 CB-Gyro-MS(3) 7,322.00 46.75 251.00 5,496.93 5,374.93 -2,495.59 -3,378.82 2,509,381.01 210,328.65 0.75 4,198.55 CB-Gyro-MS(3) 7,422.00 46.50 251.00 5,565.60 5,443.60 -2,519.26 -3,447.55 2,509,359.04 210,259.36 0.25 4,267.19 CB-Gyro-MS(3) 6/20/2017 6:54.21PM Page 8 COMPASS 5000.1 Build 81 . 110 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 Database: Sperry EDM-NORTH US+CANADA Survey 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 7,522.00 46.50 251.00 5,634.44 5,512.44 -2,542.87 -3,516.14 2,509,337.11 210,190.22 0.00 4,335.68 CB-Gyro-MS(3) 7,622.00 45.75 253.00 5,703.75 5,581.75 -2,565.16 -3,584.68 2,509,316.51 210,121.15 1.63 4,403.33 CB-Gyro-MS(3) 7,722.00 46.00 254.00 5,773.38 5,651.38 -2,585.54 -3,653.51 2,509,297.82 210,051.85 0.76 4,470.02 CB-Gyro-MS(3) 7,822.00 45.25 253.00 5,843.31 5,721.31 -2,605.84 -3,722.04 2,509,279.20 209,982.84 1.04 4,536.42 CB-Gyro-MS(3) 7,922.00 45.25 253.00 5,913.71 5,791.71 -2,626.60 -3,789.96 2,509,260.11 209,914.43 0.00 4,602.63 CB-Gyro-MS(3) 8,022.00 45.75 255.00 5,983.81 5,861.81 -2,646.25 -3,858.51 2,509,242.14 209,845.42 1.51 4,668.65 CB-Gyro-MS(3) 8,122.00 46.00 255.00 6,053.43 5,931.43 -2,664.83 -3,927.85 2,509,225.26 209,775.65 0.25 4,734.62 CB-Gyro-MS(3) 8,222.00 47.00 255.00 6,122.26 6,000.26 -2,683.61 -3,997.92 2,509,208.21 209,705.14 1.00 4,801.29 CB-Gyro-MS(3) 8,322.00 45.00 256.00 6,191.73 6,069.73 -2,701.63 -4,067.55 2,509,191.90 209,635.09 2.13 4,867.15 CB-Gyro-MS(3) 8,422.00 45.75 256.00 6,261.97 6,139.97 -2,718.84 -4,136.61 2,509,176.38 209,565.63 0.75 4,932.06 CB-Gyro-MS(3) 8,522.00 46.00 256.00 6,331.60 6,209.60 -2,736.21 -4,206.26 2,509,160.72 209,495.58 0.25 4,997.53 CB-Gyro-MS(3) 8,622.00 45.50 256.00 6,401.37 6,279.37 -2,753.54 -4,275.76 2,509,145.10 209,425.67 0.50 5,062.86 CB-Gyro-MS(3) 8,722.00 46.00 258.00 6,471.16 6,349.16 -2,769.64 -4,345.55 2,509,130.71 209,355.51 1.52 5,127.66 CB-Gyro-MS(3) 8,822.00 44.75 257.00 6,541.40 6,419.40 -2,785.04 -4,415.03 2,509,117.02 209,285.67 1.44 5,191.78 CB-Gyro-MS(3) 8,922.00 45.00 257.00 6,612.27 6,490.27 -2,800.91 -4,483.78 2,509,102.83 209,216.56 0.25 5,255.62 CB-Gyro-MS(3) 9,022.00 45.00 258.00 6,682.98 6,560.98 -2,816.22 -4,552.81 2,509,089.22 209,147.17 0.71 5,319.33 CB-Gyro-MS(3) 9,122.00 44.50 258.00 6,754.00 6,632.00 -2,830.85 -4,621.67 2,509,076.28 209,077.97 0.50 5,382.49 CB-Gyro-MS(3) 9,222.00 42.50 252.00 6,826.56 6,704.56 -2,848.59 -4,688.12 2,509,060.18 209,011.12 4.59 5,445.66 CB-Gyro-MS(3) 9,322.00 42.00 248.00 6,900.60 6,778.60 -2,871.56 -4,751.27 2,509,038.75 208,947.41 2.74 5,509.50 CB-Gyro-MS(3) 9,422.00 41.00 249.00 6,975.49 6,853.49 -2,895.85 -4,812.92 2,509,015.98 208,885.19 1.20 5,572.97 CB-Gyro-MS(3) 9,448.00 41.26 248.74 6,995.08 6,873.08 -2,902.02 -4,828.87 2,509,010.21 208,869.09 1.20 5,589.31 BLIND(4) 9,514.10 40.53 248.65 7,045.04 6,923.04 -2,917.74 -4,869.19 2,508,995.48 208,828.40 1.11 5,630.72 BLIND(4) 9,576.62 39.01 248.56 7,093.09 6,971.09 -2,932.33 -4,906.43 2,508,981.80 208,790.82 2.43 5,669.00 BLIND(4) 9,638.24 36.33 248.46 7,141.87 7,019.87 -2,946.12 -4,941.46 2,508,968.87 208,755.46 4.35 5,705.06 BLIND(4) 9,701.76 33.63 248.35 7,193.91 7,071.91 -2,959.52 -4,975.32 2,508,956.31 208,721.28 4.25 5,739.95 BLIND(4) 9,763.19 30.29 248.23 7,246.02 7,124.02 -2,971.55 -5,005.53 2,508,945.02 208,690.79 5.44 5,771.13 BLIND(4) 9,825.31 28.63 248.09 7,300.10 7,178.10 -2,982.91 -5,033.88 2,508,934.36 208,662.16 2.67 5,800.44 BLIND(4) 9,887.53 28.26 247.93 7,354.81 7,232.81 -2,994.01 -5,061.36 2,508,923.94 208,634.42 0.61 5,828.89 MWD+SC+sag(5) 9,949.84 27.83 247.68 7,409.80 7,287.80 -3,005.08 -5,088.49 2,508,913.54 208,607.03 0.72 5,857.05 MWD+SC+sag(5) 10,012.22 27.35 247.54 7,465.09 7,343.09 -3,016.08 -5,115.20 2,508,903.19 208,580.06 0.78 5,884.85 MWD+SC+sag(5) 10,075.00 25.02 245.34 7,521.43 7,399.43 -3,027.13 -5,140.60 2,508,892.77 208,554.40 4.02 5,911.64 MWD+SC+sag(5) 10,136.80 22.33 243.21 7,578.02 7,456.02 -3,037.88 -5,162.96 2,508,882.57 208,531.78 4.57 5,935.86 MWD+SC+sag(5) 10,198.47 20.85 237.59 7,635.37 7,513.37 -3,049.04 -5,182.69 2,508,871.89 208,511.79 4.12 5,958.26 MWD+SC+sag(5) 10,259.99 18.79 234.24 7,693.24 7,571.24 -3,060.70 -5,199.97 2,508,860.66 208,494.22 3.82 5,979.06 MWD+SC+sag(5) 10,322.24 17.44 227.66 7,752.41 7,630.41 -3,072.85 -5,215.01 2,508,848.89 208,478.90 3.93 5,998.38 MWD+SC+sag(5) 10,384.25 16.49 222.22 7,811.73 7,689.73 -3,085.62 -5,227.79 2,508,836.43 208,465.81 2.98 6,016.33 MWD+SC+sag(5) 10,446.88 16.29 214.03 7,871.82 7,749.82 -3,099.49 -5,238.68 2,508,822.83 208,454.58 3.70 6,033.46 MWD+SC+sag(5) 10,509.42 16.97 207.17 7,931.75 7,809.75 -3,114.88 -5,247.76 2,508,807.67 208,445.13 3.32 6,050.11 MWD+SC+sag(5) 10,570.09 18.06 204.63 7,989.61 7,867.61 -3,131.30 -5,255.72 2,508,791.44 208,436.77 2.19 6,066.53 MWD+5C+sag(5) 10,633.11 18.25 204.07 8,049.49 7,927.49 -3,149.19 -5,263.81 2,508,773.76 208,428.23 0.41 6,083.96 MWD+SC+sag(5) 6/20/2017 6:54:21PM Page 9 COMPASS 5000.1 Build 81 0 ! Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well K-03RD2 Project: McArthur River Field TVD Reference: K-03RD2 @ 122.00usft Site: King Salmon MD Reference: K-03RD2 @ 122.00usft Well: K-03RD2 North Reference: True Wellbore: K-03RD2 Survey Calculation Method: Minimum Curvature Design: K-03RD2 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 10,695.12 18.89 204.76 8,108.27 7,986.27 -3,167.17 -5,271.98 2,508,755.98 208,419.63 1.09 6,101.49 MWD+SC+sag(5) 10,757.87 19.38 204.42 8,167.55 8,045.55 -3,185.88 -5,280.54 2,508,737.49 208,410.62 0.80 6,119.79 MWD+SC+sag(5) 10,819.36 19.03 207.56 8,225.62 8,103.62 -3,204.06 -5,289.39 2,508,719.54 208,401.32 1.77 6,137.99 MWD+SC+sag(5) 10,881.52 18.76 208.73 8,284.43 8,162.43 -3,221.80 -5,298.89 2,508,702.03 208,391.40 0.75 6,156.43 MWD+SC+sag(5) 10,945.05 19.84 205.80 8,344.39 8,222.39 -3,240.47 -5,308.49 2,508,683.60 208,381.34 2.28 6,175.52 MWD+SC+sag(5) 11,006.68 20.23 205.01 8,402.29 8,280.29 -3,259.54 -5,317.55 2,508,664.76 208,371.82 0.77 6,194.43 MWD+SC+sag(5) 11,067.92 21.51 203.47 8,459.51 8,337.51 -3,279.44 -5,326.50 2,508,645.09 208,362.38 2.27 6,213.77 MWD+SC+sag(5) 11,131.25 22.02 203.14 8,518.33 8,396.33 -3,301.00 -5,335.79 2,508,623.75 208,352.57 0.83 6,234.41 MWD+SC+sag(5) 11,193.55 21.02 203.69 8,576.29 8,454.29 -3,321.98 -5,344.86 2,508,603.01 208,342.98 1.64 6,254.51 MWD+SC+sag(5) 11,255.91 22.06 203.19 8,634.29 8,512.29 -3,342.98 -5,353.97 2,508,582.23 208,333.36 1.69 6,274.66 MWD+SC+sag(5) 11,317.23 25.34 204.19 8,690.43 8,568.43 -3,365.54 -5,363.88 2,508,559.92 208,322.90 5.39 6,296.41 MWD+SC+sag(5) 11,379.65 28.12 205.03 8,746.18 8,624.18 -3,391.06 -5,375.58 2,508,534.70 208,310.58 4.49 6,321.38 MWD+SC+sag(5) 11,441.90 31.11 204.04 8,800.29 8,678.29 -3,419.05 -5,388.34 2,508,507.03 208,297.14 4.87 6,348.72 MWD+SC+sag(5) 11,504.64 33.73 204.02 8,853.24 8,731.24 -3,449.77 -5,402.04 2,508,476.66 208,282.69 4.18 6,378.48 MWD+SC+sag(5) 11,565.51. 35.68 205.20 8,903.28 8,781.28 -3,481.27 -5,416.48 2,508,445.52 208,267.49 3.39 6,409.31 MWD+SC+sag(5) 11,628.07 38.64 206.77 8,953.14 8,831.14 -3,515.22 -5,433.05 2,508,411.98 209,250.09 4.97 6,443.34 MWD+SC+sag(5) 11,690.58 41.74 206.09 9,000.88 8,878.88 -3,551.34 -5,450.99 2,508,376.31 208,231.27 5.01 6,479.78 MWD+SC+sag(5) 11,753.93 43.50 205.36 9,047.50 8,925.50 -3,589.99 -5,469.61 2,508,338.14 208,211.71 2.89 6,518.31 MWD+SC+sag(5) 11,816.69 44.78 204.04 9,092.54 8,970.54 -3,629.70 -5,487.87 2,508,298.89 208,192.49 2.51 6,557.22 MWD+SC+sag(5) 11,874.12 47.22 203.61 9,132.43 9,010.43 -3,667.49 -5,504.55 2,508,261.52 208,174.89 4.28 6,593.70 MWD+SC+sag(5) 11,937.86 50.55 205.76 9,174.34 9,052.34 -3,711.10 -5,524.62 2,508,218.41 208,153.75 5.81 6,636.45 MWD+SC+sag(5) 12,000.14 53.99 207.26 9,212.45 9,090.45 -3,755.16 -5,546.62 2,508,174.90 208,130.69 5.84 6,680.99 MWD+SC+sag(5) 12,060.61 57.97 208.30 9,246.27 9,124.27 -3,799.49 -5,569.98 2,508,131.16 208,106.24 6.73 6,726.76 MWD+SC+sag(5) 12,122.44 60.98 207.64 9,277.67 9,155.67 -3,846.53 -5,594.95 2,508,084.75 208,080.13 4.95 6,775.48 MWD+SC+sag(5) 12,185.06 63.23 206.74 9,306.97 9,184.97 -3,895.75 -5,620.23 2,508,036.15 208,053.65 3.81 6,825.79 MWD+SC+sag(5) 12,248.94 64.13 206.17 9,335.29 9,213.29 -3,947.01 -5,645.74 2,507,985.53 208,026.89 1.62 6,877.54 MWD+SC+sag(5) 12,311.39 64.19 205.81 9,362.51 9,240.51 -3,997.54 -5,670.37 2,507,935.63 208,001.03 0.53 6,928.15 MWD+SC+sag(5) 12,372.37 64.19 205.36 9,389.06 9,267.06 -4,047.05 -5,694.08 2,507,886.71 207,976.12 0.66 6,977.40 MWD+SC+sag(5) 12,435.12 64.40 205.57 9,416.28 9,294.28 -4,098.10 -5,718.39 2,507,836.27 207,950.57 0.45 7,028.08 MWD+SC+sag(5) 12,497.96 64.56 205.57 9,443.35 9,321.35 .4,149.25 -5,742.86 2,507,785.73 207,924.85 0.25 7,078.95 MWD+SC+sag(5) 12,559.68 64.66 205.53 9,469.82 9,347.82 -4,199.56 -5,766.91 2,507,736.03 207,899.58 0.17 7,128.96 MWD+SC+sag(5) 12,620.54 64.86 205.25 9,495.77 9,373.77 -4,249.29 -5,790.52 2,507,686.89 207,874.76 0.53 7,178.27 MWD+SC+sag(5) 12,681.79 65.23 205.58 9,521.61 9,399.61 -4,299.45 -5,814.35 2,507,637.33 207,849.71 0.78 7,228.02 MWD+SC+sag(5) 12,744.45 65.20 206.21 9,547.88 9,425.88 -4,350.62 -5,839.19 2,507,586.78 207,823.62 0.91 7,279.20 MWD+SC+sag(5) 12,805.13 64.93 207.06 9,573.46 9,451.46 -4,399.81 • -5,863.86 2,507,538.22 207,797.76 1.35 7,329.00 MWD+SC+sag(5) 12,867.99 63.71 208.66 9,600.70 9,478.70 -4,449.89 -5,890.33 2,507,488.80 207,770.07 3.00 7,380.78 MWD+SC+sag(5) 12,929.71 63.70 207.69 9,628.04 9,506.04 -4,498.67 -5,916.46 2,507,440.67 207,742.76 1.41 7,431.48 MWD+SC+sag(5) 12,992.09 63.51 208.42 9,655.77 9,533.77 -4,547.98 -5,942.74 2,507,392.02 207,715.28 1.09 7,482.63 MWD+SC+sag(5) 13,053.56 63.56 209.51 9,683.17 9,561.17 -4,596.12 -5,969.38 2,507,344.55 207,687.46 1.59 7,533.35 MWD+SC+sag(5) 13,115.77 63.45 209.99 9,710.92 9,588.92 -4,644.46 -5,997.01 2,507,296.90 207,658.66 0.71 7,584.95 MWD+SC+sag(5) 6/20/2017 6:54:21PM Page 10 COMPASS 5000.1 Build 81 • . Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordmaf='' . Well K-03RD2 Project: McArthur River Field TVD Reference:-- ` K-03RD2 @ 122.00usft z_ King Salmon MD Reference: K-03RD2 @ 122.00usft i K-03RD2 North Reference: True 16 K-03RD2 Survey Calculation Method: Minimum Curvature D` igrt x K-03RD2 Database: Sperry EDM-NORTH US+CANADA S .t s -...-„A:4-,,,„-.,,.. .'rerr , . % ' Map Map Vertical MD = ' Inc Azi TVD TVDSS +N/-S I+El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,176.78 63.51 210.19 9,738.16 9,616.16 -4,691.69 -6,024.38 2,507,250.35 207,630.14 0.31 7,635.68 MWD+SC+sag(5) 13,239.39 63.16 210.46 9,766.26 9,644.26 -4,739.99 -6,052.63 2,507,202.76 207,600.72 0.68 7,687.75 MWD+SC+sag(5) 13,301.60 62.61 211.56 9,794.62 9,672.62 -4,787.45 -6,081.16 2,507,156.01 207,571.04 1.81 7,739.52 MWD+SC+sag(5) 13,353.14 61.35 211.39 9,818.83 9,696.83 -4,826.25 -6,104.91 2,507,117.80 207,546.34 2.46 7,782.18 MWD+SC+sag(5) 13,407.63 61.34 211.95 9,844.96 9,722.96 -4,866.95 -6,130.02 2,507,077.74 207,520.25 0.90 7,827.08 MWD+SC+sag(5) 13,448.00 61.34 211.95 9,864.32 9,742.32 -4,897.00 -6,148.76 2,507,048.15 207,500.77 0.00 7,860.40 PROJECTED to TD brian.wheeler@halliburton.c +.w�ma.�� 6/20/17 Checked By: Michael Calkins , -• Approved By: om m„�„ „.. Date: 6/20/2017 6:54:21PM Page 11 COMPASS 5000.1 Build 81 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. MRF K-03RD2 Date Run 19-Jun-17 County State Alaska Supv. M.Rogers/B.Mize CASING RECORD Liner 7J TD 13,448.00 Shoe Depth: 13,443.00 PBTD: 13,313.00 No.Jts.Delivered 114 No.Jts.Run 104 No.Jts.Returned 4 Ftg.Delivered 4,608.03 Ftg.Run 4,203.35 Ftg.Returned 404.68 Length Measurements W/O Threads Ftg.Cut Jt. Ftg.Balance RKB RKB to BHF 48.65 RKB to CHF RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Float Shoe 7 3/4 29.0 L-80 DWC/C Davis Lynch 1.61 13,443.00 13,441.39 1 7 Liner _ 7 29.0 L-80 DWC/C Vam 81.76 13,441.39 13,359.63 Float Collar 7 3/4 29.0 L-80 DWC/C Davis Lynch 1.30 13,359.63 13,358.33 1 7 Liner 7 29.0 L-80 DWC/C Vam 41.73 13,358.33 13,316.60 landing Collar 7 29.0 L-80 DWC/C Baker 3.38 13,316.60 13,313.22 101 7 Liner _ 7 29.0 L-80 DWC/C Vam 4,079.86 13,313.22 9,233.36 Liner X/0 Pup 7 29.0 H521/DWC Baker 5.73 9,233.36 9,227.63 SDD Liner Hanger 7 29.0 P-110 H521 Baker 5.87 9,227.63 9,221.76 XO Joint 7 x 7.625 7 5/8 29.0 P-110 VTHT P X H Baker 1.30 9,221.76 9,220.46 Liner top packer 7 5/8 29.0 VTHT Baker 9,220.46 9,204.01 Csg Wt.On Hook: 120 Type Float Collar: Davis Lynch No.Hrs to Run: 29.5 Csg Wt.On Slips: 80 Type of Shoe: Davis Lynch Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg Yes X No Ft.Min. 9.4 _ PPG Fluid Description: OBM Liner hanger Info(Make/Model): Baker SDD Liner Hanger Liner top Packer?: X Yes No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: CEMENTING REPORT Shoe @ 13443 FC @ 13,358.33 Top of Liner 9204.01 Preflush(Spacer) Type: MudPUSH II Density(ppg) 12 Volume pumped(BBLs) 15 Lead Slurry Type: G Sacks: 469.4 Yield: 1.36 Density(ppg) 15.3 Volume pumped(BBLs) 113.7 Mixing/Pumping Rate(bpm): 4 Tail Slurry W Type: Sacks: Yield: 4 Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 'o Post Flush(Spacer) ix Type: MudPush II Density(ppg) 12 Rate(bpm): Volume: 10 rz Displacement: Type: OBM Density(ppg) 9.4 Rate(bpm): 5 Volume(actual/calculated): 257.8/266.2 FCP(psi): Pump used for disp: Bump Plug? X Yes No Bump press 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: Cement In Place At: 13:30 Date: 6/20/2017 Estimated TOC: 10,230 Method Used To Determine TOC: CBL VD L I,J O(4_ b>�l C''i 0 6 L ,,,. www.wellez.net WeIlEz Information Management LLC ver_102716bf ��a 7' S/f/7 • i K-03RD2 FINAL Days vs Depth 8000 K-03RD2 Plan K-03RD2 Actual 8500 9000 • 9500 10000 10500 s 4-. a v 11000 v L 3 H C� C 11500 12000 12500 13000 - • I _ _ • 13500 14000 0 5 10 15 20 25 30 35 40 Days 7/27/2017 8:40 AM Lea Oudean Hilcorp Alaska, 1 �, -bZ� AK_GeoTech 3800 Centerpoinc Drive, Suite 1400 � "" Anchorage, AK 99503 �V 09 Tele: 907 777-8337 Hilrnrp;thaaku,L1.t: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 6/23/2017 To: Alaska Oil & Gas Conservation Commission RECEIVED Meredith Guhl, Petroleum Geology Assistant 333 W. 7th Ave. Ste#100 JUN 2 3 2017 Anchorage, AK 99501 DATA TRANSMITTAL AOGCC K-03rd2 217-029 Transmitted herewith are cuttings from K-24RD3 WELL BOX # SAMPLE INTERVAL K-03rd2 1 9448'-11190' 2 11190'-13200' 3 13200'-13448' 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 R: eiy-. :y: . Date: l J • %. y\����//7, 4A THE STATE Alaska Oil and Gas ,-s_ -d�T A of/� j /\ S1K /� Conservation Commission _ 1`1L1-1 \1r1 333 West Seventh Avenue �.-. r. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 'er^'"a '� Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU K-03RD2 Permit to Drill Number: 217-029 Sundry Number: 317-218 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, /j4-‘ 7C( Cathy P oerster Chair DATED this 7dectlay of June, 2017. RBDMS .JJ L 6 2017 III III RECEIVED STATE OF ALASKA MAY 3 0 2 17 ALASKA OIL AND GAS CONSERVATION COMMISSION Cis 2x,Ce? APPLICATION FOR SUNDRY APPROVALS AOGCC C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate El Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 2 Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: ESP Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: .L...:.k, j Hilcorp Alaska,LLC Exploratory 0 Development 0' 217-029 i C`„`f/cji 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20074-02-00 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 0 No El 1 Trading Bay Unit K-03RD2 J 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL017594/ADL018777(proposed) • McArthur River Field/Hemlock 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): ±13,322(proposed) ±9,794(proposed) ±13,200(proposed) ±9,740(proposed) 2,795 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,506' 13-3/8" 2,506' 2,346' 3,090 psi 1,540 psi Intermediate ±9,600(proposed) 9-5/8" ±9,600(proposed) ±7,110(proposed) 5,750 psi 3,090 psi Production Liner ±3,922(proposed) 7" ±13,322(proposed) ±9,794(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 0. Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic 0 Development El ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/20/2017 OIL 2 I WINJ ❑ WDSPL 0 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: (907)283-1329 Authorized Signature: '•t kw.� )Date: 5/'$O/1001 COMMISSION USE ONLY Conditions of approval: Notify Commissio so that a representative may witness Sundry Number 2\ic Plug Integrity El BOP Test V Mechanical Integrity Test 0 Location Clearance 0 Acb ( 1 13 Other: •7r 350L.) ,05 c- L 1 Z) :--:s 1— Post Initial Injection MIT Req'd? Yes ❑ No ❑ ,/ 7 (' ; 7Yes ❑ No d Subsequent Form Required: /Q 1-*/1 b - -- 1 i- APPROVED BY R��MS �" JW' 1 6 2Q17 Approved by: / 2e_e.4,L....._- COMMISSIONER THE COMMISSION Date: 6. 9'( sf 1/0- •'fr7ll1/C7 ^ tye 6 /4. - '7 �Ri' .� iki m� Submit and Form 10-403 Revised 4/2017 r I t for 12 months from the date of approval. Attachments in Duplicate S • Well Work Prognosis Well: K-03rd2 Hilcorp Alaska,LLC Date:05/23/2017 Well Name: K-03rd2 API Number: 50-733-20074-02 Current Status: Sidetracked Producer Leg: Leg#4 (NW corner) Estimated Start Date: June 20, 2017 Rig: Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 217-029 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: 3,730 psi @ 9,347'TVD 0.399 lbs/ft(7.67 ppg)based on offset K-10rd2 Maximum Expected BHP: 3,730 psi @ 9,347'TVD 0.399 lbs/ft(7.67 ppg)based on offset K-10rd2 Maximum Potential Surface Pressure:2,795 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary K-03rd2 is a Hemlock only producer that will be completed with an ESP. This new well was side tracked from the current K-03rd which is comingled G and Hemlock injector. This workover will perforate and run the completion string in the new well. Last Casing Test: Casing and liner tested to 2,500 psi under PTD 217-029 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 circuli to the well. 4. Rig up E-Line and run gamma/ccl/cbl. POOH. ` , coo— Cat, A-Ocicc 5. PU TCP guns, RIH and perforate per program. 6. After detonation, circulate out any perf gas, confirm well is static, POOH. 7. PU and run ESP completion. • A high set packer, packer vent valve, and SSSV will be ran if well indicates ability to flow to surface. 8. If applicable -Set and test packer to 1,500 psig charting for 30 minutes. 9. Set BPV. NU tree,test same. 10. Turn well over to production 11. Schedule SVS testing with AOGCC as per regulations. 12. If applicable (no packer and SSSV installed in step 7)-Schedule no-flow 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 H • • McArthur River Field Well:TBU K-03RD2 PROPOSED PTD: 217 XXX API:50-733-20074-XX Hilcorp Alaska,LLc Last Completed: Future CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24" - - - Surf 24" 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2,506' 9-5/8" 47 S-95 BTC(170 its) 8.681" Surf N-80 8rnd LTC 8.681" - ±9,600'TOW 7" 29 L-80 DWC/C 6.184 ±9,400' ±13,322' 13-3/8" LINER DETAIL No Depth(MD) Depth ID Item (TVD) 1 ±9,400' ±6,961' 6.184" SDD Baker Liner Hanger 2 ±9,600' ±7,110' - KOP 3 ±9400'- 13,322' ±9,794' 6.184" 7" 29# L-80 DWC/C Liner Hanger ±9,400' 0 8.1/2"TOW ±9,600' 9-5/8" CEMENT DETAIL No TOC Depth TOC Depth Volume Item IN `: (MD) (ND) TOC 10,000' ':' ' ±10,000' ±7,427' 97 bbls 15.3 ppg Class G cement w/%2 bbl „; cemnet LCM '4 ' 1.4 ate r.. la Ir ',.\: if.' PBTD=±13,200'MD TD=±13,322'MD Max Hole Angle=±64° Updated By:MMM 03/01/2017 • 0 . McArthur River Field Well:TBU K-03RD2 HPROPOSED PTD:217-029 API:50-733-20074-02 Hilcorp Alaska,LLC Last Completed: Future CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 24" - - - Surf 24" 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2,506' 1 — 5-95 BTC(170 its) 8.681" Surf - 2 9-5/8" 47 N-80 8rnd LTC 8.681" ±9,600'TOW x 3 7" 29 L-80 DWC/C 6.184" ±9,400' ±13,322' TUBING DETAIL 4-1/2" 12.6 L-80 Supermax 3.958" ' rf ±9,122' JEWELRY DET' L No DMD Vh D ID OD lite' s' ubing Hanger _ Y ±350' 3.813" 54,90" C • gent–SSSV 13-3/8" 2 1380' ±380' 3.958" $ 1 ntingent–ESP Dual Packer w/WFT vent valve L. 3 ±400' ±400' 3.813" i .,5. 0" ntingent-X-nipple tl Discharge,Bolt-On N/A 6.750" Pumps 4 /A Intake /• 5.130" Seals A 5.620" Motors ±9,122' ±6,7 ' /A 5.620" Centralizer Anode • I 4 Liner Hanger ±9, Min ID II D 6.184' 8-117 TOW - ±9,600' PERFORATION DETAIL p 9-5/8" Top Btm Top Btm Zon- FT Date Status (MD) (MD) (TVD) (TVD) I 1 ±12,228' ±9,314' Future Proposed TOC±10,000 H2 ±12,330' ±9,359' Future Proposed H3 ±12,558' ±9,459' Future Proposed HK 1 H4 ±12,731' ±9,535' Future Proposed HK 2lial Future Pro osed H5 ±12,865' ±9,594' P ta' H6 ±13,005' ±9,655' Future Proposed HK3 v tt 'At H ' *:w HK5 "S'It, HK6 PBTD=±13,200'MD TD=±13,322'MD Max Hole Angle=±64° Updated By:ILL 05/23/17 H • . McArthur River Field Well:TBU K-03RD2 PROPOSED PTD: 217507 -3°32-920074-02 API: Hileorp Alaska.l.0 Last Completed: Future CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. J24" - Surf - -13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2,506' �_1 - 1—n24- 9 5/8„ 47 S-95 BTC(170 jts) 8.681" Surf `'^"i 2 N-80 8rnd LTC 8.681" - 9,448'TOW I x j] 3 2_9 L-80 UWCj_ 6.184 ±9,300 ±13,488 TUBING DETAIL 12.6 L-80 Supermax 3.958" Surf JEWELRY DETAIL No DMDh h DTVD epth ID OD Item Tubing Hanger ±350' ±350' 3.813" 5.965" SSSV 13-3/8" 2 X380' ±380' 3.958" 8.312" ESP Dual Packer w/W FT vent valve L . . 3 00' ±400' 3.813" 5.570' '-nipple Bolt-On N/A 6.750 umps N/A Intake 1 3 N/A 5 Seals N/A 5.62, Motors N- .22' ±6,756' N/A 5.620 Centralize 'de a-Bra- a."® 4 19p f PERFORATION DETAIL G ► 9-5/8" w Zone Top Btm Top Btm 8-112°ToFT Date Status 9,448 (MD) (MD) (TVD) (TVD) HK-1&2 ±12,244 ±12,404' s33' ±9,403' 160 Future Proposed HK-2 ±12,417 ±12,552' ±9,408' ±9,467' 135 Future Proposed HK-3 ±12,590 ±12,776' ±9,483' ±9,561' 186 Future Proposed 1 ,�II- HK-1 HK-4 ±12,791 ±12,904' ±9,568' ±9,617' 113 Future Proposed 1.'f- __- HK-2 HK-5 ±12,953 ±13,065' ±9,638' ±9,688' 112 Future Proposed 1 - �. �._ HK-6 ±13,083 ±13,195' ±9,696' ±9,746' 112 Future Proposed 1 1• HK-3 _ HK-6 ±13,209 ±13,223' ±9,753' ±9,759' 14 Future Proposed 1- j- HK-7 ±13,250 ±13,293' ±9,771' ±9,761' 43 Future Proposed 1' {. HK-4 I- ' . ICI. L'T- HK-5 I,I- 1' J 1. 1 HK-6 1 -1- 1 �- LHK-7 � TD=13,488'MD Max Hole Angle=65.23 @12,682° Updated By:DEM 06/16/17 110 0 King Salmon Platform .11 K-O3RD2 Proposed 11/21/2016 NiIIV Irn:u,ask.,1.l.t: King Salmon Tbg hanger,OCT-UH-TC-1A- K-03RD2 ESP,13 X 4'/:IBT lift and 24 X133/8 X95/8X4Y2 susp,w/4"Type H BPV profile,3/8 cont control line port BHTA,Bowen,4 1/16 5M FE x 7"-5 Stub acme Bowen top IN uiMilli um you— Valve,Swab,WKM-M,4 1/16 5M Qv oi9 FE,HWO,EE trim ---8-- ce Valve,Wing,SSV,WKM-M,3 1/8 5M ii..U� FE,w/OMNI oper,EE trim m uiiIUI m Valve,Wing,WKM-M,2 1/16 5M FE,HWO,DD trim ;ori) : o II 1 4 13 111. 1111111 M.I.- i■_�1.� Valve,Master,WKM-M,4 1/16 5M �7�� uu■ FE,HWO,EE trim �` ° ® Illt.<r`1:n tt T. Valve,Wing,WKM-M,3 1/8 5M FE, %` i�` HWO,EE trim O •y \, -^-AE Adapter,OCT-AS-ESP,13 5/8 5M API hub X 41/16 5M stdd top,w/2-%control IV— . line exits,prepped w/OCT 400-4 pocket I All unihead annular valves,2 Unihead,OCT type 3,13 5/8 5M APIx 1J = ? 1/16 5M FE OCT-20,HWO hub top X 13 3/8 BTC casing bottom, ill,*-3 1�?` , POI I'' w/1-2 1/16 5M S5O on lower Mme_ section,1-2 1/16 5M SSO on middle ' section,3-2 1/16 5M SSO on upper °—.- 1 ; section,IP internal lockpin assy _ ''-J. ll50 i,:. i. . . , I Ate-,•tiii nj SIA I; Valve,OCT-20,3 1/8 2M FE, Starting head,OCT,21%2M FE X ®I J ' I ? HWO StaEFO,full lao , set of lockpins 1111 24" 13 3/8" 9 5/8" 4%2„ • King Salmon Platform 2016 BOP Stack(Kuukpik) 06/22/2016 Hilriuh.tlaska.1.1A Rig Floor 16" Pipe O O iri n 3.74' Shaffer 13 5/8 5M Jtti(ftl rail f Shaffer SL a — 2 7/8115.5 Variables 2.83' 13 5/8 5M 1111 Blind 2 1/16 5M manual and HCR valve 2 1/16 5M manual and HCR valve 11I I I I Ip 111 111 1.76 ' .:.�w '1114. -,i I11 111111111 Iii "t' *C11,4 10.1 l .r� a Shaffer SL = 111 13 5 8 5M EW 1 ®• o _— 2 7/8-5.5 Variables III III III I11 I)I 41111 Drill deck 13.70' Riser 135/85M FEX 13 5/8 5M API hub • • Choke Manifold Valves 2 " 3" To Shaker 3" Panic To Gasbuster 3 1/8"_ 2 1/16" -,„.....c) O 2 /1 16" 1 ill ,8 I I _ , O 21/1 + 21/16" + `\ 3 1/8" © �@ A/ N L41) , Jolp�\ //© 4 2 1/16" 2 1/16" 1 Manual Choke Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold C-2 vet:" rto ji � : i #9 ''*t _t."4" r, "%I.! #1 #2 i q elle Kuukpik Drilling Rig 5 Choke Manifold 0 • E at bA 00 °1 al° ,G., 0 aI °1 °I a OIUI0IUIa UI0101 0 ai I l i , i i ••"1 1; 1•,.-1 al a1 I. .� p U) 91 I al of a1 of I 0 0. 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Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile&lift threads were deemed good, but still unable to get good tests 1) 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), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov),Jim Regg (AOGCC-jim.regg@alaska.gov) and Michael Quick (AOGCC—Michael.quick@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory (melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path, test choke manifold per standard procedure 3) 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.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPs looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPs are not leaking. Test# 1=Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) 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.) 7) 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. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) 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 as per Kuukpik's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. • • Kuukpik 5 BOP Test Procedure Fri,•ori�:�iaka, Attachment#1 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 and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/ pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow ( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/ upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure . • 0 R / � 2> as U2 � c 2E 002 .0 / 2 k� § / « — E ® 0c ) E § 10. / f .( k / / _a � t- > _ .L �� / � §. it \ E CO — n -0 ■ ■ `a \ � � k k % b t �>- N co zE cla N. 0 - y 4 - 0 a. / \ O N k a fak ■ / � _ a e o _ .c� � U \ L. k \ < -13 L. 0 E § © 2 O k $ ./ a o a � / : S \ / U -cs »k co c CA c ) / / . 7 q 0 . . c w @ U)/ > ƒ ■ % 0 0- �� co ■ « /ƒ 0 . CI / $ x § - - § 0 q Q Cl) x 2 a © % k c � co 15 0 a 1.4 � � / � C. p .. % / © a) E0 > E o 00. 0 2 k k / < 2 • • Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, May 29, 2017 12:16 PM To: Schwartz, Guy L(DOA) Cc: Cody Dinger Subject: Re: PTD 217-029 (K-03RD2 on King Salmon) Thanks Guy! Have a great Memorial Day! Monty M Myers 907.538.1168 On May 29,2017, at 12:15 PM,Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov» wrote: Monty, You have approval to proceed with the plan as proposed below. Good luck with rest of well. Update the MOC as required. Regards, Guy Schwartz AOGCC Sent from my iPhone On May 29,2017,at 11:16 AM, Monty Myers<mmyers@hilcorp.com<mailto:mmyers@hilcorp.com»wrote: Good morning Guy, Since we have some concern trying to spot a balanced plug at this depth with filtered inlet water below us in the existing casing,our plan forward will be as follows. Pertinent Info: Bottom of window-9602' Top of window-9569' Casing Size 9-5/8"47# 20 bbls of cement should give^273'of plug Bottom of plug at 9800' Top of plug at 9527' 1. POOH w/cement stinger 2. PU window mill and watermelon mill and RIH to 9800' 3. Circulate hole clean 4. POOH and PU bridge plug and RIH to 9800'on drill pipe with 10 joints of 2-7/8 tubing on bottom 1 • • 5. Set bridge plug and pull up above bridge plug 2' 6. Spot 20 bbls of 15.8 ppg class G cement on top of plug 7. Pull up hole to 9500'and circulate well clean 8. POOH with drill pipe 9. RU e-line and RIH with BP to"'9500' 10. Correlate to casing collar and set bridge plug for whipstock 5'above collar at -9500' 11. POOH with eline 12. MU whipstock and mills and TIH to 20' above bridge plug 13. Orient whipstock face to 65 degrees right of high side and set whipstock. 14. Mill window and 20'of new formation 15. Perform FIT to 12.5 ppg equivalent mud weight 16. POOH for drilling assembly Let me know if you have any additional questions Guy. Thank you very much. Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 From: Monty Myers Sent: Monday, May 29,2017 9:10 AM To:'guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov>' <guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov» Cc:Cody Dinger<cdinger@hilcorp.com<mailto:cdinger@hilcorp.com» Subject: RE: PTD 217-029(K-03RD2 on King Salmon) Good morning Guy, It appears that we are back in the old wellbore of K-03RD.We are able to run in the hole without any resistance with our cement stinger assembly, past our last drilling depth.Currently we are setting at 10,000 TMD.We circulated a bottoms up on the well to see if we would get back any filtered inlet water, but we didn't see any at bottoms up.We closed the annular and pressured up on the well and it held solid at 2500 psi,only bleeding off 80 psi after 10 mins. This window was cut at 53 degrees left of high side. I would like to abandon this window and re-cut a window above this one by setting a bridge plug and a new whipstock above it and milling a new window to 65 degrees right of high side. My question is,do I need to balance a cement plug over the old window,or will a bridge plug above it,sufficiently isolate the well below it? 2 • r Thank you!Talk to you soon. Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 From: Monty Myers Sent:Sunday, May 28,2017 7:01 AM To:guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov> Cc: Cody Dinger<cdinger@hilcorp.com<mailto:cdinger@hilcorp.com» Subject: PTD 217-029(K-03RD2 on King Salmon) Guy, We have successfully milled our window from 9569'to 9602'.We had good indication of cement behind pipe at the window,and we were able to achieve a solid FIT test without any issue. We are attempting to kick off and drill the well and it appears we are tracking casing and we cannot get departed from the well.We would like permission to lay in a 20 bbl balanced plug from our current depth at 9660' back up into the window. Please let me know if you have any issues with this. Thank you. Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 3 • OF rit� "���yyy-"s, THE STATE Alaska Oil and Gas ti , Of A Q 1 Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -...� Main: 907.279.1433 OF ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU K-03RD2 Hilcorp Alaska, LLC Permit to Drill Number: 217-029 Surface Location: 729' FSL, 130' FEL, SEC. 17, T9N, R13W, SM,AK Bottomhole Location: 946' FSL, 530' FEL, SEC. 19, T9N, R13W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to re-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, P Cathy P. Foerster Chair DATED this z$1 day of March, 2017. 'iz__Ev'-s...S"E._7 STATE OF ALASKA MAR 1 7 2017 At OIL AND GAS CONSERVATION COMMDN PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test 0 Development-Oil ❑✓ ' Service- Winj 0 Single Zone 0 Coalbed Gas 0 Gas Hydrates ❑ Redrill❑., ' Reentry❑ Exploratory-Oil 0 Development-Gas ❑ Service-Supply ❑ Multiple Zone 0 Geothermal 0 Shale Gas El 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244t TBU K-03RD2 ` 3.Address: 6.Proposed Depth: 9-7V 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 13,322' • TVD: 9,p4' t),,i McArthur River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Hemlock Oil Pool , Surface: 729'FSL,130'FEL,Sec 17,T9N,R13W,SM,AK ADL017594(SHL/TPH)ADL018777(BHL). Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1997'FSL,69'FWL,Sec 20,T9N,R13W,SM,AK N/A 5/1/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 946'FSL,530'FEL,Sec 19,T9N,R13W,SM,AK ADL017594 5116 acres/ADL018777 1902 acres 4262'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 122' 15.Distance to Nearest Well Open Surface: x-213767 y- 2511793 Zone-4 1 GL Elevation above MSL(ft): N/A to Same Pool: 2550'to G-15RD 16.Deviated wells: Kickoff depth:q(Q ao p4 feet 1 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 6y Xdegrees Downhole: 4690 Surface: 2473 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 3922' 9,400' 6,528' 13,322' 9,804' 545 ft3 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): 13,413' 9,839' N/A 13,300' 9,753' 12,634' Casing Length Size Cement Volume MD TVD Conductor/Structural 394' 24" 394' 394' Surface 2,506' 13-3/8" 1560 sx 2,506' 2,346' Intermediate 10,983' 9-5/8" 1000 sx 10,983' 8,059' Production Liner 2,735' 7" 800 sx 13,395' 9,825' Perforation Depth MD(ft): 12,386'-13,164' Perforation Depth TVD(ft): 9,069'-9,649' 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analysis Li Diverter Sketch El Seabed Report El Drilling Fluid Program Q 20 AAC 25.050 requirements Q 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 Monty Myers Email mmyersCa7hilcorp.com Printed Name Monty Myers Title Drilling Engineer Signature - Phone 777-8431 Date 3 . (7 . 7 0 ? 7 Commission Use Only Permit to Drill API N • Permit Approval n See cover letter for other �� Number: a'?. - °(, l 50- 3 3' 2.0 0711-Oa,-co Date: :J laO) l rI requirements. Conditions of approval: If box is ch cked,well may not be used to explore for,test,or produce coalbed methane,- hydrates,or gas contained in shales: [� Other: X 3 5L O raSc, IS P,& ' /e3 f Samples req'd: Yes❑ No[' Mud log req'd:Yes El NoZ' ,' /� ; .- ( P CA. 7,0�-e,..,-40H25 measures: Yes 53/No❑ Directional svy req'd:Yes g. No / j# /r _zy: .Spacing exception req'd: Yes 0 No WInclination-only svy req'd:Yes❑ No y„ (� Q re_< e.Wiw� •(®{{. (c X / ()�j Post initial injection MIT req'd:Yes❑ No El ,7, S.,,,crtiiii.j' 1) .,._ge.A:z...,^6,-(/ /r C ci irt..10 n APPROVED BY Approved by� / COMMISSIONER THE COMMISSION Date -2?—r7 7 t) ,.' 3/40 I L- 3-1\a-rt Submit Form and Form 10-401(Revised 11/ 015) i i iNH A2ILmonths from the d of approval(20 AAC 25.005(g)) Attachments in Duplicate • Hilcorp Alaska, LLC P.O. Box 244027 Monty Myers Anchorage,AK 99524-4027 110 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Energy Company 3/17/2017 RECEIVED Commissioner MAR 1 7 2017 Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: K-03RD2 Dear Commissioner, Attached is the application for permit to drill K-03RD2. K-03RD2 is an oil production well planned to be re-drilled in a South-westerly direction from the existing K-03RD utilizing the existing casing program down to 9600' MD/7110' TVD. I At 9600' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 3722'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 4-1/2" ESP completion. Drilling operations are expected to commence approximately May 1st, 2017. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • • Hilcorp Alaska, LLC K-03RD2 Drilling Program McArthur River • dby: Mt IMy Revision 1 March 17, 2017 i K-03RD2 Drilling Procedure Rev 1 Ilikorp:Ua.ka.. 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 N/U 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 Drilling Hazards 35 25.0 Rig Layout 36 26.0 FIT Procedure 37 27.0 Choke Manifold Schematic 38 28.0 Fluid Flow Diagrams 39 29.0 Offset MW vs. Depth TVD 42 30.0 Casing Design Information 43 31.0 8-1/2"Hole Section MASP 44 32.0 Plot(NAD 27) (Governmental Sections) 45 33.0 Slot Diagram (As Built) (NAD 27) 46 34.0 Directional Program (wp05) 48 • • K-03RD2 Drilling Procedure Rev 1 Itileorp Alaska,LLC 1.0 Well Summary Well K-03RD2 Pad&Old Well Designation Sidetrack of existing well K-03RD(PTD#180-144) Planned Completion Type 7"29#L-80 Liner,4-1/2"Tubing w/ESP Target Reservoir(s) Hemlock Producer H1-H3 Planned Well TD,MD/TVD 13322' MD/9804' TVD PBTD,MD/TVD 13200' MD/9758' TVD Surface Location(Governmental) 729' FSL, 130' FEL, Sec 17, T9N,R13W, SM,AK Surface Location(NAD 27) X=213767.53,Y=2511793.13 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1997'FSL, 69'FWL, Sec 20,T9N, R13W, SM,AK TPH Location(NAD 27) X=208596.23,Y=2507917.43 TPH Location(NAD 83) BHL(Governmental) 946'FSL, 530'FEL, Sec 19, T9N, R13W, SM,AK BHL(NAD 27) X=207973.68,Y=2506882.19 BHL(NAD 83) AFE Number 1711118D AFE Drilling Days AFE Drilling Amount $5.1 MM Work String 4-1/2" 16.6# S-135 CDS-40(From Saxon) RKB—AMSL 122' MSL to ML 73' BOP Equipment 13-5/8"5M Hydril"GK"Annular BOP 13-5/8"5M Cameron Type U Double Ram 13-5/8"5M Cameron Type U Single Ram Page 2 Revision 1 March, 2017 • K-03RD2 Drilling Procedure Rev 1 Ihh op ala-ka. 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: March 17,2017 Subject: Changes to Approved Permit to Drill for K-03RD2 File#: K-03RD2 Drilling Program Any modifications to K-03RD2 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 3.0 4 3.17.2017 Change 7-5/8" HYD511 casing to 7' DWC!C MMM 6.0 6 3.17.2017 Updated Schematic(KOP) 1 MMM 16.0 25 3.17.2017 Updated cement volumes for 7" - MMM 34.0 48 3.17.2017 Updated Directional plan to wp05 ' MMM Approval: Drilling Manager Date Prepared: Monty M Myers 3.17.2017 Drilling Engineer Date Page 3 Revision 1 March, 2017 • • K-03RD2 Drilling Procedure Rev 1 Ililcorp Alaska,I ii 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 7.875 6.184 6.059 L-80 DWC/C 9400 13322 0.17( BPF 4.0 Drill Pipe Information Hole OD (in) ID (in) TJ ID TJ OD Wt " " Gra 1 + Burst ' "1`i-se Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) 8-1/2" 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k UJ`EZz I3PF All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 1 March, 2017 K-03RD2 Drilling Procedure Rev 1 Ilileorp Alaska,IAA: 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. Leonard Dickerson: 0: (907)777-8317 C: (907)252-7855 b. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: a. Keegan Fleming: 0:907-777-8347 C:907-350-9439 ix. Notify Drlg Manager 1. Paul MaJ7olini: 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 1 March,2017 Hw _ 0 K-03RD2 Drilling Procedure Rev 1 Ilih-orp.Ua-ka.IA I: 6.0 Planned Wellbore Schematic McArthur River Field 11 Well:TBU K-03RD2 PROPOSEDWell: 0-733x20074-XX 1111"'r,.%LA.,I Lt Last Completed:Future CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. J L f 24"/ - Surf 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2,506' 9-5/8" 47 5-95 BTC(170its) 8.681" Surf - N-80 8rxd LTC 8.651" - _9600'TOW L-80 :3,322' L LINER DETAIL Dept Nc Depth(MD) D) ID Item ±9,400' ±6,961' 6.184" SDD Baker Liner Hanger ±9,600' ±7,110' - KOP ;400'-13,322' ±9,794' 6.184" 7"29#L-80 DWC/C µt.J €iner-!anger if. ±.9 1' 9.5/9" CEMENT DETAIL No TOC Depth TOC Depth Volume Item (MD) (TVD) ±10,000' ±7,427' 97 bbls 15.3 ppg Class G cement w/'/2 bbl cemnet LCM 1, 3, A A. ', c ' ": PBTD=±13,200'MD TD=±13,32Y MD Max Hole Angle=364` Page 6 Revision 1 March, 2017 S K-03RD2 Drilling Procedure Rev 1 Ililcorp.Alaska,LU 7.0 Drilling Summary K-03RD2 is an oil production well planned to be re-drilled in a South-westerly direction from the existing K-03RD utilizing the existing casing program down to 9600' MD/7110' TVD. f A i(-0- 41).D ( i°r1) 176-14'1 *--)/51'14- .316 -410 At 9600' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 3722' 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 4-1/2"ESP completion. Drilling operations are expected to commence approximately May 1St, 2017. 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 separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and for running the completion assembly General sequence of operations pertaining to this approved drilling procedure: `-1` 0 1. Kuukpik 5 will be over slot 32(K-03RD)to decomplete and P&A well under separate„sundry. ='`� 2. DP should be stood back in derrick £... 3/41,- Geo ti 3. PU whipstock, and mills and TIH to CIBP '1017' #tt 4. Orient whipstock and set at 65 deg left of highside. 5. Mill 8-1/2"window and 20' of new formation at 9600'. 6. POOH and LD mills. PU directional BHA and TIH to window. 7. Swap well to 9.0 ppg oil based drilling mud Fy 8. Perform FIT to 12.5 ppg EMWA, 9. Drill 8-1/2" production hole from 9620' to 13322' 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 4-1/2" completion. (Covered under separate sundry) 16. Land hanger and test. 17.ND BOPE,NU tree and test void Page 7 Revision 1 March, 2017 • • K-03RD2 Drilling Procedure Rev 1 llikori)Alaska,1,1.1' 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance 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 K-03RD2. 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 Hilcorp would like to request a variance to regulation 20 AAC 25.035(e)(4)(F)(i) which states - "the outlets must be at least two inches in nominal diameter, except that for rotary drilling rig operations, if the operation has a maximum potential surface pressure of greater than 3,000 psi, the nominal diameter of the choke outlets must be at least three inches". o The calculated MASP for this wellbore when completely evacuated to gas is 3236 psi. However, for Cook Inlet Operations, we assume that the well can never flow 100% gas, due to the water in Gkfrc, the reservoir. We reduce this MASP calculation to 2473 psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to 9.0 ppg reservoir fluid. o Hilcorp would like to request to have 2-1/16" outlets on the choke line and kill line due to this assumption Page 8 Revision 1 March,2017 K-03RD2 Drilling Procedure Rev 1 Ililcorp,tlaska,1,1A: Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 13-5/8"Shaffer 5M annular • 13-5/8"5M Shaffer SL Double gate Initial Test:250/3500 (Annular 2500 psi) • Blind ram in bottom cavity 8-1/2" • Mud cross • 13-5/8"5M Shaffer SL single gate Subsequent Tests: • 3-1/16"5M Choke Manifold 250/3500 • Standpipe,floor valves,etc (Annular 2500 psi) • Primary closing unit: Control Technology Accumulator, 3000psi, 5 station, 170 gallon reservoir, 4 nitrogen backups and 12 bladder bottles. • 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 1 March, 2017 H . . K-03RD2 Drilling Procedure Rev 1 Ili!corp Alaska.IAA 9.0 R/U and Preparatory Work 9.1 Separate sundries will be submitted that will include the following: • Pull tubing 4 • P&A lower perfs with a cement plug �' • Set CIBP 9.2 Mix mud for 8-1/2"hole section. 9.3 Verify 4.5" liners installed in mud pump#1 and 5.5" liners installed in pump #2. • Ellis Williams WH-1000 Pumps are rated at 3500 psi (100%) with 4.5" liners and can deliver 171 gpm at 86 spm. • TSM 1000 Pumps are rated at 3500 psi (100%) with 5.5" liners and can deliver 229 gpm at 86 spm. • Ideal pump rate for drilling will be 400 gpm. Both pumps running at 86 spm should achieve this. Pump#1 Ellis Williams WH1000 10" Stroke Pump#2 TSM 1000 9" Stroke 96% Efficiency Max psi 3500 psi 96% Efficiency Max psi 3500 psi Liner Size bbls/stroke Liner Size bbls/stroke 4.5 0.0472 5.5 0.0635 Strokes/minute bpm gpm Strokes/minute bpm gpm 20 0.94 40 20 1.27 53 40 1.89 79 40 2.54 107 60 2.83 119 60 3.81 160 86 4.06 171 86 5.46 229 100 4.72 198 100 6.35 267 120 5.67 238 120 7.62 320 140 6.61 278 150 7.08 297 Page 10 Revision 1 March, 2017 o K-03RD2 Drilling Procedure Rev 1 lti!carp Alaska,LLA 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 13-5/8"x 5M BOP as follows (top down): • 13-5/8"x 5M Shaffer annular BOP. Q/ • 13-5/8" Shaffer Type "SL" Double ram. (2-7/8"X 5"VBR in top cavity, blind ram in btm cavity) • 13-5/8"mud cross • 13-5/8" Shaffer Type "SL" 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 4-1/2"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> 7-5/8". V Page 11 Revision 1 March, 2017 S K-03RD2 Drilling Procedure Rev 1 Ililcorp Alaska,IAA: 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: Mud Weight VID (PPg) Viscosity PV YP HTHP WPS ES 9,600—13,322' 9.0-9.5' 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration LV T 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 9.0 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 1 March, 2017 • S K-03RD2 Drilling Procedure Rev 1 Ililcorp:Ua;ka.I.I.I 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 (-9600' 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 1500 psi /30 min. Chart record casing test &keep track of the amount of fluid pumped. Stage up to 1500 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. '7 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 1 March, 2017 I K-03RD2 Drilling Procedure Rev 1 Ilikorp Alaska,IAA: 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 1 March, 2017 iii • K-03RD2 Drilling Procedure Rev 1 nii,„,i..'la-;:t.I.IA ran dip ���� Window Master G2 Whipstock BAKER With Torque Master Bottom Trip Anchor HUGHES loiLFi`�w 9.625 53.5#Non Special Drift Casing je Baker Oil Tools • m * Upper Watermelon Mill ■ OD: 8.500 8.500 —÷ 1 `1 4- 6.25 Length: 6.25 11 Flex Joint 1 OD: 6.375 ■ A Length: 9.00 W 6.375 —► ' 4-- 9.00 Lower Watermelon Mill OD: 8.375 III Length: 5.66 II v Window Mill 40.6 - OD: 8.500 _ 8.250 —o. I f 5.66 Length: 1.13 l — Whipstock y OD: 8.000 um 8.500 __, 4___ Length: 18.54 fire 1.13 Face Angle: 1.9 A A ''i.: Face Length: 17.08 Retrieval BTA OD: 8.357 17.08 Length: :'F./11 18.54 1.9 Overall length —► Length: 44' WELL INFORMATION CUSTOMER FIELD —► =4— 8.000 LEASE Z ” Ems WELL NO. '� SHEAR BOLT • I 25,000 3.41 a 35,000 8.357 —► :1 1— 45,000 I 55,000 I i 65,000 iv 75,000 NOTE DIM LNSIONSAR BASED ON TECHUNIT DATA,ACTUAL DIM ENROLLS M AY VAI.Y Page 15 Revision 1 March, 2017 s K-03RD2 Drilling Procedure Rev 1 Ililcorp Ala.ka,LLC 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 1/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 30 L HS 65 L HS Desired orientation of the Whipstock face is 65 degrees left of high side. Hole Angle at window interval (9600' MD) is 44 deg. The wellbore trajectory is planned to kick off at 245 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). (g/'1- 13.5 P/U 5-10' above top of Whipstock. pew 13.6 Displace to 9.0 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 weight 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. v 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. �( �✓ Page 16 Revision 1 March, 2017 K -e3 �J1 K-03RD2 Drilling Procedure Rev 1 Ililcurp Alaska,1.11 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 Percent of Casing Removed(%)* 38 Milled Area(in^12) 5.908 Volume of Cuttings(inA3) 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. 20' rat hole to accommodate the 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 —9.0) * 0.052 * 6670' tvd= 1214 psi 13.14 Kick Tolerance • (12.5-9.0) * (7110/9794) =2.54 `' 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 2.54 ppg kick tolerance while drilling the interval with a 9.0 ppg fluid density. 13.15 Slug pipe and POOH. Gauge Mills for wear. .-V 13.16 Should a second run be required pick up the following BHA. Page 17 Revision 1 March, 2017 • • 14K-03RD2 Drilling Procedure Rev 1 ll.korp Alaska,LLC Back Up Mills Connection Length O.D. WINDOW MILL 4 % REG-P X MILL 2.25 8.5 NEW LOWER WATERMELON MILL 4 1/2 REG-P X 4 '/2 REG-B 5.5 8.5 FLEX JOINT 4 '/2 REG-P X 4 '/2 REG-B 9.0 6.375 STRING MILL 4 '/2 REG-P X 4 '/ REG-B 5.5 8.5 FLOAT SUB 4 '/2" IF-B X 4 '/" REG-B 3.0 6.375 30 jts-HWDP 4 '/2"XH-B X 4 '/2" REG-P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 18 Revision 1 March,2017 • • HK-03RD2 Drilling Procedure Rev 1 Ililcorp:11a.ka,1,1.1: 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2" directional 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 375-450gpm. 14.6 Motor AKO should be set at 1.2 deg. Must keep up with 5 deg/100 DLS in the build section of the wellbore. 14.7 Primary bit will be the Varel 8-1/2" VM613P PDC bit. Ensure to have a back up bit available on location. COMPONENT DATA ttem Description Serial Number OD ID Gauge Weight` Top 4 C u iathre (m) (in) j (n) PPO Con '.Th-;, "Length (hi 1 HOBS-PDC 8.400 2.500 8.500 172.13 P 4-1/2'REG 1.20 1.20 2 T SperryDrill Lobe 7/8.7.5 stg 7.000 4.952 95.69 B 4-1/2"IF 29.48 30.68 Stabilizer 8.375 3 Non Mag Float Sub 6.750 2.750 101.71 B 4-1/2"IF 3.00 33.68 4 Integral Blade 6.750 2.750 8.375 101.71 B 4.1/2"IF 3.60 37.28 5 6 3/4"DM Collar 6.750 3.125 103.40 B 4-1/2"IF 9.20 46.48 6 6 3/4"DGR Collar 6.750 1.920 97.80 B 4-1/2"IF 4.55 51.04 7 6 314'EWR-P4 Collar 6.750 2.000 104.30 B 4-112"IF 12.10 63.14 8 Inline Stabilizer(115) 6.750 1.920 8.375 112.09 B 4-1/2"IF 3.20 66.34 9 6 3/4"PWD 6.750 1.905 96.30 B 4-1/2"IF 4.44 70.78 10 6 3/4"HCIM Collar 6.750 1.920 101.70 B 4-1/2"IF 4.97 75.74 11 6 3/4"TM-HOC(Pulser) 6.900 3.250 103.60 B 4.112"IF 15.50 91.24 12 6-3/4"Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-1/2"IF 30.00 121.24 13 6-3+4'Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-112"IF 30.00 151.24 14 6-314"Non Mag Flex Drill Collar 6.750 2.813 100.77 30.00 181.24 15 6 Joint 5'HWDP 5.000 3.000 49.30 180.00 361.24 16 6-1/4'Weatherford Hydraulic Jar 6.250 2.250 91.01 30.00 391.24 17 14 Joints 5'HWDP 5.000 3.000 1 49.30 420.00 811.24 f1 811.24 Page 19 Revision 1 March, 2017 i K-03RD2 Drilling Procedure Rev 1 Ililearp Alaska..II,C 81/Z 215.9mm 401 Tool#: T9283 Assembly: A09148 Y MVI 3P rt` Navigator IADC Code: M433 '.. # t� PRODUCT SPECIFICATIONS k ' V1 Cutter Size: 13 mm Cutter Back Up: 13mm PDC &Replaceable Shock Studs * Total Cutter Count: 76 O `dam`.� Face Cutter Count: 58 • Connection: 4 1/2"API Regular t ✓ Y a Nozzle 1 Qty/Type: 6-Series 55 Nozzle 2 Qty/Type: - �: Junk Slot Area: 14.3in2(92.3cm2) Gage Pad Length: 2 1/2"(64mm) 114 Make Up Length: 11.4"(288.8mm) Shank Diameter: 5.8"(147.3mm) OPERATING PARAMETERS' Rotary Speed: For all rotary and motor applications Flowrate Min-Max: 250-750GPM(0.95-2.84m3/min) Max Weight On Bit: 42000Ibs(18683daN) • t .19 ' • Makeup Torque: 12000-16000Ft-Lbs. (16270-21693Nm) f / ere k L • Varei irtamatnnal represenia.rre. Navigator Series Bits -Varel's six step design/manufacturing process utilizes GeoScience interpreted logs. proprietary design software SPOT.3D modeling programs,CFD,and specialized manufacturing techniques to produce the best possible bit for the application.Navigator bits are engineered to a specific Directional profile for a given application.Navigator bits possess the key design elements affecting bit steerability and directional behavior helping you achieve your drilling objectives. Bit Features P -Partial PowerCutters'"" provide extra cutter density on the shoulder reducing excessive wear or cutting structure damage when drilling interbedded formations. Shock Studs-Shock studs limit drill bit vibration and increase stability allowing smooth cutting action increasing cutter life and overall bit performance. Updrill Cutters -PDC cutters strategically placed to help reduce hole problems when up drilling or back reaming. Premium Gage -The premium gage consists of thermally stable polycrystalline diamond and pdc(polycrystalline diamond compact)cutters:designed to insure that correct hole diameter is maintained. - _.��=:, •ter-�=..�,,- *ffi,..�-. '�� V A R EL www.vareiinti.com Page 20 Revision 1 March, 2017 I K-03RD2 Drilling Procedure Rev 1 Ilileorp Alaska,I.LC 14.8 TIH to window. Shallow test MWD on trip in. 14.9 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. 14.10 Drill 8-1/2"hole to 13322' MD using motor 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 attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment 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 14.11 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.12 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. 14.13 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 1 March, 2017 • • K-03RD2 Drilling Procedure Rev 1 Ilikorp Alaska,LLC 15.0 Run 7" Production Liner c 10 I 4.;,4)'3S'6 , 15.1 R/U Weatherford 7" casing running equipment. P` • Ensure 7" DWC/C x 4-1/2" CDS-40 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. • Rigid or Solid body centralizers will be pre-installed on shoe joint, FC joint, and LC joint. • Install solid body centralizers every other joint to 10,000' • 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. • 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 1 March, 2017 K-03RD2 Drilling Procedure Rev 1 Ililrorp Technical Specifications Connection Type: Size(O.D.): Weight (Wall): Grade: DWC/C Casing 7 in 29.00 lb/ft (0.408 in) L-80 lam 2012 API Spec 5CT Coupling O.D. Material L-80 Grade 80.000 Minimum Yield Strength (psi) 111111111111111111111111111WU SA 95.000 Minimum Ultimate Strength (psi) VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Pipe Dimensions Houston.TX 77041 7.000 Nominal Pipe Body O.D. (in) Fax�13-479-323300 6.184 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesa(7vamusa.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) 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) 030 API Collapse Pressure Rating (psi) 8,1 API Internal Pressure Resistance (psi) 26.2 Maximum Uniaxial Bend Rating [degrees/100 ft] 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 1 March, 2017 11111 K-03RD2 Drilling Procedure Rev 1 Ililcorp Alaska,LLC 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 1 March,2017 i S K-03RD2 Drilling Procedure Rev 1 Ililcorp.Alaska,I.I.0 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 MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Mix and pump 97 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl of Cemnet or equivalent 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 10000' TMD. 16.6 Displacement fluid will be drilling mud. —341 bbls of displacement fluid 04 zZ ') t 7"Zti ,0371 6Pr ,c ( iiôc �. /332-)- Cement Calculations — /yS dee-s- 8-1/2"OH x 7"Liner: (13322' — 10000') x 0.02259 x 1.25 = 94 bbls Shoe Track: 80' x 0.03715 = 3 bbls Total Volume(bbls): 94 + 3 = 97 bbls Total Volume(ft3): 97 bbls x 5.615 ft3/bbl= 545 ft3 Total Volume(sx): 545 ft3 / 1.34 ft3/sk= 407 sx 13 3 A8LS (JiSPL= (45 833 33 �s a 7 8 6a�s Page 25 Revision 1 March,2017 • • K-03RD2 Drilling Procedure Rev 1 Ililcorp Alaska, Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk 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. i"f°" ()•13. = 13 3 8 64-S 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. 3.0 et"- 16.12 Do not overdisplace by more than 1/2 shoe track (-1 bbls). Shoe track volume is_bls. 16.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 1 March,2017 • • K-03RD2 Drilling Procedure Rev 1 llikwrp 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. j Page 27 Revision 1 March,2017 • • K-03RD2 Drilling Procedure Rev 1 IliIcorp Alaska,LL€ 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 mmversWilcorp.com Page 28 Revision 1 March,2017 • i K-03RD2 Drilling Procedure Rev 1 i(ilcorp Alaska,L[.f. 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"29.7# casing • +/- 3950' 4-1/2" DP. • Casing scraper&brush for 9-5/8" 53.5# casing • (2000') 4-1/2" DP • Casing scraper&brush for 9-5/8" 53.5#casing • 4-1/2" DP to surface. 17.2 TIH& clean out well to landing collar(+/- 13,200' 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 t - " - •. . en r, er is +/- 30' above the 7" liner top. $7� 17.3 After wellbore has been cleaned out satisfactorily usi mud,test casing to Psi/30 min. Ensure to chart record casing test. �_z Z 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 7-5/8"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. LDDP on the trip out. � L 7 /.fir 9 -1-c) 2X0-7.) -',..j9„.3 3 - f i4' 5" b _S.-v v Page 29 Revision 1 March,2017 Hw • K-03RD2 Drilling Procedure Rev 1 Ilileorp Alaska,LLC 18.0 Run Completion Assembly 18.1 Run 4-1/2"tubing completion assembly as per separate Approved Completion Sundry 19.0 RD 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE,NU tree, test void 19.3 Rig Down et..,, 4Dl's 1 'i.€„4.911,,,, i^1. ,4-4.;,...0--0 6'`r‘ . -,4-4-;1-e-09 . C-6L- ®� . 711 Com. ` 5 3-2z -17 ye- Page 30 Revision 1 March,2017 • • K-03RD2 Drilling Procedure Rev 1 Ililrorp Alaska, 20.0 BOP Schematic Rig Floor 16" Pipe II1:III IIiiI! • III 111 lil Iil lil Ijl III iii L Shaffer III 111 Ii11i1 Ii1 I Shaffer SI --- — 2 7/8-5.5 Variables 2.83' I-d 13 S/8 SM Blind ,r1 11111 111111* 2 1116 5M manual valves g 2 1/16 5M manual and HCR valve i � 11#$$1.76 (iIr CJSvI • • �` '10 II. it; Ill Ill ul In V Shaffer Sl- - --'-'—� 135 8 5M ' _ 2 7/8.5 5 Variables 1.44' Ill III III Ill III 4 Drill deck 13.70' Riser 13 5/8 5M FE X 13 5/8 SM API hub Page 31 Revision 1 March, 2017 • 4 K-03RD2 Drilling Procedure Rev 1 FFikorp Ala.ka,LU: 21.0 Wellhead Schematic King Salmon Tbg hanger,OCT-UH•TC-1A- K•03R02 ESP,13 X 4 Y,IBT lift and 24X133/8X95/8X4Y susp,w/4"TypeHBPV profile,3/8 cont control line port BHTA,Bowen,4 1/16 5M FE x 7"-5 Stub acme Bowen top Valve,Swab,WKM-M,4 1/16 5MTTC • q.171 FE,HWO,EE trim k.171 Y Valve,Wing,SSV,WKM-M,3 1/8 SM FE,w/OMNI oper,EE trim Valve,Wing,WKM-M,2 1/16 SM FE,HWO,00 trim • i i..itil":,...;"4 I. . :,,,„, t . _ . .... Valve,Master,WKM-M,4 1/16 SM 'T-,1: - FE,HWO,EE trim t•°+ I o D Z�. Valve,Wing,WKM-M,3 1/8 SM FE, t' HWO,EE tnm • �I • Adapter,OCT•AS•ESP,13 5/8 5M API hub All al • lig X 4 1/16 5M stdd top,w/2•Yr control line exits,prepped w/OCT 400-4 pocket 1 — : t• : •l, 7"iii j'wo � {J!til .i 0 111 It.1. r. All unihead annular valves,2 Unihead,OCT type 3,13 5/8 SM API F; 1/16 SM FE OCT•20,H1N0 hub top X 13 3/8 BTC casing bottom, /,..• �� � w/1-2 1/16 SM SSO on lowerI -414111 14 4 ' section,1-2 1/16 SM SSO on middle section,3-2 1/16 5M 550 on upper • t 101"1" section,IP internal lockpin assy .1 f , 'i I / • _� 'lliValle,OCT-20,3 1/8 2M FE, Starting head,OCT,21 x 2M FE X • i� it.`r# ' HWO 24"SOW,w/1.31/8 2M EFO,full ill r• ' it/' I iiset of lockpins �� . ►"m ' ril 1 '.:• , .3318 Page 32 Revision 1 March,2017 • • K-03RD2 Drilling Procedure Rev 1 Ililcorp,11a.ka. 22.0 Days vs Depth Days Vs Depth 0 K-03RD2 2000 -- 4000 $ 6000 O Y 8000 10000 12000 14000 , 0 5 10 15 20 25 30 Days Page 33 Revision 1 March, 2017 • • 14K-03RD2 Drilling Procedure Rev 1 llilcorp: I,-k..1.1.1: 23.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: l KO3RD2 I Producer FIELD MCARTHUR RIVER KO3RD2 SURFACE X: 213768 ; As-Built Survey STATE Alaska SURFACE Y: 2511793 BOTTOMHOLEX.' j I 207571 TVD REF DATUM KB 80TTOMHOLEY: 2507151 TVD REF ELEV 122 COORD REF SYSTEM NAD27 AK4 True North GROUND ELEV 0.0 PROPOSED TD 113322 . MD WATER DEPTH 73.0 PROPOSED TD 9794 t TVD Drill a sidetrack out of the K-03RD(King Salmon)to test and complete the Hemlock H-1 thru H-6 benches. Hemlock pressures from K-10RD2 PBU in December of 2016. Objective. Geo Summary/ Based on subsurface evaluation Justification: KO3RD2 TARGETS,ANTICIPATED FORMATION TOPS&GEOHAZARDS TOP NAME FORMATION XPECTED MD TVD(FT) TVDSS(FT) Est. EMW Gradient __, FLUID - Pressure KOP I 9600 7109.57 6987.57 2910 7.9 I 0.41 COAL39I 11523 8868 8746 3911 8.5 0.44 H1X 12185 9295 9173 COAL59 COAL 12213 9308 9186 Hemlock Sand/Conglomerabr Oil Sand 12228 9314.24 9192.24 3717 7.7 0.40 H2 Sand/Conglomerate Oil Sand 12330 9358.81 9236.81 3735 7.7 0.40 H3 Sand/Conglomerate Oil Sand 12558 9458.99 9336.99 3776 7.7 0.40 H4 Sand/Conglomerate Oil Sand 12731 9534.5 9412.5 3806 7.7 0.40 H5 Sand/Conglomerate Oil Sand 12865 9593.54 9471.54 3830 7.7 0.40'r H6 Sand/Conglomerate Oil Sand 13005 9654.95 9532.95 3855 7.7 0.40 H7 Sand/Conglomerate Oil Sand 13181 9732.17 9610 3886 7.7 0.40 =Primary Objective =Secondary Objective TARGET SIZE 50 FT DATA COLLECTION REQUIREMENTS: Mud Logging 4 man Crew below KOP / LWD Data: GR/RES LWD,Triple Combo MAD pass ✓ E-Line Log Data Gyro run upon completion of the well to validate wellbore tortuosity and postcon COMPLETION TYPE ESP Completion ANTICIPATED RATES 8000 bpd gross fluid ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 4-1/2" Page 34 Revision 1 March, 2017 • • K-03RD2 Drilling Procedure Rev 1 Ililcorp Alaska,LI.0 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 1 March,2017 H • . K-03RD2 Drilling Procedure Rev 1 I Iilrorp:Ala.ka.IAA: 25.0 Rig Layout w 0 0 q r tx.o up I f � I xi v; • NO q z R 1 T1. w K vc N O O IFructure o St °� , s s w •c , 1.5)0 f____, , 10.060 + M O O' OH O oc to .o.1 to 1 ni ' ,u` is p Ilt11.I4 % rf"'"' *:W• I g m iii t,Ua! x �f�. • C 2,;t#��'�11 �Tf�.bI Z O p Y „M� 1.7•.71■� sm�s pH O O_ TT F x & s ooc o t = ED m O w a o EBI k- 00S'61r = C t i-- 1 T CD _N X' J u) o = r ((------------ _ 1 N _ .5.71*0 I II i f... t i 3, o ¢ 7 6 D P CD gL T o00 or —•..- 000 6z 1 \\N„,......____ a0 000 os c Page 36 Revision 1 March, 2017 • • K-03RD2 Drilling Procedure Rev 1 Ilileorp Alaska,i.l.0 26.0 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 37 Revision 1 March,2017 • K-03RD2 Drilling Procedure Rev 1 Ililcorp Alaska,11A: 27.0 Choke Manifold Schematic Choke Manifold Valves 2 " 3" To Shaker 3"Panic To Gasbuster 2 1/6 I ---..-0 © 2 1/16" CU? 2 1/16" g 2 1/16" i_/ 3 1/8" a / 081A Le.-0-10-_0.0.....1 I 1 f 21/16" eb21/16" Manual Choke Automatic Choke 2 1/16" Inlet Pressure Sensor 3"5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED= 3 1/18" 5,000 PSI VALVES AND LINES BLUE =2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold S7` c._ ON #10 16 'G..+/ :9 I '111 iM13a4124 Qq M ;I 016 #5ii. t s2 • 14 #15 lie_ ke IL C•1 M Nuukpik Drilling Rig S Choke Malorced Page 38 Revision 1 March, 2017 S , K-03RD2 Drilling Procedure Rev 1 Ililcorp Alaska,IAR: 28.0 Fluid Flow Diagrams x z x F S c.* . . . IT, d �X 1 1 1 1 1 1 1 1 1 I n p+lu It+P+....Ita is pa k i."-„i:ili'41:-....iL'iji:I: U la la lP la i%la lPlalp iiyi,. iN It i1I},.I1I i111I1 i Iw IM IM IM iy IM ig 13 1•[11111'1`lY In iY inln Is!w i+I:I:!.;i+!..;lip iSirli if iR�X 1X�X 1- O-. O a.a,....ii......... CTI” orn AV i 1 I I I t I I I Da Da V1 J 0) r) (a S A% ? co% A—.. Q' .1 co R K W% N� n El i 0 S co Daj'O v Z l i l l l l l i l I ialMl.siMiZiCirli=iii C1% G o V P l i i i i i l 1 i 1 DQ D4 DC DQ '' 1 1...4..i...p.iw iw lNi.'1 _ N — Q1 f0 f� i i 1'-'i"i,`-i^1^i'i`i O LI CI 1�Iaip I�l�IPiP) i-1.2.11..111:111 ip i d 2IRle 1 i 1.iFIkiP.;73•ig. I ® — • i"1F!.21,1111;V tv O i 1{I.Ip .ip is I,,Ip I & N fAiniA1A1Ai•r1l1.f1tA iririgivrivirivir a:a:a;a;a;a:aaa 481 4 Da II g r, V —404 ' 1.0 F. �o i i i xi i i i • Iyt l:Iu ita.:lol�o NA N N i i i liii NA W A i 1 i Ig!C! is DG 0 DQ i i� isiSi ! co �.. !,.c! !E a �9. k7' ) I 131a Cc5 1 I i8' I I IA I�c' , 3 a m `T1 i i.l�i_ ick;i 1 G a a o _c I 171 Is 1'I i5. 1 1-I• IIF I IM. �- i I 1 17 IA71 17 1 t 0 ill inpla lisai .iai. 20 irf crZ 3 Page 39 Revision 1 March, 2017 • • K-03RD2 Drilling Procedure Rev 1 Ilileorp Alaska,1.1.1: C C n _X or V o T. X- r io s CO 1 1 1 1 1 1 I 1 1 '1413 Cm. I I I ! i I I 1 1 I (7 (Tz 114 114 014 1.4 1114 114 114 114 fl. (PIQIPfQ1a IPIQ1QI�' IO I'�I14•1I010 Ito llf iN ltr I$I Ig iO EO 1p iO ig lg 5.• 1919 I?. as. 19 fli IT. r?, 19 I nlninl nlninlnl nin Iq lq it i;it I;it it it — I 1 i i t I 1 t 1 .v l5.t101v01010ii?1010 1. G _pp _ •a•a�6 �° �O �O �O �D �O w. oip ACA Awl 11 I I t I , , 1 • D4 DQ 0 co n 01 n ,, ♦ of F AL1 OS WA •—� a A _ x N • F x Y J _y o LJ N. _ A *O l G g (6 1 1 1 1 1 1 1 1 . _ D4 O 1 1 1 I 1 1 1 1 1 I g ��7z[// O ♦ /nim i0'i.l1PINil.141141~i011� co Q. A tl l ) l 1 1 I 1 1 1 1 j._a, ,:..' I it.,iu;14;14 iu'trio 1141 VV YV A i�i`° iii:i«..... I.r.I.:i N CO C Fr Ig it! -1 =1 =1 °I °I UI 11 c 1, .g.p4 IQ I I994 IoY IQ IO1�. = I0.it(o" i9 1.•:, "01s CU , . I°�I"I�.I9.ill tr.„it 1 iI'.! 0 1'1.Ir I�I�it fr I�I�1 1 N♦ v I ins 14 1g 1A(A I• I,T Iq I O A s C ,n.n,n.n.n.n.n.n.n 7 la-Is-1r la-it is IS Ir Ir ... r•' i$i$iaii$iiiai$i$ i -. V. VApVI r v I , N 01 � Y nI N. 0 00 —A • M N ill vi 1 I Itit 04114114 114I14h41.- ji'H i1Ji"iOi0 mN.N N CO A I Y r t 1 T r'— 44 IX I I I i0i 1 IN C i I in ill I I IS A U• I ip IA iF, i'r I iv I 1+ R l' . I i17 p G 1"1, IY ...it I it if._ I• 73 k itoli°o E, i-Inlp L�1 -0 to Ivrob�. •I 1=!70.1, • _D K 3 -n T I 1" IA lir1 IA ID O rt- c I 1• -•i_ i6i° i it-* 1 14 Ig I�I�I I. I 1 I 0.1 I.I t I I I 1° I' i _a I I Ini q11 i 1,, - v In lai° g!° !° I a 1n g "6 ,--- Cra Page 40 Revision 1 March, 2017 a K-03RD2 Drilling Procedure Rev 1 Ihle•„irp Ia.ka.I.I.I c n P _� ri T `� T �.--i V F, _ E. W 1 I I I I 1 i I 1 ISD • -D !telt&JlPw4 iiFi1,.a1— ISDqc 1 1 1 1 1 1 i 1 i 9 i) i"t' t' i.♦iuiuiuiui... f N 1.:=1«.11.::1...-1;.."1:.:1;:1«.:1;.:. -1•t PPPOPP P P P 41 , viI .S >:1 sl .I =i Si �I �1 z i' I 1 1$i laiai to igigiSi8ig-igi8i8i`d' I -ai9iv-o-ovivb 101.0i.iii"i":71, "n •Y •Y •Y•Y•Y Iq 17;1;74 IA IA IA IA Iq .ninlolo101cool010 O 00 $,4 e O (xi g(;) g-4 rn .. i l>1 O = cn ro sY w v N$ , BQ '(:7; D4 O ie;1y 1p•Iy,Ij,i,`Itji,`..Ip1 co X •J -- 111111111 1 1 1 , DQ D4 T T if�i T T1�1 N ..a co co 1 !;"II..it _ - �� .. 44 ,.� 1..i-1 !t!E 1pilalP!t!4:!PIQI A O mi-i, 1-f, 1 °i '1. ifl�'I II Iv^Int„I i i I I4 I'i l � i + 1 1 1 2r n M 9•9 _ IFIi--hill-i-••l� � ll ppp9-p Ip il'ii lE iE IY ii.Ii i f I OA o T Ci• I i6 IA I',i;i;i;IA Is 1 r a r l i i i----1---i f--T"" �5 n n.n n n.n.n IQ1r 0 ID Io°. s�i�Ip -+�j Iv iq 1$1$10 1.111!i: cs)Q 5 i i i 1 I , ! I I'6 4 Lir v \ 1 .. V t . PO E., MY ;g n A I i I ,;„,!i ! ! IN NJ IV ! ,,...,, r!"!...,.,. R CO S 1 1 I 1 i- 1, 1 I I ieIM I IS A N_ i i.„1, 1-.,sl I. 1 1 I” ,:.°iyl i� a 1 I'I' 15 ib 1 I� 7J l..1Y ly Ii:ie ll--' �,r -0 0 ipii4 %•i-I,.Inie 7 -0 KOP' C K TI T 1 Illi ll-!l61i ir. Q Cl) 0 i i5.1! Iq#4I Id i *14 In IIiY'i l... ti I I%1q I i� I i I t+1 I i4 r 41.01...01,13.14!0� l� 1•la 1 !Les!Die tr. i i l t 1 1 1 Page 41 Revision 1 March, 2017 I • K-03RD2 Drilling Procedure Rev 1 IliIcor!) tla-la,1,1.1 29.0 Offset MW vs. Depth TVD MW vs TI/D Offsets 0 —A-18(1968) 1000 —K-26RD I —K-10RD 1 2000 —A-27RD2 IL- 3000 4000 5000 , > I- I 6000 1 I ph, 7000 8000 -I 1 1110.. 9000 1 1 I ..e• a 10000 1 1 11000I 17 8 9 10 11 12 13 14 15 Mud Weight(PPG) Page 42 Revision 1 March, 2017 • 411 K-03RD2 Drilling Procedure Rev 1 Ilik orp:Ult.ka.iii: 30.0 Casing Design Information Calculation & Casing Design Factors Cook Inlet Offshore DATE 3/1/2017 WELL: K-03RD2 FIELD: McArthur River DESIGN BY: Monty M Myers Design Criteria: I Hole Size j Mud Density: ! Hole Size 8-1/2" Mud Density: 9.0 ppg _ Hole Size Mud Density: Drilling Mode f I 1 ) 1 MASP: 2473 psi (See attached MASP determination &calculation) r I I i i. ri Production Mode MASP: 4690 psi (See attached MASP determination & calculation) ollapse Calculation: t I Section Calculation 1, 2 Normal gradient external stress (0 43 psi/ft) and the casing evacuated for the internal stress E I Casing Section Calculation/Specification 1 2 3 4 Casing OD 7-5/8" Top(MD) 8,800 Top(TVD) 6,528 Bottom (MD) 13,322 Bottom (TVD) 9,804 Length 4,522 Weight(ppf) 29 Grade L-80 Connection DWC/C Weight w/o Bouyancy Factor(lbs) 131,138 Tension at Top of Section (lbs) 131,138 Min strength Tension (1000 lbs) 254 Worst Case Safety Factor(Tension) 1.94 Collapse Pressure at bottom (Psi) 4,216 , Collapse Resistance w/o tension (Psi) 4,790 Worst Case Safety Factor(Collapse) 1.14 MASP (psi) 2,473 Minimum Yield(psi) 6,890 Worst case safety factor(Burst) 2.79 Page 43 Revision 1 March, 2017 III 111 K-03RD2 H Drilling Procedure Rev 1 Iliborp Sla-ka.I,I,i: 31.0 8-1/2" Hole Section MASP Irl Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section H ylcorp K-03RD2 Cook Inlet,Alaska MD TVD Planned Top: 9600 7110 Planned TD: 13322 9804 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad KOP 7,110 2910 COAL 8.4 0.44 COAL39 8,868 3911 _ COAL 8.4 0.44 H1X 9,295 3999 Sand/Conglomerate 8.3 0.43 H2 9,359 3735 Sand/Conglomerate 8.3 0.43 _ H3 9,459 3776 Sand/Conglomerate 8.2 0.43 H4 9,535 3806 Sand/Conglomerate 7.7 0.40 H5 9,594 3830 _Sand/Conglomerate 7.7 0.40 H6 9,655 3855 Sand/Conglomerate 7.7 0.40 H7 9,732 3886 Oil Sand 7.7 0.40 TD 9,804 3933 Oil Sand 7.7 0.40 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date A-27RD2 9.3-9.5 7,755 9,718 2016 A-27 8.9-9.8 3,360 7,017 1973 A-27RD 9.5-9.7 6,328 9,950 1997 K-26RD 9.4-10.2 7,800 9,971 1995 Assumptions: 1. Anticipated fracture gradient at 9600'TMD(7110'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: 7110(ft)x 0.7(psi/ft)= 4977 4977(psi)-[0.1(psi/ft)*7110(ft)]= 4266 psi MASP from pore pressure;normal gradient at TO,(0.43 psi/ft) 9804(ft)x 0.43(psi/ft)= 4216 psi 4216(psi)-(0.1(psi/ft)*9804(ft))= 3236 psi MASP from pore pressure;unknown gas sand at TD,,at 9.2 ppg( '784 psi/ft) 9804(ft)x 0.4784(psi/ft)= 4690 psi Downhole 4690(psi)-[(2/3)*0.1(psi/ft)*9804(ft)]+[(1/3)*0.4784(psi/ft)*9804(ft)]= 2473 psi Drilling MASP Summary: (J/ � S�1. MASP while drilling 8-1/2"hole is governed by porepressure minus A(4 f.., , n 2/3 of wellbore evacuated to gas(remaining 1/3 remains 9.2 ppg drilling fluid) 4 1A510 Cor D Page 44 Revision 1 March, 2017 e-V--- C • S K-03RD2 Drilling Procedure Rev 1 I lileorp,1Iaska.1,1,1: 32.0 Plot (NAD 27) (Governmental Sections) -. \ ', fC-22 BH1 \ a, \ Legend \\ .` 1 K-03RD2_SHL ........... \\ X K-03RD2_TPH S009 013W \ \ S009N013W K-03RD2_BHL e'qv - \j® \ • Other Surface Hole Location -.` \\ • Other Bottom Hole Location ..,"\ `\\ //'// K-12BHL k_(i RDS s}IL _ 1.- -• -.' „W-.e:ll Paths _ �' __�_r__�_ _ ' r ,Grs=-- 1OilandGasUnitBoundary ''— ___ It_9;t!tT� \ ri`r. A. .itll K-18RDPBT 8111, - - ,/ ' // \\ \ -YBAD BHL__ ' 09.;/// \\ \ / /'' -c // / \ v ADLO18777--= '� p 11lb, \ „' -�-- i 1 K-01P6_gHL____--- .... o°, //1 1l ,/K-01 BHS.- -- .- ',g0°�p /// 11 ', "NFLT-03 BHL.......--' r 000005 - '_'.A, /,,, Il 14 TRADING BAY UNIT /' , 11 ADL0175_94, q rode.6 ,' ' K-N BHL 1l S009N013W- (,OSBHL S009N01.3W --- S009Nmew / 1 m , 3R13 BHL /.' t -(l k RD' TPH ,/ 11 / 1 /'// 001 /// 11 / o 11 o /' /'� ° �� 11 0 1 ' / o o 11 0 K BHL ° ��' ;1 4 OK-06P82 qHL` A 'F -O;RD2 BHL 11 K-04RD`giL \ 1 \ G-19 BHL K-04�• \1 t aG-29 BHL t'•8RD BHL TRADING BAY G-33HL B a • \ '\,;\`50�09N013 S009N01 4)3 ` S009N013W ADL018730 ‘,V...\ 1 \ G-05RD BHL / c\ 1 \ ,• / G-13 BHL \ \\• \ \ \. /' II 0 1.000 2.000 Trading Bay Unit Feet K-03RD2 Alaska State Plane Zone 4.NAD27 A IGlrorp:1104a,114: Map Date:3/1/2017 Page 45 Revision 1 March, 2017 H0 K-03RD2 Drilling Procedure Rev 1 Ilfll-urp.‘la.ka.1,1.1: 33.0 Slot Diagram (As Built) (NAD 27) CENTER LEG 4 LAT:60'51'55.8806N LON.151"36'21.1490'W CENTER LEG 1 N:2511794.345' LAT:60°51'19.9419'N E:213761.651' LON:151'36'19.8893'W ASP ZONE 4 NAD 27 N 2511756.50T :ORO E 213820.519' ,,,rASP ZONE 4 NAD 27 K-2+taL 2...,K-+°-.. 7►1��� � 180'FEL ..1tiR0 19 ,K.z7 KING SALMON PLATFORM K-).20 ASBUILT WELL LOCATIONSK.,,:A 120'FEL SECTION 16,T9N,R13W,S.M.,AK R40 K_. K NM) / "O WELL SLO1S 11.x'.;ll CENTER LEG 3 LAT:60'51'55.1292°14 / 223 FEL LON:151°36'22.1035'W 14:2511719.224' E'213712.532' ASP ZONE 4 NAD 27 ...l)RD ' " K.1 IA- 157'FEL OC-' H.1`FD CENTER LEG 2 LAT:60°51'54.7696N LON:151'36'20.9005'W N:2511681.260' w 726'FSL(N .) E:213771.191' Z ASP ZONE 4 NAD 27 J Z 650'FSL(NTS) Q I— C:r:i FSL INTS: O IW 6 4'FSL(NTS) U) O W I- U Q c, F- O SECTION CORNER D. (PROTRACTED) N 2511063.548' E:213922.792' PROTRACTED SECTION LINE NOT TO SCALE(NTS) 21 12 21 22 NOTES 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION ``�)%\1111 (EPSOLUTION ON FROM NGS STH 2010)AND ICAL ATIONS KEN5LAC51 ANB)IS AN D AC23 TO ...............1 II ESTABLISH POINT#300. THE ALASKA STATE PLANE COORDINATES �� ��7♦♦ NAD 83 ZONE 4 IN FEET ARE: N=2511443.373 "*•' m •*♦ E=1353731.256 !J.4.,.. ♦ ♦ � 7I1f1A..... ELEV.=99.189(NAVD88) ♦ ., stay A raa.ty_ 2.SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED ♦i �',- • VALUES. SCALE I,, :!/?5f/?;!:' 3. DATUM TRANSFORMATIONS(NAD83 ASPZ4 TO NAD27 ASPZ4) 0 `�'' j tII I11�������` WERE DONE USING CORPSCON SOFTWARE VERSION 6.0,1. 1 1tE r ' A • re,�rc1 HILCORP ALASKA,LLC �'` KING SALMON PLATFORM WELLS DA E t`t f3 ti 7 COOK INLET ALASKA DRAWN Br LK AS BUILT SURFACE LOCATION gc'`E '-._` 1'"01101 NO 14>,' s„EERlN0,YAPPING,SURVEYING/TEST,. NAD 27 BOOK NO 144E P 0 80%OR$01.007114 AN 90O, "K"" K^,f. :ACE lOON 14 714 tow,z,� PROTRACTED SEC. 16 TO9N R13W S"PP7 EVA..s.E.xs•tek.a.,•,m,,. Harm") 'Ua.i.a.LLC ') c><2 SEWARD MERIDIAN,ALASKA Page 46 Revision 1 March, 2017 K-03RD2 Drilling Procedure Rev 1 In1I1'11rp:%I:I.ka.I.l.f. NAD 27 Slot# Well# Northing Easting Latitude Longitude Center Leg 1 2511756.503 213820.519 60'51'55.52222" -151°36'19.94191" 1 K-21RD 2511751.133 213822.994 60°51'55.46995" -151°36'19.88928" 2 K-30 2511750.754 213819.220 60°51'55.46531" -151°36'19.96528" 3 K-18RD 2511753.106 213815.860 60°51'55.48766" -151°36'20.03428" Leg 1 4 K-17 2511757.623 213814.976 60°51'55.53191" -151°36'20.05437" 5 K-23 2511761.085 213816.638 60°51'55.56639" -151°36'20.02253" 6 K-19 2511761.888 213820.828 60°51'55.57531" -151°36'19.93833" 7 K-22RD 2511759.441 213825.218 60°51'55.55228" -151°36'19.84850" 8 K-20 2511754.730 213825.531 60°51'55.50598" -151°36'19.83984" Center Leg 2 2511681.260 213771.191 60'51'54.76960" -151°36'20.90053" 9 _ K-15RD 2511676.516 213774.559 60°51'54.72372" -151°36'20.83019" 10 K-9 2511675.411 213770.205 60'51'54.71178" -151°36'20.91754" 11 K-4RD 2511678.297 213765.971 60'51'54.73918" -151°36'21.00445" Leg 2 12 K-11 2511682.498 213765.183 60'51'54.78034" -151°36'21.02242" 13 K-13RD2 2511685.931 213767.848 60'51'54.81478" -151°36'20.97031" 14 _ K-2RD 2511686.644 213772.096 60'51'54.82282" -151°36'20.88491" 15 K-7RD 2511684.476 213775.691 60°51'54.80235" -151°36'20.81128" 16 K-5 2511680.120 213776.722 60°51'54.75972" -151°36'20.78831" Leg 3 Center Leg 3 2511719.224 213712.532 60'51'55.12919" -151°36'22.10347" Center Leg 4 2511794.345 213761.651 60'51'55.88057" -151`36'21.14901" 25 K-26RD 2511789.752 213764.548 60'51'55.83605" -151°36'21.08827" 26 K-1RD2 2511788.570 213760.661 60'51'55.82347" -151°36'21.16616" 27 K-10RD 2511791.323 213757.250 60°51'55.84976" -151°36'21.23636" Leg 4 28 K-25 2511795.528 213756.002 60°51'55.89085" -151°36'21.26364" 29 K-12RD2 2511799.318 213758.343 60'51'55.92872" -151°36'21.21826" 30 K-6RD 2511799.443 213762.467 60°51'55.93095" -151°36'21.13506" 31 K-24RD2 2511797.672 213766.437 60'51'55.91447" -151°36'21.05403" K-3RD 2511793.127 213767.529 60'51'55.86999" -151°36'21.02976" VRNECT HILCORP ALASKA,LLC n£viso. KING SALMON PLATFORM WELLS [ATE 62`''° COOK INLET ALASKA C./WN BY ICK AS BUILT SURFACE LOCATION SCA`E 1. VVtCl'lf;t IKI 1..i:1 ENGINEERING.'WWVINO NAD 27 BOOK NO 14 0. SURVEYING TESti.i 1. v04CE IV TI1)-424 Oi 077SWOT siaxT1 PROTRACTED SEC. 16 TO9N R13W WET 0.W SAICI-ANE(�B.aMECG CO" 11111'111'II 1I:I.AiI. I.I.I. -" 2 SEWARD MERIDIAN,ALASKA Z Page 47 Revision 1 March, 2017 I K-03RD2 Drilling Procedure Rev 1 ❑ilcor1,Ala4ka,LLI: 34.0 Directional Program (wp05) Page 48 Revision 1 March, 2017 I • Hilcorp Alaska, LLC McArthur River King Salmon Plan: K-03 - Slot Slot 32 K-03RD2 Plan: K-03RD2 WP05 Standard Proposal Report v, 33. 10 March, 2017 I �< rY MIME 1 �, 4 - HALLIBURTON Sperry Drilling Services _::` Hilcorp Alaska,LLC REFERENCE INFORMATION HALLIBURTON _ Hilcorp Calculation Method: Minimum Curvature Co-ordinate(N/E)Reference: Well Plan:K-03-Slot Slot 32,True North Sperry DrillingError System:ISCWSA Vertical(TVD)Reference' K-03RD2 @ 122.00usft Scan Method: Closest Approach 3D Measured Depth Reference: K-03RD2 @ 122.00usft Error Surface: Elliptical Conic Warning Method: Error Ratio Calculation Method: Minimum Curvature Project: McArthur River Site: King Salmon SECTION DETAILS well: Plan:K-03 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Wellbore: K-03RD2 1 9600.00 43.95 248.00 7109.57 -2942.61 -4905.10 0.00 0.00 5673.91 g K-03RD2 WP05 2 9617.08 45.00 245.41 7121.76 -2947.34 -4916.09 12.29 -60.00 5685.47 Design: 3 9637.08 45.00 245.41 7135.90 -2953.23 -4928.95 0.00 0.00 5699.22 4 10317.51 14.95 208.39 7722.50 -3135.98 -5197.37 5.00 -163.88 6023.15 5 11170.10 14.95 208.39 8546.21 -3329.51 -5301.96 0.00 0.00 6225.09 6 12151.05 64.00 208.00 9280.49 -3863.07 -5586.69 5.00 -0.46 6778.99 7 12451.05 64.00 208.00 9412.00 -4101.15 -5713.28 0.00 0.00 7025.78 K-03RD2 WP05 Tgt 1 DDI = 6.418 8 13322.00 64.00 208.00 9793.80 -4792.32 -6080.79 0.00 0.00 7742.24 CASING DETAILS WELL DETAILS: Plan:K-03 TVD TVDSS MD Size Water Depth: 73.00 9793.80 9671.80 13322.00 7-5/8"x 8 1/2" +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2511793.12 213767.53 60°51'55.870 N 151°36'21.030 W SURVEY PROGRAM Date:2017-03-10T00:00:00 Validated:Yes Version: Depth From Depth To Survey/Plan Tool 122.00 2522.00 K-03 PB1 CB-Gyro-MS - 2622.00 9600.00 K-03RD CB-Gyro-MS 6175- 00 9600.00 10000.00 K-03RD2 WP05 MWD Interp Azi+sag - C:i 10000.00 13322.00 K-03RD2 WP05 MWD+SC+sag I 6500_ 00 FORMATION TOP DETAILS - 90 TVDPath TVDssPath MDPath Formation - Start Dir 12.29°/100':9600'MD,7109.57'TVD:60°LT TF 8868.00 8746.00 11523.13 COAL39 6825- 9295.00 9173.00 12184.15 H 1 X 9308.00 9186.00 12213.81 COAL59 - 600 .- End Dir :9617.08'MD,7121.76'TVD 9314.24 9192.24 12228.04 Hemlock - 0 9358.81 9236.81 12329.71 H2 - --- " 9458.99 9336.99 12558.24 H3 - - Start Dir 5°/100':9637.08'MD,7135.9'TVD 9534.50 9412.50 12730.49 H4 7150- 9593.54 9471.54 12865.17 H5 9654.95 9532.95 13005.26 H6 - 10000 0 9732.00 9610.00 13181.02 H7 O - 00 End Dir :10317.51'MD,7722.5'TVD 7475- - 0p 06 c 7800- - 1p5p0 0 m - ^00 o - 41 8125- ap - Start Dir 5°/100':11170.1'MD,8546.21'TVD L - a - QD O 11000 ,�r 8450- - Cs - U_ - _ Ooh 6 8775- 11500 <I'11: - COAL39- End Dir :12151.05'MD,9280.49'TVD 9100-- 10600 �ry0o '\ - - H1X, o . -- COAL59- �ryho Total Depth:13322'MD,9793.8'TVD - sa25-- 11000 Hemlock H2 H3 �000 ,1, 1,000 - H4 H6 �ory 9750- K-03RD2 WP05 Tgt 1 H6 H7- ,txNni 00 - 16 • - 1 /,K-03RD2 WP05 -K-03RD 10075- X61 7 5/8"x8 1/2" - 11 - K-03 10400- - iiiIIIIIIIIIIIIIIIIIIIIIII III III III SII IIIIIIIII IIIIIIIIII I II I IIIIii 4875 5200 5525 5850 6175 6500 6825 7150 7475 7800 8125 8450 8775 9100 9425 Vertical Section at 231.76°(650 usft/in) • • a O m O + N V. m S; 2 000 mV Z � - �.1 "6 g Z ��'> > ~oo N o o m to co v a • d o • — L r O aYY N _NEEg 0 Z , N\ Q IX l �"F �' -15') cw cq oao,, ,,p � €msw q aapp o -- o¢ O oo p - o 3 150 .0 W � fon x rn w wo5- - oc O m- 5500 m ani L.C o 0, ... U N p N 0,0 CO 8 y5 O 0 �50 p _ 0 ,,,, 1 °0000 - `I 0 59 K.03 egg ..\5\� o o o0 0 - , a ;SO —z 0)00 8 ca - J p 0 J m r, AWY O - V •� 9 6250a U a o.o a g-' E¢<�m 5� 0 - h E3.-- 3 —N C S E0 o at a n - I N �Uww $ x,00 r'aEao, 650 a mt r _F t `g0ri O c of - n 03 — Z os�o� a o - �" a _mw`u>w E iI 9 baso ti 1 a O U c - 6 n x N _ C _ ,op0 b _ 1. L r - o > C d 0 , �S A _ E O < TLS , 3 , T - EON gio I p « .. =70 . a a "(' e t c r CEXh v 0 - • 0)GMCO •5‘‘ `a~ µ o 2 - U C N 0 041 YdYY 4' c 0 1 _ o U 2- C ac , .. —v c6 �p O��d4. ISO ^0� ❑ c - o 2 rt ,.000 - ti$ e it 3 i'' '' _ _ Q 3•50 a I O q IP FE: 0ISO mg ,1o,� _ � � i i i i i l l s i i i l h i l l l � l I I T I I I I I I ` l I I I I I I I r T 1 1 1 1- 1 I T T i l l i i i l 1--- 3 � .J 0} N O N v, N OOO N N N O N v N ` N fel N N, en N, N1 N1 q' I N N q = m (ui jsn oct)(+)quoj.U(-)41nos • 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:K-03-Slot Slot 32 Company: Hilcorp Alaska,LLC TVD Reference: K-03RD2 @ 122.00usft Project: McArthur River MD Reference: K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: Plan:K-03 Survey Calculation Method: Minimum Curvature Wellbore: K-03RD2 Design: K-03RD2 WP05 Project McArthur River 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 King Salmon Site Position: Northing: 2,511,786.28 usft Latitude: 60°51'55.800 N From: Map Easting: 213,756.95 usft Longitude: 151°36'21.240 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.40° Well Plan:K-03-Slot Slot 32 Well Position +N/-S 0.00 usft Northing: 2,511,793.12 usft Latitude: 60°51'55.870 N +EI-W 0.00 usft Easting: 213,767.53 usft Longitude: 151°36'21.030 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Water Depth: 73.00 usft Wellbore K-03RD2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2016 11/3/2016 16.25 73.76 55,453 Design K-03RD2 WP05 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,600.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 231.76 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (0) (0) (usft) usft (usft) (usft) (°1100usft) (°/100usft) (°/100usft) (0) 9,600.00 43.95 248.00 7,109.57 6,987.57 -2,942.61 -4,905.10 0.00 0.00 0.00 0.00 9,617.08 45.00 245.41 7,121.76 6,999.76 -2,947.34 -4,916.09 12.29 6.15 -15.05 -60.00 9,637.08 45.00 245.41 7,135.90 7,013.90 -2,953.23 -4,928.95 0.00 0.00 0.00 0.00 10,317.51 14.95 208.39 7,722.50 7,600.50 -3,135.98 -5,197.37 5.00 -4.42 -5.44 -163.88 11,170.10 14.95 208.39 8,546.21 8,424.21 -3,329.51 -5,301.96 0.00 0.00 0.00 0.00 12,151.05 64.00 208.00 9,280.49 9,158.49 -3,863.07 -5,586.69 5.00 5.00 -0.04 -0.46 12,451.05 64.00 208.00 9,412.00 9,290.00 -4,101.15 -5,713.28 0.00 0.00 0.00 0.00 13,322.00 64.00 208.00 9,793.80 9,671.80 -4,792.32 -6,080.79 0.00 0.00 0.00 0.00 3/10/2017 11:25:33AM Page 2 COMPASS 5000.1 Build 81 • • Halliburton I-IALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:K-03-Slot Slot 32 Company: Hilcorp Alaska,LLC TVD Reference: K-03RD2 @ 122.00usft Project: McArthur River MD Reference: K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: Plan:K-03 Survey Calculation Method: Minimum Curvature Wellbore: K-03RD2 Design: K-03RD2 WP05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (^) (°) (usft) usft (usft) (usft) (usft) (usft) -122.00 0.00 0.00 0.00 0.00 -122.00 0.00 0.00 2,511,793.12 213,767.53 0.00 0.00 100.00 0.00 0.00 100.00 -22.00 0.00 0.00 2,511,793.12 213,767.53 0.00 0.00 200.00 0.00 0.00 200.00 78.00 0.00 0.00 2,511,793.12 213,767.53 0.00 0.00 300.00 0.58 143.00 300.00 178.00 -0.32 0.24 2,511,792.80 213,767.76 0.58 0.01 400.00 0.93 123.12 399.99 277.99 -1.28 1.23 2,511,791.82 213,768.73 0.43 -0.18 500.00 1.77 105.84 499.96 377.96 -2.13 3.31 2,511,790.91 213,770.78 0.92 -1.28 600.00 2.16 125.68 599.90 477.90 -3.50 6.52 2,511,789.47 213,773.96 0.77 -2.96 700.00 2.03 116.54 699.83 577.83 -5.65 9.58 2,511,787.24 213,776.97 0.36 -4.03 800.00 2.47 150.64 799.76 677.76 -7.94 12.37 2,511,784.88 213,779.70 1.39 -4.80 900.00 4.01 189.79 899.61 777.61 -13.27 13.04 2,511,779.54 213,780.24 2.61 -2.03 1,000.00 7.18 211.42 999.14 877.14 -21.98 9.35 2,511,770.92 213,776.34 3.76 6.26 1,100.00 11.11 219.89 1,097.86 975.86 -34.69 -0.08 2,511,758.45 213,766.60 4.14 21.54 1,200.00 13.75 220.19 1,195.45 1,073.45 -51.25 -14.25 2,511,742.24 213,752.03 2.65 42.91 1,300.00 16.01 220.00 1,292.09 1,170.09 -70.91 -30.76 2,511,722.99 213,735.04 2.25 68.05 1,400.00 18.25 220.80 1,387.65 1,265.65 -93.36 -49.82 2,511,701.01 213,715.44 2.26 96.92 1,500.00 20.50 220.20 1,481.97 1,359.97 -118.53 -71.44 2,511,676.37 213,693.21 2.26 129.48 1,600.00 23.14 221.60 1,574.83 1,452.83 -146.67 -95.62 2,511,648.84 213,668.35 2.69 165.89 1,700.00 25.51 222.00 1,665.91 1,543.91 -177.35 -123.20 2,511,618.85 213,640.02 2.37 206.54 1,800.00 27.75 222.79 1,755.30 1,633.30 -210.49 -153.38 2,511,586.46 213,609.05 2.28 250.75 1,900.00 30.39 223.79 1,842.73 1,720.73 -245.80 -186.66 2,511,551.97 213,574.91 2.68 298.75 2,000.00 32.76 224.00 1,927.88 1,805.88 -283.52 -223.06 2,511,515.15 213,537.60 2.36 350.69 2,100.00 33.64 224.00 2,011.41 1,889.41 -323.07 -261.25 2,511,476.55 213,498.46 0.88 405.16 2,200.00 33.56 224.00 2,094.64 1,972.64 -362.94 -299.75 2,511,437.63 213,458.99 0.08 460.08 2,300.00 33.50 224.00 2,178.03 2,056.03 -402.65 -338.10 2,511,398.88 213,419.68 0.06 514.77 2,400.00 33.69 224.00 2,261.34 2,139.34 -442.43 -376.51 2,511,360.05 213,380.30 0.19 569.57 2,500.00 33.16 224.00 2,344.71 2,222.71 -482.15 -414.87 2,511,321.28 213,340.98 0.53 624.28 2,600.00 33.78 224.78 2,428.27 2,306.27 -521.46 -453.24 2,511,282.92 213,301.66 0.75 678.75 2,700.00 36.53 227.38 2,510.22 2,388.22 -561.29 -494.41 2,511,244.10 213,259.53 3.13 735.74 2,800.00 40.18 228.00 2,588.67 2,466.67 -602.82 -540.43 2,511,203.72 213,212.51 3.67 797.59 2,900.00 44.12 228.00 2,662.82 2,540.82 -647.70 -590.26 2,511,160.08 213,161.59 3.94 864.51 3,000.00 48.12 228.00 2,732.12 2,610.12 -695.92 -643.82 2,511,113.18 213,106.87 4.00 936.42 3,100.00 51.53 228.79 2,796.54 2,674.54 -746.77 -700.93 2,511,063.74 213,048.54 3.47 1,012.75 3,200.00 52.83 227.44 2,857.56 2,735.56 -799.41 -760.13 2,511,012.57 212,988.06 1.68 1,091.83 3,300.00 52.61 227.00 2,917.98 2,795.98 -853.70 -818.46 2,510,959.72 212,928.42 0.41 1,171.25 3,400.00 52.69 227.78 2,978.73 2,856.73 -907.56 -876.83 2,510,907.30 212,868.75 0.63 1,250.44 3,500.00 52.94 228.00 3,039.16 2,917.16 -960.90 -936.02 2,510,855.43 212,808.27 0.31 1,329.94 3,600.00 53.59 228.00 3,099.03 2,977.03 -1,014.49 -995.54 2,510,803.31 212,747.46 0.64 1,409.86 3,700.00 54.53 227.22 3,157.76 3,035.76 -1,068.97 -1,055.40 2,510,750.32 212,686.28 1.14 1,490.59 3,800.00 54.94 227.78 3,215.40 3,093.40 -1,124.36 -1,115.48 2,510,696.42 212,624.87 0.62 1,572.06 3,900.00 55.00 228.00 3,272.77 3,150.77 -1,179.19 -1,176.33 2,510,643.09 212,562.69 0.19 1,653.79 4,000.00 55.19 228.00 3,330.02 3,208.02 -1,234.05 -1,237.26 2,510,589.74 212,500.44 0.19 1,735.61 4,100.00 56.03 227.22 3,386.59 3,264.59 -1,289.56 -1,298.24 2,510,535.74 212,438.12 1.05 1,817.86 4,200.00 56.05 227.78 3,442.29 3,320.29 -1,345.85 -1,359.30 2,510,480.97 212,375.70 0.47 1,900.66 4,300.00 56.00 228.78 3,498.21 3,376.21 -1,401.02 -1,421.19 2,510,427.32 212,312.48 0.83 1,983.41 4,400.00 56.39 228.22 3,553.91 3,431.91 -1,455.87 -1,483.55 2,510,374.02 212,248.79 0.61 2,066.34 3/10/2017 11:25:33AM Page 3 COMPASS 5000.1 Build 81 I • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:K-03-Slot Slot 32 Company: Hilcorp Alaska,LLC TVD Reference: K-03RD2 @ 122.00usft Project: McArthur River MD Reference: K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: Plan:K-03 Survey Calculation Method: Minimum Curvature Wellbore: K-03RD2 Design: K-03RD2 WP05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,487.34 4,500.00 56.11 229.56 3,609.34 3,487.34 -1,510.87 -1,546.01 2,510,320.56 212,185.01 1.15 2,149.44 4,600.00 56.39 228.44 3,665.03 3,543.03 -1,564.99 -1,609.01 2,510,268.00 212,120.70 0.97 2,232.43 4,700.00 56.11 228.00 3,720.46 3,598.46 -1,620.63 -1,670.91 2,510,213.90 212,057.46 0.46 2,315.48 4,800.00 56.19 228.78 3,776.25 3,654.25 -1,675.83 -1,732.88 2,510,160.23 211,994.16 0.65 2,398.32 4,900.00 54.30 229.77 3,832.91 3,710.91 -1,729.58 -1,795.32 2,510,108.02 211,930.42 2.06 2,480.63 5,000.00 50.80 234.63 3,893.58 3,771.58 -1,778.79 -1,857.70 2,510,060.36 211,866.86 5.20 2,560.08 5,100.00 50.39 236.00 3,957.53 3,835.53 -1,821.94 -1,921.31 2,510,018.77 211,802.21 1.14 2,636.76 5,200.00 50.69 235.22 4,021.06 3,899.06 -1,865.47 -1,985.11 2,509,976.82 211,737.36 0.68 2,713.81 5,300.00 50.16 235.00 4,084.64 3,962.64 -1,909.71 -2,048.35 2,509,934.14 211,673.06 0.56 2,790.86 5,400.00 48.04 237.32 4,149.91 4,027.91 -1,952.19 -2,111.06 2,509,893.21 211,609.32 2.75 2,866.41 5,500.00 47.30 238.78 4,217.49 4,095.49 -1,991.00 -2,173.72 2,509,855.95 211,545.73 1.31 2,939.65 5,600.00 46.86 239.78 4,285.56 4,163.56 -2,028.43 -2,236.70 2,509,820.07 211,481.86 0.86 3,012.28 5,700.00 46.16 240.00 4,354.35 4,232.35 -2,064.74 -2,299.54 2,509,785.31 211,418.15 0.71 3,084.11 5,800.00 45.02 239.22 4,424.27 4,302.27 -2,100.81 -2,361.26 2,509,750.76 211,355.56 1.27 3,154.91 5,900.00 44.36 239.78 4,495.44 4,373.44 -2,136.65 -2,421.68 2,509,716.41 211,294.28 0.77 3,224.55 6,000.00 43.66 242.33 4,567.34 4,445.34 -2,170.47 -2,482.39 2,509,684.09 211,232.76 1.91 3,293.16 6,100.00 43.09 246.89 4,640.06 4,518.06 -2,200.08 -2,544.30 2,509,656.00 211,170.15 3.18 3,360.12 6,200.00 43.19 248.78 4,713.09 4,591.09 -2,225.46 -2,607.71 2,509,632.18 211,106.14 1.30 3,425.63 6,300.00 44.03 248.22 4,785.57 4,663.57 -2,250.53 -2,671.89 2,509,608.70 211,041.37 0.92 3,491.55 6,400.00 45.22 248.00 4,856.76 4,734.76 -2,276.81 -2,737.01 2,509,584.02 210,975.63 1.21 3,558.96 6,500.00 44.33 249.55 4,927.46 4,805.46 -2,302.61 -2,802.85 2,509,559.83 210,909.17 1.41 3,626.65 6,600.00 44.78 250.00 4,998.98 4,876.98 -2,326.57 -2,868.50 2,509,537.49 210,842.95 0.55 3,693.05 6,700.00 45.39 251.56 5,069.53 4,947.53 -2,350.10 -2,935.35 2,509,515.61 210,775.55 1.26 3,760.10 6,800.00 45.11 251.22 5,139.83 5,017.83 -2,372.49 -3,002.85 2,509,494.88 210,707.52 0.37 3,826.98 6,900.00 45.78 251.00 5,210.15 5,088.15 -2,395.61 -3,070.09 2,509,473.41 210,639.74 0.69 3,894.10 7,000.00 46.00 250.22 5,279.65 5,157.65 -2,419.38 -3,137.95 2,509,451.31 210,571.31 0.60 3,962.11 7,100.00 47.17 250.00 5,348.54 5,226.54 -2,444.14 -3,206.07 2,509,428.22 210,502.61 1.18 4,030.94 7,200.00 47.50 250.78 5,416.14 5,294.14 -2,468.97 -3,275.44 2,509,405.09 210,432.65 0.66 4,100.80 7,300.00 46.91 251.00 5,483.99 5,361.99 -2,492.92 -3,344.89 2,509,382.86 210,362.64 0.61 4,170.16 7,400.00 46.56 251.00 5,552.59 5,430.59 -2,516.61 -3,413.69 2,509,360.86 210,293.28 0.36 4,238.87 7,500.00 46.50 251.00 5,621.41 5,499.41 -2,540.23 -3,482.29 2,509,338.92 210,224.13 0.06 4,307.36 7,600.00 45.91 252.56 5,690.54 5,568.54 -2,563.03 -3,550.85 2,509,317.81 210,155.02 1.27 4,375.32 7,700.00 45.94 253.78 5,760.20 5,638.20 -2,583.70 -3,619.55 2,509,298.83 210,085.84 0.88 4,442.08 7,800.00 45.41 253.22 5,829.96 5,707.96 -2,603.84 -3,688.31 2,509,280.38 210,016.61 0.66 4,508.54 7,900.00 45.25 253.00 5,900.34 5,778.34 -2,624.58 -3,756.25 2,509,261.30 209,948.18 0.23 4,574.75 8,000.00 45.64 254.56 5,970.56 5,848.56 -2,644.67 -3,824.56 2,509,242.89 209,879.40 1.18 4,640.83 8,100.00 45.94 255.00 6,040.26 5,918.26 -2,663.28 -3,893.81 2,509,225.98 209,809.72 0.44 4,706.74 8,200.00 46.78 255.00 6,109.35 5,987.35 -2,682.00 -3,963.64 2,509,208.98 209,739.45 0.83 4,773.17 8,300.00 45.44 255.77 6,178.35 6,056.35 -2,700.36 -4,033.64 2,509,192.33 209,669.02 1.45 4,839.52 8,400.00 45.58 256.00 6,248.72 6,126.72 -2,717.58 -4,102.58 2,509,176.81 209,599.68 0.22 4,904.32 8,500.00 45.95 256.00 6,318.42 6,196.42 -2,734.93 -4,172.15 2,509,161.17 209,529.71 0.36 4,969.70 8,600.00 45.61 256.00 6,388.09 6,266.09 -2,752.29 -4,241.76 2,509,145.52 209,459.70 0.33 5,035.11 8,700.00 45.89 257.56 6,457.98 6,335.98 -2,768.85 -4,311.33 2,509,130.67 209,389.74 1.15 5,100.01 8,800.00 45.02 257.22 6,527.93 6,405.93 -2,784.13 -4,381.13 2,509,117.10 209,319.58 0.90 5,164.29 8,900.00 44.94 257.00 6,598.82 6,476.82 -2,799.96 -4,449.87 2,509,102.95 209,250.48 0.18 5,228.07 3/10/2017 11:25:33AM Page 4 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTONI Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:K-03-Slot Slot 32 Company: Hilcorp Alaska,LLC TVD Reference: K-03RD2 @ 122.00usft Project: McArthur River MD Reference: K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: Plan:K-03 Survey Calculation Method: Minimum Curvature Wellbore: K-03RD2 Design: K-03RD2 WP05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,547.54 9,000.00 45.00 257.78 6,669.54 6,547.54 -2,815.50 -4,518.84 2,509,089.11 209,181.15 0.55 5,291.86 9,100.00 44.61 258.00 6,740.44 6,618.44 -2,830.19 -4,587.81 2,509,076.11 209,111.84 0.42 5,355.13 9,200.00 42.91 253.36 6,812.51 6,690.51 -2,846.69 -4,655.11 2,509,061.26 209,044.16 3.63 5,418.20 9,300.00 42.10 248.89 6,886.38 6,764.38 -2,868.70 -4,718.81 2,509,040.82 208,979.94 3.13 5,481.85 9,400.00 41.22 248.78 6,961.03 6,839.03 -2,893.19 -4,780.66 2,509,017.85 208,917.50 0.88 5,545.59 9,500.00 41.78 248.22 7,036.13 6,914.13 -2,917.21 -4,842.18 2,508,995.34 208,855.42 0.67 5,608.77 vJ.•) 9,600.00 43.95 248.00 7,109.57 6,987.57 -2,942.61 -4,905.10 2,508,971.50 208,791.89 2.18 5,673.91 aa ,,,, N Start Dir 12.29°/100':9600'MD,7109.57'TVD:60°LT TF W 9,617.08 45.00 245.41 7,121.76 6,999.76 -2,947.34 -4,916.09 2,508,967.03 208,780.79 12.29 5,685.47 End Dir :8617.08'MD,7121.76'TVD 9,637.08 45.00 245.41 7,135.90 7,013.90 -2,953.23 -4,928.95 2,508,961.47 208,767.79 0.00 5,699.22 Start Dir 5°/100':9637.08'MD,7135.9'TVD 9,700.00 41.99 244.10 7,181.54 7,059.54 -2,971.68 -4,968.12 2,508,943.97 208,728.18 5.00 5,741.40 9,800.00 37.23 241.68 7,258.57 7,136.57 -3,000.66 -5,024.87 2,508,916.39 208,670.74 5.00 5,803.92 9,900.00 32.54 238.66 7,340.58 7,218.58 -3,029.02 -5,074.50 2,508,889.26 208,620.43 5.00 5,860.45 10,000.00 27.93 234.77 7,426.96 7,304.96 -3,056.53 -5,116.63 2,508,862.79 208,577.64 5.00 5,910.56 10,100.00 23.48 229.51 7,517.06 7,395.06 -3,082.99 -5,150.94 2,508,837.17 208,542.70 5.00 5,953.89 10,200.00 19.28 222.03 7,610.17 7,488.17 -3,108.21 -5,177.16 2,508,812.61 208,515.87 5.00 5,990.09 10,300.00 15.53 210.88 7,705.60 7,583.60 -3,131.98 -5,195.09 2,508,789.29 208,497.36 5.00 6,018.89 10,317.51 14.95 208.39 7,722.50 7,600.50 -3,135.98 -5,197.37 2,508,785.34 208,494.98 5.00 6,023.15 End Dir :10317.51'MD,7722.5'TVD 10,400.00 14.95 208.39 7,802.19 7,680.19 -3,154.70 -5,207.49 2,508,766.87 208,484.41 0.00 6,042.69 10,500.00 14.95 208.39 7,898.81 7,776.81 -3,177.40 -5,219.76 2,508,744.48 208,471.59 0.00 6,066.38 10,600.00 14.95 208.39 7,995.42 7,873.42 -3,200.10 -5,232.02 2,508,722.09 208,458.77 0.00 6,090.06 10,700.00 14.95 208.39 8,092.03 7,970.03 -3,222.80 -5,244.29 2,508,699.69 208,445.95 0.00 6,113.75 10,800.00 14.95 208.39 8,188.65 8,066.65 -3,245.50 -5,256.56 2,508,677.30 208,433.13 0.00 6,137.43 10,900.00 14.95 208.39 8,285.26 8,163.26 -3,268.20 -5,268.83 2,508,654.91 208,420.31 0.00 6,161.12 11,000.00 14.95 208.39 8,381.88 8,259.88 -3,290.90 -5,281.09 2,508,632.52 208,407.49 0.00 6,184.80 11,100.00 14.95 208.39 8,478.49 8,356.49 -3,313.60 -5,293.36 2,508,610.13 208,394.67 0.00 6,208.49 11,170.10 14.95 208.39 8,546.22 8,424.22 -3,329.51 -5,301.96 2,508,594.43 208,385.68 0.00 6,225.09 Start Dir 5°/100':11170.1'MD,8546.21'TVD 11,200.00 16.45 208.35 8,575.00 8,453.00 -3,336.63 -5,305.81 2,508,587.41 208,381.67 5.00 6,232.52 11,300.00 21.45 208.25 8,669.55 8,547.55 -3,365.21 -5,321.19 2,508,559.21 208,365.59 5.00 6,262.29 11,400.00 26.45 208.18 8,760.91 8,638.91 -3,400.97 -5,340.37 2,508,523.93 208,345.54 5.00 6,299.49 11,500.00 31.45 208.14 8,848.39 8,726.39 -3,443.63 -5,363.20 2,508,481.84 208,321.67 5.00 6,343.83 11,523.13 32.60 208.13 8,868.00 8,746.00 -3,454.45 -5,368.99 2,508,471.17 208,315.62 5.00 6,355.07 COAL39 11,600.00 36.45 208.10 8,931.32 8,809.32 -3,492.87 -5,389.51 2,508,433.27 208,294.16 5.00 6,394.97 11,700.00 41.45 208.08 9,009.07 8,887.07 -3,548.31 -5,419.10 2,508,378.57 208,263.22 5.00 6,452.53 11,800.00 46.45 208.06 9,081.04 8,959.04 -3,609.53 -5,451.74 2,508,318.17 208,229.09 5.00 6,516.06 11,900.00 51.45 208.04 9,146.70 9,024.70 -3,676.06 -5,487.19 2,508,252.52 208,192.03 5.00 6,585.08 12,000.00 56.45 208.02 9,205.53 9,083.53 -3,747.40 -5,525.17 2,508,182.13 208,152.32 5.00 6,659.07 12,100.00 61.45 208.01 9,257.10 9,135.10 -3,823.01 -5,565.39 2,508,107.53 208,110.25 5.00 6,737.46 12,151.05 64.00 208.00 9,280.49 9,158.49 -3,863.07 -5,586.70 2,508,068.00 208,087.98 5.00 6,778.99 End Dir :12151.05'MD,9280.49'TVD 3/10/2017 11:25:33AM Page 5 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:K-03-Slot Slot 32 Company: Hilcorp Alaska,LLC ND Reference: K-03RD2 @ 122.00usft Project: McArthur River MD Reference: K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: Plan:K-03 Survey Calculation Method: Minimum Curvature Wellbore: K-03RD2 Design: K-03RD2 WP05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,173.00 12,184.15 64.00 208.00 9,295.00 9,173.00 -3,889.34 -5,600.66 2,508,042.08 208,073.37 0.00 6,806.22 H1X 12,200.00 64.00 208.00 9,301.95 9,179.95 -3,901.92 -5,607.35 2,508,029.67 208,066.38 0.00 6,819.26 12,213.81 64.00 208.00 9,308.00 9,186.00 -3,912.87 -5,613.18 2,508,018.86 208,060.28 0.00 6,830.61 COAL59 12,228.04 64.00 208.00 9,314.24 9,192.24 -3,924.17 -5,619.18 2,508,007.72 208,054.00 0.00 6,842.32 Hemlock 12,300.00 64.00 208.00 9,345.78 9,223.78 -3,981.28 -5,649.55 2,507,951.37 208,022.25 0.00 6,901.52 12,329.71 64.00 208.00 9,358.81 9,236.81 -4,004.86 -5,662.08 2,507,928.11 208,009.14 0.00 6,925.96 H2 12,400.00 64.00 208.00 9,389.62 9,267.62 -4,060.63 -5,691.74 2,507,873.07 207,978.13 0.00 6,983.78 12,451.05 64.00 208.00 9,412.00 9,290.00 -4,101.15 -5,713.28 2,507,833.10 207,955.60 0.00 7,025.78 12,500.00 64.00 208.00 9,433.46 9,311.46 -4,139.99 -5,733.94 2,507,794.77 207,934.00 0.00 7,066.05 12,558.24 64.00 208.00 9,458.99 9,336.99 -4,186.21 -5,758.51 2,507,749.17 207,908.30 0.00 7,113.96 H3 12,600.00 64.00 208.00 9,477.30 9,355.30 -4,219.35 -5,776.13 2,507,716.47 207,889.87 0.00 7,148.31 12,700.00 64.00 208.00 9,521.13 9,399.13 -4,298.71 -5,818.33 2,507,638.17 207,845.75 0.00 7,230.57 12,730.49 64.00 208.00 9,534.50 9,412.50 -4,322.91 -5,831.20 2,507,614.29 207,832.29 0.00 7,255.65 H4 12,800.00 64.00 208.00 9,564.97 9,442.97 -4,378.07 -5,860.53 2,507,559.87 207,801.62 0.00 7,312.83 12,865.17 64.00 208.00 9,593.54 9,471.54 -4,429.79 -5,888.03 2,507,508.83 207,772.87 0.00 7,366.45 H5 12,900.00 64.00 208.00 9,608.81 9,486.81 -4,457.43 -5,902.72 2,507,481.56 207,757.50 0.00 7,395.10 13,000.00 64.00 208.00 9,652.64 9,530.64 -4,536.79 -5,944.92 2,507,403.26 207,713.37 0.00 7,477.36 13,005.26 64.00 208.00 9,654.95 9,532.95 -4,540.96 -5,947.14 2,507,399.14 207,711.05 0.00 7,481.68 H6 13,100.00 64.00 208.00 9,696.48 9,574.48 -4,616.15 -5,987.11 2,507,324.96 207,669.25 0.00 7,559.62 13,181.02 64.00 208.00 9,732.00 9,610.00 -4,680.45 -6,021.30 2,507,261.52 207,633.49 0.00 7,626.27 H7 13,200.00 64.00 208.00 9,740.32 9,618.32 -4,695.50 -6,029.31 2,507,246.66 207,625.12 0.00 7,641.88 13,300.00 64.00 208.00 9,784.16 9,662.16 -4,774.86 -6,071.50 2,507,168.36 207,580.99 0.00 7,724.15 13,322.00 64.00 208.00 9,793.80 9,671.80 -4,792.32 -6,080.79 2,507,151.13 207,571.29 0.00 7,742.24 Total Depth:13322 MD,9793.W TVD Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) K-03RD2 WP05 Tgt 1 0.00 0.00 9,412.00 -4,101.15 -5,713.28 2,507,833.10 207,955.60 -plan hits target center -Circle(radius 50.00) 3/10/2017 11:25:33AM Page 6 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTONI Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:K-03-Slot Slot 32 Company: Hilcorp Alaska,LLC TVD Reference: K-03RD2 @ 122.00usft Project: McArthur River MD Reference: K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: Plan:K-03 Survey Calculation Method: Minimum Curvature Wellbore: K-03RD2 Design: K-03RD2 WP05 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C) C) 13,322.00 9,793.80 7 5/8" 7-5/8 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (1 12,329.71 9,358.81 H2 12,184.15 9,295.00 H1X 13,181.02 9,732.00 H7 13,005.26 9,654.95 H6 12,865.17 9,593.54 H5 12,228.04 9,314.24 Hemlock 12,730.49 9,534.50 H4 12,558.24 9,458.99 H3 11,523.13 8,868.00 COAL39 12,213.81 9,308.00 COAL59 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 9,600.00 7,109.57 -2,942.61 -4,905.10 Start Dir 12.29°/100':9600'MD,7109.57'TVD:60°LT TF 9,617.08 7,121.76 -2,947.34 -4,916.09 End Dir :9617.08'MD,7121.76'ND 9,637.08 7,135.90 -2,953.23 -4,928.95 Start Dir 5°/100':9637.08'MD,7135.9'TVD 10,317.51 7,722.50 -3,135.98 -5,197.37 End Dir :10317.51'MD,7722.5'ND 11,170.10 8,546.22 -3,329.51 -5,301.96 Start Dir 5°/100':11170.1'MD,8546.21'TVD 12,151.05 9,280.49 -3,863.07 -5,586.70 End Dir :12151.05'MD,9280.49'ND 13,322.00 9,793.80 -4,792.32 -6,080.79 Total Depth:13322'MD,9793.8'ND 3/10/2017 11:25:33AM Page 7 COMPASS 5000.1 Build 81 • • N d En' i ra) a 3 c 0) a C 4 t L I Q In a III NIB 0, C O c▪ o N d a N a d M N o c o a o N412 W O d• O M N O L T + a O ? d• No Z o r t 10 M , G V o o° m Y in J O .3 T .L N —J ds � amiii o � fn O 6 'D = a. s E d w `0 3 L M — Lu Zvi V/ • U C tp M N L Q. 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N CO U• C U dN ��� <N Lo CO W dt� cn ry� m �NmO� _ - - = _ G LL W05N _..Lu _ o I; 0 Pc � -_ _:. p OO m m VV ONNOO LLNNOO p CD NMO U 0 C r CO 0 - 0 0 N oO d -.-_—� _.._ o > c a- .-- o _ o . O M N O E• O N N 0 - , c Y d Y p p < N < m c CO M ��\ —Np _... -.-. O O c c0 0 0 I _ i _iai= Lc � O _ o OCD L -_g o 0 a_ z I , _ co o \\ w m O o v v el C o rn 2 P,..4 0)/ d to O Y y o U) CC p rn O O N 1 = N m • P p11 -, , O i 0 COO U ' 1o0L II III III IIIIII , III m ; Z J 0 S p Co Co op p p I ' l I I I 1 1 1 1 I ' ' l 1 IliIM JWil Q o O C o 0 0 o o L N _ W (o M D 7 M O N �(ui,usn 00'09) uoneaedas aaqua°of aa;uao aope,d uoReaedas RECEIVED ., . IVE STATE OF ALASKA ' ALL OIL AND GAS CONSERVATION COMMON MAR 0 6 2 0 17 PERMIT TO DRILL 20 AAC 25.005 AU..,, N. r la.Type of Work: lb.Proposed Well Class: Exploratory-Gas 0 Service- WAG ❑ Service-Disp ❑ 1 c.Specify if well is . oposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil 0 • Service- Winj ❑ Single Zone 0 • Coalbed Gas 0 Gas Hydrates ❑ Redrill 0 i Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Geothermal • Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 ' Single Well ❑ 11.Well Nam• and Number: Hilcorp Alaska,LLC Bond No. 022035244 • BU K-03RD2 ' 3.Address: ' 6.Proposed Depth: 12.Field mool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 13,322' ' TVD: 9,804'• McArthur River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Hemlock Oil Pool ' Surface: 729'FSL,130'FEL,Sec 17,T9N,R13W,SM,AK , ADL017594(SHL/TPH)ADL018777(BHL) Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1997'FSL,69'FWL,Sec 20,T9N,R13W,SM,AK N/A 5/1/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 946'FSL,530'FEL,Sec 19,T9N,R13W,SM,AK r ADL017594 5116 acres/ADL018777 1902 a es 4262'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 122' 15.Distance to Nearest Well Open Surface: x-213767 y- 2511793 Zone-4 ' GL Elevation above MSL(ft): N/A to Same Pool: 2550'to G-15RD 16.Deviated wells: Kickoff depth:900C) 3pt5 feet ; 17.Maximum Potential Pressures in •sig(see 20 AAC 25.035) Maximum Hole Angle: 68 degrees • Downhole: 4690 Surface: 2473 18.Casing Program: Specifications Top - Setting Depth Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade _ Coupling Length MD TVD D TVD (including stage data) 8-1/2" 7-5/8" 29.7# L-80 HYD 511 4522' 8,800' 6,52: 3,322' 9,804' 414 ft3 0� 4 19. PRESENT WELL CONDITION SUMMARY(To be complet=. for "-drill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): : t.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 13,413' 9,839' N/A `/ 13,300' 9,753' 12,634' Casing Length Size \ 'e Cement Volume MD TVD Conductor/Structural 394' 24" 394' 394' Surface 2,506' 13-3/8" 1560 sx 2,506' 2,346' Intermediate 10,983' 9-5/8" s 1000 sx 10,983' 8,059' Production _ Liner 2,735' 800 sx 13,395' 9,825' Perforation Depth MD(ft): 12,386'-13,164' , Perforation Depth TVD(ft): 9,069'-9,649' 20. Attachments: Property Plat Q BOP Sk:.era Drilling Program STime v.Depth Plot Q Shallow Hazard Analysis Diverter -r 0 Seabed Report Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representa, e: Date 22.I hereby certify that the foregoing is true and the pr• edure approved herein will not be deviated from without prior written approval. / Contact Monty Myers Email mmVerSehIICOrp.COm Printed Name Monty Myers Title Drilling Engineer Signature Phone 777-8431 Date 3. 0 4 . -20 1 7 '-----......_ Commission Use Only Permit to Drill API Number: ' Permit Approval See cover letter for other l l• —O�1 Ci ? 1 Oj"j requirements. Number: d. I 50- �3� oC.� ��o���� Date: q Conditions of approval: box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 1� Other: Samples req'd: Yes 2. No' Mud log req'd:Yes No d H2S measures: Yes No Directional svy req'd:Yes No❑ Spacing exception req'd: Yes El No L Inclination-only svy req'd:Yes ElNo[✓� Post initial injection MIT req'd:Yes Cl No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ?' 3/&17 t lit'�{/ Submit Form and Form 10-401(Revised 11/2015) QIRene tatoA Inths from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • Monty 411 Hilcorp Alaska, LLC Myers P.O. Box 244027 y Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Energy Company 3/6/2017 RECEIVED Commissioner BAR 6 2017 Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue AOG CC Anchorage, Alaska 99501 Re: K-03RD2 Dear Commissioner, Attached is the application for permit to drill K-03RD2. K-03RD2 is an oil production well planned to be re-drilled in a South-westerly direction from the existing K-03RD utilizing the existing casing program down to 9000' MD/6670' ND. At 9000' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 4322'x 8-1/2" open hole section is planned. A 7-5/8"29.7# L-80 HYD 511 prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 4-1/2" ESP completion. Drilling operations are expected to commence approximately May 15t, 2017. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 i 0 H Hilcorp Alaska, LLC K-03RD2 Drilling Program McArthur River ro d by: Mme`I M Revision 0 March 3, 2017 r • K-03RD2 Drilling Procedure Rev 0 II ileorp A laska.1.1.1 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 N/U 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 7-5/8"Production Liner 22 16.0 Cement 7-5/8"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 Drilling Hazards 35 25.0 Rig Layout 36 26.0 FIT Procedure 37 27.0 Choke Manifold Schematic 38 28.0 Fluid Flow Diagrams 39 29.0 Offset MW vs.Depth TVD 42 30.0 Casing Design Information 43 31.0 8-1/2"Hole Section MASP 44 32.0 Plot(NAD 27) (Governmental Sections) 45 33.0 Slot Diagram (As Built) (NAD 27) 46 34.0 Directional Program (wp03) 48 • K-03RD2 Drilling Procedure Rev 0 Ililcorp Alaska.TALC 1.0 Well Summary Well K-03RD2 Pad&Old Well Designation Sidetrack of existing well K-03RD(PTD#180-144) Planned Completion Type 7-5/8"29.7#L-80 Liner,4-1/2"Tubing w/ESP Target Reservoir(s) Hemlock Producer H1-H3 Planned Well TD,MD/TVD 13322' MD/9804' TVD PBTD,MD/TVD 13200' MD/9758' TVD Surface Location(Governmental) 729' FSL, 130' FEL, Sec 17, T9N,R13W, SM,AK Surface Location(NAD 27) X=213767.53,Y=2511793.13 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1997'FSL, 69'FWL, Sec 20, T9N,R13W, SM,AK TPH Location(NAD 27) X=208596.23,Y=2507917.43 TPH Location(NAD 83) BHL(Governmental) 946'FSL, 530'FEL, Sec 19, T9N,R13W, SM,AK BHL(NAD 27) X=207973.68,Y=2506882.19 BHL(NAD 83) AFE Number 1711118D AFE Drilling Days AFE Drilling Amount $5.1 MM Work String 4-1/2" 16.6# S-135 CDS-40 (From Saxon) RKB—AMSL 122' MSL to ML 73' BOP Equipment 13-5/8"5M Hydril"GK"Annular BOP 13-5/8" 5M Cameron Type U Double Ram 13-5/8" 5M Cameron Type U Single Ram Page 2 Revision 0 March,2017 K-03RD2 Drilling Procedure Rev 0 I h rp:Ua-ka. 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Emmy Company Changes to Approved Permit to Drill Date: March 1, 2017 Subject: Changes to Approved Permit to Drill for K-03RD2 File#: K-03RD2 Drilling Program Any modifications to K-03RD2 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 3.01.2017 Drilling Engineer Date Page 3 Revision 0 March,2017 • • K-03RD2 Drilling Procedure Rev 0 Ililrorp Ala:ku,LLC 3.0 Tubular Program Hole Section OD (in) Wt(#/ft) Coupl OD ID (in) Drift(in) Grade Conn Top Bottom 8-1/2" 7-5/8" 29.7 7.625 6.875 6.75 L-80 HYD 511 8800 13322 4.0 Drill Pipe Information Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) 8-1/2" 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 March, 2017 K-03RD2 Drilling Procedure Rev 0 Ililcorp.Alaska,Lu: 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. Leonard Dickerson: 0: (907) 777-8317 C: (907)252-7855 b. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: a. Keegan Fleming: 0:907-777-8347 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 March, 2017 • K-03RD2 Drilling Procedure Rev 0 IIilourp.ilu<ka. 6.0 Planned Wellbore Schematic McArthur River Field Well:TBU K-03RD2 PROPOSED API:01733 20074-XX Last Completed:Future CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. I 24" - - Surf JL 13.3/8" 61 K-55 Butt LT&C 12 515" Sur 2,506' 9-5/8„ 47 5-95 BTC(170 its) 8.681" Surf N-80 8rnd LTC 8.681" - ±9,000'TOW 7-5/8" 29.7 6.875" ±13,322' a: LINER DETAIL No Depth(MD) (TVD ID Item 1 ±6,528' 6.67" SDD Baker Liner Hanger 2 ±9,; ±6,670' - KOP 3 ±8800' x_9,804' 6.875" 7-5/8"29.7#L-801 CEMENT DETAIL No TOC Depth TOC Depth Volume Item (MD) (TVD) ±10,000' ±7,520' 74 bbls 15.3 ppg Class G cement w/1/4 bbl cemnet LCM • 4 4 v. R1r • Page 6 Revision 0 March, 2017 • S K-03RD2 Drilling Procedure Rev 0 llilcorp.Alaska,LLf. 7.0 Drilling Summary K-03RD2 is an oil production well planned to be re-drilled in a South-westerly direction from the existing K-03RD utilizing the existing casing program down to 9000' MD/6670' TVD. At 9000' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 4322' x 8-1/2"open hole section is planned. A 7-5/8"29.7#L-80 HYD 511 prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 4-1/2"ESP completion. Drilling operations are expected to commence approximately May 1st, 2017. 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 separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack and for running the completion assembly General sequence of operations pertaining to this approved drilling procedure: 1.1 Kuukpik 5 will be over slot 32(K-03RD)to decomplete and P&A well under separate sundry. 2. DP should be stood back in derrick 3. PU whipstock, and mills and TIH to CIBP 4. Orient whipstock and set at 45 deg right of highside. 5. Mill 8-1/2"window and 20' of new formation at 9000'. 6. POOH and LD mills. PU directional BHA and TIH to window. 7. Swap well to 9.0 ppg oil based drilling mud 8. Perform FIT to 12.5 ppg EMW 9. Drill 8-1/2" production hole from 9020' to 13322' MD,performing short trips as needed 10. Perform short trip and condition mud. POOH 11. LD Directional Tools. RIH w 7-5/8"liner. Set liner and cement. Circ wellbore clean. 12. POOH, laying down DP and liner running tools, 13. PU 7-5/8" casing scraper assembly and TIM to landing collar. 14. Circ casing clean. POOH laying down DP. 15. Run 4-1/2" completion. (Covered under separate sundry) 16. Land hanger and test. 17.ND BOPE,NU tree and test void Page 7 Revision 0 March, 2017 I K-03RD2 Drilling Procedure Rev 0 liloorp: Ia-La.I.IA: 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance 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 K-03RD2. 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 Hilcorp would like to request a variance to regulation 20 AAC 25.035(e)(4)(F)(i)which states - "the outlets must be at least two inches in nominal diameter, except that for rotary drilling rig operations, if the operation has a maximum potential surface pressure of greater than 3,000 psi, the nominal diameter of the choke outlets must be at least three inches". o The calculated MASP for this wellbore when completely evacuated to gas is 3236 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 2473 psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to 9.0 ppg reservoir fluid. o Hilcorp would like to request to have 2-1/16" outlets on the choke line and kill line due to this assumption Page 8 Revision 0 March,2017 • • K-03RD2 Drilling Procedure Rev 0 Ililcorp Alaska,1.11C Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 13-5/8"Shaffer 5M annular • 13-5/8"5M Shaffer SL Double gate Initial Test:250/3500 • Blind ram in bottom cavity (Annular 2500 psi) 8-1/2" • Mud cross • 13-5/8"5M Shaffer SL single gate Subsequent Tests: • 3-1/16"5M Choke Manifold 250/3500 • Standpipe,floor valves,etc (Annular 2500 psi) • Primary closing unit: Control Technology Accumulator, 3000psi, 5 station, 170 gallon reservoir, 4 nitrogen backups and 12 bladder bottles. • 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/TestWitnessNoti£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 March, 2017 • • K-03RD2 Drilling Procedure Rev 0 Ililcorp AIa.ka.LU: 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 mud for 8-1/2"hole section. 9.3 Verify 4.5" liners installed in mud pump #1 and 5.5" liners installed in pump#2. • Ellis Williams WH-1000 Pumps are rated at 3500 psi (100%) with 4.5" liners and can deliver 171 gpm at 86 spm. • TSM 1000 Pumps are rated at 3500 psi (100%) with 5.5" liners and can deliver 229 gpm at 86 spm. • Ideal pump rate for drilling will be 400 gpm. Both pumps running at 86 spm should achieve this. Pump#1 Ellis Williams WH100010" Stroke Pump#2 TSM 10009" Stroke 96% Efficiency Max psi 3500 psi 96% Efficiency Max psi 3500 psi Liner Size bbls/stroke Liner Size bbls/stroke 4.5 0.0472 5.5 0.0635 Strokes/minute bpm gpm Strokes/minute bpm gpm 20 0.94 40 20 1.27 53 40 1.89 79 40 2.54 107 60 2.83 119 60 3.81 160 86 4.06 171 86 5.46 229 100 4.72 198 100 6.35 267 120 5.67 238 120 7.62 320 140 6.61 278 150 7.08 297 Page 10 Revision 0 March, 2017 K-03RD2 Drilling Procedure Rev 0 IliI(orp AIa ca. 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 13-5/8"x 5M BOP as follows (top down): • 13-5/8"x 5M Shaffer annular BOP. • 13-5/8" Shaffer Type "SL" Double ram. (2-7/8" X 5"VBR in top cavity, blind ram in btm cavity) • 13-5/8"mud cross • 13-5/8" Shaffer Type "SL" 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 4-1/2"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> 7-5/8". Page 11 Revision 0 March,2017 M i K-03RD2 Drilling Procedure Rev 0 Ili!carp Alaska,Ill 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) 9,000—13,322' 9.0-9.5 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product Concentration 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 9.0 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 March,2017 • • K-03RD2 Drilling Procedure Rev 0 IliI(orp Ala.ka,I.IA: 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 (9000' 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 1500 psi / 30 min. Chart record casing test& keep track of the amount of fluid pumped. Stage up to 1500 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 March, 2017 • • K-03RD2 Drilling Procedure Rev 0 Ililcarp Alaska,LLC 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 %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 March, 2017 • • K-03RD2 Drilling Procedure Rev 0 Ilile orp:.la-1.t.I.1.1: En ���� Window Master G2 Whipstock BAKER With Torque Master Bottom Trip Anchor HUGHES ;� � 9.625 53.5#Non Special Drift Casing Baker Oil Tools • isi • Upper Watermelon Mill ■ OD: 8.500 8.500 —♦ I V 4— 6.25 Length: 6.25 )) Flex Joint OD: 6.375 III 1 • Length: (z Ho W 6.375 —0- ' 4— 9.00 Lower Watermelon Mill OD: 8.375 M Length: 5.66 • Window Mill 40.6 - OD: 8.500 8.250 —1. I 4- 5.66 Length: 1.13 l Whipstock OD: 8.000 8.500 _I, ,Q 4_ Length: 18.54 ��� I 1.13 Face Angle: 1.9 A J" Face Length: 17.08 I II Retrieval BTA OD: 8.357 17.08 Length: 3.41 18.54 1.9 Overall length —► Length: 41' WELL INFORMATION CUSTOMER ♦ FIELD —IP. =I 4— 8.000 LEASE ♦• • IN; WELL NO. SHEAR BOLT • I 25,000 3.41p 35,000 8.357 --to. : 45,000 I+ 55,000 1 II 65,000 ♦ 75,000 NOTE DIM ENSIONS AR BASED ON TECH DWI DATA.ACTUAL DIM ENS IONS MAY VARY Page 15 Revision 0 March, 2017 • • K-03RD2 Drilling Procedure Rev 0 Ilileorp Alaska,t.LC 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: 30 L HS 60 L HS Desired orientation of the Whipstock face is 45 degrees right of high side. Hole Angle at window interval (9000' MD) is 45 deg. The wellbore trajectory is planned to kick off at 255 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). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9.0 ppg 80/20 Enviromul MOBM. 13.7 Record P/U, 5/0 weights, and free rotation. Slack off to top of whipstock and with light weight 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. Page 16 Revision 0 March, 2017 • • K-03RD2 14Drilling Procedure Rev 0 Ililcorp Alaska,1.1.1: 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 Percent of Casing Removed (%)* 38 Milled Area(in"12) 5.908 Volume of Cuttings(in"3) 1134.272 Density of Casing(Ib./in"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.20' rat hole to accommodate the 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 —9.0) * 0.052 * 6670' tvd= 1214 psi 13.14 Kick Tolerance • (12.5-9.0) * (6670/9804) = 2.38 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 2.4 ppg kick tolerance while drilling the interval with a 9.0 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 March, 2017 • • K-03RD2 Drilling Procedure Rev 0 Ililcorp Ala.,ka.LU; 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 '/ REG-B 5.5 8.5 FLEX JOINT 4 '/ REG-P X 4 '/ REG-B 9.0 6.375 STRING MILL 4 '/ REG-P X 4 '/ REG-B 5.5 8.5 FLOAT SUB 4 '/" IF-B X 4 1/2" REG-B 3.0 6.375 30 jts-HWDP 4 1/"XH-B X 4 1/2" REG-P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY.! Page 18 Revision 0 March, 2017 H0 • K-03RD2 Drilling Procedure Rev 0 11 ilcorp,Alaska,1.1.1: 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2" directional 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 375-450gpm. 14.6 Motor AKO should be set at 1.2 deg. Must keep up with 5 deg/100 DLS in the build section of the wellbore. 14.7 Primary bit will be the Varel 8-1/2" VM613P PDC bit. Ensure to have a back up bit available on location. COMPONENT DATA ' Itemti w'y o;. -ri ,`- '. * Desert - ) (In) (In) {n) MO Cofftect on (it) o. 1 HDBS-PDC 8.400 2.500 8.500 172.13 P 4-112"REG 1.20 1.20 2 T SperryDrill Lobe 7/8-7.5 stg 7.000 4.952 95.69 B 4-1/2"IF 29.48 30.68 Stabilizer 8.375 3 Non Mag Float Sub 6.750 2.750 101.71 B 4-112"IF 3.00 33.68 4 Integral Blade 6.750 2.750 8.375 101.71 8 4-1/2"IF 3.60 3728 5 6 3'4"DM Collar 6.750 3.125 103.40 B 4-12"IF 9.20 46.48 6 6 3/4"DGR Collar / 6.750 1.920 97.80 8 4-1/2"IF 4.55 51.04 7 6 314"EWR-P4 Collar 1 6.750 2.000 104.30 8 4-1.2"IF 12.10 63.14 8 Inline Stabilizer(ILS) 6.750 t920 8.375 112.09 B 4-112"IF 3.20 66.34 9 6 314"PWD 6.750 1.905 96.30 B 4-1.2"IF 4.44 70.78 10 6 314"HCIM Collar 6.750 1.920 101.70 B 4.1/2'IF 4.97 75.74 11 6 34"TM-HOC(Puller) 6.900 3.250 103.60 B 4-112"IF 15.50 91.24 12 6-3/4"Non Mag Flex Drill Cohar 6.750 2.813 100.77 B 4-1/2"IF 30.00 121.24 13 6-3/4"Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-1/2"IF 30.00 151.24 14 6-3/4"Non Mag Flex Drill Collar 6.750 2.813 100.77 30.00 181.24 15 6 Joint 5"HW DP 5.000 3.000 49.30 180.00 361.24 16 6-1/4"Weatherford Hydraulic Jar 6.250 2.250 91.01 30.00 39124 17 14 Joints 5-HWDP 5.000 3.000 49.30 420.00 811.24 ri 811.24 Page 19 Revision 0 March,2017 • • K-03RD2 Drilling Procedure Rev 0 I lileorp ala..<ka.I,LI: 8 1/2" (215 9mm) • '0 Assembly:-„ A09148 VM613P IADC Code: M433: PRODUCT SPECIFICATIONS \ cCutter Size: 13 mm (� 1,..410. i �, Cutter Back Up: 13mm PDC&Replaceable Shock Studs Total Cutter Count: 76 0 Face Cutter Count: 58 i Connection: 4 1/2"API Regular e Nozzle 1 Qty/Type: 6-Series 55 Nozzle 2 Qty/Type: Junk Slot Area: 14.3in'(92.3cm2) Gage Pad Length: 2 1/2"(64mm) 11114 Make Up Length: 11.4"(288.8mm) Shank Diameter: 5.8"(147.3mm) OPERATING PARAMETERS' Rotary Speed: For all rotary and motor applications Flowrate Min-Max: 250-750GPM(0.95-2.84m3/min) Max Weight On Bit: 42000Ibs(18683daN) • 3 • • Makeup Torque: 12000-16000Ft-Lbs. (16270-21693Nm) ( ♦ 0 'G'}petatmg parameters shG*r r;are£ypaca:;.for the t,1 type spec b. ,:/1.11,„ I 1 # Fc€recommendations on your npe is appticatc'contact our I Varet Internal onai represe?°Ftaave• . Navigator Series Bits -Varel's six step design/manufacturing process utilizes GeoScience interpreted logs. proprietary design software SPOT.3D modeling programs.CFD,and specialized manufacturing techniques to produce the best possible bit for the application.Navigator bits are engineered to a specific Directional profile for a given application.Navigator bits possess the key design elements affecting bit steerability and directional behavior helping you achieve your drilling objectives. Bit Features P -Partial PowerCutters'"provide extra cutter density on the shoulder reducing excessive wear or cutting structure damage when drilling interbedded formations. Shock Studs -Shock studs limit drill bit vibration and increase stability allowing smooth cutting action increasing cutter life and overall bit performance. Updrill Cutters -PDC cutters strategically placed to help reduce hole problems when up drilling or back reaming. Premium Gage -The premium gage consists of thermally stable polycrystalline diamond and pdc(polycrystalline diamond compact)cutters:designed to insure that correct hole diameter is maintained. V A R EL www.varelinti.com Page 20 Revision 0 March,2017 • K-03RD2 14Drilling Procedure Rev 0 llilcorp Alaska,LLC 14.8 TIH to window. Shallow test MWD on trip in. 14.9 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. 14.10 Drill 8-1/2"hole to 13322' MD using motor 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 attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment 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 14.11 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.12 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. 14.13 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 March, 2017 • i K-03RD2 Drilling Procedure Rev 0 Hilcorp Alaska.11€ 15.0 Run 7-5/8" Production Liner 15.1 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8"HYD 511 x 4-1/2" CDS-40 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. • Rigid or Solid body centralizers will be pre-installed on shoe joint, FC joint, and LC joint. • NO centralizers will be installed on liner • Ensure proper operation of float shoe & FC. 15.4 Continue running 7-5/8"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. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8" HYD 511 M/U torques Casing OD Minimum Maximum Yield Torque 7-5/8" 5,900 ft-lbs 10,300 ft-lbs 52,000 ft-lbs Page 22 Revision 0 March, 2017 • • K-03RD2 Drilling Procedure Rev 0 Illileorp I I Tenarishydri Size: 7.625 in. Wall: 0.375 in. Weight: 29.70 lbs/ft Connection: Wedge 511TM Grade: [80.1 Casing/Tubing: CAS Min. Wall Thickness: 87.5 % PIPE BODY DATA GEOMETRY Standard Drift Nominal OD 7.625 in. Nominal Weight 29.70 lbs/ft 6.750 in. Diameter Special Drift Nominal ID 6.875 in. Wall Thickness 0.375 in. N/A Diameter Plain End Weight 29.06 lbs/ft PERFORMANCE Body Yield 683 x 1000 lbs Internal Yield 6890 psi SMYS 80000 psi Strength Collapse 4790 psi WEDGE 5 I 1"' CONNECTION DATA GEOMETRY Connection OD 7.625 in. Connection ID 6.787 in. Make-Up Loss 3.700 in. Critical Section 5.218 sq. in. Threads per in. 3.28 Area PERFORMANCE 417 x 1000 Internal Pressure Tension Efficiency 61.1 % Joint Yield Strength 6890 psi lbs Capacity Compression Compression 504 x 1000 lbs 73.8% Bending 29 0/100 ft Strength Efficiency External Pressure 4790 psi 0 Al Capacity t IMA(E-UP TORQUES Minimum 5900 ft-lbs Optimum 7100 ft-lbs Maximum (1) 10300 ft-lbs OPERATIONAL LIMIT TORQUES Operating Torque 35000 ft-lbs Yield Torque 52000 ft-lbs BLANKING DIMENSIONS Blanking Dimensions Page 23 Revision 0 March, 2017 • S K-03RD2 Drilling Procedure Rev 0 Ilikorp Alaska,LLC 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 March, 2017 int • K-03RD2 Drilling Procedure Rev 0 IIrkorp Alaska.1.1.1: 16.0 Cement 7-5/8" 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 MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Mix and pump 73.8 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl of Cemnet or equivalent 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 7-5/8" casing and 8-1/2" open hole. Est TOC 10000' TMD. 16.6 Displacement fluid will be drilling mud. —368 bbls of displacement fluid Cement Calculations 8-1/2"OH x 7-5/8"Liner: (13322' — 10000') x 0.01371 x 1. 5 = 68.3 bbls Shoe Track: 120' x 0.04591 = 5.5 bbls Total Volume(bbls): 68.3 + 5.5 = 73.8 bbls Total Volume(ft3): 73.8 bbls x 5.615 ft3/bbl= 414 ft3 Total Volume(sx): 414 ft3 / 1.34 ft3/sk= 309 sx Page 25 Revision 0 March, 2017 • • K-03RD2 Drilling Procedure Rev 0 Ililcorp Alaska.IAA: Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk 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 5.5 bbls. 16.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 March, 2017 40 ! K-03RD2 Drilling Procedure Rev 0 Ililcorp 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 March,2017 O K-03RD2 Drilling Procedure Rev 0 llilcorp Alaska,IAA: 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 mmvers(iiJiilcorp.com Page 28 Revision 0 March,2017 • K-03RD2 Drilling Procedure Rev 0 Ililcorp Alaska,1.1A: 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 7-5/8"29.7# casing • +/- 4550' 4-1/2" DP. • Casing scraper&brush for 9-5/8" 53.5# casing • (2000') 4-1/2" DP • Casing scraper&brush for 9-5/8" 53.5# casing • 4-1/2" DP to surface. 17.2 TIH & clean out well to landing collar(+/- 13,200' 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 7-5/8" landing collar when crossover is+/- 30' above the 7-5/8" liner top. 17.3 After wellbore has been cleaned out satisfactorily using mud, test casing to 1500 psi/30 min. Ensure to chart record casing test. 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 7-5/8"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. LDDP on the trip out. Page 29 Revision 0 March, 2017 • K-03RD2 Drilling Procedure Rev 0 llilrorp Alaska,LII 18.0 Run Completion Assembly 18.1 Run 4-1/2"tubing completion assembly as per separate Approved Completion Sundry 19.0 RD 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE,NU tree,test void 19.3 Rig Down Page 30 Revision 0 March, 2017 • K-03RD2 Drilling Procedure Rev 0 1lilcorp Alaska,1.I.I 20.0 BOP Schematic Rig Floor 16" Pipe Ill 111 111111111 ✓I! Itl ltl ill III 1111 111 1-11 3. 741. Shaffer 13 5/8 5M Iti_IIL1111.I1 lit Shaffer Sl ------ - 2 7/8-5.5 Variables 2.83' 13 5/8 51,1 • - Blind 7 1:16 5M manual valves and HCR valve �t f,jer,. I11 111111 Iil IVI r11 1.76 p1 h,I1 g ,j`411401 .a) 111111 ill - Sha er St 13 5 8 51.1 — 2 7/8.5.5 Variables 1.44' Ia] Ill lil I/1 lii Drill deck 13.70' Riser 135/8 SM FE 13 5/8 5M API hub J 3 Page 31 Revision 0 March, 2017 H • • K-03RD2 Drilling Procedure Rev 0 IliIcor!AIa_.ka,LLA: 21.0 Wellhead Schematic King Salmon Tbg hanger,OCT-WIC-LA- IC-031M ESP,13 X 4 Y,IBT lift and 24 X133/8X 95/8X 43S cusp,w/4"Type H BPV profile,3/8 cont control line port BHTA,Bowen,4 1/16 5M FE x 7"-5 Stub acme Bowen top T xxxxxxxxximi Valve,Swab,WKM-M,4 1/16 5M FE,HWO,EE trim t►• 1A Valve,Wing,SSV,WKM•M,31/8 SM I r -' FE,w/OMNI oper,EE trim Valve,Wing,WKM-M,2 1/16 SM NIIIIIIINIIII FE,HWO,DO trim ; ii [ (5) •} r 11111111111111111111 Valve,Master,WKM-M,4 1/16 5M Z1: FE.HWO,El trim �` 'I• t •'.�. Valve,Wing,WKM-5,3 1/8 SM FE, ar HWO,EE trim 04. 1 i. t Adapter,OCT-A5-ESP,13 5/8 5M API hub I!! im I L X 4 1/16 SM stdd top,w/2-X control I_ • ' I line exits,prepped w/OCT 400-4 pocket 0 .. 79Af iP �,!. t o 1 �I .. ".II i 71 II ► 4Ie ' All unihead annular valves,2 Unihead,OCT type 3,13 5/8 SM API ® g��+ , ? 1/16 SM FE OCT-20,HWO hub top X 13 3/8 BTC casing bottom, 1. err 1 , 1,I " w/1-2 1/16 SM SSO on lower �� • section,1.21/16 5M 550 on middle "mi i:t section,3.2 1/16 SM SSO on upper >r� s . section,IP internal lockpin assy ,I4 ,r• .III '44111 it ��.w Starting head,OCT,21 Valve,OCT-20,31/8 2M FE, X 2M FE X . HWO �� 1111110.1111 :x it . I• 24"SOW,w/1.3 1/8 2M EFO,full set of lockpins _ :3 3/S" -•q 5/8" 4 h" Page 32 Revision 0 March, 2017 • K-03RD2 Drilling Procedure Rev 0 Ilileorp Alaska.LIA 22.0 Days vs Depth Days Vs Depth 0 K-03RD2 2000 4000 .4. 6000 o. 3 8000 10000 \\NNNNNN\N 12000 14000 0 5 10 15 20 25 30 Days Page 33 Revision 0 March, 2017 I 0 II K-03RD2 Drilling Procedure Rev 0 llilcnrp Alaska,1.1.1': 23.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: KO3RD2 i Producer FIELD: MCARTHUR RIVER1 KO3RD2 SURFACE X: 213768 As-Built Survey .1,7-117-.F Alaska SURFACE Y: 2511793 BOTTOM HOLE X.' 207974 -,k.i r_ ,FUNI KB BOTTOM HOLEY: 2506882 -)i/ E.L 122 € COORD REF.SYSTEM NAD27 AK4 True North r`/ 0.0 PROPOSED TD: 13322 MD " 73.0 PROPOSED TD: 9805 i TVD Drill a sidetrack out of the K-03RD(King Salmon)to test and complete the Hemlock H-1 thru H-6 benches . Objective: Geo Summary/ Based on subsurface evaluation Justification: KO3RD2 TARGETS,ANTICIPATED FORMATION TOPS& GEOHAZARDS FLUID KOP 9000 6670 -6560 i 2910 8.4 0.44 COAL39 COAL 111544 8939 -8817 3911 8.4 0.44 MKR_13 COAL 11901 9212 -9090 3999 8.3 0.43 Hemlock Sand/Conglomerate Oil Sand 12132 9347 -9225 4059 8.4 0.43 H2 Sand/Conglomerate Oil Sand 12266 9408 -9286 4064 8.3 0.43 H3 Sand/Conglomerate Oil Sand 12526 9506 -9384 4077 8.2 0.43 H4 Sand/Conglomerate Oil Sand 12740 9586 -9464 3833 7.7 0.40 H5 Sand/Conglomerate Oil Sand 12879 9638 -9516 3875 7.7 0.40 H6 Sand/Conglomerate Oil Sand 13087 9716 -9594 3911 7.7 0.40 .. L,. vim,.,,, H7 Sand/Conglomerate Oil Sand 13322 9804 -9682 3933 7.7 0.40 =Primary Objective = Secondary Objectiw TARGET SIZE 50 FT DATA COLLECTION REQUIREMENTS: Mud Logging: 4 man Crew below KOP • / LWD Data: GR/RES LWD,Triple Combo MAD pass E-Line Log Data: Gyro run upon completion of the well to validate wellbore tortuosity and postion. COMPLETION TYPE ESP Completion ANTICIPATED RATES 8000 bpd gross fluid i ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 4-1/2" Page 34 Revision 0 March,2017 • K-03RD2 Drilling Procedure Rev 0 IIileorp Alaska,LLC 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 March, 2017 Ha . K-03RD2 Drilling Procedure Rev 0 Itikorp Alaska,1,IA. 25.0 Rig Layout o' -. 1 w 0 ,o T O N (a O N Q 1 c T I J fr t aStructureg m \ C "" �' 10.000 5� 0 0 o is o �r�-}}• N 'i '�� m I ■ O ■ ■ N O W fli 8r,� l.1 ...,.....„ a � I "Ti t M o $ # ,r i , '7 RFS , t 2 o , t ' • 1 4 I 'NI Elem. isO Li „�:,, ' ' rl i::Ia F -I 8 o_ DD it i009 01 EDg= o SO av r. 4aCo 0 0 o tv o I a 3 o to O gi l-- OOS'61I-� g1• �LL o ci NX' — 44 al icl ir •Tib j ,4.Ti� $ �, o �N INV .`4 • N L C O b. 0. 8. X.A.1 I 1 i c------ m r m W 000 0t: ----0."•- 000.0Z \\\\\\N,.,......,...............: g 000 OS .rte A p c 7 3 0 a Page 36 Revision 0 March, 2017 • K-03RD2 Drilling Procedure Rev 0 I I lrnrp;11aska,LI : 26.0 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 37 Revision 0 March,2017 H • K-03RD2 Drilling Procedure Rev 0 Ilileorp Alaska,LLC 27.0 Choke Manifold Schematic Choke Manifold Valves 2" To Shaker 3"Panic To Gasbuster 3 1/8"I L —a -{- `Ys© 2 1/16" I ' © 2 1/16" 21/16" (te). 21/16" rn� 31/41) \8"` I fN LO.0.11...0.0.1 f I / t 21/16" 21/16" Manual Choke Automatic Choke 2 1/16" Inlet Pressure Sensor 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED= 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16"5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold C•2 firr - ins no , i- itt 6* ;L.:*"*# ,,..,.'-, r. ft. Its _. L r or .: fix, � . ._ i. #16 #5 *2 ae *4 " Kuukpik Drilling Rig 5 Choke Manhold Page 38 Revision 0 March, 2017 • • HK-03RD2 Drilling Procedure Rev 0 IIilcorp Alaska,LI.0 28.0 Fluid Flow Diagrams n c. r T. r 0 W s • 1 I I i I 1 1 1 1 ¢I ��j�I 1 1 1 1 1 1 1 1 1 4 n UQ 11.11.11.1.11.11.11.11.114 i�i�i:iji:it!it!i:i: v' i%i%la lain'lei icliclic .v.i'^it i^l1[Tiv.1 1 i' . 1§i§igin i§l ilt t ivhivNiviai i • ;ninininininininin 11 1�I±Iq!,!.Is 11!q I L ! L ! L r L yy _ inin L O' ' 'O _ I :113 I"!II I ix ix 0 pp a p 0) y c 'AQ 0 WL1 • c' rfy1 o ul v P.; WD CD K N� 4=s .O DQ O 1 r 1 1 1 1 t 1 1 I. 0 Z ialJIPIN11i_wii+lr-101p COa 0 . •••f i i Li i ti i 1, Dd P1 IX DQ _, 1 .,,,,.,,,,,!....!..!,,,,.,„,!•,,,...! IV I l i�l�lil !*1441 O i litia�11PlP�i,'!.'1! h in!§1 1 1 i l 1 kC ? le iiv liIIr± , , R -, 0• I iC 10 in In 101 1ny'int N.co 1 i�IA 11 IA IA in 11 1A 1 O• .71 1 L 1 / i L 1 1 t nnnn•nnn!nn !E"!E.!S!S!S!S!e!l!S -.. i!i!a!al!a!3!a!3 CD• ct R. I. et 11111 N i i I "4; I I IM • 1.'r. i:w'1�1p1 tiiil«'.ioie I IV• N N I I I i l l i N• W A $ 1t i 1 1 1 1� >1 ® DG i ! ! igiri is 1• •! in• i1rii i+ A g2 ! I i� i`1`i 1- iY 1 1" ' ly 10 1 la !-I iCr ..is II;IS in i 1 13 10 ie.�S ri'''Irr.inlir I i 1a, it l�i Ir (I' a ® 'O a O >__ i i7i^ iti•i Iw y • i 1414 1!1:I 1! 0 CL i 1 1 17I'1 IC T t 1 t 1. !° G !n i i in 1 inig 1.1°is iii.iii. _ r. Page 39 Revision 0 March, 2017 HI • K-03RD2 Drilling Procedure Rev 0 IliIcorp Alaska,LLf. C C A X- E0 -O eT: 0 K w _. I i I i i i i i 1 -o Uw co I i i i i i i i i 1 A 0'w It./IN Ita Ita II./I'+lta l' Ita 1�1:^:i:.`°,i i:Si".I:7,l:ice Iezliiiy00y 00� 000+X+0 elici�lala iiii 14 Ilalalal$ilall . Inl° nl�tnlrQl�In l° , , O 14 1414!;••!4 14 1" 14 14 Inlet '1 1 I 11 1 t i$ia i° i°i° i°i°1°i° N X4:31 &-4 04 04 0 n cn0_ A 0) t7--t7--)•- s p% O W%p ar 70 I w% 5 n>% SAO %o 0 i I I i I i I i IS 1.!-!..1....1...1.-1,..1...1 1 0 N . i . .... ' oa% %v ��Id Ia IN!'Iu!r�!"1�! n l i i i l i i i i 1. 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I Iw Ua ira it 1 1 ! 1 1 I 1 .e.(V• W A i i I i i i i i i;i it ffi i i in i.Ili is A 0 i i2 it ir.i-i iF i i i mit ii i i e' 17 XI i ii1 iti€iai i �!� i i ! i+ n E. - O S E i 11:1-1 i,i"•! i N sR t�. i i"1,; is•i!! •i, i i 1 i5.i i i `�7 i i i I.I"i i" O nIiIi . $ S$! ;iA o am 2 a Page 40 Revision 0 March, 2017 I 0 H K-03RD2 Drilling Procedure Rev 0 Illilcorp Alaska.HA: C n e-. ..... 7i 77 la U .. ...-: E (....? _. = 111111111 % ..... 71 = 1.40,00i-1100,Vtie.i4i14iM (1."7., 111111111 r = If It tI , 11 6 -. i...i...i....i.•pi..iii.y.i.o...;,.. rr:i •0,0,0,0..0,0,0-0,0. 4 4 v= 41.t.lg,regli:Itli'8 ...' igigigigigigigigi8 • 1010101010i0i0/010 11 t 1 ittit I ioieioioioioip 7 —10--- I'i•••1'ili!il 1-.1 'irn i7 i7 rr _• aiati°i°i° i° °,'i° fr; V CT X-aCY) 4e6--si ?: Xxr Cr(4? re' C ..... ; ED' 17 * 1 -A a) E IIIIIIIII ,r a_ --,:e- .... — . . . . . . . . . ..r. iii i i i i 17, Mill"7 T -1-i 1>q 4 P-1 Pcli fixl N.) -- CO (0 ..... 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Page 41 Revision 0 March, 2017 • • tirK-03RD2 Drilling Procedure Rev 0 Ilil orp:Ua<ka. 29.0 Offset MW vs. Depth TVD MW vs TVD Offsets o A 18(1968) 1000 - — K-26RD K-10RD 2000 -- — —A-27RD2 3000 - 4000 — 5000 0 6000 7000 1111111111 8000 — --- 9000 — 10000 — 11000 8 9 10 11 12 13 14 15 Mud Weight(PPG) Page 42 Revision 0 March, 2017 • i K-03RD2 Drilling Procedure Rev 0 IliIrorp:\Ia•ka.I.1.1: 30.0 Casing Design Information Calculation & Casing Design Factors Cook Inlet Offshore DATE: 3/1/2017 WELL: K-03RD2 FIELD: McArthur River DESIGN BY: MontyMMyers Design Criteria: Hole Size Mud Density: Hole Size 8-1/2" i Mud Density:, 9.0 ppg Hole Size Mud Density:1 Drilling Mode MASP: 2473 psi (See attached MASP determination&calculation) Production Mode I I MASP: 4690 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 7-5/8" Top(MD) 8,800 Top(TVD) 6,528 Bottom (MD) 13,322 Bottom (TVD) 9,804 mm Length 4,522 Weight (ppf) 29.7 Grade L-80 Connection HYD 511 Weight w/o Bouyancy Factor(lbs) 134,303 Tension at Top of Section(lbs) 134,303 Min strength Tension(1000 lbs) 254 Worst Case Safety Factor(Tension) 1.89 Collapse Pressure at bottom (Psi) 4,216 Collapse Resistance w/o tension (Psi) 4,790 Worst Case Safety Factor(Collapse) 1.14 MASP (psi) 2,473 Minimum Yield (psi) 6,890 Worst case safety factor(Burst) 2.79 Page 43 Revision 0 March, 2017 H410 0 K-03RD2 Drilling Procedure Rev 0 II ilrnr1•:11a.ka.LLA 31.0 8-1/2" Hole Section MASP ElMaximum Anticipated Surface Pressure Calculation Flilcorp 8-1/2"Hole Section ,_.„,....M,,, K-03RD2 Cook Inlet,Alaska MD TVD Planned Top: 9000 6670 Planned TD: 13322 9804 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad KOP 6,670 2910 COAL 8.4 0.44 COAL39 8,939 3911 COAL _ 8.4 0.44 MKR_13 9,212 3999 Sand/Conglomerate 8.3 0.43 Hemlock 9,347 4059 Sand/Conglomerate_ 8.4 0.43 H2 9,408 4064 Sand/Conglomerate 8.3 0.43 H3 9,506 4077 Sand/Conglomerate 8.2 0.43 H4 9,586 3833 Sand/Conglomerate 7.7 0.40 H5 9,638 3875 Sand/Conglomerate 7.7 0.40 H6 9,716 3911 Sand/Conglomerate 7.7 0.40 H7 9,804 3933 Oil Sand _ 7.7 0.40 TD 9,804 3933 Oil Sand 7.7 0.40 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date A-27RD2 9.3-9.5 7,755 9,718 2016 A-27 8.9-9.8 3,360 7,017 1973 A-27RD 9.5-9.7 6,328 9,950 1997 K-26RD 9.4-10.2 7,800 9,971 1995 Assumptions: 1. Anticipated fracture gradient at 9000'TMD(6670'TVD)=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: 6670(ft)x 0.7(psi/ft)= 4669 4669(psi)-[0.1(psi/ft)*6670(ft)]= 4002 psi MASP from pore pressure;normal gradient at TD,(0.43 psi/ft) 9804(ft)x 0.43(psi/ft)= 4216 psi 4216(psi)-(0.1(psi/ft)*9804(ft))= 3236 psi MASP from pore pressure;unknown gas sand at TD,at 9.2 ppg(0.4784 psi/ft) 9804(ft)x 0.4784(psi/ft)= 4690 psi Downhole 4690(psi)-[(2/3)*0.1(psi/ft)*9804(ft)]+[(1/3)*o.4784(psi/ft)*9804(ft)]= 2473 psi Drilling MASP Summary: 1. MASP while drilling 8-1/2"hole is governed by pore pressure minus 2/3 of wellbore evacuated to gas(remaining 1/3 remains 9.2 ppg drilling fluid) Page 44 Revision 0 March,2017 HK-03RD2 Drilling Procedure Rev 0 Ililrorp Alaska.1,1.1: 32.0 Plot (NAD 27) (Governmental Sections) ..._ .44K-22BHL-_______________.. , ......... \ a, \ Legend I '%, •\\ K-03RD2_SHL `• \\ K-03RD2_TPH S009N013W -.`.. \ S009N013W -1 K-03RD2_BHL @2a CIV �`� @ \% Other Surface Hole Location „`.� `\ ..' • Other Bottom Hole Location .K-12 BHL K-03RD2_SRL . \ ' _ -- Well Paths —r;'_��__ _ __ g`s Oil and Gas Unit Boundary ``- - -~�� __ ;; -- .,:... Iiiiii,,_-- s. K-18RDP8?D-HL.- �'�` ..� --- •-' . / \ t5-tBRD BHL ��'/' ami/�' \� �‘ F �,/�y / - , ,J� // h • \ -----ADL018777: _ - - ' ' ,'�.''�° '; \`\ r-- - /'/ - '---- *, ,'/ 1% K-01Pt36HL___ -- -.2' , ---' %i,_no?'t' d�"'_ ///, 1; / ANF17--03 BHL- -- oodoo - / / 1 TRADING BAY UNIT - ADL017594,' p - SBHL /N BHL 11 S009N013W- S009N013W ----- , S009N013W ,'- aaa L� , K�ROBHL ,,- Imo.- K-IORD2 TP11 ,// 11 r ,' .' 11 o 11 . o - It • 0 - 0 I 1 - o t ,' o ' t K�8BHL o -- -' t 1 10K-68452 QHL -' A 1 ——————— 'K-i)RD2 13ttL 1\ K-04RO fil I \ G-19 BHL K-04 B.L \ t \\G-29 BHL ••8RD BHL TRADING BAY G-33 BHL • • • `\S009N013W SOO9N 113W f SOI9N113WADL08 730C1 &) \� t.;\♦ 1 \ G-05RO BHL / - - G-13BHL \ \ \ \ -. -- • 0 1,000 2.000 ini Trading Bay Unit Fet Alaska State Peane Zone 4,NAD27A K-03RD2 Ilik arp Alaska.IAA: Map Date:3/1/2017 Page 45 Revision 0 March, 2017 I K-03RD2 Drilling Procedure Rev 0 IIill.urp alu-ka.HA: 33.0 Slot Diagram (As Built) (NAD 27) CENTER LEG 4 LAT:60"51'55.88061N LON:151'36'21.1490'W CENTER LEG 1 N:2511794.345' LAT:60'51'19.9419'N E:213781.851' LON:151°36'19.8893"W ASP ZONE 4 NAD 27 N-2511756.503' 01..1. .2 E:213820.519' K02 ASP ZONE 4 NAD 27 K K-n,. T`,� „ 180'FEL K-1v:o: .ftp 19 KING SALMON PLATFORM 02) 14-22830 11.1 ASBUILT WELL LOCATIONS , 120'FEL SECTION 16,T9N, R13W.S.M.,AK 160 K 21N0 / NO WELL SLOTS IRIS 1L CENTER LEG 3 LAT:60°51'551292'N 227'FEL LON:151°36'22.1035'W N:2511719224' E 213712.532' ASP ZONE 4 NAD 27 K-K.117R0 ' ' K •6gib S 187'FEL K-6 W 1960 CENTER LEG 2 LAT:60'51'54.7696'N LON:151.36'20.9005'W N:2511681260' w 726'FSL(N .) E:213771.191' Z ASP ZONE 4 NAD 27 IZ 650'FS1(NTS) 0 690'FSL(NTS) 0 LU 6 .1'FSL!NTSi (!) 0 W I- 0 Q C' I- 0 D: SECTION CORNER 0_ (PROTRACTED) N 2511063.548' E,213922.792' PROTRACTED SECTION LINE NOT TO SCALE(NTS) se u, 21 22 NOTES 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION `'N��1111 (EPOCH 2010)AND VERTICAL CONTROL(NAVD88)IS AN OPUS =� OFA I it SOLUTION FROM NGS STATIONS KENS,AC51 AND AC23 TO P'C�-•""..../ 111 ESTABLISH POINT#300. THE ALASKA STATE PLANE COORDINATES =y�:' 7 '', NAD 83 ZONE 4 IN FEET ARE: N=2511443.373 -*•' E=1353731.256 ELEV.=99.189(NAVD88) i .• s:<;+.v.0.;,: .. 2.SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED SCALE 11 •'•s/2oM:-' VALUES. •• 3. DATUM TRANSFORMATIONS(NAD83 ASPZ4 TO NAD27 ASPZ4) f,a I 1.-.6 11111 L t""`,,7' WERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1, i It FEET P'''''HILCORP ALASKA,LLC RevlsaN - ‘troa+Mc he= KING SALMON PLATFORM WELLS W1E- 624414 COOK INLET ALASKA DRAWN BY e AS BUILT SURFACE LOCATION SCALE ' 414V£C1 460. 147863 6r ENOEERIN01 MAPPING/SURVEYING r1E147040 NAD 27 6•...,1,NO 14.06 PG.sax 468 SOLOOTNA 648 90693 vdCE 190/1263442/6 FAL:480E/261-1,, "'CAI"' PROTRACTED SEC. 16 TO9N R13W z EET LS1u6aANEo*uA CG<.� u 1v tiilorp Alaska,LLC 1 W' c"2 SEWARD MERIDIAN,ALASKA Page 46 Revision 0 March, 2017 • K-03RD2 Drilling Procedure Rev 0 IIiirorp:%Iaska.I.1,/: NAD 27 Slot# Well# Northing Easting Latitude Longitude Center Leg 1 2511756.503 213820.519 60'51'55.52222" -151°36'19.94191" 1 K-21RD 2511751.133 213822.994 60°51'55.46995" -151°36'19.88928" 2 K-30 2511750.754 213819.220 60°51'55.46531" -151°36'19.96528" 3 K-18RD 2511753.106 213815.860 60°51'55.48766" -151°36'20.03428" Leg 1 4 K-17 2511757.623 213814.976 60°51'55.53191" -151°36'20.05437" 5 K-23 2511761.085 213816.638 60°51'55.56639" -151°36'20.02253" 6 K-19 2511761.888 213820.828 60°51'55.57531" -151°36'19.93833" 7 K-22RD 2511759.441 213825.218 60°51'55.55228" -151°36'19.84850" 8 K-20 2511754.730 213825.531 60°51'55.50598" -151°36'19.83984" Center Leg 2 2511681.260 213771.191 60°51'54.76960" -151°36'20.90053" 9 K-15RD 2511676.516 213774.559 60'51'54.72372" -151°36'20.83019" 10 K-9 2511675.411 213770.205 60°51'54.71178" -151°36'20.91754" 11 K-4RD 2511678.297 213765.971 60'51'54.73918" -151°36'21.00445" Leg 2 12 K-11 2511682.498 213765.183 60'51'54.78034" -151°36'21.02242" 13 K-13RD2 2511685.931 213767.848 60°51'54.81478" -151°36'20.97031" 14 K-2RD 2511686.644 213772.096 60°51'54.82282" -151°36'20.88491" 15 K-7RD 2511684.476 213775.691 60°51'54.80235" -151°36'20.81128" 16 K-5 2511680.120 213776.722 60°51'54.75972" -151°36'20.78831" Leg 3 Center Leg 3 2511719.224 213712.532 60'51'55.12919" -151°36'22.10347" Center Leg 4 2511794.345 213761.651 60°51'55.88057" -151°36'21.14901" 25 K-26RD 2511789.752 213764.548 60°51'55.83605" -151'36'21.08827" 26 K-1RD2 2511788.570 213760.661 60'51'55.82347" -151°36'21.16616" 27 K-10RD 2511791.323 213757.250 60°51'55.84976" -151°36'21.23636" Leg 4 28 . K-25 2511795.528 213756.002 60°51'55.89085" -151°36'21.26364" 29 K-12RD2 2511799.318 213758.343 60'51'55.92872" -151°36'21.21826" 30 K-6RD 2511799.443 213762.467 60°51'55.93095" -151°36'21.13506" 31 K-24RD2 2511797.672 213766.437 60°51'55.91447" -151°36'21.05403" 32 K-3RD 2511793.127 213767.529 60°51'55.86999" -151°36'21.02976" Pacw cT HILCORP ALASKA,LLC REVIsaN KING SALMON PLATFORM WELLS EaEE COOK INLET ALASKA DRAWN E, AS BUILT SURFACE LOCATION SCALE NA PROJECT NO 1a . ENGINEERING'MOPING SURVEYING TE NAD 27 BOOK NO 14Gt ,pct°190717A1t OCAK 7; ` CA"C6 PROTRACTED SEC. 16 TO9N R13W SI.FE' EJB SA"Q-.4.F(EAK,t/�AECGCOII Ilii&orp Aln�ku,I.i.(: 2 SEWARD MERIDIAN,ALASKA Page 47 Revision 0 March,2017 • K-03RD2 Drilling Procedure Rev 0 Ililcorp,tIaska, 1,1.1: 34.0 Directional Program (wp03) Page 48 Revision 0 March, 2017 • Hilcorp Energy Company Trading Bay King Salmon K-03 K-03RD2 Plan: K-03RD2 wp03 Standard Proposal Report 15 November, 2016 HALLIBURTON Sperry Drilling Services HALLIBURTON Hilcorp Energy Company HD REFERENCE INFORMATION Hilcorp Calculation Method:Minimum Curvature Co-ordinate(N/E)Reference:Well K-03-Slot Slot 32,True North Sperry Drilling Error System:ISCWSA Vertical(TVD)Reference: K-03RD2 @ 122.00usft Scan Method: Closest Approach 3D Measured Depth Reference: K-03RD2©122.00usft Error Surface: Elliptical Conic Warning Method: Error Ratio Calculation Method: Minimum Curvature Project: Trading Bay - Site: King Salmon SECTION DETAILS Well: K-03 Sec MD Inc Azi TVD +NI-S +E/-W Dleg TFace VSect Target Wellbore: K-03RD2 1 9000.00 45.00 257.78 6669.54 -2815.50 -4518.84 0.00 0.00 5247.09 Design: K-03RD2 wp03 2 9017.08 46.05 255.23 6681.51 -2818.35 -4530.69 12.29 -60.00 5257.83 3 9037.08 46.05 255.23 6695.39 -2822.02 -4544.61 0.00 0.00 5270.67 4 9876.42 22.64 187.05 7406.05 -3070.56 -4871.34 5.00 -147.70 5679.95 5 11350.22 22.64 187.05 8766.29 -3633.56 -4940.94 0.00 0.00 6106.37 6 12302.11 68.00 210.00 9422.00 -4232.37 -5199.08 5.00 29.32 6697.39 K-03RD2 wp2 Tgt1 DDI = 6.411 7 13322.00 68.00 210.00 9804.06 -5051.31 -5671.89 0.00 0.00 7595.13 CASING DETAILS WELL DETAILS: K-03 Water Depth: 73.00 TVD TVDSS MD Size +N/-S +E/-W Northing Easting Latittude Longitude 6669.55 6547.55 9000.01 9 5/8"47#TOW 0.00 0.00 2511793.12 213767.53 60°51'55.870 N 151°36'21.030 W 9804.06 9682.06 13322.00 7"x 8 1/2" SURVEY PROGRAM Date:2016-11-03T00:00:00 Validated:Yes Version: Depth From Depth To Survey/Plan Tool 122.00 2522.00 CB-Gyro-MS CB-Gyro-MS 2622.00 9000.00 K-03RD CB-Gyro-MS 6175 9000.00 9300.00 K-03RD2 wp03 MWD_Interp Azi X00 9300.00 13322.00 K-03RD2 wp03 MWD+SC+sag KOP:Start Dir 12.29°/100':9000'MD,6669.54'TVD:60°LT TF FORMATION TOP DETAILS - TVDPath TVDssPath MDPath Formation 6500- -- 8939.00 8817.00 11544.23 COAL39 - 00 """End Dir :9017.08'MD,6681.51'TVD 9212.00 9090.00 11901.44 MKR 13 - ,ta 9347.00 9225.00 12131.86 Hemlock - ---Start Dir 5°/100':9037.08'MD,6695.39'TVD 9408.00 9286.00 12266.10 H2 95 .00 9464.00 12739.90 H4 6825_ 9 5/8"47#TOW 9638.00 95116.00 12878.71 H5 _ 0 End Dir :9876.42'MD,7406.05'TVD 9716.00 9594.00 13086.93 H6 9804.00 9682.00 13321.84 H7 05r7150- _ O0 - ,^00 7475- X00't - 00 0 7800- c 105p0 000 NN 0 - LC) 8125 - L - Q yo a)❑ 11 000 8450- o Start Dir 5°/100':11350.22'MD,8766.29'TVD > _--- \ X000 8775- 0 N I. \\ - End Dir :12302.11'MD,9422'TVD 0 COAL3• 00 9100- '%°- 00 <1' - ,.0 _ MKR_13 ,moo) 0 9425-- N\ c:,HemlocM H2 000 'goo H 3 Nry 9750_- / H4 H5 Hs y�03RD2 wp03 ^0b^0 _ ,\�500 K-03RD2 wp2 Tgt1 H7 � K-03RD - 7"x 8 1/2" 10075_ NN Total Total Depth:13322'MD,9804.06'TVD - - K-03 10400- - 4875 5200 5525 5850 6175 6500 6825 7150 7475 7800 8125 8450 8775 9100 9425 Vertical Section at 228.31°(650 usft/in) • • Project: Trading Bay COMPANY DETAILS:Hilco p Energy Company WELL DETAILS:K-03 MAL.LIBIJRTON Site: KingSalmon Calculation Method:Minimum Curvature Water Depth: 73.00 1�(01�) Error System:ISCWSA +N/-S +E/-W Northing F shag Latitude Longitude eace.a y oextl.tp - Well: K-03 Scan Method:Closest Approach 30 0.00 0.00 2511793.12 213767.53 60.51'55.870N 151°30 21 030 W Wellbore: K-03RD2 Error Surface:Elliptical Conic 2a75— Plan: K-03RD2 wp03 Warning Method:Error Ratio 8 - 4 i -2700-- 95/8"47#TOW a `8 j 9 S g o -2925— c q b ,.4 o , , � rP s ,A, S s �� )?J6 -3150— c 7500 , d,^ i4'<" _ 7750 t ...'%. $$ ✓S. 8000 $? 4d -3375— 6 0 4 "q 8250 `,;y, '�, � �� _ 'E 8500 90 .2.Q. -3600— .e '. _7j2 _ `Sr 8750 `a :), S 8 0 9000 v-3825— - Start Dir 5°/100:11350.22'MD,8766.29TVD + - 9 b O - AQ 9jJ0 REFERENCE INFORMATION 4050_ K-03RD2 wp2 Tgtl Co-ordinate(WE)Reference:Wel K-03-Slot Slot 32,True North — Ve0cal(TVA)Reference:K-03R02 @ 122.00usn G - °S� Measured C kulaoonth e Method:Minimum SR Curvature `_ -4275— - - SURVEY PROGRAM - End Dir:12302.11'MD,9422'TVD 9 Date:2016-11-03700:00:00 Validated:Yes Version: - J� -0500— Depth From Depth To Survey/Plan Tool 122.00 2522.00 K-03 PB1 CB-Gyro-MS - 2622.00 9000.00 K-03RD CB-Gyro-MS - 9000.00 9300.00 K-03RD2 wp03 MWDInterp Azi 9300.00 13322.00 K-03RD2 wp03 MWD_+SC+sag -4725- - CASING DETAILS 4:040).? TVD TVDSS MD Size Name 6669.55 6547.55 9000.01 9-5/8 9 5/8"478 TOW 4950— �'W 9220 9804.06 9682.06 13322.00 7 7"x 8 1!T 7"x812"\\ - _ - Total Depth:13322'MD,9804.00TVD -5175— -5400— -Illliiiiiiiliiiiiillllllllliiiirliiiiiillliiiiiiiiiiillliiiiiiillliilllliiiiiiiiiillllliiiilll 6525 -6300 -6075 -5850 -5625 -5400 -5175 4950 4725 4500 4275 4050 -3825 -3600 -3375 -3150 -2925 -2700 -2475 West(-)/East(+)(450 usft/in) 0 411 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA ELocal Co-ordinate Reference: Well K-03-Slot Slot 32 Company: Hilcorp Energy Company TVD Reference: K-03RD2 @ 122.00usft Project: ' Trading Bay MD Reference: ,--f--,,,4-. K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: _ " K-03 Survey Calculation Method: Minimum Curvature Wellbore 7i. K-03RD2t ` ""`"` Design: K-03RD2 wp03 Project -'> Trading Bay 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 iSite` t) .= King Salmon _44.4444..4,4444,4 Site Position: Northing: 2,511,786.28 usft Latitude: 60°51'55.800 N From: Map Easting: 213,756.95usft Longitude: 151°36'21.240 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.40 ° Well K-03-Slot Slot 32 Well Position +N/-S 0.00 usft Northing: 2,511,793.12 usft Latitude: 60°51'55.870 N +EI-W 0.00 usft Easting: 213,767.53 usft Longitude: 151°36'21.030 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Water Depth: 73.00 usft 1<,03RD2 .Aw - ,:;. .a ...,ra:;xrrrxr?,rsz. tt ae: €.s..e:a x.:z; , z :.r:: x..,s..? a.z-.;__.., ,€€,3.., zxr„„e.:s .a� a°^ ,^'r re : j Sample Date •e • ,fr Field Strength ; (nT) BGGM2016 11/3/2016 16.25 73.76 55,453 Design K 03RD2 w.03 .a Audit Notes: Version: Phase: PLAN Tie On Depth: 9,000.00 Vertical Section: Depth From(TVD) ,'+Nl-S . +El-W Direction i . (usft) .1 (usft) (usft) a: . (°) 0.00 0.00 0.00 228.31 Plan Sections F y Measured Vertical TVD :"Dogleg Build : Turn Depth Inclination Azimuth Depth System +N/-S ,_i = +E!-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) .%)°":"4,:, (usft) (°/100usft) i (°/100usft) (°/100usft) e) 9,000.00 45.00 257.78 6,669.54 6,547.54 -2,815.50 -4,518.84 0.00 0.00 0.00 0.00 9,017.08 46.05 255.23 6,681.51 6,559.51 -2,818.35 -4,530.69 12.29 6.15 -14.78 -60.00 9,037.08 46.05 255.23 6,695.39 6,573.39 -2,822.02 -4,544.61 0.00 0.00 0.00 0.00 9,876.42 22.64 187.05 7,406.05 7,284.05 -3,070.56 -4,871.34 5.00 -2.79 -8.12 -147.70 11,350.22 22.64 187.05 8,766.29 8,644.29 -3,633.56 -4,940.94 0.00 0.00 0.00 0.00 12,302.11 68.00 210.00 9,422.00 9,300.00 -4,232.37 -5,199.08 5.00 4.77 2.41 29.32 13,322.00 68.00 210.00 9,804.06 9,682.06 -5,051.31 -5,671.89 0.00 0.00 0.00 0.00 11/15/2016 12:53:25PM Page 2 COMPASS 5000.1 Build 81 • 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: rs Well K-03-Slot Slot 32 Company: Hilcorp Energy Company FT VD Reference: K-03RD2 @ 122.00usft Project: Trading Bay 1.MD Reference: ;" 3 , ' " K-03RD2 @ 122.00usft Site: King Salmon North Reference: "I True Well K-03 Survey Calculation Method: Minimum Curvature Wellbore K-03RD2 ` : „ill*, Design: K 03RD2 wp03 ' `i mom".._.,Fi.,t.,,.u:_a a;iP ....�,u LIALI.s'MMILA;'ML ,. `,INIL r..EP..>... Rat . .; ..1,,,n' _,.. -::,...' :, ...L.......m..,..': Planned Survey ,F `PI •J Measured . . Vertical . Map Map Depth Inclination Azimuth Depth TVDss -. 44' Northing Easting r ftft ` e p (usft) (0) (°) (usft) usft / an (us ) _ (us ) ..; ,,, s „. 0.00 0.00 0.00 0.00 -122.00 0.00 0.00 2,511,793.12 213,767.53 0.00 0.00 100.00 0.00 0.00 100.00 -22.00 0.00 0.00 2,511,793.12 213,767.53 0.00 0.00 200.00 0.00 0.00 200.00 78.00 0.00 0.00 2,511,793.12 213,767.53 0.00 0.00 300.00 0.58 143.00 300.00 178.00 -0.32 0.24 2,511,792.80 213,767.76 0.58 0.03 400.00 0.93 123.12 399.99 277.99 -1.28 1.23 2,511,791.82 213,768.73 0.43 -0.07 500.00 1.77 105.84 499.96 377.96 -2.13 3.31 2,511,790.91 213,770.79 0.92 -1.05 600.00 2.16 125.68 599.90 477.90 -3.50 6.52 2,511,789.47 213,773.96 0.77 -2.54 700.00 2.03 116.54 699.83 577.83 -5.65 9.58 2,511,787.24 213,776.97 0.36 -3.40 800.00 2.47 150.64 799.76 677.76 -7.94 12.37 2,511,784.88 213,779.70 1.39 -3.96 900.00 4.01 189.79 899.61 777.61 -13.27 13.04 2,511,779.54 213,780.24 2.61 -0.91 1,000.00 7.18 211.42 999.14 877.14 -21.98 9.35 2,511,770.92 213,776.34 3.76 7.64 1,100.00 11.11 219.89 1,097.86 975.86 -34.69 -0.08 2,511,758.45 213,766.60 4.14 23.13 1,200.00 13.75 220.19 1,195.45 1,073.45 -51.25 -14.25 2,511,742.24 213,752.03 2.65 44.72 1,300.00 16.01 220.00 1,292.09 1,170.09 -70.91 -30.76 2,511,722.99 213,735.04 2.25 70.13 1,400.00 18.25 220.80 1,387.65 1,265.65 -93.36 -49.82 2,511,701.01 213,715.44 2.26 99.30 1,500.00 20.50 220.20 1,481.97 1,359.97 -118.53 -71.44 2,511,676.37 213,693.21 2.26 132.18 1,600.00 23.14 221.60 1,574.83 1,452.83 -146.67 -95.62 2,511,648.84 213,668.35 2.69 168.95 1,700.00 25.51 222.00 1,665.91 1,543.91 -177.35 -123.20 2,511,618.84 213,640.02 2.37 209.95 1,800.00 27.75 222.79 1,755.30 1,633.30 -210.49 -153.38 2,511,586.45 213,609.04 2.28 254.53 1,900.00 30.39 223.79 1,842.73 1,720.73 -245.80 -186.66 2,511,551.97 213,574.91 2.68 302.87 2,000.00 32.76 224.00 1,927.88 1,805.88 -283.52 -223.06 2,511,515.15 213,537.60 2.36 355.14 2,100.00 33.64 224.00 2,011.41 1,889.41 -323.07 -261.25 2,511,476.55 213,498.45 0.88 409.95 2,200.00 33.56 224.00 2,094.64 1,972.64 -362.94 -299.75 2,511,437.63 213,458.99 0.08 465.23 2,300.00 33.50 224.00 2,178.03 2,056.03 -402.65 -338.10 2,511,398.87 213,419.68 0.06 520.27 2,400.00 33.69 224.00 2,261.34 2,139.34 -442.43 -376.51 2,511,360.04 213,380.30 0.19 575.42 2,500.00 33.16 224.00 2,344.71 2,222.71 -482.15 -414.87 2,511,321.27 213,340.98 0.53 630.48 2,600.00 33.78 224.78 2,428.27 2,306.27 -521.46 -453.24 2,511,282.92 213,301.66 0.75 685.28 2,700.00 36.53 227.38 2,510.22 2,388.22 -561.29 -494.41 2,511,244.10 213,259.53 3.13 742.52 2,800.00 40.18 228.00 2,588.67 2,466.67 -602.82 -540.43 2,511,203.71 213,212.51 3.67 804.50 2,900.00 44.12 228.00 2,662.82 2,540.82 -647.70 -590.26 2,511,160.07 213,161.59 3.94 871.56 3,000.00 48.12 228.00 2,732.12 2,610.12 -695.92 -643.82 2,511,113.18 213,106.87 4.00 943.62 3,100.00 51.53 228.79 2,796.54 2,674.54 -746.77 -700.93 2,511,063.73 213,048.53 3.47 1,020.09 3,200.00 52.83 227.44 2,857.56 2,735.56 -799.41 -760.13 2,511,012.56 212,988.05 1.68 1,099.32 3,300.00 52.61 227.00 2,917.98 2,795.98 -853.70 -818.46 2,510,959.71 212,928.42 0.41 1,178.98 3,400.00 52.69 227.78 2,978.73 2,856.73 -907.56 -876.83 2,510,907.30 212,868.74 0.63 1,258.40 3,500.00 52.94 228.00 3,039.16 2,917.16 -960.90 -936.02 2,510,855.43 212,808.27 0.31 1,338.07 3,600.00 53.59 228.00 3,099.03 2,977.03 -1,014.49 -995.54 2,510,803.31 212,747.45 0.64 1,418.16 3,700.00 54.53 227.22 3,157.76 3,035.76 -1,068.97 -1,055.40 2,510,750.31 212,686.28 1.14 1,499.09 3,800.00 54.94 227.78 3,215.40 3,093.40 -1,124.36 -1,115.48 2,510,696.41 212,624.86 0.62 1,580.80 3,900.00 55.00 228.00 3,272.77 3,150.77 -1,179.19 -1,176.33 2,510,643.08 212,562.69 0.19 1,662.70 4,000.00 55.19 228.00 3,330.02 3,208.02 -1,234.05 -1,237.26 2,510,589.73 212,500.43 0.19 1,744.69 4,100.00 56.03 227.22 3,386.59 3,264.59 -1,289.56 -1,298.24 2,510,535.74 212,438.11 1.05 1,827.15 4,200.00 56.05 227.78 3,442.29 3,320.29 -1,345.85 -1,359.30 2,510,480.96 212,375.69 0.47 1,910.18 4,300.00 56.00 228.78 3,498.21 3,376.21 -1,401.02 -1,421.19 2,510,427.31 212,312.47 0.83 1,993.09 4,400.00 56.39 228.22 3,553.91 3,431.91 -1,455.87 -1,483.55 2,510,374.01 212,248.78 0.61 2,076.14 11/15/2016 12:53:25PM Page 3 COMPASS 5000.1 Build 81 I 0 Halliburton I-IALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA tLocal Co-ordinate Reference: Well K-03-Slot Slot 32 Company: Hilcorp Energy Company TVD Reference: PR K-03RD2 @ 122.00usft Project: Trading Bay MD Reference: _ K-03RD2 @ 122.O0usft Site: King Salmon North Reference: True Well: K-03 Survey Calculation Method: Minimum Curvature Wellbore: K-03RD2 Design: K-03RD2 wp03 ; ,. ,��:..�..:ems- _.�,��•.�. , .4.s�� ...�.,. ,.; �,�.: »� .....a-:�, ..��:,,�� .�. Planned Survey y. . : .•, a Measured Vertical d ANitirg, Map Map Depth Inclination Azimuth Depth TVDsstt.a. Northing Easting o (usft) (a) (1 (usft) usft (usft) (usft) 4,500.00 56.11 229.56 3,609.34 3,487.34 -1,510.87 -1,546.01 2,510,320.55 212,185.00 1.15 2,159.36 4,600.00 56.39 228.44 3,665.03 3,543.03 -1,564.99 -1,609.01 2,510,267.99 212,120.69 0.97 2,242.41 4,700.00 56.11 228.00 3,720.46 3,598.46 -1,620.63 -1,670.91 2,510,213.89 212,057.44 0.46 2,325.64 4,800.00 56.19 228.78 3,776.25 3,654.25 -1,675.83 -1,732.88 2,510,160.22 211,994.15 0.65 2,408.63 4,900.00 54.30 229.77 3,832.91 3,710.91 -1,729.58 -1,795.32 2,510,108.01 211,930.41 2.06 2,491.00 5,000.00 50.80 234.63 3,893.58 3,771.58 -1,778.79 -1,857.70 2,510,060.35 211,866.85 5.20 2,570.31 5,100.00 50.39 236.00 3,957.53 3,835.53 -1,821.94 -1,921.31 2,510,018.76 211,802.19 1.14 2,646.52 5,200.00 50.69 235.22 4,021.06 3,899.06 -1,865.47 -1,985.11 2,509,976.81 211,737.35 0.68 2,723.11 5,300.00 50.16 235.00 4,084.64 3,962.64 -1,909.71 -2,048.35 2,509,934.13 211,673.05 0.56 2,799.76 5,400.00 48.04 237.32 4,149.91 4,027.91 -1,952.19 -2,111.06 2,509,893.20 211,609.31 2.75 2,874.85 5,500.00 47.30 238.78 4,217.49 4,095.49 -1,991.00 -2,173.72 2,509,855.93 211,545.72 1.31 2,947.45 5,600.00 46.86 239.78 4,285.56 4,163.56 -2,028.43 -2,236.70 2,509,820.06 211,481.84 0.86 3,019.37 5,700.00 46.16 240.00 4,354.35 4,232.35 -2,064.74 -2,299.54 2,509,785.29 211,418.14 0.71 3,090.45 5,800.00 45.02 239.22 4,424.27 4,302.27 -2,100.81 -2,361.26 2,509,750.75 211,355.55 1.27 3,160.53 5,900.00 44.36 239.78 4,495.44 4,373.44 -2,136.65 -2,421.68 2,509,716.40 211,294.27 0.77 3,229.49 6,000.00 43.66 242.33 4,567.34 4,445.34 -2,170.47 -2,482.39 2,509,684.08 211,232.75 1.91 3,297.32 6,100.00 43.09 246.89 4,640.06 4,518.06 -2,200.08 -2,544.30 2,509,655.99 211,170.13 3.18 3,363.24 6,200.00 43.19 248.78 4,713.09 4,591.09 -2,225.46 -2,607.71 2,509,632.16 211,106.12 1.30 3,427.48 6,300.00 44.03 248.22 4,785.57 4,663.57 -2,250.53 -2,671.89 2,509,608.68 211,041.35 0.92 3,492.07 6,400.00 45.22 248.00 4,856.76 4,734.76 -2,276.81 -2,737.01 2,509,584.00 210,975.61 1.21 3,558.18 6,500.00 44.33 249.55 4,927.46 4,805.46 -2,302.61 -2,802.85 2,509,559.82 210,909.15 1.41 3,624.51 6,600.00 44.78 250.00 4,998.98 4,876.98 -2,326.57 -2,868.50 2,509,537.47 210,842.93 0.55 3,689.48 6,700.00 45.39 251.56 5,069.53 4,947.53 -2,350.10 -2,935.35 2,509,515.59 210,775.53 1.26 3,755.04 6,800.00 45.11 251.22 5,139.83 5,017.83 -2,372.49 -3,002.85 2,509,494.86 210,707.50 0.37 3,820.34 6,900.00 45.78 251.00 5,210.15 5,088.15 -2,395.61 -3,070.09 2,509,473.39 210,639.71 0.69 3,885.93 7,000.00 46.00 250.22 5,279.65 5,157.65 -2,419.38 -3,137.95 2,509,451.29 210,571.29 0.60 3,952.42 7,100.00 47.17 250.00 5,348.54 5,226.54 -2,444.14 -3,206.07 2,509,428.20 210,502.58 1.18 4,019.76 7,200.00 47.50 250.78 5,416.14 5,294.14 -2,468.97 -3,275.44 2,509,405.08 210,432.63 0.66 4,088.08 7,300.00 46.91 251.00 5,483.99 5,361.99 -2,492.92 -3,344.89 2,509,382.84 210,362.61 0.61 4,155.86 7,400.00 46.56 251.00 5,552.59 5,430.59 -2,516.61 -3,413.69 2,509,360.84 210,293.25 0.36 4,223.00 7,500.00 46.50 251.00 5,621.41 5,499.41 -2,540.23 -3,482.29 2,509,338.91 210,224.10 0.06 4,289.93 7,600.00 45.91 252.56 5,690.54 5,568.54 -2,563.03 -3,550.85 2,509,317.79 210,155.00 1.27 4,356.30 7,700.00 45.94 253.78 5,760.20 5,638.20 -2,583.70 -3,619.55 2,509,298.81 210,085.81 0.88 4,421.35 7,800.00 45.41 253.22 5,829.96 5,707.96 -2,603.84 -3,688.31 2,509,280.36 210,016.58 0.66 4,486.09 7,900.00 45.25 253.00 5,900.34 5,778.34 -2,624.58 -3,756.25 2,509,261.29 209,948.15 0.23 4,550.63 8,000.00 45.64 254.56 5,970.56 5,848.56 -2,644.67 -3,824.56 2,509,242.88 209,879.37 1.18 4,615.00 8,100.00 45.94 255.00 6,040.26 5,918.26 -2,663.28 -3,893.81 2,509,225.96 209,809.69 0.44 4,679.09 8,200.00 46.78 255.00 6,109.35 5,987.35 -2,682.00 -3,963.64 2,509,208.96 209,739.42 0.83 4,743.68 8,300.00 45.44 255.77 6,178.35 6,056.35 -2,700.36 -4,033.64 2,509,192.32 209,668.99 1.45 4,808.18 8,400.00 45.58 256.00 6,248.72 6,126.72 -2,717.58 -4,102.58 2,509,176.79 209,599.66 0.22 4,871.11 8,500.00 45.95 256.00 6,318.42 6,196.42 -2,734.93 -4,172.15 2,509,161.15 209,529.68 0.36 4,934.60 8,600.00 45.61 256.00 6,388.09 6,266.09 -2,752.29 -4,241.76 2,509,145.51 209,459.67 0.33 4,998.12 8,700.00 45.89 257.56 6,457.98 6,335.98 -2,768.85 -4,311.33 2,509,130.65 209,389.71 1.15 5,061.10 8,800.00 45.02 257.22 6,527.93 6,405.93 -2,784.13 -4,381.13 2,509,117.09 209,319.55 0.90 5,123.38 8,900.00 44.94 257.00 6,598.82 6,476.82 -2,799.96 -4,449.87 2,509,102.94 209,250.45 0.18 5,185.24 11/15/2016 12:53:25PM ' Page 4 COMPASS 5000.1 Build 81 • 0 Halliburton HALLIBURTONI Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well K-03-Slot Slot 32 Company: Hilcorp Energy Company TVD Reference: K-03RD2 @ 122.00usft Project: Trading Bay MD Reference: a K-03RD2 @ 122.00usft I Site: King Salmon North Reference: : True , Well:'''-. .. K-03 Survey Calculation Method: Minimum Curvature Wellbore K-03RD2 Design: K-03RD2 wp03 II Planned Survey ,i, Measured , Vertical ° Map ,. Map . Depth Inclination Azimuth Depth TVDss% N/-S +EFW a i,Northing 4 Easting DLS " Vett Section (usft) (°) (°) (usft) usft (usft) °,(usft) (usft) (usft) ;: 6,547.54 9,000.00 45.00 257.78 6,669.54 6,547.54 -2,815.50 -4,518.84 2,509,089.09 209,181.12 0.55 5,247.09 KOP:Start Dir 12.29°/100':9000'MD,6669.54'TVD:60°LT TF 9.017.08 46.05 255.23 6,681.51 6,559.51 -2,818.35 -4,530.69 2,509,086.54 209,169.20 12.29 5,257.83 End Dir :9017.08'MD,6681.51'TVD 9,037.08 46.05 255.23 6,695.39 6,573.39 -2,822.02 -4,544.61 2,509,083.21 209,155.19 0.00 5,270.67 Start Dir 5°/100':9037.08'MD,6695.39'TVD 9,100.00 43.42 252.79 6,740.08 6,618.08 -2,834.19 -4,587.18 2,509,072.08 209,112.34 5.00 5,310.55 9,200.00 39.35 248.38 6,815.11 6,693.11 -2,856.06 -4,649.52 2,509,051.75 209,049.49 5.00 5,371.65 9,300.00 35.49 243.15 6,894.54 6,772.54 -2,880.87 -4,704.92 2,509,028.30 208,993.49 5.00 5,429.52 9,400.00 31.89 236.87 6,977.75 6,855.75 -2,908.43 -4,752.97 2,509,001.92 208,944.78 5.00 5,483.74 9,500.00 28.67 229.27 7,064.13 6,942.13 -2,938.54 -4,793.31 2,508,972.81 208,903.72 5.00 5,533.88 9,600.00 25.97 220.09 7,153.00 7,031.00 -2,970.97 -4,825.61 2,508,941.18 208,870.64 5.00 5,579.57 9,700.00 23.96 209.22 7,243.70 7,121.70 -3,005.46 -4,849.64 2,508,907.28 208,845.77 5.00 5,620.46 9,800.00 22.83 196.93 7,335.53 7,213.53 -3,041.77 -4,865.21 2,508,871.37 208,829.31 5.00 5,656.23 9,876.42 22.64 187.05 7,406.04 7,284.04 -3,070.55 -4,871.34 2,508,842.74 208,822.48 5.00 5,679.95 End Dir :9876.42'MD,7406.05'TVD 9,900.00 22.64 187.05 7,427.81 7,305.81 -3,079.56 -4,872.45 2,508,833.77 208,821.15 0.00 5,686.78 10,000.00 22.64 187.05 7,520.10 7,398.10 -3,117.76 -4,877.17 2,508,795.69 208,815.49 0.00 5,715.71 10,100.00 22.64 187.05 7,612.40 7,490.40 -3,155.96 -4,881.89 2,508,757.62 208,809.84 0.00 5,744.64 10,200.00 22.64 187.05 7,704.69 7,582.69 -3,194.16 -4,886.62 2,508,719.55 208,804.18 0.00 5,773.57 10,300.00 22.64 187.05 7,796.99 7,674.99 -3,232.36 -4,891.34 2,508,681.47 208,798.53 0.00 5,802.51 10,400.00 22.64 187.05 7,889.28 7,767.28 -3,270.57 -4,896.06 2,508,643.40 208,792.87 0.00 5,831.44 10,500.00 22.64 187.05 7,981.58 7,859.58 -3,308.77 -4,900.79 2,508,605.32 208,787.21 0.00 5,860.37 10,600.00 22.64 187.05 8,073.87 7,951.87 -3,346.97 -4,905.51 2,508,567.25 208,781.56 0.00 5,889.31 10,700.00 22.64 187.05 8,166.17 8,044.17 -3,385.17 -4,910.23 2,508,529.18 208,775.90 0.00 5,918.24 10,800.00 22.64 187.05 8,258.46 8,136.46 -3,423.37 -4,914.95 2,508,491.10 208,770.24 0.00 5,947.17 10,900.00 22.64 187.05 8,350.76 8,228.76 -3,461.57 -4,919.68 2,508,453.03 208,764.59 0.00 5,976.10 11,000.00 22.64 187.05 8,443.05 8,321.05 -3,499.77 -4,924.40 2,508,414.96 208,758.93 0.00 6,005.04 11,100.00 22.64 187.05 8,535.35 8,413.35 -3,537.97 -4,929.12 2,508,376.88 208,753.27 0.00 6,033.97 11,200.00 22.64 187.05 8,627.64 8,505.64 -3,576.17 -4,933.84 2,508,338.81 208,747.62 0.00 6,062.90 11,300.00 22.64 187.05 8,719.94 8,597.94 -3,614.37 -4,938.57 2,508,300.74 208,741.96 0.00 6,091.84 11,350.22 22.64 187.05 8,766.29 8,644.29 -3,633.56 -4,940.94 2,508,281.62 208,739.12 0.00 6,106.37 Start Dir 5°/100':11350.22'MD,8766.29'TVD 11,400.00 24.84 189.95 8,811.86 8,689.86 -3,653.36 -4,943.92 2,508,261.89 208,735.65 5.00 6,121.77 11,500.00 29.39 194.52 8,900.86 8,778.86 -3,697.83 -4,953.71 2,508,217.67 208,724.78 5.00 6,158.65 11,544.23 31.44 196.15 8,939.00 8,817.00 -3,719.42 -4,959.64 2,508,196.24 208,718.32 5.00 6,177.43 COAL39 11,600.00 34.05 197.95 8,985.90 8,863.90 -3,748.25 -4,968.50 2,508,167.63 208,708.76 5.00 6,203.22 11,700.00 38.79 200.63 9,066.35 8,944.35 -3,804.23 -4,988.17 2,508,112.15 208,687.72 5.00 6,255.15 11,800.00 43.58 202.81 9,141.59 9,019.59 -3,865.36 -5,012.59 2,508,051.64 208,661.81 5.00 6,314.04 11,900.00 48.41 204.64 9,211.05 9,089.05 -3,931.16 -5,041.56 2,507,986.56 208,631.24 5.00 6,379.44 11,901.44 48.48 204.66 9,212.00 9,090.00 -3,932.14 -5,042.01 2,507,985.60 208,630.77 5.00 6,380.43 MKR_13 12,000.00 53.26 206.21 9,274.19 9,152.19 -4,001.14 -5,074.87 2,507,917.42 208,596.23 5.00 6,450.86 12,100.00 58.12 207.59 9,330.54 9,208.54 -4,074.77 -5,112.26 2,507,844.73 208,557.05 5.00 6,527.74 11/15/2016 12:53:25PM Page 5 COMPASS 5000.1 Build 81 i • Halliburton I-IALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA ;'Local Co-ordinate Reference Well K-03-Slot Slot 32 Company: Hilcorp Energy Company TVD Reference: K-03RD2 @ 122.00usft Project: Trading Bay 'MD Reference: € K-03RD2 @ 122.00usft Site: King Salmon North Reference: t True Well: 'K-03 i Survey Calculation Method: Minimum Curvature Wellbore:1 K-03RD2 ;' Design: i'. K-03RD2 wp03 .1 ,,,,,,,,w,,,,,,,,,,,,,,,,,,„,,,,,,; Planned Survey .,.� Measured , ,, ,, Vertical Map Map Depth Inclination Azimuth Depth TVDssI`g +1.1/4 + W 'sE/- " - Northing Easting DLS ° iiVert Section " (usft) (°) (°) (usft) usft (usft) (usft) 'ti (usft) (usft) , 9 225.00' 12,131.86 59.68 208.00 9,347.00 9,225.00 -4,098.90 -5,124.98 2,507,820.92 208,543.74 5.00 6,553.29 Hemlock 12,200.00 63.01 208.84 9,379.67 9,257.67 -4,151.47 -5,153.44 2,507,769.06 208,514.01 5.00 6,609.51 12,266.10 66.24 209.60 9,408.00 9,286.00 -4,203.58 -5,182.59 2,507,717.67 208,483.59 5.00 6,665.94 H2 12,300.00 67.90 209.98 9,421.21 9,299.21 -4,230.68 -5,198.10 2,507,690.97 208,467.42 5.00 6,695.54 12,302.11 68.00 210.00 9,422.00 9,300.00 -4,232.37 -5,199.08 2,507,689.30 208,466.40 4.99 6,697.40 1 End Dir :12302.11'MD,9422'TVD 12,400.00 68.00 210.00 9,458.67 9,336.67 -4,310.97 -5,244.46 2,507,611.83 208,419.11 0.00 6,783.56 12,500.00 68.00 210.00 9,496.13 9,374.13 -4,391.27 -5,290.82 2,507,532.69 208,370.80 0.00 6,871.58 12,526.34 68.00 210.00 9,506.00 9,384.00 -4,412.42 -5,303.03 2,507,511.85 208,358.07 0.00 6,894.77 H3 12,600.00 68.00 210.00 9,533.59 9,411.59 -4,471.57 -5,337.18 2,507,453.55 208,322.48 0.00 6,959.61 12,700.00 68.00 210.00 9,571.05 9,449.05 -4,551.86 -5,383.54 2,507,374.42 208,274.17 0.00 7,047.63 12,739.90 68.00 210.00 9,586.00 9,464.00 -4,583.90 -5,402.03 2,507,342.84 208,254.90 0.00 7,082.75 H4 12,800.00 68.00 210.00 9,608.51 9,486.51 -4,632.16 -5,429.90 2,507,295.28 208,225.86 0.00 7,135.65 12,878.71 68.00 210.00 9,638.00 9,516.00 -4,695.36 -5,466.39 2,507,232.99 208,187.84 0.00 7,204.94 H5 12,900.00 68.00 210.00 9,645.97 9,523.97 -4,712.46 -5,476.25 2,507,216.14 208,177.55 0.00 7,223.68 13,000.00 68.00 210.00 9,683.44 9,561.44 -4,792.75 -5,522.61 2,507,137.00 208,129.24 0.00 7,311.70 13,086.93 68.00 210.00 9,716.00 9,594.00 -4,862.56 -5,562.91 2,507,068.21 208,087.24 0.00 7,388.22 H6 13,100.00 68,00 210.00 9,720.90 9,598.90 -4,873.05 -5,568.97 2,507,057.87 208,080.93 0.00 7,399.72 13,200.00 68.00 210.00 9,758.36 9,636.36 -4,953.35 -5,615.33 2,506,978.73 208,032.62 0.00 7,487.75 13,300.00 68.00 210.00 9,795.82 9,673.82 -5,033.64 -5,661.69 2,506,899.59 207,984.31 0.00 7,575.77 13,321.84 68.00 210.00 9,804.00 9,682.00 -5,051.18 -5,671.82 2,506,882.31 207,973.75 0.00 7,595.00 H7 13,322.00 68.00 210.00 9,804.06 9,682.06 -5,051.31 -5,671.89 2,506,882.18 207,973.68 0.00 7,595.13 Total Depth:13322'MD,9804.06'TVD Targets a- r ., Target Name i` ,, ' 9 hit/miss target Dip Angle Dip Dir.'1' TVD +E1-W ,kfr Northing Easting 'Shape (°) (°) (usft) sft• (usft) 14, (usft) (usft) K-03RD2 wp2 Tgt1 0.00 0.00 9,422.00 -4,232.37 -5,199.08 2,507,689.30 208,466.40 -plan hits target center -Circle(radius 50.00) 11/15/2016 12:53:25PM Page 6 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTON Standard Proposal Report _. Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference:"' Well K-03-Slot Slot 32 Company: Hilcorp Energy Company TVD Reference: ," K-03RD2 @ 122.00usft Project: "Trading Bay MD Reference: :`= K-03RD2 @ 122.00usft Site: King Salmon North Reference: True Well: K-03 `Survey Calculation Method:. Minimum Curvature Wellbore:'hhhthh K-03RD2 Design: f K-03RD2 wp03 " ; :1 . � � r ."mom ,._ 7. " ,a :, Casing Points " Measured Vertical Casing = Hole '<' Depth Depth Diameter Diameter (usft) usft) ( ) ;La .e 9,000.01 6,669.55 9 5/8"47#TOW 9-5/8 13-1/2 . . 13,322.00 9,804.06 7"x 8 1/2" 7 8-1/2 Formations red . . Vertical Vertical Dip LTMea:uDeptDepth SS; a ;', Directio.,(usft) (usft) j �: (") r, 12,131.86 9,347.00 Hemlock 11,901.44 9,212.00 MKR13 12,739.90 9,586.00 H4 12,266.10 9,408.00 H2 13,086.93 9,716.00 H6 12,526.34 9,506.00 H3 12,878.71 9,638.00 H5 11,544.23 8,939.00 COAL39 13,321.84 9,804.00 H7 Plan Annotations nMeasured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment ;'1674.;''.406W044, '333, ',.. . 9,000.00 6,669.54 -2,815.50 -4,518.84 KOP:Start Dir 12.29°/100':9000'MD,6669.54'TVD:60'LT TF 9,017.08 6,681.51 -2,818.35 -4,530.69 End Dir :9017.08'MD,6681.51'TVD 9,037.08 6,695.39 -2,822.02 -4,544.61 Start Dir 5°/100':9037.08'MD,6695.39'TVD 9,876.42 7,406.04 -3,070.55 -4,871.34 End Dir :9876.42'MD,7406.05'TVD 11,350.22 8,766.29 -3,633.56 -4,940.94 Start Dir 5°/100':11350.22'MD,8766.29'TVD 12,302.11 9,422.00 -4,232.37 -5,199.08 End Dir :12302.11'MD,9422'TVD 13,322.00 9,804.06 -5,051.31 -5,671.89 Total Depth:13322'MD,9804.06'TVD 11/15/2016 12:53:25PM Page 7 COMPASS 5000.1 Build 81 • Hilcorp Energy Company Trading Bay King Salmon K-03 K-03RD2 PTD 167-086 K-03RD2 wp03 1i Sperry Drilling Services Clearance Summary Anticollision Report 15 November,2016 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: King Salmon•K-03•K-03RD2-K-03RD2 wp03 Well Coordinates:2,511,793.12 N,213,767.53 E(60°51'55.87"N,151°36'21.03"W) Datum Height: K-03RD2 Q 122.00usft Scan Range: 9,000.00 to 13,322.00 usft.Measured Depth. Scan Radius is 1,532.20 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited • Version:5000.1 Build: 81 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services • • Hilcorp Energy Company HALLIBURTON Trading Bay Anticollision Report for K-03-K-03RD2 wp03 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:King Salmon-K-03-K-03RD2-K-03RD2 wp03 Scan Range:9,000.00 to 13,322.00 usft.Measured Depth. Scan Radius is 1,532.20 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-15RD-G-15RD-G-I5RD 13,300.00 1,516.04 13,300.00 1,164.42 12,296.18 4.312 Clearance Factor Pass- King Salmon K-01-K-01-K-01 9,118.65 905.21 9,118.65 199.37 8,797.73 1.282 Centre Distance Pass- K-01-K-01-K-01 9,950.00 976.35 9,950.00 115.83 9,610.72 1.135 Ellipse Separation Pass- K-01-K-01-K-01 10,000.00 987.08 10,000.00 116.50 9,644.97 1.134 Clearance Factor Pass- K-01-K-01PB1-K-01PB1 9,118.65 905.21 9,118.65 199.37 8,797.73 1.282 Centre Distance Pass- K-01-K-01 PB1-K-01 PB1 9,950.00 976.35 9,950.00 115.83 9,610.72 1.135 Ellipse Separation Pass- K-01-K-01PB1-K-01PB1 10,000.00 987.08 10,000.00 116.50 9,644.97 1.134 Clearance Factor Pass- K-03-K-03-K-03 11,736.55 1,264.02 11,736.55 1,109.99 11,363.06 8.206 Centre Distance Pass- K-03-K-03-K-03 12,100.00 1,331.24 12,100.00 1,043.17 11,680.50 4.621 Ellipse Separation Pass- K-U3-K-03-K-03 12,250.00 1,396.00 12,250.00 1,057.40 11,803.11 4.123 Clearance Factor Pass- K-03-K-03 PBI-K-03 PBI 10,602.06 1,491.75 10,602.06 1,419.75 9,731.00 20.718 Centre Distance Pass- K-03-K-03 PBI-K-03 PBI 10,650.00 1,492.52 10,650.00 1,419.00 9,731.00 20.300 Ellipse Separation Pass- K-03-K-03 PBI-K-03 PB1 10,950.00 1,531.79 10,950.00 1,445.87 9,731.00 17.827 Clearance Factor Pass- K-03-K-03RD-K-03RD 9,300.00 20.18 9.300.00 3.11 9,278.31 1.183 Clearance Factor Pass- K-19-K-19-K-19 IIIIII Ellisallill Mak 9,000.00 -20.17 8,763.30 0.970 Centre Dtstarl . K-19-K-19-K-19 MM. Ma050.00 -22.49 8,813.41 0.967 Clearance Factor FAIL- K-19-K-19 PBI-K-19 P61 lirrg,000.00 -20.17 g 8,76341 L 0.970 Centre Distance F K-19-K-19 P81-K-19 PBI IMMI I„ 9,050.00 -22.49 =9,8141. iii 0.967 Clearance Factor Plan:K-26RD(K-08)-K-08-K-08 12,125.00 1,524.95 12,125.00 1,230.08 11,939.14 5.171 Clearance Factor Pass- Plan:K-26RD(K-08)-K-08-K-08 13,300.00 1,091.02 13,300.00 906.25 12,863.84 5.905 Ellipse Separation Pass- Plan:K-26RD(K-08)-K-08PB3-K-08PB3 12,125.00 1,524.95 12,125.00 1,230.08 11,939.14 5.171 Clearance Factor Pass- Plan:K-26RD(K-08)-K-08PB3-K-08PB3 13,300.00 1,113.11 13,300.00 918.70 12,723.52 5.726 Ellipse Separation Pass- Plan:K-26RD(K-08)-K-08PB4-K-08PB4 12,125.00 1,524.95 12,125.00 1,230.08 11,939.14 5.171 Clearance Factor Pass- Plan:K-26RD(K-08)-K-08PB4-K-08PB4 13,300.00 1,071.80 13,300.00 865.03 12,956.40 5.184 Ellipse Separation Pass- Plan:K-26RD(K-08)-K-08RD-K-08RD 9,000.00 614.97 9,000.00 523.48 8,774.22 6.722 Clearance Factor Pass- Plan:K-26RD(K-08)-K-08RDPB1-K-08RDPB1 9,000.00 613.98 9,000.00 399.39 8,756.84 2.861 Clearance Factor Pass- 15 November,2016-13:12 Page 2 of 5 COMPASS • 0 Hilcorp Energy Company HALLIBURTON Trading Bay Anticollision Report for K-03-K-03RD2 wp03 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:King Salmon-K-03-K-03RD2-K-03RD2 wp03 Scan Range:9,000.00 to 13,322.00 usft.Measured Depth. Scan Radius is 1,532.20 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 Plan:K-26RD(K-08)-K-08RDPB2-K-08RDPB2 9,000.00 614.97 9,000.00 523.48 8,774.22 6.722 Clearance Factor Pass- RIG:K-10-K-10-K-10 9,000.00 1,419.53 9,000.00 976.67 8,430.68 3.205 Clearance Factor Pass- RIG:K-10-K-10RD-K-10RD 9,000.00 1,419.53 9,000.00 976.82 8,430.68 3.206 Clearance Factor Pass- RIG:K-10-Plan:K-10RD2-K-10RD2 wp05 9,000.00 1,417.03 9,000.00 970.30 8,526.76 3.172 Centre Distance Pass- RIG:K-10-Plan:K-10RD2-K-10RD2 wp05 9,075.00 1,420.49 9,075.00 969.98 8,643.28 3.153 Ellipse Separation Pass- RIG:K-10-Plan:K-10RD2-K-10RD2 wp05 9,225.00 1,432.57 9,225.00 975.42 8,874.75 3.134 Clearance Factor Pass- RIG:K-10-Plan:K-10RD2-K-10RD2-RIG 9,000.00 1,419.53 9,000.00 976.66 8,455.37 3.205 Ellipse Separation Pass- RIG:K-10-Plan:K-10RD2-K-10RD2-RIG 9,250.00 1,451.80 9,250.00 994.85 8,876.80 3.177 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 122.00 2,522.00 CB-Gyro-MS 2,622.00 9,000.00 CB-Gyro-MS 9,000.00 9,300.00 K-03RD2wp03 MWD_Interp Azi 9,300.00 13,322.00 K-03RD2wp03 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. 15 November,2016- 13::12 Page 3 of 5 COMPASS • 4110 • HALLIBURTON Project Trading Bay REFERENCE INFORMATION WELL DETAILS:K-03 NAD 1927(NADCONCONUS) Alaska Zone 04 Site: King Salmon c-erdinete(WE)Reference:Well K-03-Slot Slot 32,True North Water Depth: 73.00 Well: K-03 Vertical(TVD)Reference:KA3RD2 a 122.00ueR +N/-S +E/-W Northing Earring Latim ere Longitude Sperry Drilling Measured Depth Reference:KA3RD2 122,32061 0.00 0.00 2511793.12 213767.53 60°51'55.870N 151°36'21.030 W Wellbore: K-03RD2 celaukLen Method Minimum Curvature Plan. K-03RD2 wp03 SURVEY PROGRAM GLOBAL FILTER APPLIED:All wellpaths within 200'.100/1000 of reference ril "i'(.t)11 Date:2010-11-03T00:00:00 Validated:Yes Version: 9000.00 To 13322.00 Ladder/S.F. Plots CASING DETAILS Depth From Depth E-Survey/Plan Tool 122.00 2522.00 K-O3RD (1) CB-Gyro-MS 2622.00 9000.00 K-03RD CB-Gyro-MS TVD TVDSS MD Size Name WFU-03 Omitted 9000.00 9300.00 K-03RD2 03 9300.00 13322.00 K-03RD2wwpp03 MWD_InterAz MWD+SC+sag 6669.55 6547.55 9000.01 980306 9682.06 13322.00 9-5/877"x9tO�W IIIIIIIIIiI 5 • Y ,. r "i K01P61 I K-01— `so.00 �L mh!Hli n to B { 1 I U .. K 19 i y 1403RD 0 30.00 -- 22 ._. "S l / Z m 0.00 I l I I I i i i I I I l i i I i l i l � l l l l H i l i ! ! ! ! I L I I l l l l l l l l l l l l I L I I illi illi I L I I 8100 8400 8700 9000 9300 9600 9900 10200 10500 10800 11100 11400 11700 12000 12300 12600 12900 13200 13500 Measured Depth(600 usft/in) \\:------- ---- -- \ 6.00— ....________::7 4.50— I ' o ` m 3.00 '.. ........__ __ ill m m - Collision Risk Procedures Req. 1.50 - Collision Avoidance Req. _ No-Go Zone-Stop Drillingf 0.00 -�. 11 1 I 11 1 1 I l 1 1 1_.. 1111 1111 1111 111111111 I TT-- 1 I I I 1111 1 1 1 1 1 1 1 1 1111 1111 1111 1111 1 1 1 1 1 1 1 1 8100 8400 8700 9000 9300 9600 9900 10200 10500 10800 11100 11400 11700 12000 12300 12600 12900 13200 13500 Measured Depth • • Hilcorp Energy Company Trading Bay King Salmon K-03 K-03RD2 PTD 167-086 K-03RD2 wp03 Sperry Drilling Services Clearance Summary Anticollision Report 15 November,2016 Critical Offset Well: WFU-03 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: King Salmon-K-03•K-03RD2-K-03RD2 wp03 Well Coordinates:2,511,793.12 N,213,767.53E(60°51'55.87"N,151°36'21.03"W) Datum Height: K-03RD2 @ 122.00usft Scan Range: 9,000.00 to 13,322.00 usft.Measured Depth. Scan Radius Is Unlimited.Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,000.00 usft Version: 5000.1 Build:81 Scan Type: NO GLOBAL FILTER:fa n,user'^ filtering criteria Scan Type: 25.00 HALLIBURTON Sperry Drilling Services • • Hilcorp Energy Company HALLIBURTON Trading Bay Anticollision Report for K-03-K-03RD2 wp03 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: King Salmon-K-03-K-03RD2-K-03RD2 wp03 Scan Range:9,000.00 to 13,322.00 usft.Measured Depth. Scan Radius is Unlimited.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is 1,000.00 usft 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 Wildcats WFU-03-W Foreland Unit-WFU-03 WFU-03-W Foreland Unit-WFU-03 WFU-03-W Foreland Unit-WFU-03 - - - 111.11111111 - - Survey fool program From To Survey/Plan Survey Tool (usft) (usft) 122.00 2,522.00 CB-Gyro-MS 2,622.00 9,000.00 CB-Gyro-MS 9,000.00 9,300.00 K-03RD2 wp03 MWD_Interp Azi 9,300.00 13,322.00 K-03RD2wp03 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. 15 November,2016-13:18 Page 2 of 4 COMPASS • • Hilcorp Energy Company HALLIBURTON Trading Bay Anticollision Report for K-03-K-03RD2 wp03 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to K-03RD2 @ 122.00usft. Northing and Easting are relative to K-03-Slot Slot 32. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:-1.40°. Ladder Plot I I I I I I • I I I I/ I I ►\ .-gni 2401 ��w ..r CO CO p 160 LEGEND -9-WFU-03,W Foreland Unit,WFU-03 V0 $ K-03RD2v„p03 C 4) r� O 80 , I I I I I I a) I I U I I I 0 0 2500 5000 7500 10000 12500 Measured Depth(2500 usft/in) 15 November,2016-13:18 Page 3 of COMPASS • • Hilcorp Energy Company HALLIBURTON Trading Bay Anticollision Report for K-03 -K-03RD2 wp03 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 10.00- 8.75- 7.50 0.00-8.75--.7.50 ........................._......._._..--._......_—._.'__.._....._._..................._........_.__. _....._................_..................._..............._..—_—..................................._._......_. N 6.25 LEGEND LL - 0 5.00 . --- --....---------- '� -g-WFU-03,WForelandUnitWFU-03V0 - -$ K-03RD2wp03 co3.75— ........ _ .__... ..__._... ......... ..i. 2.50— —Collis on Avoidance Req �No-Go Zone-Stop Drilling 1.25 0.04) i i i i i i a Hi I i a a a till i i i a 1 1 1 1 1 1 1 1 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 Meowed Depth(2500 us/in) 15 November,2018-13:18 Page 4 014 COMPASS • • Trading Bay Unit PROPOSED Well#K-03RD Last Completed:FUTURE Ifiicerp Alaska,LIC PTD: 180-144 API:50-733-20074-01 CASING DETAIL RKB to Hanger=35' SIZE WT GRADE CONN ID TOP BTM. ---"""71 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2506' 5-95 BTC(170 jts) 8.681" Surf 9 5/8" 47 N$0 8rnd LTC(74 its) 8.681" N 80 BTC(31 Its} 8.681" 10,983' 7" 29 N-80/S-95 6.1$4" 10,660, 0,660 13,345' TUBING DETAIL 13.55#Bare/ -80 Polycore Lined41/2" 14.55#Lined L _ BTC 3.56" Surf 10,319' •c 4-1/2") . 11.6#Bare/ L-80 Polycore Lined 3.64" 10,119' 12,368' f../ 12.55#Lined TPL-4040 3-1/2" 9.2# N-80 BTC 2.992" 12,368' 12,382' JEWELRY DETAIL (..../‘" Depth Depth No MD TVD ID OD Item 1 ±9,017' ±7,781' CIBP(set for whipstock) . 11/ 2 12,368' 9,056' 3.000" 5.125" -Baker 80-40 PBR w/30,000#shear 12,370' 3 WLM 9,057' 3.000" 5.968" Baker FHL w/70,000#shear ' V 4 12,382' 9,066' 2.992" Bottom of Eline cut tubi# (\D/ L7' K X PERFORATION DETAIL I 'will Ir' Zone Top Btm Top Btrn (MD) (MD) (TVD) (TVD) Amt SPF Date Status A. 9/10/14& ,`. 6-5 12,386' 12,462' 9,069' 9,126' 76 6 9/14/14 kp, G-5 12,408' 12,460' 9,086' 9,124' 52' 2 6/20/1996 4/ 9/10/14& 6-7 12,532' 12,592' 9,178' 9,222' 60 6 9/14/14 awe .ie e 3 B-0 12,530' 12,565' 9,176' 9,202' 35' 4/8 Cut Tal ' + ,," B-1 12,592' 12,622' 9,222' 9,244' 30 6 9/14/14 ,yF "' 4.1.-- G-5 B-1 12,605' 12,620' 9,232' 9,243' 15' 4/8 C.01:; ,rr71, G 7 B-2 12,633' 12,649' 9,252' 9,264' 16 12 9/9/14 Cemented B-2 12,634' 12,664' 9,253' 9,275' 30' 4/8 &0 8-2 12,680' 12,700' 9,287' 9,302' 20' 4 ;; B-1 8-3 12,745' 12,760' 9,335' 9,346' 15' 4/8 =&2 6-3 1 12,769' 12,799' 9,353' 9,375' 30' 4 1 `: ' _ 8-4 12,808' 12,820' 9,382' 9,391' 12' sgzd '- ..,F .'it -B-3 8-4 12,820' 12,880' 9,391' 9,435' 60' 4/8 " .yf B-7 13,134' 13,164' 9,626' 9,649' 30' r itvt,„ . ',-,`:.-4 ai�1 Ad'. &7 Fill Tagged w/2.80"GR on 6/17/96 @ 13,156'WLM A) Tubing tail(45') 9/14/14 @ Approx.12,634' PBTD=13,300' TDs 13,413' MAX HOLE ANGLE=56"@ 4,100'MD ANGLE @ PERFS.=43° KOP @ 300' Updated by: JLL 11/17/16 • • Trading Bay Unit SCHEMATIC Well#K-03RD Last Completed:09/18/2014 ltacar,Alaaka,LLC (� PTD: 180-144 ci;‘,44y API:50-733-20074-01 CASING DETAIL RKB to Hanger=35' SIZE WT GRADE CONN ID TOP BTM. r - 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2506' 5-95 BTC(174 Jts) 8.681" Surf 9-5/8" 47 N-80 8md LTC(74 its) 8.681" - - N-80 BTC(31 its) 8.681" - 10,983' 7" 29 N-80/S-95 6.184" 10,660' _ 13,395' TUBING DETAIL 4-1/2" 13.554 Bare/ L8O Polycore Lined 356" Surf 10,119' 14.554 Lined BTC 11.611 Bare/ Polycore Lined 4-1/2" 12.554 Lined L-80 TPL_4040 3.64" 10,119' 12,368' 3-1/2" 9.24 N-80 BTC 2.992" 12,368' 12,382' JEWELRY DETAIL No Depth Depth MD ND ID OD Item _ FMC Tubing Hanger,4-1/2"w/pup&X-O to 3-1/2"8TC e 1 10,118' 7,470' Crossover from BTC Extended to TPL-4040 2 12,368' 9,056' 3.000" 5.125" Baker 80-40 PBR w/30,0004 shear I: 3 1231 9,057' 3.000" 5.968" Baker FHL w/70,0004 shear WLM 4 12,382' 9,066' 2.992" Bottom of Eline cut tubig , X PERFORATION DETAIL Top Top Ettm Zone (MD) (MD) (ND) ) Amt SPF Date t 9/10/14& ,/to 0-5 12,386' 12,462' 9,069' 9,126' 76 6 9/14/14 7 ...----+ G-5 12,408' 12,460' 9,086' 9,124' 52' 2 6/20/1996 14)3'0 2 iv r "< 3 G-7 12,532' 12,592' 9,178' 9,222' 60 6 9/10/14& V 4 9/14/14 fp B-0 12,530' 12,565' 9,176' 9,202' 35' 4/8 ^7r E-Line Cut Tail G-5 B-1 12,592' 12,622' 9,222' 9,244' 30 6 9/14/14 &Pit 8-1 12,605' 12,620' 9,232' 9,243' 15' 4/8 gL5 G-7 8-2 12,633' 12,649' 9,252' 9,264' 16 12 9/9/14 X©tl Iv� B-0 13-2 12,634' 12,664' 9,253' 9,275' 30' 4/8 B-1 8-2 12,680' 12,700' 9,287' 9,302' 20' 4 B-2 8-3 12,745' 12,760' 9,335' 9,346' 15' _ 4/8 A8-3 12,769' 12,799' 9,353' 9,375' 30' 4 B-3 8-4 12,808' 12,820' 9,382' 9,391' 12' sqzd -B 4 B-4 12,820' 12,880' 9,391' 9,435' 60' 4/8 8-7 13,134' 13,164' 9,626' 9,649' 30' 8-7 Fill Tagged w/2.80"GR on 6/17/96 @ 13,156'WLM .'' A) Tubing tail(45') 9/14/14 @ Approx.12,634' PBTD=13,300' TD=13,413' MAX HOLE ANGLE=56"@I 4,100'MD ANGLE @ PERFS.=43" KOP @ 300' Updated by: DEM 11/07/15 • • TRANSMITTAL LETTER CHECKLIST WELL NAME: / LL, I'.-O PJ .2, PTD: 07/ —0 Z,? Aevelopment —Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: IG l4-0.51A, POOL: c fl+c. , 41,1/e4r 11'E/1liod< C() I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) 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)(2XB) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 41 0 El 171 , , , , N a) 0 , 2 ui , , , , , , I • c as , C d , ,, , , , ,, L aao ; , , , , , , , N. O. , , , , O N c , o1p , . , , , z. , , E. 0 O o, z c 0 o' m5 as g' a) 0 4 0. °) 0 �, 0) , E, C' L' pr so Y () Y' W c Ci_ (a), ?' S>, 0) L, M L, c ° m, 4), o o. 0 o. @ m, a 0 CI ct a. '3, g . F- o a a MO N' N, _, L, d 0 W O 1, C' N W, C, • Z In c, c' y, , a 0 E, 0 m' , 0) m. 8 7, o E, c .- .N as. -0' , 0 0 a=, 0, , a L, r) Y, m, ' oi a v' D o'. 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C7 E N All ` O C O Lij-, I• CL < a w � 0 TD as 0 a a a • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Weil History file and to simplrfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. TBU M-06RD 50-733-20585-01-00 McArthur River Field Kenai Peninsula Borough, Alaska June 5, 2017 – June24, 2017 Provided by: Approved by: John Serbeck Compiled by: Allen Odegaard Garnet Knopp Mike Skiles Distribution Date: July 20, 2017 TBU M-06RD 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 ............................................................................................................................. 8 3.1 Lithostratigraphy ............................................................................................................................. 8 3.2 Lithology Details ............................................................................................................................. 9 3.2.1 Tyonek Formation ................................................................................................................. 10 3.2.2 Hemlock Formation ............................................................................................................... 19 3.2.3 Hemlock H1X_FW ................................................................................................................. 19 3.2.4 Hemlock HTKE-FW ............................................................................................................... 20 3.2.5 Hemlock HK2T ...................................................................................................................... 20 3.2.6 Hemlock HK2T_LOWER ....................................................................................................... 20 3.2.7 Hemlock HK3T ...................................................................................................................... 21 3.2.8 Hemlock HK4T ...................................................................................................................... 21 3.2.9 Hemlock HK5T ...................................................................................................................... 22 3.2.10 Hemlock HK6T ...................................................................................................................... 22 3.2.11 Hemlock HK7T ...................................................................................................................... 23 3.2.12 West Foreland Formation ...................................................................................................... 24 3.2.13 West Foreland WFT .............................................................................................................. 24 3.2.14 West Foreland WF_2 ............................................................................................................ 25 3.2.15 West Foreland WF_3 ............................................................................................................ 27 3.3 Sampling Program ........................................................................................................................ 29 4 Drilling Data ......................................................................................................................................... 30 4.1 4.1 Surveys ................................................................................................................................... 30 4.2 Bit Record ..................................................................................................................................... 38 4.3 Mud Record .................................................................................................................................. 39 4.4 Drilling Progress ........................................................................................................................... 40 5 SHOW REPORTS ............................................................................................................................... 41 6 DAILY REPORTS ................................................................................................................................ 42 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 TBU M-06RD 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Baseline 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 & RigW atch) 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 19 29 Brendon Schmidt 0.25 18 Mike Skiles 11 6 Jake Robertson 4 16 Garnet Knopp 1 25 *1 Years’ experience as Logging Geologist *2 Days at wellsite between rig up and rig down of logging unit. TBU M-06RD 3 2 GENERAL WELL DETAILS 2.1 Well Objectives M-06RD is an oil production well planned to be re-drilled in a south-westerly direction from the existing M- 06 utilizing the existing casing program down to 7,279’ MD / 4,880’ TVD. At 7,279’ MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock and West Foreland targets. A 8,320’ 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 7,279’ MD at 54.2° and began immediately dropping angle to 11.9° by 8,475’ MD. Held inclination at 11°-14° until 10,563’ MD. Continue drilling while dropping angle to 5° at 10,752’ MD. Continue drilling while building angle to 84° at 13,218’ MD. Held ~84° to 15,472’ (TD). 7” liner was hung from the 9-5/8” casing at 7,002’ MD and ran down to 15,467’ MD. Operator: HILCORP ALASKA, LLC Well Name: TBU M-06RD Field: McArthur River Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Shane Hauck, Evan Harness, Harold Soule, Andy Lundale Location: Surface Coordinates 970' FNL, 532' FWL, Sec 33, T9N, R13W, SM, AK Mud Line Elevation 160’ AMSL Rotary Table Elevation 187’ AMSL Classification: Development - Oil API #: 50-733-20585-01-00 Permit #: 217-064 Rig Name/Type: Steelhead 51 / Steelhead Platform Spud Date June 05, 2017 Total Depth Date: June 24, 2017 Total Depth 15,472’ MD / 9,911.42’ TVD Primary Targets West Foreland Oil Pool Total Depth Formation: West Foreland 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” 15,472’ 9,911.42’ WF3 9.10 82.28 7” 15,467’ 9,910.31 N/A TBU M-06RD 4 2.3 Daily Activity Summary June 3, 2017 Pump cement, pull out of hole, lay down 4” drill pipe and 3.5” tubing, rig up E-line, test casing, run in hole with E-line, tag cement @ 7,881’, run in hole with junk basket. June 4, 2017 Run in hole with junk basket, pull out of hole with junk basket, Re-run junk basket until clean, Make up whipstock bottom hole assembly, perform shallow hole test, Make up rest of bo ttom hole assembly and run in hole with whipstock. June 5, 2017 Run in hole with whipstock, Clean/Prep pits for oil based mud, Swap over to oil based mud, Mill window from 7279' to 7340', Preform FIT test to 12.68 ppg EMW, pull out of hole. June 6, 2017 Pull out of hole, lay down milling assembly, Test bops, pick up bottom hole assembly, run in hole. June 7, 2017 Run in hole to window, circulate & condition mud, drill ahead from 7,340’ to 8,230’ @ report time. June 8, 2017 Drill ahead from 8,230' to 9,940' @ report time. June 9, 2017 Drill ahead from 9,940’ to 11072', Circulate bottoms up, Prepare for bit trip. June 10, 2017 Pulled out of hole to surface, replacing bit & servicing bottom hole assembly @ report time. June 11, 2017 Ran in hole to bottom w/ new drill bit and serviced bottom hole assembly, circulated, drilled ahead; drilling ahead at 11,316' @ report time. June 12, 2017 Drilled ahead from 11,316' to 12,310' @ report time. June 13, 2017 Drilled ahead from 12,310' to 12,424'. Pulled out of hole for new bit due to low rate of penetration. At surface at report time. June 14, 2017 Ran in hole to bottom, washing/reaming the last few stands. Resumed drilling according to plan. Drilling ahead at 12,658' @ report time. June 15, 2017 Drilled ahead from 12,658' to 12,878'. Wiper trip to 11,020'. Ran in hole back to bottom and resumed drilling. Drilling ahead at 13,037'. June 16, 2017 Drilled ahead to 13,272'—low penetration rate. Circulated bottoms up then began pulling out of hole. Pulling out of hole at 5,084' @ report time. TBU M-06RD 5 June 17, 2017 Pulled out of hole to surface, laid down bottom hole assembly. Testing blow out prevention equipment @ report time. June 18, 2017 Completed blow out prevention equipment testing. Troubleshot new directional bottom hole assembly and began run back in hole. Running in hole at 6,560' @ report time. June 19, 2017 Ran back in hole to bottom with new bit & bottom hole assembly. Resumed drilling from 13,272' to 13,424'. Began wiper trip to 11,070' to rearrange posit ion of torque reducers. Running back to bottom @ report time. June 20, 2017 Ran in hole back to bottom. Drilled ahead from 13,424'. Drilling ahead at 13,890' @ report time. June 21, 2017 Drilled ahead to 13,922'—low penetration rate and sticking on bottom. Broke free and pulled out of hole to surface. At surface replacing bottom hole assembly@ report time. June 22, 2017 Drilled ahead from 11,316' to 12,310' @ report time. Replaced bit & bottom hole assembly, changing from rotary steerable to mud-motor with 1.22° bend. Ran back in hole. Worked tight spot @ 13,500’-13,600’. RIH at 13709' @ report time. June 23, 2017 Completed RIH to 13,922' and resumed drilling @ 01:40. Drilled ahead from 13,922' to 15,003'. Pulled out of hole 10 stands for short wiper trip then ran in hole back to 15,003'. Resuming drilling ahead right @ report time. June 24, 2017 Resumed drilling at 15,003' after wiper trip. Drilled to total depth (TD) @ 15,472'. Circulated bottoms up then began pulling out of hole. Pulling out at 3120' @ report time. June 25, 2017 Pulled out of hole, laid down bottom hole assembly, Ran back in hole with cleanout assembly. Slip & cut drill line at the window. Continue RIH to TD. Circulating at TD @ report time. June 26, 2017 Circulated bottoms up at TD then pulled out of hole to window, working tight spot @ 12,700'. Ran back in hole to TD. Circulating at TD @ report time. June 27, 2017 Pulled out of hole to window, pumped dry job, completed pulling out of hole & laid down bottom hole assembly (cleanout assembly). Rig up and run 7" liner. Running 7" liner near 600' @ report time. June 28, 2017 Continued running liner to window. Circulated & conditioned mud, got parameters with drive sub. Continued running liner into open hole to hanger & packer assembly. Make up hanger & packer assembly as per Baker rep. Continued running liner into open hole on drill pipe from derrick. Currently running in at 9400' @ report time. TBU M-06RD 6 June 29, 2017 Continued running liner in open hole to TD, final value TBD. Circulated & conditioned mud for cement job. Rigged up cementers. Pumped cement job. Had trouble setting packer. Circulated 2x bottoms up, washed up coal cuttings. Rig down cementers. Pumped dry job, detached drill pipe from liner top and pulled drill pipe out of hole. Laying down Baker running tool @ report time. June 30, 2017 Checked running tool—good. Changed out lower rams to VBR and tested. Picked up casing scraper bottom hole assembly and singled in on 4" DP to 4,172'. Pick up second 7" scraper. Running in hole a t 4,172' @ report time. July 1, 2017 Tripped in hole with scraper; casing pressure test. Rig down Canrig Mudlogging unit. TBU M-06RD 7 TBU M-06RD 8 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 8,556 7,057 -6,897 7,279’ 4,880’ -4,720’ Coal-39 11,383 8,644 -8,484 11,364’ 8,653’ -8,493’ H1X FW 11,828 9,035 -8,875 11,784’ 9,030’ -8,870’ Coal-59 11,876 9,073 -8,913 11,632’ 8,898’ -8,738’ HTKE-FW 11,888 9,082 -8,922 11,849’ 9,084’ -8,924’ HTK2 11,932 9,116 -8,956 11,892’ 9,119’ -8,959’ WF 1 13,084 9,638 -9,478 12,966’ 9,629’ -9,469’ WF 2 13,959 9,744 -9,584 13,562’ 9,718’ -9,558’ WF 3 15,269 9,882 -9,722 14,796’ 9,827’ -9,667’ TD 15,595 9,916 -9,756 15,472’ 9,911’ -9,751’ TBU M-06RD 9 3.2 Lithology Details Lithology descriptions of all Kenai Group and Cenozoic 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 diversity 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. TBU M-06RD 10 3.2.1 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 tr ace 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. 7,279’ to 11,784' MD (-4,720' to -8,870' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 452.7 0.11 134.2 510.6 1.6 50.9 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 7,432 4,972 239 61,457 0 0 0 0 0 0 7,466 4,994 178 47,870 0 0 0 0 0 0 7,549 5,049 251 65,035 0 0 0 0 0 0 7,710 5,163 130 35,712 0 0 0 0 0 0 7,942 5,346 130 25,010 0 0 0 0 0 0 8,062 5,450 135 36,043 0 0 0 0 0 0 8,197 5,572 198 53,500 0 0 0 0 0 0 8,252 5,623 251 65,146 0 3 0 0 0 0 8,408 5,771 221 59,700 0 4 0 0 0 0 8,475 5,836 294 77,358 0 6 0 0 0 0 8,582 5,941 177 46,463 0 4 0 0 0 0 8,771 6,124 247 65,610 0 8 0 0 0 0 8,880 6,231 161 42,385 0 8 0 0 0 0 9,110 6,455 223 61,742 0 0 0 0 0 0 9,231 6,573 158 43,255 0 9 0 0 0 0 9,356 6,694 282 77,112 0 17 0 0 0 0 9,600 6,932 306 81,817 0 16 0 0 0 0 9,692 7,022 234 61,538 0 15 0 0 0 0 10,078 7,396 214 57,302 0 15 0 0 0 0 10,159 7,475 391 105,583 0 41 4 0 0 0 10,382 7,692 444 120,933 0 23 0 0 0 0 10,452 7,760 278 68,141 0 16 0 0 0 0 10,558 7,864 226 60,262 0 21 0 0 0 0 10,650 7,954 292 78,921 0 23 0 0 0 0 10,696 8,000 228 62,321 462 68 0 0 0 0 10,716 8,019 202 56,686 0 16 0 0 0 0 10,830 8,133 193 53,867 0 29 0 0 0 0 11,012 8,313 262 65,519 324 46 0 0 0 0 11,338 8,628 511 132,889 0 28 0 0 0 0 TBU M-06RD 11 Tuffaceous Claystone / Tuffaceous Siltstone (7340'-7390') = light gray to pinkish gray; mushy, clotted, crumbly; hydrophilic, very slightly cohesive; slightly adhesive; no fracture; massive cuttings; dull, earthy luster; matte to silty textures; inter-bedded with tuffaceous sand/sandstone. Sand / Sandstone (7390'-7450') = medium to medium light gray, occasional yellowish gray; lower medium to upper fine grained, common upper to lower clast size; angular to sub-angular to sub-round; moderate sphericity; moderate to well sorted; impact to pitted texture mature nature; non to very weak siliceous cement; dominant grain support; appears arenaceous; clean; good estimated porosity and permeability; no hydro-carbon indicators. Coal (7450’-7500') = 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. Carbonaceous Shale (7500'-7480') = black to some mottled grayish black; firm to hard; overall resinous luster with some earthy laminations; matte texture; sub-planar to hackly fracture; often inter-bedded with coal; no odor or sample fluorescence; no oil indicators. Tuffaceous Clay (7480'-7590') = pale yellowish brown to pinkish gray; very soft; lumpy to clumpy; clustered to clotted; very hydrophilic; non to very slight cohesive; slightly adhesive; amorphous fracture; earthy luster; ashy texture; massive gradation clay and silt abundant coal cavings. Sand (7590'-7660') = 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; some local grain support; composed of 90% quartz, 10% lithic fragments; fair to poor to poor porosity and permeability. Sand / Tuffaceous Clay (7660'-7720') = pale yellowish brown to medium gray fine to medium grained sand; quartz-dominated with lesser black lithics and cream -colored feldspars; and occasional very coarse grains of clear -iridescent blue subhedral quartz; poor to fair sorting; sub-angular to rounded; interspersed with firm angular clasts of light brown tuffaceous claystone. Coal / Tuffaceous Siltstone (7720'-7750') = coal fragments of varying size interspersed with light to medium brown sub-angular clasts of tuffaceous siltstone. Tuffaceous Claystone / Tuffaceous Siltstone (7750'-7830') = medium brown to medium gray firm subangular clumps of tuffaceous claystone and siltstone; some brown/black micro -bedding; smaller percentages of fine-grained salt-and-pepper colored quartz-dominated sand-stone; occasional millimeter- scale inter-bedding of siltstone and fine-grained sandstone. Coal / Tuffaceous Claystone (7830'-7860') = coal dominated; with lesser firm angular fragments of medium brown tuffaceous claystone and silt-stone; and minor fine to medium-grained tuffaceous sandstone; and very minor very coarse sand sized to granule sized sub-rounded clasts of quartz. Sand / Tuffaceous Sandstone (7860'-7940') = pale yellowish gray to salt and pepper colored coarse grained sand and grain-supported clumps of medium-grained tuffaceous sandstone; quartz-dominated with lesser black and cream-colored lithics; fair sorting; sub-rounded; moderate to high sphericity; minor sub-angular clumps of light brown tuffaceous siltstone with occasional blown/black wavy micro-bedding; siltstone content increasing downward. TBU M-06RD 12 Coal / Tuffaceous Siltstone (7940'-8030') = coal inter-bedded with light gray to dark gray firm to friable sub-angular clumps of tuffaceous siltstone and claystone; and lesser salt -and-pepper colored fine to medium grained tuffaceous sandstone; silt/claystone has occasional wavy black/brown laminations and millimeter scale alternating beds of silt-stone and fine-grained quartz-rich sandstone; very occasional individual sub-rounded to rounded quartz grains up to granule conglomerate sized; clear to iridescent blue in color. Tuffaceous Claystone / Tuffaceous Siltstone (8030'-8100') = light gray to dark gray firm to friable sub- angular clumps of tuffaceous claystone and siltstone; flaky habit; dull to shiny luster; clayey texture; with some minor coal clasts and coarse sand to granule conglomerate sized sub-rounded quartz grains; some silt-stone/sandstone inter-bedding and wavy black/brown laminations; tuffaceous sandstone content increasing gradationally downward. Tuffaceous Sandstone / Sand (8100'-8180') = olive green to pale yellowish brown tuffaceous siltstone and medium-grained tuffaceous sandstone; clay-supported with sub-equal proportions of quartz and black and pink lithics; fair to well sorted; sub-rounded; moderate to high sphericity; grades downward into cleaner, better-sorted sand; medium to coarse grained; rich in clear to blue quartz and translucent tan feldspar; with lesser black lithics; sub-angular to rounded; moderate sphericity. Coal / Tuffaceous Siltstone / tuffaceous claystone (8180'-8260') = fragments of coal interspersed with firm to fragile rounded to sub-angular shiny chunks of light to medium gray tuffaceous claystone and clay- supported tuffaceous siltstone; occasional medium to very coarse sand sized sub-angular to sub-rounded particles of clear to light blue quartz and smoky tan colored feldspar; sand content varies vertically; sand is poor to fairly sorted. Sand / Tuffaceous Sandstone (8260'-8340') = buff to light gray medium to coarse grained sand; dominated by clear to smoky colored quartz with lesser black, pink, and brown lithics; poor to fair sorting; angular to rounded; moderate sphericity; with some larger rounded black and tan clasts of fine to medium grained tuffaceous sandstone; and minor massive medium gray sub-angular clasts of tuffaceous siltstone; very minor coal fragments and individual grains of quartz up to granule conglomerate sized. Sand / Coal (8340'-8420') = fragments of coal interspersed with tan to light gray sand consisting of sub- equal proportions of clear to light blue quartz and creamy feldspar; with minor black and red lithic grains; lower medium to upper coarse grained; fair sorting; angular to subrounded; moderate sphericity; also friable sub-rounded clumps of clay supported fine to medium grained quartz-rich tuffaceous sandstone; minor flaky chunks of medium gray tuffaceous siltstone and claystone. Coal / Tuffaceous Siltstone (8420'-8500') = conchoidal fragments of coal of varying sizes mixed with light to medium gray sub-angular firm to friable clasts of tuffaceous siltstone and claystone; some showing light to dark gray wavy inter-bedding; also subrounded to rounded olive colored clasts of fine to medium grained tuffaceous sandstone, dominated by clear quartz and milky feldspar grains; and minor angular to sub-rounded individual grains of quartz, coarse sand to granule conglomerate sized, clear to blue translucent colored. Tuffaceous Sandstone / Sand (8500'-8590') = medium light gray to light gray with light greenish gray secondary hues; very coarse upper to fine upper, mostly medium upper to medium lower; trace to 10% in very coarse range, mostly angular bit-broken; very poor sorting; very angular to sub rounded; low to moderate sphericity; bit impacted coarser to sub-rounded finer grains; sub-mature; mostly tuffaceous hydrophilic clay cement; dominant grain support; trace local matrix support; predominantly quartz; becoming generally coarser with depth; overall fair to good estimated porosity and permeability; no oil odor, fluorescence or other oil indicators. TBU M-06RD 13 Coal (8590'-8640') = 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. Conglomerate Sandstone / Sand (8640'-8740') = light gray to medium light gray with light greenish gray and light olive gray secondary hues; very coarse upper to fine lower grained, mostly coarse lower to medium upper; scattered to abundant very coarse clear to white quartz and medium gray clasts; very angular to angular to sub-rounded, occasionally nodular, mostly sub-angular to angular; abundant bit impact; very poor sorting; low to moderate sphericity; sub-mature nature; some very light gray hydrophilic tuffaceous clay matrix; some hard siliceous cement; overall fair to good estimated porosity and permeability; no oil odor, fluorescence or other oil indicators. Coal / Carbonaceous Shale (8740'-8800') = black to grayish black; mottled dark yellowish brown carbon clays in micro-laminations; firm in coals to soft in clays; resinous mottled earthy lusters; hackly coal fracture to sub-planar carbon clay fracture; composed of sub-bituminous to lignitic coal with micro laminae of very carbon clay and shale; no oil odor, fluorescence or other oil indicators. Sand / Tuffaceous Sandstone (8800'-8880') = buff to light gray medium to coarse grained sand; dominated by clear to smoky colored quartz with lesser black, pink, light blue, and brown lithic fragments; poor to fair sorting; angular to rounded; moderate sphericity; with some larger rounded black and tan clasts of fine to medium grained sand-stone; and minor massive medium gray sub-angular clasts of tuffaceous siltstone; very minor coal fragments and individual grains of bit broken quartz up to granule conglomerate sized. Coal (8880'-8930') = 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 oil indicators. Tuffaceous Siltstone (8930'-9000') = buff to light gray medium to pinkish gray; very poor to poorly indurated; clustered to clotted consistency; mushy to pasty; tack y to slimy; non to slightly cohesive; moderately adhesive; hydrophilic; sub-earthy to amorphous fracture; massive cuttings habit; PDC bit buttercurl cuttings observed; moderate earthy luster; silty to clayey ashy texture; inter -beds and grades with tuffaceous claystone; inter-beds with coals and carbonaceous shale; no petroleum odor or sample fluorescence; no oil indicators. Siltstone / Tuffaceous Claystone (9000'-9070') = moderate olive brown to light to medium olive gray; moderately hard to moderately soft; irregular to earthy fracture; sub-tabular to common PDC style cuttings; dull earthy luster, occasionally sub-waxy; moderately clayey to silty texture; occasional carbonaceous material in siltstone; no petroleum odor over oil based mud; no petroleum odor or sample fluorescence; no oil indicators. Coal / Carbonaceous Clay and Silt (9070'-9130') = black mottled grayish brown; firm becoming hard in larger fragments; earthy mottled resinous luster; matte to silty in carbon clay; sub-planar to sub-tabular fracture along shale partings; composed of micro laminations of coal and very carbon clay and silt; grading to tuffaceous siltstone; no petroleum odor or sample fluorescence; no oil indicators. Conglomerate Sandstone / Sandstone (9130'-9240') = light to medium light gray with light greenish gray and light olive gray secondary hues; coarse lower to fine upper, mostly medium upper to medium lower; scattered to abundant very coarse to pebble sized clear to white; often bit broken quartz and medium gray nodular clasts; very angular to angular to sub-rounded, mostly sub-angular; abundant bit TBU M-06RD 14 impact; poor sorting; moderate sphericity; locally common very light gray ashy clay hydrophilic and soluble in-fill/cement; occasional trace to scattered siliceous zones; predominantly grain supported; composition is 95% quartz, 5% lithics; overall fair to good porosity and permeability; no oil odor, fluorescence or other oil indicators. Coal (9240'-9290') = dominantly black to brownish black; tough to brittle tenacity, occasionally crumbly; irregular, splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub-platy cuttings habit; greasy to waxy luster; abrasive texture; no petroleum odor or sample fluorescence above oil based drilling fluid; no other oil indicators. Conglomerate Sandstone / Sandstone (9290'-9400') = light to medium light gray, light greenish gray and light olive gray secondary hues; coarse lower to fine upper, mostly medium upper to medium lower; scattered to abundant very coarse to pebble sized clear to white; often bit broken quartz and medium gray nodular clasts; very angular to angular to subrounded, mostly sub -angular; abundant bit impact; very poor sorting; moderate sphericity; locally common very light gray ashy clay hydrophilic and solub le in- fill/cement; occasional trace to scattered siliceous zones; predominantly grain supported; composition is 95% quartz, 5% lithics; overall fair to good porosity and permeability; no oil odor, fluorescence or other oil indicators; often inter-bedded with thin coal seams. Tuffaceous Siltstone (9400'-9450') = pinkish gray to light to medium gray; very poor induration; lumpy to clumpy to clotted consistency; slightly mushy to pasty; slightly to moderately cohesive; moderate to good adhesiveness; amorphous to sub-earthy fracture; sub-nodular to massive habit; earthy luster; silty to ashy texture; hydrophilic; no oil odor, fluorescence or other oil indicators; often inter-bedded with thin coal seams. Sand / Tuffaceous Sandstone (9450'-9500') = golden brown to light olive gray sub-rounded soft to firm clasts of fine to medium grained tuffaceous sandstone and associated individual medium to very coarse sized sand grains; primarily quartz but black lithics increasing downward; poor to fair sorting; sub -angular to rounded; moderate to high sphericity. Tuffaceous Sandstone / Tuffaceous Siltstone (9500'-9550') = light olive gray to dark gray firm to friable sub-angular clasts of massive tuffaceous siltstone and sub-rounded clasts of fine to medium grained quartz-rich tuffaceous sandstone; fair sorting; sub-angular to rounded grains in a clayey matrix; with silt- stone content increasing downward; and occasional coal fragments. Tuffaceous Sandstone (9550'-9600') = buff to olive gray colored rounded to sub-angular clasts of fine to medium grained, quartz-dominated tuffaceous sandstone with clayey matrix; and lesser massive friable sub-angular chunks of tuffaceous siltstone; and minor sub-rounded to angular individual clear to smoky quartz grains up to granule conglomerate sized. Tuffaceous Sandstone / Tuffaceous Siltstone / Tuffaceous Claystone (9600'-9650') = tawny to dark gray friable to firm fragments of tuffaceous claystone and siltstone with some wavy laminations; and sub - rounded clasts of fine to very fine grained clay-supported tuffaceous sandstone dominated by clear quartz and creamy feldspar. Coal / Tuffaceous Sandstone (9650'-9700') = fragments of coal inter-bedded with fine to medium grained tuffaceous sandstone, rich in subhedral quartz and tawny feldspar; and olive gray to dark gray friable clasts of tuffaceous siltstone and claystone. Tuffaceous Claystone / Tuffaceous Siltstone (9700'-9760') = olive gray to pale yellow brown firm to soft clumps of tuffaceous claystone and siltstone; some showing black/brown micro-bedding; lesser clasts of black and tan fine grained tuffaceous sandstone dominant in quartz and cream colored feldspar; minor coal fragments. TBU M-06RD 15 Tuffaceous Claystone / Sand (9760'-9820') = light gray to dark gray firm to friable nodules of varying size, of tuffaceous claystone, siltstone, and lesser clay-supported fine grained creamy feldspathic arenite; some coal clasts showing fine inter-bedding with fine grained quartz-rich sandstone; also quartz- dominated sub-rounded to very angular fine to lower coarse sand grains which increase in content downward. Sand (9820'-9880') = tan to medium gray quartz-dominated sand, lower medium to upper coarse grained; with minor milky feldspar and black lithics; fair sorting; angular to subrounded; moderate spher icity; with larger fragile sub-rounded clasts of fine to medium grained quartz-rich tuffaceous sandstone; and subangular clasts of olive gray tuffaceous claystone and siltstone, occasionally with planar laminations present; no visible cut or odor. Sand (9880'-9950') = 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 subrounded; with small clusters of f ine to medium-grained tuffaceous sandstone and larger fragile clumps of tuffaceous claystone and siltstone; minor conchoidally fractured coal fragments. Tuffaceous Siltstone / Tuffaceous Claystone (9950'-10000') = tawny to medium gray soft angular clumps of tuffaceous claystone and laminar tuffaceous siltstone; with lesser fragments of quartz/feldspar rich fine to medium grained tuffaceous sandstone. Sand / Tuffaceous Siltstone / Coal (10000'-10100') = pale yellowish brown to olive gray quartz- dominated sand, medium grained; with minor black, pink, and orange lithic grains and occasional blue quartz grains up to conglomerate sized; fair to well sorted; subangular to rounded; with larger sub- rounded chunks of fine to medium grained tuffaceous sandstone and large subangular laminar chunks of tuffaceous claystone and siltstone, frequently with black/grey/brown micro -bedding visible; sand content decreases downward; with coal dominant at 10080'. Tuffaceous Siltstone / Coal (10100'-10180') = light to medium gray large subangular clumps of tuffaceous siltstone, with earthy luster and some planar laminations; minor clumps of clay supported fine to medium grained tuffaceous sandstone rich in clear quartz and milky feldspar; abundant coal near 10110'. Siltstone / Tuffaceous Claystone (10180’-10250') = moderate olive brown to light to medium olive gray; moderately hard to moderately soft; irregular to earthy fracture; sub-tabular to common PDC bit buttercurl cuttings observed in claystone pieces; dull earthy luster, occasionally sub-waxy; moderately clayey to silty texture; occasional carbonaceous material in siltstone; no oil odor, fluorescence or other oil indicators; often inter-bedded with thin coal seams. Tuffaceous Siltstone (10250'-10310') = 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 inter-bedded with thin coal seams. Coal (10310'-10370') = 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 hydro-carbon indicators. Conglomerate Sandstone / Sand (10370'-10480') = light gray to medium light gray with light greenish gray and light olive gray secondary hues; coarse lower to fine upper, mostly medium upper to medium lower; scattered to abundant very coarse to pebble sized clear to white often bit broken quartz grains; very angular to angular to sub-rounded, occasionally nodular, mostly subangular; abundant bit impact; TBU M-06RD 16 poor sorting; moderate sphericity; locally common very light gray to almost white ashy clay hydrophilic and soluble infill; also occasional trace to scattered siliceous zones; predominantly grain supported; composition is 95% quartz, 5% lithic fragments; overall fair to good porosity and permeability; no oil odor; no fluorescence over oil based mud or other indicators. Tuffaceous Siltstone (10,480'-10,530') = pale yellowish brown; poor induration; brittle; hydrophilic; amorphous to sub-earthy fracture; amorphous to sub-platy cuttings habit; slight visible fracture; ashy to silty texture; trace to occasion -ally common off white to gray ash in sample; no oil indicators; often inter- bedded thin coal seams. Coal (10530'-10580') = 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 oil indicators. Sand / Conglomeratic Sand (10580'-10660')= dominantly light olive gray, transitions to slightly higher lightness values with light gray to medium light gray as a secondary hue; very fine upper to very coarse; fines upward; nearly all disaggregated; apparent soluble tuffaceous matrix; dominantly very angular to angular to subangular, but som e scattered subrounded; equant subspherical shape; predominantly quartz, trace to 10% lithic fragments; often interbedded with thin coal seams; no petroleum odor or sample fluorescence; no other hydrocarbon indicators. Tuffaceous Siltstone (10,660'-10,710') = pale yellowish brown; poor induration; brittle; hydrophilic; amorphous to sub-earthy fracture; amorphous to sub-platy cuttings habit; slight visible fracture; ashy to silty texture; trace to occasionally common off white to gray ash in sample; no oil indicators; commonly interbedded with thin coal seams. Sand (10710'-10770') = 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; poor to fair sorting; angular to rounded; low to high sphericity; with larger subrounded nodules of consolidated salt -and-pepper tuffaceous sandstone; fine to medium grained; and subangular fragments of tuffaceous siltstone often showing black/brown fine planar laminations; minor coal fragments. Tuffaceous Sandstone / Coal (10770'-10830') = olive gray to dark gray firm subrounded nodules of varying size, of quartz rich fine to medium grained tuffaceous sandstone with abundant black lithic minerals and clayey matrix; fair sorting; subangular to rounded; moderate to high sphericity; also numerous individual loose sand grains, most commonly quartz, ranging in size from medium sand to conglomerate sized; occasional subangular fragments of microbedded gray tuffaceous siltstone; numerous coal fragments. Coal / Tuffaceous Siltstone (10830'-10880') = numerous coal fragments of all sizes interspersed with firm to fragile sub-rounded nodules of medium gray salt and pepper tuffaceous sandstone; with sub -equal proportions of clear to smoky quartz and black lithics and minor feldspar content; fine to medium grained; subangular to subrounded; fair sorting; minor individual sub-rounded to subangular sand grains mostly quartz, ranging from coarse sand to granule sized; and soft subangular clumps of gray/brown tuffaceous siltstone/claystone. Coal / Tuffaceous Sandstone (10880'-10970') = numerous coal fragments of all sizes interspersed with firm to soft nodules of light to medium gray clay supported tuffaceous sandstone; quartz dominated; very fine to medium grained; with scattered granule sized individual clear and blue subrounded quartz grains; quartz rich medium to coarse grained sand content decreasing downward; lesser clumps of tuffaceous siltstone with some showing bedding. TBU M-06RD 17 Coal / Tuffaceous Sandstone (10970'-11070') = abundant conchoidal and blocky coal fragments of varying size; subrounded; medium gray nodules of medium to coarse grained tuffaceous sandstone with some clayey matrix; mostly quartz and cream colored feldspar, with minor black lithics; loose sand grains whose abundance varies vertically; also dominated by quartz but grain size up to granule; minor grey tuffaceous siltstone clasts; dull cut fluorescence in tuffaceous sandstone clasts. Sand / Tuffaceous Sandstone (11070'- 11140') = light olive gray to medium gray quartz dominated sand with lesser tan feldspar and minor lithic grains; fine to coarse grained; poor to fair sorting; subangular to rounded grains; with abundant firm rounded nodules of consolidated clay supported tuff aceous sandstone, also quartz rich; upper fine to lower coarse grained; moderate sorting; subangular to rounded grains; and angular clasts of laminated tuffaceous siltstone; loose sand content decreasing downward. Tuffaceous Sandstone / Sand (11140'- 11200') = medium gray to medium brown subrounded firm nodules of clay supported tuffaceous sandstone; quartz-dominated; fine to medium grained; fair sorting; subangular to subrounded; with abundant loose sand particles of same mineralogy, but grain size up to coarse sand; poorly sorted; subrounded; minor fragments of coal and brown tuffaceous siltstone. Sand / Coal (11200'-11280') = light gray to dark gray quartz and feldspar rich sand, upper fine to lower coarse grained; poor to fair sorting; subrounded to rounded; with abundant coal flakes and fragments throughout; numerous firm rounded nodules of quartz-rich clay-supported medium grained tuffaceous sandstone; and angular fragments of tuffaceous siltstone; with minor firm angular blocks of light cream colored tuffaceous claystone. Sand (11280'-11360') = light olive gray to medium gray sand, quartz dominated with lesser tan feldspar and black lithics; upper fine to lower coarse; poor to fair sorting; subrounded to rounded; moderate to high sphericity; with occasional rounded clusters of fine to medium grained tuffaceous sandstone of same mineralogy; with clayey matrix; occasional fibrous or conchoidal fragments of laminated gray tuffaceous siltstone. Note: Coal 39 was from 11,364’ to 11,385’ MD (-8,493’ to -8,512’ TVDSS) Coal / Tuffaceous Sandstone (11360'- 11420') = abundant blocky and conchoidal coal fragments of varying size interspersed with sub-equal quantities of medium gray laminated tuffaceous siltstone fragments and firm rounded nodules of quartz-rich fine to medium grained tuffaceous sandstone. Sand / Tuffaceous Sandstone (11420'- 11510') = light gray to medium gray sand, rich in clear quartz and white to tan feldspar, with minor black lithics; upper fine to upper coarse grained; poor to fair sorting ; subangular to rounded; with soft clumps of fine to medium grained tuffaceous sandstone of same mineralogy; and creamy to gray subangular nodules of tuffaceous siltstone; no visible fluorescence or odor. Sand (11510'-11570') = tan to medium gray quartz dominant sand, upper fine to upper coarse grained; fair sorting; angular to rounded; with abundant coal fragments of varying size; and fragile clumps of fine to medium grained tuffaceous sandstone also quartz dominant; and angular fragments of tuffaceous siltstone showing occasional planar laminations. Sand / Conglomerate Sand / Conglomerate (11570'-11660') = light olive gray with light medium gray as secondary hue; very fine lower to conglomerate sized granule; mostly fine upper to medium upper grained, but large portion coarse to conglomerate; moderately to poorly sorted; dominantly angular to subangular with some very angular and some subrounded; poor to very poor sphericity; 90% quartz, 10% lithic fragments; interbedded with tuffaceous siltstone; slightl y to moderately calcareous; petroleum odor masked by oil based mud; trace dull yellow sample fluorescence over oil based mud; moderately dull yellow cut fluorescence. TBU M-06RD 18 Note: Coal 59 was from 11,632’ to 11,669’ MD (-8,738’ to -8,770’ TVDSS) Coal (11660' - 11730') = grayish black to brownish black, olive black, black; moderately hard to hard; tough, occasionally slightly brittle tenacity; irregular to sub-planar fracture; occasionally blocky, sub- conchoidal; sub-platy to wedge-like cuttings habit; sub-flaky to scattered sub-bladed; overall sub-greasy to sub-earthy luster; matte to abrasive texture; ranging from dominantly sub-bituminous to bituminous; non-calcareous; oil indicators masked by oil based drilling fluid. Conglomerate Sand (11730'-11860') = overall light to medium olive gray to light olive brown; dominantly milky, sub-transparent to transparent, white to off white individual grains, scattered light to medium green; trace scattered red to red-orange; dominantly upper coarse to lower coarse, scatter ed upper medium to occasionally subgranular sized fragments; very poorly to poorly sorted; dominantly very angular to angular, rare subangular to subrounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert-like texture; petroleum odor masked by oil based mud; moderately fast yellow streaming fluorescence; dull yellow moderately weak cut fluorescence; dark straw to light brown vi sible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. TBU M-06RD 19 3.2.2 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. Individual clasts are often spherical to sub-discoidal with sub rounded to rounded, and rarely, subangular grains. Typically grains are well to moderately well sorted and either appear completely unconsolidated or occur in very fragile clusters. 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 faces. Black and green mafic 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. They often display poor to moderate sorting, 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. 3.2.3 Hemlock H1X_FW 11,784’ to 11,849' MD (-8,870' to -8,924' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 210.8 11.3 80.8 77.0 12.0 24.1 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Conglomerate Sand (11730'-11860') = overall light to medium olive gray to light olive brown; dominantly milky, sub-transparent to transparent, white to off white individual grains, scattered light to medium green; trace scattered red to red-orange; dominantly upper coarse to lower coarse, scattered upper medium to occasionally subgranular sized fragments; very poorly to poorly sorted; dominantly very angular to angular, rare subangular to subrounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert-like texture; petroleum odor masked by oil based mud; moderatel y fast yellow streaming fluorescence; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. TBU M-06RD 20 3.2.4 Hemlock HTKE-FW 11,849’ to 11,892' MD (-8,924’ to -8,959' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 124.7 6.7 87.3 36.0 14.0 18.2 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Carbonaceous Shale (11860'-11930') = black to brownish black to brownish gray as 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 cuttings; common PDC bit buttercurl cuttings; dull luster; matte texture; non-calcareous; very dull yellow to no fluorescence in shale pieces. Sand (11930'-11990') = very light gray to pale yellowish brown quartz dominated sand, with minor gray, tan, pink and black lithics; upper fine to upper coarse grained; fair sorting; subangular to rounded; moderate to high sphericity; with minor firm to soft tuffaceous sandstone clasts of same mineralogy; and occasional coal clasts; dull cut fluorescence. 3.2.5 Hemlock HK2T 11,892’ to 11,962' MD (-8,959’ to -9,011' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 293.9 6.1 103.6 89.0 12.0 34.3 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,913 9,134 89 17485 1488 844 111 219 45 44 Sand (11930'-11990') = very light gray to pale yellowish brown quartz dominated sand, with minor gray, tan, pink and black lithics; upper fine to upper coarse grained; fair sorting; subangular to rounded; moderate to high sphericity; with minor firm to soft tuffaceous sandstone clasts of same mineralogy; and occasional coal clasts; dull cut fluorescence. 3.2.6 Hemlock HK2T_LOWER 11,962’ to 12,127' MD (-9,011’ to -9,123' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 382.7 2.7 107.0 88.0 14.0 38.9 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks TBU M-06RD 21 Sand (11990'-12070') = light gray to pale yellowish brown clean quartz rich sand, with minor tawny feldspar and pink and black lithic grains; upper fine to upper coarse grained; fair sorting; subrounded to rounded; with occasional granule conglomerate sized quartz grains and sub rounded clusters of consolidated sandstone; showing moderate streaming fluorescence, dull yellow moderate cut fluorescence, light brown visible cut; also occasional sub -angular clasts of gray/black laminated tuffaceous siltstone. Sand (12070'-12150') = milky white to yellowish brown sand, dominated by quartz grains, with lesser white-tan feldspar and minor pink and black lithics; low clay content; some consolidated clusters; upper fine grained to upper coarse grained with a few conglomerate sized grains; f air sorting; subangular to rounded; moderate to high sphericity; some consolidated clusters show low to moderate cut and streaming fluorescence; minor larger subangular tuffaceous claystone clasts and coal fragments. 3.2.7 Hemlock HK3T 12,127’ to 12,229' MD (-9,123’ to -9,183' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 293.6 1.8 95.9 57.0 16.0 32.5 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand (12150'-12220') = light gray to medium gray sand, very rich in clear to blue quartz, with eggshell colored feldspar and lesser black, orange and pink lithics; upper fine to upper coarse grained with occasional conglomerate grains; fair sorting; subangular to rounded; moderate sphericity; with occasional firm consolidated sandstone clusters which produce moderate bright yellow streaming and cut fluorescence; and minor fragments of coal and laminated tuffaceous siltstone. 3.2.8 Hemlock HK4T 12,229’ to 12,374' MD (-9,183’ to -9,263' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 123.5 1.3 58.4 42.0 10.0 26.1 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand / Conglomerate (12220'-12310') = light olive gray to light olive brown sand, quartz dominant, with lesser cream to tan colored feldspar and very minor black lithics; upper fine to lower very coarse grained with some granule sized grains; poor to fair sorting; subangular to rounded; low clay content; occasional sub- angular fragments of coal and gray/ black laminated tuffaceous siltstone; some consolidated sandstone clusters showing moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. TBU M-06RD 22 Sand / Tuffaceous Siltstone (12310'- 12400') = tan to medium gray quartz/feldspar rich sand, upper fine to upper coarse grained with some conglomerate clasts; fair sorting; subangular to rounded; and occasional consolidated sandstone clusters of same mineralogy; sand content diminishing downward; medium gray tuffaceous siltstone fragments showing fine gray/black laminations and curved cuttings habit; siltstone content increasing downward. 3.2.9 Hemlock HK5T 12,374’ to 12,581' MD (-9,263’ to -9,359' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 215.1 1.2 72.7 67.0 5.0 25.5 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sand / Tuffaceous Sandstone (12400'- 12490') = light olive gray to medium gray, abundant in clear to blue quartz and tan feldspar with minor black lithic grains; upper fine to upper coarse grained to some conglomerate grains; fair sorting; sub-angular to rounded; with occasional consolidated sandstone clusters; minor subangular fragments of tuffaceous siltstone and coal; clusters show moderate light yellow streaming fluorescence and dull cut fluorescence. Sand (12480'-12560') = light gray to dark gray salt and pepper sand, subequal proportions of quartz, feldspar and black lithic grains; upper fine to very coarse grained with numerous conglomerate grains; poor sorting with larger clast sizes favoring quartz; sub-angular to subrounded; abundant coal fragments; minor fragments of gray tuffaceous siltstone; very few consolidated sandstone clusters. 3.2.10 Hemlock HK6T 12,581’ to 12,798' MD (-9,359’ to -9,424' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 242.6 1.2 96.2 84.0 6.0 28.8 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 12,587 9,520 84 17,836 863 511 87 136 32 31 Sand (12560'-12640') = light olive gray to pale yellow brown sand, quartz dominated with lesser t an feldspar and black lithic components; minor clay content; upper fine to upper coarse grained with a few conglomerate clasts; fair sorting; subangular to subrounded; moderate sphericity; scattered coal fragments of all sizes; minor firm subangular chunks of tuffaceous claystone and laminated tuffaceous siltstone; occasional consolidated sandstone clusters showing moderate streaming fluorescence and dull yellow cut fluorescence. TBU M-06RD 23 Sand / Tuffaceous Sandstone (12640'- 12740') = pale yellowish brown to dark gray sand, quartz- dominant; with lesser milky white and pink feldspar and black lithics; upper fine to very coarse grained with abundant conglomerate grains; poor to fair sorting with larger clasts predominantly quartz; sub- angular to subrounded; minor subangular fragments of tuffaceous siltstone and claystone; occasional consolidated sandstone clusters showing mild yellow streaming fluorescence and dull cut fluorescence and residual stain. Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone (12740'-12880') = very light gray; clast size pebble to very coarse upper to coarse lower; angular bit impacted fragments to sub- rounded; very poor to moderate developed sphericity; moderate sorting; polished to chip texture; mature nature; non to very weak siliceous cement; unconsolidated; dominant grain support; slight visible clay matrix; composed of predominantly quartz with some lithic fragments; fair to good porosity and permeability; moderate yellow streaming fluorescence; weak yellow cut fluorescenc e; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. 3.2.11 Hemlock HK7T 12,798’ to 12,966' MD (-9,424’ to -9,469' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 148.0 1.2 54.8 115.0 7.0 32.5 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 12,819 9,589 115 23,200 1534 962 111 265 54 62 11,861 9,600 83 16,311 1145 725 88 216 47 54 Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone (12740'-12880') = very light gray; clast size pebble to very coarse upper to coarse lower; angular bit impacted fragments to sub- rounded; very poor to moderate developed sphericity; moderate sorting; polished to chip texture; matur e nature; non to very weak siliceous cement; unconsolidated; dominant grain support; slight visible clay matrix; composed of predominantly quartz with some lithic fragments; fair to good porosity and permeability; moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. Tuffaceous Siltstone (12880'-12940') = light olive gray to medium gray firm to friable curved wedges of tuffaceous siltstone; planar habit; occasional fine light gray-dark gray laminations; and soft clumps of light gray tuffaceous claystone; minor fine to coarse grained subrounded sand grains throughout, mostly quartz; very minor consolidated sandstone clusters, no visible fluorescence. TBU M-06RD 24 3.2.12 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 sandst one 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. 3.2.13 West Foreland WFT 12,966’ to 13,562' MD (-9,469’ to -9,558' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 167.1 0.5 64.8 56.0 8.0 21.9 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 13,186 9,674 52 10,107 708 343 44 103 26 33 13,293 9,686 56 11,957 511 239 29 60 14 16 13,500 9,710 44 10,363 343 124 8 25 0 0 Tuffaceous Claystone (12940'-12990') = very pale gray soft subrounded clumps of massive claystone, occasionally with small angular black volcanic grains contained within; frosted luster; and lesser medium to dark gray subangular plated fragments of tuffaceous siltstone; minor fine sand grains mostly quartz; minor coal fragments of all sizes. Sand (12990'-13020') = olive gray to medium gray sand, quartz dom inant; with minor black lithic grains; upper fine to upper coarse grained; fair sorting; subangular to subrounded; with occasional large soft clumps of tuffaceous claystone and siltstone; sand (13020'-13120') = light olive gray to medium gray quartz dominated sand with minor tan colored feldspar and black lithics; minor clay content which varies vertically; upper fine to very coarse grained with occasional conglomerate clasts; fair sorting with larger clast sizes favoring quartz; subangular to subrounded; m oderate sphericity; minor larger fragments of platy tuffaceous siltstone and claystone; minor consolidated clusters of fine to medium grained sandstone of same mineralogy which shows moderate to fast light yellow streaming fluorescence and dull yellow cut. Tuffaceous Sandstone / Tuffaceous Siltstone (13120'-13240') = light olive gray to medium gray quartz rich sandstones; grain size is upper very fine to lower coarse; angular to sub -rounded; low to moderate sphericity; well to moderate sorting; sandstone nodules contain a volcanic ash that is white to bluish white in color and clumpy / soft texture; sample contains some black lithics, lower coarse to upper coarse in size, subrounded to rounded, with moderate sphericity; tuffaceous siltstone is light gray to medium gray, TBU M-06RD 25 quartz rich, lower very fine in size, very well sorted, firmly friable, subangular to rounded massive cuttings; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. Tuffaceous Sandstone / Tuffaceous Siltstone (13240'-13400') = light olive gray to medium gray quartz rich sandstones; grain size is upper very fine to lower medium; angular to subrounded; low sphericity; moderate sorting; sand nodules, upper coarse in size, rounded to well rounded; black lithics, lower medium to upper medium in size, subangular to subrounded, low sphericity; tuffaceous siltstone is light gray to medium gray, quartz rich, lower very fine, very well sorted, firmly friable, subangular; weak light yellow streaming fluorescence; weak yellow cut fluorescence; faint brown visible cut; weak bright yellow residual cut fluorescence. Tuffaceous Sandstone / Tuffaceous Siltstone (13400'-13540') = light olive gray to medium gray quartz rich sandstones; upper very fine to lower coarse grained; angular to subrounded; low to moderate sphericity; well to moderate sorting; sandstone pieces contain a volcanic ash that is off -white to blue- white in color and has a clumpy / very soft texture; sample contains some black lithics, lower coarse to upper coarse in size, subrounded to rounded with moderate sphericity; tuffaceous siltstone is light gray to medium gray, quartz rich, lower very fine in size, very well sorted, firmly friable, subangular to rounded massives; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. 3.2.14 West Foreland WF_2 13,562’ to 14,796' MD (-9,558’ to -9,667' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 525.8 0.2 123.9 72.0 4.0 25.4 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 13,681 9,730 51 10,396 597 323 51 88 19 24 13,774 9,739 54 11,324 682 432 66 122 28 27 13,822 9,743 72 15,862 727 456 87 135 35 37 14,130 9,768 61 13,323 597 357 57 98 25 23 Tuffaceous Siltstone / Volcanic Ash (13,540'-13,700') = tuffaceous siltstone is light gray to medium gray; quartz rich, lower very fine grained, very well sorted, firmly friable, angular to subangular to rounded massives; volcanic ash is light olive gray to medium olive gray in color, clay sized particulates, very well sorted, pulverulent tenacity, smooth texture, laminae structure; black lithics, lower medium to upper medium in size, subangular to subrounded, low sphericity; coal seam shows at 13,590' and is dominate, grayish black to black in color, angular to subangular in angularity, poorly sorted, conchoidal fracture, dense tenacity, dull luster; quartz sand nodules, light brown tan to medium brown tan in color, sub - rounded to rounded in shape, upper medium to upper coarse in size, well to moderately sorte d, moderate to high sphericity, silica cement; sands are light olive gray to medium olive gray, unconsolidated, poorly sorted, lower fine to lower medium in size, angular to subrounded; common to scattered yellow to yellow - green light sample fluorescence; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. TBU M-06RD 26 Tuffaceous Claystone / Sand (13700'- 13760') = light gray to dark gray curved and subangular firm fragments of massive tuffaceous claystone, rarely showing dark -light gray planar laminations and elongated sand sized clasts of black volcanic glass; minor unconsolidated sand grains throughout, varying vertically; mostly clear quartz; lower medium to lower coarse grained with rare grains as large as granule conglomerate; fair sorting; subhedral grains. Sand / Tuffaceous Claystone (13760'- 13860') = proportions of sand and claystone fluctuating with MD depth; sand is medium olive gray to dark gray; dominated by clear to smoky quartz with lesser tan feldspars and black lithics; abundant clayey matrix; upper fine to lower coarse grained; fair to well sorted; subangular to rounded; moderate to high sphericity; commingled with light gray to beige soft to firm curved and subangular fragments of massive tuffaceous claystone and lesser platy tuffaceous siltstone; some fragments showing light-dark gray planar laminations; consolidated sandstone clusters have moderate bright yellow streaming fluorescence; moderate yellow cut fluorescence; light to medium brown visible cut; weak to moderate yellow residual cut fluorescence. Sand (13860'-14010') = medium olive gray to dark gray quartz rich sand with lesser tan and black lithics and minor clayey matrix; upper fine to upper coarse grained with a few granule conglomerate sized clasts; fair sorting; subangular to subrounded; with minor coal fragments and platy angular chunks of dark gray tuffaceous siltstone and light gray tuffaceous claystone; a few consolidated sandstone clusters showing moderate to fast light yellow streaming fluorescence; moderate bright yellow cut fluorescence; dark straw to brown visible cut; weak to moderate yellow residual cut fluorescence. Sand / Tuffaceous Sandstone (14010' - 14130') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and occasional light green individual grains; upper fine to lower medium; dominantly quartz framework with rare micas and dark lith ic fragments; tuffaceous sandstone has white mushy clayey matrix, which also contains trace to 10% ash; friable to soft; crumbly tenacity; subangular to subrounded; moderate to moderately low sphericity; fair to poor sorting; non-calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand (14130'-14230') = medium olive gray to dark gray quartz-rich sand with lesser tan and black lithics and minor clayey matrix; upper fine to upper coarse grained with a few granule conglomerate sized clasts; fair sorting; subangular to subrounded; with minor coal fragments and platy angular chunks of dark gray tuffaceous siltstone and light gray tuffaceous claystone; trace to 10% off -white to light gray ash; rare consolidated sandstone clusters showing moderate to fast light yellow streaming fluorescence; moderate bright yellow cut fluorescence; dark straw to brown visible cut; weak to moderate yellow residual cut fluorescence; oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (14230' - 14350') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and occasional light green individual grains; upper fine to lower medium; dominantly quartz framework with rare micas and dark lithic fragments; tuffaceous sandstone has white mushy clayey matrix, which also contains trace to 10% ash; friable to soft; crumbly tenacity; subangular to subrounded; moderate to moderately low sphericity; fair to poor sorting; non-calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based drilling fluid. Tuffaceous Sandstone / Tuffaceous Siltstone / Sand (14350'-14480') = light olive gray to moderate olive brown; fragile massive clumps of clay-supported tuffaceous siltstone and fine to medium grained tuffaceous sandstone, with occasional medium to very coarse sand grains interspersed throughout, mostly quartz; minor coal particles; trace micas; intact sandstone clusters are predominantly quartz with TBU M-06RD 27 scattered lithic fragments; petroleum odor masked by oil based mud; trace oil staining; moderate to fair yellow streaming fluorescence; dull yellow-white moderate cut fluorescence; faint dark straw to light brown visible cut; faint brown to faint straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based drilling fluid. Sand / Tuffaceous Sandstone (14480' - 14600') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and trace lig ht green individual grains; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has a white mushy clayey matrix, which also contains trace to 10% off -white ash; friable to very friable to soft; crumbly tenacity; subangular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non-calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (14600' - 14710') = overall light brown to light olive gray, light olive brown; milky, transparent to translucent; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has a white mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub-angular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non - calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influ enced by oil based drilling fluid. Tuffaceous Claystone (14710'-14770') = light gray to medium olive gray fragile subangular clumps of massive tuffaceous claystone; waxy luster; lesser dark gray laminar fragments of tuffaceous siltstone; occasional sand grains strewn throughout, mostly subhedral quartz with lesser black lithics; grain size from medium sand to granule conglomerate with larger grain sizes favoring quartz. 3.2.15 West Foreland WF_3 14,796’ to 15,472' MD (-9,667’ to -9,751' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 600.7 2.1 148.6 48.0 7.0 26.8 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 15,381 9,898 49 9,809 878 389 44 102 25 35 Sand / Tuffaceous Sandstone (14770'- 14900') = medium olive gray to medium olive brown sand, dominated by clear to smoky quartz; with lesser tan, bluish white, and black lithics; minor clayey matrix; lower fine to upper coarse grained with a few quartz clasts up to granule conglomerate sized; poor to fair sorting; subangular to rounded with quartz grains showing most maturity; moderate to high sphericity; occasional subrounded friable clumps of light gray tuffaceous claystone; minor subangular firm planar fragments of dark gray tuffaceous siltstone; occasional consolidated sandstone clusters of same mineralogy with moderate to fast bright yellow streaming fluorescence; moderate bright yellow cut fluorescence; light brown to medium straw visible cut; brown residual cut ring; moderate yellow residual cut fluorescence; minor oil stain; oil indicators possibly masked or influenced by oil based drilling mud. TBU M-06RD 28 Sand / Tuffaceous Sandstone (14900'- 15000') = yellowish gray to medium gray sand dominated by clear to smoky quartz; with minor tan and black lithics and some clayey matrix; upper fine to coarse grained with some grains up to granule conglomerate; larger grains almost all quartz; fair sorting; sub - angular to rounded; abundant firm to soft rounded tuffaceous sandstone clusters of same mineralogy but fine-medium grained; lesser soft light gray clumps of tuffaceous claystone with fine embedded angular clasts of volcanic glass; sandstone clusters showing fast- moderate yellow streaming fluorescence; moderate bright yellow cut fluorescence; brown visible c ut; minor oil stain. Sand (15000'-15100') = light olive gray to medium gray sand dominated by clear to smoky quartz with minor tan and black lithics and varying levels of clayey matrix; lower medium to upper coarse grained with a few conglomerate quartz clasts; subangular to rounded; moderate sphericity; semiconsolidated sandstone clusters of same mineralogy; minor firm subangular dark gray fragments of tuffaceous siltstone and soft light gray tuffaceous claystone; moderate whitish yellow streaming and cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (15100' - 15240') = overall light brown to light olive gray, light olive brown; milky, transparent to translucent; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has an off -white, mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub-angular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non- calcareous; no petroleum odor above oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based drilling fluid. Sand (15240'-15340') = light olive gray to medium gray sand dominated by clear to smoky quartz with minor dusky brown and black lithics and varying levels of clayey matrix; lower medium to upper coarse grained, with a few conglomerate quartz clasts; subangular to rounded; moderate sphericity; semi - consolidated sandstone clusters of same mineralogy; minor firm subangular dark gray fragments of tuffaceous siltstone and soft, light gray tuffaceous claystone; m oderate whitish yellow streaming and cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Sand / Tuffaceous Sandstone (15340' - 15470') = overall light brown to light olive gray, light olive brown; milky, transparent to translucent; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has an off white, mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub-angular to subrounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non- calcareous; no petroleum odor above oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; m inor to trace oil stain; sandstone clusters showing fast-moderate yellow streaming fluorescence; oil indicators possibly masked or influenced by oil based mud. TBU M-06RD 29 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution A Washed and Dried Reference 7,279’ – 12,900’ 12,900’ – 15,472’ 30’ *15’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference 7,279’ – 12,900’ 12,900’ – 15,472’ 30’ *10’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Box 1: 7,279’ – 9,060’ Box 2: 9,060’ – 10,320’ Box 3: 10,320’ – 12,330’ Box 4: 12,330’ – 13,680’ Box 5: 13,680’ – 15,472’ *Note: 15’ samples were caught as the drill rate allowed; if the drilling rate was faster than 60’/hour, 30’ samples were caught. Most of the 15’ samples were from between 12,900’ and 13,500’. TBU M-06RD 30 4 DRILLING DATA 4.1 4.1 Surveys 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 0.0 100.0 0.46 161.57 100.00 -0.38 0.13 -0.34 0.46 200.0 0.24 141.70 200.00 -0.93 0.38 -0.81 0.25 300.0 0.40 263.49 300.00 -1.13 0.17 -1.06 0.56 400.0 0.26 288.30 399.99 -1.10 -0.40 -1.16 0.20 450.0 0.60 25.90 449.99 -0.83 -0.39 -0.89 1.37 455.0 0.62 26.49 454.99 -0.78 -0.37 -0.84 0.42 460.0 0.68 22.53 459.99 -0.73 -0.34 -0.79 1.50 465.0 0.80 16.24 464.99 -0.67 -0.32 -0.72 2.89 470.0 0.96 7.53 469.99 -0.59 -0.31 -0.65 4.16 475.0 1.12 358.29 474.99 -0.50 -0.30 -0.56 4.63 480.0 1.37 350.46 479.99 -0.39 -0.31 -0.45 6.04 485.0 1.65 344.73 484.99 -0.27 -0.34 -0.34 6.36 490.0 2.03 340.70 489.99 -0.11 -0.39 -0.20 8.02 495.0 2.40 339.22 494.98 0.07 -0.46 -0.04 7.49 500.0 2.88 337.80 499.98 0.28 -0.54 0.15 9.69 505.0 3.24 336.60 504.97 0.53 -0.64 0.37 7.31 510.0 3.51 337.21 509.96 0.80 -0.76 0.61 5.45 515.0 3.72 335.62 514.95 1.09 -0.89 0.86 4.65 520.0 3.86 336.41 519.94 1.39 -1.02 1.12 2.99 525.0 3.96 337.76 524.93 1.70 -1.15 1.40 2.72 530.0 4.09 336.73 529.92 2.03 -1.29 1.68 2.97 535.0 4.26 336.53 534.90 2.36 -1.43 1.97 3.41 540.0 4.45 335.28 539.89 2.71 -1.59 2.28 4.25 545.0 4.60 336.45 544.87 3.07 -1.75 2.59 3.52 550.0 4.72 337.23 549.86 3.44 -1.91 2.92 2.71 555.0 4.79 337.89 554.84 3.83 -2.07 3.26 1.78 560.0 4.89 337.74 559.82 4.22 -2.23 3.60 2.02 565.0 4.99 338.64 564.80 4.62 -2.39 3.95 2.53 570.0 5.06 339.15 569.78 5.02 -2.54 4.31 1.66 575.0 5.09 340.19 574.76 5.44 -2.70 4.68 1.94 580.0 5.17 341.54 579.74 5.86 -2.84 5.06 2.90 585.0 5.22 343.57 584.72 6.29 -2.98 5.45 3.81 590.0 5.27 345.19 589.70 6.73 -3.10 5.85 3.13 595.0 5.33 344.63 594.68 7.18 -3.22 6.26 1.58 TBU M-06RD 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) 600.0 5.40 346.96 599.66 7.63 -3.34 6.67 4.58 610.0 5.46 347.15 609.61 8.56 -3.55 7.52 0.63 620.0 5.44 350.06 619.57 9.49 -3.74 8.39 2.77 630.0 5.44 354.58 629.52 10.42 -3.86 9.27 4.28 640.0 5.45 353.49 639.48 11.37 -3.96 10.17 1.04 650.0 5.54 355.04 649.43 12.32 -4.06 11.08 1.74 660.0 5.55 356.60 659.39 13.28 -4.13 12.00 1.51 670.0 5.57 0.68 669.34 14.25 -4.15 12.94 3.96 680.0 5.55 357.37 679.29 15.22 -4.17 13.87 3.21 690.0 5.62 357.09 689.24 16.19 -4.22 14.81 0.75 700.0 5.70 358.77 699.20 17.18 -4.25 15.76 1.84 710.0 5.77 1.80 709.15 18.18 -4.25 16.74 3.11 720.0 5.84 359.86 719.09 19.19 -4.23 17.72 2.08 730.0 5.86 0.64 729.04 20.21 -4.23 18.72 0.82 740.0 6.05 7.69 738.99 21.24 -4.15 19.74 7.55 750.0 6.23 9.24 748.93 22.30 -3.99 20.81 2.45 760.0 6.38 10.19 758.87 23.38 -3.81 21.90 1.83 770.0 6.50 11.38 768.81 24.48 -3.60 23.02 1.79 780.0 6.80 9.73 778.74 25.62 -3.39 24.18 3.56 790.0 7.13 8.60 788.67 26.82 -3.19 25.39 3.57 800.0 7.30 8.64 798.59 28.06 -3.00 26.64 1.70 810.0 7.53 8.40 808.50 29.34 -2.81 27.93 2.32 820.0 7.91 10.56 818.41 30.66 -2.59 29.27 4.78 825.0 8.19 10.97 823.36 31.35 -2.46 29.97 5.72 850.0 8.80 12.37 848.09 34.96 -1.71 33.66 2.58 875.0 9.42 13.89 872.77 38.82 -0.81 37.62 2.66 900.0 9.85 14.76 897.42 42.87 0.22 41.80 1.82 925.0 10.56 15.98 922.03 47.14 1.40 46.23 2.97 950.0 11.43 16.11 946.57 51.73 2.72 50.99 3.48 975.0 12.26 17.69 971.03 56.63 4.21 56.11 3.56 1,000.0 13.00 19.03 995.43 61.82 5.94 61.55 3.18 1,025.0 14.12 19.62 1,019.73 67.35 7.88 67.38 4.51 1,050.0 14.99 20.23 1,043.93 73.26 10.02 73.62 3.53 1,075.0 15.93 20.47 1,068.02 79.51 12.34 80.23 3.77 1,100.0 16.71 20.76 1,092.02 86.08 14.81 87.19 3.14 1,125.0 17.71 20.63 1,115.90 93.00 17.42 94.53 4.00 1,150.0 18.51 20.67 1,139.66 100.27 20.16 102.23 3.20 1,175.0 19.32 20.20 1,163.31 107.87 22.99 110.27 3.30 TBU M-06RD 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) 1,200.0 20.36 19.93 1,186.82 115.84 25.90 118.69 4.18 1,225.0 21.19 19.39 1,210.20 124.19 28.89 127.50 3.41 1,250.0 21.92 19.31 1,233.45 132.85 31.93 136.63 2.92 1,275.0 22.93 19.13 1,256.56 141.86 35.07 146.12 4.05 1,300.0 23.74 19.04 1,279.51 151.22 38.31 155.97 3.24 1,325.0 24.49 18.42 1,302.33 160.89 41.58 166.13 3.17 1,350.0 24.94 18.31 1,325.04 170.81 44.88 176.54 1.81 1,375.0 25.21 18.32 1,347.69 180.87 48.21 187.09 1.08 1,400.0 25.33 18.09 1,370.29 191.01 51.54 197.72 0.62 1,425.0 25.47 18.01 1,392.88 201.20 54.86 208.41 0.58 1,450.0 25.63 17.75 1,415.43 211.46 58.17 219.15 0.78 1,475.0 26.31 17.40 1,437.91 221.90 61.48 230.07 2.79 1,500.0 26.86 17.09 1,460.26 232.59 64.80 241.23 2.27 1,525.0 27.43 17.05 1,482.51 243.49 68.14 252.61 2.28 1,550.0 28.27 16.58 1,504.61 254.67 71.52 264.26 3.47 1,575.0 29.25 15.98 1,526.53 266.22 74.89 276.27 4.09 1,600.0 29.85 15.72 1,548.28 278.08 78.26 288.59 2.45 1,625.0 30.48 15.94 1,569.89 290.16 81.69 301.13 2.56 1,650.0 31.34 16.14 1,591.34 302.50 85.24 313.96 3.46 1,675.0 32.02 16.43 1,612.62 315.11 88.92 327.07 2.79 1,700.0 32.53 16.51 1,633.75 327.91 92.70 340.40 2.05 1,725.0 33.42 17.01 1,654.73 340.94 96.63 353.98 3.72 1,750.0 34.25 17.75 1,675.49 354.22 100.79 367.86 3.71 1,775.0 35.04 18.32 1,696.06 367.73 105.19 382.02 3.42 1,800.0 35.84 18.38 1,716.43 381.49 109.75 396.45 3.20 1,825.0 36.69 18.51 1,736.58 395.52 114.43 411.18 3.41 1,850.0 37.37 18.63 1,756.54 409.79 119.22 426.17 2.74 1,875.0 38.16 18.86 1,776.31 424.29 124.14 441.40 3.21 1,900.0 39.15 19.17 1,795.83 439.05 129.23 456.94 4.04 1,925.0 40.09 19.43 1,815.09 454.10 134.50 472.79 3.82 1,950.0 40.76 19.49 1,834.12 469.39 139.90 488.90 2.68 1,975.0 41.63 19.80 1,852.93 484.89 145.44 505.26 3.57 2,000.0 42.41 19.91 1,871.50 500.63 151.12 521.88 3.13 2,025.0 43.11 20.24 1,889.86 516.57 156.95 538.73 2.94 2,050.0 43.98 20.51 1,907.98 532.72 162.95 555.81 3.56 2,075.0 44.70 20.68 1,925.86 549.07 169.09 573.14 2.92 2,100.0 45.47 20.74 1,943.51 565.63 175.35 590.69 3.08 2,125.0 46.43 20.68 1,960.89 582.44 181.71 608.50 3.84 TBU M-06RD 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) 2,150.0 47.32 20.54 1,977.98 599.52 188.13 626.59 3.58 2,175.0 48.11 20.57 1,994.80 616.84 194.62 644.93 3.16 2,200.0 48.90 20.39 2,011.36 634.38 201.17 663.50 3.21 2,225.0 49.97 20.56 2,027.62 652.17 207.82 682.34 4.31 2,250.0 50.81 20.50 2,043.56 670.21 214.57 701.44 3.37 2,275.0 51.66 20.55 2,059.21 688.46 221.41 720.77 3.40 2,300.0 52.72 20.58 2,074.54 706.96 228.35 740.36 4.24 2,325.0 53.55 20.59 2,089.54 725.68 235.38 760.19 3.32 2,350.0 54.54 20.61 2,104.22 744.62 242.50 780.25 3.96 2,375.0 55.42 20.54 2,118.56 763.79 249.69 800.56 3.53 2,400.0 56.40 20.12 2,132.57 783.20 256.89 821.10 4.16 2,425.0 57.17 19.80 2,146.27 802.86 264.02 841.86 3.26 2,450.0 57.81 19.40 2,159.71 822.72 271.10 862.81 2.89 2,475.0 58.03 19.02 2,172.98 842.73 278.07 883.88 1.56 2,500.0 58.04 18.78 2,186.22 862.79 284.94 904.98 0.82 2,525.0 58.00 18.62 2,199.46 882.88 291.74 926.08 0.57 2,550.0 57.94 18.12 2,212.72 902.99 298.41 947.19 1.71 2,575.0 57.96 17.88 2,225.98 923.15 304.96 968.30 0.82 2,600.0 57.67 17.41 2,239.30 943.31 311.38 989.40 1.97 2,625.0 57.51 17.06 2,252.70 963.47 317.63 1,010.45 1.34 2,650.0 57.39 16.75 2,266.15 983.63 323.76 1,031.48 1.15 2,675.0 57.51 16.68 2,279.60 1,003.81 329.82 1,052.51 0.53 2,700.0 57.55 16.29 2,293.02 1,024.04 335.80 1,073.56 1.33 2,725.0 57.68 16.17 2,306.41 1,044.31 341.70 1,094.64 0.66 2,750.0 57.48 16.01 2,319.82 1,064.58 347.55 1,115.72 0.97 2,775.0 57.46 15.99 2,333.26 1,084.84 353.36 1,136.77 0.10 2,800.0 57.38 16.13 2,346.72 1,105.09 359.19 1,157.81 0.57 2,825.0 57.36 16.34 2,360.20 1,125.30 365.08 1,178.83 0.71 2,850.0 57.43 16.62 2,373.67 1,145.50 371.05 1,199.86 0.98 2,875.0 57.42 17.00 2,387.13 1,165.67 377.14 1,220.88 1.28 2,900.0 57.47 17.13 2,400.59 1,185.81 383.33 1,241.90 0.48 2,925.0 57.61 17.28 2,414.00 1,205.96 389.57 1,262.95 0.75 2,950.0 57.48 17.59 2,427.42 1,226.09 395.89 1,283.98 1.17 2,975.0 57.22 17.73 2,440.91 1,246.14 402.27 1,304.97 1.14 3,000.0 57.28 17.69 2,454.43 1,266.17 408.67 1,325.92 0.28 3,072.86 57.06 17.84 2,493.93 1,324.48 427.35 1,386.95 0.35 3,168.71 56.93 19.17 2,546.15 1,400.70 452.86 1,466.98 1.17 3,260.90 56.93 19.25 2,596.45 1,473.65 478.28 1,543.80 0.07 TBU M-06RD 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) 3,357.21 56.94 19.37 2,649.00 1,549.83 504.97 1,624.04 0.10 3,449.22 56.50 19.50 2,699.48 1,622.36 530.56 1,700.50 0.49 3,547.59 56.36 20.67 2,753.88 1,699.34 558.71 1,781.86 1.00 3,643.09 56.22 21.20 2,806.88 1,773.54 587.09 1,860.57 0.48 3,738.50 56.95 21.71 2,859.42 1,847.66 616.22 1,939.37 0.89 3,831.92 57.24 20.45 2,910.18 1,920.84 644.43 2,017.05 1.17 3,927.73 56.90 19.67 2,962.26 1,996.38 672.02 2,096.88 0.77 4,023.52 56.94 19.24 3,014.54 2,072.06 698.75 2,176.65 0.38 4,117.41 57.11 18.68 3,065.65 2,146.55 724.34 2,255.01 0.53 4,210.85 56.76 18.65 3,116.62 2,220.74 749.40 2,332.95 0.38 4,305.63 56.57 18.38 3,168.71 2,295.82 774.55 2,411.79 0.31 4,401.60 56.35 18.19 3,221.73 2,371.77 799.64 2,491.46 0.28 4,497.82 56.46 17.98 3,274.98 2,447.96 824.52 2,571.31 0.21 4,590.07 56.45 17.98 3,325.95 2,521.09 848.26 2,647.92 0.01 4,686.07 56.11 17.62 3,379.24 2,597.12 872.67 2,727.51 0.47 4,780.89 56.39 17.80 3,431.92 2,672.22 896.65 2,806.10 0.33 4,873.99 56.04 18.60 3,483.70 2,745.73 920.82 2,883.17 0.81 4,970.50 56.37 18.84 3,537.38 2,821.69 946.56 2,962.99 0.40 5,066.34 54.46 18.87 3,591.78 2,896.36 972.06 3,041.50 1.99 5,160.45 54.41 19.02 3,646.51 2,968.76 996.91 3,117.66 0.14 5,255.33 54.31 18.18 3,701.80 3,041.84 1,021.50 3,194.42 0.73 5,350.76 54.32 18.69 3,757.47 3,115.38 1,046.02 3,271.60 0.43 5,444.12 54.33 20.27 3,811.91 3,186.87 1,071.31 3,346.97 1.37 5,539.18 54.17 21.09 3,867.45 3,259.05 1,098.55 3,423.45 0.72 5,633.32 54.42 20.75 3,922.40 3,330.45 1,125.84 3,499.19 0.40 5,728.34 54.59 20.87 3,977.57 3,402.77 1,153.33 3,575.86 0.21 5,823.77 54.52 21.26 4,032.91 3,475.32 1,181.27 3,652.87 0.34 5,919.03 54.42 20.51 4,088.27 3,547.75 1,208.91 3,729.68 0.65 6,013.63 54.20 20.29 4,143.46 3,619.76 1,235.69 3,805.90 0.30 6,108.41 54.80 19.40 4,198.50 3,692.34 1,261.88 3,882.53 0.99 6,202.60 54.36 19.55 4,253.09 3,764.71 1,287.47 3,958.82 0.48 6,296.40 54.52 19.64 4,307.64 3,836.59 1,313.06 4,034.64 0.19 6,390.16 54.49 19.97 4,362.08 3,908.41 1,338.93 4,110.46 0.29 6,487.39 54.32 20.99 4,418.67 3,982.48 1,366.59 4,188.88 0.87 6,582.05 54.28 20.16 4,473.91 4,054.45 1,393.60 4,265.10 0.71 6,676.15 54.56 20.11 4,528.66 4,126.30 1,419.95 4,341.06 0.30 6,771.75 54.47 20.06 4,584.15 4,199.41 1,446.68 4,418.33 0.10 6,865.97 54.42 19.21 4,638.94 4,271.61 1,472.44 4,494.50 0.74 TBU M-06RD 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) 6,961.34 54.38 19.33 4,694.46 4,344.81 1,498.03 4,571.60 0.11 7,056.06 54.29 18.79 4,749.69 4,417.54 1,523.16 4,648.14 0.47 7,149.76 54.28 18.21 4,804.38 4,489.69 1,547.30 4,723.89 0.50 7,246.02 54.14 16.48 4,860.68 4,564.21 1,570.58 4,801.75 1.47 7,279.00 54.19 16.53 4,879.99 4,589.85 1,578.17 4,828.44 0.20 7,344.15 54.23 16.64 4,918.09 4,640.50 1,593.26 4,881.20 0.15 7,442.65 49.82 16.80 4,978.68 4,714.84 1,615.59 4,958.67 4.48 7,523.64 48.72 16.95 5,031.52 4,773.58 1,633.40 5,019.92 1.36 7,623.13 45.65 17.14 5,099.13 4,843.34 1,654.79 5,092.72 3.10 7,722.42 40.17 15.20 5,171.83 4,908.22 1,673.67 5,160.19 5.67 7,813.13 38.34 9.69 5,242.09 4,964.22 1,686.08 5,217.54 4.34 7,901.85 36.21 7.09 5,312.69 5,017.36 1,693.95 5,271.08 2.99 7,999.01 30.03 5.08 5,394.02 5,070.10 1,699.65 5,323.74 6.46 8,095.50 26.03 4.33 5,479.18 5,115.28 1,703.39 5,368.58 4.16 8,185.72 22.98 2.47 5,561.26 5,152.62 1,705.65 5,405.46 3.49 8,284.83 19.30 359.56 5,653.69 5,188.34 1,706.36 5,440.41 3.86 8,376.13 17.70 357.81 5,740.27 5,217.30 1,705.71 5,468.46 1.85 8,475.62 11.88 346.90 5,836.44 5,242.42 1,702.81 5,492.26 6.47 8,570.97 12.38 345.59 5,929.66 5,261.88 1,698.04 5,510.13 0.60 8,666.36 14.67 349.14 6,022.40 5,283.65 1,693.22 5,530.23 2.55 8,766.10 12.26 347.30 6,119.39 5,306.38 1,688.51 5,551.30 2.46 8,856.23 12.95 345.91 6,207.35 5,325.51 1,683.95 5,568.89 0.84 8,952.36 13.67 348.30 6,300.90 5,347.09 1,679.02 5,588.78 0.94 9,047.95 12.60 356.73 6,394.00 5,368.56 1,676.13 5,609.04 2.29 9,142.77 12.83 0.65 6,486.49 5,389.42 1,675.67 5,629.24 0.94 9,237.31 13.23 0.57 6,578.59 5,410.74 1,675.89 5,650.06 0.42 9,332.95 14.21 358.53 6,671.50 5,433.42 1,675.70 5,672.10 1.14 9,426.34 13.49 355.61 6,762.18 5,455.74 1,674.57 5,693.58 1.08 9,521.29 12.69 356.31 6,854.66 5,477.18 1,673.05 5,714.11 0.86 9,616.49 12.22 352.85 6,947.62 5,497.61 1,671.13 5,733.57 0.93 9,711.14 12.75 2.19 7,040.05 5,517.99 1,670.28 5,753.22 2.20 9,807.53 14.74 2.53 7,133.67 5,540.86 1,671.23 5,775.71 2.07 9,899.15 15.42 358.71 7,222.14 5,564.68 1,671.47 5,798.96 1.31 9,991.69 13.72 356.15 7,311.71 5,587.93 1,670.45 5,821.37 1.96 10,079.27 11.68 354.54 7,397.14 5,607.11 1,668.91 5,839.70 2.36 10,178.77 13.89 355.44 7,494.16 5,629.04 1,667.01 5,860.62 2.23 10,278.10 13.61 354.16 7,590.65 5,652.55 1,664.87 5,883.03 0.42 10,372.77 12.66 352.41 7,682.84 5,673.92 1,662.36 5,903.27 1.08 TBU M-06RD 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) 10,468.02 12.94 356.07 7,775.72 5,694.91 1,660.25 5,923.23 0.90 10,563.92 12.40 350.83 7,869.29 5,715.79 1,657.87 5,943.02 1.32 10,659.78 9.05 335.79 7,963.48 5,732.84 1,653.14 5,958.55 4.53 10,752.30 5.87 315.50 8,055.22 5,742.85 1,646.84 5,966.86 4.41 10,847.20 6.25 283.27 8,149.62 5,747.49 1,638.41 5,969.47 3.56 10,943.65 8.24 263.31 8,245.31 5,747.89 1,626.44 5,967.14 3.30 11,037.22 8.56 237.91 8,337.91 5,743.41 1,613.87 5,959.92 3.95 11,134.00 12.46 218.57 8,433.07 5,731.41 1,601.25 5,945.36 5.38 11,225.55 16.44 204.25 8,521.74 5,711.87 1,589.76 5,923.72 5.81 11,323.62 20.35 202.84 8,614.78 5,683.49 1,577.44 5,893.28 4.01 11,418.51 21.36 202.99 8,703.45 5,652.37 1,564.28 5,859.99 1.07 11,513.74 24.24 206.01 8,791.23 5,618.83 1,548.93 5,823.84 3.26 11,608.77 27.37 205.79 8,876.78 5,581.62 1,530.87 5,783.49 3.29 11,703.69 28.29 203.15 8,960.72 5,541.29 1,512.54 5,740.05 1.62 11,799.05 32.36 200.24 9,043.02 5,496.55 1,494.82 5,692.45 4.53 11,892.09 38.09 198.08 9,119.00 5,445.86 1,477.28 5,639.11 6.31 11,986.67 44.07 199.31 9,190.26 5,387.03 1,457.33 5,577.29 6.38 12,081.44 50.47 200.19 9,254.53 5,321.56 1,433.79 5,508.17 6.79 12,175.61 53.62 199.46 9,312.45 5,251.71 1,408.63 5,434.43 3.40 12,272.50 56.51 197.96 9,367.93 5,176.48 1,383.17 5,355.38 3.24 12,367.27 57.54 197.31 9,419.51 5,100.71 1,359.09 5,276.13 1.23 12,462.23 60.91 199.57 9,468.09 5,023.35 1,333.26 5,194.92 4.10 12,552.72 65.85 197.48 9,508.63 4,946.66 1,307.61 5,114.40 5.84 12,649.66 72.45 193.41 9,543.12 4,859.39 1,283.57 5,023.95 7.85 12,744.77 74.76 192.88 9,569.97 4,770.54 1,262.83 4,932.71 2.49 12,839.74 74.87 191.59 9,594.84 4,680.97 1,243.41 4,841.08 1.31 12,932.66 73.92 192.33 9,619.84 4,593.42 1,224.86 4,751.60 1.28 13,029.17 75.39 193.62 9,645.38 4,502.73 1,203.95 4,658.53 2.00 13,123.84 79.82 195.47 9,665.70 4,413.26 1,180.72 4,566.13 5.05 13,218.65 84.45 198.32 9,678.67 4,323.44 1,153.43 4,472.45 5.72 13,322.14 83.39 198.79 9,689.63 4,225.88 1,120.69 4,370.00 1.12 13,416.39 82.92 198.11 9,700.86 4,137.11 1,091.07 4,276.83 0.87 13,511.09 83.67 198.13 9,711.92 4,047.72 1,061.82 4,183.13 0.79 13,606.39 83.10 199.58 9,722.89 3,958.14 1,031.23 4,088.93 1.63 13,701.97 84.92 198.41 9,732.87 3,868.26 1,000.30 3,994.38 2.26 13,796.67 85.08 197.70 9,741.12 3,778.57 971.06 3,900.39 0.76 13,892.84 84.88 196.74 9,750.17 3,687.03 943.04 3,804.87 1.02 13,918.14 85.05 196.54 9,752.39 3,662.88 935.82 3,779.72 1.02 TBU M-06RD 37 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) 14,013.45 85.99 197.04 9,759.84 3,571.91 908.37 3,684.89 1.11 14,108.50 85.25 196.60 9,767.10 3,481.20 880.95 3,590.32 0.91 14,204.01 84.94 196.69 9,775.26 3,390.02 853.69 3,495.33 0.34 14,298.50 84.69 195.93 9,783.80 3,299.71 827.26 3,401.37 0.84 14,392.93 84.76 196.17 9,792.49 3,209.35 801.26 3,307.47 0.26 14,487.10 84.63 195.75 9,801.19 3,119.19 775.47 3,213.82 0.46 14,581.70 85.56 196.56 9,809.28 3,028.66 749.24 3,119.69 1.30 14,676.75 85.31 195.87 9,816.85 2,937.68 722.78 3,025.08 0.77 14,771.50 85.01 195.68 9,824.84 2,846.83 697.12 2,930.77 0.38 14,867.10 84.45 194.62 9,833.62 2,754.94 672.25 2,835.63 1.25 14,964.56 83.51 194.61 9,843.84 2,661.16 647.79 2,738.74 0.96 15,056.97 82.70 195.08 9,854.94 2,572.47 624.28 2,647.04 1.01 15,153.04 82.45 194.95 9,867.35 2,480.46 599.60 2,551.83 0.30 15,245.60 81.96 194.89 9,879.91 2,391.85 576.00 2,460.17 0.53 15,341.19 81.77 194.85 9,893.43 2,300.39 551.72 2,365.58 0.20 15,435.57 82.28 194.45 9,906.53 2,209.97 528.07 2,272.15 0.68 15,472.00 82.28 194.45 9,911.42 2,175.01 519.06 2,236.06 0.01 Note: Survey @ 15,472’ is a projection to bit depth. TBU M-06RD 38 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drilled HRS AVE ROP (Ft/HR) CONDITION Mill 8.5” Window Mill / Baker Oil Tools 12619457 N/A 7,279’ 7,340’ 61’ 13.50 9.96 — 1 8.5” HDBS MMD75DC 12896068 7x12 / 0.7731 7,340’ 11,072’ 3,732’ 35.18 146.0 1-4-BT-S-X-I-NO-PR 2 8.5” HDBS MMD75DC 12896069 7x12 / 0.7731 11,072’ 12,424’ 2,340’ 22.66 48.15 8-4-RO-C-X-I-WT-PR 3 8.5” HDBS MMD75DC 12920423 7x12 / 0.7731 12,424’ 13,272’ 848’ 22.45 70.47 1-2-CT-N-X-I-WT-PR 4 8.5” Varel V711PDG1HRU 4009435 4x12, 4x11 / 0.8130 13,272’ 13,922’ 650’ 13.65 87.36 4-2-BT-C-X-I-CT-PR 5 8.5” HDBS MM75D 12670051 5x14 / 0.7517 13,922’ 15,472’ 1,550’ 13.40 140.70 2-1-CT-C-X-I-SD-TD 5RR 8.5” HDBS MM75D 12670051 5x14 / 0.7517 15,472’ 15,472’ — — — — TBU M-06RD 39 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 AgNO3 CaCl2 (ppbl) Lime (ppb) ENVIROMUL 6/5/2017 7,340 4,870 8.90 72 22 13 10/23/27 4.0 3/0 8.3 80.6/19.4 — 2.973 1.5 14.03 9.32 6/6/2017 7,340 4,870 8.95 110 23 18 14/29/33 4.0 3/0 9.3 80.9/19.1 — 2.816 1.5 14.03 8.81 6/7/2017 8,129 5,225 8.85 67 22 12 10/29/33 3.6 3/0 7.9 80.1/19.9 — 2.993 1.5 14.03 8.81 6/8/2017 9,924 7,220 9.00 57 20 12 9/22/25 3.6 3/0 8.3 81.1/18.9 — 3.137 1.5 13.54 8.03 6/9/2017 11,072 8,371 8.95 55 19 11 10/20/22 3.6 3/0 8.0 82.2/17.8 0.01 3.099 1.7 14.51 10.23 6/10/2017 11,072 8,371 8.95 63 20 11 8/18/20 3.6 3/0 8.1 83.3/16.7 0.01 3.110 1.6 15.49 8.81 6/11/2017 11,250 8,545 9.00 68 21 12 8/22/26 3.6 3/0 7.2 82.4/17.6 0.01 3.436 1.7 19.85 7.38 6/12/2017 12,153 9,046 9.00 62 23 11 8/23/26 3.4 3/0 8.6 84.4/15.6 0.01 3.039 1.9 19.85 10.88 6/13/2017 12,424 9,423 9.05 77 23 11 11/24/27 3.4 3/0 8.6 83.8/16/2 0.01 3.099 1.8 19.85 9.84 6/14/2017 12,658 9,423 9.00 62 22 14 9/21/23 3.4 3/0 8.0 83.3/16.7 0.01 3.132 1.8 22.76 9.19 6/15/2017 13,021 9,632 9.00 63 23 11 9/20/23 3.4 0/3 8.0 84.4/15/6 0.01 3.165 1.8 22.76 6.86 6/16/2017 13,272 9,682 9.05 68 24 13 10/22/25 3.4 0/3 8.7 84.4/15.6 0.01 3.119 1.7 17.91 9.97 6/17/2017 13,272 9,682 9.05 82 24 12 10/23/26 3.4 0/3 8.7 84.4/15.6 0.01 3.119 1.7 17.91 9.97 6/18/2017 13,272 9,682 9.05 97 25 12 9/21/23 3.8 0/3 9.3 85.4/14.6 0.01 3.082 1.9 16.94 12.56 6/19/2017 13,424 9,690 9.05 89 25 13 9/24/37 3.6 0/3 8.7 84.9/15.1 0.01 3.133 1.8 16.94 10.10 6/20/2017 13,880 9,700 9.05 68 29 15 12/26/30 3.6 0/3 9.2 84.3/15.7 0.01 2.998 2.0 16.94 7.38 6/21/2017 13,922 9,702 9.05 90 26 14 11/26/30 2.8 0/3 9.7 83.6/16.4 0.01 2.895 1.9 14.03 9.45 6/22/2017 13,922 9,702 9.05 90 31 16 15/29/34 2.8 0/3 10.2 84.1/15.9 0.01 2.790 1.9 15.97 6.73 6/23/2017 15,003 9,851 9.05 76 29 16 14/26/28 3.8 0/3 9.7 83.6/16.4 0.01 2.889 1.8 15.00 8.68 6/24/2017 15,472 9,851 9.10 68 28 12 9/20/22 3.8 0/3 10.2 83.0/17.0 0.01 2.843 1.7 14.03 8.03 6/25/2017 15,472 9,851 9.25 68 25 12 11/22/24 3.8 0/3 10.7 83.4/16.6 0.01 2.913 1.9 15.97 8.16 6/26/2017 15,472 9,851 9.30 85 27 12 9/20/22 3.8 0/3 10.2 83.0/17.0 0.10 3.082 1.5 13.06 5.44 6/27/2017 15,472 9,851 9.35 103 28 12 9/20/23 4.2 0/3 10.9 82.9/17.1 0.10 3.032 1.4 12.09 4.92 6/28/2017 15,472 9,851 9.40 128 28 13 10/22/26 4.2 0/3 10.7 82.9/17.1 0.10 3.082 1.8 14.51 5.44 6/29/2017 15,472 9,851 9.40 123 30 14 10/20/24 4.2 0/3 10.2 83.0/17.0 0.10 3.197 1.7 14.03 5.96 6/30/2017 15,472 9,851 9.45 151 30 14 10/21/23 4.0 0/3 10.4 82.9/17.1 0.10 3.197 1.7 14.03 5.57 7/1/2017 15,472 9,851 9.45 102 29 15 10/22/24 4.0 0/3 10.7 82.9/17.1 0.10 3.200 1.6 13.54 5.57 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 TBU M-06RD 40 4.4 Drilling Progress 7,000 8,000 9,000 10,000 11,000 12,000 13,000 14,000 15,000 16,000 Days Vs. Depth TBU M-06RD 41 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 11660'MD 11760'MD Country:20 8922'TVD 9009'TVD Averages Before During After Maximum ROP (fph)65 ft/hr 80 ft/hr 101 ft/hr 212 ft/hr WOB 11 klbs 15 klbs 20 klbs 26 klbs RPM 144 rpm 138 rpm 138 rpm 157 rpm PP 2712 psi 2696 psi 2705 psi 2754 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal Chloride Total Gas 40 22 29 47 C1 (ppm)8,326 4,401 6,815 11,479 C2 (ppm)154 106 111 406 C3 (ppm)77 76 44 173 C4 (ppm)43 50 31 100 C5 (ppm)6 14 8 37 Lithology Odor none Amount 20%Type slow Amount Amount minor Distribution patchy Intensity weak Color Color brown Intensity mod/wk Color yellow Color yel/wht Intesity Color straw-brown Color Comments Report by: Residual Cut Conglomerate Sand (11730'-11860') = overall light to medium olive gray to light olive brown; dominantly milky, sub-transparent to transparent, white to off white individual grains, scattered light to medium green; trace scattered red to red-orange; dominantly upper coarse to lower coarse, scattered upper medium to occasionally sub-granular sized fragments; very poorly to poorly sorted; dominantly very angular to angular, rare sub-angular to sub-rounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert-like texture; petroleum odor masked by oil based mud; moderately fast yellow streaming fluorescence; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/12/2017 12:20 PM Cut Free Oil in Mud Kenai Borough Alaska USA minor ft. brn to straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis weak-mod Allen Odegaard / Garnet Knopp masked by oil base mud0.8 dull yellow Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #2 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12000'MD 12350'MD Country:20 9199'TVD 9410'TVD Averages Before During After Maximum ROP (fph)126 ft/hr 84 ft/hr 31 ft/hr 383 ft/hr WOB 20 klbs 20 klbs 21 klbs 66 klbs RPM 151 rpm 142 rpm 144 rpm 181 rpm PP 2802 psi 2761 psi 2978 psi 3004 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal Chloride Total Gas 46 32 17 64 C1 (ppm)8,896 5,657 3,024 11,991 C2 (ppm)798 658 198 1,449 C3 (ppm)387 248 67 782 C4 (ppm)168 119 40 313 C5 (ppm)60 49 19 119 Lithology Odor none Amount 20%Type streaming Amount Amount minor Distribution clusters Intensity moderate Color Color brown Intensity moderate Color light Color yel/wht yellow Intesity Color straw-brown Color Comments Report by: Residual Cut Sand / Conglomerate (12220'-12310') = light olive gray to light olive brown sand, quartz dominant, with lesser cream to tan colored feldspar and very minor black lithics; upper fine to lower very coarse grained with some granule sized grains; poor to fair sorting; sub-angular to rounded; low clay content; occasional sub- angular fragments of coal and gray/ black laminated tuffaceous siltstone; some consolidated sandstone clusters showing moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/13/2017 3:36 AM Cut Free Oil in Mud Kenai Borough Alaska USA minor ft. brn to straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis weak Allen Odegaard / Garnet Knopp masked by oil base mud0.6 dull yellow Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #3 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12425'MD 12525'MD Country:20 9449'TVD 9496'TVD Averages Before During After Maximum ROP (fph)28 ft/hr 72 ft/hr 93 ft/hr 215 ft/hr WOB 22 klbs 17 klbs 16 klbs 30 klbs RPM 148 rpm 103 rpm 92 rpm 170 rpm PP 2940 psi 2971 psi 2931 psi 3072 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chloride Total Gas 20 20 28 37 C1 (ppm)3,360 3,780 5,937 7,752 C2 (ppm)445 231 239 512 C3 (ppm)99 56 109 145 C4 (ppm)59 20 46 55 C5 (ppm)27 0 6 27 Lithology Odor none Amount 20%Type streaming Amount Amount v. minor Distribution clusters Intensity moderate Color Color brown Intensity weak Color light Color yel/wht yellow Intesity Color straw-brown Color Comments Report by: Residual Cut Sand / Tuffaceous Sandstone (12400'- 12490') = light olive gray to medium gray, abundant in clear to blue quartz and tan feldspar with minor black lithic grains; upper fine to upper coarse grained to som e conglomerate grains; fair sorting; sub-angular to rounded; with occasional consolidated sandstone clusters; minor sub-angular fragments of tuffaceous siltstone and coal; clusters show moderate light yellow streaming fluorescence and dull cut fluorescence. Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/14/2017 3:36 AM Cut Free Oil in Mud Kenai Borough Alaska USA minor ft. brn to straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis weak Allen Odegaard / Garnet Knopp masked by oil base mud0.6 dull yellow Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #4 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12680'MD 12770'MD Country:20 9551'TVD 9576'TVD Averages Before During After Maximum ROP (fph)55 ft/hr 75 ft/hr 107 ft/hr 134 ft/hr WOB 21 klbs 22 klbs 20 klbs 31 klbs RPM 98 rpm 97 rpm 95 rpm 149 rpm PP 2925 psi 2884 psi 2906 psi 2965 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal Chloride Total Gas 23 23 27 46 C1 (ppm)4,046 3,913 5,500 8,436 C2 (ppm)493 385 361 841 C3 (ppm)110 128 103 275 C4 (ppm)52 72 46 185 C5 (ppm)6 26 10 88 Lithology Odor none Amount 20%Type streaming Amount Amount minor Distribution clusters Intensity weak Color Color brown Intensity weak Color light Color yel/wht yellow Intesity Color straw-brown Color Comments Report by: Residual Cut Sand / Tuffaceous Sandstone (12640'- 12740') = pale yellowish brown to dark gray sand, quartz- dominant; with lesser milky white and pink feldspar and black lithics; upper fine to very coarse grained with abundant conglomerate grains; poor to fair sorting with larger clasts predominantly quartz; sub- angular to sub-rounded; minor sub-angular fragments of tuffaceous siltstone and claystone; occasional consolidated sandstone clusters showing mild yellow streaming fluorescence and dull cut fluorescence and residual stain. Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/15/2017 4:30 AM Cut Free Oil in Mud Kenai Borough Alaska USA minor ft. brn to straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis weak Allen Odegaard / Garnet Knopp masked by oil base mud0.4 dull yellow Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #5 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12790'MD 12870'MD Country:20 9581'TVD 9603'TVD Averages Before During After Maximum ROP (fph)107 ft/hr 79 ft/hr 25 ft/hr 148 ft/hr WOB 20 klbs 21 klbs 9 klbs 33 klbs RPM 95 rpm 106 rpm 128 rpm 146 rpm PP 2905 psi 2874 psi 2725 psi 2944 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal Chloride Total Gas 27 53 18 115 C1 (ppm)5,430 10,109 3,217 23,278 C2 (ppm)383 640 134 1,539 C3 (ppm)104 395 64 973 C4 (ppm)47 168 39 394 C5 (ppm)11 55 11 120 Lithology Odor none Amount 35%Type streaming Amount Amount minor Distribution clusters Intensity moderate Color Color brown Intensity weak Color yellow Color yellow Intesity Color straw-brown Color Comments Report by: Residual Cut Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone (12740'-12880') = very light gray; clast size pebble to very coarse upper to coarse lower; angular bit impacted fragments to sub- rounded; very poor to moderate developed sphericity; moderate sorting; polished to chip texture; mature nature; non to very weak siliceous cement; unconsolidated; dominant grain support; slight visible clay matrix; composed of predominantly quartz with some lithic fragments; fair to good porosity and permeability; moderate yellow streaming fluorescence; weak yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; dull yellow residual cut fluorescence. Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/15/2017 10:42 AM Cut Free Oil in Mud Kenai Borough Alaska USA minor ft. brn to straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis weak Allen Odegaard / Garnet Knopp masked by oil base mud0.9 yellow Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #6 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 13030'MD 13270'MD Country:20 9645'TVD 9685'TVD Averages Before During After Maximum ROP (fph)33 ft/hr 60 ft/hr 81 ft/hr 132 ft/hr WOB 22 klbs 20 klbs 16 klbs 29 klbs RPM 108 rpm 118 rpm 142 rpm 141 rpm PP 2941 psi 2893 psi 3105 psi 2953 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chloride Total Gas 17 24 40 53 C1 (ppm)2,939 4,411 8,436 10,304 C2 (ppm)218 279 287 712 C3 (ppm)58 120 134 350 C4 (ppm)28 56 50 148 C5 (ppm)4 20 11 61 Lithology Odor none Amount 40%Type streaming Amount Amount minor Distribution clusters Intensity mod-high Color Color brown Intensity moderate Color yellow Color yellow Intesity Color dark straw-light brown Color Comments Report by: Residual Fluorescence Cuttings Analysis moderate Allen Odegaard / Garnet Knopp masked by oil base mud0.9 yellow Oil Show Rating Cut Free Oil in Mud Kenai Borough Alaska USA minor ft. brn to straw Stain Fluorescence Cut Fluorescence Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/16/2017 13:13:00 PM Residual Cut Tuffaceous Sandstone / Tuffaceous Siltstone (13120'-13240') = light olive gray to medium gray quartz rich sandstones; grain size is upper very fine to lower coarse; angular to sub-rounded; low to moderate sphericity; well to moderate sorting; sandstone nodules contain a volcanic ash that is white to bluish white in color and clumpy / soft texture; sample contains some black lithics, lower coarse to upper coarse in size, sub-rounded to rounded, with moderate sphericity; tuffaceous siltstone is light gray to medium gray, quartz rich, lower very fine in size, very well sorted, firmly friable, sub-angular to rounded massive cuttings; good to moderate yellow streaming fluorescence; yellow cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderate yellow residual cut fluorescence. 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #7 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 13605'MD 13740'MD Country:20 9722'TVD 9736'TVD Averages Before During After Maximum ROP (fph)108 ft/hr 113 ft/hr 68 ft/hr 406 ft/hr WOB 15 klbs 15 klbs 9 klbs 44 klbs RPM 157 rpm 139 rpm 145 rpm 172 rpm PP 2999 psi 2978 psi 3029 psi 3066 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chloride Total Gas 33 18 10 52 C1 (ppm)7,352 3,532 1,808 10,396 C2 (ppm)284 146 27 597 C3 (ppm)113 85 22 323 C4 (ppm)34 38 15 139 C5 (ppm)- 7 - 43 Lithology Odor none Amount 20%-30%Type streaming Amount Amount minor Distribution clusters Intensity mod-high Color Color brown Intensity moderate Color yellow Color yellow Intesity Color dark straw-light brown Color Comments Report by: Residual Cut Tuffaceous Siltstone / Volcanic Ash (13,540'-13,700') = tuffaceous siltstn lt gry to med gry; qtz rich, lwr VF grained, v well sorted, firmly friable, ang to subang to rnded massives; volcanic ash is lt olive gray - med olive gray, cly szd particulates, v well sorted, pulverulent tenacity, smth text, laminae structure; blk lithics, lwr to upper med in size, subang to subrded, low sphericity; dominant coal seam shows at 13,590', gryish blk to blk, ang to subang, poorly sorted, conch fract, dense tenacity, dull luster; qtz sd nodules, lt brn tan to med brn tan in color, subrded to rded, upper med to upper coarse in size, well to mod sorted, mod to high sphericity, silica cement; sands are lt olive gray to med olive gray, unconsol, poorly sorted, lwr fine to lwr med in size, ang to subrded; common to scattered ylw to ylw-grn light sample fluorescence; good to mod ylw stream fluorescence; ylw cut fluorescence; dk straw to lt brn vis cut; faint brn to med straw residual cut ring; mod ylw residual cut fluorescence. Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/20/2017 14:51:00 PM Cut Free Oil in Mud Kenai Borough Alaska USA minor brown-straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis moderate Allen Odegaard / Garnet Knopp masked by oil base mud0.4-0.6 yellow Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #8 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 13820'MD 14710'MD Country:20 9743'TVD 9819'TVD Averages Before During After Maximum ROP (fph)64 ft/hr 126 ft/hr 114 ft/hr 303 ft/hr WOB 28 klbs 12 klbs 8 klbs 66 klbs RPM 124 rpm 101 rpm 96 rpm 160 rpm PP 3014 psi 3292 psi 3423 psi 3652 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal 9.1 lbs/gal Chloride Total Gas 25 27 12 72 C1 (ppm)5,168 5,557 1,905 15,862 C2 (ppm)172 258 46 727 C3 (ppm)110 139 46 456 C4 (ppm)56 70 37 222 C5 (ppm)13 25 19 72 Lithology Odor none Amount 20%-40%Type cut Amount Amount minor Distribution clusters Intensity moderate Color Color brown Intensity moderate Color wht-ylw Color yellow Intesity Color dark straw-light brown Color Comments Report by: Residual Fluorescence Cuttings Analysis mod-high Allen Odegaard / Garnet Knopp masked by oil base mud0.4-0.7 bright yellow Oil Show Rating Cut Free Oil in Mud Kenai Borough Alaska USA minor light brown Stain Fluorescence Cut Fluorescence Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/23/2017 16:34:00 PM Residual Cut Sand / Tuffaceous Sandstone (14480' - 14600') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and trace light green individual grains; upper fine to lower medium grained; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has a white mushy clayey matrix, which also contains trace to 10% off-white ash; friable to very friable to soft; crumbly tenacity; sub-angular to sub-rounded to rounded; moderate to moderately low sphericity; fair to poor sorting; non- calcareous; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #9 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 14795'MD 15472'MD Country:20 9827'TVD 9911'TVD Averages Before During After Maximum ROP (fph)160 ft/hr 148 ft/hr - 601 ft/hr WOB 14 klbs 13 klbs - 17 klbs RPM 97 rpm 102 rpm - 114 rpm PP 3509 psi 3416 psi - 3632 psi Mud Weight 9.1 lbs/gal 9.1 lbs/gal - 9.1 lbs/gal Chloride Total Gas 45 27 - 49 C1 (ppm)9,516 4,899 - 9,809 C2 (ppm)498 544 - 1,050 C3 (ppm)274 149 - 389 C4 (ppm)127 67 - 384 C5 (ppm)50 26 - 160 Lithology Odor none Amount 25%-50%Type streaming Amount Amount trace Distribution clusters Intensity moderate Color Color brown Intensity moderate Color ylw-wht Color yellow Intesity Color dark straw-light brown Color Comments Report by: Residual Cut Sand (15240'-15340') = light olive gray to medium gray sand dominated by clear to smoky quartz with minor dusky brown and black lithics and varying lev els of clayey matrix; lower medium to upper coarse grained, with a few conglomerate quartz clasts; subangular to rounded; moderate sphericity; semi- consolidated sandstone clusters of same mineralogy; minor firm subangular dark gray fragments of tuffaceous siltstone and soft, light gray tuffaceous claystone; moderate whitish yellow streaming and cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators possibly masked or influenced by oil based mud. Hilcorp Alaska, LLC 50-733-20585-01-00TBU M-06RD McArthur River Field Steelhead 51 6/24/2017 10:35 PM Cut Free Oil in Mud Kenai Borough Alaska USA minor brown-straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis mod-high Allen Odegaard / Garnet Knopp Ended at TD. masked by oil base mud0.4-1.0 bright ylw Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 TBU M-06RD 42 6 DAILY REPORTS Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / H. Soule DATE June 04, 2017 DEPTH 0 PRESENT OPERATION RIH w/ whipstock TIME 23:55:53 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION 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 MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RIH with junk basket, POOH with junk basket, Rerun junk basket until clean, Make up Whipstock BHA, Perform shallow hole test, Make up rest of BHA and RIH w/ whipstock. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2625 REPORT BY M. Skiles Page 1 of 1Daily Report 6/5/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCO... Hilcorp Alaska LLC MacArthur River DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / H. Soule DATE Jun 05, 2017 DEPTH 7340' PRESENT OPERATION POOH TIME 23:48:11 YESTERDAY 7280' 24 HOUR FOOTAGE 60' CASING INFORMATION 9 5/8" @ 7279' 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 1 8 1/2" Mill 13346364 7279' 7340' 61' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 36.0 @ 7327' 0.1 @ 7293' 10.0 2.44340 FT/HR SURFACE TORQUE 17013 @ 7318' 12939 @ 7281' 15158.3 14594.54590 AMPS WEIGHT ON BIT 21 @ 7331' 1 @ 7281' 12.5 1.95631 KLBS ROTARY RPM 103 @ 7281' 87 @ 7293' 96.1 97.15456 RPM PUMP PRESSURE 2522 @ 7337' 1321 @ 7286' 1840.2 2502.06982 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 13 @ 7327' 1 @ 7293' 5.0 TRIP GAS CUTTING GAS 0 @ 7340' 0 @ 7340' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 3403 @ 7327' 139 @ 7280' 1016.7 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 7340' 0 @ 7340' 0.0 AVG PROPANE (C-3) 0 @ 7340' 0 @ 7340' 0.0 CURRENT 1.3 BUTANE (C-4) 0 @ 7340' 0 @ 7340' 0.0 CURRENT BACKGROUND/AVG 1.3 PENTANE (C-5) 0 @ 7340' 0 @ 7340' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Tuffaceous siltstone, Tuffaceous claystone, Claystone DAILY ACTIVITY SUMMARY RIH w/ whipstock, Clean/Prep pits for OBM, Swap over to OBM, Mill window from 7279' to 7340', Preform FIT test to 12.68 ppg EMW, POOH. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2625 REPORT BY M. Skiles Hilcorp Alaska LLC MacArthur River DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 06, 2017 DEPTH 7340' PRESENT OPERATION RIH TIME 23:48:11 YESTERDAY 7340' 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 7279' 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 1 8 1/2" HDBS MMD75DC 12896068 7X12 7340' 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 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7340' TO TOOLS Rotary Steerable + MWD/RWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY POOH, L/D milling assembly, Test BOPs, P/U BHA, RIH CANRIG PERSONNEL ON BOARD 2 DAILY COST $2625 REPORT BY M. Skiles Hilcorp Alaska LLC McArthur River Unit DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 07, 2017 DEPTH 8230' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 7340' 24 HOUR FOOTAGE 890' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7722.42' 40.17° 15.20° 5171.83' 7813.13' 38.34° 9.69° 5242.09' 7901.85' 36.21° 7.09° 5312.69' 7999.01' 30.03° 5.08° 5394.02' 8095.5' 26.03° 4.33° 5479.18' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8 1/2" HDBS MMD75DC 12896068 7X12 7340' 890' 9:32 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1002.1 @ 8143 1.4 @ 7414 135.1 131.01 FT/HR SURFACE TORQUE 21806 @ 7354 0 @ 8135 17017.4 18308.56 AMPS WEIGHT ON BIT 73 @ 8136 0 @ 8113 13.4 20.55 KLBS ROTARY RPM 157 @ 8124 0 @ 8135 129.9 142.23 RPM PUMP PRESSURE 2502 @ 7340 0 @ 7960 2146.3 2211.47 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7340' TO TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 250 @ 7549 3 @ 8093 39.7 TRIP GAS n/a CUTTING GAS 0 @ 8230 0 @ 8230 0.0 WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 65423 @ 7433 374 @ 8094 10079.3 CONNECTION GAS HIGH -- ETHANE (C-2) 33 @ 7903 8 @ 8173 0.4 AVG -- PROPANE (C-3) 0 @ 8230 0 @ 8230 0.0 CURRENT -- BUTANE (C-4) 0 @ 8230 0 @ 8230 0.0 CURRENT BACKGROUND/AVG 25u/15u PENTANE (C-5) 0 @ 8230 0 @ 8230 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Sand 60%, Tuffaceous Siltstone 20%, Tuffaceous Sandstone 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY RIH to window, circulate & condition mud, drill ahead from 7340’ to 8230’ @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Unit DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 08, 2017 DEPTH 9940' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 8230' 24 HOUR FOOTAGE 1710' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9521.29' 12.69° 356.31° 6854.66' 9616.49' 12.22° 352.85° 6947.62' 9711.14' 12.75° 2.19° 7040.05' 9807.53' 14.74° 2.53° 7133.67' 9899.15' 15.42° 358.71° 7222.14' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8 1/2" HDBS MMD75DC 12896068 7X12 7340' 2600' 21:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 614.5 @ 8803 0.5 @ 9681 170.9 73.60 FT/HR SURFACE TORQUE 25850 @ 9875 0 @ 9658 20845.0 21684.61 AMPS WEIGHT ON BIT 92 @ 9842 0 @ 8666 16.0 6.77 KLBS ROTARY RPM 159 @ 8282 0 @ 9842 147.1 147.45 RPM PUMP PRESSURE 2440 @ 9833 0 @ 9841 2243.8 2284.86 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7340' TO TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 306 @ 9600 2 @ 9658 50.8 TRIP GAS -- CUTTING GAS 0 @ 9940 0 @ 9940 0.0 WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 83126 @ 9602 445 @ 9010 13155.2 CONNECTION GAS HIGH -- ETHANE (C-2) 276 @ 9860 6 @ 9787 17.4 AVG -- PROPANE (C-3) 43 @ 9827 2 @ 9671 2.7 CURRENT -- BUTANE (C-4) 0 @ 9940 0 @ 9940 0.0 CURRENT BACKGROUND/AVG 17u/12u PENTANE (C-5) 0 @ 9940 0 @ 9940 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Sand 40%, Tuffaceous Siltstone 20%, Tuffaceous Claystone 20%, Tuffaceous Sandstone 10%, Conglomerate 10% DAILY ACTIVITY SUMMARY Drill ahead from 8230' to 9940' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Unit DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 09, 2017 DEPTH 11072' PRESENT OPERATION Pulling out of Hole TIME 23:59 YESTERDAY 9940' 24 HOUR FOOTAGE 1132' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10659.78' 9.05° 335.79° 7963.48' 10752.30' 5.87° 315.50° 8055.22' 10847.20' 6.25° 283.27° 8149.62' 10943.65' 8.24° 263.31° 8245.31' 11037.22' 8.56° 237.91° 8337.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8 1/2" HDBS MMD75DC 12896068 7X12 7340' 3793' 35:12 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1674.1 @ 10973 1.0 @ 10496 124.7 35.52 FT/HR SURFACE TORQUE 28493 @ 11037 17891 @ 11064 22663.0 22450.30 AMPS WEIGHT ON BIT 33 @ 10885 2.0 @ 10838 16.9 19.24 KLBS ROTARY RPM 173 @ 11018 84 @ 10510 149.2 150.79 RPM PUMP PRESSURE 2576 @ 11031 1606 @ 10718 2334.9 2513.92 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7279' TO 11072' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 443 @ 10382 2 @ 10015 61.3 TRIP GAS -- CUTTING GAS 0 @ 11072 0 @ 11072 0.0 WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 120933 @ 10382 1380 @ 10017 15984.8 CONNECTION GAS HIGH -- ETHANE (C-2) 510 @ 11013 3 @ 10410 47.9 AVG -- PROPANE (C-3) 106 @ 10693 2 @ 10219 10.3 CURRENT 10u BUTANE (C-4) 5 @ 10171 3 @ 10152 0.1 CURRENT BACKGROUND/AVG 12u/10u PENTANE (C-5) 0 @ 11072 0 @ 11072 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Tuffaceous Sandstone 50%, Tuffaceous Siltstone 30%, Sand 20% @ 11050' DAILY ACTIVITY SUMMARY Drilled ahead to 11072', Circ bottoms up, Prep for bit trip. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 10, 2017 DEPTH 11072' PRESENT OPERATION Servicing BHA TIME 23:59 YESTERDAY 11072' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10659.78' 9.05° 335.79° 7963.48' 10752.30' 5.87° 315.50° 8055.22' 10847.20' 6.25° 283.27° 8149.62' 10943.65' 8.24° 263.31° 8245.31' 11037.22' 8.56° 237.91° 8337.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8 1/2" HDBS MMD75DC 12896068 7X12 7279' 11072' 3793' 35:12 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 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 7279' TO 11072' TOOLS Rotary Steerable + LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pulled out of hole to surface, replacing bit & servicing BHA @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 11, 2017 DEPTH 11316' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 11072' 24 HOUR FOOTAGE 244' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10752.30' 5.87° 315.50° 8055.22' 10847.20' 6.25° 283.27° 8149.62' 10943.65' 8.24° 263.31° 8245.31' 11037.22' 8.56° 237.91° 8337.91' 11134.00' 12.46° 218.57° 8433.07' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8 1/2" HDBS MMD75DC 12896069 7X12 11072' 244' 3:26 1 8 1/2" HDBS MMD75DC 12896068 7X12 7279' 11072' 3793' 35:12 1-4-BT-S-X-I-NO-PR low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 240.0 @ 11074 2.2 @ 11108 81.8 104.54 FT/HR SURFACE TORQUE 22795 @ 11267 0 @ 11264 18931.3 19146.41 AMPS WEIGHT ON BIT 65 @ 11170 2 @ 11075 18.2 11.47 KLBS ROTARY RPM 158 @ 11208 0 @ 11264 145.4 143.91 RPM PUMP PRESSURE 2875 @ 11122 -4 @ 11073 2775.9 2783.29 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 11072' TO TOOLS Rotary Steerable + LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 160 @ 11309 12 @ 11266 44.4 TRIP GAS 601u CUTTING GAS 0 @ 11316 0 @ 11316 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 44008 @ 11309 1786 @ 11140 11442.7 CONNECTION GAS HIGH - ETHANE (C-2) 148 @ 11179 1 @ 11227 7.4 AVG - PROPANE (C-3) 25 @ 11116 3 @ 11108 4.2 CURRENT 49u BUTANE (C-4) 0 @ 11316 0 @ 11316 0.0 CURRENT BACKGROUND/AVG 3u/49u PENTANE (C-5) 0 @ 11316 0 @ 11316 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY Sand 40%, Tuffaceous Sandstone 20%, Tuffaceous Siltstone 20%, Coal 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Ran in hole to bottom w/ new drillbit and serviced BHA, circulated, drilled ahead; drilling ahead at 11316' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 12, 2017 DEPTH 12310' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 11316' 24 HOUR FOOTAGE 994' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11799.05' 32.36 200.24 9043.02' 11892.09' 38.09 198.08 9119.00' 11986.67' 44.07 199.31 9190.26' 12081.44' 50.47 200.19 9254.53' 12175.61' 53.62 199.46 9312.45' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8 1/2" HDBS MMD75DC 12896069 7X12 11072' 1238' 18:29 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 382.7 @ 12025 1.3 @ 12260 88.7 26.19 FT/HR SURFACE TORQUE 26519 @ 11988 0 @ 12224 21480.4 22056.02 AMPS WEIGHT ON BIT 66 @ 12030 1 @ 11676 16.8 20.65 KLBS ROTARY RPM 181 @ 12306 0 @ 12224 140.6 176.01 RPM PUMP PRESSURE 2915 @ 12144 0 @ 12224 2757.9 2765.66 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 11072' TO TOOLS Rotary Steerable + LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 510 @ 11338 11 @ 11750 43.4 TRIP GAS - CUTTING GAS 0 @ 12310 0 @ 12310 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 135377 @ 11339 1507 @ 11810 9708.7 CONNECTION GAS HIGH - ETHANE (C-2) 1510 @ 11914 7 @ 11357 339.3 AVG - PROPANE (C-3) 871 @ 11914 3 @ 11357 158.9 CURRENT 24 BUTANE (C-4) 349 @ 11982 3 @ 11393 76.4 CURRENT BACKGROUND/AVG 3u/24u PENTANE (C-5) 104 @ 11997 1 @ 11957 24.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY Sand 50%, Conglomerate 20%, Tuffaceous Sandstone 10%, Tuffaceous Siltstone 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Drilled ahead from 11316' to 12310' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4520 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 13, 2017 DEPTH 12424' PRESENT OPERATION Replacing bit/Servicing BHA TIME 23:59 YESTERDAY 12310' 24 HOUR FOOTAGE 114' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11986.67' 44.07° 199.31° 9190.26' 12081.44' 50.47° 200.19° 9254.53' 12175.61' 53.62° 199.46° 9312.45' 12272.50' 56.51° 197.96° 9367.93' 12367.27' 57.54° 197.31° 9419.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8 1/2" HDBS MMD75DC 12896069 7X12 11072' 12424' 1352' 22:41 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 105.7 @ 12323 1.4 @ 12356 39.5 22.06 FT/HR SURFACE TORQUE 24530 @ 12329 18234 @ 12424 22391.5 18234.63 AMPS WEIGHT ON BIT 24 @ 12420 3 @ 12324 20.7 23.66 KLBS ROTARY RPM 173 @ 12409 123 @ 12350 148.0 154.61 RPM PUMP PRESSURE 3096 @ 12396 2137 @ 12319 2934.6 3008.62 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 11072' TO 12424' TOOLS Rotary Steerable + LWD/MWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 45 @ 12398 9 @ 12375 21.9 TRIP GAS - CUTTING GAS 0 @ 12424 0 @ 12424 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 10096 @ 12398 1408 @ 12375 3760.5 CONNECTION GAS HIGH - ETHANE (C-2) 798 @ 12341 67 @ 12403 411.8 AVG - PROPANE (C-3) 186 @ 12384 33 @ 12403 108.7 CURRENT 0u BUTANE (C-4) 104 @ 12389 27 @ 12375 61.8 CURRENT BACKGROUND/AVG -/0u PENTANE (C-5) 57 @ 12417 4 @ 12371- 30.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled ahead from 12310' to 12424'. Pulled out of hole for new bit due to low ROP. At surface at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 14, 2017 DEPTH 12658' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 12424' 24 HOUR FOOTAGE 234' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12175.61' 53.62° 199.46° 9312.45' 12272.50' 56.51° 197.96° 9367.93' 12367.27' 57.54° 197.31° 9419.51' 12462.23' 60.91° 199.57° 9468.09' 12552.72' 65.85° 197.48° 9508.63' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HDBS MMD75DC 12920423 7X12 12424' 234' 4:12 2 8 1/2" HDBS MMD75DC 12896069 7X12 11072' 12424' 1352' 22:41 8-4-RO-C-X-I-WT-PR Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 242.6 @ 12594 1.2 @ 12490 98.3 1.78 FT/HR SURFACE TORQUE 28274 @ 12486 0 @ 12493 23579.0 21686.38 AMPS WEIGHT ON BIT 45 @ 12589 1 @ 12497 18.7 21.58 KLBS ROTARY RPM 169 @ 12425 0 @ 12493 98.0 107.61 RPM PUMP PRESSURE 3071 @ 12430 0 @ 12589 2938.5 2920.27 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12424' TO TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 84 @ 12587 5 @ 12471 29.9 TRIP GAS 372u CUTTING GAS 0 @ 12658 0 @ 12658 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 17836 @ 12587 475 @ 12470 5951.6 CONNECTION GAS HIGH - ETHANE (C-2) 863 @ 12587 9 @ 12443 298.4 AVG - PROPANE (C-3) 511 @ 12587 4 @ 12443 128.6 CURRENT 24u BUTANE (C-4) 226 @ 12588 2 @ 12494 52.5 CURRENT BACKGROUND/AVG 3u/24u PENTANE (C-5) 69 @ 12588 2 @ 12596 12.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY Sand 70%, Tuffaceous Sandstone 10%, Tuffaceous Siltstone 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Ran in hole to bottom, washing/reaming the last few stands. Resumed drilling according to plan. Drilling ahead at 12658' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 15, 2017 DEPTH 13037' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 12658' 24 HOUR FOOTAGE 379' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12552.72' 65.85° 197.48° 9508.63' 12649.66' 72.45° 193.41° 9543.12' 12744.77' 75.76° 192.88° 9569.17' 12839.74' 74.87° 191.59° 9594.84' 12932.66' 73.92° 192.33° 9619.84' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HDBS MMD75DC 12920423 7X12 12424' 613' 15:56 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 406.2 @ 12968 0.5 @ 12970 59.6 14.76 FT/HR SURFACE TORQUE 28639 @ 12860 0 @ 12874 23354.7 18121.98 AMPS WEIGHT ON BIT 131 @ 12968 5 @ 12877 20.0 23.36 KLBS ROTARY RPM 149 @ 12719 0 @ 12968 107.2 123.37 RPM PUMP PRESSURE 2989 @ 12952 0 @ 12876 2868.5 2905.08 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12424' TO TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 115 @ 12819 6 @ 12752 26.0 TRIP GAS - CUTTING GAS 0 @ 13037 0 @ 13037 0.0 WIPER GAS 82u CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 23278 @ 12820 651 @ 12752 4764.0 CONNECTION GAS HIGH - ETHANE (C-2) 1539 @ 12820 10 @ 12963 319.3 AVG - PROPANE (C-3) 972 @ 12820 8 @ 12969 144.1 CURRENT 10u BUTANE (C-4) 393 @ 12821 0 @ 12779 68.4 CURRENT BACKGROUND/AVG 3u/10u PENTANE (C-5) 120 @ 12823 0 @ 12779 20.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock PRESENT LITHOLOGY Sand 60%, Tuffaceous Siltstone 20%, Tuffaceous Claystone 20% DAILY ACTIVITY SUMMARY Drilled ahead from 12658' to 12878'. Wiper trip to 11020'. Ran in hole back to bottom and resumed drilling. Drilling ahead at 13037' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 16, 2017 DEPTH 13272' PRESENT OPERATION Pulling out of hole TIME 23:59 YESTERDAY 13037' 24 HOUR FOOTAGE 235' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12839.74' 74.87 191.59 9594.84' 12932.66' 73.92 192.33 9619.84' 13029.17' 75.39 193.62 9645.38' 13123.84' 79.82 195.47 9665.70' 13218.65' 84.45 198.32 9678.67' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HDBS MMD75DC 12920423 7X12 12424' 13272' 848' 22:27 Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 132.0 @ 13164 0.7 @ 13197 61.1 1.47 FT/HR SURFACE TORQUE 27366 @ 13165 18023 @ 13055 23473.4 18667.64 AMPS WEIGHT ON BIT 28 @ 13250 6 @ 13252 20.3 17.69 KLBS ROTARY RPM 141 @ 13226 96 @ 13198 118.5 116.65 RPM PUMP PRESSURE 2952 @ 13168 2418 @ 13171 2905.9 2934.25 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12424' TO 13272' TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 53 @ 13184 8 @ 13066 24.7 TRIP GAS - CUTTING GAS 0 @ 13272 0 @ 13272 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 10303 @ 13184 1512 @ 13160 4494.5 CONNECTION GAS HIGH - ETHANE (C-2) 711 @ 13187 36 @ 13229 281.8 AVG - PROPANE (C-3) 349 @ 13184 21 @ 13229 121.9 CURRENT 1u BUTANE (C-4) 147 @ 13186 17 @ 13133 57.6 CURRENT BACKGROUND/AVG 3u/1u PENTANE (C-5) 60 @ 13184 1 @ 13142 21.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled ahead to 13272'. Low penetration rate. Circulated bottoms up then began pulling out of hole. Pulling out of hole at 5084' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 17, 2017 DEPTH 13272' PRESENT OPERATION Testing BOP TIME 23:59 YESTERDAY 13272' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12839.74' 74.87° 191.59° 9594.84' 12932.66' 73.92° 192.33° 9619.84' 13029.17' 75.39° 193.62° 9645.38' 13123.84' 79.82° 195.47° 9665.70' 13218.65' 84.45° 198.32° 9678.67' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 1/2" HDBS MMD75DC 12920423 7X12 12424' 13272' 848' 22:27 1-2-CT-N-X-I-WT-PR Low ROP 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 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 12424' TO 13272' TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT 0u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Pulled out of hole to surface, laid down BHA. Testing BOP @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 18, 2017 DEPTH 13272' PRESENT OPERATION Running in hole TIME 23:59 YESTERDAY 13272' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' 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 1/2" Varel V711PDG1HRU 4009435 4X12, 4X11 13272' 0' 00:00 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 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT 0u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Completed BOP testing. Troubleshot new directional BHA and began run back in hole. Running in hole at 6560' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 19, 2017 DEPTH 13424' PRESENT OPERATION Wiper Trip TIME 23:59 YESTERDAY 13272' 24 HOUR FOOTAGE 152' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13322.14' 83.39° 198.79° 9689.63' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8 1/2" Varel V711PDG1HRU 4009435 4X12, 4X11 13272' 152' 03:27 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 130.4 @ 13296 1.1 @ 13370 64.1 75.21 FT/HR SURFACE TORQUE 27262 @ 13405 17859 @ 13370 23252.3 19484.37 AMPS WEIGHT ON BIT 48 @ 13412 8 @ 13364 21.7 48.02 KLBS ROTARY RPM 173 @ 13301 69 @ 13350 121.5 123.64 RPM PUMP PRESSURE 3201 @ 13274 2451 @ 13321 3070.8 3042.97 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 56 @ 13293 11 @ 13358 26.3 TRIP GAS 400u CUTTING GAS 0 @ 13424 0 @ 13424 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 12000 @ 13294 1877 @ 13356 5260.4 CONNECTION GAS HIGH - ETHANE (C-2) 574 @ 13296 23 @ 13391 180.4 AVG - PROPANE (C-3) 257 @ 13295 16 @ 13358 84.4 CURRENT 3u BUTANE (C-4) 96 @ 13296 4 @ 13315 35.2 CURRENT BACKGROUND/AVG 3u/3u PENTANE (C-5) 33 @ 13296 5 @ 13283 8.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Ran back in hole to bottom with new bit & BHA. Resumed drilling from 13272' to 13424'. Began wiper trip to 11070' to rearrange position of torque reducers. Running back to bottom @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 20, 2017 DEPTH 13890' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 13424' 24 HOUR FOOTAGE 466' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13416.39' 82.92° 198.11° 9700.86' 13511.09' 83.67° 198.13° 9711.92' 13606.39' 83.10° 199.58° 9722.89' 13701.97' 84.92° 198.41° 9732.87' 13796.67' 85.08° 197.70° 9741.12' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8 1/2" Varel V711PDG1HRU 4009435 4X12, 4X11 13272' 618' 11:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 233 @ 13632 1.2 @ 13628 98.6 44.50 FT/HR SURFACE TORQUE 29959 @ 13680 18112 @ 13704 25684.9 22020.04 AMPS WEIGHT ON BIT 48 @ 13424 2 @ 13648 16.9 33.54 KLBS ROTARY RPM 172 @ 13681 71 @ 13461 140.0 117.41 RPM PUMP PRESSURE 3318 @ 13861 2313 @ 13494 3020.5 3082.95 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 72 @ 13822 5 @ 13890 19.4 TRIP GAS - CUTTING GAS 0 @ 13890 0 @ 13890 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 15862 @ 13822 358 @ 13889 3818.0 CONN ECTION GAS HIGH - ETHANE (C-2) 727 @ 13822 16 @ 13451 142.8 AVG - PROPANE (C-3) 455 @ 13822 7 @ 13454 79.4 CURRENT 5u BUTANE (C-4) 222 @ 13822 0 @ 13548 36.3 CURRENT BACKGROUND/AVG 3u/5u PENTANE (C-5) 71 @ 13822 5 @ 13608 9.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY Sand 60%, Tuffaceous Siltstone 20%, Tuffaceous Claystone 20% DAILY ACTIVITY SUMMARY Ran in hole back to bottom. Drilled ahead from 13424'. Drilling ahead at 13890' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 21, 2017 DEPTH 13922' PRESENT OPERATION Replacing BHA TIME 23:59 YESTERDAY 13890' 24 HOUR FOOTAGE 32' CASING INFORMATION 9 5/8" @ 7279' 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 1/2" Varel V711PDG1HRU 4009435 4X12, 4X11 13272' 13922' 650' 13:39 Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 208.1 @ 13901 0.2 @ 13893 55.3 14.16 FT/HR SURFACE TORQUE 23971 @ 13909 15429 @ 13922 22877.0 15429.61 AMPS WEIGHT ON BIT 65 @ 13922 8 @ 13917 33.4 65.96 KLBS ROTARY RPM 139 @ 13895 0 @ 13922 114.6 0.20 RPM PUMP PRESSURE 3108 @ 13892 2382 @ 13909 2610.0 2509.54 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 13272' TO 13922' TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 8 @ 13899 4 @ 13922 7.1 TRIP GAS - CUTTING GAS 0 @ 13922 0 @ 13922 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 709 @ 13900 206 @ 13922 493.3 CONNECTION GAS HIGH - ETHANE (C-2) 94 @ 13900 16 @ 13922 49.1 AVG - PROPANE (C-3) 44 @ 13900 8 @ 13922 23.6 CURRENT 0u BUTANE (C-4) 34 @ 13904 4 @ 13911 17.5 CURRENT BACKGROUND/AVG 3u/0u PENTANE (C-5) 19 @ 13904 11 @ 13905 1.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled Ahead to 13922'. Low ROP and sticking on bottom. Broke free and pulled out of hole to surface. At surface replacing BHA @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR E. Harness / H. Soule DATE Jun 21, 2017 DEPTH 13922' PRESENT OPERATION Replacing BHA TIME 23:59 YESTERDAY 13890' 24 HOUR FOOTAGE 32' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13796.67' 85.08° 197.70° 9741.12' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8 1/2" Varel V711PDG1HRU 4009435 4X12, 4X11 13272' 13922' 650' 13:39 Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 208.1 @ 13901 0.2 @ 13893 55.3 14.16 FT/HR SURFACE TORQUE 23971 @ 13909 15429 @ 13922 22877.0 15429.61 AMPS WEIGHT ON BIT 65 @ 13922 8 @ 13917 33.4 65.96 KLBS ROTARY RPM 139 @ 13895 0 @ 13922 114.6 0.20 RPM PUMP PRESSURE 3108 @ 13892 2382 @ 13909 2610.0 2509.54 PSI DRILLING MUD REPORT DEPTH 13890 MW 9.05 VIS 70 PV 27 YP 19 FL 3.6 Gels 12/25/27 CL-- FC 0/3 SOL 9.0 SD 0.01 OIL 81.5/18.5 MBL - pH - Ca+ 13.06 CCI - MWD SUMMARY INTERVAL 13272' TO 13922' TOOLS Geo-Pilot 7600EDL GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 8 @ 13899 4 @ 13922 7.1 TRIP GAS - CUTTING GAS 0 @ 13922 0 @ 13922 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 709 @ 13900 206 @ 13922 493.3 CONNECTION GAS HIGH - ETHANE (C-2) 94 @ 13900 16 @ 13922 49.1 AVG - PROPANE (C-3) 44 @ 13900 8 @ 13922 23.6 CURRENT 0u BUTANE (C-4) 34 @ 13904 4 @ 13911 17.5 CURRENT BACKGROUND/AVG 3u/0u PENTANE (C-5) 19 @ 13904 11 @ 13905 1.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY Sand 60%, Tuffaceous Sandstone 10%, Conglomerate Sand 10%, Tuffaceous Siltstone 10%, Carbonaceous Shale 10% @ 13,920' DAILY ACTIVITY SUMMARY Drilled Ahead to 13922'. Low ROP and sticking on bottom. Broke free and pulled out of hole to surface. At surface replacing BHA @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / A. Lundale DATE Jun 22, 2017 DEPTH 13922' PRESENT OPERATION Running In Hole TIME 23:59 YESTERDAY 13922' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13416.39' 82.92° 198.11° 9700.86' 13511.09' 83.67° 198.13° 9711.92' 13606.39' 83.10° 199.58° 9722.89' 13701.97' 84.92° 198.41° 9732.87' 13796.67' 85.08° 197.70° 9741.12' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" HDBS MM75D 12670051 5X14 13922' 0' 00:00 4 8 1/2" Varel V711PDG1HRU 4009435 4X12, 4X11 13272' 13922' 650' 13:39 4-2-BT-C-X-I-CT-PR Low ROP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A - FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A - AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A - KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A - RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A - PSI DRILLING MUD REPORT DEPTH 13922' MW 9.05 VIS 90 PV 26 YP 14 FL 2.8 Gels 11/26/30 CL-- FC 0/3 SOL 9.7 SD 0 OIL 83.6/16.4 MBL - pH - Ca+ 14.03 CCI - MWD SUMMARY INTERVAL 13922' TO TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS 94u CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS 132u CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 8u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 3u/8u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2 PRESENT LITHOLOGY Sand 60%, Tuffaceous Sandstone 10%, Conglomerate Sand 10%, Tuffaceous Siltstone 10%, Carbonaceous Shale 10% @ 13920' DAILY ACTIVITY SUMMARY Replaced bit & BHA, changing from rotary steerable to mudmotor with 1.22° bend. Ran back in hole. Worked tight spot @ 13500- 13600. RIH at 13709' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / A. Lundale DATE Jun 23, 2017 DEPTH 15003' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 13922' 24 HOUR FOOTAGE 1081' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 14581.70' 85.56° 196.56° 9809.28' 14676.75' 85.31° 195.87° 9816.85' 14771.50' 85.01° 195.68° 9824.84' 14867.10' 84.45° 194.62° 9833.62' 14964.56' 83.51° 194.61° 9843.84' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" HDBS MM75D 12670051 5X14 13922' 1081' 09:18 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 210.1 @ 14760 2.5 @ 14295 133.6 147.60 FT/HR SURFACE TORQUE 24204 @ 14992 0 @ 14908 14339.0 23507.34 AMPS WEIGHT ON BIT 100 @ 14908 0 @ 13931 10.8 15.41 KLBS ROTARY RPM 106 @ 14388 0 @ 13922 97.9 96.87 RPM PUMP PRESSURE 3651 @ 13984 21 @ 14908 3364.2 3570.33 PSI DRILLING MUD REPORT DEPTH 13922' MW 9.05 VIS 90 PV 31 YP 16 FL 2.8 Gels 15/29/34 CL-- FC 0/3 SOL 10.2 SD 0 OIL 84.1/15.9 MBL - pH - Ca+ 15.97 CCI - MWD SUMMARY INTERVAL 13922' TO TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 61 @ 14130 4 @ 13922 27.5 TRIP GAS - CUTTING GAS 0 @ 15003 0 @ 15003 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 13570 @ 14131 206 @ 13922 5538.6 CONNECTION GAS HIGH - ETHANE (C-2) 936 @ 14988 16 @ 13922 307.0 AVG - PROPANE (C-3) 390 @ 14508 8 @ 13922 140.3 CURRENT 8u BUTANE (C-4) 188 @ 14508 4 @ 14034 70.0 CURRENT BACKGROUND/AVG 3u/28u PENTANE (C-5) 67 @ 14509 2 @ 14061 26.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 40%, Tuffaceous Sandstone 30%, Conglomerate 10%, Tuffaceous Siltstone 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Completed RIH to 13922' and resumed drilling @ 01:40. Drilled ahead from 13922' to 15003'. Pulled out of hole 10 stands for short wiper trip then ran in hole back to 15003'. Resuming drilling ahead right @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / A. Lundale DATE Jun 24, 2017 DEPTH 15472' PRESENT OPERATION Pulling Out Of Hole TIME 23:59 YESTERDAY 15003' 24 HOUR FOOTAGE 469' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' proj. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8 1/2" HDBS MM75D 12670051 5X14 13922' 15472' 1550' 13:24 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 600.7 @ 15381 2.1 @ 15067 157.3 124.09 FT/HR SURFACE TORQUE 27291 @ 15450 21461 @ 15074 24078.9 23788.83 AMPS WEIGHT ON BIT 17 @ 15085 1 @ 15009 12.9 13.81 KLBS ROTARY RPM 113 @ 15288 84 @ 15012 104.3 100.99 RPM PUMP PRESSURE 3631 @ 15434 2584 @ 15202 3423.8 3513.18 PSI DRILLING MUD REPORT DEPTH 15003' MW 9.05 VIS 76 PV 29 YP 16 FL 3.8 Gels 14/26/28 CL-- FC 0/3 SOL 9.7 SD 0 OIL 83.6/16.4 MBL - pH - Ca+ 15.00 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 48 @ 15381 7 @ 15115 26.9 TRIP GAS - CUTTING GAS 0 @ 15472 0 @ 15472 0.0 WIPER GAS 42u CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 9809 @ 15381 1291 @ 15008 4968.1 CONNECTION GAS HIGH - ETHANE (C-2) 1050 @ 15048 111 @ 15006 560.3 AVG - PROPANE (C-3) 388 @ 15381 22 @ 15007 151.2 CURRENT 0u BUTANE (C-4) 164 @ 15439 14 @ 15286 63.4 CURRENT BACKGROUND/AVG 3u/27u PENTANE (C-5) 67 @ 15439 2 @ 15115 22.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Resumed drilling at 15003' after wiper trip. Drilled to TD @ 15472'. Circulated bottoms up then began pulling out of hole. Pulling out at 3120' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $4570 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / A. Lundale DATE Jun 25, 2017 DEPTH 15472' PRESENT OPERATION Cleanout Run TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' proj. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5rr 8 1/2" HDBS MM75D 12670051 5X14 15472' 15472' 0' 00:02 5 8 1/2" HDBS MM75D 12670051 5X14 13922' 15472' 1550' 13:24 2-1-CT-C-X-I-SD-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.10 VIS 68 PV 28 YP 12 FL 3.8 Gels 9/20/22 CL- - FC 0/3 SOL 10.2 SD 0.10 OIL 83.0/17.0 MBL - pH - Ca+ 14.03 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS 118u CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 7u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 3u/10u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Pulled out of hole, laid down BHA, Ran back in hole w/ cleanout assembly. Slip & cut drill line at the window. Continue RIH to TD. Circulating at TD @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / A. Lundale DATE Jun 26, 2017 DEPTH 15472' PRESENT OPERATION Cleanout Run TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' proj. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5rr 8 1/2" HDBS MM75D 12670051 5X14 15472' 15472' 0' 00:02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.25 VIS 68 PV 25 YP 12 FL 3.8 Gels 11/22/24 CL-- FC 0/3 SOL 10.7 SD 0.10 OIL 83.4/16.6 MBL - pH - Ca+ 15.97 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS - CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS 74u CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 9u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 3u/8u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Circulated bottoms up at TD then pulled out of hole to window, working tight spot @ 12,700'. Ran back in hole to TD. Circulating at TD @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / A. Lundale DATE Jun 27, 2017 DEPTH 15472' PRESENT OPERATION Running Liner TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' proj. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5rr 8 1/2" HDBS MM75D 12670051 5X14 15472' 15472' 0' 00:02 2-1-CT-C-X-I-SD-TD C/O Run complete DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.30 VIS 85 PV 27 YP 12 FL 3.8 Gels 9/20/22 CL- - FC 0/3 SOL 10.2 SD 0.10 OIL 83.0/17.0 MBL - pH - Ca+ 13.06 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS - CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 2u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 2u/6u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Pulled out of hole to window, pumped dry job, completed pulling out of hole and laid down BHA/Cleanout assembly. Rig up and run 7" liner. Running 7" liner near 600' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / H. Soule DATE Jun 28, 2017 DEPTH 15472' PRESENT OPERATION Running Liner TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' proj. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5rr 8 1/2" HDBS MM75D 12670051 5X14 15472' 15472' 0' 00:02 2-1-CT-C-X-I-SD-TD C/O Run complete DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.35 VIS 103 PV 28 YP 12 FL 4.2 Gels 9/20/23 CL-- FC 0/3 SOL 10.9 SD 0.10 OIL 82.9/17.1 MBL - pH - Ca+ 12.09 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS 123u CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 0u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 2u/2u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Continued running liner to window. Circulated & conditioned mud, got parameters with drive sub. Continued running liner into open hole to hanger & packer assembly. Make up hanger & packer assembly as per Baker rep. Continued running liner into open hole on drill pipe from derrick. Currently running in at 9400' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / H. Soule DATE Jun 29, 2017 DEPTH 15472' PRESENT OPERATION Pulling Out Of Hole TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' proj. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5rr 8 1/2" HDBS MM75D 12670051 5X14 15472' 15472' 0' 00:02 2-1-CT-C-X-I-SD-TD C/O Run complete DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.40 VIS 128 PV 28 YP 13 FL 4.2 Gels 10/22/26 CL- - FC 0/3 SOL 10.7 SD 0.10 OIL 82.9/17.1 MBL - pH - Ca+ 14.51 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS 134u CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 0u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 2u/2u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Continued running liner in open hole to TD, final value TBD. Circulated & conditioned mud for cement job. Rigged up cementers. Pumped cement job. Had trouble setting packer. Circulated 2x bottoms up, washed up coal cuttings. Rig down cementers. Pumped dry job, detached drill pipe from liner top and pulled drill pipe out of hole. Laying down Baker running tool @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp Hilcorp Alaska LLC McArthur River Field DAILY WELLSITE REPORT TBU M-06RD REPORT FOR S. Hauck / H. Soule DATE Jun 30, 2017 DEPTH 15472' PRESENT OPERATION Running In Hole TIME 23:59 YESTERDAY 15472' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 7279' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 15153.04' 82.45° 194.95° 9867.35' 15245.60' 81.96° 194.89° 9879.91' 15341.19' 81.77° 194.85° 9893.43' 15435.57' 82.28° 194.45° 9906.53' 15472.00' proj. 82.28° 194.45° 9911.42' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 6" Roller cone (cement cleanout) N/A N/A N/A N/A N/A N/A DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION N/A @ N/A N/A @ N/A N/A N/A FT/HR SURFACE TORQUE N/A @ N/A N/A @ N/A N/A N/A AMPS WEIGHT ON BIT N/A @ N/A N/A @ N/A N/A N/A KLBS ROTARY RPM N/A @ N/A N/A @ N/A N/A N/A RPM PUMP PRESSURE N/A @ N/A N/A @ N/A N/A N/A PSI DRILLING MUD REPORT DEPTH 15472' MW 9.45 VIS 151 PV 30 YP 14 FL 4.0 Gels 10/21/23 CL- - FC 0/3 SOL 10.4 SD 0.10 OIL 82.9/17.1 MBL - pH - Ca+ 14.03 CCI - MWD SUMMARY INTERVAL 13922' TO 15472' TOOLS SperryDrill Motor w/ 1.22° bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS N/A @ N/A N/A @ N/A N/A TRIP GAS - CUTTING GAS N/A @ N/A N/A @ N/A N/A WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) N/A @ N/A N/A @ N/A N/A CONNECTION GAS HIGH - ETHANE (C-2) N/A @ N/A N/A @ N/A N/A AVG - PROPANE (C-3) N/A @ N/A N/A @ N/A N/A CURRENT 0u BUTANE (C-4) N/A @ N/A N/A @ N/A N/A CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) N/A @ N/A N/A @ N/A N/A HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland 2/3 PRESENT LITHOLOGY Sand 30%, Tuffaceous Sandstone 30%, Tuffaceous Siltstone 20%, Conglomerate 10%, Tuffaceous Claystone 10% DAILY ACTIVITY SUMMARY Checked running tool; good. Changed out lower rams to VBR and tested. Picked up casing scraper BHA and singled in on 4" DP to 4172'. P/U second 7" scraper. Running in hole at 4172' @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3675 REPORT BY Garnet Knopp
