The URL can be used to link to this page

Home My WebLink About216-137Nolan 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: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40748KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250715 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf BRU 211-35 50283201890000 223050 6/2/2025 AK E-LINE Perf BRU 213-26 50283201920000 223069 6/23/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/4/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/22/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/12/2025 AK E-LINE PPROF BRU 241-23 50283201910000 223061 6/10/2025 AK E-LINE Cement/Perf BRU 241-23 50283201910000 223061 6/19/2025 AK E-LINE CIBP BRU 241-23 50283201910000 223061 6/21/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 6/4/2025 AK E-LINE PlugPerf KBU 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf LIS L5-26 50029220790000 190110 6/21/2025 AK E-LINE Patch MRU M-25 50733203910000 187086 6/17/2025 AK E-LINE CIBP PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN PBU 18-15C 50029217550300 211172 6/12/2025 AK E-LINE CBL/Perf PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM SRU 241-33B 50133206960000 221053 5/25/2025 AK E-LINE CIBP Please include current contact information if different from above. T40659 T40660 T40661 T40662 T40663 T40664 T40664 T40664 T40665 T40665 T40665 T40665 T40666 T40667 T40668 T40669 T40670 T40671 T40672 T40673 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.16 10:52:24 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 9/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240927 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 8/14/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 8/18/2024 YELLOWJACKET PERF BRU 214-13 50283201870000 222117 9/13/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 9/9/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 8/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 9/14/2024 AK E-LINE CBL END 1-61 50029225200000 194142 9/11/2024 READ CaliperSurvey KBU 32-06 50133206580000 216137 8/6/2024 YELLOWJACKET PERF MPU B-24 50029226420000 196009 9/9/2024 READ CaliperSurvey MPU L-03 50029219990000 190007 9/18/2024 READ CaliperSurvey MPU R-103 50029237990000 224114 9/16/2024 AK E-LINE TubingCut MPU R-103 50029237990000 224114 9/19/2024 AK E-LINE TubingCut MRU M-02 50733203890000 187061 9/17/2024 AK E-LINE Plug NCIU A-19 50883201940000 224026 9/20/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/13/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/15/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/18/2024 AK E-LINE CBL NCIU A-20 50883201960000 224065 9/11/2024 AK E-LINE PPROF NCIU A-20 50883201960000 224065 8/26/2024 READ MemoryRadialCementBondLog PBU 09-27A 50029212910100 215206 9/13/2024 AK E-LINE CBL/TubingPunch PBU 09-34A 50029213290100 193201 12/31/2023 YELLOWJACKET PL PBU 13-24B 50029207390200 224087 8/21/2024 YELLOWJACKET CBL-PERF PBU 13-24B 50029207390200 224087 8/23/2024 YELLOWJACKET CBL PBU 13-26 50029207460000 182074 8/13/2024 YELLOWJACKET CCL PBU NK-26A 50029224400100 218009 7/20/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T39593 T39594 T39595 T39596 T39597 T39598 T39599 T39600 T39601 T39602 T39603 T39603 T39604 T39605 T39605 T39605 T39605 T39606 T39606 T39607 T39608 T39609 T39609 T39610 T39611 KBU 32-06 50133206580000 216137 8/6/2024 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.27 14:47:28 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 3. Address: 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 10,560 feet N/A feet true vertical 9,723 feet N/A feet Effective Depth measured 10,462 feet 6,263 feet true vertical 9,626 feet 5,578 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 10,547' MD 9,710' TVD Packers and SSSV (type, measured and true vertical depth) 4-1/2" Swell Pkr; N/A 6,263' MD 5,578' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4,790psi 7,500psi 5,210psi 6,890psi 8,430psi 1,499' 1,452' Burst Collapse 2,480psi Production Liner 6,801' 10,547' Casing Structural 6,089' 9,710' 6,801' 10,547' 120'Conductor Surface Intermediate 16" 10-3/4" 120' 1,499' measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-137 50-133-20658-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEE FEDA028142 Kenai / Beluga/Up Tyonek Gas, Tyonek Gas Kenai Beluga Unit (KBU) 32-06 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 24 Size 120' 37 301796 0 557 37 Chad Helgeson, Operations Engineer 324-402 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1188 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 p k ft t Fra O s 6. A G L PG , 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 8:36 am, Sep 13, 2024 Page 1/1 Well Name: KEU KBU 32-06 Report Printed: 9/5/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:7/22/2024 End Date: Report Number 1 Report Start Date 7/19/2024 Report End Date 7/19/2024 Last 24hr Summary ARRIVED AT FIELD OFFICE. OPENED WORK PERMIT. RIGGED UP ON KBU 32-06. PT PCE 250 - 3000 LBS. PERFORMED DRIFT RUN TO TAG DEPTH. (10,355). POOH. RIH WITH PL LOGGING TOOLS. LOGGED TO BOTTOM. TOOL STARTED SHORTING OUT LOGGING BOTTOM INTERVAL. POOH TO DIAGNOSE ISSUE. DECISION MADE TO LAY DOWN AND RESTART THE FOLLOWING DAY. JOB CONTINUED ON 20-JULY-2024 Report Number 2 Report Start Date 7/20/2024 Report End Date 7/21/2024 Last 24hr Summary PTW, JSA with Ops, MIRU AK Eline. PT Lube 250L/2500H. Ran production per engineers procedure, making multiple passes to 10,300ft. initial down pass @ 160 FPM, 40, 80, 120 Up/down passes from 7900-10300. make station stops @ 10300, 10150, 9700, 9500, 8100, 7900. POOH and RD. Report Number 3 Report Start Date 8/6/2024 Report End Date 8/7/2024 Last 24hr Summary PTW, JSA with YJOS E-line. MIRU PT lubricator 250/2000 psi. RIH perforate D4B sands from 10262'-10287' (25') with 2.75" HSC, 6 spf, 60* phasing. 36 psi flowing tubing pressure. Guns shot up hole. Kinked wire. Re head e line. RIH perforate D4B sands from 10237'-10262' (25') 100 psi flowing tubing pressure. RIH perforate D3B sands from 10104'-10124' (20') 126 psi flowing tubing pressure . Rih perforate D3B sands from 10084'-10104' (20') 126 whp. RIH perforate D3A sands from 10039'-10059' (20'). All shots fired. RIg back YJOS E line unit. Report Number 4 Report Start Date 8/7/2024 Report End Date 8/8/2024 Last 24hr Summary PTW, JSA with YJOS E-line. MIRU. MU Perf guns 2.75" HSC, 6 spf, 60* phasing. RIH re-perf 18' D2 sands from 9762' - 9780' with 131 psi FTP. RIH re-perf 20' D1 sands from 9632' - 9652' with 145 psi FTP. RIH Re-perf 9' UT_1D sands from 8294' - 8303' FTP 145 psi. RIH Re-perf 25' TY 72_8 sands from 8032' - 8057' FTP 145 psi. Rig back YJOS E-Line unit. Report Number 5 Report Start Date 8/8/2024 Report End Date 8/9/2024 Last 24hr Summary PTW, JSA with YJOS E-line. MIRU. MU Perf guns 2.75" HSC, 6 spf, 60* phasing. RIH w/ switch guns. Perforate 9' D1 Upper sands from 9616' - 9625'. Pinched in FTP 106 psi. Perf 17' TY 75_8 sands from 8370' - 8387'. FTP 106 psi. RIH. Perforate 8' TY 73_1 sands from 8069' - 8077'. Pinched in FTP 108 psi. Final FTP 110 psi. All shots fired and in scallops. RD E-Line. Close out PTW and turn well over to Ops. ***Job Complete *** Report Number 6 Report Start Date 8/17/2024 Report End Date 8/17/2024 Last 24hr Summary PTW, JSA with Ops, MIRU AK Eline. PT Lube 250L/2500H. Ran production per engineers procedure, making multiple passes to 10,200ft. initial down pass @ 160 FPM, 40, 80, 120 Up/down passes from 7900-10200. make station stops @ 10000, 9700, 9550, 8200, 8000. POOH and RD. Field: Kenai Gas Field Sundry #: State: Alaska Rig/Service:Permit to Drill (PTD) #:216-137Permit to Drill (PTD) #:216-137 Wellbore API/UWI:50-133-20658-00-00 Updated by DMA 08-28-24 SCHEMATIC Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00-00 PBTD = 10,462 MD / 9,626 TVD TD = 10,560 MD / 9,723 TVD Max Dev 38 deg @ 2,629 RKB = 18.65 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 109 X-56 Weld 15Surf 120' 10-3/4"Surf. Csg 45.5 L-80 Buttress 9.95Surf 1,499 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 6,801 TUBING 4-1/2"Production 12.6 L-80 DWC/C HT 3.958Surf 10,547 116 10-3/4 4-1/2 No. Depth ID Item 1 204.276Tubing Hanger 2 6,263'4.27615 ft Swell Packer (Water Swell) 7-5/8 2 RA-C 8,850 RA-B 9,555 RA-A 10,255 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status Beluga/Upper Tyonek Gas Pool Top: 5,293 MD, 4,656 TVD. TY 72-8 8,0328,0577,2647,28925Beluga/Upr Ty 10/2/21 Open TY 72-8 8,0328,0577,2647,28925Beluga/Upr Ty 8/7/24 Open TY 73-1 8,0698,0777,2997,3078Beluga/Upr Ty 8/8/24 Open UT 1D 8,294 8,303 7,513 7,522 9Beluga/Upr Ty 10/2/21 Open UT 1D 8,294 8,303 7,513 7,522 9Beluga/Upr Ty 8/7/24 Open TY 75-8 8,370 8,387 7,586 7,602 17Beluga/Upr Ty 8/8/24 Open TY D1U 9,616 9,625 8,788 8,797 9Beluga/Upr Ty 8/8/24 Open TY D1 9,632 9,655 8,805 8,828 23Beluga/Upr Ty 10/1/21 Open TY D1 9,632 9,652 8,805 8,825 21Beluga/Upr Ty 8/7/24 Open Tyonek Deep 1 Gas Pool Top: 9,742 MD, 8,917 TVD. D-2 9,762 9,780 8,933 8,951 18Ty Gas Pool #1 6/9/20 Open D-2 9,762 9,780 8,933 8,951 18Ty Gas Pool #1 8/7/24 Open D-3A 10,039 10,059 9,207 9,227 20Ty Gas Pool #1 8/6/24 Open D-3A 10,041 10,059 9,209 9,227 18Ty Gas Pool #1 12/10/19 Open D-3B 10,084 10,124 9,252 9,291 40Ty Gas Pool #1 6/9/20 Open D-3B 10,084 10,124 9,252 9,291 40Ty Gas Pool #1 8/6/24 Open D-4B 10,237 10,287 9,403 9,452 50Ty Gas Pool #1 7/3/18 Open D-4B 10,237 10,287 9,403 9,452 50Ty Gas Pool #1 8/6/24 Open D-4C 10,312 10,327 9,477 9,492 15Ty Gas Pool #1 4/4/17 Open D-4D 10,333 10,347 9,498 9,512 14Ty Gas Pool #1 4/4/17 Open D-4D 10,369 10,3929,534 9,556 23Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/413-1/2 hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8 hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710 MD 4-1/26-3/4 hole. 160 bbls 15.3 Class G pumped with 100% returns.3/22/17 CBL shows ToC at 5126 MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 Note: Comingled production from Tyonek gas Pool #1 and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510C: Last ran: 9/8/23 TY D1 UT D1 TY 72-8 TY 73-1 TY 75-8TY D1U 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: 9/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240909 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 24 50133206390000 214112 8/22/2024 AK E-LINE PPROF BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/9/2024 AK E-LINE PPROF KBU 32-06 50133206580000 216137 8/17/2024 AK E-LINE PPROF KBU 32-06 50133206580000 216137 7/20/2024 AK E-LINE PPROF MPU L-54 50029236070000 218066 8/14/2024 READ Caliper Survey Please include current contact information if different from above. T39522 T39523 T39524 T39525 T39525 T39526 KBU 32-06 50133206580000 216137 8/17/2024 AK E-LINE PPROF KBU 32-06 50133206580000 216137 7/20/2024 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.09 12:37:48 -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 Other: 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,560'N/A Casing Collapse Structural Conductor Surface 2,480 psi Intermediate 4,790 psi Production 7,500 psi Liner 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: Contact Email: Contact Phone: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,430 psi9,710'10,547' 120' 1,499' 6,801' Perforation Depth MD (ft): 10,547'4-1/2" 7-5/8"6,801' 16" 10-3/4" 120' 1,499' 6,890 psi 5,210 psi 120' 1,452' 6,089' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 9,723'10,462'9,626'1,341 N/A MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE FEDA028142 216-137 50-133-20658-00-00 Kenai Gas Field Beluga/Up Tyonek Gas, Tyonek Gas Same CO 510C Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 32-06 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 12.6# / L80 10,547' July 25, 2024 4-1/2" Swell Pkr; N/A 6,263' MD / 5,578' TVD; N/A See Schematic See Schematic 4-1/2" 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: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 m n P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.07.12 16:37:26 - 08'00' Noel Nocas (4361) 324-402 By Grace Christianson at 8:04 am, Jul 15, 2024 Obsolete form. SFD SFD 7/15/2024 DSR-7/15/24 10-404 BJM 7/24/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.25 08:47:55 -08'00'07/25/24 RBDMS JSB 073024 Well Prognosis Well: KBU 32-06 Well Name: KBU 32-06 API Number: 50-113-20658-00-00 Current Status: Gas Producer Permit to Drill Number: 216-137 First Call Engineer: Chad Helgeson (907) 777-8504 (O) (907) 229-4824 (C) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8663 (C) Maximum Expected BHP: ~ 2071psi @ 7,307’ TVD Based on max RFT data from KBU 32-06 obtained in 2017 Max. Potential Surface Pressure:1341 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.68 psi/ft using 13.1 ppg EMW FIT at the intermediate casing shoe Shallowest Allowable Perf TVD: MPSP/(0.68-0.1) = 1341 psi / 0.58 = 2,312‘ TVD Top of Applicable Gas Pool: ~5,293’ MD/ ~4,656’ TVD Well Summary KBU 32-06 is a steady commingled gas producer at Kenai Gas Field. It flows at ~1200mcfd and ~10 bwpd @ 55 psi. This well has commingled production between the Beluga/Upper Tyonek Pool and Tyonek Pool #1. The last production log was run in September of 2023. A cap string was run in Spring of 2024, but was unsuccessful unloading the well, so it was pulled and as needed soap sticks have been used to unload the well. During a recent SL tag event with a bailer after a production decline of 20%, pieces of calcium scale were removed. The goal of this work is to reperf the existing zones in the event that perf tunnels are plugged with scale. However, there are some additional sand opportunities in the Beluga/Upper Tyonek Pool that will also be perforated. Per CO 510C, a production log would be run within 30 days of completing these perforations. The goal of this project is to reperforate some sands in Tyonek Deep 1 Pool and in the Beluga/Upper Tyonek Pool, to add production to the well. Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Max Inclination = 38 degrees at 2629’ MD x Drifts o 7/8/24: SL Worked bridges with a 3.5” DD Bailer @ 9677, 9787, 10087, 10175, 10,280 and worked to 10,389’ Bailer recovered ½ gal of sand and chucks of scale o 12/21/23: SL tagged hydrates @ 288’ & tagged bottom at 10,328’ E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,000 psi High. 3. Run PLT – determine fluid level and zones making water a) If wet zone is deepest in well, set CIBP ~25ft above wet sand b) If plug is set at the top of the Deep Tyonek 1 Pool, dump 25ft of cement on plug 4. RIH and perforate the sands listed in the table below, bottom to top per Geo/RE some additional sand opportunities in the Beluga/Upper Tyonek Pool that will also be perforated. Top of Applicable Gas Pool: MD/ ~4,656’ TVD~5,293’ , equivalent to ~2,568' MD SFD reperf the existing zones Well Prognosis Well: KBU 32-06 Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) TY_72_8 ±8,032’ ±8,057’ ±7,264’ ±7,289’ ±25’ TY_73_1 (new) ±8,069’ ±8,077’ ±7,299’ ±7,307’ ±8’ UT_1D ±8,294’ ±8,303’ ±7,513’ ±7,522’ ±9’ TY_75_8 (new) ±8,370’ ±8,387’ ±7,586’ ±7,602’ ±17’ TY_D1Upr (new) ±9,616’ ±9,625’ ±8,788’ ±8,797’ ±9’ TY_D1 ±9,632’ ±9,652’ ±8,805’ ±8,825’ ±20’ TY_D2 ±9,762’ ±9,780’ ±8,933’ ±8,951’ ±18’ TY_D3A ±10,039’ ±10,059’ ±9,207’ ±9,227’ ±20’ TY_D3B ±10,084’ ±10,124’ ±9,251’ ±9,192’ ±40’ TY_D4B ±10,237’ ±10,287’ ±9,403’ ±9,452’ ±50’ a. New proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot 5. RD E-Line Unit and turn well over to production. SL/EL Production log: Must be run within 30 days of commencement of comingled production, after well has stabilized per CO 510C (unless plug is set over the Tyonek Deep 1 Pool) 1. RU EL/SL and PT lubricator to 250 psi low / 2,000 psi high 2. RIH with PLT logging tool 3. Acquire dynamic passed and stop counts per OE (dependent on what’s shot) 4. Confirm good data, then RDMO EL Attachments: 1. Current schematic 2. Proposed Schematic Updated by DMA 05-01-24 SCHEMATIC Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00-00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 109 X-56 Weld 15”Surf 120' 10-3/4"Surf. Csg 45.5 L-80 Buttress 9.95”Surf 1,499’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 6,801’ TUBING 4-1/2"Production 12.6 L-80 DWC/C HT 3.958”Surf 10,547’ 116” 10-3/4” 4-1/2” No.Depth ID Item 1 20’4.276”Tubing Hanger 2 6,263'4.276”15 ft Swell Packer (Water Swell) 7-5/8” 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status TY_72_8 8,032’8,057’7,264’7,289’25’Beluga/Upr Ty 10/2/21 Open UT_1D 8,294’8,303’7,513’7,522’9’Beluga/Upr Ty 10/2/21 Open TY_D1 9,632’9,655’8,805’8,828’23’Beluga/Upr Ty 10/1/21 Open D-2 9,762’9,780’8,933’8,951’18’Ty Gas Pool #1 6/9/20 Open D-3A 10,041’10,059’9,209’9,277’18’Ty Gas Pool #1 12/10/19 Open D-3B 10,084’10,124’9,252’9,291’40’Ty Gas Pool #1 6/9/20 Open D-4B 10,237’10,287’9,403’9,452’50’Ty Gas Pool #1 7/3/18 Open D-4C 10,312’10,327’9,477’9,492’15’Ty Gas Pool #1 4/4/17 Open D-4D 10,333’10,347’9,498’9,512’14’Ty Gas Pool #1 4/4/17 Open D-4D 10,369’10,392’9,534 9,556’23’Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/4”13-1/2” hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710’ MD 4-1/2”6-3/4” hole. 160 bbls 15.3 Class G pumped with 100% returns.3/22/17 CBL shows ToC at 5126’ MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 Note: Comingled production from Tyonek gas Pool #1 and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510C: Last ran: 9/8/23 TY-D1 UT-1D TY-72-8 Updated by CAH 07-09-24 PROPOSED Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00-00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 109 X-56 Weld 15”Surf 120' 10-3/4"Surf. Csg 45.5 L-80 Buttress 9.95”Surf 1,499’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 6,801’ TUBING 4-1/2"Production 12.6 L-80 DWC/C HT 3.958”Surf 10,547’ 116” 10-3/4” 4-1/2” No.Depth ID Item 1 20’4.276”Tubing Hanger 2 6,263'4.276”15 ft Swell Packer (Water Swell) 7-5/8” 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status Beluga/Upper Tyonek Gas Pool Top: 5,293’ MD, 4,656’ TVD. TY_72_8 8,032’8,057’7,264’7,289’25’Beluga/Upr Ty 10/2/21 Open TY_73-1 ±8,069’±8,077’±7,299’±7,307’±8’Beluga/Upr Ty TBD Proposed UT_1D 8,294’8,303’7,513’7,522’9’Beluga/Upr Ty 10/2/21 Open TY_75-8 ±8,370’±8,387’±7,586’±7,602’±17’Beluga/Upr Ty TBD Proposed TY_D1 Upr 9,616’9,625’8,788’8,797’9’Beluga/Upr Ty TBD Proposed TY_D1 9,632’9,655’8,805’8,828’23’Beluga/Upr Ty 10/1/21 Open Tyonek Deep 1 Gas Pool Top: 9,742’ MD, 8,917’ TVD. D-2 9,762’9,780’8,933’8,951’18’Ty Gas Pool #1 6/9/20 Open D-3A 10,041’10,059’9,209’9,277’18’Ty Gas Pool #1 12/10/19 Open D-3B 10,084’10,124’9,252’9,291’40’Ty Gas Pool #1 6/9/20 Open D-4B 10,237’10,287’9,403’9,452’50’Ty Gas Pool #1 7/3/18 Open D-4C 10,312’10,327’9,477’9,492’15’Ty Gas Pool #1 4/4/17 Open D-4D 10,333’10,347’9,498’9,512’14’Ty Gas Pool #1 4/4/17 Open D-4D 10,369’10,392’9,534 9,556’23’Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/4”13-1/2” hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710’ MD 4-1/2”6-3/4” hole. 160 bbls 15.3 Class G pumped with 100% returns.3/22/17 CBL shows ToC at 5126’ MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 Note: Comingled production from Tyonek gas Pool #1 and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510C: Last ran: 9/8/23 TY-D1 UT-1D TY-72-8 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Installed & Pulled Cap String Development Exploratory 3. Address: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 10,560 feet N/A feet true vertical 9,723 feet N/A feet Effective Depth measured 10,462 feet 6,263 feet true vertical 9,626 feet 5,578 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 10,547' MD 9,710' TVD Packers and SSSV (type, measured and true vertical depth)4-1/2" Swell Pkr; N/A 6,263' MD 5,578' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Chad Helgeson, Operations Engineer 324-100 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 1669 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 30 Size 120' 7 301531 0 392 34 measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-137 50-133-20658-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEE FEDA028142 Kenai / Beluga/Up Tyonek Gas, Tyonek Gas Kenai Beluga Unit (KBU) 32-06 Plugs Junk measured Length Production Liner 6,801' 10,547' Casing Structural 6,089' 9,710' 6,801' 10,547' 120'Conductor Surface Intermediate 16" 10-3/4" 120' 1,499' 4,790psi 7,500psi 5,210psi 6,890psi 8,430psi 1,499'1,452' Burst Collapse 2,480psi p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:10 pm, May 03, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.05.03 13:43:59 -08'00' DSR-5/6/24 RBDMS JSB 051524 Well Name: KEU KBU 32-06 API #:50-133-20658-00-00 Field:Kenai Gas Field Start Date:4/15/2024 Permit #:216-137 Sundry #:324-100 End Date:4/23/2024 4/15/2024 4/17/2024 4/23/2024 Activity Report Pull capillary sting to surface. Recovered all capillary tubing (9630') and foot valve. Rig down cap string tuck. MIRU Cap string truck and install 3/8" SS spool on truck. Stab tubing into injector head and pack off assembly. Make up 3/4" foot valve. Pull soap launcher and stab on well. PT pack off assembly and well connection 250/3500 psi. RIH with cap string. Planned to set at 10,100'. Solid tag at 9751'. RIH weight 800 lbs. PIck up weight 2800 lbs. Pull cap string in tension to 9720' and lock down. Set hydraulic and manual pack off assembly. Install mechanical hanger into packoff profile. Leave truck rigged up. Possibly setting cap string at multiple depths. Pull Cap string up 100' to 9630'. Daily Operations: Page 1 of 1 Updated by DMA 05-01-24 SCHEMATIC Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00-00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 109 X-56 Weld 15”Surf 120' 10-3/4"Surf. Csg 45.5 L-80 Buttress 9.95”Surf 1,499’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 6,801’ TUBING 4-1/2"Production 12.6 L-80 DWC/C HT 3.958”Surf 10,547’ 116” 10-3/4” 4-1/2” No.Depth ID Item 1 20’4.276”Tubing Hanger 2 6,263'4.276”15 ft Swell Packer (Water Swell) 7-5/8” 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status TY_72_8 8,032’8,057’7,264’7,289’25’Beluga/Upr Ty 10/2/21 Open UT_1D 8,294’8,303’7,513’7,522’9’Beluga/Upr Ty 10/2/21 Open TY_D1 9,632’9,655’8,805’8,828’23’Beluga/Upr Ty 10/1/21 Open D-2 9,762’9,780’8,933’8,951’18’Ty Gas Pool #1 6/9/20 Open D-3A 10,041’10,059’9,209’9,277’18’Ty Gas Pool #1 12/10/19 Open D-3B 10,084’10,124’9,252’9,291’40’Ty Gas Pool #1 6/9/20 Open D-4B 10,237’10,287’9,403’9,452’50’Ty Gas Pool #1 7/3/18 Open D-4C 10,312’10,327’9,477’9,492’15’Ty Gas Pool #1 4/4/17 Open D-4D 10,333’10,347’9,498’9,512’14’Ty Gas Pool #1 4/4/17 Open D-4D 10,369’10,392’9,534 9,556’23’Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/4”13-1/2” hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710’ MD 4-1/2”6-3/4” hole. 160 bbls 15.3 Class G pumped with 100% returns.3/22/17 CBL shows ToC at 5126’ MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 Note: Comingled production from Tyonek gas Pool #1 and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510C: Last ran: 9/8/23 TY-D1 UT-1D TY-72-8 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 Other: Install Cap String 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,560'N/A Casing Collapse Structural Conductor Surface 2,480 psi Intermediate 4,790 psi Production 7,500 psi Liner 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: Contact Email: Contact Phone: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,430 psi9,710'10,547' 120' 1,499' 6,801' Perforation Depth MD (ft): 10,547'4-1/2" 7-5/8"6,801' 16" 10-3/4" 120' 1,499' 6,890 psi 5,210 psi 120' 1,452' 6,089' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 9,723'10,462'9,626'~ 350 psi N/A MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE FEDA028142 216-137 50-133-20658-00-00 Kenai Gas Field Beluga/Up Tyonek Gas, Tyonek Gas Same CO 510C Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 32-06 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 12.6# / L80 10,547' March 5, 2024 4-1/2" Swell Pkr; N/A 6,263' MD / 5,578' TVD; N/A See Schematic See Schematic 4-1/2" 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: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 m n P s 66 t g Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:49 pm, Feb 20, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.20 10:59:25 - 09'00' Noel Nocas (4361) 324-100 Obsolete form SFD BJM 2/27/24 DSR-2/21/24SFD 2/23/2024 10-404 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.27 16:33:57 -09'00'02/27/24 RBDMS JSB 022824 Well Prognosis Well: KBU 32-06 Date: 2/6/2024 Well Name: KBU 32-06 API Number: 50-113-20658-00-00 Current Status: Gas Producer Permit to Drill Number: 216-137 First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Max. Expected BHP: ~ 1230 psi @ 8,805’ TVD Based on max RFT data from KBU 32-06 obtained in 2017 Max. Potential Surface Pressure ~ 350 psi Using 0.1 psi/ft gradient Well Summary KBU 32-06 is a steady Tyonek Gas Pool #1 producer. It flows at ~1600mcfd and ~10 bwpd. This well has commingled production between the Beluga/Upper Tyonek Pool and Tyonek Pool #1. The last production log was run in September of 2023. This cap string will need to be pulled to run annual production logs for proper gas allocations. The goal of this project is to install a cap string for methanol or soap injection as needed to optimize well performance. Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Max Inclination = 38 degrees at 2629’ MD x SL (12/21/23) – tagged hydrates @ 288’ & tagged bottom at 10,328’ Procedure 1. RU Cap String Truck 2. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off and pressure test against swab valve to 1500 psi 3. RIH with 3/8” capillary string Initially set at 400’ for Methanol injection a. If production of water becomes problematic, cap string may be moved as deep as practical for foamer injection ~10,100’. 4. Install slips and connect tubing to chemical injection pump. 5. Set spool of remaining string near well 6. RD cap string unit, and turn well over to production. Attachments: 1. Proposed Schematic Updated by CAH 2-6-24 PROPOSED Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00-00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’ CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 109 X-56 Weld 15”Surf 120' 10-3/4"Surf. Csg 45.5 L-80 Buttress 9.95”Surf 1,499’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 6,801’ TUBING 4-1/2"Production 12.6 L-80 DWC/C HT 3.958”Surf 10,547’ 116” 10-3/4” 4-1/2” No.Depth ID Item 1 20’4.276”Tubing Hanger 2 6,263'4.276”15 ft Swell Packer (Water Swell) 7-5/8” 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status TY_72_8 8,032’8,057’7,264’7,289’25’Beluga/Upr Ty 10/2/21 Open UT_1D 8,294’8,303’7,513’7,522’9’Beluga/Upr Ty 10/2/21 Open TY_D1 9,632’9,655’8,805’8,828’23’Beluga/Upr Ty 10/1/21 Open D-2 9,762’9,780’8,933’8,951’18’Ty Gas Pool #1 6/9/20 Open D-3A 10,041’10,059’9,209’9,277’18’Ty Gas Pool #1 12/10/19 Open D-3B 10,084’10,124’9,252’9,291’40’Ty Gas Pool #1 6/9/20 Open D-4B 10,237’10,287’9,403’9,452’50’Ty Gas Pool #1 7/3/18 Open D-4C 10,312’10,327’9,477’9,492’15’Ty Gas Pool #1 4/4/17 Open D-4D 10,333’10,347’9,498’9,512’14’Ty Gas Pool #1 4/4/17 Open D-4D 10,369’10,392’9,534 9,556’23’Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/4”13-1/2” hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710’ MD 4-1/2”6-3/4” hole. 160 bbls 15.3 Class G pumped with 100% returns.3/22/17 CBL shows ToC at 5126’ MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 Note: Comingled production from Tyonek gas Pool #1 and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510C: Last ran: 9/8/23 TY-D1 UT-1D TY-72-8 Capillary String (3/8”) 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: 10/04/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# IRU 41-01 50283200880000 192109 9/17/2023 HALLIBURTON Coilflag KBU 32-06 50133206580000 216137 9/8/2023 HALLIBURTON PPROF LRU C-02 50283201900000 223057 9/13/2023 HALLIBURTON RBT MPU E-37 50029236160000 218158 9/24/2023 READ Caliper Survey MPU F-53A 50029225780100 213136 9/27/2023 READ Caliper Survey MPU F-79 50029228130000 197180 9/26/2023 READ Caliper Survey MPU L-57 50029236090000 218072 9/26/2023 READ Caliper Survey MPU S-06 50029231630000 203109 9/29/2023 READ Caliper Survey MPU B-32 50029235700000 216151 9/12/2023 HALLIBURTON Perf TBU K-09 50733201100000 1068038 10/1/2023 READ Caliper Survey Please include current contact information if different from above. T38028 T38029 T38030 T38031 T38032 T38033 T38034 T38035 T38036 T38037 10/4/2023 KBU 32-06 50133206580000 216137 9/8/2023 HALLIBURTON PPROF Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.04 13:03:04 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: 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 10,560 feet N/A feet true vertical 9,723 feet N/A feet Effective Depth measured 10,462 feet 6,263 feet true vertical 9,626 feet 5,578 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 10,547' 9,710' 4-1/2"6,263' MD Packers and SSSV (type, measured and true vertical depth)Swell packer N/A 5,578' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 4,790psi 7,500psi 5,210psi 6,890psi 8,430psi Burst Collapse 2,470psi 120' 1,452' 6,089' 9,710' 6,801' 10,547'4-1/2" measuredPlugs Junk measured N/A Length 120' 1,499' Size Conductor Surface Intermediate 16" 10-3/4" 7-5/8" Production Liner 6,801' 10,547' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-137 50-133-20658-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEEA028142 Kenai / Tyonek Gas Pool 1, Beluga/Upper Tyonek Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Kenai Beluga Unit 32-06 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 7 1152,322 0 20 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 120' 1,499' 15 Structural TVD 321-492 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 977 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 8 45 Ryan Rupert ryan.rupert@hilcorp.com 777-8503 L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 7:59 am, Oct 28, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.10.27 13:31:13 -08'00' Dan Marlowe (1267) DSR-10/28/21 Perforate Perforate New Pool BJM 11/2/21 SFD 10/28/2021 RBDMS HEW 10/28/2021 Rig Start Date End Date E-Line 10/1/21 10/8/21 10/02/2021 - Saturday TRAVEL FROM HES SHOP TO KENAI GAS FIELD. ARRIVE ON LOCATION, START AND WARM UP EQUIPMENT, INITIATE PERMIT, AND PJSM. BEGIN RIG UP, PICK UP WIRELINE, AND STACK PCE. PRESSURE TEST LUBE 250L/2000H. CHECK FIRE TOOLSTRING, HOOK UP GUNSTRING AND STAB ON WELL.;RIH W/ 1.375" FISHING NECK CH/GPLT/15'x2.875" HSC (3' LOADED). OAL: 24', MAX OD 3.375", TW 300#. LOG CORRELATION PASS FROM 9800'-9500' USING HALLIBURTON SPERRY DRILLING GAMMA RAY LOG AS REFERENCE. SEND TO TOWN FOR APPROVAL. TOLD LOG WAS ON DEPTH. LOG PERFORATION PASS STOPPING AT CCL DEPTH: 9633.5'. CCL TO TOP SHOT OFFSET: 18.5'. PERFORATE 9652'-9655'. LOST 300# AFTER SHOOTING. GOOD INDICATIOn of fire. POOH.;AT SURFACE, SHUT IN AND BLEED OFF. BREAK OFF LUBE AND DROP DOWN SPENT GUN. CHECK FIRE TOOLSTRING AND ARM GUN. STAB ON WELL. RIH W/ 1.375" FISHING NECK CH/GPLT/21'x2.875" HSC (20' LOADED). OAL: 30', MAX OD 3.375", TW 380#. LOG CORRELATION PASS FROM 9800'-9500' USING HALLIBURTON SPERRY DRILLING GAMMA RAY LOG AS REFERENCE. SEND TO TOWN FOR APPROVAL. TOLD LOG WAS ON DEPTH.;LOG PERFORATION PASS STOPPING AT CCL DEPTH: 9624.5'. CCL TO TOP SHOT OFFSET: 7.5'. PERFORATE 9632-9652'. LOST 1000# AFTER SHOOTING. GOOD INDICATION OF FIRE. START TO POOH;AT SURFACE AND APPROXIMATELY 40' FROM THE TOOL TRAP, TENSION STARTED TO RISE. BUMPED THE LINE AND EASED THE KINKS THROUGH THE GREASE TUBES. SHUT IN AND BLEED OFF. BREAK OFF LUBE AND LAY DOWN ON GROUND. BREAK GREASE HEAD APART AND PULLED KINKED LINE OUT OF THE TUBES. REASSEMBLE GREASEHEAD AND RETIE A NEW ROPE SOCKET. DECISION MADE TO RESUME RIG UP AND SHOOT THE REMAINING 3 GUNS TOMORROW. BEGIN RIG UP, PICK UP WIRELINE, AND RAISE LUBE. PRESSURE TEST LUBE 250L/2000H. CHECK FIRE TOOLSTRING, HOOK UP GUNSTRING AND STAB ON WELL. RIH W/ 1.375" FISHING NECK CH/GPLT/15'x2.875" HSC (9' LOADED). OAL: 24', MAX OD 3.375", TW 300#. LOG CORRELATION PASS FROM 8500'-7900' USING HALLIBURTON SPERRY DRILLING GAMMA RAY LOG AS REFERENCE. SEND TO TOWN FOR APPROVAL. TOLD LOG WAS ON DEPTH.;LOG PERFORATION PASS STOPPING AT CCL DEPTH: 8281.5'. CCL TO TOP SHOT OFFSET: 12.5'. PERFORATE 8294'-8303'. LOST 450# AFTER SHOOTING. GOOD INDICATION OF FIRE. START TO POOH. AT SURFACE, SHUT IN AND BLEED OFF. BREAK OFF LUBE AND DROP DOWN SPENT GUN. CHECK FIRE TOOLSTRING AND ARM GUN. STAB ON WELL. RIH W/ 1.375" FISHING NECK CH/GPLT/15'x2.875" HSC (5' LOADED). OAL: 24', MAX OD 3.375", TW 300#;LOG CORRELATION PASS FROM 8250'-7950' USING HALLIBURTON SPERRY DRILLING GAMMA RAY LOG AS REFERENCE. SEND TO TOWN FOR APPROVAL. TOLD LOG WAS ON DEPTH. LOG PERFORATION PASS STOPPING AT CCL DEPTH: 8035.5'. CCL TO TOP SHOT OFFSET: 16.5'. PERFORATE 8052'-8057'. LOST 400# AFTER SHOOTING. GOOD INDICATION OF FIRE. START TO POOH;AT SURFACE, SHUT IN AND BLEED OFF. BREAK OFF LUBE AND DROP DOWN SPENT GUN. CHECK FIRE TOOLSTRING AND ARM GUN. STAB ON WELL. RIH W/ 1.375" FISHING NECK CH/GPLT/21'x2.875" HSC (20' LOADED). OAL: 30', MAX OD 3.375", TW 380#. LOG CORRELATION PASS FROM 8250'- 7950' USING HALLIBURTON SPERRY DRILLING GAMMA RAY LOG AS REFERENCE. SEND TO TOWN FOR APPROVAL. TOLD LOG WAS ON DEPTH.;LOG PERFORATION PASS STOPPING AT CCL DEPTH: 8024.5'. CCL TO TOP SHOT OFFSET: 7.5'. PERFORATE 8032'-8052'. LOST 1000# AFTER SHOOTING. GOOD INDICATION OF FIRE. START TO POOH. AT SURFACE, SHUT IN AND BLEED OFF. BREAK OFF LUBE AND DROP DOWN SPENT GUN. START TO RIG DOWN ELINE. RIG DOWN COMPLETE. PUT EVERYTHING AWAY. Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name KBU 32-06 50-133-20658-00-00 216-137 10/01/2021- Friday PERFORATE 8032'-8052'. PERFORATE 9632-9652'. PERFORATE 8294'-8303'. PERFORATE 9652'-9655'. PERFORATE 8052'-8057'. Rig Start Date End Date E-Line 10/1/21 10/8/21 Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name KBU 32-06 50-133-20658-00-00 216-137 10/08/2021- Friday PTW, JSA with HES slick line crew. MIRU equipment. Program memory tools. Pressure test slick line lubricator 500/2,500 psi. RIH with memory tools. Log 60/90/120 f/min up/down logging passes from 7,900' to 10,350'. Log station stops 7,900' (15min), 8,175', 8900', 9,700' (15min), 9,900', 10,072', 10,175', 10,300', 10,350' all stops besides 2 are 5min. Tag PB @ 10,367'. POOH @ 120f/min with memory tools logging jewelry log. Break off well and DL memory tools, data is good. Rig down SL equipment. Depart location. Updated by DH 10-26-21 SCHEMATIC Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00-00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 109 X-56 Weld 15” Surf 120' 10-3/4" Surf. Csg 45.5 L-80 Buttress 9.95” Surf 1,499’ 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 6,801’ TUBING 4-1/2" Production 12.6 L-80 DWC/C HT 3.958” Surf 10,547’ 116” 10-3/4” 4-1/2” No. Depth ID Item 1 20’ 4.276” Tubing Hanger 2 6,263' 4.276” 15 ft Swell Packer (Water Swell) 7-5/8” 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status TY_72_8 8,032’ 8,057’ 7,264’ 7,289’ 25’ Beluga/Upr Ty 10/2/21 Open UT_1D 8,294’ 8,303’ 7,513’ 7,522’ 9’ Beluga/Upr Ty 10/2/21 Open TY_D1 9,632’ 9,655’ 8,805’ 8,828’ 23’ Beluga/Upr Ty 10/1/21 Open D-2 9,762’ 9,780’ 8,933’ 8,951’ 18’ Ty Gas Pool #1 6/9/20 Open D-3A 10,041’ 10,059’ 9,209’ 9,277’ 18’ Ty Gas Pool #1 12/10/19 Open D-3B 10,084’ 10,124’ 9,252’ 9,291’ 40’ Ty Gas Pool #1 6/9/20 Open D-4B 10,237’ 10,287’ 9,403’ 9,452’ 50’ Ty Gas Pool #1 7/3/18 Open D-4C 10,312’ 10,327’ 9,477’ 9,492’ 15’ Ty Gas Pool #1 4/4/17 Open D-4D 10,333’ 10,347’ 9,498’ 9,512’ 14’ Ty Gas Pool #1 4/4/17 Open D-4D 10,369’ 10,392’ 9,534 9,556’ 23’ Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/4”13-1/2” hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710’ MD 4-1/2”6-3/4” hole. 160 bbls 15.3 Class G pumped with 100% returns. 3/22/17 CBL shows ToC at 5126’ MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 Note: Comingled production from Tyonek gas Pool #1 and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510B:Last ran: 10/08/21 TY-D1 UT-1D TY-72-8 TY_72_8 8,032’ 8,057’ 7,264’ 7,289’ 25’ Beluga/Upr Ty 10/2/21 Open UT_1D 8,294’ 8,303’ 7,513’ 7,522’ 9’ Beluga/Upr Ty 10/2/21 Open TY D1 9,632’ 9,655’ 8,805’ 8,828’ 23’ Beluga/Upr Ty 10/1/21 Open_, , , , g/py//p Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/20/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 32-06 (PTD 261-137) Perf 10/01/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/25/2021 By Abby Bell at 12:35 pm, Oct 25, 2021 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/20/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 32-06 (PTD 184-243) Production Profile 10/08/2021 Report 10/12/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/25/2021 By Abby Bell at 12:33 pm, Oct 25, 2021 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 Other: _N2 / patch___ 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,560'N/A Casing Collapse Structural Conductor Surface 2,480 psi Intermediate 4,790 psi Production 7,500 psi Liner 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 Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 777-8503 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng ryan.rupert @hilcorp.com 9,723'10,462'9,626'~ 1230 psi N/A 4-1/2" Swell Pkr; N/A 6,263' MD / 5,578' TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A028142 216-137 50-133-20658-00-00 KBU 32-06 Kenai Gas Field / Beluga/Upper Tyonek Gas Pool, Tyonek Gas Pool 1 Length Size CO 510B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 12.6# / L80 TVD Burst 10,547' 8,430 psi MD 6,890 psi 5,210 psi 120' 1,452' 6,089' 120' 1,499' 9,710'4-1/2" 16" 10-3/4" 120' 7-5/8"6,801' 1,499' 10,547' Perforation Depth MD (ft): 6,801' See Attached Schematic 10,547' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: October 6, 2021 4-1/2" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 8:03 am, Sep 21, 2021 321-492 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.20 21:45:13 -08'00' Taylor Wellman (2143) BJM 9/28/21 SFD 9/26/2021 Perforate New Pool 10-404 DSR-9/27/21 dts 9/29/2021 JLC 9/29/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.29 10:22:48 -08'00' RBDMS HEW 9/30/2021 Well Prognosis Well: KBU 32-06 Date: 9/20/2021 Well Name:KBU 32-06 API Number:50-113-20658-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:216-137 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Max. Expected BHP:~ 1230 psi @ 8,805’ TVD Based on max RFT data from KBU 32-06 obtained in 2017 Max. Potential Surface Pressure ~ 1230 psi (Based on max BHP to surface) Well Summary KBU 32-06 is a steady Tyonek Gas Pool #1 producer. It flows at ~1000mcfd and 10 bwpd. Given the opportunity uphole in the Beluga/Upper Tyonek Pool, additional perforations are proposed below. CO 510B Rule #5 allows comingling of the Beluga/Upper Tyonek Pool, Tyonek Pool #1, and the Kenai Deep Tyonek Pools, as long as certain post-perf production logging requirements are met. This job will comingle the existing Tyonek Gas Pool #1 perfs with proposed perfs in the Beluga/Upper Tyonek Pool. A production log will be obtained within 30 days of comingling, per CO 510B. The goal of this project is to perforate uphole sands in the Beluga/Upper Tyonek Pool, to add production to the well Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Max Inclination = 38 degrees at 2629’ MD x Drifts o 5/11/21: SL made it to 10,377’ with a 2.75” blind box and tagged SL set down at 10,044’ with a 3.80” centralizer o 4/15/21: SL mentioned a tight spot at 8200’while POOH with the vortex tool o 2/26/21: SL set vortex tool at 9712’ MD. Had a premature setdown at 8166’. o 6/9/20: EL GPT tagged PBTD at 10,320’ MD and found FL at 10,266’ MD EL made it as deep as 10,124’ (no tag) with a 20’ x 2-7/8” gun. EL did have hangups and got stuck below 9780’ MD with the final 2-7/8” gun.Could move down, but not up. Worked free. o 12/10/19: EL GPT found fluid at 10,260’ MD (no tag) EL shot an 18’ x 2-7/8” gun and got as deep as 10,059’ MD. (no tag) o 7/3/18: EL GPT found fluid at 10,350’ MD (no tag) EL shot a 28’ x 2-7/8” gun and got as deep as 10,287’ MD. (no tag) CO 510B Rule #5 allows comingling of the Beluga/Upper Tyonek Pool, Tyonek Pool #1, This job will comingle the existing Tyonek Gas Pool #1 perfs with proposed perfs in the Beluga/Upper Tyonek Pool. Well Prognosis Well: KBU 32-06 Date: 9/20/2021 Nitrogen Risk x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) x Ensure all crews are aware of stop work authority E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,000 psi High. 3. Consult with OE to determine if Nitrogen is needed to pressure up wellbore 4. RU Nitrogen Truck 5. Pressure up wellbore per OE 6. Rig up perf gun (Likely 2-7/8” 4-6 spf) 7. RIH and perforate the sand listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) LB1B ±6,879’±6,892’±6,163’±6,176’±13’ LB1D ±6,977’±6,999’±6,255’±6,277’±22’ LB3 ±7,414’±7,425’±6,669’±6,680’±11’ LB4B ±7,667’±7,683’±6,913’±6,929’±16’ LB4C ±7,724’±7,733’±6,968’±6,977’±9’ LB5B ±7,877’±7,884’±7,115’±7,122’±7’ LB5C ±7,890’±7,910’±7,128’±7,148’±20’ TY_72_8 ±8,032’±8,057’±7,264’±7,289’±25’ TY_73_1 ±8,069’±8,085’±7,299’±7,315’±16’ UT_1D ±8,294’±8,303’±7,513’±7,522’±9’ TY_75_8 ±8,369’±8,387’±7,584’±7,602’±18’ TY_D1 ±9,632’±9,655’±8,805’±8,828’±23’ Consult with OE for what WHP’s to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Trudi Hallett (RE): 301-6657 ii. Ben Siks (Geo): 229-0865 d. Above perfs will be shot in the Beluga/Upper Tyonek Pool. This comingling with currently open Tyonek Pool #1 is covered by CO 510B 8. RD E-Line Unit and turn well over to production. Well Prognosis Well: KBU 32-06 Date: 9/20/2021 SL/EL Production log: Must be run within 30 days of commencement of comingled production, after well has stabilized per CO 510B 1. RU EL/SL and PT lubricator to 250 psi low / 2,000 psi high 2. RIH with PLT logging tool 3. Acquire dynamic passed and stop counts per OE (dependent on what’s shot) 4. Confirm good data, then RDMO EL/SL Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 3,500 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 4-1/2” patch or plug 5. RIH and set plug or patch per OE. a. IF the entirety of the Tyonek Pool #1 is plugged off, 25’ of cement will need to be dump bailed on top of the plug b. Only a plug between the two pools would require cement. 6. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations Must be run within 30 days of commencement of comingled production, after well has stabilized per CO 510B RIH with PLT logging tool Updated by CRR 09-20-21 SCHEMATIC Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00- 00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 109 X-56 Weld 15”Surf 120' 10-3/4"Surf. Csg 45.5 L-80 Buttress 9.95”Surf 1,499’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 6,801’ TUBING 4-1/2"Production 12.6 L-80 DWC/C HT 3.958”Surf 10,547’ 116” 10-3/4” 4-1/2” No.Depth ID Item 1 20’4.276”Tubing Hanger 2 6,263'4.276”15 ft Swell Packer (Water Swell) 7-5/8” 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status D-2 9,762’9,780’8,933’8,951’18’Ty Gas Pool #1 6/9/20 Open D-3A 10,041’10,059’9,209’9,277’18’Ty Gas Pool #1 12/10/19 Open D-3B 10,084’10,124’9,252’9,291’40’Ty Gas Pool #1 6/9/20 Open D-4B 10,237’10,287’9,403’9,452’50’Ty Gas Pool #1 7/3/18 Open D-4C 10,312’10,327’9,477’9,492’15’Ty Gas Pool #1 4/4/17 Open D-4D 10,333’10,347’9,498’9,512’14’Ty Gas Pool #1 4/4/17 Open D-4D 10,369’10,392’9,534 9,556’23’Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/4”13-1/2” hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710’ MD 4-1/2”6-3/4” hole. 160 bbls 15.3 Class G pumped with 100% returns.3/22/17 CBL shows ToC at 5126’ MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 Updated by CRR 09-20-21 PROPOSED SCHEMATIC Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00- 00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 109 X-56 Weld 15”Surf 120' 10-3/4"Surf. Csg 45.5 L-80 Buttress 9.95”Surf 1,499’ 7-5/8"Intermediate 29.7 L-80 BTC 6.875"Surf 6,801’ TUBING 4-1/2"Production 12.6 L-80 DWC/C HT 3.958”Surf 10,547’ 116” 10-3/4” 4-1/2” No.Depth ID Item 1 20’4.276”Tubing Hanger 2 6,263'4.276”15 ft Swell Packer (Water Swell) 7-5/8” 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amt Pool Date Status Perfs per sundry D-2 9,762’9,780’8,933’8,951’18’Ty Gas Pool #1 6/9/20 Open D-3A 10,041’10,059’9,209’9,277’18’Ty Gas Pool #1 12/10/19 Open D-3B 10,084’10,124’9,252’9,291’40’Ty Gas Pool #1 6/9/20 Open D-4B 10,237’10,287’9,403’9,452’50’Ty Gas Pool #1 7/3/18 Open D-4C 10,312’10,327’9,477’9,492’15’Ty Gas Pool #1 4/4/17 Open D-4D 10,333’10,347’9,498’9,512’14’Ty Gas Pool #1 4/4/17 Open D-4D 10,369’10,392’9,534 9,556’23’Ty Gas Pool #1 4/3/17 Open OPEN HOLE / CEMENT DETAIL 10-3/4”13-1/2” hole. 110.5 bbls of 12# lead cement and 72 bbls of 15.4 ppg Class A pumped. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL of 12.5ppg Class G Extended lead and 30.5 BBLs 15.8 ppg Class G tail pumped. 45BBLs of losses, but recovered 40bbls of mud push at surface. 2/18/17 CBL shows ToC at 1710’ MD 4-1/2”6-3/4” hole. 160 bbls 15.3 Class G pumped with 100% returns.3/22/17 CBL shows ToC at 5126’ MD D-4C D-4D D-4D D-4B D-3B D-3A D-2 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 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 10,560 feet N/A feet true vertical 9,723 feet N/A feet Effective Depth measured 10,462 feet 6,263 feet true vertical 9,626 feet 5,578 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 10,547' MD 9,710' TVD 4-1/2" Swell Pkr; Packers and SSSV (type, measured and true vertical depth)N/A 6,263' MD 5,578' TVD N/A; N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 5,210 psi 7,500 psi 2. Operator Name:Hilcorp Alaska, LLC tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 8,430 psi 120' 1,452' 6,089' 9,710' Collapse 2,480 psi 4,790 psi Casing Structural 16" 10-3/4" 7-5/8" Length 6,890 psi 120' 1,499' 6,801' 10,547' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 160 Casing Pressure Liner 1698 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-220 70 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-137 50-133-20658-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 0 Representative Daily Average Production or Injection Data 6720 Kenai Beluga Unit (KBU) 32-06 N/A FEE A028142 6,801' Plugs Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 Kenai Gas Field / Beluga-Upper Tyonek Gas Pool, Tyonek Gas Pool 1N/A measured TVD Tubing Pressure 15 Oil-Bbl measured true vertical Packer 4-1/2"10,547' WINJ WAG 1676 Water-Bbl MD 120' 1,499' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:46 pm, Jun 24, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.24 13:27:35 -08'00' Taylor Wellman Perforate DSR-6/24/2020 RBDMS HEW 6/24/2020 gls 6/25/20 r: N2 Rig Start Date End Date E-Line 6/9/20 6/9/20 06/09/2020 - Tuesday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,500 psi high. Well been shut in since midnight RIH w/GPT tool and tie into perf log. Tag at 10,320' and FL - 10,266'. Run correlation log and pull out of hole. Had some drum gear trouble around 8500'. Fix problem and pooh. RIH 2-7/8" x 20' HC Razor, 6 spf, 60 deg phase perf gun and tie into old perf log. Run correlation log and send to town. Get ok to perf from 10,104' to 10,124' with 216.3 psi on tubing. Spotted and fired gun. After 5 min - 215.8 psi, 10 min - 215.2 psi and 15 min - 214.6 psi. POOH All shots fired gun was dry. RIH w/ 2-7/8" x 20' HC Razor, 6 spf, 60 deg phase perf gun and tie into old perf log. Run correlation log and send to town. Get ok to perf from 10,084' to 10,104' with 215.8 psi on tubing. Spotted and fired gun. After 5 min - 214.1 psi, 10 min - 212.8 psi and 15 min - 212.3 psi. POOH All shots fired gun was dry. RIH w/ 2-7/8" x 18' HC Razor, 6 spf, 60 deg phase perf gun and tie into old perf log. Run correlation log and send to town. Get ok to perf from 9,762' to 9,780' with 212.5 psi on tubing. While trying to spot gun the tools got hung up. We couldn't go up but could go down a few feet. Worked tools up and down staying below pull out weight and after about 25 min of that we got where we could go down. Went down to 20 more feet and logged back up and we were free. Went back down but stay above where we got stuck and ran another log and corelated it with the one I sent to town. We were off 25' by working stuck tools. Got back on depth and spotted and fired gun w/212.5 psi. After 5 min - 211,7 psi, 10 min -211.2 psi and 15 min - 211.1 psi. POOH All shots fired gun was dry. Rig down lubricator and turn well over to the field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 32-06 50-133-20658-00-00 216-137 Updated by DMA 06-17-20 SCHEMATIC Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00 PBTD = 10,462’ MD / 9,626’ TVD TD = 10,560’ MD / 9,723’ TVD Max Dev 38 deg @ 2,629’ RKB = 18.65’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 109 X-56 Weld 15” Surf 120' 10-3/4" Surf. Csg 45.5 L-80 Buttress 9.95” Surf 1,499’ 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 6,801’ TUBING 4-1/2" Production 12.6 L-80 DWC/C HT 3.958” Surf 10,547’ 1 16” 10-3/4” 4-1/2” JEWELRY DETAIL No. Depth ID OD Item 1 20’ 4.276” 11” Tubing Hanger 2 6,263' 4.276” 6.875” 15 ft Swell Packer (Water Swell) 7-5/8” TOC = 1,710’ from CBL on Feb 18, 2017 2 RA-C 8,850’ RA-B 9,555’ RA-A 10,255’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Footage Status D-2 9,762’ 9,780’ 8,933’ 8,951’ 6/9/20 18’ Open D-3A 10,041’ 10,059’ 9,209’ 9,277’ 12/10/19 18’ Open D-3B 10,084’ 10,124’ 9,252’ 9,291’ 6/9/20 40’ Open D-4B 10,237’ 10,287’ 9,403’ 9,452’ 7/3/18 50’ Open D-4C 10,312’ 10,327’ 9,477’ 9,492’ 4/4/17 15’ Open D-4D 10,333’ 10,347’ 9,498’ 9,512’ 4/4/17 14’ Open D-4D 10,369’ 10,392’ 9,534 9,556’ 4/3/17 23’ Open OPEN HOLE / CEMENT DETAIL 10-3/4” 13-1/2” hole. 110.5 bbls (276sx) of 12# lead cement and 72 bbls (331 sx) 15.4 ppg Class A. 35 bbls of lead cement returns to Surface 7-5/8" 9-7/8” hole. 167.5 BBL (438 sx) of 12.5ppg Class G Extended lead and 30.5 BBLs (148sx) 15.8 ppg Class G tail. 45BBLs of losses, but recovered 40bbls of mud push at surface. 4-1/2” 6-3/4” hole. 160 bbls (675sx) 15.3 Class G. 100% returns. D-4C D-4D D-4D D-4B D-3B D-3A D-2 D-2 Open 40’6/9/209,291’D-3B 10 084’10,124’9,252’ D-2 9,762’ 9,780’8,933’8,951’6/9/20 18’Open D-3B Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.29 11:55:15 -08'00' Taylor Wellman By Jody Colombie at 2:46 pm, May 29, 2020 320-220 X DLB 05/29/2020 10-404 gls 6/1/20 DSR-5/29/2020 6/2/2020 dts 6/1/2020 JLC 6/1/2020 RBDMS HEW 6/4/2020 �..- Kea° ^ R"_ 1 Vr" nk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN ' O LUL REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing _ s shutdown Li Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casin g ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Displace N2 E 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Stratigraphic❑ Exploratory ❑ Service ❑ 216-137 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20658-00-00 7. Properly Designation (Lease Number): 8. Well Name and Number: FEE A028142 Kenai Beluga Unit (KBU) 32-06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Gas Field / Beluga -Upper Tyonek Gas Pool, Tyonek Gas Pool 1 11. Present Well Condition Summary: Total Depth measured 10,560 feet Plugs measured N/A feet true vertical 9,723 feet Junk measured N/A feet Effective Depth measured 10,462 feet Packer measured 6,263 feet true vertical 9,626 feet true vertical 5,578 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' Surface 1,499' 10-3/4" 1,499' 1,452' 5,210psi 2,480psi Intermediate 6,801' 7-5/8" 6,801' 6,089' 6,890psi 4,790psi Production 10,547' 4-1/2" 10,547' 9,710' 8,430psi 7,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 10,547' MD 9,710' TVD 4-1/2" Swell Pkr; Packers and SSSV (type, measured and true vertical depth) N/A 6,263' MD 5,578' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1665 4 45 75 Subsequent to operation: 0 2502 9 0 0 14. Attachments (required per 20 AAC 25.070,25o71, 8 25.283) 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 EJ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WIND ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-549 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerl�hilcoro.com Authorized Signature: Date)0Tc,,'La,2b Contact Phone: 777-8420 Form 10-404 Revis 4/2017 �,� ,Z U Submit Original Only rr�rvg®� RBDMS H611/JAN 13 2020 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number lWell Permit Number I Start Date End Date KBU 32-06 E -Line 1 50-133-20658-00-00 1 216-137 1 12/10/19 12/10/19 Daily Operations: 12/10/2019 -Tuesday Sign in and Mobe to location. Spot equipment. PTW and JSA. Attempt to PT lubricator and had 0 -ring leak. Replaced same. PT lubricator to 250 psi low and 3500 psi high. Well shut in. TP - 210 psi. RIH w/GPT tool and correlated to OHL. Ran correlation log and send to town. Found FL at 10,260'. Town said log was on depth. TP - 215 psi. RIH w/ 2-7/8" x 2' Razor HC, 6 spf, 60 deg phase and tie into OHL. Ran correlation log and send to town. Get ok to perf from 10,048' to 10,050' of the MA sand w/215 psi on tubing. Spotted and fired gun. TP went to 218 psi when shot, 5 min - 223 psi, 10 min - 230 psi and 15 min - 231 psi. POOH. All shots fired and gun was dry. RIH w/ 2-7/8" x 18' Razor HC, 6 spf, 60 deg phase and tie into OHL. Ran correlation log and send to town. Get ok to pert from 10,041' to 10,059' with 234.6 psi on tubing. After 5 min - 236.6 psi, 10 min - 240.5 psi and 15 min - 243.1 psi. POOH. All shots fired and gun was dry. Rig down equipment and turn well back over to field. n SCHEMATIC HiLmmp Nee4a. LLC RKB = 18.65' 16" L{ c Type J 10-3/4" Conn. ID TOC = 1,710' 16" Conductor— Driven to Set Depth from CBL on Feb X-56 y 18, 2017 Surf 120' A� Surf. Csg 45.5 L-80 Buttress 9.95" 0� 7 /8" -5 Intermediate 29.7 i —BTC 6.875" Surf 6,801' TUBING 41/2" Production 12.6 L-80 DWC/CHT 3.958" Surf 10,547 b• Open D 4 10,333' 10,347' 9,498' 9,512' 4/4/17 h Open D-41310,369' 10,392' 9,534 9,556' 7' 23' Open 1` 4w1 �• 11 — „ 2 7-5/8" - RA -C 8,854 � 1 RA -B 9,555' s 1 D-3A� D-48 RA -A 10,255' a D -4C D -4D r D -4D 4-1/2" _r P8TD = 10,462' MD / 9,626' TVD TD = 10,560' MD / 9,723' TVD Max Dev 38 deg @ 2,629' Kenai Gas Field Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00 rA V nIr n PTA u Size Type Wt Grade Conn. ID opBtm 16" Conductor— Driven to Set Depth 109 X-56 Weld 15" Surf 120' 10-3/4" Surf. Csg 45.5 L-80 Buttress 9.95" Surf 1,499' 7 /8" -5 Intermediate 29.7 L-80 —BTC 6.875" Surf 6,801' TUBING 41/2" Production 12.6 L-80 DWC/CHT 3.958" Surf 10,547 JEWELRY DETAIL No. Depth ID OD Item Ili zu, 1 4.276" 1 11" 1 Tubing Hanger 2 1 6,263' 4.276" 1 6.875" 1 15 ft Swell Packer (Water Swell) PFRFr1RATI0I\1 r)FTAII Sands Top (MD) Btm (MD) Top (ND) Btm (ND) Date Footage Status D -3A 10,041' 10,059' 9,208' 9,226' 12/9/19 18' Open D-413 10,237' 10,287' 9,403' 9,452' 7/3/18 50' Open D -4C 10,312' 10,327' 9,477' 9,492' 4/4/17 15' Open D 4 10,333' 10,347' 9,498' 9,512' 4/4/17 14' Open D-41310,369' 10,392' 9,534 9,556' 4/3/17 23' Open OPEN HOLE / CEMENT DETAIL. Updated by DMA 12-30-2019 13-1/2" hole. 110.5 bbls (276sx) of 12# lead cement and 72 bbls (331 sx) 15.4 ppg 10-3/4" Class A. 35 bbls of lead cement returns to Surface 9-7/8" hole. 167.5 BBL (438 sx) of 12.5ppg Class G Extended lead and 30.5 BBLs 7-5/8" (148sx) 15.8 ppg Class G tail. 45681s of losses, but recovered 40bbls of mud push at surface. 4-1/2" 6-3/4" hole. 160 bbls (675sx) 15.3 Class G. 100% returns. Updated by DMA 12-30-2019 THE STATE °f1.1L GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Re: Kenai Gas Field, Beluga -Upper Tyonek Gas Pool and Tyonek Gas Pool 1, KBU 32-06 Permit to Drill Number: 216-137 Sundry Number: 319-549 Dear Mr. York: Enclosed is the approved application for the 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, \� , 1�� . Price Chair DATED this day of December, 2019. RBDMS W -4/n C 0 61019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 I..% IN-: DEC v;48 AQ 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown ❑ Suspend ❑ Perforate Q ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ )UL Other: V 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ifeP/iLCG . Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ • Stratigraphic ❑ Service ❑ 216-137 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 in Duplicate 50-133-20658-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510A Will planned perforations require a spacing exception? Yes Li❑ No • Kenai Belugla Unit (KBU) 32-06 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE A028142 Kenai Gas Field / Beluga -Upper Tyonek Gas Pool, Tyonek Gas Pool 1 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): 10,560' 9,723' 10,462' 9,626' —2,578 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' Surface 1,499' 10-3/4" 1,499' 1,452' 5,210psi 2,480psi Intermediate 6,801' 7-5/8" 6,801' 6,089' 6,890psi 4,790psi Production 10,547' 4-1/2" 10,547' 9,710' 8,430psi 7,500psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6# / L-80 10,547' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 4-1/2" Swell Pkr; N/A 6,263' MD/5,578' TVD; N/A 12. Attachments: Proposal Summary El Wellbore schematic 21 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 16, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 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: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: Ctwo Dod h1Icor .Conn Contact Phone: 777-8443 �1 Authorized Signature: / '� Date: " L2;., � e t i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 9 - Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS«^-' DEC 0 6 2019 Post Initial Injection MIT Req'd? Yes No p,�/ t, Spacing Exception Required? Yes No 1, Subsequent Form Required: 16 O 1�,./ '- �// APPROVED BY Approved by: COMMISSIONER Date: THE COMMISSION � � �C r �y ,�F�/ Submit Form and �t i 10-ao3 Revi ed / 017 Fp�G Approved applic nl5y�i^r l2Nnti frm the date of approval. [(� achments in Duplicate N Ililcom Alk., M Well Prognosis Well: KBU 32-06 Date: 12/2/2019 Well Name: KBU 32-06 API Number: 50-133-20658-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: December 16, 2019 Rig: E -Line Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 216-155 First Call Engineer: Christina Twogood (907) 777-8443 (907)-378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (985)-867-0665 (C) AFE Number: Max. Expected BHP: - 3,500 psi @ 9,226' TVD (Based on RFT data) Max. Anticipated Surface Pressure: - 2,578 psi @ 9,226' TVD (Based on RFT data and gas gradient to surface (0.1 psi/ft)) Brief Well Summary KBU 32-06 is a gas producer currently completed in the D-4 A and B sands (deeper horizons). The purpose of this work/sundry is to add the D -3A interval in the Tyonek to increase production. Notes Regarding Wellbore Condition • The well is currently producing 1600 MCFD from the Tyonek sands. • Minimum ID is 3.958". • Last tag @ 10,459' MD w/ 2.25" gauge ring on 1/3/2018. Safety Concerns • Discuss Nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,500 psi High. kyr. 2. RIH with GPT tool and find flui level. If fluid is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to pert. 4. RU perf guns. U Hileory Alaska, LLQ 5. RIH and perforate the following interval: Well Prognosis Well: KBU 32-06 Date:12/2/2019 Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Tyonek L D -3A +10,041 +10,059 +9,208 +9,226 +18 a. Depending on fluid level and shut-in pressure achieved, 2' long guns may be shot first in the top of each interval to equalize pressure (to minimize the risk of being blown up hole) and then the remaining perfs will be shot. b. Proposed perfs also shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Tyonek Pool based on Conservation Order No. 510A. 6. POOH. 7. RD E -Line. 8. Turn well over to production. (Test SSV with -in 5 days of stable production on well —notify AOGCC 24hrs before testing) E -line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,500 psi High. 3. RIH and set 4-1/2" Casing Patch or set 4-1/2" CIBP above the zone and dump 35' of cement on top of the plug. Attachments: 1. Actual Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure—N2 Operations Kenai Gas Field SCHEMATIC Well: KBU32-06 11 PTD: 216-137 Hilrurp AlnaW. LLC API: 50-133-20658-00 RKB = 18.65' 16" 30-3/4" t'/ TOC = 1,710' from CBL on Feb ` 18, 2017 i5 7-5/8" RA -C 8,850' q' FRA -8 9,555' 2 D -4B RA -A 10,255' D -4C D -4D D -4D 4-1/2" Lj PBTD = 10,462' MD / 9,626' TVD TD = 10,560' MD / 9,723' TVD Max Dev 38 deg @ 2,629' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor—Driven to Set Depth 109 X-56 Weld 15" Surf 120' 10-3/4" Surf. Csg 45.5 L-80 Buttress 9.95" Surf 1,499' 7-5/8" Intermediate 29.7 L780 BTC 6.875" Surf 6,801' TUBING 4-1/2" Production 12.6 L-80 I DWC/CHT 1 3.958" 1 Surf 1 10,547' JEWELRY DFTAII No. Depth ID OD Item 1 20' 4.276" 11" Tubing Hanger - 2 1 6,263' 1 4.276" 1 6.875" 1 15 ft Swell Packer (Water Swell) PFRFnRATlr1N nPTAll Sands Top (MD) Btm (MD) Top(TVD) Btm (TVD) Date Footage Status D -4B 10,237' 10,287' 9,403' 9,452' 7(3/18 50' Open D -4C 10,312' 10,327' 9,477' 9,492' 4/4/17 15' Open D 4 10,333' 10,347' 9,498' 9,512' 4/4/17 14' Open D 4 10,369' 10,392' 9,534 9,556' 4/3/17 23' Open OPEN HOLE / CEMENT DETAIL Updated by CMT 12-3-2019 13-1/2" hole. 110.5 bbls (276sx) of 12# lead cement and 72 bbls(331 sx) 15.4 ppg 10-3/4" Class A. 35 bbls of lead cement returns to Surface 9-7/8" hole. 167.5 BBL (438 sx) of 12.5ppg Class G Extended lead and 30.5 BELS 7-5/8" (148sx) 15.8 ppg Class G tail. 45BBLs of losses, but recovered 40bbls of mud push at surface. 4-1/2" 6-3/4" hole. 160 bbls (675sx)15.3 Class G. 100% returns. Updated by CMT 12-3-2019 Kenai Gas Field PROPOSED SCHEMATIC Well: KBIJ 3706 Hi4vep Alarkn, LLC API: 50-133-20658-00 RKB = 18.65' 16" 10-3/4" M TOC = 1,710' from CBL on Feb 18, 2017 7-5/8" RA -C 8,850' 2 RA -e 9,555' A D -3A D -4B RA -A 10,255' p i D -4C D -4D D -4D 4-1/2" PBTD = 10,462' MD / 9,626' TVD TD = 10,560' MD / 9,723' TVD Max Dev 38 deg @ 2,629' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor -Driven to Set Depth 109 X-56 Weld 15" Surf 120' 10-3/4" Surf. Csg45,5 D -4B L-80 Buttress 9.95" Surf 1,499' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 6,801' TUBING 4-1/2" 1Production 12.6. L-80 DWC/C HT 3.958" Surt 10,547 JEWELRY DETAII No. Depth ID OD Item 1 20' 4.276" 11" 1 Tubing Hanger 2 6,263' 4.276" 6.875" 1 15 It Swell Packer (Water Swell) PFRr:np ATIrIAI 11PTAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date FootageStatus 9-7/8" hole. 167.5 BBL (438 sx) of 12.5ppg Class G Extended lead and 30.5 BBLs D -3A ±10,041' ±10,059' ±9,208' ±9,226' Proposed ±18' TBD D -4B 10,237' 10,287' 9,403' 9,452' 7/3/18 50' Open D -4C 10,312' 10,327' 9,477' 9,492' 4/4/17 15' Open D -4D 10,333' 10,347' 9,498' 9,512' 4/4/17 14' Open D -4D 10,369' 10,392' 9,534 9,556' 4/3/17 23' Open OPEN HOLE / CEMENT DETAIL Updated by CMT 12-3-2019 13-1/2" hole. 110.5 bbls (2765x) of 12# lead cement and 72 bbls (331 sx)15,4 ppg 10-3/4" Class A. 35 bbls of lead cement returns to Surface 9-7/8" hole. 167.5 BBL (438 sx) of 12.5ppg Class G Extended lead and 30.5 BBLs 7-5/8" (148sx) 15.8 ppg Class G tail. 45BBLs of losses, but recovered 40bbls of mud push at surface. 4-1/2" 6-3/4" hole. 160 bbls (675sx)15,3 Class G. 100% returns. Updated by CMT 12-3-2019 11 STANDARD WELL PROCEDURE [fit, orp Alaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINALv1 Page 1 of 1 *CANNED JAN 1 ) r • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL T§ P eRT 1 :u, la.Test: U Initial U Annual U Special lb.Type Test: U Stabilized U Non Stabilized U Multipoint ❑ Constant Time ❑ lsochronal Q Other: Nodal 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska,LLC 04/14/17 216-137 3.Address: 6.Date TO Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 02/25/17 50- 133-20658-00 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 526'FSL,1250'FWL,Sec 6,T4N,R11 W,SM,AK 84' KBU 32-06 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 1976'FNL,1534'FEL,Sec 6,T4N,R11 W,SM,AK 10,462'MD/9,626'TVD Kenai Gas Field Total Depth: 9.Total Depth(MD+TVD): Beluga/Upper Tyonek GP 1/ 1952'FNL, 1514'FEL,Sec 6,T4N,R11 W,SM,AK 10,560'MD/9,723'ND Tyonek GP 1 4b.Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15.Property Designation: Surface: x- 272168 y-2362578 Zone- 4 N/A FEE A028142 TPI: x- 274474 y-2365309 Zone- 4 16.Type of Completion(Describe): l Total Depth: x- 274494 y- 2365332 Zone- 4 4-1/2"Production String,Perforated 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 4-1/2" 12.6# 3.958" 10,547' 10,312'-10,327' 18.Tubing Size Weight per foot,lb. l.D.in inches Set at ft. 10,333'-10,347' N/A 10,369'-10,392' 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23,Specific Gravity Flowing Fluid(G): 6,263' N/A N/A 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): Tubing Q Casing 156 F° 1058 psia @ Datum -9419 TVDSS psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: 0.57 0 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. X 2. X 3. X 4. X 5. X Basic Coefficient Flow Temp. Super Comp. No. (24-Hour) hwPm Pressure Gravity Factor Rate of Flow Factor Factor (l,Mcfd Fb or Fp Pm Ft Fg Fpv 1. 2. 3. 4. 5. Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. 2. 3. Critical Pressure 4. Critical Temperature . 5 . Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDE Submit in Duplicate RBDMS (,L-,3 2 4 7118 • • • Pc Pct Pf P12 No. Pt pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Pse Pf2-Ps2 1. 2. 3. 4. 5. 25. AOF (Mcfd) 1,316 n Remarks: KBU 32-06 is a lower rate gas well flowing —45% drawdown. The AOF was calculated w/nodal based on RFT and current flowing data.The attached report form Prosper summarizes the matched IPRNLP system. I hereby certify that the foregoing is true and correct to the best of my knowledge. I l Reservoir Engineer Date /S f Signed Title111 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producin face were reduced to zero psia Fb Basic orifice factor Mcfd/ Pm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 1/Z dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000),dimensionless Gg Specific gravity of separator gas(air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L,feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 • • . >1 tp CO O N H N H O N M F 01 O N 01 0 in 0. N U co N N N N U) co Ol O 1/40 H a' U) a• Ol In M H -.4 -ri a) N t0 M 01 W N CO a' 0 (C) N F N N H 1.0 O a) H U co H 4-) Cr) 0 \ M H M a' t0 co 01 H M a' t0 N 01 O N In U) O 0 H J-) 0 HHHHHHINNNIN H z a) w •J —— co >, co co O 0) U) tP 0 H N MH N a• In O N 0) 4-1 OD Ul m F N a' N M N M H O 0 H M U) N I •ri 0 a'j N N 0) M CO U) N O CO l0 U) a• In •d H O Ch N ) ¢a U) to t0 t0 F coW O• Ol O H N H a' H t0 l0 Ci H H H H H H H H 1-1 H 19 O a• ON N r- a' C) a' a' O CO CO H O a' O 01 O t0 N U) (.0 O 01 N 0 N N CO 0 a' CO N N H . •ri F N 4.) --4 M N 1/40 H 0) N N co co 0) O N M a• 3) F 01 '0 U N H H M d' 3) CO 0 N a• N 01 H In U) (--• 0) -r1 IN O HHHHHNNNNN $4 1 w O 0 U a) N d' M C) U) N F U) N CO M CO M N N t0 0) O N a' 30 N O 0) 0 H H N N M M d+ v a' O H 4.) 4) w 0 H N M a• to t0 co o) O H N M a• to 0 N O CO a) b a• a' a• a' a• a• a• a' a' U) U) N U) U) N U) O N N ••-) 2 I-oa -0 N N0 O H W a) U) a' In co U) N N U) N O M CO M N N t0 0) co O N a' t0 N O 01 0 H H N N M M a' a' a• 1 N a) 4) w O H N In a• In t0 CO 01 O H N M a' U) tP N M Q) iti• N O a• a. a' a• a. a' a' a• U) 01 U1 U) 31 U) U) U) 10 H 0,• •.1 A a) >,pi. H14 •Hrl H >S 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 0 a) z z z z z 2 z z Z z z z z z z z '0 0'0 0 a)H O O 0 O C) 0 0 Cr O O O C) O C) O C) O O 7 W N 5-1 14 w Eu' . C) O C) 0 C) O C) O O O 0 O O O O O C) Z01 H CC.'> (0 -r1 U) U) U) U) U) U) U) to U) U) N U) U) U) U) U) U) t0 H N N MP 0 t0 lfl l0 tP 1.4 t9 tp t0 ID (0 b l0 O l0 tp 0 H a) >,W— a) N Si Y" U N 0m0a0 N M gy o H 4 0 r0 "4444. Cr O O O O O O O O O O C) C) C) O O O til x XH CO >'N • IH O O O 0 0 0 0 0 -C) 0 C) 0 0 C) O 0 0 'i 0.Oj r i to 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C) Z Na, O -O N O• r0 {.moi H N N 0 co w U A', w 00 >, a w WN • 0 to C) O C) O 0 O O O 0 C) 0 O C) O O O O of V (41 .0 a-,H--- N-a, WO. a) 0)w•,-IIn a) O 'O J-,H N P 0 o to q• • o. WW 0 t/ i . N H -0 a) 0 'O 0 O O O O C) O O C) O O O O Co O C) 0.1 / as N U In * C N A a) t1.0 — N C) 0 UX N IN 44 0 N 0 O O O O C) O O O O O C) O 0 O O O O N A to\\ N .0 *4.)C Id 0 40 •rl a) -ri Oa XI A.) a) *H' 0•ri H b, NHHHCI CS 44 044 V-t) .-.H ,y' 0 C.U)01 H a) --i 44 N 44 a) -r1 0 / 0 —4,1.)$-1 k a Raft •a0 0 0. ' O H C O OCCN�) I f 1 f N 44 p -- U; 0 0 Z r1 ft to ft a a) O 1/40 a) a) 1-, 0 *H ft p H I--I HH ft O 0k H ,-a) co co 0 O O O 0 O O O C) O O CD O o O -rt co N 0 0 0 H ft}•'t 'a 0 •r1 a) w a. to14 u ora; 4vaft a 4) •ri N >, to i-,J-,i-, N f a'ft b 0 .k p.`•.-. I 4C a) N O 0-,1 O 44 z 44 F 0 AN co CA L4 CO Q•A?.. fC* •� 0 a) 0 O a' a' t0 N a' 0 H 01 N 01 NO N N 0) C''1 O •. .. •• .. .. .. .. •• •• *y.* N Ci 4-) U O a' U) N In a' CO t0 N (V CO to H N U) Ul In 14 (4 .0 C) N a) 0000 x '000' ftHft a 4• ••i N O OD w In 0 t0 Ni N N In a) 0 o CO a' N N H 1-1•.1•.i O O'0 O O a) ft•7'ft 0,N N N a' M H O 01 O tD U) CO N O CO N U) N C) N •f 043.0-•.i•ri O.0-r1 H 41,H f H a) a H a• a' a' a' C M M M M M 01 N N N N N H H H N a) ai-,i-, Z+)+)C4 *Hf li v0 H H (040 40. of N a) U #H 4 R' 0 H a) HH 0$'-, a) >, *to* 1 (I) N N N a) a) 0 N 3-) 4,gz f a) 0 O M N N N C) O t0 N a• t0 N 1/40 U) to U) N W CO a) C1 14•ri a) CI-ri 44 W ft NO1 N al a' In a' 01 M a' O 01 H a' 01 U) N O O W O0 CI Ni�i� aH *toCk 0 V H U) a) 0 0 0 541-I)•r1 C) 4 0. N •r1 N 01 a' U) 01 U) N H O O 01 O O C) H N M 0 'O N a1 U U H aS 0.0 *z* —14 N.-. N N a' t0 CO H '' N O M N 01 N U) CO H a' N X 0 a)4-) a) a) ¢.N H H HOH a'H01HU NF N NNO1 0101M a1MOt a •In 0 '(V a'CO a•01U)01U) \ W Z i-, ai P J)U) J-) *H* •r1 Ci A-)`--a) O H 01 a' N N N In H 0) 32 N CR O M 01 NH a) N 04a b O ft O ft ) .0 o N t0 H M H H 0 0 O) 01 01 O In O N O O a• 0 a)•d0 *,•ft to Al aCiU co H N Ma H H M t0 0) H a' N M M t0 01 \ N+ 0 N 5i a Din f In k N• U 0 a C) •OHO MOt00010H OHO HO H O N ONON 000700In OM O • H CO H '0 0 x C) * * 'a •ri >,•rf O O O O O C) O O O O C) O O O 0 O ri i I 04 ft ft X ft a) a)A as v O O O O . O O O O O 0 0 O O C) O U U'U 41 P P \ O O O o O r.4 •ei 01 1.1 a 5 Pj 0 H 01 a' H a' N a' N H N a' N CO a' M H In '0 4.)O cT O a' 01 U) 31 N M 01 Cr U) a. H O O UD U U`-' VD In COU V) N U1 r) O 0) M M a' t0 N O N t> -vi a' N N U) N • U) N 0 O CO CO O (0 U) 3) • H 01 O w--. 'DHN COU)Ht0 a'CO •01 •H •In to<V<V N 0001 OH •0)O a' •CO .N N a) >1 31001 •U) 10 •N Mt0 a'O a'H •N •In •a' .U) •F mcHOI H MHO '0 H •a'00) ON N a' t0 U)U)a'UD In N N OH OO -Ol O H OHH P H '0 M O 0 M C) N M H O U) N 01 (0 co 01 tP Cl' Na a)' >,--....-„-• H N H N N a' a' U) t0 (OF O O O1 H H . •154, al 01)l-)44 U 0 H O H •O •In •010H .H •H •H •01 •O •H .01 •01 .F O y„) 0 U0 40•.I U a) Oto •H 001 O U)O CO N O 4)ON O HO N O N O N 0010 H 00) a' S4 •r1 P'.U CO •O O O H N Ol a• U) a' O 10 CO 01 N Ul 0 U) • O -C N 0 f)7.�I\ O • a X 0 H,F.4-) O 0 .4 H O o 61 CO N Ul M H 01 N U1 N a) N a) W H H H H H H O C) O O O O 01 01 01 01 14.)4 X C-) .-- co co CO CO CO CO O CO CO O 00 CO N N N N • • 0 N C W . 0) CO Sr CO N O 1/40 r m •• N N N • O sr N N •cr CO m N W CO 0) O • .-i H N •• • O N d' • !' N O▪ N CO CO dt W M N CO M W CO • V) I) ./) • CO • Ch 0 tO 40 W • • • M W m • u) In u) CO• 0) O • 1n In W • 0 0 0 0 z ZZ z 0 0 O • CD 0 0 •u1 v) Irl 40 40 W 0 0 0 v u CO • M 0 0 O Z z° z° z° • • N N U N N O O`— N CI) O` N • m N V) N m N m -rl-,1 .�{ Lk O 0 O TJ >,>.>. H-..O O -. 0 0 P 40 \ 0 m m M M a a O U M M a a O U U O 44'0'0'0— +111-ri•ri N N \�N 4)+)•.-1-d N N .--....-..W I 0,..\\ 01 4-14-14-.1 .0100 OM 444-14J4-3140 OM N - N 4 A7 CA•.-1--I.ri•.1•.1•-4-rl \\ C C\\ •ri b)\\ \\C C 0,--to, M a) EHE m m m m m m m A A N 4)t-1 J-1 >4 m NAA N N 1)4)7 ›.4, 0 • U)U)m a0.0.0.0'0.a l.-i U Uw4-1 '0 O.U)r-I.-1 0 Uww TS o.v w •Y• M O O O M m./)O O O O O O r I 0 d•N O N 0'O O O r I O a'O O N 0)0 0 0 d' 0)00) N Od` 01 N O O O N O H 0) 0)d'0 0 0 O 0 O H .f)CO H m m N CO • •try CO HI 0) CO N 0) • • r-1 d'IDM •Md'0 H N dmN Q • 4 •MC•0 •mr W o . W ' • ,0)0) 40•l0 4.r)co N 4 H V`ON .l01f) CO H.-1 d 0• •H O ,-i •0• .HI C) H •d' • 0 0 • O H 0 • O HI O 0 0 0 O • N N N N N C A C C N C C C >,>,>,>,>,>,N C N N >,>,>,>,>,>,a C N N 1iN O 1rO bO •r .0.N 1 -+1-11 O 0 N N5Lr+11,- O O N N 4040m0•r1• 1mrMXd-riri ri rCyN•r1• 10.. • 11•ri00 41 P' C414r4m .0 >401O )MMI0) mm0) 0U0mm - mmm0) 040mm.P 0 0 0 C mum MN Cp000045C1,44:10o0oo414) 10 • •ri 0 - NT0rNNP - 0iNN0U• HN0Nuv ) UUirN0a) O 0iN-rNNO $ 0 0.Om010m4) 041 EN000. mmNN Na)E •• N C70+ 0' +Iwa 0•i11 l•i>> N a i•1 > N a a 00. a o N'U O 1) OTS m > .-i T7 m ›. > ri a) 0 •.i v U)TS E N 00E--,,10 O •d 0$TS m TS N-0 m '000000 • • cf. • r" CO a b v N b O C)) t)� 4 N G T1- N Cm7 U z ( SZ UO O N d' cv r- C •O o 400' -d ri ri w H ,0 1-7 TS N ,-1H1 w '0 • d• 0 H 0 U N H b 1-7 0)r0. N.-i 0 O., N r-7 m 0.-1 N 11 0 • H .--i0 0 254,1d •N N O N 4 N 7-.I-1•0 ”-1000Z • Cl) .1-I 0H N.-1 U a)4-I ri.0 Ori U N 4-) N • .I-1 N H'U A m-rl C r-1 O 1) O.7. m H•ri C•r1 11 0 .0 v 0$HH.P H (O Z 0 TS •.i W N M N m CO 0 .-1 H •-i X N HI O N a N 0 4.1 O N N • OD N W 0 H .0a)-'l ')) TS 11-ri z m-ri N N •r{ • CO N H ,44 P. m m N N w a '0 N •• CO cp U) '3 .-1 H 0 N N 4i-ri N 0 O N O M a) 00) A •.i NN NN Z O)1n 0 W H W N .3 0. r1 N N a IO N N W 0Y HI -ri O N 4-r VI CO H CO444 3 N U)•O u 0 • ,r000000 '0W•� N • • O . 115 H • O O O .N0 0 Z W • O H 3 N H 4)•r1 • N N N d' a) 0r...4 N H u) Cr) X N N v' H N i W CO N ri d'H.--1 V•• ' • • N N • • • HH N (n,-I • 0) CO CO Hm CO N M CD CO CO OJ • • 0) W CO 0 CO m CO CO • N N N N • • 0 o U) N -�I I 0 N D 63 . Cl) Z_ ao o Ij�I Q S'W )Z D I m m m m co co >, N _ G Z - ICo() Y D Y H CO Y O H I- H H H H N I 63 Iw1 ISI ID IU I X X X X X X 0 U_ Oil 2 j 2-I- 2-u) aQ 0.0 a2 1 I 1 1 i 1 b co 5 j >- I to i 0 0 O 08 1 O Z -0 a Cl) U) U) Cl) Cl) U) ivQ ow v% 0 v 0 0 0 0 0 0 T � a mal 20 Ip� 20 2Z Z Z Z Z Z 2 2 2 2 2 N IND N D N O N D N O N 16 145 1 N 1 N 1 N IEo Eo E� Eo EJ EU EU EU EU EU EU Z 3 Imo 630 630,1 630 6301 630 630 630 630 630 630 E Co w? : c_1 c _1 c 0 c.J C p C Z c Z c Z c Z c Z c Z Q N I N I N N 1 N N N N N N N f0, N !r a0, 0) CD S Z 2 2 2 2 C j 63 i LL p LL p LL �I LLL p LL >I LL I LL I it I LL I LL I Il I p _ _ __ __N __M __ __CC) __f0 U) 'V i w 'N I N N C N 1 N C Np Np Np Np Np Np C7 c w 1 m c CO c m 0 asasQ 4 C/) 63 u) min min CD /) CO v) O 0163o 630 63 I mo 63 1 CO I m I is I ca 163 1 63 1 p SD U00 O UO 0,(0 0 0 0 0 0 o O o O oQ� 1 � I �Q l �w N �� E �� E ��m d 7 E cZ cZ C d CO �eQZm CO_— C I C ICI E I C I C 1ww m O I OQ OQOwf0O Co O w H O O 7 O O 7 O 3 O 7 V (1)co—lN ml 4)LpIU) N C01d 4)m1 I N o N o m a N o N o m o o EDLIEDLT, EDEJ ED CD O U c a j%- N. N- N- N- N- r r N- N- N- a. N Y 0 I O O O co 0 0 0 0 O O O 63 'N N N N N N N N N N N N A/ CC as I ,..-1-1 co co co co co co co co co co 0 W 0 (1) 0 = =i V S 0 op O V I Z Q w cr VQ-!O 0 03 Co CO -1 (C) CO s— co CO CO 0) 0) N- 6- 7 m 63 co O r O 0 O - V' V a w Z CL/� 0 1pal N c O O CO `!I. N w j co0) CO N 0 0 0 0 0 0 20 U � � 0) CO N a N m O j E Q ' 0 N V CZ4. 00 63 c c... J CO H X ZI C Q 0a. r N C I- _ cn Z r-- w o 5 a N 00 �WJ J M mm N Cl) Q p Q ZYc I a (1,660;O CD 1 Q oZ E I 0 Da) d Uo cis E 0 63w Z 7 COg 63 Co CO CO Co 63 63 63 CO N N co co O 63 co co co co 63 co N C E 0 0 0 0 0 0 0 0 0 0 0) W Z m s a m CO :°:NJ :4 :° :a 0 0 Z 1 O « 0 0 0 0 0 0 0 r. I0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) M H ', p y m• V V V V 7 V V V W.. F N 1563 E 0 0 0 0 0 0 0 0 0 0 0 Z .0 p {1J O z N N N CO3 CO CO Co N N N N N N N CO CO CO CO CO CO re I O O w Z ' a8 63 .. I 2 0 '- YLL LO W LL 2D a°i U « a Z w J 2 I Q 0 0 0 0 0 0 0 0 0 0 L) j E 0 a a� of+° Q.10 0 0 0 0 0 0 0 0 0 0 4 d 2 L 0 h 3 J 0 w w w w w w w w w w w • 0 o 0 N o �ODO I (---- o 1 Cl) U) CO Cl) U) CO co CO U) N U) CO U) CO co co co CO N Lc, O- m co co co co m m CO CU m CO CO CO CO CO CO CO mT CO Z ~ F H H H E. F- H H F- F- H H ♦- H ti N a a a a a a a a a a a a a a a a a a M U X X X X X X X X X X X X X X X x X X ca c7 I I I I I I I I I I I II I I b c 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U 0 0 b Z Z Z Z Z ZZZZZZZZ_ 0)ZI ZI Z Z Z E-,6=1 N=I N=I ) 1 6 XI N I N I N I N I N I N I N 1 1 1 0) 1 N= N= N= Z _ _ _ _ _ _ _ 0)EU EU EU EU EU EU EU EU EU EU EU EU EU EU EU EUI EUI EUI MO MO MO MO MO MO MO MO MO MO MO MO MO MO MO Mm 20 (00 a y Z O Z y Z O Z m.Z y Z O Z O Z O Z 11-)i Z O Z O Z O Z O Z y Z Z N Z N Z Q 2 2 2 2 2 2 S X S Z 2 X 2 2 LL I it I it I it I it I LL I U I U I it I LL I it I it it I it I it I it N1 11 co'I LL v1 __n __oo __O) __0 __ ..N __M __� __U) __(O __n __001 ..O) __O __(O N N N M M M M M M M M M M 0 (n QO O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O N O N O () m (nm (nm com <nm 0) m (nm (nm OD as 0) ay U) ay (nm ODm U) m U) m N N N 0 4 q Mw M0 Mw . U) w U .@9 U) .M cn M(n _ co .@- CO .@- (n M cn 4 U) M In a6 5 @� m„ m 001 m 00I m 00I m 00I m 001 m 00I moi m 001 m 00I m 00I mol m 001 co 00I co 00I co 00I m 114 1 m I Ql O oOOOOOOoooOOOOo O O w °W Pa ( WPaPW ( WcW ( W PW PW PW PW PW ( a )W s a aE I E I E I C I E 1 E I E I E I E I E I E I E I E I E I E I E Ia1c 1 2 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2 ' 2o ' o o 0 ` to ,DU (DU aU 0U (Dv (DU (DU (DU (DU (Dv v (Dv (DU (DU (DU (Dac (Dc a OO OO O) o OO OO O 00 0 0 0 0 0 0 OO OO OO OO ooCe JJ = W U W O W U W U W U W U W U W U W U W U W U W U W U W U W U W U W U W U O '5 N- N- N- M1- M M n r N- M M N- M N- N- N- N ag " 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W NNNNNNNNNNNNNNNNNN Et a M M M co M M M M M M M M M M M M M M re /W V Ja 2 U Z < O O_ 00 (0 CO U) CO CO 0 V O) 0 M M CO CO '� CO O a) O O (O CO CO V O) CO CO O O r- O) _ = Nr- IC) V V N- N- N` M N- N- (O r CO O CO CO CO 1 a cu O u Ci. ti C N 0 0 0 0 0 0 0 0 0 0 O o 0 0 0 0 0 0 0 G a) O a L- N-- EI V c••=-1 U o r-- o < Cl co o 03 NP. M Z r� CO a N n J v• Cl) Q % Q Z _ I Y I a) Q C � ' Q Z o E U m 2 CO m m CO CO CO CO CO CO CO m m CO CO CO CO CO CO ID N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N- CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CI o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 n > o a) o) a) a) a) o) o) o) a) a) a) a) a) a) o) a) o) C) F- a V a V V '7 V V V V V V V V t7 V V CO O O O O O O O O O O O O O O O O O O CO CO W 00 O CO CO CO co a0 CO CO CO CO CO CO W co CO r N N N N N N N N N N N N N N N N N N N E 0 G CO O 0 U w U U U U U U U U U U U U U U U U U U 0 d amWwwW wwwwWwwW wwW W w w 0 • • o r o o o' N o c--- CO �a0 co Co co co co N co co co co co N co N Cl) co co co N Y9p CO CO CO CO CO CO f0 CO CO CO CO CO CO CO CO CO CO CO >, N Z • F F F F F F- I- F- F- F I- I- I- I- I- F- I- I- CL CL CL a CL CL a CL a a CL EL a E CL CL CL a A U X X X X X X X X X X X X X X X X X X al e 1 1 1 1 1 I 1 1 1 1 1 1 I 1 I I 1 1 b U) z z z z z Z Z Z z z Z Z Z Z Z Z Z z 6I aj S äi' aj S aj S aj S aj S aj S aj S aj S aj S aj S aj S aj S aj S aj S aj S aj S z E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 E 01 cU COU COU cU cU cU CO, cU cU cU cU cU 20 20 2C9 20 20 20 Q oz oz oz oz oz mZ mZ NZ a)Z mZ a)Z mZ mz mZ mZ mz mz Nz 2 S S S S 2 2 2 2 2 S S S S S S S 2 LL I W I it I �- I �- I W I W I W I It I W I W I W I W I W I W I W I W _I W I _IS _O _n CO_ _p) _O _7 _N ..M . _ t _Cp _O _n CO_ _,O) _O _ _N (/) NO 0)O 0)O 0)o NO N N N N N N N N N N NN Nd• No Q C/)O (/)O C/)O O O O coo (n 0 O (n 0 O 0)0. w° (n 0 (n 0 (n 0 (n O (/)O :O :0 .-. ..-. @ .-.-. @ .-. .-. .-. .-. .p. .-. .-. .-.- .--. t-. .0 C. IoW (0( �� °W "0W .'W "win .-'W :aW ..0 .o.N :dam ..W .10.W �0) .f..W �W �W I f0 1 CO 1 CU 1 CU 1 C13 1 m I CZ 1 M 1@ I@ 1@ I CZ I I@ 1 M I CZ I I ❑m ❑m ❑m ❑O ❑m ❑co ❑c0 ❑(O ❑CO ❑co ❑co ❑ co ❑co ❑ m ❑cp ❑CO ❑ CO ❑m rn00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 7 C C C C C C C C C C C C C C C C C C CO O I O 1 O 1 O 1 p 1 O 1 O I O 1 O 1 O 1 O 1 O I O 1 ,_ I O 1 O 1 ,_ 1 ,_ �— a` a` a` a a` a` a` a` a` a` C a` a a` a a a` coC/) 0c 0c Oc Oc Oc 0c 0c Oc 0c 0c 0c 0c 0c 00 00 we 00 . 0 N v o 0 0 0 0 o 0 o 0 o 0 0 0 o 0 o 0 o 0 o 0 o 0 o 0 0 o 0 0 o 0 0 o 1 i QJ N W U W U W U W U W U W U W U W U W U W U W U W U W U W U W U W U W U W U 0N-n n )` 0- r` n N- N- 0- N- N- 0- N- N- N- 0- a g U 0 0 0 0 0 0 E. 0 E.0 0 0 0 0 0 0 0 0 LUN N N N N N N N N N N N N N N N N N < cm a) m 63 W a a- m 0, a) O) a O) a) dceM M co co co co M co co co co co co co co co co C,') LU (.) v) 1 J_ Q Z w 1 U) N CO 7 1'- n U) C) N- N- (O N- co N- N CA )` - 00 co N U) O) CO N co co CO r N C) COO U) 7 CO U) 7 co CO CO f'- N M U) M CO U) N V co N- J o y Omr-- 0 0 0 0 0 0 0O 0 0 0 0 O 0 0 0 G r If) a E oU � is. o • Q o N ,t N 0. M F- r Z 5� CO M J V m CO Zt as Q Yp a) Q0 E Q Zo •E▪ 0 z Co CO Co CO CO CO CO CO Co CO CO CO CO CO CO m CO CO d m m CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO •CO N ❑ a ❑ a a a a CI a a a a ❑ a a ❑ a rn CO m CO CO CO m CO CO CO m CO CO CO CO Co CO m CO CD ❑ bb b O b b 5 5 o b o O a b 0 a c5 o C) > CD 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) rn 0) C) 0) 0) 0) M F V• V V V V 7 R 7 7 7 7 V. 0 O O 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 Up CO CO CO CO CO CO 00 CO CO CO CO CO c0 CO CO CO CO CO N N N N N N N N N N N N N N N N N N N 0 C1.0 O 0 U 0 0 0 0 0 0 0 0 0 0 U U 0 0 U 0 U 0 ow O P. ❑ ❑ a a a a ❑ a a a a a a a a a a a a CL 2 W W W W W W W W W W W W W W W W W w • • o • • r•-• o0 w JI No o 0 -o U C CO w Cl) Cl) Cl) o Cl) Cl) CO w co co co co co I U0 N LL9 o m co co co co m co m m ca co m m CO co) U) W T .?• Z 1— r-- 1- H H F F F I- F F F F F U D 1.-I ti a a a a aa a a a a a a a a WI JI D >:',c 0 X X X X X X X X X X X X X X F in < z. r) I I I I I I I I I I I I I D U I b 6 (D0000000000000 <, w D i' 5 � cn (n cn cn (n cn cn cn v) cn cn (n u) or a Lo Z z z z Z Z Z Z Z Z Z Z Z Z a I-, O w=I a)=I w=I a)=I a)=1 a)=1 62 62 N=I w=I a)=I a)=I a)=I w=I N=I Mm MN Mo Z EU EU EU EU EU EU EU EU EU EU EU EU EU E0 Do Do D 1 m m m m m m m m m @ m @ @ m m o mo moo IT. cU cU cU cU cU cU cU cU cU cU cU cU cU cU Y _ YJ Yo Q N Z OZ OZ OZ OZ OZ OZ OZ OZ OZ OZ OZ OZ OZ 1 I I I 1� 1LyI LLI Lt EI it LLI LLI III LLI lit LLS LLS it Lt ao ds e -M1 -N1 -�1 -co -�1 -co ^OI ^OI 1 -NI -M1 -Q1 -Lo ^n1 0 Ce 0 CC 0 I U a)V a)V W v a)v c)a a)v m y a) u) a) a) 7r)LO a)in r)If) m Ln �_ I 2 I c Q U m U m U Uco — co cS U U U U (9 U F U m U U@ U@co— O F 2 p S D 2 p COU� @UI mUl co Ica I caU� ca 1 mU1 @Ul mUl @UI co Ito l mUl a) o hi o -01 CD co Dco Dco DCo Dco 0 a C)co D(p D0 CD co C)co DCC Dco Dcp ILO U:C) W Q w - — W 0 c) c� — —0 W c)W c� 0 ZI 0 ZI (W w c � —Crc1 'c 1 c 1 'c 1 'c � 'c 1 'c 1 'c 1 'c � 'c 1 'c 1 c 1 'c 1 'c 'c c a . m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 oQ oQ 2W-o a` a` a` a a` a a a` a` a` a` N V co 0 c 0 c w e w e 0 c 0 c 0 c 0 c 0 c 0 c c c c a) c 0)�= 02CD U IX o 0 0 0 0 0 0 0 0 0 0 0 0 0 �I o w co' w SIU QJ N W U W U W U W U W U W U W U W U W U W U W U W U W U W U W O U W O W O D 0 Y r- n r-- n r-- n r-- r r- r- n r N. CL g 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W N N N N N N N N N N N N N N N N N Q W CD 0) C) C) C) 0) 0) 0) 0) C) 03 0) A/ a M M M M M M M M M M M M M M M M M 111 1� CC 0 V J• Q z ▪ " '' Q as p W co r` co iCO CO In nn N O N-CO r- N CO N- V CO Cl) CO O co co co O CO O Lo (T (T a- a. c C ~ 0 O 0 0 0 0 0 O 0 0 0 0 0 0 0 5 N a O a ti E V N U o t•-• o J o Tr Q co N cc M 0. I- H Z 2 < NI CO 0 v J Tr p W Cl) Q p , Q ZC W p Y m Q p a Z E o E 0 m z to m m m CO m CO m CO m CO CO m CO CO m m N j is CO CO CO CO CO CO (o CO CO fo CO CO io CO CO CO N D 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N- CO CO 9 w w w To CO COww w w o D 0 55 0 0) 0) 0) 0) 0 0 0 0 0 0 0 0 0 0 0 0 0 > m a a) m a ma a a a ma rn rn a a co CO Tr V 7 V `Cl' V `Cr 7 V 7 - V V O O O O O O O O O O O O O O O O O CO OD CO CO CO a0 a0 W CO CO a0 a0 CO OD U) CO W N N N N N N N N N N N N N N N N N N •� 0 O CO LO p O U Y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Cc.7 E O a2ww wwwwwww wwwwwLU w 0 • i • c I U` i N C o = r N N to V7 N N UJ () N N N V) N N o �1 �1 Z UI N1 v -o -v -q V -q V a -o -v. 'o -o >, c z 0 0 =I N F U) U 0 U) I- 1- I- F- I- I- H F- F- F- H H '' Z 0 a a a a a a a a a a T M _U a U (� I Z X X X X X X X X X X X X ro I 1 1 1 J 1 1 1 1 1 1 1 5 Q1 wl Z a II U) U) U) U) U) U) Cl) Cl) U) Cl) U) U) () (O I m C9 C7 U C9 C7 C9 C9 C7 C7 C7 C7 C7 M N N N% N O N I I I I I Z S I I IN 0 Z Z Z Z Z Z Z Z Z Z I I co co co MD co I I I I I I 1 I I I 1 Z D > >o D J1 ) 0 0 0 0 0 0 0 0 0 0 0 0 Y Y Y J Y o Y Z Z Z Z Z Z Z Z Z Z Z Z Q a 1 ISI I� I i I I I I I I I I I I 2 e e•o e- I I I I I I I I I I I I N (+) V b CO f` CO O) 0 r N M 0 0 U U U 0 0 0 0 0 0 0 0 0 U) '- - - I - C - O 0 0 0 0 0 0 0 0 0 0 O Q I 2 2 U 2 0 2 03 CO N CO CO CZ CO Co CO :6 CO - — —U as.. a .- a) g a) I ia0I a)w IN U aU I a �I N N an N n N n N n N n a � I'- ILL o LL d Il U1 LE QF N LE a LL 8 LL O Il 8 Li o LE o lL g Li o Li:0 LL p w p w cs Lt 8 c c c m c a_ c c 1 c 1 c 1 c I c I c I c I c I c I c I c I c I s l e° 2 0 O Q:� O w F- 2 O 2 7 2 3 2 7 2 7 2 7 2 7 2 7 2 3 2 7 2 7 2 7 2 U) O N ...N U�F- U SIX U. U C 0 c 0 c 0 c U c U C. U c U c U c p c U c V c 0 a) as N N a)co'd a O 1 N 4) WO a) o a) o WO WO a) o a) o WO a) O w0 WO N O Et CD QJ c 'w2 w2 Wox WoU) ED u_ wU wU Lai c) wU Lai c) wU Lai L) wU wU ED El c) ED c) Q l 'ti n r- r- n r- n r- r- r- n n r- r- r r r- a CO " '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W N N N N N N N N N N N N (N N N (Ni CV Q �0, O c0 6 a) O) O) O) O) O) O) O) O) O) A/ a CYC M co (h M M M M M O) O) O)M M co co co co co co re W V U) V J S < U' Z Q 03 R J d o w ati C C o G Nn ti E U N U o o n Q00 •0 M F- i— _ h. G Q N ' m M Tr M w m m CO a p z Wc 0 Y a < C E G Z `' £ 03z a) CO m m CO CO CO m CO CO CO CO CO CO m m CO a) m m m m m m m m co co m m m m m m CO N I a a a a 0 a 0 0 0 0 a a 0 0 0 a 0 N- co s o m (o CO CO a) CO CO CO a) CO O CO CO CO rn o 0 0 0 0 o 0 65 66 0 0 0 0 0 0 r > rn rn CD rn rn CD CD o) a) rn rn rn rn rn CO rn rn M Cr V V V V V V C V V 'V V V V V V Tr O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 (0 CO CO CO O 00 00 00 CO 00 CO 00 CO 00 00 0O 00 a0 N N N N N N N N N N N N N N N N N N EE O CO25 .2 CO U 0 U0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 L) O a O 0 0 a 0 a a a c) c. P. 0 a 0 0a c) a a d d 2 W W W W w w w W W LU W w w LU w w LU • • o r o ..- o o N u) u) N N N N Jo N N N N N .CO N to N to N ry co Lc) O •O V 'O V V V V V V V V V V V V V -O V CD Z 1-- H F F H H- I- I- H H H H H H- I- I- 1- I- ,-, N IZ n. d d d 0 d d d d d 0- d d d d d d M U X X1 X1 x1 x1 /XX x1 xl xl x xl /x x1 xl x1 xl xl xl 'ti • 5 C9 C9 C9 0 0 C9 0 0 0 C9 0 C9. 0 0 0 0 0 0 g O z z z zzzzzzzzzzzzzzz I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I II I C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Z 0 0 0 0 C9 C9 C9 0 C9 C9 0 C9 C9 C9 0 0 0 0 E. zz z z_ z_ z_ z_ z_ z_ z_ z_ z_ z_ z_ z_ I _ _zzz Q I I 1 I 1 1 1 I I Co' I 1 1 1 1 I I I V O O r co O O N V O O r O O) O (n O O O O O O O0 O O O O O 0 0 0 0 O Q0 Co CO .@. CO .O. .0. .CO CO 2 2 .0. 2. .O. .C- CO 1.0 C7 1 NO N� NU NU NU NU NU 6° aim NU NU NN NU N� NO N� 4jU NO I — I — I • I - I - 1 - I - 1 - I - 1 - 1 - I - 1 - I - I - I - I - I l �I O LL O Il O LL O LL O LL O it O it O •- O it O it CO 11 CO Il CO it CO Il O it co ii O I�co A V O V O V O V O V O V O V O O O V O V O V O II V O V O V O V O V O O O O O CC a c I Ce c I CL c I CC c I Ce .E I .E I c I Ce c I CC c I CC c I CC c I c I CC c I CC c I CL c I Ce c I Ce c I E I CoO 7 O 7 O 7 O 7 O O O 7 O 7 O 3 O 7 O 7 O O 7 O 3 O 7 �O 3 O 7 O 7 O 7 U U `U `U `U U U U U U U U U U U U U U U (D c (D O W O W O W O W O W O W O W O W O W O W O W O W O (D c a) c c a) c v o o 0 o 0 o D o o ? o o o o o o 0 o o o o ? o 0 o Ce QJ ,CO U CO U W U CO U W U W U W U W U W 0 W U W U CO U W U W U W 0 W U W 0 W U 0 r r r r r r r r r r r r r r r r P- CL g " '5 0 0 0 0 5 5 5 0 5 5 0 0 5 0 0 0 0 N N N N N N N N N (N N N N N N N N W Q O0ON600OO) 0) ) 0) 0) A ) 0) 0) 0) ) ) O 0) 0) /e a Co CO Co Co Co Co Co Co Co Co Co CO CO CO Co Co Co Co re U CD V J < Z ▪ c? Q ra S.J o n3 O. � C 2 o o` O N a U o rq r- o J c. `° Q o °° r M 0. I- � Z_ r 752 M Q N W D V n LI Cn Q• 150 Q Z 111 O Y ° i Q O 0 C z • 0 � z CO Co Co Co Co CO CO CO CO Co Co CO Co CO Co CO CO CO d CO CO Co CO Co Co CO Co CO CO CO CO Co CO Co CO Co CO C"-) 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Ps CO CO Co Co CO CO CO CO CO CO CO ;C) CO CO Co Co CO Co ) C) C) C) o) C) o) o) C) o) o) m C C C 0) rn CD 0 06 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O MN- a) a) a) a) a) 0) 0) 0) 0) 0) 0) (5) 0) Cr) 0) 0) a) a)M V V V V V V V V V V V V V V V V V V O O O O O O O O O O O O O O O O O <O 0 CO CO O CO O O CO CO CO O CO CO O CO CO CO CO CO N N N N N N N N N N N N N N N N N N N FE-... ` CO Ci O CO' U w 0 0 U 0 0 0 0 U 0 0 U U 0 0 0 0 U 0 O I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o_ 2w w w w w w w w w w w w w w w w w w • • S c c O N U) U) C0 V) U) U) Ul V) CO Cl) W U) N V) U) U) 0 U) N CO Np .0 .0 .0 '0 '0 V. 'O '0 V - '0 - V. V 'O V V V p Z F F— F— F— F— I— F- I- I- F- I- I- I- F— N 0- 0- 0- 0- a. a. a. CL a a. a. a a a. a. a 11 CL T X X X X X X X X X X X X X X X X X X M U 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 ° 5 co co Cl) co U co U co co co U co co U co co U U b C7 0 CD CD CD CD CD CD CD C9 0 0 CD CD CD C9 C9 CD N Z_ Z_ Z_ Z_ Z_ Z_ Z_ Z_ Z_ Z_ Z 7_ Z_ Z_ Z_ Z_ Z_ Z_ F. II I I I I I I I I I I I I I I I I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Za 0 0 CD CD CD 0 0 CD 0 CD CD 0 CD CD CD CD CD CD Z z z z z z z z z z z z z z z z z z IIIIIIIIIIIIIIIIII N1 CO v1 (C)I (Cl1 N- W1 0)I O1 1 NI M1 v1 (C)I (Cll N-I COI 0)ICO CO CO 01 CO CO 01 01 U O O O O O O O O O O O O O O cr O O O O ' 0 N U -U U -N U N U -U U U U U U U U U U U U N co 1 N 1 N 1 I 1 N 1 —N 1 - 1 N 1 - 1 - 1 - 1 - 1 - 1 - 1 - 1 —N 1 — 1 _ 8LE8UW8W8UW8W8W8W8LL8LE8W8 u:8W8W8LL8LL8W8LL8 U .99c 2� 9� Y� 2� 0 CL 0� 0� 0� 0� 0� P� .0W 0� 0 CC 0 Ce .0 CC o DI o DI o DI o =I o ,I o ,I o ,I o =I o DI o DI o ,I o DI o ,I o 3I o ,I o 31 0 ,I o 3I @ IL-.U U U `U U U U U U U U U U U U U U U U C) C C) C V C C) C U C U C U C V C C) C V C V C U C U C U C V C U C U C U C J WO WO WO WO WO WO WO WO WO WO WO WO WO WO WO WO WO WO Ce aaJ E W U W U W U W U W U W U W U W U W U W U W U CO U W U W U CO U CO U W U W U Lt 0 Yr` N. N. r, N. N. N. N. r` n N. N- O- a y U g o 0 0 0 0 o O 0 0 N N 0 N 0 N 0 N N W N N N N N N N N N N N N N N N N N N Q 0) m 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) m 0) N Ce a CO CO CO M CO CO M CO CO CO M CO CO CO CO CO CO CO Ce W 0 ✓ 0) VQ _ C? Z acop d co3 J o co aI 2 g ° O N ti E o N U N is. 0 CD SaCA N Qcc M F Z r- 5� G a N m V YM.1 J Tr M d (/) a as z a ! ICC W00 a) a O a Z £ o D £ U coZ 1, co CO N CO N 03 CU CO CO CO CO CO CO CO Co CO CO CO 41 co co co co co co CU co co to co co co CU co co co CO N a a a a O a a O a a a 0 a a a a a a N. 1 CO CO CU CO CU CU Co CO CO Co CO CO CO CO CO CO CO CO rn it c a Io - 0 0 0 5 0 0 b 'a 0 0 0 0 0 0 0 0 > 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) O 0) co F 7 7 Tr V V .7 V .1 7 Cr R c} .7 V R vY R - r O O O 0 O O O O 0 O O O 0 O 0 O 0 0 00 CO 00 CO CO 00 00 00 00 00 00 CO CO W 00 CO CO CO CO N N N N N N N N N N N N N N N N N N N .` o ▪ CO O o UU w . 0 U U U U 0 U U U U U U 0 U U 0 U c.. d o 'a a a a a pa a a a a a a a a a a a d 0. M W w w w w W w w w w w w W w W w W W 0 • 0 r-- ,--,o - o o ,. v N y to N 0) (0 N N D. a N in O v. a V v V V V V (7 0 • n h T o z I- F- F- F- F- - I- F- F- 0 0 " a N a a a a a a a a J J N N w CCCI V. N < T p 01 01 01 01 01 01 01 01 ' M M m1 y ml OI m1 N m1 c0 NI Le) ZZ Z Z Z Z Z Z Y co Y F- Y co Y ci F- 2 2 2 2 2 2 2 2 N F- I= O m N N m F I I I I I I I I co z z N 0) a) N ix 62 aj a • C 0 0 0 0 0 0 0 0 D D D E c�'p E- I Eco E� I Z 0 0 0 C7 0 0 0 m co a co rn _ o co a co co o .__ Q I I I I I I x 2 Y1'O o 0 co.5 co a N O) N co N �_ N N N O I I I I I I I 2-a J J W ari MIE MI a2 LLce MI MIg to in In in to in In I to o LU LU I 1 I -nl -rl nl Cl) 0 0 0 0 0 0 0 0 - ° m m °�r �� CON m �� m m� Q co co co :o c0 }o co S v cnm cncp Ym Y 0)it- 0)a Y Y� C? 6cn IyWI 6 i • • o . * -. -• o co H a H co I- 2 2 2 2 a N o 1 u) I U) I co C9 C9 C7 C9 1 co U a U a U a a a a a U N N o 'CD CD g 1 I g I I I I I g 0 Z O p 0 U 0 U 0 U _J U) J J 0 ° C ti co _U i m m NI CD a tDI CD a COI 0 a1 a1 a1 al a-1 cC CO p N N J I J J I U co Com.) Cp.) J b 6 iM co a J a J a J LL LL LL LL a N :1- I 1 I a a a a H p IZ Z NC�j vial NC�j Nal hi Nal N=I N=I N$I Q) l U Z D D ELL E� E � EN ELL E� EN E � Eo) EM LL M a M O M a M O co a M O co co M O co N co O a F. < < C I Cu- C I CLL C I CLL C V C M C co C co D 0 0 a) c ma a) c a)a o c a)a_ a)o a)o a)O mO c J J LL LL a LL D LL a LL D LL a LL fI LL �I LL col LL coI o w Lu _ _ _N __� _00 __O) U) m m a).u- a)LC) 000 Orn 00 0� 0p 0) �O Ln �O rn 0O N O QU) -U) 0)E, CO,- U)N U)N CO co co U) co co U) co co U) co Co C? Q Q (0DoE (0-J . 9 :°-J (t1-J ;°oo6 12 u)6 42OD6 0 N OD � Z Z Co I M I co I M I ca I M I co Ict M Ict M Ice co Ice _ I N YU) YU) po (0 po N po ca po o p0 N p0 N poW poW poW poW LLo-0 0 W 32 Or 4,)cc co 4,2� L2aC M o� () Co 32� I 32 Or I 32 CC I 32 Cr I 9� '2,,, On W o W C IU) c I IU) c I c I� c 1 c la C la C la C la c mice o �K o �� o �� o �� o SLC O D0) o 'I- o �H O �H o �H O 3� - Mp Mp O W U� O W .�.-U� ...moil) Uw OU UU UU OU 17.0111 t) - poW pow y oat y owl y oat 0 oWI W oal W oWI W oal W oat W oat () co_t y oal IX QJ E cal: ca WUH LUOa WOH WOa W0H W0a u.IUU w0U w0O LUOO LUOH 0 1 ' n N- n r- n N- N- N- N- N- N. O. g " o 0 0 0 0 0 0 0 0 0 W N N N N N N N N N N N Q LL) Ln Ln to in in Ln Lo Lf) Co) '4)IX jl a Ill O Lo Lo Ln Ln Ln Ln Ln u) Ln i L7 V J a Z r co M co N Ili Q w N CO N O N N O N O _O N — 3 O O ca p r rCD r CV r M M M 01V J 0 a. C M M LL) co LOC) M C r 0 0 0 N TT NN 7 0 O O O C "4-, o o O O 0 O 0 N a E0 o N K 0 J QQ o '° r M 0. H Z r- L� n 2 a N ', 0 •a- Ca Y.1M n W com a 0 Q ztu C a o CI Z EO N I" U N E co c.> L) Z U) U Co Co M co co co M co co co co d -o -o Co Co Co Co M CO CO CO Co Co CO CO N Co CO 0 0 0 0 0 p p 0 p p p N S I co Co co co CO co CO co tea co co 0 0) _) 0) o_) o_) o_) o) o) o) o) cm o) o p J J p p p p p p p p p p p r` > N CO CO co co co co co co co co co M co H N- r` N- r r- hn N- n N- N- N- r` T c0 00 00 00 (CO CO CO00 CO CO CO co CO W CO r N N N N N N N N N N N N N N D Lo U O « - li 0 0 0 0 0 0 0 0 0 0 0 0 0 c) O a) p l 0 0 0 0 0 0 0 0 0 0 0 p p d d m J J W W W LU W W 111 W LU LU W • • o CS o 0 a1 v a1 a 0 0 0 0 N do aL) aoaaaaa o l l l l l Jl l m CT O pO Z aa � 0_ 0_N 0 l Ul 0 aaaa N >, os M V a to a CO a �I �I �I COI o D a x 1 v P I _J I J I U 0 U 0 -'o N m 0 4 J a1 co J a1 J a a a a N a "' Y 03 0 H cf)in H J J EE 0 al 0 aI =1 I 4I =I MIQ Z N w -oo O O -o Z Cl) U- U) LL CO N 0 O co D Z D E ° E In (n .>. v a 0 a 0 co CO N O m LL co I I 1 Q d cl d cl d o 0 0 o YI nl O 0c 9 9 9 0 0 Q O d o d �1 �I col col e'5O J it fc M M M M • 0 0 O o O O U- Nil' D D D D D U) (C) CO 0) O O N O N o N 0.D - 0_ 1:0 o m m m m m 5 5 0 0 0 c0-7) 0:1-7) (13.5 10-7) =QY Y Y Y Y 0 Qj JI N JI N N Jl N- N N Jl N cn 6 Nice —�1 o Nce —(0ice —6Lii N NI0 N�l Z N N N N N N rn ()U00) y ()Ce ° Uit Ct:o c)CC� c)it CC:o (.)CC I c)cwI ()it ix I Uit cwI ()p Ycc ELLIOEE ELLE U v v v U v D c I • c I� c I • c 10) c I c Ia c Ia c Ia 'c Ia c a F.'a c c c c c c o0) 0 0 a o0) 0 0 IY 0 0.) 0 0 E- 0I- o - 0 0 I•- o a w 0 0 0 0 0 0 =° Uw 1.7.UW Jr,C) �Uw �U� �U� �U� ..U� �U� �a Q o U U U v v 0 �� 4-, c11.1 0 c I 0 c w 0 c I o c w 0 c a 0 0c13_ 0° ca. 0 c a N N N N N N N '..Ce -I o I o a o I o a o I o I o I o I o I coI `°w qJ � wUa w0E- wOa wUi- W0a WOO w0U w00 w0U ED c) CV w w w w w w 0A `j 0 I. 1- n N- h N- n r- r- N. h n r- n h Is CL C..1 p O p O 5 O O 5 5 O O O o O O O W N N N N N N N N N N N N (N N N N Q I) In l!') I[) LO IC) In (0 if) U) U) )f) i() U) (0 N a 0 0 co rn 0 Lo 'o to to rn to icy Lo in co to CC LU 0 0) Cbp Co.) -I < 2 C7 Z O Q .. ILC W o E J Q a 0 G a) SO O O N T:). o N V ti C) �O O Q 9 0 (SiOS ✓ elI— H 5F Z � L /G� 0 N_ I, W - R J cr p W CO w //� v/ Q p Q Z W c I— a) Q n 0 Zii) 0 E U c Z co co co co co co m co co m co `m m m CO m ca CO CI) co is co is co to co co co Co v co co CU CO co CO M 0 0 0 0 0 0 0 0 0 0 m 0 0 0 0 0 0 cv m m m m m m m m m m I CO CO CO co CO CO 0 0) m 0) 0) At At rn o) ) 0) 0) 0) 0 rn o) m •rn rn 'En o 0 0 0 0 0 0 0 0 0 0 0 3 0 0 0 0 0 5 I.- co co co co co co co co co co V -4f 7 V V I"- TI; t0 iao co ao ao ,- co co 5 ao ao 5 ao ao co ao co co co 7 ,N N N N N N N N N N N N N N N N N N C ((00 c 0 U .: 0 0 0 0 0 0 0 0 0 U0 U 0 0 0 0 0 LU O it 0 a 0 0 0 0 0 0 0 0 0 p 0 0 0 0 0 0 d a 2 w w w w w w w w w w J LU w w 111 w w • • 0 o 0 0tV o � a0 O r r r r c0 W O T el N o M ,_ N N N 0 Z N N N N N N N N N N N N N N ti N rr r r r r r r r r r r r r r >, M _U j o o O o 0 0 0 o O O o o O o O cd Ma a a a a a a a a a a a a a a 'O ▪ 5 x a) as as a) a) a) a) a) a) a) a) a) N N a) w cc cc cc cc cc cc cc cc cc cc cc fr ce cc g in E E c c c c c c c c c c c E c c g c -o 0 0 0 0 0 0 0 `o `o `o o `0 0 0 `o Z �I t £ 2I 2I Ij IiI I 2I IJ 2I 2I 2I 2I 2I IJ 2I 2IOO O O O O O O O co O0 0 <0 oO O O N N ON 0N 0N 0N 0N oN ON 0 N 0NMN N N MMMMMMM MMMm Jo Jo D m m m m m m m m m mY Y Y 1 Y Y Y Y Y Y Y Y Y Yit Il LE Il LE lL LE Il Il Il Il lL lL IlU U U U U U U UU U U U U UC CE EC C E CC C C E C C O o0 0o,,_ O w 4_ o w O w y- O.- O w O 4_ O O w w O w. O 4_ r U'O U'O - U'O C'O U'O C'O 0'O U73 "O 73 13 13 O a a a U a a .) O. a ) a a a U a U Oa U O. U a aas aaa) a)r N t` an a) a) N N a)r a)n aaaa)r a)rJ N. N. N.Ce QJ W W W W W W W x— W 1— W a— W a— W a— W a— W a— W a— W W W W.— W a— CC 0Y N- I- N- N- I N- N- N- N- N- N- N- N- N- r` N- N- a U 0 0 0 co 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W N N N N (N N N N N N N (N N N N N N N N Q ( (n LO (f) U) (f) n U) n (n (n (c) T) (n (n n U) Ur) (n Ce a IX n n n n (n U)) n n n (n (n n n n n n n to U) MI 0 O co % 1 J = c?0 Z Q 1,2 co J o (0 co a ,� 5g o O a j E ! o V N U w O — Q O ta 9 a) Net r vsI- H I Zr` S� D 0I W D J szt W COCD V) ¢ o II Q Z W 0 p I a) QO a 0 Zo E U (a Z CO CO CO CO CO m CO as CO CO CO m CO a) m as co as co a) as CO CO a) CO CO CO CO CO CO CO CO fa CO CO CO CO CO CO CI N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r` as Co as as CO as CO as as Co as Co as as as rn Co Co CO Co o 'om 5 .5 rn os 'os rn a) aarn a) oo5 0 0 0 0 0 O 0 0 0 0 0 O 0 0 0 0 0 0 0 0 oN` v v v v v v Ti- v v v v v v v v v v v v M F l r r N- N- N. N- N- n r` � N. N. N- n N- r- 1 N- N r CO 0 0 0 0 0 0 0 0 0 0 0 w CO 0o ao 0 CO CO CO ✓ N N N N N N N N N N N N N N N N N N N N • O D1.0 O of U U U U U U U U U U U U U U U U U U U U 0 , O d 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d a 2 W W W w w w w w w w w w w w w W w w w • • o r 9 a) 'N c 4 Ln ch h th O ,- N coln O �N N N N N N N (v) d' U) 4Pi- a0 O) — o Z !N N N N N N N N N N N N N N () () C) C) .-, N 'r r t r r r r t t r r t t r r r r r >; C9 ) O O O O O O O O O O O O O O O O O O L7 M — a. a. O. O. C2 a O_ a. a. a. O_ a. a. O. O. a. a. O. i b e- D i 4) 4) a) co a) a) a) C) a) C) to o) a) a) a) a) a) a) 4 4. cc to C C E C C C C C C C C C C E E E E E c `0 0 0 0 0 `o `0 0 0 0 `o o `0 0 0 0 0 `o Z �I �I �I �I �I �I �I �I �I �I �I �I �I �I �I �I �I 2I a o 0 0 co 0 0 0 0 0 0 0 0 0 (0 0 0 0 0 Q N NN N N N N N N N N N N N N N N (N C) M M M M M M C') M CO O') M M M CO M 01 CO CO m Co CO a) CO a) co co CO co co m CO m CO CO CO CO Q Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y N N N N N N N N N N N N N N N N N N I. I1 it I1 it LL LL LE I1 it LL it LL IL it It it it WU U U U U U U U U U U U U U U U U U 7 'C 'C 'C C C 'C 'C 'C C 'C 'C 'C 'C 'C 'C 'C 'C 'C oO 4- O 4- O O O O O 4- O w O w O w O w O w. O 4- O w O w 4-OO 4- O w r to 14E. ta ta 15E. tn '8a ta ta ta ta ta 11E. ta ta ta ta tEL 15a `in n n Is— n n n n n n 1,.: n Q� w� w � w � w .- w.- w— D3<- ED‘m w .- w� w� w� w� w� w� w� w� w� 0 Y ` n n n n n n n n n n n N- N- N- n n CL g U o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LU N N N N N N (N N N N N CN N (N N N N N < in u) (C) U) to in to to to in to LOLf) IL) to In IL) to O. Ln to in Ln n to to to L() L() to tCe o n L() to in in to Ce LU ID O u) U J a ▪ (-? Z IS Q a) co J 0. CO /� O � i Lig C C T g G N a 0 UN N Uc. ti o Q as N I••• G Z n CO n v W a CO ) V) a o Q w W Y g N Q n Z E oD Z co 03 irs 11"3" co as co co co 3 N o 0 a 0 a 0 a a a a a a a 0 0 0 0 a rn (o co co m CO CO CO m CO CO m CO CO CO Co CO CO CD co m m m m co .� 5 5 5 Zo 5 5 m c m m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r > v v v v v v v v v v v v v v v v v v C") 1. n N. n N- N- n n N- n n n n N- n n n n n (o ao ao ao 0o ao co CO 00 0o ao ao co OT) CO ao 0o CO ao ✓ N N N N N N N N N N N N N N N N N N N 0 O 0 1.0 o 0 U O 0 0 0 0 0 U U 0 0 U 0 U U U 0 0 0 C7 E O w www wwwwwww wwwwwa 2 0 0 • • o ro o N o v 9 CI• 0 0 w _ N O `r N c) v m U' 0) o c c E E C) �) N Z M M M M M M M ('�) M M M 0 O .0 m m 0 0 ti i' 'C r 'C i' 'C Q' f6 C C C C >' ) 0 O O O O O O O O O O O p p O O 'b r) a a. a. a a a a. a a a a — E E c _ a a a Cl) a a a a Cl) a Cl) (i r° E co 10 E E E E E E E E E E E m e c = = F O O O O O O O O O O O c in in 0 0 U LL E-- 6 2 2 IL Z 6 I I I I I I I I co o o o o co co 0 0 0 o CO Q O O o O O c c O O O O N N N N N N N IN N N N N N N N N N N M M M (O M M M M r) M M M r) M CO r) r) M U) m m m co m oo m m m m m m m m m m m m Q Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y , 0 hi ai ai ai ai ai ai ai ai ai ai 6 6 6 ai 6 ai IL I1 I1 IL it I.L it LE I.L It Il U LL U: ...- E.-D IL.- MLL OU U V O U U 0 U U U 0 U U 0 O a U • U 0 m 'c -c C c 'C C c 'C 'c C c c 'C Et 'c 0 'c 0 'C Et % Oo o.,... 04_ O o oo _ o.,_ O o4_ ow_ o o 213 2o_ o 2 o 2cl't 2o• _a oa v a a oa va E. v oa nv 0 o 0 QJ N w WT- WT- ED T- ED T- WT- W w.- w<- CO W w GJ 2E ED 1-- OD-J 51_J 51 2E W l- 0 0 Y F- N- 1 N- r- n r- N r` r` r. N- n N- N- N- 1-- 0- ` a g " io 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 UJ N N (N N N N N N N N N N N N N N N N Q L. to U' U) L. U' U) U) U' 0 U) U' U) 0 L. U' U)) to 0 o... a s.- O.. G O. �+ W � V E Q `o c Z — I Q 70 Mt_C T 0 G O y O n -c-r.11- El 1 i o N U (� ,...C%. coQ � g N Q r co H Z r� 5� D I G Q N CO D J 7 p 01 m N Cl) ¢ 0 Q Z 1 Y 01 a) ICC z E 0 _a) U , ' E m Z m m m m m m m m m m m m m m m m m m 31 m m m m m m m m m m m CO m m CO m CO m N I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r- m co m co m co co m m co Co co m m co m co �o CD D .5rn rn m rn 0) 0) 0) m 0) rn 0) m rn rn 0) 0 0 '10 0 0 ' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I v v v v v v v v v v v v v v v v v v r) H r- N- r- r- n 1 r- r n r- r- r- r- r- r- r` r r-- ,r- .- ao co 00 ao CO co ao ao ao co co CC; ao U' co OD rb o r N N N N N N N N N N N N N N N N N N N .` o o p U w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 V O aE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 �w w w w w w w w w w w w w w w w w w • • n o - 9 w - wco N o o O 0 N- O O N ea • co co CD 0 Q) o) -� J J J co U I- 1- --I J N CO lf) NTt t # 4t o Z 0 J J J 0 0 COm CO O J. O O J J r r A O O E E C c co 0 o o c @ >, >. C C o O E E o 0 0 0 0 .n • — m is 0 0 E E 0 0 0 0 0 o aQi a) CDo aai aai cII 04 o o c m m CO 0 U CC Ce CC CCo CC to co coC; ;0 0 _j .. c c C C o o co (0 0 0 0 0 0 h Cn )l) 0 0 LL LL U 0 J J .0 .0 -C -C -C Z C0 CD (0 (0 CO CO CD O o CD CO CD CO CO CO (n CO CO dO 9 9 9 O O 0 o O o O o O O O (O (o CO o Q jNN N N N N N N N N N N N N N N N N N M CO CO CO CO CO CO CO CO CO CO CO CO CO M M M co M U) Co CO Co Co U) Co Co m Co C)0 Co CO m 00 00 U) m Co m o Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y ai 43 ai ai 45 ai 45 43 ai 45 45 45 45 45 45 43 45 43 45 LL ii LE E. it it LL LE I1 LL LL it LE it it jr, iL LE ii u) U U U U U U U U U U U U U U U U U U U- 7 'C 'C'6 'C C'E 'C 'C 'C C C C 'C C 'C C C-o C-o C 1 'C-0 C D. o 2-p 2 a 2 ti 2 a O w 2:'' 2„_ O' 0 0 0 0 0 2 O a 2a 2a 2a 26 rN C� a�0 a)> a)u cu> a)0 m> aw a)> co CD m CD a)0 a)> m(2 a)(;, a�F CD N a)o JJ y W W - W di I-- W D - W Lu 1-- W W W LU W2 ED I-- war) EL op WC) W0 W — ON- n n N- n n n N n n N- n n n n n a g U o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N W N N N N N N NNNNN N N N N N N Q (0 0 (C)) Cn U) CO (C) CC) U) ll) U) U) LO U) U) (C) If) U) U) 4r 4 04%,"W 0 CO c? Z Q Q aS a ,, 2 � ° N a) 1 all 0 E VN N U - ti 0 J (, „ Q occt aWI ) ` N Cl. r F Z n D CO < N CD J V CO CO 111 a) V/ Z a Q Y H �., Q C a z E -433 0 faz 0 m CO CO CO CO co co co CO CO CO m co co co co co co d co co co co co co is as co co as CO CO co co co as as as M '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N O CO CO CO CO m CO CO CO CO CO CO CO CO co CO CO CO as • rn o) 'C .5 o) C rn 'o) '2 'C) 'C) '5 'rn rn o) .- :it m m 0 0 I,0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1,- v c v .. v v v v v v . . . v v v v v . (") F n n n n n n n n N- N- n n N- N- n N- N- n n ✓ CO CO CO CO 00 CO C7:1 073 CO CO CO CO 00 07) CO CO W3 C70 70 ✓ '1 N N N N N N N N NNNCVN N N N N N N N - O O co P. o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U c.) O a) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O. M W W W W W W LU W W W LU LU LU W LU W LU W LU 0 • .. r. _.. N 0 _. 9a � � � N o ; Z I IZ I o c, o- > >, n D D N co 0 tp 0 a� o No Z o .E (n in zI zI zi > M _ o M E o > > E as n o o O 0 F0 b p 0) co ❑ > E E ❑ > ❑ > •❑ � co J J J C) 0 0 0 W- U U ❑ ❑ 0 UY CL >- 0000z �' a) a) o E m 1- H � F- H o m F- I- 1- H n E o E o E o Z c 0,E -' 0)0) O 6 CO Co 0 CO CD 0 m C m C CO CO CO o OU al co Fr. m 0 0 0 0 0 m Li_ o 0 0 0 0 o O LL O L,L o o O O Q N oTEC C W M M M M M M M,_ M 77 M co Cq M M J LLO WO WO D @❑ 0 _ Q ) D U D D D DU DU D D D D W 'NI 'NI NI m W 52") La La o1 1 03 CO CO CO CO CO CO I CD I CD CO CO CO 00 O M O M 1.7':CO < I,Y o N= ❑ E E �O Y Y Y Y Y Y Y Y Y Y Y Y � I CA I � I . ui a0i O ri Li is Q ui ai ai ai ui ai ai Q ai Q ai ai ui ui Z m a:,m @ m •- lL ❑❑ ❑❑❑ c)Et IL IL IL IL Il IL LL w1 iLwl LL W LL iL Y ❑ YI 0 Y ❑ YI E a OF-H- IHF c3 E 'E E 'E E E .0 .0 Ew E E 'E E Din .0 0_ co .0 0_ c .0 0_ co o O6 .00000 2W1 0 0 0 0 0 0 0LL11 2LL11 0 0 0 2 Moo 2o, ooN 2oM V U 15 C2� � �� aa)i0 0 N 0 0 0 N 00 00 N 0 N N (O W NJ ZI NJ ZI NJ ZI Ce QJ N 11 ED O LLNNNN6A W❑ W W W W W W Lu c) W ❑ W W W W N2 W 2❑ W2❑ W 2❑ /0/L� Y j r- r- r- N- N- r- r- n r- N- I N- r` r_ r- N- r N Om Q O O O O O O O O O O O O O O O N N N W N N N N N N N N N N N N N N Q In L(7 lf) 10 In In t() l\ In In In l\ l(7 up ol N N CDN IX EL L I CD LU CD LD LD LD CD LO LO CD CD L L co IX W c.) rn VQ S C7 ZO o 0 - O < o w. Co Co a0 1`6 7 in up O O O m N W O O 15 JO Q as Cl. O / U CO N Ln C co CO M N Tc• ; rcv Oco7rO 0 N N co O El" E 0 UN 0 N ti o Q 9 ^ 9 v ou N ca 0. M 5r Z N 2 / a• N V N M ILIJ Cr) Q 0 Q Z Ill O Y a) Q o 0 Z o 0 N d 0 E U Al Z CO m m m fa fo m fo @ @ CO fa fa m fa a� m com N fa N fa fa ca CO fa CO CO @ @ fa N (a V CO CO CO N ❑ 0O 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 ❑ ❑ ❑ ❑ 49 ❑ 0 0 n To _1 To co co ca m m ca m m m To To To 2 To To m o ❑ ❑ 2 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ i ❑ ❑ ❑ nV m• to LC) Ln LO LO LC) Ln CD Lf) 0 LO LO CD 10 O O 0 MF_ ` N-r` r` rr` N- N- N- r` r- r• r• r` r• r` r- M M M rM M co CD co'- W co CO CO CO CO CO CO CO 00 00 CO M W CO co co CO N N N N N N N N N N N N N N N N N N N N .` O LJ co Lo wU ., U 0 0 0000000 0 U U U U U 0 U 0 C. 0 m ❑ 'o 0 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 ❑ ❑ ❑ ❑ 0 0 0 0 IL 2 W _1 LU W W W W W W W LU LU W W W _1 LU LU LU • • 0 1 o 10 o o) a a a a N C9O ?I ?I ?I a I CZ 0) 0) C1 0) a 0) 0) 0) n CO Cl) Cl) U) N in co o 0 0 0 0 CO v CO• (0 vi CO CO CO p o Z Z1 Z1 Z1 d O O v 0 0 0 0 0 0 0 0 II EL CC CO N 0 _O _O Q J N °' Ce W Ce Ce C[ W CC Ce O N _M v T CZ M 0 I— F- I— O O o co _ N co r CO r 'p N _ 0 0 0 �1 co co o 0 0 0 0 0 0 CV 0 0 0 o O o o H 0 0 o O o 0 0 0 0 0 0 0 o F• O W LL W • t Z O_x N x 0 0 0 O 0 O 0 0 0 N N N N Z W W W coI 'N w v x el X NI NI NI NI NI NI NI NI NI m1 001 001 001 _ 6) CO 63 "'' 6) m CO m m CCI 031 cal cal 031 O N M E: CCL C a c a 9 L7 0 Q 2 CO co N.:. — N M v 0 I,- CO O Q X 01 X 01 X 01 M M J m ? 0 0 Y 4 01 01l 01 01 01 01 01 01 01 01 01 01 01 LL oI W of W oI I I NI I NI -1 >,63 0 N MI 01 NI NI 01 0I NI of col �I of �1 _I N N N D D e- D W 2-C U In M W M V 0 O) M V Co O N (C) CO O M O co N M CO CO CC CO d' Co O LL m CO O) O N CO v v v v IC) (1) 1)0 co=I m=I CO 7I Y Y d Y d 0 2 N co co N- N- N- N- n N- r` r- r- N- r- I@ Co @ Co Co N 6)V N V Z N J 6)0 6) 0) N o) N a) 0) o) Cl) N N o) G) 0 YIN 0 Y1 U 0 YI r) LL L,L coI LL 01 Y it U it N LL LE Il LL it [L it it it it LL it it • U d to .0 EL co UCL co U U U lL U W U O _U U_ U U U U U U U U U U U 7 � C - C cc— C Q'_ C C 0 C w 0 W C O C O C C C C C C C C C C C C C co 2O'I oON1 2Oc`')1 0 2w ow M0 2 ) o Z 0 0 0 0. 0 0 0 0 0 0 0 0 0 r (•) , y J_D N J D y J D N y 0I 0 01 c0< 0, 9 o U U U U U 0 0 U U C.) 0 U II— J G) 4) C) G) U) 4) 0 0 4) U) C) 0 G) J 1.y I W 2 cc W =or WSor CO W O W O N 2 WO) CO or W W W W W LU W W LU W W W W 0A 1 ` m r r- r- r- n r- N- Is- I,- n r N. r r h. n I,- h Iii u U O O O _ O 0 - O 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N W 0) O) O) 0) 0) 0) W 0) 0) .0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) N N N N N N roe dre m m co co co m n r� n N� r; r; r; W O CO Q.- 0 J Z (ID Z Q .+ oCVCV coco O O 0 J O. CO CL • C N (0 C r O d' V V C O c '� ''.O O O • N a o V = U N W t- o J Q <° ocueko N R Lr, P. Z r� 5 7 G 0 N Tr 7 v m J W C/) Q a1.▪ --6 Q ZU W O Y a▪) ICE o 0 Zo u) m U c E R Z u) 6) CO co CO 6) co N c6 6) co co co co co CO Co CO CO CO CO CO CO O CO Co co CO CO CO -0 CO CO CO CO CO CO CO CO co CO CO CO CO CO CO N 0 0 0 0 0 0 co 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r CO CO CO f6 O To 2 m To co co CO CO CO CO CO CO CO 63 CO CO CO rn rn 0)o) coo) o) CD rn 'En rn rn 'En 'Eo rn o) 6) 'ED 'En 'En "En E) o 0 0 0 0 0 0 0 _1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M > 0 M M CO CO 0 .0 O O) O) co O) O) O) O) O) O) 0) O) 0) 0) 0) r ~ M M M CO M M M V co V V V V V Tr Tr Tr 7 Tr V 7 N-- C‘17) CO Co CO CO CO Co co co Co Co Co co Co O 0 0 0 co Co Co W c0 V. N N N N N N N N N N N N N N N N N N N N N N N •� o O in o o 1C.) 0 0 0 0 0 0 0 0 0 U U U U U U U U U U U U U 0 0 0 ,0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d a 2 W W W W W W W W LU W W W W LU LU LU W W W W W • • 00 CA CA 0) 0) D) 0) 0) 0) CI) 0) m 01 0) 0) 0) 0) 0) 0) C) CP 0) CA 0) CA 0) 0) 0) 0) 0) N 0 a a n s a a a a a n a a a a a a a a a a a a a a a a a a a co U) co co (n (0 co co co co co co U) U) U) co (0 co co co U) U) U) Cl) U) co co co co (0 N in o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 01 >, o Z CC CC R d' cc cc ce ce cc 2 cc 2 R c CC CC CC CC CC CC ce R rr x CC CC CY CC CC ti (%, 1f) CO N- CO O 0 N CO 7 10 CO n CO O) 0 N V) Tr 10 n CO 0) 0 N CO V* t() T COV N N N N N N (ii N N N M M M M C? (h M M M( 'T V V VV' 8 c 0 X X X X X X X X X X X X X X X X X X X X X X X X X X X X X g CD 0 0 0 0 0 0 0 0 0 0 0o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 H NI NI NI NI NI NI Ni Ni Ni NI NI NI NI NI NI NI NI NI NI NI N1 Ni NI NI NI Ni NI NI NI O CO CO m co co co CO m 0) m CO CO CO CO m CO Co co CO CO m co m m co m co co co Z a1f) CO N- CO 0) 0 N CO Cr 1() CO N- CO 0) 0 N co V 1C) O n CO 0 N CO E ,—I .-1 C.. e1 11 .1 NI NI NI NI NI N1 NI NI NI NI CO COI CO CO CO COI COI CO1 CO V1 v1 VI v1 Q 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 �I CO' 01 NI 01 01 CO' 01 UI NI CO 0 1 NI rI NI 01 01 01 NI MI 01 01 LO NI 01 01 'Cl-'I V1 CO U) n CO 0 CO CO n N 0 N CO 0 Cr n 0 O n n CO CO N n O CO n 0 CO N- CO Cn to CO O OCO n 00 CO CO 0) O O O N CO CO V (() (() CO CO n CO CO N CO CO < n n n n n n n n n N- n co co co Co co co co Co co CO CO CO CO CO 0) 0) 0) 0) ai ai ai ai hi hi ui ai ui ai ui ai ai ai ai ui ui ui ai ai ai ui ai hi ai ai hi hi ai LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL iE LL Il LL I.L LL LL LL LL LL LE (0U U U U U U U U U U U U U U U U U U U U U U U U U U U U U 7 C C C C C C C C C C C C C C C C C C C C C C C C C C C C C N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o CO 0a) N a) NN 0) NUUC.) 0 NN0NN0)N N C.) C.) a C.) a) C.) Cl.) 0) CD C.) N C.) a.I LL J c W W W W W W W W W W W W W W W W W W W W W W W W W W W W W 0 1in N- N- n n n n n n n n n n n n N- n n n n N- N. n n n n CL U !0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N W QO) co 0) c a) m m O) a) O) a) m O) 0) O) a) co O) O) 0) a) a) a) O) O) co co co O) W 0• (0 V E 0 Z 8 a • co a) J a cu , o ats. C C � o G N a) T3_ E 0 U N UN w ti 0 J `° a OA N a ii"** Z n �\ Q V C\ W J 7 M W Cl) Q p a 11,1 Z r Y all < O E Ci zo E• 0 m Z CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CD CO m CO CO CO m CO CO m CO CO CO CO CO CO CO CO CO CO CO CO m CO m CO CO m CO CO N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO cn 0) 0) .0) .0) .0) .0) '0) 0) .0) 0) .0) .i7) 0) .0) 0) .0) .0) .0) .0) .0) .0) .0) '0) '0) '0) '0) '0) '0) .0) o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 01 n(7 > 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) ~ Cl- 'Cr *Cr Cr Cr V V' cr .1 V' V- .1 V V V 7 7 V 7 V - V. - V V V . CO CO CO CO CO CO CO CO 00 CO CO CO CO 00 CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO c N N N N N N N N N N N N N N NN N N N N N N N N N N N N N N .` O G 0 O 0 U w o o U o o U U U o o o U o U o o o U U o U U U U o U U U U O a`) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d a •a 1 W W W LU LU LU W LU LU W W LU W W W W LU W W LU W LU W W LU W W W W • • o i" o aC. C) co C) co C) co a) C) C) C) 0) C) C) C) C) 0) 0) 0) o 0) 0. C. 0. 0. 0. C. 0. a 0. 0. C. C. C. C. C. C. C. a N co u) U) m C) m rn rn m C) rn a (0 o 0 0 0- O. a �. �. O. O. o_ • U) C/) CO U) Cl) Cl) Cl) CO U) Cl) CO CO U) CO CO Cl) CO CO T co 2 p p p p p p p 0 p 0 0 p 0 0 p 0 0 0 o Z U) U) U) co U) U) U) co p •� CCCCCLCLCeCLCLCLCLCCIYCLCLCCCCCLCLI:t >!.; M 0 d' �i C6 c- N M V 0 CO N- CO (A 0 N M V U) CO I- CO at N M U) r, co 0) O I I N N N N N N N N N b N6 O O X X X X X X X X X X X X X X X X X X O O X X X X X X X X X 0 O O O O O O O O O O O O O O O O O g N N 0 0 0 0 0 0 0 0 0 U) U) U) U) U) U) U) U7 U) U) U) U) C0 U) U) U) U) U) Z coCO UI UI UI UI �I of UI 01 UI <I <I <I <I <l <I <I <I <I <I <I <I <I <I <I <I <I <IF I v U) < < < < < < < < < o c- N co v (o (o n Co coo N (`1 v co co N- N M V U) CO N 00 0) a- a- a- a- a- '- a- N N N N N N N N Q i0l of of Ol of of OI of of of of of Ol Ol Ol O of Ol of Ol Ol OI OI of Ol O Ol of 0l . NI CO MI of rl NI 01 LI NI of of LI C) 1I _I in 01 01 NI of of of CO 0I NI MI 01 NI 'I • U) CO CO M V CO O CO V 0 00 N 0 N- CO 0 0 CO N- N 0 N CO 0 N- 0 li d V co 0) ON M V V U) U) U) U) O CO CO 0 N- CO CO CO O 0 0 0 < 0) CM 0 CO N- N N N- N- N- N- N- N- f` N- N- h N- I- N- r N- N- N- N- N- CO 00 CO 9 I ai ai hi hi ai ai ai ai ai ai ai ai ai hi ai 6 ai ai ai hi ai ai ai ai ai ai ai hi hi et Il lL u. IL Il lL Il Il lL Il u. lL Il lL Il Il lL 11 lL Il Il Il Il lL IL Il IL IL O O U o U U O O U U U U o o O U O U U U U C) U U U o o O o 7 C C C C C C C C C C C C C C C C C C Ogg C C C C C C C C C O O O O O -0 O O O O O O O O O O O O O O O O O O O O O O O co I— 0 0) NNN NNN 0 N 0Na) a) a) NNNN NN N N N N 0) N N N N N ~ J i W W W W W W W W W W W W W W W W W W W W W W W W W W W W W 0 7 N- r n N- N- h N- N. h N- N- N- N- N- N- N- N- N- n N- N- N- h I- N- N- I- N- N Cl. g V o s o 0 0 o 0 0 0 o 0 0 0 0 0 0 0 0 0 0 o O O o 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N W Q 0) 0) m 0) m a -a a) 0, 0, a, cn a a m a o) m cn o) W c cn O 'O O Cn • 0. r` r; I>; n n r; I>; n n r; I>` r; n I>` n W 0 u) V = 0 z aA co O. as CLI.. 0 20 01 Ta E , N 0 -0 o o0 a▪ `° 0 N to0. 5�_ Z rI G Q N CO m W CO CO a o ' 'CC z Y o o a O o 2 Eo 0 z Co COCD CO CO CD Co CO CO CO CO CO Co CO CO CO CD CD CO CO CD CO CD CD Co CO CO CO CO o co co CD CO CO CD CO CO CO CO CD CD CO CD CD CO CD CO Ca CO CD CD CD C6 CO CO CO CD CO 01 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N- CD CD CD CO CD CO CD CO CO CO CO CO CD CO CD CD CD CD CO CO CO CO CO CO CO CO CO CO CO O p 6 .0 p p p 6 5 0 o p p p p 5566600565 O p p p 55 o n > CD 0) 0) CM CD CD CM 0) CM CM CD CD CD 0) 0) 0) 0) CM rn CM 0) CD CM CM O O CA 0) 0) • ~ v v v v v v v v v v v v v v v v v v v v v c v v v v v v . t0 ao co 0o 0o co co co ao co Co co co o Co co co co coop co co 0o 0 co 0o co Co Co Co ✓ N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 0 O m co O 0 U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 L) cpO 0. gww w w w wwwwwwwwwwwwwwwwwwww www w • • o O 0 N C I 0) 0) 0) 0) O) 0) 0) 0) 0) C0) C) 0) o) O) O) o) O O 1 C. O. 0_ 0. C. 0. 0. C. C. O. C. C. C. C. O_ 0. O. ! z z N co0 O U) U) U) U) Cl) (I) U) (I) (I) Cl) CO CO U) Cl) U) U) U) o /\ J\ 1 A Z Q Q Q 0 Q Q 0 0 0 Q Q 0 0 0 0 0 0 Q } }\ ,? C..)• U O) O N CO V LC) n CO 0) 0 N CO a )f) CO n T N M M M M M M M M M 1- 1- 1- V V V V co0 Cl) N 'O N �. >, 6' in 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M N 0 H O O O O O O O O O O O O O O O O O Q H p I toin iI I.0 LO LI LI 01 �I �I LI LI LI LC) 11)�I 1.0 I.0�I 11 Z n. 0 r Z 0¢0 N O Q N CO U) CCD N. W 0 Q N CO a U) Q . . O 07 N N CO CO CO CO CO CO CO CO Cr) 7 V V �T V V Q 0 Q @ 111111111111111110 '.0 O O O 00 O O O O O O O O O O O Q N N 1 1 I 1 1 1 1 1 1 1 1 1 1 1 I 1 I N 0 0) 0) N CO 0) 0 LO N O 0 Tr V co N CO W _ 0 0 co U 10 0 n n Co co N n CO co n O co n 00 Cn Q 10No CO 00 CO Cr) CO W CO CO CO OOo 0) 0) 0) CA CO CO C 0) CO N N CU N N N N N N CO N N N N N N N Z Il it it it I1 I.L it it it. it it it I1 11 it it it w C Q Q v o g c) v a v g g q o 0 0 n Y 0) Z Z O 0 0 0 0 0 0 0 0 0 0 '0 0 0 '0 '0 '0 '0 on w E c) O© II o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co Q E } co O U U U U U O U U U U O O O O O U O W 0 0 a) m m a) a) a) a) m a) m a) a) a) m m m m • 0 IX J 'C'1,2 LU W LU LU LU LU LU LU LU W W LU LU W W LU LU N 2 LL 0A n n n n n n n n n n n n n n n n N. cp a.. v 0 w LV co U o 0 o O O O o 0 o O o o 0 0 0 0 0 E Y E m '', rn 0 1 N N N N N N N N N N N N N N N N N CO 7 1 Q W QCL rn a) a) a) a) rn a) a) a) o) a) a) a) a) a) a) a) co Zai o) Ce d n n izz n m Con ii E ) N ° 1 'C N pU) O) W 0 Q j CO = E3 E Z O• to ai a, QCL 1 O 0 0 ` Cl)N 0 .� n c J C. .' 0 U C� o co '' d G N a 0 O E1 o VN 0 1 11 0 } cJ Q c N 0 o to — M Q 1 O (Ocz 0 r O IO r H Z n 1 _ co o 111 C6 C < N I d Q N • O 111 W 11 C 0C H E W COE p ICJ . -• O (/) Q 1O1 N I- • o Z — ._ W O - 0 Q .1 •� c• 0 n 1 Q Z E ) . > E Ci) C T 0 0 1 c 0 2 0 CO1 Z I co 1 Ca CO CO (O CO CO CO CO CO CO CO CO CO CO CO (O CO 'a-, 11 N CO CO CO CO CO CO CO CO CO CO- CO CO CO CO CO CO CO '0 1'.. CO 0 0 0 0 Q Q 0 0 0 0 0 0 0 Q Q Q 0 C Q CV • o 0 CO 0 0 CO CO CO CO CO CU CO 0 CO CO c6 0 0 0 4 � 0 Q '6 O b O b 5 6 6 6 b b 5 5 5 6 5 6 J E p 0 M > 0) O 0 CA 0) 0) 0) O Cr) O) 0) 0) 0) 0) CA 0) 0) O w > •C I- v v v v . . v v v v v v v v v v v . C co co co co co co co co co co co co co co co co co co co W E . N N N N N N N N N N N N N N N N N N N NCI) W 0 H a d c o E a !N Z 0 0 co O ct H oII • o d a o o 2 U .2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U 0 CL a z o 0 aE 0 II0 Q Q Q 0 0- 0 Q Q Q. Q 0 00 0 0 O 2 U ti 0 d w LU w w w w w w w LU LU w w LU w w w ° °) 1 LL o 0 • o o 1 o 0 o co N Lo to O 1 o Z N M V v N O Z F. a c? CO in !° s a CI Et -I J J N CL 111 g 7 IX a a reO V J• Q Z Qc. co J Q w O u) CL G N Q 0 ti E N C.) =' 0 m o 0 ti E C O co N Q N 0 vs r M R H 0 O IS, 2 a (11 W = V V W m lam' m 0 CO R o 0 Q Y1p 1 111 o a) Q O a Z E o 0 £0 Z d • M o o \ 11 N N N c N V N 5. M Fre CO CO O d N 2 0 d W m Ce 'C c C1 0 a) c d C] • Z m 0 w V O a c C 0 J N N .Q' N U £ � a m o a C7 E d 1 E E O o 0 0 o m o 0 • 21 61 37 ..9 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 2 8 4 1 ftllrmrp Mask*,T.1A: Fax: 907 777-8510 RECEIVED E-mail: snolan@hilcorp.com DATA LOGGED /U/2o11 K.BENDER JUL 192017 DATE 07/17/17 AOGCC To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 32-06 Rotary Sidewall Core digital data CD1: 50X 7/11/201712:34 PM Fid folder 200X 7/11/2017 12:34PM File folder J Copy of Hilcorp KBU 32-06 HH-94469 CEC Lab Final Data.xlsx 6/13/2017 12:30PM Microsoft Excel War... 28 KB Hilcorp KBU 32-06 HH-94469 Rotary Core Data 5-24-17.xlsx 5/25/2017 10:01 AM Microsoft Excel Wor... 125 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: //�� Date: • • 21 61 37 Seth Nolan Hilcorp Alaska, LLC 2 8 3 3 0 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 0 Tele: 907 8 Hile+arpAltwko,I.Lc ��'��""® Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED JUN 2 9 2017 -I ' 3'2011 K BENDER DATE 06/28/17 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 32-06 Digital data and prints Prints: Perforation Record CD1: KBU 32-06 PERF_04APR17.pdf 6/12/201710:41 AM PDF Document 815 KB KBU 32-06_PERF_04APR17 img.tif 6/12/2017 10:41 AM TIF File 2,772 KB L IN KBU 32-06_PERF_04APR17 LAS.zip 6/12/2017 1:18PM Compressed(zippe... 69 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: ✓�� `�``�Date: • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 2 2017 1a.WellStatus: L COM❑PLETGO ❑N OReR❑ECOMPLE❑TION Suspended❑REPORT Aity C�6o Oil Gas • Abandoned lb.Well Clas . 20AAC 25.105 20AAC 25.110 Development ❑] . Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,SuJpyor, it,,...:-'17 A,14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 7 G..4 •216-137/317-119 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 February 1,2017 • 50-133-20658-00-00• 4a. Location of Well(Governmental Section): 8. Date TD Reached:j,(02 - 16.Well Name and Number: Surface: 526'FSL, 1250'FWL,Sec 6,T4N, R11 W,SM,AK • February,25;2017 1>1.. -r7 KBU 32-06 ' Top of Productive Interval: 9. Ref Elevations: KB: 84 17. Field/Pool(s): Kenai Gas Field • 1976'FNL, 1534'FEL,Sec 6,T4N, R11 W,SM,AK GL:65.6 BF:65.6 Beluga/Upper Tyonek GP 1/Tyonek GP 1 • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1952'FNL, 1514'FEL,Sec 6,T4N, R11 W,SM,AK •10,462'MD/9,626'TVD• FEE A028142 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 272168 • y- 2362578 • Zone- 4 •10,560'MD/9,723'TVD • • N/A TPI: x- 274474 y- 2365309 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 274494 y- 2365332 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes Q(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary Array Dielectric Tool(ADT-GR), Elemental Capture Sonde(ECS-GR), Hostile Natural Gamma Ray Spectrometry(GR/HNGS) Radial Cement Bond Log(02182017), Radial Cement Bond Log(03222017), Production Profile,2"/5"Formation Log MD/TVD 2"LWD Combo Log MD/TVD,2"Gas Ratio Log MD/TVD,2"Drilling Dynamics Log MD/TVD, Final Well Report ROP-DGR-EWR-CTN_ALD 2"/5"MD, DGR-EWR-CTN-ALD 2"/5"TVD t•-•C/-r7 L• u it C•i� L2-) 7 a �• `6 Gus''. 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 16" 109# X-56 Surface 120' Surface 120' Driven Driven 10-3/4" 45.5# L-80 Surface 1,499' Surface 1,452' 13-1/2" 276 sx Lead/331 sx Tail 35 bbls 7-5/8" 29.7# L-80 Surface 6,801' Surface 6,089' 9-7/8" 438 sx Lead/148 sx Tail 4-1/2" 12.6# L-80 Surface 10,547' Surface 9,710' 4-1/2" 675 sx 24.Open to production or injection? Yes Q 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): N/A 10,312'-10,327'MD/9,477'-9,492'TVD 10,333'-10,347'MD/9,498'-9,512'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 10,369'-10,392'MD/9,534'-9,556'TVD '21\11:1.L.'i``k; ', E Was hydraulic fracturing used during completion? Yes❑ No Q . 6 SPF 2-7/8" 1-1/o4 II- Per 20 AAC 25.283(i)(2)attach electronic and printed information `,i _1-flF-lE l.) DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1,-4- , 2 4- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/4/2017 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/19/2017 24 Test Period —O 0 562 9.4 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 254 8 24-Hour Rate — 0 • 562 • 9.4 N/A Form 10-407 Revised 11/2015 (,-'•-/` C �NUED ON PAGE 2 Subm' ORIGINIAL on y ..,0j/7 RBDMS 0- MAY 1 6 2017 6, r7 • • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑Q • Sidewall Cores: Yes 0 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. Analysis of SWC still pending at time of submittal. Full analysis will be submitted upon receipt. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑✓ • No El Permafrost-Top If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 10,312'(D4A) 9,477' information, including reports,per 20 AAC 25.071. P3 A10 4,160' 3,597' The Tyonek D4B sand at a depth of 10337-10355 MD was tested for-1 day I P3 All 4,245' 3,672' with an IP rate of 631.21 Mscf/D of gas and 20.91 stb/D of water. P4 B1 4,334' 3,752' P6 5,054' 4,431' Upper Beluga 5,305' 4,670' Lower Beluga 6,793' 6,085' UT 1B 8,178' 7,406' TY D2 9,746' 8,921' TY D3B 10,060' 9,231' TY D4A 10,295' 9,464' Formation at total depth: Tyonek D6 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys,Csg and Cmt Reports,Surveillance Reports. 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. Contact: Cody Dinger Email: cdincer(C�hilcorp.com Printed Name: Cody Dinger Title: Drilling Tech / Signature:, Phone: 777-8389 Date: ( /2-4-45(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 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including,but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • Kenai Gas Field 11 SCHEMATIC Well:2 6033706 API: 50-133-20658-00 ruu m i,:ua,l,,.I.i.r. RKB=18.65' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" `"Al 1 16 Conductor-Driven 109 X-56 Weld 15" Surf 120' to Set Depth 10-3/4" Surf.Csg 45.5 L-80 Buttress 9.95" Surf 1,499' 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 6,801' _k " , TUBING r 4-1/2" Production 12.6 L-80 DWC/C HT 3.958" Surf 10,547' 10-3/4" i4,0 , TOC=1,710' JEWELRY DETAIL om CBL on Feb . No. Depth ID OD Item 18,2017 «r �. _ 1 20' 4.276" 11" Tubing Hanger 2 6,263' 4.276" 6.875" 15 ft Swell Packer(Water Swell) to 4'' a . 1.4t4 �e rA 6 ' ., k{441_ axe, ,:r� ` .; PERFORATION DETAIL p. a. °w+ Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status ,. T -, D-4A 10,312' 10,327' 9,477' 9,492' 4/4/17 2-7/8" Open 4• "' ' '' D-4B 10,333' 10,347' 9,498' 9,512' 4/4/17 2-7/8" Open . D-4B 10,369' 10,392' 9,534 9,556' 4/3/17 2-7/8" Open t}r Fk , to ;' r ti �r. 7-5/8" +, - * * l''4 to Cti' .1,r g :1 444 444 RA-C 8,850' I t''. RA-B 9,555' OPEN HOLE/CEMENT DETAIL 13-1/2"hole.110.5 bbls(276sx)of 124 lead cement and 72 bbls(331 sx)15.4 ppg 10-3/4 Class A. RA-A 10,255' 435 bbls of lead cement returns to Surface 9-7/8"hole.167.5 BBL(438 sx)of 12.5ppg Class G Extended lead and 30.5 BBLs 7-5/8" (148sx)15.8 ppg Class G tail. 45BBL5 of losses,but recovered 40bbls of mud push at vi: 5, or-ij surface. 4-1/2" ?,'rr V t 541 4-1/2" 6-3/4"hole.160 bbls(675sx)15.3 Class G.100%returns. aacjitiiPBTD=10,462'MD/9,626'TVD TD=10,560'MD/9,723'TVD Max Dev 38 deg @ 2,629' Updated by CJD 05-12-17 • • Hilcorp Energy Company Composite Report Well Name: KEU KBU 32-06 Field: Kenai Gas Field County/State: Kenai,Alaska (LAT/LONG): svation(RKB): 18 API#: 50-133-20658-00-00 Spud Date: 2/1/2017 Job Name: 1613181D KBU 32-06 Drilling Contractor AFE#: AFE$• 4 1/28/2017 Suck water out of boilers. Shut down generators. Rig down remaining power cords. Secure loose items in all buildings. Mobilize Generators,pits,mud pumps,mud pits to KGF 14-6 pad.;Start picking up rig mats as they come available. General housekeeping.;Spot cranes and haul truck to pick derrick. Pick derrick and secure to truck. Pick carrier off of sub. Remove all handrails from rig floor/sub. Move HPU unit. Pick sub structure and mobilize.;Continue picking up rig mats and clearing Iocation.;On Kalotsa pad continue to clean&clear pad.Remove old herculiner and felt.Back haul misc tools&equipment to KRU.;On 14-06 pad finish laying out mat boards,install pony walls for sub. Rig up hand rails,wind walls and lights on all available buildings.Work on PM's and service mud pumps. 1/29/2017 Center and set sub over well. Set drawworks skid,pits,mud pumps Generator,HPU,Boilers. Set derrick on sub. Set water tanks and doghouse. Raise doghouse. Install windwalls.;Start connecting water,steam,and electrical lines. Half mast Derrick. Meet with production to verify spotting of office trailers. Set office trailers. Run power lines and rig up trailers.;Lay out felt and liner for catwalk. Set catwalk. Set support trailers(MWD,Mud,Canrig). Continue rigging up pits. Rig up boilers 1 and 2. Spool up drill line,rig up weight indicator.;Rig up hydraulic lines to sub. Install torque tube. 1/30/2017 Continue rigging up.Finish hooking up water,steam and fuel lines.Change out teflon and bushings on torque tube extend frame.Pick up top drive and hook to blocks.Set up handy berm containment.;UD top drive cradle. Work on removing V-door hing pins for inspection. Rig up mud pits,change deck rubbers on shakers,change equalizer cable. Load water and fire up boiler 2;circulate steam.Continue rigging up lights.Run Pason wires. Install centrifuge house.Total Safety on location,set up gas monitoring system and test. Rig up top drive to extend frame,kelley;hose,service loops and top drive hydraulic lines. Function test top drive.;R/U directional decoder on draw works. Inspect saver sub&shim bail extension cylinders on top drive.Set poor boy degasser.;Ready boiler#1 for inspection.R/U bails,elevators on tongs on rig floor.R/U pull&snub lines.Set Geronimo line. Hook up Pason lines from pits to rig floor.;Housekeeping around pad and rig.Trim up herculiner and felt against handy berm.Repair leaks in steam system. Spot DSA spool&riser in cellar. 1/31/2017 Pre-spud meeting with Hilcorp safety,production operators and both crews. Discussed the importance of good communication and working together. Discussed production alarms and action taken by rig;during an alarm.Rig Accepted 06:00 hrs 1/31/17;Install shaker screens,build hooch for centrifuge feed pump. Install DSA and begin n/u of conductor riser,function tested all pit equipment,built spud mud,installed flow line,chained off stack,;replaced liner wash pump on#1 pump,performed boiler#2 inspection with State Rep,tested rig ESD,CO washpipe on topdrive,check liner and seal seam between catwalk and rig,set up pipe racks,;racked and tallied DP and HWDP,hung tarps at cellar entrance,treated KCL mud in pits 9 and 10,then back hauled back to G&I storage,primed and ran mud pumps,flooded conductor,pressure tested;surface lines,kelly hose and topdrive. Blew down topdrive.Test ran centrifuge.;Install tarps on V-door.Move suction line for centrifuge.Trouble shoot Pason alarms.;lnstall 15.75"ID wear ring.;P/U&rack back in derrick 19 jts 4.5"HWDP,Jars& 40 jts 4.5"CDS 40 drill pipe.;Stage BHA,OD/ID and ready rig floor for M/U.;PJSM.M/U 13 1/2"surface BHA to 120'(Motor,MWD,Flex Collar&1 stand HWDP). 2/1/2017 Spudded well tagging up at 130;started drilling ahead 10K wob,447 gpm and pump pressure dropped to 274 psi at 200'.PU and trouble shot pump issues. Found popoff on#2 pump failed.;Replaced popoff assembly and resumed rotating ahead 3 to 10K wob,513 gpm-1204 psi,60 rpm-4500 ft/lbs on bott torque. Drilled to 360'.;Circulated hole clean at 411 gpm-815 psi,60 rpm-4300 ft/lbs off bott torque while working pipe.Spotted cement silo and racking surface casing. Received Weatherford casing equipment.;Pulled up hole from 360'to 110'.PU 2 x 6 3/4"NM flex DC's and jars.TIH to 360'with no fill.;Resumed drilling 13 1/2"surface from 360'to 795'.Rotating wob 1 to 10K,518 gpm-1260 psi,60 rpm-4330 ft/lbs on bott torque,50 to 160 ft/hr ROP.Sliding wob 7 to 12K,516 gpm-1486 psi,;105 psi diff,114 to 195 ft/hr ROP,MW 9.0/vis 180.Kicked off at 500'building 3 deg/100'.3 of 4 of our trucks are waiting to offload at G&I,4th truck nearly full.Decision made to pull wiper trip;At 796'pumped hi-vis nut plug sweep around at 527 gpm-1411 psi,30 rpm-3970 ft/lbs off bott torque.Had 20%increase in cuttings with sweep to surface.Received 276 sx lead cement in silo.;Pulled up hole from 795'to 298'on elevators with no issues.TIH from 298'to 795'and still no trucks.4th truck full and sent to G&I after sweeping hole clean.Pulled up hole from 795'to 298'.;Waiting on all 4 of our trucks(2-70 bbl super suckers,2-100 bbl vac trucks)to offload at G&I while monitoring well on trip tank.(Drift casing,work on PM's,and start building KCL in premix).;RIH from 240'to 796'with no issues. Broke circulation at 500'.;Drill ahead from 796'to 1,105 MD/1,092'TVD,550 GPM, 1700 PSI,60 RPM,5 K Trq,6-25 K WOB,PU wt 50 K,SO wt 46 K,ROT wt 48 K.;216 bbls cuttings hauled to G&I 174 bbls class II fluid hauled to G&I 2/2/2017 Cont directional drilling 13 1/2"surface hole from 1105'to TD at 1509'.Sliding wob 14 to 26K,549 gpm-1889 psi,55 to 265 psi diff,39 to 250 ft/hr ROP,MW 9.1/vis 72, BGG 11 units.;At 1509'we are at 30.64 deg Inc,39.81 deg Azi,1460'TVD.1.82'low and 3'left of the line.;Circulated hole clean with no sweep(all trucks full and awaiting offload at G&I).525 gpm-1540 psi.Environmental Coordinator Keegan Fleming did walk through of rig and location,no issues.;Pulled up hole on elevators from 1509'to 1223',up wt 53K.At 1223'we had an overpull of 20K.MU topdrive and pumped up hole. Did not have any indication of tight hole. Resumed pulling on elevators;from 1197'to 271'with no further issues.Hole fill was 2.9 bbls over calculated.Called out a 3rd vac truck for backup cuttings handling.;Serviced rig and topdrive.;TIH from 271'to 1509',down wt 40K.MU topdrive but did not wash last stand down. Had no fiIl.;Filled pipe followed with a 20 bbl hi-vis nut plug sweep.Pumped at 541 gpm-1630 psi.Did 3 full circulations.At 2nd circ hole unload a large amount of fine sand.Circ until clean at shakers.;Pulled up hole 5 stands and flow checked.Well static.Blew dwn topdrive and cont POOH.Saw no tight hole at 1223'.Racked back 6 3/4" kflex DC's and jars,LD all 8"tools.Bit graded at 1-1.;Drain stack,MU run tool and engage wear ring.Vac out cellar to BOLD's.Clean and clear rig floor.;BOLD's, W pull wear ring and LD test joint/run tool.CO elevators,PU and dummy run landing jnt/hanger.R/U power tongs&casing slips.:Run 10 3/4"45.5#L-80 BTC W casing.M/U shoe track&check floats good. Run casing on land on hanger @ 1,499';UD casing tongs.R/U cement head&cement lines.Break circulation.;Circ&cond for cement job,250 gpm,200 psi,reciprocate pipe 10', PU wt 75 K,SO wt 50 K;PJSM&Cement 10 3/4"casing.Schlumberger prime ` pumps&pressure test lines 500 psi low,3500 psi high.;123 bbls cuttings hauled to G&I,339 bbls Cum. 127 bbls class II fluid hauled to G&I,301 bbls Cum. • \� • • 2/3/2017 Held PJSM with SLB cementers,Peak drivers and rig team while circulating casing at 256 gpm-185 psi,working pipe every couple minutes with 10'stroke,up wt 70K,dwn wt 50K.;SLB loaded lines with 5 bbls water and checked for leaks.SLB pressure tested lines at 1000 low 4230 high,good tests.Rig pumped 28 bbls 10 ppg MudPush II at 3.3 bpm,47 psi,and shut down.;SLB dropped bottom plug and_pumped 110.5 bbls(276 sx)12 ppq Class A lead cement at 5 born. 100 psi,followed by 72 bbls(331 sx)15.4 ppq Class A tail cement at 5 bpm.:SLB dropped top plug,then displaced with 135 bbls 9 ppg Spud Mud at 5.5 bpm, 410 psi.Slowed to 2 bpm with 10 bbl to go.Bumped the plug and held 1175 psi(FCP of 435 psi)for 3 minutes,;bled off and floats held.Bled back.5 bbls to truck.Had 28 bbls MudPush II return to surface and 35 bbls of 12 ppq lead cement to surface.Cemnet was added to both lead and tail cement at 1 ppb.;Mix water temp at 77 deg. Pumped 50%excess on both lead and tail.Reciprocated the string throughout most of the job,landed the hanger when we started j�� seeing string weight drop off.Had 0 losses.;With MudPush to surface,diverted remaining returns to cellar box through the 4"outlet on conductor.Up wt 100K, CI VL wt 30K at time of landing hanger.CIP at 08:49 hrs,2-3-17.;RD cleaned up and released SLB cementers.Pumped black water thorugh fill up line into wellbore and cellar box,cleaned out cellar box,hauled off excess spud mud,pulled landing jnt,flushed wellhead;removed chains from stack,removed flowline/fillup line,removed bolts from conductor riser assembly.Started building 6%KCL mud in pits 6-7-8-9-10. HSE Rep Leonard Dickerson did audit of rig.;MU packoff assembly on landing joint,landed same,verified landing,RILD's,pulled landing jnt and LD same.Staged"B"section of wellhead in cellar.;Removed flow nipple,spacer spools and DSA.Layed over beaver slide,spotted BOP skid and raised same.Spotted crane,picked BOP stack and transitioned to cellar trolley's.;Installed multibowl"B"section,packed off wellhead to 4000 psi and tested void f/5 minutes at 500 low,then 10 minutes at 3000 high.With crane/Production Operator on loc,set wellhouse..N/U BOPE. Install spacer spool for BOP and set stack. Install HCR valves and hook kill/choke lines up. Connect hydraulic lines. Set and connect degasser. Hook up and pressure up accumulator.;function rams. Continue building 6%KCUPHPA mud. Install catch can,bell nipple and flow line.;Rig down long bails. Rig up testing equipment. Install test plug. Flood BOP. Shell test BOPE. 2/4/2017 Perfumed shell test on BOP stack and choke manifold,blew down all surface lines,cleaned up cellar area,re-hung tarps over cellar entrance,removed 4" valves from conductor,cont mud mixing.;Obtained waived witness of testing from AOGCC Jim Regg via telephone at 11:00 am,flooded stack and surface lines,opened annulus valve,began testing BOPE at 11:30 am,Total Safety on loc;at 11:30 am and calibrated/tested all gas detection equipment.Tested BOPE at 250 low f/5 minutes,3500 high for 10 minutes.Tested annular at 250/2500.Functioned flow alarm and pit gain/loss alarms.;After testing IBOP on topdrive,could not blow down due to ice plug in Kelly hose. Disconnected hose from topdrive and ran 60'of 3/4"conduit up hose to thaw with steam, Kelly hose cleared but still;have a plug in stand pipe,cont thawing that while testing BOPE. Performed draw down test with no issues.Racked 40 jnts DP at catwalk while testing BOPE.Had two fail/pass tests.;Continue to test BOPE,test manual and auto chokes.;Blow down choke manifold. Pull test plug. Flood stack and purge air.;Test 10-3/4"casing to 2600 psi for 30 minutes-good.;Rig down testing equipment,set wear bushing. Continue to attempt and clear stand pipe. Pull conduit out of Kelley hose and steam stand pipe. Prep to pick up pipe.;Pick up 40 joints of drill pipe. Ice in drill pipe is not allowing the drift to fall through. Steam pin ends to get drift out of drill pipe.;Replace gooseneck on top drive. Connect Kelley hose,continue to attempt and thaw stand pipe. Move HWDP and collars from off driller side to drillers side.;Rack back 20 stands of drill pipe. 2/5/2017 Cont PU single in hole,then rack back a total of 120 joints 4 1/2"DP(60 stnds). Had ice plug cleared in stand pipe and stand pipe blown down at 08:30.;MU topdrive on last stand and circulated through surface lines,standpipe and topdrive. Pressure tested standpipe, Kelly hose and gooseneck at 2000 psi.No leaks. RU to blow down topdrive.;Blew down topdrive,prepped rig floor to MU BHA#2. Verify straps.;M/U BHA#2;9-7/8"MM65 PDC bit,7"motor with 1.5°bend, Integral Blade Stab,DM collar(measure rig floor offset)DGC Collar,EWR-P4 collar,stab,PWD,HCIM collar,ALD collar,CTN collar,TM collar;Upload MWD, shallow pulse test MWD. RFO=2.54/6.96=131.38°;Continue M/U BHA(2)Flex collars,XO,(2)HWDP,Jars,Well Commander circ sub,XO,(15)HWDP.;Continue to trip in hole with 4-1/2"CDS40 drill pipe to 1366'. Wash down to plugs 139gpm/268 psi,tag up at 1412';Drill out shoe track with 30-40 rpms/6000-7800 ft-lbs 440 gpm/1250 psi varying weight on bit to drill up plugs,5-7K WOB drilling out shoe track.;Drill 20'new hole at 50 rpms/6100 ft-lbs,440 gpm/1247 psi 1-3K WOB to 1529' 2/6/2017 Held PJSM,displaced well from spud mud to 6%KCL mud with no issues.With good KCL to surface shut down,blew dwn topdrive,cleaned shakers and ditches and pit#4.RU test chart and pump.;Circ with test pump to purge air from lines,closed rams,pressured up to 264 psi,9.0 ppg mud,1450'tvd to achieve an EMW of 12.5 DPP.Good test. RD equipment,blew dwn hoses and pump.Checked SPR's;Resumed drilling from 1529'to 2236'.Sliding wob 4 to 8K,470 gpm-1079 psi,50 psi diff,200 to 300 ft/hr ROP to maintain build rate.Mad passing slide intervals at 180 ft/hr due to ROP,;rotating wob 2 to 4K,420 gpm-980 psi,75 rpm-7400 ft/lbs on bott torque,180 ft/hr ROP.MW 9.1/vis 52, ECD's 9.4 ppg,BGG 9 units.Hole unloading mass amounts of sand every bottoms up after;connections,and shakers run over.Skimming fluid off cuttings bin and storing in pit#10.Will transfer over shakers during wiper trip to recover fluid.;Cont directional drilling 9 7/8"intermediate hole from 2236'to 2545',sliding 20'every stand to maintain 37°inc. Sliding parameters:wob 4 to 8K,420 gpm-1123 psi,80 psi diff,;300 ft/hr ROP to maintain tool face. Mad Pass all slide intervals. Rotating parameter: wob 3-5K,420 gpm/1044 psi,70 rpms/8250 ft-lbs,ROP 180 fph, ECD 9.45 ppg EMW;with 9.0 ppg mw.;Circulate hole clean at 425 gpm/1000 psi,40 rpms/7,200 ft-lbs. Circulate 2.5 x hole volume until shakers clean up. Obtain SPR's. Flow check well,observe slight drop in fluid(seepage loss).;Blow down top drive.;Perform wiper trip to shoe. PUW 72K, SOW 56K. POOH to 1447'with no issues. Hole took 2.63 bbls over calculated hole fill.;Service rig;top drive,draw works.. Monitor well on trip tank while servicing. 0.75 bbls lost in 30 minutes for a static loss rate of 1.5 bph.;RIH to 2545'with no issues,washing last stand to bottom,no fill. Pipe displaced 1.54 bbls less than calculated.;Continue to drill ahead from 2,545'to 2890'. Pump high viscosity/nut plug sweep with 10 ppb additional carbonates no increase in cuttings. Slide as needed to maintain;well plan. MAD passing all slides. sliding parameter:WOB 8K,280 ROP,420 gpm/1140 psi with 60 psi diff. Rotating parameters:WOB 4-6K,74 rpms/8500 ft-lbs;420 gpm/1083 psi.ECD's 9.47 ppg EMW. MW 9.0 ppg.;81 bbls cuttings hauled to G&I,497 bbls Cum. 249 bbls class II fluid hauled to G&I, 1063 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum. • • 2/7/2017 Cont directional drilling 9 7/8"hole from 2890'to 3230',sliding wob 5 to 7K,416 gpm-1170 psi,70 to 120 psi diff,296 ft/hr ROP,Rot wob 3 to 4K,419 gpm- 1090 psi,85 rpm-8800 ft/lbs;off bottom torque,175 ft/hr ROP,MW 9.0/vis 49,ECD's at 9.4 ppg,BGG 11 units.SLR 169 Op's Manager and Structural Engineer on location to inspect derrick and sub-base at 09:30.;Obtain survey,then circ drill string to clean hole while derrick being inspected.445 gpm-1100 psi,40 rpm-6300 ft/lbs off bottom torque,up wt 72K,dwn wt 70K.;Cont drilling from 3230'to 3540',rot wob 3 to 4K,448 gpm-1165 psi,65 rpm-8550 ft/lbs on bott torque,180 ft/hr ROP. Racked 7 5/8"casing and removing thread protectors,spotted upright water tank.;Clean hole with 2 full circulations,436 gpm-1094 psi,40 rpm-7000 ft/lbs off bott torque.Obtained survey and SPR's,flow check static.;Pull up hole on elevators from 3540'to 2482'with no issues.Up wt 100K. Hole fill was 4.5 bbls over calculated.At 2482'crew held BOP drill.;Serviced rig and topdrive.;TIH on elevators from 2482'to 3479'with no issues and no fill. Washed last stand down,made connection and started 20 bbl hi-vis nutplug sweep down drill string.;Cont directional drilling 9 7/8"hole from 3540'to 3973', with sweep to surface had 10%increase in cuttings to surface,sweep on time. Slide as needed to maintain directional profile and 2°/100;drop at 3700'as per plan. MAD pass all slides. Slide Parameters:ROP 200 fph,WOB 4-6K,480 gpm/1400 psi.;Rotating parameters:140fph,480 gpm/1400 psi,80 rpms/9700 ft- lbs. ECD 9.43,MW 9.0ppg. Start to Increase background LCM(varying sized carbonate)to 30 ppb at 3300'TVD.;Observe 400 psi drop in pump pressure with 4%drop in flow. Check SPR,mud pump#2 SPR is 70 psi lower than previous. Clean out suction and discharge screens. Initially appears SPR coming back;then dropping back off. Rack back three stands to 3783'. Circulate at 222 gpm/427 psi with mud pump#1 rotating 17 rpms/6000 ft-lbs while reciprocating pipe and trouble shooting MP#2;Check valve on cylinder 1,appears to be ok but change out. Observe suction manifold to be 50-60% full of carbonates/sand. Clean out manifold,test run pumps-good.;TIH to 3973'and continue drilling ahead to 4154',sliding as needed to maintain 2°/100'drop. MAD Passing all slides. Sliding parameters:WOB 3-5K,ROP 50-200 fph,466gpm/1378 psi.;Rotating parameters: 140 fph,WOB 4-6K,460gpm/1397 psi, 80rpms/10800 ft-lbs of torque. ECDs 9.38 ppg EMW,MW 9.0 ppg. Continue to increase LCM background to 30 ppb.;264 bbls cuttings hauled to G&I,761 bbls Cum. 226 bbls class II fluid hauled to G&I,11289 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum.;Distance to plan:3.31' 3.3'high,0.32'Righ 2/8/2017 Cont direction _drilling 9 7/8"hole from 4154'to 453i' Rotating wob 1 to 3K,477 gpm-1483 psi,60 rpm-9700 ft/lbs on bott torque, 110 ft/hr ROP.Sliding wob 12K,472 gpm-1475 psi,83 psi diff,35;to 50 ft/hr ROP.MW 9.0/vis 45,ECD's 9.4 ppg, BGG 13 units with a max of 36 units at 4471'.Did have some noticeable losses at 4329'and 4343'but was short lived.Cont rack and tally 110 of 7 5/8";casing and prepping 30 more joints for thread protector removal.Mad passed all slide intervals. Loaded upright water tank with 380 bbls fresh water and RU steam loop to heat same.;CBU x 2 at 485 gpm-1513 psi,60 rpm-9186 ft/lbs off bott torque.Obtained survey,SPR's and flow checked(slight seepage).;Pulled up hole from 4533'to 4158'and blew down topdrive.Up wt 120K.Cont pulling up hole from 4158'to 3474'with no issues.;Serviced,Grease blocks,TD,DW and brake. Clean out suction and discharge screens on mud pumps, clean out suction manifold on mud pump#1;RIH from 3474'to 4,533'with no issues. Wash last stand to bottom,no fill,proper displacement.;Continue to drill ahead from 4,533 to 5105'sliding as needed to maintain WP05.MAD Pass all slides. Sliding Parameters:rop 20-50 fph,wob 2-4K,475gpm/1491 psi with 81psi diff.;Rotating parameters:90-140 fph,WOB 5-7K,475 gpm/1500 psi,82 rpms/10500 ft-lbs. ECD 9.43ppg EMW,MW 9.0 ppg;153 bbls cuttings hauled to G&I,914 bbls Cum. 27 bbls class II fluid hauled to G&I,1316 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum.;Distance to plan:4.28' 4.0'high,1.53'left 2/9/2017 Cont directional drilling 9 7/8"hole from 5105'to 5526'.Rot wob 3 to 6K,476 gpm-1626 psi,80 rpm-10,000 to 17,000K fUlbs on bott torque,90 ft/hr ROP. Sliding wob 3 to 8K,481 gpm-;1626 psi,14 to 114 psi diff,12 to 50 ft/hr ROP.MW 9.0/vis 44,ECD's 9.2 to 9.4 ppg, BGG 4 to 16 units.Cont working last of 7 5/8"casing/shoe track.;At 5342',after making a connection and attempting to slide ahead,string hung up.Could not rotate free,could not pull free,PU 50K over jars did not fire.SO with reduced pump rate,increased pump;rate and PU at a faster pace and string was free. Rotated ahead with no further issues. Had a max of 181 units at 5526'while CBU for wiper trip,after drilling into a sand.;Obtained survey,SPR's and flow check shows slight seepage.Circulated hole clean at 474 gpm-1503 psi,40 rpm-10,000 ft/lbs off bott torque.Gas dropped off to 16 units over 40 minutes circulating.;Pulled up hole from 5526'to 4460'; 15-20K bobble noted at 5065'and 5035'(stab 30'back from bit),15K drag noted from 4855'to 4845'wipe clean.;BOP drill with good response. Service rig;grease Top drive,draw works. Check brakes.;RIH from 4460'to 5526'with no issues,washing last stand to bottom no fill noted.;Continue to drill 9-7/8"from 5526'to 5832'. Pump sweep at 5526',came back on time with 10%increase in cuttings. Slide at 5713'due to a right walk and slight drop tendency.;Sliding remains to be difficult with getting weight transfer to bit and multiple 5-10K overpulls when picking up out of a slide,and(2)30-35K overpulls.;Sliding parameters:ROP 0- 20fph,480gpm/1600-1800 psi with 0-200 psi differential.Rotating parameters:ROP 50-120 fph,WOB 5-8K,480 gpm/1741 psi,62 rpms/12K-15K ft-lbs. ECDs 9.42 ppg,MW 9.05.;211 bbls cuttings hauled to G&I, 1125 bbls Cum. 359 bbls class II fluid hauled to G&I, 1675 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum.;Distance to plan:3.46' 3.4'Right,0.6'low. 2/10/2017 Cont directional drilling 9 7/8"hole from 5829'to 6366'.Rotating wob 7K,485 gpm-1720 psi,65 rpm-12,000 ftllbs on bott torque,85 to 100 ft/hr ROP.Sliding wob 5K,476 gpm-1601 psi,144 psi diff,;30 ft/hr ROP.MW 9.1/vis 50,ECD's at 9.5 ppg,BGG 11 units.Had a max gas of 106 units after drilling through a sand at 6065'.Finished up 7 5/8"casing.Changed TD depth to 6810'as per Geologist.;Cont directional drilling from 6366'to 6670'.490 gpm,60 rpm,7k wob, 13k torque on,1l k torque off,9.15 MW,9.55 ECD, 176k up,98k dn,124k rot weights.Shakers blinding off running wet.;Adding 30 bph water.Clays interbedded with siltstones and very fine sands. Losses appear to be around 3 bph.72 bbls lost last 24 hours.;Drill from 6670'to 6810'.Shakers running wet, adding 30 bph H20,480 gpm,60 rpm,7k wob,60'/hr rop.Did not need to slide,held 18°inclination,and 39°azimuth. Record SPR's.;Pump sweep,circulate and condition wellbore for short trip. Ease pumps back up to 500 gpm.,80 rpm,178k up,98k dn,122k rot weights.;223 bbls cuttings hauled to G&I, 1348 bbls Cum. 477 bbls class II fluid hauled to G&I,2152 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum. Daily losses DH 72 bbls,Cum DH 72 bblsWellbore position:6.88'to plan. .13'low,6.87'right. • • 2/11/2017 Tripped out of hole on elevators f/6810'to 6486'wiping through tight spots at 6550'(15k),6510'(25k)and at 6486'(25K)that we could not pull through. Pumped OOH with 420 gpm-1430 psi;f/6493'to 6145'where overpull could not be worked through. Back reamed OOH with 400 gpm-1400 psi,40 rpm-12k torque from 6145'to 5310'. Tripped out of hole on elevators from;5310'to 1460', working through tight spots at 5150'(30k),5120'(30k),5070'(30k),4930' (15k)until clean.On trip tank calculated hole fill was 35 bbls,actual hole fill was 38 bbls.;Put hole on trip tank,hung blocks,RU and cut/slipped 75'of drill line. Serviced rig and topdrive.Functioned upper rams.Fluid loss at 3.3 bph.;TIH on elevators from 1460'to 1525',MU topdrive and CBU one time at 365 gpm-1520 psi.;Cont TIH on elevators from 1525'to 2200'MD.;TIH on elevators to 3100'.Tripping speed held to 1200 to 1400'/hr to get returns.Attempted to trip faster and began pushing mud away.Tripped slower to protect wellbore.Full returns.;CBU,stage pumps up to 470 gpm,30 rpm.9.25 ppg MW out 50 vis.1300 psi pump,no gas seen.;TIH on elevators to 4551'.Tripping speed held to 1200 to 1400'/hr to get full returns. Hole in good shape.;CBU,stage pumps up to 459 gpm,30 rpm.9.25 ppg MW out 50 vis. 1450 psi pump,no gas seen.Shakers running wet at bottoms up,some increase in cuttings load seen.;TIH on elevators to 6100'.Tripping speed held to 1200 to 1400'/hr to get full returns.Hole in good shape.No hole drag seen in the claystone.;Circulate 250 barrels. Drill string volume x's 2. Hole remains in good shape.Full returns,and actual displacement equaled calculated.342 gpm,30 rpm,1000 pp,9.56 ECD.;TIH on elevators from 6100'to 6654'MD.Set down 25k twice.picked up clean.Begin reaming.Swelled claystones.took 5 to 10 k bit weight 50 rpm,360 gpm to clean up.;Reaming @ 6654 to bottom.Swelled claystones.took 5 to 10 k bit weight 50 rpm,360 gpm to clean up.Torque increased from 1l k back ground to 13,500 ft./lbs.while working tight spots.No fill.;Slowly stage pumps up to drilling rates.508 gpm,73 rpm,1l k torque,1930 pp.Once rate was up pump sweep surf.to surf.Shakers unloaded.Dominant cuttings returned was fine sand and clay.No gas.;45 bbls cuttings hauled to G&I, 1393 bbls Cum. 135 bbls class II fluid hauled to G&I,2287 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum. Daily losses DH 74 bbls,Cum DH 146 bbls 2/12/2017 POOH from 6810'to 116'on elevators.Had one 20K over pull at 6594'that we worked through one time and cleaned up.Remainder of hole was very good shape.;Held PJSM on removal of RA sources.;Remove RA sources,plug in and download MWD tool.During this time,well on trip tank,fluid loss rate at 2 bph.;LD remainder of smart tools,motor and bit.Bit graded at 1-2.Calculated hole fill for entire trip=53 bbls,actual hole fill for entire trip=90.5 bbls.;Clear/clean rig floor while spotting SLB e-line unit.Held PJSM with rig crew and SLB crew.;Finish rig up of SLB wire line unit.Assist SLB with Jet Heater to warm equipment. Rig up sheaves,install line wiper.Verify fishing diagram.SIMOPS:Work on shaker beds,pumps,ODS hydraulic winch.;Monitor well on trip tank.Wellbore taking 2.5 bbls/hr loss rate. Heavy winds,and blowing snow.;Start in hole with drift run.Tool length 11.7'.Max OD 4.55".Clear path to bottom and out.Good run,prepare to pick up RFT tool.SIMOPS:House keeping,organize tool room on rig floor.;PJSM:Lay down drift assembly on cat walk. Pick up Gamm Ray,RFT tool assembly,strap and caliper tools.Function test sensors.SIMOPS:Open up suction manifold on MP's.;Gamma Ray tool failure at surface.Pick up back up tool.Certify length and OD.;RIH with Repeat Formation Testing assembly.Begin logging @ 6717',MB-9.After tie-in,actual data collection began @ 03:00. 15 stations of 48 completed.Current RFT depth of investigation 5785'MD.;SIMOPS:Clean suction and discharge screens on both pumps.Complete change out of hydraulic winch on upper mezzanine.Well still exhibiting 2.2 to 2.5 bph loss rate per hour.;35 bbls cuttings hauled to G&I, 1428 bbls Cum. 95 bbls class II fluid hauled to G&I,2382 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum. Daily losses DH 75 bbls.Cum DH 221 bbls 2/13/2017 _ Continue to obtairiRFT's from 5785'to 4195'.Total of 48 stations tested. Rig crew serviced rig pump#1,cont housecleaning and prepped to stage cleanout BHA.SLB e-line POOH from 4195',cleaned and;LD tools,RD and released.Static loss rate of 1 to 2 bph throughout the day.;PU BHA#3(cleanout assembly) as follows:re-run 9.875"MM65 PDC bit,bit sub w/float,XO,stab,2 x NM flex DC's,XO.Total of 9.6 bbls lost to hole last 12 hrs.;Cont TIH with HWDP,jars, HWDP for a total BHA length of 634'.;Trip in 4W CDS 40 DP on elevators from 634'to 1255'.Trip speed 1200 to 1400'/hr. Hole in good shape.Began losing mud @ 12 bph static loss rate©1120'hole depth.Tripped to 1255'.;Establish circulation @ 48 spm 3.3 bpm,80 psi.CBU.After bottoms up the loss rate went back to the constant 2 to 3 bbl/hr. Blow down top drive.;TIH on elevators from 1255'to 2486'.1000 to 1200'/hr trip speed.Pushed away 6 barrels.Attempted to trip faster,but could see the mud level dropping away at faster rates.CBU 280 gpm,20 rpm,5k;CBU 280 gpm,20 rpm,5k torque 310 psi pump pressure.No loss during circulation. Hole appears to be healing as we get deeper.;TIH on elevators from 2486 to 3736'. Increased trip speed to 1800'/hr.Good displacement.;Circulate BU 380 gpm,25 rpm,6k torque,580 psi pp,MW out 9.25 ppg,53 vis.Blow down top drive.;TIH.Hold trip speed to 1800'/hr. Hole able to support faster trip speed the deeper we go. No obstructions.Trip from 3736'to 4970'.Good hole displacement.;CBU @ 4970'MD.440 gpm,25 rpm,860 psi pp,8k torque, 110k up/70k do/85k up weights.BD TD.Line up to trip tank.;TIH.From 4970'to 5500'MD. 1800 to 2000'/hr trip speed.;0 bbls cuttings hauled to G&I, 1428 bbls Cum. 0 bbls class II fluid hauled to G&I,2382 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum. Daily losses DH 48 bbls.Cum DH 269 bbls 2/14/2017 Cont TIH on elevators from 5500'to 6807'with no issues. Up wt 160K,dwn wt 70K.MU topdrive and washed last single to bottom.;Circ 398 gpm-877 psi,80 rpm-12,000 fUlbs off botm torque.CBU one time then pumped 20 bbl hi-vis nutplug sweep around.BGG 7 units.Circulate on more annular volume bringing pH up from 8.1 to 10.1.;Obtain SPR's,MP1 at 48 spm=215 psi,MP2 at 48spm 206 psi. Flow check well.;POOH with clean out assembly from 6810'to 635'. One 25K bobble at 6640',wipe through clean. Stand back HWDP. L/D jars,XO,collars. Hole fill calc=50.8,measured=69.48.;Pick up test joint for 7.625" solid body casing rams,make up to wear bushing running tool,clean and clear rig floor.Suck out cellar with Peak.Lay down rig elevators/bails.;Pull wear ring. Remove from rig floor.;Change out Upper pipe rams to 7.625"casing solid body rams.SIMOPS:Continue to get ready to test on the rig floor.;Rig up test equipment.;Test BOPE.Test annular to 250 psi low for 5 mins,2500 psi high for 10 mins.Test 7.625"casing ram to 250 psi low for 5 mins.3500 psi for 10 mins.;Rig down test equipment,blow down lines remove test plug.;Make dummy run with landing joint and hanger.Measure 20.20 rig floor to load shoulder. Calculated prior to dummy run to be 20.20 by Wellhead hand.SIMOPS:place casing spiders,tongs on catwalk.;PJSM:Rig up Weatherford casing equipment. Stage centralizers.;PJSM.Make up shoe track, Baker Locked to pin end of#4.Check floats.Good.Run 7.625"L-80 29.7#DWC to ioint#10,and then cross over to BTC.DWC torqued to 22k,BTC torqued to 7700 fUlbs.;Continue to run 7.625"L-80 29.7#BTC casing to joint#25,1056'MD. Heavy snow last night 4 to 6 inches.Very wet snow. Packing into slips,and requiring steaming to clear out very 5 to 7 joints.;18 bbls cuttings hauled to G&I, 1446 bbls Cum. 72 bbls class II fluid hauled to G&I,2454 bbls Cum. 0 bbls cement hauled to G&I,35 bbls Cum. Daily losses DH 50 bbls,Cum DH 319 bbls • • 2/15/2017 Continue to RIH with 7-5/8"casing from 1056'to 1260'at 1900 fph,watching displacement to dictate running speed. Static loss rate was 2.1 bph.;Circulate annular volume at 160 gpm. Blow down top drive.;Continue to RIH with 7-5/8"casing from 1260'to 3305'max 1900fpm. Displacement shows about 1-2 bbl loss/10 joints on top of static loss rate of 2.1 bph,decreasing to 0.5-1 bbls/10 joints at 2441'.;Circulate annular volume,staging pumps up to 225 gpm/105 psi in the up stroke.;Continue to RIH with 7-5/8"casing from 3305 to 5352'.;Circulate annular volume staging pumps up in upstroke to 205 gpm/181 psi. 5 bbls lost during circulation. PUW 175K,SOW 94K;Continue to run 7.625"L-80 29.7#BTC casing.fr 5352'to 6775'.Pick up landing joint and hanger.Land casing on depth 6801.48'.;Remove casing bales hydraulic rams to allow the top drive to screw into landed hanger joint.;Circulating and conditioning mud for cement job. SIMOPS:Rig down Weatherford casing equipment,power tongs,slips,elevators.250 gpm,245 psi.Reciprocate string.Pull up to 300k,broke over and;moved with 240k up.Came down,landed,picked up 4 feet and caught the lower pipe rams with hanger,drop down,attempt to pull up again and contacted at the PP same mark.Set down.Stayed landed.;Rig up cement head and lines,cement manifold.;PJSM with cement crew and rig crew.SIMOPS:Continue to C&C. p(� Position all trucks,people,D110,complete radio checks.Prime SLB pumps.;SLB pumped 5 bbls of water. Pressure test low to 2000 psi,high 3500 psi.Rig 1 . pumped mud push 41 bbls.SLB batched up and pumped 80 bbls of 11 ppg Lite CRETE cement @ 5 bpm,450 psi.;CeJnent DumP Packed off.SLB beaan trouble shooting problem.Emptied tub with Peak truck.45 mins later began to circulate out with rig pump.;Circulate mud push,and 80 bbls of cement out with rig.280 gpm,pressure start 262 psi.Lift pressure 588 psi.Dump all mud push and cement to cuttings tank outside.Treat with citric acid,D110.;*Note:Cement pumping unit completed cleaning out 04:00.;BIow down mud lines back to mud pumps,rig down cement head and hard lines.Clear cement manifold of fluid. Rig down,and pick up swedge.;Build black water pill in pill pit.Line up to kill line and flush BOP stack.Circulate mud system to lower PH from 12.5 to 10.;0 bbls cuttings hauled to G&I, 1446 bbls Cum. r/S- 0 bbls class II fluid hauled to G&I,2454 bbls Cum. ,; • • 2/19/2017 Single in with 4.5"CDS 40 from 2300'to 4420'MD.;RIH from Derrick to 6652'. Wash down 200 gpm/1067 psi. Observe stringers at 6664'taking little effort to work through 0-3K WOB 50 psi diff pressure.;Tag up at 6697'. Drill up plug and float equipment with 5-15K WOB,30 rpms/10,000-13500 ft-lbs,268 gpm/ 100-350 psi differential. Displace to 10 ppg mud while drilling ahead to 6830'.;Circulate hole clean and ensure even 10.0 ppg MW all the way around.269 gpm/1700 psi.;Rig up and perform FIT to 13.1 ppg EMW. Rig down and blow down testing equipment.;Continue drilling ahead from 6830'to 6855';ROP 70- 90 fpm,WOB 10K,30 rpms/12,300 ft-lbs,265 gpm/2060 psi with 450 psi diff, ECD 10.74 ppg EMW.;Directional drilling from 6855'to 7057';ROP 70-90 fph, WOB 10K,65 rpms/12,300 ft-lbs,268 gpm/2080 psi with 400 psi diff,ECD 10.81 ppg EMW. Attempted to slide 10 x's,motor stalling with 4k wob.;Directional drilling from 7057'to 7120'.pump lube sweep to bit.(20 bbls mud,1/2 drum NXS,3 sxs Nut plug)..Orient and slide,motor stalling w/ light weight.2k wob motor in full stall.;290 gpm,2250 psi with 400 diff.Well bore is smooth,good weight transfer.164k up/80k do/104k rot.After unsuccessful slide rotate ahead rest of the stand.;Directional drilling from 7120'to 7171'.Pump 2nd lube sweep to bit.(20 bbls mud,1/2 drum NXS,3 sxs Nut plug).Orient and slide,Able to get 6 feet.Motor stalling at light weights.;Directional drilling from 7171'to 7242'. P/U 168k,S/O 80k,Rot 108k,Torque 13k,Gpm,294,Rpm 80,PP on bottom 2350 psi with 400 diff.ECD=10.83 ppg,MW=10.0;Wellbore position: 12.39'from plan.7.4'high/9.9'right.;8 bbls cuttings hauled to G&I, 1493 bbls Cum. 77 bbls class II fluid hauled to G&I,3187 bbls Cum. 0 bbls cement hauled to G&I, 117 bbls Cum. Daily losses DH 0 bbls,Cum DH 542 bbls 2/20/2017 Continue to drill ahead from 7242'to 7828'. Sliding as needed,MAD pass all slides. Sliding Parameters:10-40 fph,WOB 4-6 K,291 gpm/2039 psi with 80 diff. Rotating parameters:;ROP 120—140 fph,WOB 6-8K,284 gpm/2466 psi with 256 diff,60 rpms/13800 ft-lbs of torque. ECD's 11.25 ppg EMW with 10.0 ppg mud. Observe stick slip while drilling ahead;slow rotary from 80 rpms to 60 to attempt and mitigate. Alternate mud pumps and clean suction and discharge screens to aid in MWD detection.;Max gas 253u at 7691',no connection gas BGG 28u. Obtain survey and SPR's:pump#1 599 psi,pump#2 572 psi at 48 spm.;Pump Hi-Vis sweep Surf.to surf.30%increase in cuttings.Came back 30 BBLS early. PP 2191,Gpm 289,MW 10.1,Rpm 75,TQ 13k, Pumped two more BU strokes for shakers to clean up.Monitor.Static.;Trip out on elevators.7828'to 7511'.Pulled tight @ 7468'.30k over 3 x's. Drop down to 7511'. Prepare to back ream.;Back ream fr 7511'to casing shoe @ 6801.Encountered swelling clays.PP 1820,Gpm 260,Rpm 75,13.5 to 14.5k TQ,MW= 10.1 ppg, ECD=11.25 ppg.BR into casing then place bit 70'outside casing.;RIH one stand.Circ.sweep surf.to surf.10 ppb medium nut plug,10 gallons condet, Hi-Vis 20 bbls,50%increase in cuttings.PP 1726,Gpm 262,Rpm 75,TQ.12.7k.Pull into casing up to 6788'.BD TD.;Service rig.Top drive,draw works,iron roughneck.Drive line bolts,All fluids in motors.;Trip in the hole on elevators to bottom.6788'MD to 7728'MD.Wash/ream last stand.Calc. displacement=19.8 bbls.Actual displacement=19.2 bbls.Hole in good shape.;Pump Hi-Vis sweep.directional drill from 7728'to 7893'MD,PP 2300,Gpm 260, Rpm 60,TQ 13k,460 diff, ECD=11.01,MW=10.15 ppg.;79 bbls solids to KGF G&I.Cumulative:1,599 291 bbls Class II junk fluid to KGF G&I Cumulative:3,541 0 bbls cement to KGF G&I Cumulative:117 bbls Daily losses downhole:0 bbls Cumulative:542;Wellbore position:8'off plan.7 low,3'left. 2/21/2017 Continue drilling ahead from 7893'to 8,330'sliding as needed to maintain WP. Weight transfer to the bit has improved after the wiper trip to the shoe. MWD detection has been spotty,continue to;alternate mud pumps and clean suction and discharge screens to assist. Continue to weigh mud system up gradually to 10.45 ppg. no connection gas observed. BGG 20u.;Sliding Parameters:ROP30-50 fph,282 psi/2190psi with 166 diff,WOB 3-5K. Rotating Parameters:70- 120 fpm,282psi/2484psi with 445 diff,70 rpms/14500 ft-lbs. ECD's 11.42 ppg with 10.45 ppg MW.;Continue drilling ahead from 8,330'to 8,819 sliding as needed to maintain WP.Drilling Parameters:285 gpm,2400 psi, WOB 6-9K,PU wt 200 K,SO wt 90 K,ROT wt 120 K,70 rpm,Trq 12-14 K ft lbs.;Pump sweep and circulated hole clean for short trip.285 gpm,2400 psi.(10%increase in cuttings with sweep).Mud wt In/Out 10.8 ppg;68 bbls solids to KGF G&I.Cumulative:1,667 202 bbls Class II junk fluid to KGF G&I Cumulative:3,743 0 bbls cement to KGF G&I Cumulative: 117 bbls Daily losses downhole:0 bbls Cumulative:542 2/22/2017 Continue to circulate hole clean at 285 gpm,2400 psi. Obtain SPR's,monitor well.;POOH with drilling assembly to 8504'where it pulled 25K over at the beginning of a stand. Attempt to wipe clean unable to. Establish circulation,but pump pressure continues to build,attempt to;rotate and neutral weight stalling out. RIH one stand while establishing circulation 200 gpm/1400 psi,rotary 50 rpms/14300 ft-lbs. Ream up from 8555'to 8504'and back down to 8473'.;Lay down one single to be able to work pipe. Continue POOH from 8473'to 7676'on elevators,observe consistent 5-7K drag tight spots noted at 8191',and 8010' wipe clean. Conduct BOPE drill.;Service rig:grease draw works,check drive bolts.;RIH from 7676'to 8819'with no issues,washing last stand to bottom, calculated hole fill. Wiper gas 1848u.;Continue drilling 6-3/4"hole from 8819'to 8892'. Pump high viscosity/nut plug sweep once on bottom,10%increase in cuttings. Initial ROP 100 fph quickly diminishing after 4'down to 5-10 fph,;attempt to adjust parameters:WOB from 4K-20K,rotary 50-80 rpm's with no improvement in ROP. Parameters look similar to prior to wiper trip. Pump nut plug/drill n slide sweep with no improvement.;Pick up off bottom several times as we adjust parameters. Slide at 6-10 fph,Motor is building differential pressure,but WOB is drilling off slow.Continue rotating ahead.;Pump lubricity pill with 30 gallons of NXS lube once it hits the bit at 8847 observe ROP increase to 90 fph,decreasing back to 40-50 fph. Rotating parameters:;ROP 5-100 fph,WOB 4-20K,287 gpm/2900 psi with 450 diff 80 rpms/14000 ft-lbs. ECD's 12.26 ppg EMW. Continue to weigh mud system up,current weight 11.0 ppg.;Continue drilling ahead from 8,892 to 9,180'sliding as needed to maintain WP.Drilling Parameters:295 gpm,2600 psi, WOB 15 K,PU wt 210 K,SO wt 98 K,ROT wt 134 K,75 rpm,Trq 14 K ft lbs.;Drilling thru various hard spots and significantly slowing rop.Pumped lube sweep with no success.Weighted up mud system from 11.0 ppg to 11.2 ppg.;18 bbls solids to KGF G&I.Cumulative:1,685 72 bbls Class II junk fluid to KGF G&I Cumulative:3,815 0 bbls cement to KGF G&I Cumulative:117 bbls Daily losses downhole:0 bbls Cumulative:542 2/23/2017 Continue to drill ahead from 9180'to 9198'with 10-15 fph ROP,WOB 8-20K,293 gpm/2644 psi 260 diff,80 rpms/14300 ft-lbs. Pump sweep with 2.5%NXS lube,shortly after exiting the bit observe ROP;increase to 50-100 fph. Begin adding NXS lube to the active system.;Continue drilling ahead from 9197'to 9520' continue to add NXS lube up to a concentration of 0.5%with increasingly steady higher ROPs. Continue to weigh up mud system to 11.4 ppg;sliding as needed to drop 2°/100;MAD passing all slides. Sliding parameters:ROP 20-60 fph,WOB 2-5K,292 gpm/2791 psi with 200 diff.;Rotating parameters:70-120 fph,WOB 9-12K,285 gpm/2950 psi with 400 diff,80 rpms/15400 ft-lbs. ECD's 12.55 ppg EMW.;Continue drilling ahead from 9520'to 9817'.Drilling Parameters:285 gpm,2700 psi, WOB 10 K,PU wt 196 K,SO wt 110 K,ROT wt 146 K,75 rpm,Trq 15 K ft lbs.;Pump sweep and circ hole clean. No increase in cuttings:POOH from 9817'to 8702'.Tight spots @ 9784'&9716'with 25 k over pull.Worked thru once without pumps.;Service rig.;RIH from 8702' to 9817'with no issues.Washed last stand to bottom while pumping sweep out of bit.;54 bbls solids to KGF G&I.Cum:1,739 bbls 306 bbls Class II junk fluid to KGF G&I.Cum:4,121 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:542 bbls • • 2/24/2017 Continue drilling from 9817'to 10205'. Sweep after wiper trip did not have an increase in cuttings but did come back 11 bbls early. ROP after wiper trip 50-80 fph diminishing to;15-20 fph. Pump one 2.5%NXS lube sweep with temporary increase in ROP(50-70 fph for 8'). Second sweep initial ROP increase to 30 fph gradually increasing to 80-100 fph at 9961';with intermittent slower drilling(20fph). Rotating Parameters:80-100 fph,75 rpms/15,500 ft-lbs,10-12K WOB, 288 gpm/3260 psi with 500 diff. ECD's 12.91 ppg with 11.6 ppg MW.;Continue drilling ahead from 9817'to 10524'.Drilling Parameters:285 gpm,2700 psi, WOB 15 K, PU wt 206 K,SO wt 112 K,ROT wt 150 K,75 rpm,Trq 13-17 K ft lbs.;27 bbls solids to KGF G&I.Cum:1,766 bbls 63 bbls Class II junk fluid to KGF G&I.Cum:4,184 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:542 bbls 2/25/2017 Continue drilling 6-3/4"hole from 10,524'to 10560'rotating ahead:ROP 15-50fph,284 gpm/3055psi with 488 diff,60 rpms/15700 ft-lbs of torque,ECD 13.0 ✓ ppg with 11.9 ppg MW.;Pump high viscosity sweep(10%increase,on time)and circulate hole clean while weighing up mud system to 12.1 ppg 274 gpm/2400 psi,60 rpms/15000 ft-lbs. Obtain SPR's,monitor well.;Wiper trip to casing shoe:PUW 230 SOW 120. Observe 5-10K over pull to break over coming out of the slips.;Continue to POOH wiping tight spots of 25-40K at 8482',8456',8362',8305',8214',7999',7894',7667',7631',7503',7432',7381',7315',7195', 7174',6947',;6923',and 6871'. Unable to wipe two spots clean at 7631'and 7129'establish circulation and rotary to back ream at 200 gpm,50 rpms/10K torque up to 15K. POOH to 6715'.;Hole fill took 8.13 over calculated.;Slip and cut 116'drilling line.;Service rig;adjust brakes,grease crown,top drive. Change out dies on iron roughneck.;RIH with no issues from 6715'to 10,560';Pump sweep&circ hole clean with 285 gpm,2600 psi,mud wt In/out 12.1 ppg.Prep pits for displacement.;Spot 193 bbls high vis mud in open hole.;POOH from 10,560'to 7,000'(1 tight spot in coals @ 8575'with 40 k max overpull worked thru once and clear);84 bbls solids to KGF G&I.Cum: 1,850 bbls 166 bbls Class II junk fluid to KGF G&I.Cum:4,350 bbls 0 bbls cement to KGF G&l.Cum:117 bbls _Daily losses downhole 24 bbls.Cum:566 bbls 2/26/2017 Continue to POOH from 7000'to 120'with no issues.;UD BHA.Remove sources,read MWD tools. Bit grade 1-1-WT-A-X-I-NO-TD. Significant wear noted on in-line stabilizers.;Prep clean out BHA.;Spot E-Line truck. Rig up E-Llne.;RIH with E-line dummy run tools to TD of 10,560'.Pick up off bottom&tool hung up @ 10,500'. Pull free with 3K overpull. No other tight spots.;Perform differential sticking test© 10,370'&9,500'for 5 min(good)RIH to 10,370'and perform 10 • min test(good)POOH with E-line dummy run tools.;M/U E-line RFT&gamma assembly&RIH to 10,560'.POOH while logging to 6801'.RIH to 10,370'for pressure samples. POOH taking RFT pressure samples.(Formation losses.5 bbls/hr);0 bbls solids to KGF G&I.Cum: 1,850 bbls 0 bbls Class II junk fluid to KGF G&I.Cum:4,350 bbls 18 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 18 bbls.Cum:584 bbls 2/27/2017 Continue taking formation pressure reading with XBT tool on SLB E-Line. Collected 55 samples. Monitor well on trip tank,static loss rate 0.5 bph.;Sim Ops: perform 16,000 hr maintenance on MP#2 engine,change fan belt on MP 1,work on PM's on fuel pumps,HPU motor,clean pits 1 and 5.Clean suctions on mud pumps.;Cont.collecting formation pressure samples.Monitor well on trip tank,static loss rate 0.5 bph.;POOH with E-line XPT assembly and UD.;M/U E- line side wall coring assembly&RIH to 9,544'.(Tight spots 7060',7150'&7400');POOH while taking 50 sidewall core samples.Rig working on PM's.Changed out swabs&liners on mud pumps from 5"to 5.5";0 bbls solids to KGF G&I.Cum:1,850 bbls 0 bbls Class II junk fluid to KGF G&I.Cum:4,350 bbls 18 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 12 bbls.Cum:596 bbls 2/28/2017 Continue to collect a total of 50 side-wall cores on SLB E-Line. POOH with E-Line. Lay out tools,retrieved 44 of 50 cores.Cont to move smart tools and mud products to next pad.;MU neutron lithology tool,held PJSM with a-line and rig crew on loading RA source,load source and RIH on e-line to 10,481'with no issues.C/O outer shaker screens to 140's for cleanout run.;Pull up hole logging from 10,481'to 9400'.At 10,300'and 10,000'e-line had overpulls of 2K.Well on trip tank during logging,hole took 3.36 over last 12 hours.;Cont logging up hole from 9400'to 7700'.Had a 3K overpull at 9250'and a 4K overpull at 8678'.;Down hole E-Line tool fail and lost communication with tools.;POOH&change out E-line tools. PJSM prior to removing radio active sources.;RIH with Gamma&neutron lithology tool to 7700'.;Cont.logging from 7700'to 6650'.;POOH with E-line tools. PJSM prior to removing radio active sources.R/D E- line.;Service rig&top drive.;M/U 6 3/4"clean out BHA&RIH to 1940';5 bbls solids to KGF G&I.Cum: 1,855 bbls 45 bbls Class II junk fluid to KGF G&I.Cum:4,395 bbls 18 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 12 bbls.Cum:608 bbls 3/1/2017 Cont to TIH with BHA#5(6.75"cleanout assembly)from 1940'to 6789',filling pipe every 1500'.;MU topdrive,fill pipe and CBU one time at 275 gpm-994 psi. Had a max of 70 units gas at bottoms up. Blew down topdrive.;Cont TIN from 6789'to 8649'filling pipe every 1500'.;MU topdrive,fill pipe and CBU one time at 260 gpm-143 psi.Had a max of 153 units gas at bottoms up.Blew down topdrive.;Cont TIH from 8649'to bottom at 10,560'.MU topdrive and washed last two stands to bottom.Had+/-20'fill.207 gpm-1247 psi,50 rpm-14,300 ft/lbs off bott torque.;CBU one time then pumped a 20 bbl hi-vis nutplug sweep around at 270 gpm-1475 psi,50 rpm-14,000 ft/lbs off bott torque.Had 235 units gas at bottoms up.Did one more circ after sweep to surface,;then pumped a 20 bbl nutplug pill followed with 5 ppb nutplug in suction pit and spotted pill in open hole section to help with seepage after core sampling.Had 10%increase in cuttings from sweep.;POOH from 10560'to 6784';Cont.to POOH while laying down 4 1/2"drill pipe from 6784'to 2000';0 bbls solids to KGF G&I.Cum:1,855 bbls 0 bbls Class II junk fluid to KGF G&I.Cum:4,395 bbls 0 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 8 bbls.Cum:616 bbls 3/2/2017 Cont POOH LD 4 1/2"DP from 2000'to HWDP at 380'.;TIH from 380'to 4178'with 4 1/2"DP from derrick,filling pipe at 2249'.MU topdrive.;Filled pipe then did one full circ to remove any air from wellbore,at 219 gpm-550 psi and blew down topdrive. Had no gas at bottoms up.;POOH LD 4 1/2"DP from 4178'to 380',then LD HWDP,jars,flex DC's,stab,bit sub and bit.Bit in fine shape,graded new-0.;Drained BOP stack,PU test joint and retrieved wear ring.;Dummy run landing joint/hanger(18.65'),change elevators,change grabber dies,RU fill up line,RU casing tongs,slips 4 elevators.;PJSM on running casing.P/U shoe track to 127.Check floats(good).;RIH 4 1/2"12.6#DWC production casing from 127'to 6366'PU wt 70 K&SO wt 50 K.;1 bbls solids to KGF G&I.Cum: 1,856 bbls t_ , 9 bbls Class II junk fluid to KGF G&I.Cum:4,404 bbls I if '1( L' 0 bbls cement to KGF G&I.Cum:117 bbls Z Daily losses downhole 15 bbls.Cum:631 bbls • • 3/3/2017 Cont.to RIH 4 1/2"12.6#PWC production casing from 6366'to 6779',just above Intermediate casing shoe.;MU circ swedge and topdrive,break circ at 187 gpm-379 psi,change from short to long bails and YT elevators.Blew down topdrive.;Cont PU single in hole with 4 1/2"casing from 6779'to 8850'(half way down open hole)with no issues,down wt 56K.;Mu circ swedge and topdrive,break circ at 242 gpm-683 psi.Had 38 units max gas at bottoms up.Up wt 105K, dwn wt 66K. Blew down topdrive.Called out SLB cementers and wellhead Rep.;Cont PU single in hole with 4 1/2"casing from 8850'to 9685'where string became differentially stuck after making up joint#231.Started seeing some slight sticking at 9600',after connections;but broke over pretty easy on the down stroke and no issues while slacking off.;At 9685'we could not slack off at all nor PU and break free.Notified Drilling Engineer.Work pipe at 180K up,30K down with no movement.LD jnt#231 and installed circ swedge.PU jnt#231;and MU topdrive. Broke circ at 230 gpm-650 psi,cont to work pipe at 180K up,60K down,maybe slight movement on upstroke.Increased pump rate to 330 gpm-1115 psi,isolated active system;to pits 2-3-4 and started cutting mud weight back from 12.1 ppg to 11.6 ppg.At bottoms up we had 12.0 in-12.2 out and 45 units gas.Cont circ and work increased up wt to 240K to 260K,rotated 2;rounds on string-7800 ft/Ibs torque on topdrive and cont to work pipe(MU on DWC 6000 ft/lbs)with no luck,got 1 round back after releasing grabber and working pipe. With mud weight at 11.6 in-11.6;out,LD jnt#231 and started pulling to 280K.BGG at 0 to 1 units,pump 352 gpm-1073 psi.Discussed with Drilling Engineer about pumping a 25 bbl 6%brine pill(MW 8.6+)with 1 drum NXS lube and spot;outside casing. Put MudPush from pill pit on vac truck,cleaned pill pit and loaded with 24 bbls 6%brine,added 1 drum NXS lube. Have had no issues circulating or apparent losses.;Spot 21 bbls of 8.6 ppg KCL brine with 5%NXSA lube out side of casing in annulus and let soak for 1 hr.Cont.to work stuck casing with no success.;Circulate out brine pill&cut mud wt from 11.6 ppg to 11.0 ppg.Work stuck casing 250-280 k pick up&80-40 k slack off.No success.;Hang off blocks&change out bolts on brake pads on draw works.Circulate& cond mud 11.0 ppg in&out.;Cont.to work stuck casing 250-280 k pick up&80-40 k slack off. No success.Mobilize Halliburton Black Magic stuck pipe pill to rig.Prep pill pit for black magic.;2 bbls solids to KGF G&I.Cum:1,858 bbls 188 bbls Class II junk fluid to KGF G&I.Cum:4,592 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/4/2017 Loaded 18 bbls diesel into pill pit and mixed 25 bbl batch of Black Magic bringing weight up to 11.0 ppg to reduce chance of migration up hole.Offloaded first batch into vac truck then built;second 25 bbl batch.Circulated string at 294 gpm-802 psi with no gas and worked pipe at 260K up,60K down with no movement while building pill.Shoe at 9685'md/8850'tvd(Tyonek D2 est 500 psi).;Held PJSM with rig crew,mud engineer and Peak driver on pumping/spotting pill and blowdown topdrive.Lined up on pill pit and pumped 45 bbls,leaving 5 bbls inside casing. 197 gpm-618 psi.;Chased pill with 142 bbls 11.0 ppg 6%KCL mud. Pill coverage outside casing=1,666',top of pill at 8019'md.Shut down pump,no gas,no flow.;Broke off topdrive,broke off 19'pup jnt, lowered same to rig floor and blew down topdrive,stand pipe and mud line.MU pup jnt and topdrive on string and parked at 80K.Allowed pill to soak while;servicing various rig equipment.;Held PJSM with rig crew and Weatherford Rep.Started working pipe at 288K up,60K down.Up stroke#6 we gained a good 8"of movement up hole,then another 4"on up stroke#10.Put two wraps to the;right in string,+/-7800 ft/lbs torque and cont to work with no further movement.Got back 1 1/2 rounds after working a dozen times. Parked string at 60K for crew change and discuss plan forward.;Letting black magic pill soak for 1 to 1.5 hours then attempting to free pipe with 240-280 K up&60-40 K down. Attempt to apply rotation with 7 k ft/lbs.and work pipe. No success.;4 bbls solids to KGF G&I.Cum: 1,862 bbls 161 bbls Class II junk fluid to KGF G&I.Cum:4,753 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/5/2017 Cont to soak and work 4 1/2"casino with no movement.280K up,60K down.;Pumped through bleeder to fluid pack mudline,pumped 30 bbls 6%KCL mud at 139 gpm-636 psi to move top of Black Magic pill up hole,from 8019'to 6801'.Broke off topdrive and pup joint,blew down.;Soaked pill and worked pipe with no movement while wait on Pollard e-line and Baker Fishing Rep arrival,at 280K up,60K down.Pollard on location at 13:30 hrs.LD pup joint and change to long bails;to allow XO's and side entry sub on stump. Hung sheaves,MU freepoint tool and RIH to 85'to wait on Baker.Baker Rep on location at 18:00 hrs and joined pre-tour meeting with crew coming on tour.;RIH with E-line free point tool and attempt to locate free point.Tool not working properly and getting faulty readings. POOH with free point tool.;M/U new free point tool&RIH.Take free point measurements inside casing&open hole. Continued to have good tool movement down to 9,535'.;Casing appears to be stuck below that depth around 4 1/2"shoe track. Discussing plan forward to make cut @ 9,455'POOH with free point tools and L/D.;0 bbls solids to KGF G&l.Cum:1,862 bbls 0 bbls Class II junk fluid to KGF G&I.Cum:4,753 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/6/2017 Pollard set up gamma tool and chem cutter assembly.;Held PJSM with Pollard and rig crews,MU packoff and pump in sub and started in hole.Obtained parameters at 9475',correlated depth with RA marker marker at 9392',set ccl at 9436',anchor at 9447';and chem cutter at 9455'.Set casing string in tension 65K over neutral weight and cut 4%"casing.E-line unit had good indication of tool firing but we saw no change on weight indicator.Slacked off;tool and saw collar at 9434'and cut at 9455',but no longer detecting collar at 9475'.Pulled back into string with no issue seeing cut,collar at 9434'and RA marker at 9392'. SO with same results,;appears shoe track assembly(5%joints-230)slid toward bottom of wellbore.Notified Drilling Engineer.Bottom of 4 1/2"casing string now at 9455'md,open ended.;POOH with e-line.Tool assembly became hung up at 1080',got free then hung up at 1000'.Appears anchor grabbing.Rolled rig pump at idle down casing and got returns no problem,pump psi allowed;anchor to close enough to come free and pull to surface.RD Pollard packoff and pump in sub.Have slight flow up casing string.;PU and MU 20'pup joint and topdrive.Circulate at 219 gpm-1171 psi ICP increasing to 219 gpm-535 psi FCP. Circulated Black Magic pill out of hole,overboarded 140 bbls diesel contaminated mud;while Pollard changed anchor arms on freepoint tool.Had a max of 901 units gas at bottoms up.Cont to work pipe at 280-300K up wt,60-80K down with no movement while circ.Dwn pump at 9 units BGG.;Break off topdrive and pup joint,blew down topdrive and monitored well for flow while Pollard prepped freepoint tool for re-run.Peak vac truck made contact with garage door at G&I after offload.;Notified HSE Rep Matt Hogge via telephone about vac truck incident.Updated AOGCC Rep Jim Regg of freepoint/casing cut operations via e-mail (bi-weekly BOP test due 3-4-17).;MU freepoint tool on rig floor and started in casing string.Tool would not go down due to lack of weight and bow spring centralizers.Removed tool and added weight bar,re-insert in string and start;down hole.Tool hanging up on casing connections,POOH and relieve tension on bowspring centralizers.Re-insert tool and RIH.;Attempt to locate free point.Data inconsistent&not reliable.Consult with engineer&discuss plan forward. Decision made to POOH for casing cutter.POOH&L/D free point tools;M/U chemical cutter&gamma tool.RIH&locate RA joint C @ 7,988'.Pulled up hole& spaced out cutter in middle of joint#56©7,262'.;Pulled drill string in tension to 170K&fired guns.String jumped&weight dropped to 50K for a net string weight loss of 60K.Successful cut @ 7,262'.POOH with e-line tools.Chemical cutter hanging;Chemical cutter anchors hanging up inside casing on collars. Having to cycle pumps to aid in pulling E-line out of the hole. Fish#1 @ 7,262'to 9,455'&Fish#2 @ 10,290'to 10,560';15 bbls solids to KGF G&I.Cum: 1,877 bbls 140 bbls Class II junk fluid to KGF G&I.Cum:4,958 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls • • 3/7/2017 Cont pulling chem cutter/gamma tool out of hole.Having to pump down casing string to relieve e-line tool anchors.At 457'e-line tool hung up(joint#12),while trying free up cable pulled from rope;socket(release set at 1974 ft/lbs).Cont POOH with e-line,RD released Pollard.Notified Drilling Engineer.;Held PJSM with Weatherford,rig crew and Pollard Rep.Pull up hole slow with 4 1/2"casing,up wt 68K,from 7262'to 6646'(15 joints).Started looking for e-line tool at joint #11.At joint 15 still;no sign of tool.We are now inside 7 5/8"casing(shoe at 6801'),notified Drilling Engineer that tool most likely slid down hole.;Stabbed TIW and XO.Monitored well on trip tank.Changed over to short bails and smaller elevators.;Cont to POOH LD 4 1/2"casing from 6646'to 4908'.Pulling slow due to swell packer in string,to reduce chance of swabbing and finding e-line tool.Still no sign of tool.Held BOP drill at 4908';Removed TIW,MU topdrive,pumped dry job,blew down topdrive.,Cont POOH LD 4 1/2"casing from 4908'to surface,checking every joint for e-line tool.Did not find the tool. Recovered a total of 174.5 joints 4 1/2"casing,swell packer and 19 turbolizers.Cutoff;joint length=19'.RD Weatherford casing equipment.Calculated hole fill=31.4 bbls,actual hole fill=35.16 bbls.Discussed BOP test time with AOGCC Rep Brian Bixby(06:00 on 3-8-17 to accommodate;new hire inspector coming from Anchorage). Notified Pollard Slickline of need to retrieve chem cutter/gamma tool.Decision made to attempt that after BOP testing due to time involved.;Monitor well on trip tank while cleaning rig floor,BOP stack and cellar area.Load piperacks with 4 1/2"DP and strap same.Pick up and rack back 24 stands of 4.5"CDS40 DP. Wellbore static.;Continue to strap,rabbit,pick up and stand back 26 more stands of 4.5" CDS40 DP.Wellbore static.Total stands in derrick=50.;Drain stack. Clean out cellar of residual fluids Pick uo test ioint.test plus.Set Plua.Fill stack and lines with water for shell test.Test to 3000 Psi AOGCC inspectors on , location.Begin test.;7 bbls solids to KGF G&I.Cum:1,884 bbls 73 bbls Class II junk fluid to KGF G&I.Cum:5,031 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls ems' 3/8/2017 AOGCC Reps Brian Bixby and Lou Laubenstein on location at 06:00 hrs.Flooded stack and surface lines,worked valves to remove air.Tested BOPE at 250/3500 psi(250/2500 on annular);at 5 min low,10 min high. Had one fail/pass on lower pipe rams due to bleeding off. Function ram.Re-tested OK.Total Safety on loc at 09:00 and tested all gas detection equipment.;Blew down surface lines,RD test equipment,pulled test plug and installed wear ring.Re-aligned all valves etc for well control. Pollard slickline on loc at 14:00 hrs.Spotted unit and hung sheave.;MU weight bar,jars and 3.70"LIB.RIH and tagged up solid at 7290'SLM.POOH and had good indication we set down on 6 1/4"turbolizer.MU 4.5"LIB and re-ran,setting down again at 7290'SLM.;POOH and still seeing indication of turbolizer.Called out for a selection of magnets,placed LIB photo's in"0"drive.MU 4.5"magnet and RIH,set down at 7290'SLM,POOH slow with no turbolizer.;Monitoring well on trip tank with no gain or loss.Baker Fishing Rep also on Iocation.;Re-ran 4.5"magnet and set down at 1870'.POOH slow thinking maybe we had lost fish previous trip.Nothing on magnet.Re-ran magnet 3rd time and set down at 7290'SLM.POOH slow. No centralizer.;Made up 3.5"concave magnet,1.75"5 foot weight bar to 4 arm globe centralizer.POOH no turbolizer.One ounce of scale.Pollard Manager arrived with single arm wireline grabber.3.7'long. RIH.;Trip in with single arm wireline grabber 3.7'long to rope socket. Tag up on depth.7290'.Work tool.Drop in 15'deeper. Stabilizer appeared to move downhole.POOH from 7305.;POOH to surface with sngl arm wire line grabber.Install 3.7"LIB.RIH.Tag up @ 7307'.Drop down twice.POOH.No identifiable markings seen at surface.Monitor the well on trip tank.No loss.;lnstall 4.5"LIB.Tag up @ 7305'. POOH.5 distinct markings of the turbolizer blades.Pictures placed on 0 drive in well folder.Appears the blade was hung up in open hole and is now on the liner top.;lnstall 3.5"concave magnet. RIH.tagged up @ 7305'MD.POOH slow.Wellbore remains static.No fish.;Install single arm wireline grabber,to attempt to flip turbolizer and align with stump,to allow overshot to be used to pull liner. RIH to 7305'MD.Work tool.Did not move.POOH for 4.5"magnet.;RIH with 4.5"magnet. Hang up @ 1640'MD, POOH to check tools.;0 bbls solids to KGF G&I.Cum:1,884 bbls 0 bbls Class II junk fluid to KGF G&I.Cum:5,031 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/9/2017 POOH slow on slickline after setting down 4.5"magnet at 1640'.Nothing on the magnet. RIH and tag at 7305'SLM. POOH and again nothing on the magnet. RD and release Pollard slickline.;PU Baker 2.5"x 4.75"tapered tap at 3'long,XO,bumper sub,jars,XO, HWDP x 6 jnts,XO,intensifier,XO.Total length 225'.;PU single in hole with CDS-40 4 1/2"DP from 225'to 3338'.;Service rig and topdrive,checked brake bands on drawworks,serviced iron roughneck.;Cont to PU and single in with 4 1/2"DP from 3338'to 4276'.;Cont TIH 4 1/2"DP from derrick,from 4276'to 6755'.;MU topdrive and do one full circ at 326 gpm- 1453 psi.Had a max of 1490 units gas at bottoms up which had dropped to 25 units at shut down.Re-adjusted topdrive torque while circ.Blew down topdrive.;Cont trip in open hole exiting casing shoe at 6801'.TIH to 7251'.CBU 315 GPM,1490 PSI,20 RPM,TQ 9500,Max gas 1157 units.;Wash down to top of fish.7255'Pressure up to 3100,no loss in flow.On fish. 128K up,78k dn,90k rot.Work string a few inches deeper each time.Make 1 foot of progress. Begin rotation 10 rpm.;Engage fish.Set 60k dn.TQ spiked to 12k stop rotation.Work up to 140k and allow jars to meter and fire.Repeat with 150k up Fire jars. Prepare to stand back a stand and pick up working joint.;Stand back stand#114,P/U 31.68'joint.Set down to 48k,pull up to 160k.Taper tap slipped out of fish.Drop back in with 20k dn,re-engage fish.Torque up to 13k.Stop rotation.375 GPM,1840 PSI.;Pick up to 150k,taper tap slipped out.Decide to POOH for 1)Overshot if we have the centralizer on the taper tap,or 2)Spear if we do not have the lost centralizer.Progress was made.;Pump out of the open hole back into the casing @ 6801.Circulate another gas slug from around the fish that was coming up.Max gas 1195 units.;Circulate another gas slug from around the fish that was coming up.Max gas 1195 units.;Monitor well.Static.Pump dry job. Blow down top drive.;Pull out of the hole on elevators,monitor on continuous trip tank.Calculated fill=48 bbls,Actual fill=58 bbls.;Lay down accelerator jars,stand back 3 stands HWDP.Lay down tapered tap,no centralizer,scarring on the threads.BHA#6.;Pick up spear.Rerun bumper sub,hydraulic jar and accelerator.BHA#7;3 bbls solids to KGF G&I.Cum:1,887 bbls 27 bbls Class II junk fluid to KGF G&I.Cum:5,058 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls • 3/10/2017 TIH on 4%"DP and spear assembly to 6752'.BHA length=222'.;MU topdrive,filled pipe and CBU 1 time at 327 gpm-1625 psi.Had a max of 568 units at bottoms up. Up wt 112K,down wt 72K.;Cont TIH exiting Intermediate shoe at 6801',down through open hole to 7258'and tagged up.Pulled up hole at 127K.;MU topdrive and broke circ at pump idle(47 spm),430 psi.S/O and re-tag fish,pressure increased to 1722 psi,then broke over and dropped slowly to 400 psi.Set down to 50K on fish,then PU to 140K,;SO and PU to 150K,SO and PU to 160K.Allowed jars to fire and as we pulled up the spear pulled free. Repeated steps with same results.SO to 30K setting down fairly hard twice.PU to 150K and fired;jars,then pulled to 160K.S/O to 50K,pulled to 160 then 180K firing jars.Spear held.Started SO and increase up in 10K increments firing jars.Still have pump at idle and good returns.Near bottoms;up and seeing 1147 units gas. Ran into up weight fairly quick and fired jars at 300K.String weight dropped to 170K and we cont pulling up hole.Appears casing string came free.Cont pulling 1st;full stand and racked back.Up wt 170K. Pulling good.Have 43K additional string weight from prior to engaging fish.;Cont pulling up hole from 7200'BHA depth to 4609',putting 2193'of 4 1/2"casing inside Intermediate casing shoe.Hole fill looking good and no issues at all pulling up hole.;At 4609'(BHA depth)MU topdrive and circulated surf to surf at 303 gpm-1240 psi.Initial bottoms up we had 1543 units gas which dropped off,and second bottoms up had 1319 units.With gas down;to 20 units did flow check,no flow.Pumped 20 bbl dry job and blew down topdrive.;Cont POOH from 4609'to 3180'(BHA depth).At this point,hole fill was 3.15 bbls over calculated.;Cont POOH from 3180'to BHA at 253'.Good hole fill.;Lay down accelerator jars.Rack back 3 stands 4.5"CDS 40 HWDP.;Make up 5'CDS 40 pup to top of fishing assembly.Pick up to fish. Fish fully engaged with spear inside to shoulder. (Pictures on 0 drive). Lay down XO/Hyd.Jar/Drilling bumper sub.:Install 3.5"IF lift sub in spear,pick up set slips,install collar clamp on cut joint.;Rig up Weatherford casing equipment.Lay down cut joint with spear,22.75'. Install casing elevators. PJSM on laying down casing.;Lay down 31 joints of 4.5"DWC/C 12.6#casing!1 cut joint /1 RA joint/18 turbolators. Dope all pin ends before placing thread protectors on.All joints were good.;Lay down 18 joints of 4.5" DWC/C 12.6#casing!1 cut joint 17.35' /2 RA joints/12 turbolators. Dope all pin ends before placing thread protectors on.All joints were good.;3 RA joints verified to have marker in box end with Sperry hand held meter.Rig down Weatherford casing equipment.;Service rig.Inspect derrick,drilling line after jarring operations.Inspect blocks,top drive,brake linkage,crown,all pins and keepers,all fluid levels in motors.;Make up BHA#8 Fishing assembly.Overshot,bumper sub,Hyd jars,6 HWDP,Accelerators,pump out sub,224.79'.;Single in 40 joints of drill pipe to 1485'MD.;0 bbls solids to KGF G&I.Cum:1,887 bbls 5 bbls Class II junk fluid to KGF G&I.Cum:5,063 bbls iL 0 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 0 bbls.Cum:631 bbls (.5 3/11/2017 Cont to PU and single in hole on 4 1/2"DP from 1464'to 3212'.BHA consists of a 6.38"OD overshot.:Corft TIH from derrick from 3212'to 5200'and pipe running over.;MU topdrive and CBU at 302 gpm-657 psi.Had a max of 1181 units gas at bottoms up.Flow check is static.;Cont TIH from 5200'to 6758',just above Intermediate casing shoe.;MU topdrive and 337 gpm-1025 psi.Had a max of 1639 units at bottoms up and flow show increased from 32%to 46%. Slowed pump to 139 gpm-311 psi and cont to circ out gas below 100 units.No flow.;Cont TIH from 6758'to 7823'(open hole),up wt 120K,dwn wt 78K. No issues.;MU topdrive and CBU at 235 gpm-635 psi,20 rpm-10,000 ft/lbs off bott torque. Had a max of 927 units at bottoms up. Flow check is static.;Cont TIH from 7823'to 9733'. Up wt 148K,dwn wt 85K.;MU topdrive and circ at 228 gpm-789 psi.20 rpm-11,900 ft/lbs off bott torque.Had a max of 1047 units followed by 778 units gas.Circ until gas down to 300 units and dropping.;Wash and slow ream from 9733 to 10307'MD.230 GPM,20 RPM,820 PSI,12.5k Torque, Up Wt=195k,Dn Wt=98k, Rot Wt=135k.SPR#1 MP 48 spm=469 psi.;Circulate and condition on bottom.Reciprocate,no rotation as per Baker hand. Pump Hi-Vis sweep surface to surface.Minimal cuttings increase.Establish parameters;Rotate 10 RPM,280 GPM,184k up,96k down,122k rotation. Wash/ream down to fish.Saw increase in pump pressure©10330.Top of fish @ 10327.26'.Pressure up to 1600 psi.Pick up and see no overpull.;Lay down working single,pick up full stand.;280 GPM, 10 RPM,1100 PP,Work down to Re-engage fish.More working room down with the full stand.Set down to 70k,pp 3000 psi.Shut down pump. Pick up to 240k jars fired and fish came free.;Move fish up hole with a 220k break over weight,and 205k free travel,no pump.With shoe track 8 feet off bottom begin circulation.Good circulation.Sat still for one minute and were differentially;stuck above the jars.Work pipe up and down,max up weight 300k.Came free with 70k downward movement. Send derrick man to board,prepare to keep coming out.Fish weighs 2200 lbs.Up weight=202k;Driller saw some increase in up weight.Begin to pump out of hole.Full rates.No rotation.300 GPM,900 PSI.Pump out from 10330'MD to 7060' MD at report time.;0 bbls solids to KGF G&I.Cum:1,887 bbls 0 bbls Class II junk fluid to KGF G&I.Cum:5,063 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/12/2017 Cont to pump out of hole from 6800'to 6500',just inside Intermediate casing shoe.Pumped at 300 gpm-860 psi.;Circ and condition mud from 11.2 back to 11.0 ppg.at 297 gpm-763 psi, BGG 12 units. Flow check was static.Pumped dry job and blew down topdrive.;Cont to POOH racking back in derrick from 6500'to overshot and had no fish.Notified Drilling Engineer,discussed options,decision made to TIH with modified taper tap.Over shot had external;scarring and sign of metal to metal contact on outer edge of mill guide teeth(pics in"0"drive).Monitor well on trip tank,no losses,no gain.;Expediter and Baker Rep ran taper tap to Knight Oil Tool,and had 18"of cut right carbide affixed to lower stem. Rig crew serviced rig and topdrive,cleaned floor and prepped for cut and slip.;Prepare to slip and cut drilling line.Finish housekeeping tasks, Lay down fishing tools from rig floor.;Slip and cut drilling line. Pick up working single,hang off blocks,remove weight indicators,Slip and cut 76'of line.adjust kick back rollers,un-hang blocks,lay down single.Check crown saver.;Pick up taper tap, XO,bumper sub,jars,XO,6 HWDP,XO,accelerators,pump out sub,XO to DP. 226'.;Trip in hole out of the derrick.Monitor displacement on trip tank.TIH to 5514'MD.Good displacement.;Trip in hole out of the derrick from 5514 to 6756'.Good displacement.;Circulate at shoe.290 GPM, 1200 PSI,Max gas 1174. MW in/out 11 ppg.129k up weight,82k down weight.;Trip in hole from 6756'to 8627'.Good displacement.;Circulate bottoms up @ 8627'.290 GPM,1350 PSI,188k up weight,96k down weight,122k rotate weight 15 RPM,Max gas=1451. Blow down TD.;Trip in hole from 8627'to 10327'.Top of fish.Good displacement.;Establish parameters.Locate top of fish.CBU before fishing. 290 GPM,1600 PSI, 15 RPM.;4 bbls solids to KGF G&I.Cum:1,891 bbls 36 bbls Class II junk fluid to KGF G&I.Cum:5,099 bbls 0 bbls cement to KGF G&I.Cum:117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 0 • 3/13/2017 Circulated above fish at 290 gpm-1432 psi, 15 rpm-13,400 fUlbs off bott torque,up wt 220K,dwn wt 140K while pump and rotate.SO and tag at 10,329'. PU and increase rotary to 25 rpm-14,000 fUlbs.;SO to 10,333'with slight psi increase,PU to 10,324'and stop rotary.SO to 10,337'and set down 40K on fish. PU to 10,332'and rotate string.SO to 10,338'and pump pressure climbing quick to 2470;Work string from 10,338'up to 10,337 back and forth.Stop rotation and SO to 10,342',pump pressure climbing to 3000 psi.Down pump and rotate while SO to 10,339',topdrive stalled at 16,000 ft/lbs.;Pull up hole to 320K and fired jars.Immediately lost string weight.Pump on and SO until psi climbing.SO to 10,342'then pull up to 240K.Pump psi up and down at 2700 psi then slowly dropping off.;SO to 110K on fish pump psi climbing fast,SO to 90K pump pressure at 2600.PU seeing drag and pump psi at 2240.So to 90K.Pull up hole to 10,312'and stop.Pump psi up and down then dropped to 1365.;SO to 10,347'rotating and down pump,then no rotary.PU to 240K then 250K and pump. Pressure coming up fast at 10,324'.Jars fired or pump psi blew fish off tapered tap.Pump psi dropped fast.;SO and re-engage at 10,347'while rotating and pumping.Down pump and topdrive stalled at 16,000 ft/lbs.PU to 240K then 250K.Start pump at idle and pressure increased quick over 537(killrate psi);Down pump as we have indication fish on tapered tap.By this time we have a full stand pulled.Racked back stand and cont pulling up hole.Had to pull 2nd stand to 300K but it broke over gently.;Cont pulling up hole slow and gentle from 10,267'(BHA depth)to tapered tap.Initially seeing drag from 240K to 260K but the more we pulled the smoother hole conditions got.Pulled into Intermediate:shoe at 6801'and blew down topdrive.Had back flow up DP pretty much the entire trip.Indicating we did not have fish(float shoe and float collar).With tapered tap to surface we have the fish.;Broke off cutoff joint and LD tapered tap.LD 2 full joints and found a-line tool stabbed through float collar.LD FC joint and had Pollard remove their tool.LD shoe joint,nose of float shoe missing;Lay down shoe track fish with lost E-line tool stuck inside.(pictures on the 0 drive). Break down all fishing tools and cross overs.Lay down and band all Baker tools to pallets for shipping.;Clean and clear rig floor.Gather up and place all Turbolizers in wooden crate for shipment.Swap out casing elevators for drill pipe elevators.;Pick up mule shoe,make up to HWDP stand.Run 3 stands of HWDP,and trip to 5600'.;TIH from 5600'to 6791'. Began screwing into TD to stop U-tube on std 87, std 90 could not back out of saver sub.Change out saver sub.;Circulate gas out from shoe.Max gas 1357.310 GPM,50 RPM,9800 TQ,Flow check.Well static.Pump dry job.;POOH laying down singles.From 6791'to 3898'MD.;0 bbls solids to KGF G&I.Cum:1,891 bbls 0 bbls Class II junk fluid to KGF G&I.Cum:5,099 bbls 0 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/14/2017 POOH laying down singles.From 3898'to 189'.;RIH with excess pipe in the derrick from 189'to 3726'.;Circulate annular volume at 550 gpm 1040 psi. Max gas 470 units.;POOH laying down drill pipe from 3726'to surface.;Pull wear ring. Rig up Weatherford casing equipment. Break off DWC/C x CDS 40 XO off ,s—pup joint. Rig up fill up line. Stage centralizers on rig flgor.:Finish riaaina uo to run casing.Pick up pup joint'A'and break out XO,Lay down joint'A',Count t and verify pipe tally numbers and joints on location(250 in stack,3 RA jts.,2 pups,11 strapped,;Prejob meeting.Casing crew,rig crew,Tool Pusher, CoMan.;Baker lock to pin end of joint#4.Check floats.Run casing,placing a centralizer on every joint.Midnight @ joint#73,3149'.6000 ft/lbs torque (,V s•� average.;Run 4.5"DWC/C 12.6#L80 casing from joint#73 to#77 with a centralizer each one,then every other one to joint#95,One swell packer after joint `\_ , #100.(OD=6.5"). TIH to joint#160.At shoe.6779;Circulate bottoms up at the shoe.Prepare the remaining 90 joints for the open hole run.Max gas=1706. `� l v GPM 295,550 PSI,MW 11.05 PPG. The gas came up 1500 strokes early and elevated until BU.;Run 4.5"DWC/C 12.6#L80 casing from joint#160 to joint# v` 185.6000 ft/lbs of torque.7818'MD.:4 bbls solids to KGF G&I.Cum:1,895 bbls 86 bbls Class II junk fluid to KGF G&I.Cum:5,185 bbls 0 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/15/2017 Continue to RIH with 4.5"DWC/C casing from 7818'to 10.548'. Observe slight differential from 8472'to bottom with consistent 10-20K slack off to break over, up to 30K at 9046',9900',and 9935'.;While landing observe hanger hang up in blind rams and LPR;hook up tugger and pull landing joint over to center over well.;Rig up circulation head. Circulate up to 7 bpm 1034 psi. Rig down casing equipment and rig up cementing equipment.;SLB pressure tested lines at 1500 low 4000 high,good tests.Rig pumped 15.3 bbls 12.5 ppg MudPush II at 5 bpm,602 psi,and shut down.SLB dropped bottom plug and pumped 160 bbls (675 sx)15.3 pp9;Class G cement at 4.4 bpm, 170 psi_SLB dropped top plug,then displaced with 10 bbls 8.34 ppg water at 6 bpm,157 psi,followed by 150 bbls 6%KCL at 6 bpm.Slowed to 3 bpm with with 20 bbl to go;FCP 3000 psi. Did not bump the plug held FCP for 5 minutes,bled off and floats held.Bled back 1.25 bbls to truck.Cemnet was added at 1 ppb.Mix water temp at 78 deg.Pumped 50%open hole excess.;Unable to reciprocate the string due to the hanger catching in pipe rams.Had full returns during job. Up wt 125K,dwn wt 72K at time of landing hanger.CIP at 14:45 hrs,3-15-17.;Rig down SLB cement equipment.Blow down all equipment. Back haul unused dry cement.;Back out landing joint,suck out BOP stack. Set casing pack off with wellhead .,, specialist.;Rig down casing bails and elevators. Clean and clear rig floor. Start hauling off excess mud and cleaning pits. Prep to N/D BOP while waiting on „tI.� cement.;WOG 12 hours.CIP @ 14:45.Clean rig floor.Inventory and send down all subs on rig floor,place in proper sub racks.TIW/Dart/Tong heads. Remove 0l and clean flow box.Clean pits,BOPE,Cellar area,:Tear down mud pumps for inspection,clean suction screens,discharge screens,bear traps,using Peak VAC truck suck out all fluids from pumps and traps.Rig down 3rd party work shacks,MWD/MudM./MLog.;Rig down suction lines,bleed off lines,Rig down power cords,install BOPE trolley beam,rig up remote winch rig down vibrator line rig down steam lines to up right water tank.;Rig up test pump hoses,chart recorder.Pressure test production 4.5"casing bore.3500 psi for 30 mins.Charted.Close blinds,fluid pack to above blinds,pump in kill line with test pump.;Volume pumped 1.9 bbls.Volume returned 1.9 bbls.Test retained 99%of pressure. Lost 30 psi in 30 mins.Chart scanned and in the rig folder.Rig down.Bring T bar to rig floor.;Set BPV.Begin nipple down of BOPE.:74 bbls solids to KGF G&I.Cum:1,969 bbls 701 bbls Class II junk fluid to KGF G&I.Cum:5,886 bbls 0 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/16/2017 Continue to N/D BOP and spacer spool. Clean cellar area. Haul off mud and clean pits.;N/U dry hole tree. Sim Op:Move service shacks. Continue cleaning pits. Prep to remove top drive.;Pack off neck seals and test to 5000 psi for five minutes-good. Test void 500 psi/5 minutes,5000 psi for 15 minutes-good. Pull BPV,install TWC. Test tree to 5000 psi-good.;Freeze protect well with 30'of diesel. Rig Released 14:00-KBU 14-05 next well.;42 bbls solids to KGF G&I.Cum:2011 bbls 498 bbls Class II junk fluid to KGF G&I.Cum:6384 bbls 0 bbls cement to KGF G&I.Cum: 117 bbls Daily losses downhole 0 bbls.Cum:631 bbls 3/17/2017 • • Hilcorp Energy Company Composite Report Well Name: KEU KBU 32-06 Field: Kenai Gas Field County/State: Kenai,Alaska (LAT/LONG): svation(RKB): API#: 50-133-20658-00-00 Spud Date: Job Name: 1613181C KBU 32-06 Completion Contractor c j3L AFE#: AFE$: . ........................................... 3/22/2017 PTW,JSA.Mobe to location.Sport equipment. Rig up Eline lubricator, PT to 250 low and 3000 psi high.,RIH w/HLD CBL too 1'0408'to and log from 10,408' to 5500'It was at different levels.,Riq down lubricator and turn well over to field.,Rig down lubricator and turn well back over to field 3/30/2017 Fire equipment. Hold safety meeting. Discuss job procedure and review SLB JSA.,Spot equipment. Rig up SLB CTU 13 wtih 1.75"CT.,24 hr BOPE test witness notification sent 3/29/17@ 13:29. Witness waived on 3/29/17 @ 15:13 via Mike Quick. Start BOPE test. Draw down test. Test all rams and valves to 250/4000 psi. BOPE test passed.,Rig up pressure transducer and field triplex pump to MIT 7 5/8 x 4 1/2"IA.,Pressure up to 2765 psi. watch pressure until + flat line. Start 30 minute test 2562 psi. End at 2555 psi after 30 minutes. Send graph to town.,Rig up N2 IA ironto pump in subs for reverse N2 lift. Location rsecure. Crews will be back at 0600 hrs. 3/31/2017 Obtain PTW. Hold safety meeting. discuss job procedure and review JSA.,Fire equipment. Make up B A as follows. 1.75"OD CC,1.75"OD stinger x2, 2.125"OD ball drop nozzle with.75"hole in tip. Total BHA length 9.3',Stab on well. PT stack 250/4000 psi. Open swab. RIH Fire N2 unit and start cooling down. Online N2 down backside at 500 scf/min @ 2600' Tagged 10,445' Increase N2 rate to 1000 scf/min WHP/pump pressure 3100 psi. 160 bbls returned. Start POOH to surface. Control well let bleed down from 3100 to 850 psi.,POOH to surface. Taggged up. Close swab. SITP 936 psi.,Rig down CTU 13. 160 bbls returned 2061 gallons of n2 pumped. 4/3/2017 PTW,JSA.Mobe to location.Sport equipment. Rig up Eline lubricator, PT to 250 low and 3500 psi high.,RIH with Press/Temp tool and tie into Halliburton i LWD log.Tagged cement at 10,441'and fluid level at 10,402'.POOH,RIH w/2-7/8"x23'HC,6 SPF,60 deg phase and tie into Halliburton LWD log.Run correlation log and send to town.Get ok tq perf from 10,369'to 10,392'.Fired gun with 573 psi on tubing.After 5 min pressure was 574 psi and stayed that way til out of hole.Gun was dry..,Rig down lubricator and turn over to field.They will try and flow well but don't go below 275 psi while monitoring LEL.If it won't sustain then shut in overnight and plan on running PT survey in morning. 4/4/2017 PTW,JSA.Mobe to location. Rig up Eline lubricator,PT to 250 low and 3500 psi high.,RIH with Press/Temp tool and tie into Halliburton LWD log.Tagged cement at 10,441'and fluid level at 10,354'(BHP right above FL is 430 psi)Surface pressure is 250 psi.POOH,RIH w/2-7/8"x14'Razor HC,6 spf.60 deg phase and tie into Halliburton LWD log.Run correlation log and send to town.Get ok to perf from 10,333'to 10,347;Spotted and fired shot after pressuring up tubing from 250 psi to 595 psi.After 5 min tubing pressure was 596 psi.POOH.All shots fired.Re-headed cable head while pressureing up tubing to 595 psi. before we fired shots.TP-599 psi after we got out of hole,RIH w/2-7/8"x15 Razor HC,6 spf.60 deg phase and tie into Halliburton LWD log. Run correlation log and send to town.Get ok to perf from 10,312'to 10,327 with 609.2 psi.Fired gun and after 5 min pressure was 612 psi POOH.All shots fired and well has 660 psi on tubing out of hole.,Rig down lubricator and turn well over to production. 4/14/2017 PTW,JSA.Mobe to location. Rig up Eline lubricator,Change out wellhead flange from Bowen to Otis.PT to 250 low and 3500 psi high.. Gas 648 mcfd Water—5.3 bpd??? Tubing Pressure=281 psi,RIH with SLB PLT and tie into Halliburton LWD log.Made 30 fpm,60 fpm and 90 fpm logs from 10,300'to 10,420'.Fluid level approx.10,347.Made 5 min stages at 10,424', 10,367',10,331'and 10,305'..POOH with good data.,Rig down SLB lubricator and turn well back over to field. • • Hilcorp Alaska, LLC Kenai Gas Field KGF 14-6 Pad KBU 32-06 501332065800 Sperry Drilling Definitive Survey Report 02 March, 2017 HALLIBURTON mm Sperry Drilling • i Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well KBU 32-06 Project: Kenai Gas Field TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) • Site: KGF 14-6 Pad MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Well: KBU 32-06 North Reference: True r Wellbore: KBU 32-06 Survey Calculation Method: Minimum Curvature ' Design: KBU 32-06 Database: Sperry EDM-NORTH US+CANADA Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) 4 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 KBU 32-06 Well Position +NI-S 0.00 usft Northing: 2,362,578.00 usft • Latitude: 60°27'39.310 N +E/-W 0.00 usft Easting: 272,168.44 usft . Longitude: 151°15'44.021 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 64.69 usft Wellbore KBU 32-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength .. : > .. 4" , . (°) (°) (nT) BGGM2016 1/31/2017 16.01 73.46 55,356 Design KBU 32-06 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.03 39.79 Survey Program Date 3/2/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 109.17 1,469.66 MWD+SC+sag(1)(KBU 32-06) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 01/30/2017 1,513.71 6,769.43 MWD+SC+sag(2)(KBU 32-06) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 02/06/2017 6,860.04 10,522.33 MWD+SC+sag(3)(KBU 32-06) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 02/20/2017 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 18.00 0.00 0.00 18.00 -64.69 0.00 0.00 2,362,578.00 272,168.44 0.00 0.00 UNDEFINED 109.17 0.07 95.44 109.17 26.48 -0.01 0.06 2,362,577.99 272,168.50 0.08 0.03 MWD+SC+sag(1) 201.64 0.13 190.89 201.64 118.95 -0.11 0.09 2,362,577.88 272,168.53 0.17 -0.03 MWD+SC+sag(1) 260.10 0.10 259.00 260.10 177.41 -0.19 0.03 2,362,577.81 272,168.47 0.22 -0.13 MWD+SC+sag(1) 325.36 0.13 32.76 325.36 242.67 -0.14 0.01 2,362,577.86 272,168.45 0.32 -0.10 MWD+SC+sag(1) 386.59 0.03 15.66 386.59 303.90 -0.06 0.06 2,362,577.94 272,168.49 0.17 -0.01 MWD+SC+sag(1) 448.82 0.09 186.06 448.82 366.13 -0.10 0.05 2,362,577.90 272,168.49 0.19 -0.04 MWD+SC+sag(1) 509.77 0.81 35.94 509.77 427.08 0.21 0.30 2,362,578.20 272,168.75 1.46 0.35 MWD+SC+sag(1) 571.20 1.48 28.32 571.19 488.50 1.25 0.93 2,362,579.24 272,169.40 1.12 1.56 MWD+SC+sag(1) 632.45 2.55 30.79 632.40 549.71 3.12 2.01 2,362,581.08 272,170.51 1.75 3.68 MWD+SC+sag(1) 693.76 3.99 26.98 693.61 610.92 6.19 3.67 2,362,584.12 272,172.23 2.37 7.11 MWD+SC+sag(1) 756.05 5.66 31.88 755.67 672.98 10.73 6.28 2,362,588.61 272,174.92 2.76 12.27 MWD+SC+sag(1) 3/2/2017 4:38:43PM Page 2 COMPASS 5000.1 Build 81 • • 1Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well KBU 32-06 Project: Kenai Gas Field TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Well: KBU 32-06 North Reference: True Wellbore: KBU 32-06 Survey Calculation Method: Minimum Curvature Design: KBU 32-06 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 818.92 7.75 31.77 818.11 735.42 16.97 10.15 2,362,594.77 272,178.91 3.32 19.54 MWD+SC+sag(1) 880.36 11.11 32.00 878.71 796.02 25.52 15.47 2,362,603.21 272,184.39 5.47 29.50 MWD+SC+sag(1) 942.50 12.38 37.66 939.55 856.86 35.87 22.71 2,362,613.42 272,191.83 2.76 42.09 MWD+SC+sag(1) 1,004.11 15.00 39.33 999.40 916.71 47.27 31.80 2,362,624.64 272,201.14 4.30 56.67 MWD+SC+sag(1) 1,065.87 16.51 37.42 1,058.84 976.15 60.42 42.20 2,362,637.60 272,211.79 2.58 73.43 MWD+SC+sag(1) 1,128.59 18.97 36.02 1,118.58 1,035.89 75.74 53.61 2,362,652.70 272,223.49 3.98 92.51 MWD+SC+sag(1) 1,191.38 20.69 36.51 1,177.64 1,094,95 92.91 66.21 2,362,669.62 272,236.42 2.75 113.77 MWD+SC+sag(1) 1,252.88 25.11 37.24 1,234.28 1,151.59 112.04 80.58 2,362,688.47 272,251.15 7.20 137.66 MWD+SC+sag(1) 1,315.01 25.43 37.99 1,290.46 1,207.77 133.05 96.77 2,362,709.17 272,267.74 0.73 164.17 MWD+SC+sag(1) 1,377.34 27.66 38.78 1,346.22 1,263.53 154.88 114.07 2,362,730.66 272,285.45 3.62 192.01 MWD+SC+sag(1) 1,440.26 29.88 38.19 1,401.37 1,318.68 178.59 132.91 2,362,754.00 272,304.74 3.56 222.28 MWD+SC+sag(1) 1,469.66 30.64 39.81 1,426.76 1,344.07 190.10 142.23 2,362,765.33 272,314.29 3.79 237.10 MWD+SC+sag(1) 1,513.71 28.43 39.82 1,465.09 1,382.40 206.78 156.14 2,362,781.74 272,328.51 5.02 258.81 MWD+SC+sag(2) 1,574.88 30.74 40.90 1,518.28 1,435.59 229.78 175.70 2,362,804.36 272,348.51 3.88 289.01 MWD+SC+sag(2) 1,636.17 34.87 39.91 1,569.78 1,487.09 255.07 197.21 2,362,829.23 272,370.49 6.79 322.20 MWD+SC+sag(2) 1,698.23 36.73 39.12 1,620.12 1,537.43 283.08 220.30 2,362,856.79 272,394.12 3.09 358.50 MWD+SC+sag(2) 1,759.73 36.67 39.39 1,669.43 1,586.74 311.54 243.56 2,362,884.80 272,417.91 0.28 395.25 MWD+SC+sag(2) 1,822.40 37.37 40.24 1,719.46 1,636.77 340.52 267.72 2,362,913.31 272,442.62 1.38 432.99 MWD+SC+sag(2) 1,884.27 37.35 40.41 1,768.64 1,685.95 369.14 292.01 2,362,941.46 272,467.46 0.17 470.53 MWD+SC+sag(2) 1,946.31 37.10 39.59 1,818.04 1,735.35 397.89 316.14 2,362,969.74 272,492.13 0.90 508.06 MWD+SC+sag(2) 2,008.04 37.48 39.38 1,867.15 1,784.46 426.76 339.92 2,362,998.14 272,516.46 0.65 545.46 MWD+SC+sag(2) 2,070.07 37.25 38.96 1,916.45 1,833.76 455.94 363.70 2,363,026.87 272,540.79 0.55 583.10 MWD+SC+sag(2) 2,132.56 37.34 39.91 1,966.17 1,883.48 485.18 387.75 2,363,055.64 272,565.40 0.93 620.96 MWD+SC+sag(2) 2,194.17 37.38 40.03 2,015.14 1,932.45 513.84 411.76 2,363,083.83 272,589.96 0.13 658.35 MWD+SC+sag(2) 2,257.06 37.41 40.50 2,065.10 1,982.41 542.98 436.45 2,363,112.49 272,615.20 0.46 696.54 MWD+SC+sag(2) 2,320.61 37.26 40.21 2,115.63 2,032.94 572.35 461.41 2,363,141.38 272,640.71 0.36 735.08 MWD+SC+sag(2) 2,380.80 37.18 39.79 2,163.56 2,080.87 600.24 484.81 2,363,168.81 272,664.64 0.44 771.49 MWD+SC+sag(2) 2,444.16 37.38 41.11 2,213.97 2,131.28 629.44 509.71 2,363,197.53 272,690.10 1.30 809.86 MWD+SC+sag(2) 2,505.51 37.50 40.08 2,262.69 2,180.00 657.76 533.97 2,363,225.38 272,714.90 1.04 847.15 MWD+SC+sag(2) 2,567.10 38.37 40.39 2,311.26 2,228.57 686.67 558.43 2,363,253.81 272,739.91 1.45 885.01 MWD+SC+sag(2) 2,629.59 38.90 40.41 2,360.08 2,277.39 716.38 583.72 2,363,283.03 272,765.76 0.85 924.03 MWD+SC+sag(2) 2,691.43 38.12 40.63 2,408.46 2,325.77 745.65 608.74 2,363,311.81 272,791.33 1.28 962.53 MWD+SC+sag(2) 2,753.84 37.54 40.41 2,457.76 2,375.07 774.75 633.61 2,363,340.43 272,816.75 0.95 1,000.80 MWD+SC+sag(2) 2,816.61 36.99 40.60 2,507.71 2,425.02 803.64 658.29 2,363,368.85 272,841.99 0.90 1,038.81 MWD+SC+sag(2) 2,879.62 37.09 39.75 2,558.01 2,475.32 832.64 682.78 2,363,397.37 272,867.02 0.83 1,076.76 MWD+SC+sag(2) 2,940.85 37.01 39.48 2,606.88 2,524.19 861.06 706.30 2,363,425.33 272,891.08 0.30 1,113.65 MWD+SC+sag(2) 3,002.69 37.19 40.53 2,656.20 2,573.51 889.64 730.28 2,363,453.44 272,915.61 1.06 1,150.95 MWD+SC+sag(2) 3,064.63 37.25 39.83 2,705.52 2,622.83 918.26 754.45 2,363,481.59 272,940.32 0.69 1,188.42 MWD+SC+sag(2) 3,126.92 37.71 39.73 2,754.96 2,672.27 947.39 778.70 2,363,510.25 272,965.13 0.74 1,226.32 MWD+SC+sag(2) 3,187.94 37.26 39.67 2,803.38 2,720.69 975.96 802.42 2,363,538.36 272,989.39 0.74 1,263.45 MWD+SC+sag(2) 3/2/2017 4:38:43PM Page 3 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well KBU 32-06 ( Project: Kenai Gas Field TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Well: KBU 32-06 North Reference: True Wellbore: KBU 32-06 Survey Calculation Method: Minimum Curvature Design: KBU 32-06 Database: Sperry EDM-NORTH US+CANADA I 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 3,250.72 36.74 39.87 2,853.51 2,770.82 1,005.00 826.59 2,363,566.93 273,014.11 0.85 1,301.24 MWD+SC+sag(2) 3,312.33 36.96 39.76 2,902.81 2,820.12 1,033.38 850.25 2,363,594.85 273,038.31 0.37 1,338.18 MWD+SC+sag(2) 3,374.73 37.34 39.67 2,952.55 2,869.86 1,062.37 874.33 2,363,623.37 273,062.93 0.62 1,375.87 MWD+SC+sag(2) 3,435.96 37.58 39.70 3,001.15 2,918.46 1,091.03 898.11 2,363,651.57 273,087.26 0.39 1,413.11 MWD+SC+sag(2) 3,498.03 36.73 39.32 3,050.62 2,967.93 1,119.95 921.96 2,363,680.03 273,111.66 1.42 1,450.60 MWD+SC+sag(2) 3,560.57 36.90 39.95 3,100.69 3,018.00 1,148.81 945.87 2,363,708.42 273,136.11 0.66 1,488.07 MWD+SC+sag(2) 3,622.71 36.98 40.07 3,150.36 3,067.67 1,177.41 969.88 2,363,736.56 273,160.67 0.17 1,525.42 MWD+SC+sag(2) 3,684.53 37.46 39.01 3,199.59 3,116.90 1,206.25 993.68 2,363,764.93 273,185.02 1.30 1,562.81 MWD+SC+sag(2) 3,746.19 36.87 38.54 3,248.72 3,166.03 1,235.29 1,017.01 2,363,793.52 273,208.90 1.06 1,600.05 MWD+SC+sag(2) 3,808.65 36.18 39.11 3,298.92 3,216.23 1,264.25 1,040.31 2,363,822.03 273,232.75 1.23 1,637.22 MWD+SC+sag(2) 3,870.46 34.98 39.31 3,349.19 3,266.50 1,292.12 1,063.05 2,363,849.45 273,256.01 1.95 1,673.18 MWD+SC+sag(2) 3,931.79 33.57 39.16 3,399.86 3,317.17 1,318.87 1,084.89 2,363,875.78 273,278.37 2.30 1,707.72 MWD+SC+sag(2) 3,994.17 32.64 38.89 3,452.12 3,369.43 1,345.34 1,106.35 2,363,901.83 273,300.32 1.51 1,741.78 MWD+SC+sag(2) 4,056.89 31.40 38.64 3,505.29 3,422.60 1,371.26 1,127.17 2,363,927.35 273,321.64 1.99 1,775.03 MWD+SC+sag(2) 4,118.52 30.74 38.21 3,558.08 3,475.39 1,396.18 1,146.94 2,363,951.89 273,341.88 1.13 1,806.83 MWD+SC+sag(2) 4,180.45 28.61 38.32 3,611.89 3,529,20 1,420.25 1,165.92 2,363,975.59 273,361.32 3.44 1,837.48 MWD+SC+sag(2) 4,243.11 27.11 38.33 3,667.28 3,584.59 1,443.22 1,184.08 2,363,998.21 273,379.92 2.39 1,866.75 MWD+SC+sag(2) 4,305.53 25.62 38.94 3,723.21 3,640.52 1,464.88 1,201.38 2,364,019.52 273,397.63 2.43 1,894.46 MWD+SC+sag(2) 4,368.22 24.40 39.35 3,780.02 3,697.33 1,485.44 1,218.11 2,364,039.76 273,414.75 1.97 1,920.96 MWD+SC+sag(2) 4,429.89 22.50 40.05 3,836.59 3,753.90 1,504.32 1,233.78 2,364,058.34 .273,430.78 3.11 1,945.50 MWD+SC+sag(2) 4,491.25 21.44 39.62 3,893.50 3,810.81 1,521.95 1,248.49 2,364,075.68 273,445.82 1.75 1,968.46 MWD+SC+sag(2) 4,552.18 20.36 38.61 3,950.42 3,867.73 1,538.81 1,262.21 2,364,092.27 273,459.86 1.87 1,990.19 MWD+SC+sag(2) 4,615.38 18.40 37.04 4,010.03 3,927.34 1,555.36 1,275.08 2,364,108.57 273,473.04 3.21 2,011.15 MWD+SC+sag(2) 4,677.66 18.00 37.91 4,069.20 3,986.51 1,570.80 1,286.91 2,364,123.78 273,485.17 0.78 2,030.59 MWD+SC+sag(2) 4,738.25 17.84 37.73 4,126.85 4,044.16 1,585.53 1,298.34 2,364,138.29 273,496.88 0.28 2,049.22 MWD+SC+sag(2) 4,800.26 17.56 38.63 4,185.92 4,103.23 1,600.35 1,309.99 2,364,152.88 273,508.81 0.63 2,068.06 MWD+SC+sag(2) 4,861.79 17.46 38.32 4,244.60 4,161.91 1,614.84 1,321.51 2,364,167.15 273,520.61 0.22 2,086.57 MWD+SC+sag(2) 4,923.90 17.35 38.78 4,303.87 4,221.18 1,629.37 1,333.09 2,364,181.45 273,532.46 0.28 2,105.14 MWD+SC+sag(2) 4,985.74 17.06 39.73 4,362.94 4,280.25 1,643.53 1,344.66 2,364,195.39 273,544.30 0.65 2,123.43 MWD+SC+sag(2) 5,047.23 17.62 40.14 4,421.64 4,338.95 1,657.58 1,356.43 2,364,209.22 273,556.33 0.93 2,141.76 MWD+SC+sag(2) 5,109.48 17.72 39.84 4,480.95 4,398.26 1,672.06 1,368.57 2,364,223.46 273,568.75 0.22 2,160.66 MWD+SC+sag(2) 5,172.82 17.17 40.99 4,541.38 4,458.69 1,686.52 1,380.88 2,364,237.68 273,581.33 1.02 2,179.64 MWD+SC+sag(2) 5,233.18 17.10 40.59 4,599.06 4,516.37 1,699.98 1,392.50 2,364,250.91 273,593.21 0.23 2,197.42 MWD+SC+sag(2) 5,295.23 17.48 41.31 4,658.30 4,575.61 1,713.91 1,404.58 2,364,264.61 273,605.56 0.70 2,215.86 MWD+SC+sag(2) 5,357.91 17.43 40.44 4,718.10 4,635.41 1,728.13 1,416.89 2,364,278.58 273,618.13 0.42 2,234.66 MWD+SC+sag(2) 5,420.69 18.15 39.33 4,777.87 4,695.18 1,742.85 1,429.18 2,364,293.06 273,630.71 1.27 2,253.84 MWD+SC+sag(2) 5,482.91 18.38 38.81 4,836.96 4,754.27 1,757.99 1,441.47 2,364,307.97 273,643.28 0.45 2,273.34 MWD+SC+sag(2) 5,546.22 18.32 38.91 4,897.05 4,814.36 1,773.51 1,453.98 2,364,323.24 273,656.08 0.11 2,293.27 MWD+SC+sag(2) 5,607.52 18.22 39.44 4,955.26 4,872.57 1,788.40 1,466.12 2,364,337.90 273,668.51 0.32 2,312.48 MWD+SC+sag(2) 5,670.54 17.97 40.28 5,015.16 4,932.47 1,803.43 1,478.66 2,364,352.69 273,681.33 0.57 2,332.05 MWD+SC+sag(2) 3/2/2017 4:38:43PM Page 4 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well KBU 32-06 Project: Kenai Gas Field TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Well: KBU 32-06 North Reference: True Wellbore: KBU 32-06 Survey Calculation Method: Minimum Curvature Design: KBU 32-06 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 5,731.67 18.00 39.48 5,073.31 4,990.62 1,817.91 1,490.76 2,364,366.93 273,693.71 0.41 2,350.93 MWD+SC+sag(2) 5,794.27 18.12 40.21 5,132.82 5,050.13 1,832.81 1,503.20 2,364,381.59 273,706.43 0.41 2,370.34 MWD+SC+sag(2) 5,856.25 18.13 39.37 5,191.73 5,109.04 1,847.63 1,515.54 2,364,396.17 273,719.05 0.42 2,389.62 MWD+SC+sag(2) 5,919.12 18.21 39.34 5,251.46 5,168.77 1,862.79 1,527.97 2,364,411.09 273,731.77 0.13 2,409.22 MWD+SC+sag(2) 5,981.36 18.03 39.54 5,310.62 5,227.93 1,877.74 1,540.27 2,364,425.80 273,744.35 0.31 2,428.58 MWD+SC+sag(2) 6,043.11 17.95 40.40 5,369.35 5,286.66 1,892.35 1,552.52 2,364,440.17 273,756.88 0.45 2,447.65 MWD+SC+sag(2) 6,105.38 18.34 39.04 5,428.52 5,345.83 1,907.27 1,564.91 2,364,454.85 273,769.55 0.92 2,467.04 MWD+SC+sag(2) 6,167.14 18.26 38.64 5,487.16 5,404.47 1,922.38 1,577.07 2,364,469.72 273,782.00 0.24 2,486.43 MWD+SC+sag(2) 6,228.29 18.24 38.69 5,545.23 5,462.54 1,937.33 1,589.03 2,364,484.44 273,794.25 0.04 2,505.58 MWD+SC+sag(2) 6,290.68 17.92 39.40 5,604.54 5,521.85 1,952.37 1,601.23 2,364,499.24 273,806.73 0.62 2,524.94 MWD+SC+sag(2) 6,351.71 18.11 38.88 5,662.58 5,579.89 1,967.01 1,613.14 2,364,513.65 273,818.92 0.41 2,543.81 MWD+SC+sag(2) 6,414.92 18.18 38.94 5,722.65 5,639.96 1,982.32 1,625.51 2,364,528.72 273,831.57 0.11 2,563.49 MWD+SC+sag(2) 6,477.00 18.20 38.78 5,781.62 5,698.93 1,997.41 1,637.67 2,364,543.58 273,844.02 0.09 2,582.87 MWD+SC+sag(2) 6,540.61 18.34 39.29 5,842.03 5,759.34 2,012.90 1,650.23 2,364,558.82 273,856.87 0.33 2,602.81 MWD+SC+sag(2) 6,603.87 18.11 39.22 5,902.11 5,819.42 2,028.22 1,662.74 2,364,573.90 273,869.68 0.37 2,622.59 MWD+SC+sag(2) 6,665.95 18.04 39.77 5,961.13 5,878.44 2,043.09 1,674.99 2,364,588.52 273,882.22 0.30 2,641.85 MWD+SC+sag(2) 6,729.29 18.04 40.14 6,021.36 5,938.67 2,058.12 1,687.59 2,364,603.32 273,895.10 0.18 2,661.47 MWD+SC+sag(2) 6,769.43 18.18 39.48 6,059.51 5,976.82 2,067.71 1,695.58 2,364,612.74 273,903.27 0.62 2,673.94 MWD+SC+sag(2) 6,860.04 19.11 40.12 6,145.36 6,062.67 2,089.96 1,714.12 2,364,634.64 273,922.24 1.05 2,702.91 MWD+SC+sag(3) 6,923.37 19.54 41.05 6,205.12 6,122.43 2,105.87 1,727.76 2,364,650.29 273,936.17 0.83 2,723.87 MWD+SC+sag(3) 6,985.60 19.82 40.77 6,263.72 6,181.03 2,121.71 1,741.48 2,364,665.86 273,950.20 0.47 2,744.82 MWD+SC+sag(3) 7,047.55 19.81 40.41 6,322.00 6,239.31 2,137.66 1,755.15 2,364,681.54 273,964.16 0.20 2,765.82 MWD+SC+sag(3) 7,109.82 19.66 39.73 6,380.61 6,297.92 2,153.75 1,768.68 2,364,697.37 273,978.00 0.44 2,786.84 MWD+SC+sag(3) 7,171.77 19.72 38.13 6,438.94 6,356.25 2,169.99 1,781.80 2,364,713.35 273,991.43 0.88 2,807.71 MWD+SC+sag(3) 7,234.38 19.80 36.39 6,497.86 6,415.17 2,186.83 1,794.61 2,364,729.94 274,004.56 0.95 2,828.86 MWD+SC+sag(3) 7,295.77 17.87 33.94 6,555.97 6,473.28 2,203.02 1,806.04 2,364,745.91 274,016.30 3.40 2,848.61 MWD+SC+sag(3) 7,357.63 16.22 34.08 6,615.11 6,532.42 2,218.05 1,816.18 2,364,760.74 274,026.72 2.67 2,866.65 MWD+SC+sag(3) 7,420.15 15.84 33.85 6,675.20 6,592.51 2,232.37 1,825.83 2,364,774.87 274,036.64 0.62 2,883.82 MWD+SC+sag(3) 7,481.68 15.72 33.78 6,734.41 6,651.72 2,246.27 1,835.14 2,364,788.59 274,046.22 0.20 2,900.46 MWD+SC+sag(3) 7,543.71 15.74 33.55 6,794.11 6,711.42 2,260.26 1,844.46 2,364,802.41 274,055.81 0.11 2,917.18 MWD+SC+sag(3) 7,605.31 15.59 33.72 6,853.43 6,770.74 2,274.11 1,853.67 2,364,816.07 274,065.28 0.25 2,933.72 MWD+SC+sag(3) 7,668.74 15.82 34.35 6,914.49 6,831.80 2,288.34 1,863.28 2,364,830.11 274,075.16 0.45 2,950.80 MWD+SC+sag(3) 7,730.48 15.93 35.19 6,973.87 6,891.18 2,302.21 1,872.91 2,364,843.80 274,085.06 0.41 2,967.63 MWD+SC+sag(3) 7,790.97 15.77 34.20 7,032.06 6,949.37 2,315.80 1,882.32 2,364,857.20 274,094.72 0.52 2,984.08 MWD+SC+sag(3) 7,853.08 15.73 34.43 7,091.84 7,009.15 2,329.72 1,891.82 2,364,870.94 274,104.49 0.12 3,000.86 MWD+SC+sag(3) 7,917.57 15.96 34.05 7,153.88 7,071.19 2,344.28 1,901.73 2,364,885.30 274,114.67 0.39 3,018.39 MWD+SC+sag(3) 7,979.46 16.47 36.53 7,213.31 7,130.62 2,358.38 1,911.72 2,364,899.21 274,124.93 1.39 3,035.62 MWD+SC+sag(3) 8,041.22 16.66 36.79 7,272.51 7,189.82 2,372.50 1,922.23 2,364,913.13 274,135.71 0.33 3,053.20 MWD+SC+sag(3) 8,103.40 17.73 37.22 7,331.91 7,249.22 2,387.18 1,933.29 2,364,927.59 274,147.05 1.73 3,071.56 MWD+SC+sag(3) 8,164.90 17.58 37.67 7,390.51 7,307.82 2,401.99 1,944.63 2,364,942.18 274,158.67 0.33 3,090.19 MWD+SC+sag(3) 3/2/2017 4:38:43PM Page 5 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well KBU 32-06 Project: Kenai Gas Field TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Well: KBU 32-06 North Reference: True Wellbore: KBU 32-06 Survey Calculation Method: Minimum Curvature Design: KBU 32-06 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) (°/1001 (ft) Survey Tool Name 8,227.41 18.37 38.53 7,449.97 7,367.28 2,417.17 1,956.54 2,364,957.12 274,170.87 1.33 3,109.47 MWD+SC+sag(3) 8,288.91 17.93 38.63 7,508.41 7,425.72 2,432.14 1,968.49 2,364,971.87 274,183.10 0.72 3,128.63 MWD+SC+sag(3) 8,350.05 17.66 38.31 7,566.62 7,483.93 2,446.77 1,980.11 2,364,986.27 274,195.00 0.47 3,147.31 MWD+SC+sag(3) 8,412.06 17.81 38.50 7,625.69 7,543.00 2,461.57 1,991.84 2,365,000.85 274,207.02 0.26 3,166.19 MWD+SC+sag(3) 8,473.29 17.70 38.67 7,684.00 7,601.31 2,476.17 2,003.49 2,365,015.21 274,218.94 0.20 3,184.86 MWD+SC+sag(3) 8,536.06 18.41 39.42 7,743.68 7,660.99 2,491.28 2,015.75 2,365,030.08 274,231.48 1.19 3,204.31 MWD+SC+sag(3) 8,597.96 18.15 40.14 7,802.45 7,719.76 2,506.20 2,028.17 2,365,044.76 274,244.19 0.56 3,223.73 MWD+SC+sag(3) 8,659.59 18.02 39.24 7,861.04 7,778.35 2,520.92 2,040.39 2,365,059.25 274,256.68 0.50 3,242.86 MWD+SC+sag(3) 8,720.99 17.71 39.09 7,919.48 7,836.79 2,535.52 2,052.28 2,365,073.62 274,268.86 0.51 3,261.69 MWD+SC+sag(3) 8,782.51 17.55 39.26 7,978.11 7,895.42 2,549.97 2,064.05 2,365,087.83 274,280.90 0.27 3,280.32 MWD+SC+sag(3) 8,845.28 17.73 39.11 8,037.93 7,955.24 2,564.71 2,076.07 2,365,102.35 274,293.20 0.30 3,299.34 MWD+SC+sag(3) 8,907.40 16.01 38.37 8,097.37 8,014.68 2,578.77 2,087.36 2,365,116.18 274,304.75 2.79 3,317.37 MWD+SC+sag(3) 8,969.20 15.53 38.90 8,156.85 8,074.16 2,591.89 2,097.84 2,365,129.10 274,315.49 0.81 3,334.16 MWD+SC+sag(3) 9,031.86 15.56 37.66 8,217.21 8,134.52 2,605.07 2,108.24 2,365,142.08 274,326.14 0.53 3,350.95 MWD+SC+sag(3) 9,094.46 15.76 37.88 8,277.49 8,194.80 2,618.43 2,118.59 2,365,155.23 274,336.74 0.33 3,367.83 MWD+SC+sag(3) 9,158.15 15.35 38.43 8,338.85 8,256.16 2,631.86 2,129.14 2,365,168.46 274,347.55 0.68 3,384.91 MWD+SC+sag(3) 9,219.24 13.97 41.47 8,397.95 8,315.26 2,643.72 2,139.05 2,365,180.13 274,357.68 2.59 3,400.36 MWD+SC+sag(3) 9,282.44 11.87 40.55 8,459.54 8,376.85 2,654.37 2,148.33 2,365,190.60 274,367.16 3.34 3,414.49 MWD+SC+sag(3) 9,341.71 10.51 39.65 8,517.69 8,435.00 2,663.17 2,155.74 2,365,199.25 274,374.74 2.31 3,425.99 MWD+SC+sag(3) 9,404.49 8.76 40.80 8,579.58 8,496.89 2,671.20 2,162.52 2,365,207.15 274,381.67 2.80 3,436.49 MWD+SC+sag(3) 9,466.40 8.57 41.49 8,640.78 8,558.09 2,678.22 2,168.66 2,365,214.05 274,387.94 0.35 3,445.82 MWD+SC+sag(3) 9,527.45 8.71 41.02 8,701.14 8,618.45 2,685.11 2,174.71 2,365,220.83 274,394.12 0.26 3,454.99 MWD+SC+sag(3) 9,592.02 8.44 40.34 8,764.99 8,682.30 2,692.42 2,180.98 2,365,228.01 274,400.54 0.45 3,464.61 MWD+SC+sag(3) 9,654.90 8.48 41.32 8,827.18 8,744.49 2,699.41 2,187.03 2,365,234.89 274,406.72 0.24 3,473.86 MWD+SC+sag(3) 9,715.71 8.49 41.24 8,887.33 8,804.64 2,706.16 2,192.95 2,365,241.52 274,412.76 0.03 3,482.83 MWD+SC+sag(3) 9,777.61 8.54 41.47 8,948.55 8,865.86 2,713.04 2,199.01 2,365,248.28 274,418.95 0.10 3,491.99 MWD+SC+sag(3) 9,841.27 8.56 41.18 9,011.50 8,928.81 2,720.14 2,205.26 2,365,255.27 274,425.33 0.07 3,501.45 MWD+SC+sag(3) 9,900.98 8.78 41.55 9,070.53 8,987.84 2,726.90 2,211.20 2,365,261.91 274,431.41 0.38 3,510.45 MWD+SC+sag(3) 9,962.50 8.82 41.69 9,131.32 9,048.63 2,733.94 2,217.46 2,365,268.82 274,437.80 0.07 3,519.86 MWD+SC+sag(3) 10,024.04 8.38 43.41 9,192.17 9,109.48 2,740.72 2,223.68 2,365,275.48 274,444.14 0.83 3,529.05 MWD+SC+sag(3) 10,087.91 8.12 42.30 9,255.38 9,172.69 2,747.43 2,229.91 2,365,282.08 274,450.51 0.48 3,538.20 MWD+SC+sag(3) 10,150.88 8.25 40.12 9,317.71 9,235.02 2,754.18 2,235.81 2,365,288.71 274,456.54 0.53 3,547.16 MWD+SC+sag(3) 10,213.61 8.32 39.40 9,379.78 9,297.09 2,761.13 2,241.59 2,365,295.54 274,462.45 0.20 3,556.20 MWD+SC+sag(3) 10,275.74 8.09 39.19 9,441.28 9,358.59 2,767.99 2,247.21 2,365,302.30 274,468.20 0.37 3,565.07 MWD+SC+sag(3) 10,339.66 8.01 41.33 9,504.57 9,421.88 2,774.82 2,252.99 2,365,309.01 274,474.11 0.49 3,574.02 MWD+SC+sag(3) 10,404.57 8.22 38.78 9,568.83 9,486.14 2,781.83 2,258.89 2,365,315.91 274,480.14 0.64 3,583.18 MWD+SC+sag(3) 10,467.40 8.26 39.04 9,631.01 9,548.32 2,788.84 2,264.54 2,365,322.81 274,485.92 0.09 3,592.18 MWD+SC+sag(3) 10,522.33 7.96 38.84 9,685.39 9,602.70 2,794.87 2,269.41 2,365,328.74 274,490.91 0.55 3,599.93 MWD+SC+sag(3) 10,560.00 . 7.96 38.84 9,722.70 • 9,640.01 . 2,798.93 2,272.68 2,365,332.74 274,494.26 0.00 3,605.15 PROJECTED to TD 3/2/2017 4:38:43PM Page 6 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well KBU 32-06 Project: Kenai Gas Field TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Well: KBU 32-06 North Reference: True Wellbore: KBU 32-06 Survey Calculation Method: Minimum Curvature Design: KBU 32-06 Database: Sperry EDM-NORTH US+CANADA mitchelllaird@halliburton.com 0' Michael Calkins -- --. Date: 3/2/2017 Checked By: 2017.03,0213:4411-09'00' Approved By: 3/2/2017 4:38:43PM Page 7 COMPASS 5000.1 Build 81 • ! Hilcorp Energy Company CASING &CEMENTING REPORT Lease&Well No. KEU KBU 32-06 Date Run 2-Feb-17 County Kenai State Alaska Supv. R Pederson/A Dorr CASING RECORDAr.azi 4 Surface v 5 TD 1,509.00 Shoe Depth: 1,499.00 PBTD: 1,417.00 No.Jts.Delivered No.Jts.Run 36 No.Jts.Returned Ftg.Delivered Ftg.Run 1,476.94 Ftg.Returned Length Measurements W/O Threads Ftg.Cut Jt. Ftg.Balance RKB 18.00 RKB to BHF RKB to CHF 21.72 RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Float Shoe 113/4 BTC Antelope 1.57 1,499.36 1,497.79 2 Casing 10 3/4 45.5 _ L-80 BTC Tenaris 79.47 1,497.79 1,418.32 Float Collar 11 3/4 BTC Antelope 1.32 1,418.32 1,417.00 33 Casing 10 3/4 45.5 L-80 BTC Tenaris 1,340.98 1,417.00 76.02 Casing Pup 10 3/4 45.5 L-80 BTC Tenaris 10.05 76.02 65.97 Casing 10 3/4 45.5 L-80 BTC Tenaris 39.24 65.97 26.73 Hanger&Pup 13 5/8 45.5 L-80 BTC Tenaris 4.31 26.73 22.42 Csg Wt.On Hook: 58,000 Type Float Collar: Antelope Oil Tool Float No.Hrs to Run: 6 Csg Wt.On Slips: Type of Shoe: Antelope Oil Tool Bullnr Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg X Yes No 10 Ft.Min. 9 PPG Fluid Description: Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: Yes No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: 17 total 13 1/2"bow spring centralizers.2 centralizers on jt#1, 1 centralizer per jt on#2&#3, 1 centralizer every other jt #4-29 CEMENTING REPORT Shoe @ 1499 FC @ 1,417.00 Top of Liner Preflush(Spacer) Type: MudPush II Density(ppg) 10 Volume pumped(BBLs) 28 Lead Slurry Type: Class A Sacks: 276 Yield: 2.44 Density(ppg) 12 Volume pumped(BBLs) 110.5 Mixing/Pumping Rate(bpm): 5 Tail Slurry / w Type: Class A Sacks: 331 Yield: 1.22 Density(ppg) 15.4 Volume pumped(BBLs) 72 Mixing/Pumping Rate(bpm): 5 u) Post Flush(Spacer) ix Type: Density(ppg) Rate(bpm): Volume: LL Displacement: Type: Spud Mud Density(ppg) 9 Rate(bpm): 5.5 Volume(actual/calculated): 135/136 FCP(psi): 435 Pump used for disp: SLB Bump Plug? X Yes No Bump press 1175 Casing Rotated? Yes X No Reciprocated? X Yes No %Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X, Yes No Vol to Surf: . c 3 . 'irk Cement In Place At: 8:49 Date: 2/3/2017 Estimated TOC: 0 Method Used To Determine TOC: Cement Returns Post Job Calculations: Calculated Cmt Vol @ 0%excess: Total Volume cmt Pumped: 182.5 Cmt returned to surface: 35 Calculated cement left in wellbore: 147.5 OH volume Calculated: OH volume actual: Actual%Washout: 25 www.wellez.net WellEz Information Management LLC ver_102716bf Hilcorp Energy Company CASING &CEMENTING REPORT Lease&Well No. KEU KBU 32-06 Date Run 15-Feb-17 County Kenai State Alaska Supv. C Montague/R Wall CASING RECORD Intermediate • TD 6,810.30 Shoe Depth: 6,801.48 PBTD: No.Jts.Delivered 184 No.Jts.Run 165 No.Jts.Returned 19 Ftg.Delivered Ftg.Run Ftg.Returned Length Measurements W/O Threads Ftg.Cut Jt. Ftg.Balance RKB 18.00 RKB to BHF RKB to CHF 21.72 RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Float Shoe 8 5/8 29.7 L-80 DWC Weatherford 303 1.63 6,801.48 6,799.85 2 Casing 7 5/8 29.7 L-80 DWC 84.77 6,799.85 6,715.08 Float collar 8 5/8 29.7 L-80 DWC Weatherford 402 1.33 6,715.08 6,713.75 154 Casing 7 5/8 29.7 L-80 BTC 6,641.78 6,713.75 71.97 Casing pup 7 5/8 29.7 L-80 BTC 10.16 71.97 61.81 1 Casing 7 5/8 29.7 _ L-80 BTC 39.04 61.81 22.77 Hanger w/pup 2.57 22.77 20.20 CEMENTING REPORT Shoe @ 6801.48 FC @ 6,713.75 Top of Liner #N/A Preflush(Spacer) Type: Mud Push 2 Density(ppg) 10 Volume pumped(BBLs) 44 Lead Slurry Type: G blend extended Sacks: 438 Yield: 2.14 Density(ppg) 12.5 Volume pumped(BBLs) 167.5 Mixing/Pumping Rate(bpm): 6.7 Tail Slurry W Type: G blend Sacks: 148 Yield: 1.16 Density(ppg) 15.8 Volume pumped(BBLs) 30.5 Mixing/Pumping Rate(bpm): 5.5 'I' Post Flush(Spacer) F- re Type: water Density(ppg) 8.34 Rate(bpm): 5.5 Volume: 10 L Displacement: Type: KCL/PHPA Density(ppg) 9.35 Rate(bpm): 5.5 Volume(actual/calculated): 308.5/308.5 FCP(psi): 1150 Pump used for disp: cement truck Bump Plug? X Yes No Bump press 1600 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 85 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 262 Cement In Place At: 16:20 Date: 2/17/2017 Estimated TOC: 1,710 Method Used To Determine TOC: CBL ✓ fd / CJ Post Job Calculations: Calculated Cmt Vol @ 0%excess: 149.3 Total Volume cmt Pumped: 198 Cmt returned to surface: 0 Calculated cement left in wellbore: 198 OH volume Calculated: 254 OH volume actual: 205 Actual%Washout: 2 www.wellez.net WellEz Information Management LLC ver_102716bf Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. KEU KBU 32-06 Date Run 14-Mar-17 County Kenai State Alaska Supv. R Pederson/R Wall CASING RECORD Production ow TD 10,560.00 Shoe Depth: 10,547.21 PBTD: No.Jts.Delivered 274 No.Jts.Run 250 No.Jts.Returned 24 Ftg.Delivered 11,343.60 Ftg.Run 10,547.00 Ftg.Returned 796.00 Length Measurements W/0 Threads Ftg.Cut Jt. 122.00 Ftg.Balance 674.00 RKB 18.00 RKB to BHF RKB to CHF 21.72 RKB to THF Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Shoe 5 20.0 L-80 DWC Antelope 1.42 10,547.21 10,545.79 2 Casing 41/2 12.6 L-80 DWC VAM 82.38 10,545.79 10,463.41 Float Collar 5 20.0 L-80 DWC Antelope 1.30 10,463.41 10,462.11 4 Casing 41/2 12.6 L-80 DWC VAM 165.40 10,462.11 10,296.71 RAJointA 41/2 12.6 L-80 _ DWC VAM 41.70 10,296.71 10,255.01 16 Casing 41/2 12.6 L-80 DWC VAM 658.72 10,255.01 9,596.29 RA Joint B 41/2 12.6 L-80 DWC VAM 41.67 9,596.29 9,554.62 16 Casing 41/2 12.6 L-80 DWC VAM 664.16 9,554.62 8,890.46 RAJointC 41/2 12.6 L-80 DWC VAM 40.09 8,890.46 8,850.37 62 Casing 41/2 12.6 L-80 DWC VAM 2,569.67 8,850.37 6,280.70 Pup Joint 41/2 12.6 L-80 DWC VAM 3.11 6,280.70 6,277.59 Swell Packer 6 5/8 12.6 L-80 DWC 15.00 6,277.59 6,262.59 Pup Joint 41/2 12.6 L-80 DWC VAM 13.95 6,262.59 6,248.64 149 Casing 41/2 12.6 L-80 DWC VAM 6,165.80 6,248.64 82.84 Pup Joint A 41/2 12.6 L-80 DWC VAM 19.71 82.84 63.13 1 Casing 41/2 12.6 L-80 DWC VAM 41.38 63.13 21.75 Casing Hanger 41/2 12.6 L-80 DWC Cactus 3.10 21.75 18.65 Csg Wt.On Hook: 110,000 Type Float Collar: Antelope No.Hrs to Run: 13 Csg Wt.On Slips: 72,000 Type of Shoe: Antelope Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg Yes X No 13 Ft.Min. 11 PPG Fluid Description: 6%KCL Liner hanger Info(Make/Model): Liner top Packer?: _Yes No Liner hanger test pressure: Floats Held X Yes_ No Centralizer Placement: Centralizer on#1,then every joint from#3 to#77.Then every other one to#95.88 ran. CEMENTING REPORT Shoe @ 10548 FC @ 10,463.00 Top of Liner Preflush(Spacer) Type: Mud Push II Density(ppg) 12.5 Volume pumped(BBLs) 15.3 Lead Slurry Type: Class G Sacks: 675 Yield: 1.33 Density(ppg) 15.3 Volume pumped(BBLs) 160 Mixing/Pumping Rate(bpm): 4.4 Tail Slurry W Type: Sacks: Yield: o Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 1- z Type:Water Density(ppg) 8.34 Rate(bpm): Volume: 10 LL Displacement: Type: 6%KCL Brine Density(ppg) 8.7 Rate(bpm): 6 Volume(actual/calculated): 150/150 FCP(psi): 3000 Pump used for disp: Schlumberger Cement Bump Plug? Yes X 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: 0 Cement In Place At: 14:45 Date: 3/15/2017 Estimated TOC: 6,100 Method Used To Determine TOC: lift pressure calc. Post Job Calculations: Calculated Cmt Vol @ 0%excess: 106.81 Total Volume cmt Pumped: 160 Cmt returned to surface: 0 Calculated cement left in wellbore: 160 OH volume Calculated: 92.4 OH volume actual: Actual%Washout: www.wellez.net WellEz Information Management LLC ver_102716bf r i KBU 32-06 FINAL DAYS VS DEPTH KBU 32-06 Actual -KBU 32-06 Plan 0 500 1000 1500 2000 2500 3000 3500 4000 4500 E 5000 F-- a- 5500 0 0 cc 6000 N 2 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 0 10 20 30 40 50 60 DAYS 5/12/2017 • • KBU 32-06 MW vs Depth 0 KBU 32-06 Plan 1000 -KBU 32-06 Actual 2000 3000 4000 5000 6000 s a ai 7000 N f6 1\444\ al 8000 9000 10000 11000 12000 13000 14000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) 5/12/2017 11th Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive I 0 Anchorage, AK 99503 1111 111 Tele: 907 777-8308 Hilesirp:tlamka..1.LC Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 05/10/2017 RECEIVED To: Alaska Oil & Gas Conservation Commission MAY 11 2017 Meredith Guhl Ap�GC Petroleum Geology Assistant AO GCC W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 32-06 7 boxes: Dry Cuttings WELL= SAMPLE INTERVAL KBU 32-06 1509-2880 KBU 32-06 2880-4350 KBU 32-06 4350-5970 KBU 32-06 5970-7080 KBU 32-06 7080-8250 KBU 32-06 8250-9480 KBU 32-06 9480-10560 Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Rec-'ved B : � Date: 5 112-1( q— • 21 6137 Seth Nolan Hilcorp Alaska, LLC 8 1 72 GeoTech 3800 Centerpoint Drive, Suite 100 y 1 7 2 Anchorage, AK 99503 E p f3 Tele: 907 777-83 Iiilf�nrp al:e�han 1.ld: RECEIVES Fax: 907 777-851008 77-85010 2 8 1 7 4 E-mail: snolan@hilcorp.com DST 2 8G 1 7 5 ED MAY 052017s,,./2011 M. K.BENDER DATE 05/02/17 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 32-06 Prints and digital data Prints: Radial Cement Bond Log 2" Drilling Dynamics Log MD/TVD Production Profile Final Well Report 2"/5" Formation Log MD/TVD ROP-DGR-EWR-CTN_ALD 2"/5" MD 2" LWD Combo Log MD/TVD DGR-EWR-CTN-ALD 2"/5"TVD 2"Gas Ratio Log MD/TVD CD1: 28 172 IOU_32-06 RBT_22MAR17.pdf 3/27/2017 8:39 AM PDF Document 8,724KB KBU_32-06_RBT_22MAR17 img.tiff 3/27/2017 8:39 AM ii-t-File 28,728 KB KBU_32-06_RBT_22MAR 17 MainPass.las 3/27/2017 8:56 AM LAS File 8,475 KB KBU_32-06_RBT_2:2MAR17 RepeatPass.las 3/27/20178:57 AM LAS File 16 KB CD2: _ 2 8 1 7 .3 Hilcorp KBU_32-06_PPROF_14APR17 4/17/2017 3:25 PM File folder CD3: 2 8 1 7 4 Daily Reports 5/2/2017 3:31 PM File folder DML Data 5/2/2017 3:31 PM File folder . Final Well Report 5/2/2017 3:31 PM File folder LAS Data 5/2/2017 3:31 PM File folder Log PDFs 5/2/2017 3:31 PM File folder Log TIFFS 5/2/2017 3:31 PM File folder Show Reports 5/2/2017 3:31 PM File folder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: o_e„..Leat • • 11 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 H lrnr� Alaska,1,IA: Fax: 907 777-8510 Q F E-mail: snolan@hilcorp.com CD4: 28 17 5 _Log Viewers 3/15/201710:18 AM File folder CGM 3/15/20 17 10:18 AM File folder Definitive Survey 3/15/2017 10:18 AM File folder EMF 3/15/201710:18 AM File folder LAS 3/15/201710:18 AM File folder PDF 3/15/20 17 10:18 AM File folder TIFF 3/15/201710:18 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: y of rIt w\��y/ksv THE STATE Alaska Oil and Gas 4 • r ofT asKA Conservation Commission ` 5 = _- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Kenai Field,Beluga-Upper Tyonek and Tyonek Gas Pools, KBU 32-06 Permit to Drill Number: 216-137 Sundry Number: 317-119 Dear Mr. Helgeson: 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, Cath '. Foerster Chair DATED this Ay of March, 2017. RDD8VIS \ A - 3 2017 • •` RECEIVED STATE OF ALASKA �� ALASKA OIL AND GAS CONSERVATION COMMISSION 7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend 0 Perforate Q• Other Stimulate ❑ Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: Coil Tubing Ops ❑✓ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ 216-137 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20658-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 510A ' Kenai Beluga Unit(KBU)32-06 • Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): FEE A028142 • Kenai Gas Field/Beluga-Upper Tyonek Gas Pool,Tyonek Gas Pool 1 • 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): 10,560' 9,723' 10,462' 9,626' 2,626 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' Surface 1,499' 10-3/4" 1,499' 1,452' 5,210psi 2,480psi Intermediate 6,801' 7-5/8" 6,801' 6,089' 6,890psi 4,790psi Production 10,547' 4-1/2" 10,547' 9,710' 8,430psi 7,500psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80 10,547' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 4-1/2"Swell Pkr;N/A 6,263'MD/5,578'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: CommencingOperations: March 23,2017 OILWINJ WDSPL p 0 ❑ 0 Suspended ❑ 16.Verbal Approval: Date: GAS 2 . WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 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. Contact Taylor Nasse-777-8354 Email tnasse( hilcorD.com Printed Name Chad Helgeson Title Operations Manager ir°' Signature � , /A/�. Phone 907-777-8405 Date 3/1'07 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: e-t- , 3r-7 - ' k i Plug Integrity 0 BOP Test LJ Mechanical Integrity Test ❑ Location Clearance ❑ - S .- 3 I2 '3 In. Other: l©G[� psL a ,f-- Cc,+b4,) ceL 4.: j1&l'1= to v',. :,_.�.r eS • Post Initial Injection MIT Req'd? Yes El No El0 a�/ ) Spacing Exception Required? Yes ID No No Subsequent Form Required: I C3 1 0-7- 6.--"---11 APPROVED BY RBD �`� L✓I` ��;73 20'i7 Approved by:0 .",....?„,..„.4_,_ COMMISSIONER THE COMMISSION Date: .2_'— l -. j-th--(7A Submit Form and Form 10-40 Revi d 11/2015 Qp v icya for 12 months from the date of approval. Attachments in Duplicate , • • Well Prognosis Well: KBU 32-06 Hilcarp Alaska,LL) Date:3/17/2017 Well Name: KBU 32-06 API Number: 50-133-20658-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: March 23rd, 2017 Rig: Coil Unit 13 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 216-155 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907) 903-0341 (C) Second Call Engineer: Ted Kramer (907)777-8420 (0) (985) 867-0665(C) AFE Number: 1613181C Maximum Expected BHP: -3,548 psi @ 9,219' TVD (Max pressure from XPT collected in open hole) Max. Potential Surface Pressure: -2,626 psi @ 9,219' TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary KBU 32-06 is a grass roots development well targeting gas sands in the Tyonek formation. This new well reached TD on 2/25/17. The purpose of this work/sundry is to evaluate cement,jet the well dry with CT, and perforate. ' Notes Regarding Wellbore Condition • Well is filled with filtered 6% KCI. • Slickline tag and make gauge ring run prior to startingwok. • E-line will complete CBL prior to starting sundry work • An MIT-IA(7-5/8"x 4-1/2")will be performed to 2,500 psig for 30 minutes using the coiled tubing pumps prior to beginning of sundry work. L 1 -/3o ;:.,, ,A Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. - Rea. N' P az), • Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) • Ensure all crews are aware of stop job authority Coiled Tubing Procedure (start of Sundry work) 1. MIRU Coiled Tubing, PT BOPE psi Hi 250 Low. Notify AOGCC 24 hrs. in advance of BOP test. If slickline or eline tags cement shallower than 10,400. Follow steps 2-6&9-11. 2. MU Mill and Motor BHA. 3. RIH and mill cement and cleanout to 10,440'-10,460' MD. 4. Circulate hole clean with 2 bottoms up, ensure any rubber or cement is free from the hole. 5. RU N2 pumping unit. 6. Drop ball and come online with N2 and jet well dry. • Estimated volume of displaced 6% KCI is 159 bbl. If slickline or eline tags cement deeper than 10,400. Proceed with steps 7-11. 7. RIH w/1-3/4" coiled tubing and 2-1/4"jet nozzle BHA to±10,440' MD and tag PBTD. 8. PU 5ft and displace well fluids with Nitrogen. • • Well Prognosis Well: KBU 32-06 Ililcorp Alaska,LLQ Date:3/17/2017 • Estimated volume of displaced 6% KCI is 159 bbl. 9. Once well is dry,verify desired surface pressure to leave on well with Operations Engineer. 10. POOH w/coil. LD BHA. 11. RD Coiled Tubing. E-Line Procedure 12. MIRU e-line and pressure control equipment. PT lubricator to 3,500 psi Hi 250 Low. Note that the well is pressurized with nitrogen. • If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 13. Perforate the following Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns(up to 12 SPF with 2 perf runs) Zone Sands Top (MD) Btm (MD) FT Tyonek D-2 9,755' 9,785' 30' Tyonek D-3A 10,030 10,065' 35' Tyonek D-3B 10,075' 10,135' 60' Tyonek D-4A 10,225' 10,300' 75' Tyonek D-4B 10,305' 10,355' 18' Tyonek D-4C 10,360' 10,395' 35' a. Proposed perfs also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Tyonek Pool based on Conservation Order No. 510A. 14. POOH. 15. RD e-line. 16. Turn well over to production. (Test SSV with-in 5 days of stable production on well—notify AOGCC 24hrs before testing) E-line Procedure (Contingency): 1. If any zone produces sand and/or water or needs isolated . 2. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 3. RIH and set 4-1/2" CIBP at depth above zone. Or 4. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual and Proposed Well Schematics 2. Coil BOPE Schematic 3. CT Flow Diagrams(Forward and Reverse Jetting) 4. Wellhead Diagram Kenai Gas Field • Er SCHEMATIC Well: KBU 32-06 PTD: 216-137 API: 50-133-20658-00 Hi!carp Alaska,LLC RKB=18.65' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm Conductor—Driven 16" 10-3/4" 109 X-56 Weld 15" Surf 120' 16" ' 14to Set Depth Surf.Csg 45.5 L-80 Buttress 9.95" Surf 1499' fil 7-5/8" Intermediate 29.7 L-80 BTC 6.875" Surf 6,801' TUBING ItI 4-1/2" Production 12.6 L-80 DWC/C HT 3.958" Surf 10,547' 10-3/4" - TOC=2,048' 1JEWELRY DETAIL om CBL on Feb No. Depth ID OD Item 18,2017 1 20' 4.276" 11" Tubing Hanger 1 ` 2 6,263' 4.276" 6.875" 15 ft Swell Packer(Water Swell) • _ y , 9 7-5/8" L. .' ( ''' I-0/z, RA-C 8,850' •,4 s RA-B 9,555' 4 OPEN HOLE/CEMENT DETAIL 13-1/2"hole.110.5 bbls(276sx)of 12#lead cement and 72 bbls(331 sx)15.4 ppg L 10-3/4" Class A. RA-A 10,255' 35 bbls of lead cement returns to Surface 11 9-7/8"hole.167.5 BBL(438 sx)of 12.5ppg Class G Extended lead and 30.5 BBLS q 7-5/8" (148sx)15.8 ppg Class G tail. 45BBLs of losses,but recovered 40bbls of mud push at h:' surface. 4-1/2" a'G 4-1/2" 6-3/4"hole.160 bbls(675sx)15.3 Class G.100%returns. PBTD=10,462'MD/9,626'TVD TD=10,560'MD/9,723'TVD Max Dev 38 deg @ 2,629' Updated by DMA 03-17-17 Kenai Gas Field • PROPOSED SCHEMATIC Well: KBU32-06 PTD: 216-137 API: 50-133-20658-00 Ailcorp Alaska,LLC RKB=18.65' CASING DETAIL Size Type Wt Grade Conn. ID Top Btm ` Conductor-Driven "r 16" 109 X-56 Weld 15" Surf 120' 16" 1 to Set Depth ill ,� 10-3/4" Surf.Csg 45.5 L-80 Buttress 9.95" Surf 1499' kmi 7-5/8" Intermediate 29.7 L-80 DWC/C HT 3.958" Surf 10,547'BTC 6.875" Surf 6,801' a TUBING n V 4-1/2" Production 12.6 L-80 10-3/4" TOC=2,048' JEWELRY DETAIL om CBL on Feb -.)'4,,'.t, No. Depth ID OD Item 18,20175, 1 20' 4.276" 11" Tubing Hanger 2 6,263' 4.276" 6.875" 15 ft Swell Packer(Water Swell) rk t • 10 a' PERFORATION DETAIL , Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status " D-2 9,755' 9,785' 8,946' 8,956' TBD 2-7/8" Proposed ... D-3A 10,030 10,065' 9,198' 9,233' TBD 2-7/8" Proposed 4r- D-3B 10,075' 10,135' 9,243' 9,302' TBD 2-7/8" Proposed + LIZ D-4A 10,225' 10,300' 9,391' 9,465' TBD 2-7/8" Proposed ?3-, c 11r D-4B 10,305' 10,355' 9,470' 9,520' TBD 2-7/8" Proposed -1. -NI D-4C 10,360' 10,395' 9,525 9,559' TBD 2-7/8" Proposed t tryt , 2 B r ® , 7-5/8" RA-C 8,850' ti` RA-B 9,555' Iv ) it) OPEN HOLE/CEMENT DETAIL 13-1/2"hole.110.5 bbls(276sx)of 12#lead cement and 72 bbls(331 sx)15.4 ppg 10-3/4" Class A. RA-A 10,255' !a► 't4.i bbls of lead cement returns to Surface 9-7/8"hole.167.5 BBL(438 sx)of 12.5ppg Class G Extended lead and 30.5 BBLs 0 4-1/2" 7-5/8" (148sx)15.8 ppg Class G tail. 45BBL5 of losses,but recovered 40bbls of mud push at surface. ' 4-1/2" 6-3/4"hole.160 bbls(675sx)15.3 Class G.100%returns. PBTD=10,462'MD/9,626'TVD TD=10,560'MD/9,723'TVD Max Dev 38 deg @ 2,629' Updated by DMA 03-17-17 • • Kenai Gas Field KBU 32-06 ,�.,,,i, �. ._ r 03/17/2017 �a �3 , Coil Tubing BOP 7 Lubricator to injection head I I 1.75"Tandem Stripper 1 011E1 Blind/Shear =41/1610 =Blind/Shear I■I■I. rja —MINN 11111111110 e■IMINI Blind/Shear_— Blind/ShearIII,I■ .I,I,I 51....Slip _ O= Er Slip 1E110C: e tillPipe111* Pipe 1St 1 Mud Cross C '"� �"" 4 1/16 10M X 4 1/16 10M _ Outlet ra mi w/2- 2 1/16 10M full ,, opening FMC valves VI al ]I' • • I_ to I itO hie: int Mt Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M Crossover spoola 4 1/16 10M X 4 1/16 5M • • 6 8] a B ,Io Q = 0 '] 1 e i Z Q m O e o Z Y ' C ovw D Z ++ Y uo 55 N ] 0 . N. NEtt •••-__/ U I e V{) y C 0 c z ya N s N 111•4 Z L 0 L O C c - U • O d O H .:: li .: .2.1 I I I '11.1.' t iiii in iii iiii --7 iw na in i� _ o; o U Z s 0 n 0 O • ¢ A V • A 5 011111O 4 i 8 c o m C 0, c r'- OEd �aU No11Z g N • • 8j CD 0 D U p ,) Z m 0 B $) -00 � % $) 00Q ,I o su, C Q —1 Vose o ='9ths (/) A v P, iV 1 9 L • D z e 14111a, ►• N • s.. • V V • C ,,,I____ .,1 jN N Z N i 47. co 1z o a cc o io L ' i III i-iiiIii 'I , � JIII III IIII I' S_ ; 3 C O I d 0 1— I I N giA V •A 411111 i O 1 k EI C III OCC 12 oa^\/,J U 0 q 0 A s k a i • Kenai Gas Field • KBU 32-06 Current 03/17/2017 Hik.rp,1 14.{,4.I.IA. Kenai Gas Field Tubing hanger,ported,11 X KBU 32-06 4 1/2"DWC susp X 5.250-4 16 X 10%X 7 5/8 X 4 1/2 stub acme left hand lift,4"H BPV,3.998"min bore,7" extended neck BHTA,Otis,4 1/16 5M FE X 6.5"Otis Quick Union va 910 9—asiil ��\O,�t�� N1'-' 1 _(x`11 aJ\\L Valve,Swab,CIW FLS, ��: Ja\�e3,�'�3, 12'.<30 \�e3,\t"�15 t 5� Ja FF at° 4 1/16 5M FE, HWO,DD trim 31�$ $�0 opet !: ." 0 ) \ / w 4 r110f , i,,,,,,, , ,) , „. „, , , 4>.E Valve, Upper Master a CIW-FLS,4 1/16 5M FE, HWO,DD trim iE 1!(r€lY AJ I Rotating flange,4 1/16 5M x rt➢E ®—=.®�!� 4 1/16 5M Valve, Master,CIW FLS, „ , 4 1/16 5M FE,HWO,DD trimJ. N fir = : I, l p ' w =, Kt Multibowl Wellhead, : + 115MX16%3M,w/ (-11,77; r _o tell f 4-2 1/16 5M 550 a' 'I = — aa r�1� Starting head, :l'a I ® r� 16%3MXAll i 16"SOW,w/ ._sME � ! UTZ it 2-2 1/16 5M Ed F' w 16 1 10%„ 7 5/8" 4/2„ • STANDARD WELL PROCEDURE Iiii,orpa.1.4 NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H25/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 4 Ki3t Pth 21t013io Regg, James B (DOA) From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Sunday, March 05, 2017 8:44 AM @P'< .316)((7 To: Regg,James B (DOA) 1 t Subject: RE: SLR 169 Update on KBU 32-06 We are making arrangements to do a free point and cut this afternoon. Once we start pulling out of hole and lay down casing, I will send a notice for BOP test prior to us going in to jar loose any fish. Should start freepoint work about 4PM this afternoon, so sending of notice should be close to 24 hours in advance. Rance From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Saturday, March 04, 2017 11:29 AM To: Rance Pederson - (C) Subject: RE: SLR 169 Update on KBU 32-06 Understood. If you have to trip pipe to surface you will need to test before rerunning. Otherwise we will grant the extension to get pipe run and cemented. Sent from my Samsung Galaxy smartphone. Original message From: "Rance Pederson - (C)" <rpederson@hilcorp.com> Date: 03/04/2017 8:05 AM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg(a,alaska.gov> Subject: SLR 169 Update on KBU 32-06 Jim, we started running our 4%2" casing as planned the evening of 3-2-17, and at 13:00 hrs yesterday, 3-3-17 we became differentially stuck at 9685', 20 joints off bottom. Our initial mud weight was 12.1 ppg and we have since reduced that to 11.0 ppg with no increase in gas. We have been circulating with no issues, and working pipe throughout yesterday and last night.This morning we are currently building a Black Magic pill to spot and soak outside the shoe track section, in hopes that allows us to come free. We are due for our bi-weekly BOP test today, and anticipated being done with casing run and cementing by yesterday afternoon. If we can get free today,will continue to run the last 20 joints to bottom and get cemented as planned. Drilling Engineer will be talking with the asset team to discuss cementing casing in place here at 9685' if need be. Just wanted to give you an update on our situation...we may over run our due date for BOP test trying to get free'd up and finished up on KBU 32-06 (PTD: 216-137) Rance Pederson Drilling Foreman Kenai Beluga Unit 907-776-6776 1 • • V8q. -d Regg, James B (DOA) 24_'137C From: Clint Montague - (C) <cmontague@hilcorp.com> Sent: Thursday, February 23, 2017 12:21 PM i7 To: Regg, James B (DOA) /� Cc: Monty Myers Subject: Notification of H2S Sensor replacement Attachments: SLR 169 Notice of H2S Sensor Change 2.23.17.docx Mr. Regg, We had a battery die on the rig floor H2S sensor this morning. We changed it out with a spare and Total Safety should _— be be on location within the hour to bump test the sensor. I have attached a notice with a more detailed explanation. If you have any questions please contact me. Thank you, Clint Montague Hilcorp DSM SLR 169 907-776-6776 office 907-776-6796 doghouse 1 t • • U ie4wp a i,I,t,t: Notice of Rig Floor H2S Sensor Change • Date/Time: 2/23/2017 at 06:00 hrs. • Well: KBU 32-06 • Location: Kenai Gas Field, Pad 14-6, Mile 10.5 K-Beach Road • PTD: 216-137 • Rig Name: SLR 169 • Operator Contact: Clinton Montague at 907-776-6776 / cmontague@hilcorp.com • Operation Summary: While drilling 6-3/4" Production section, at a depth of 9182' md, during a tourly well control equipment inspection checklist it was noted the Rig Floor H2S sensor battery was dead. • Actions Taken: The sensor was changed out and notified Total Safety of the asked them to send a Rep out to the rig, to change out sensor to test the replacement. We are expecting Total Safety to arrive early afternoon. • • 1<gu_ z-�, Pri) Z16( 3 Regg, James B (DOA) From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Tuesday, February 07, 2017 8:11 PM �,i_ 2� t7 To: Regg,James B (DOA) Y Subject: Notice of H2S Sensor Change Attachments: SLR 169 Notice of H2S Sensor Change.docx Jim, I had Total Safety change out an H2S sensor in our cellar/sub base today.The replacement was calibrated and bump tested. The reset did shut off the lights, but I had Total Safety change it out anyway,just to be on the safe side. Rance Pederson Drilling Foreman Kenai Beluga Unit 907-776-6776 1 t • 1ledrxclr L1t.LA,1.(.f: Notice of Cellar H2S Sensor Change • Date/Time: 2/07/2017 at 12:00 hrs. • Well: KBU 32-06 • Location: Kenai Gas Field, Pad 14-6, Mile 10.5 K-Beach Road • PTD: 216-137 • Rig Name: SLR 169 • Operator Contact: Rance Pederson at 907-776-6776 / rpederson@hilcorp.com • Operation Summary: While drilling 9 7/8" Intermediate section, at a depth of 3354' md, our cellar H2S sensor tripped visual alarm, showing 5 ppm on the doghouse control panel. Canrig mudloggers gas detection equipment currently showed 6 units at shakers, which had been averaging 11 units all morning, with no sudden increase in gas units. A handheld sniffer was used to check sub-base cellar area and cellar box, with no detection of H2S or LEL (all zeros). We activated the reset button on the doghouse control panel and the visual lights shut off. • Actions Taken: Notified Total Safety of the false alarm and asked them to send a Rep out to the rig, to change out sensor and test the replacement. Total Safety Rep arrived on location at 16:00 hrs from Anchorage, replaced the cellar H2S sensor, calibrated and bumped tested sensor with no issues. We had no further alarms while waiting for Total Safety Rep to arrive on location. • • Seth Nolan Hilcorp Alaska, LLC 2 1 6 1 v GeoTech 3800 Centerpoint Drive, Suite 100 RECEIV Anchorage, 99503 Tele: 907 777-8308 Hilts rp alopka,1JA: Fax: 907 777-8510 MAR 09 2017 E-mail: snolan@hilcorp.com DATE 03/08/17 AOGCC DATA LOGGED Is !\3/201-7 d, K. BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 32-06 Production profile and digital data Prints: Array Dielectric Tool (ADT-GR) Elemental Capture Sonde (ECS-GR) Hostile Natural Gamma Ray Spectrometry (GR/HNGS) Radial Cement Bond Log CD1: Elog digital data 2 8 0 4 9 ECS-ADT 3/8/2017 4:13 PM File folder a HNGS 3/8/ 2017 4:13 PM File folder ! XPT 3/8/2017 4:14 PM File folder CD2: 28050 r KBU32-06_RBT_18FEB17.pdf 3/1/2017 10:20 AM PDF Document 15,225 KB L j KBU32-06 RBT_18F®17 img.tiff 2/18/2017 8:19 PM TIFF File 33,995 KB ?j KBU 32-06_RBT_18FEB 17 MainPass.las 3/1/2017 10:25 AM LAS File 8,192 KB U KBU 32-06_RBT_18FEB 17 Repeat.las 3/1/2017 10:26 AM LAS File 359 KB Thumbs.db 3/8/2017 4:28 PM Data Base File 4 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: G1) 'ict) `k:K ' SOF 7 • 111 w\ ��yA THE STATE Alaska Oil and Gas of® LAsKA Conservation Commission 333 West Seventh Avenue 1151- �^h GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Um Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Engineer Hilcorp Alaska,LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Kenai Field,Beluga/Upper Tyonek and Tyonek Gas 1 Pools,KBU 32-06 Hilcorp Alaska, LLC Permit to Drill Number: 216-137 Surface Location: 526' FSL, 1250' FWL, Sec. 6, T4N, R11W, SM,AK Bottomhole Location: 2067' FNL, 1607' FEL, Sec. 6,T4N, R11 W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair a.� DATED this qday of December, 2016. RECEIVE... .- STATE OF ALASKA ALDA OIL AND GAS CONSERVATION COM J N OCT 26 2016 CC PERMIT TO DRILL 20 AAC 25.005 ' O t la.Type of Work: 1 h.Proposed Well Class! Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ 1c.Specify if well is proposed for: Drill 0. Lateral ❑ Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone ❑✓ • Coalbed Gas ❑ Gas Hydrates 0 Redril❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas 0 • Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 ' Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 KBU 32-06 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 10,487' - TVD: 9,665' . Kenai Gas Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga/Upper Tyonek Gas Pool Surface: 526'FSL,1250'FWL,Sec 6,T4N,R11 W,SM,AK FEE A028142 Tyonek Gas Pool 1 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2011'FSL,2304'FWL,Sec 6,T4N,R11 W,SM,AK N/A 12/15/2016 ' Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2067'FNL,1607'FEL,Sec 6,T4N,R11 W,SM,AK 2492 Acres 8904'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 84 15.Distance to Nearest Well Open Surface: x-272168 • y- 2362578 - Zone-4 GL Elevation above MSL(ft): 65.6 to Same Pool: 1652'to KBU 22-06Y 16.Deviated wells: Kickoff depth: 500 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) , i/cL� C^' Maximum Hole Angle: 37 degrees Downhole: _20315 2 1'�Y Surface: 1.064 a Z-3 d. `� 5e,, 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 16" 16" 109# X-56 Weld 120' Surface Surface 120' 120' Driven 13-1/2" 10-3/4" 45.5# L-80 BTC 1,500' Surface Surface 1,500' 1,455' 875.8 ft3 9-7/8" 7-5/8" 29.7# L-80 BTC 6,600' Surface Surface 6,600' 5,904' 983 ft3 6-3/4" 4-1/2" 12.6# L-80 DWC/C HT 10,487' Surface Surface 10,487' 9,665' 623 ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot g Shallow Hazard Analysis0 Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 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 Email mmvers@hilcorp.com Printed Name Monty Myers Title Drilling Engineer Signature --- ' Phone 777-8431 Date ft, . 2(.. . 20/6 Commission Use Only Permit to Drill ,..., ff `2 API Number: Permit Approval See cover letter for other Number: -` 37 50-X33-26 5S- Date: \1 - 2 Z- \(e requirements. Conditions of approval: If box is checked,wellmay no be sed to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: [r Other: 7 3500 /$C t3 p P' 1 e-.. Samples req'd: Yes❑ No[ Mud log req'd:Yes❑ No®" �n /vi lT r 1 A f Q HZS measures: Yes❑ No Q Directional svy raga:Yes Ei No❑ C L =-c�ti Spacing exception req'd: Y s❑ No[� Inclination-only svy req'd:Yes❑ NO[� i,,I ,,�,-u�,.i 76 •44-c_z 57 t- ..37 e i1)IL) Post initial injection MIT req'd:Yes❑ No❑ '14› `x'2--1-1 i L APPROVED BY Approved by: �0 /29.?„4,7c/4/-...___ COMMISSIONER/ THE COMMISSION Date:/2-?, / OTRPtr3i1 f'1lS V-1Submit Form andForm 10-401(Revised 11/2015) v fA j onths f m the date of approval(20 AAC 25.005 ) Att chments in Duplicate Hilcorp Alaska, LLC • P.O. Box 244027 • Monty Myers Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcor Enerld 10/26/2016 REC Commissioner _ D Alaska Oil &Gas Conservation Commission 2 6 2016 333 W. 7th Avenue Anchorage, Alaska 99501 AOGCC Re: KBU 32-06 Dear Commissioner, KBU 32-06 is a 10,487' MD/9,665' TVD Beluga/Upper Tyonek development well off the 14-06 pad in • the Kenai Gas Field. Reservoir analysis and subsurface mapping has identified an undrained area of the Kenai Field that will target reserves in D2, D3B, and D4 sands. Secondary targets include the Lower Beluga-Upper Tyonek. The base plan is a directional wellbore with a kick off point at 500' MD. Maximum hole angle will be 37 deg. Vertical section will be 3457 ft. Drilling operations are expected to commence approximately December 15th, 2016. The Saxon Rig # 169 will be used to drill and complete the wellbore. The well will be perforated after the rig has departed. (S&Ogki r t ck,,4.(1 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 • • H Hilcorp Alaska, LLC Kenai Beluga Unit KBU 32-06 Drilling Program Kenai Field Revision 0 October 21, 2016 • KBU 32-06 Drilling Procedure Hilcorp Alaka,LLC 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/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 16-3/4"Conductor Riser 11 11.0 Drill 13-1/2"Hole Section 12 12.0 Run 10-3/4"Surface Casing 16 13.0 Cement 10-3/4"Surface Casing 19 14.0 BOP N/U and Test 22 15.0 Drill 9-7/8"Hole Section 23 16.0 Run 7-5/8"Intermediate Casing 28 17.0 Cement 7-5/8"Cement Procedure 30 18.0 Drill 6-3/4"Hole Section 33 19.0 Run 4-1/2"Production Long String 39 20.0 Cement 4-1/2"Production Long String 42 21.0 RDMO 44 22.0 BOP Schematic 45 23.0 Wellhead Schematic 46 24.0 Days Vs Depth 47 25.0 Geoprog 48 26.0 Anticipated Drilling Hazards 49 27.0 Saxon Rig 169 Layout 52 28.0 FIT Procedure 53 29.0 Choke Manifold Schematic 54 30.0 Casing Design Information 55 31.0 9-7/8"Hole Section MASP 56 32.0 6-3/4"Hole Section MASP 57 33.0 Spider Plot(NAD 27) 58 34.0 Surface Plat(As Built)(NAD 27) 59 35.0 Offset MW vs TVD Chart 60 36.0 Directional Plan 61 • • KBU 32-06 Drilling Procedure Hitrm•p:11aa.a,LLC 1.0 Well Summary Well Kenai Beluga Unit 32-06 Pad&Old Well Designation KBU 32-06 is a grass roots well on the existing 14-06 pad Planned Completion Type 4-1/2"production longstring Target Reservoir(s) Tyonek/Beluga Planned Well TD, MD/TVD 10,487' MD/9,665' TVD PBTD,MD/TVD 10,300' MD/9,479' TVD Surface Location(Governmental) 526' FSL, 1250' FWL, Sec 6, T4N,R11W, SM,AK Surface Location(NAD 27) X=272168.44,Y=2362578.00 Surface Location(NAD 83) Top of Productive Horizon 2011'FSL, 2304'FWL, Sec 6, T4N,R11W, SM,AK (Governmental) TPH Location(NAD 27) X=273334.36,Y=2363942.27 TPH Location(NAD 83) BHL(Governmental) 2067'FNL, 1607'FEL, Sec 6, T4N, R11W, SM,AK BHL(NAD 27) X=274400.00,Y=2365219.00 BHL(NAD 83) Maximum Anticipated Pressure in 2030 psig ( 2 5'-' 1E' CCf psig(Downhole) Maximum Anticipated Pressure in 1064 psig 2_30 0 , = psig(Surface) AFE Number 1613181D AFE Drilling Days 25 AFE Completion Days AFE Drilling Amount $4.3MM AFE Completion Amount Work String 4-1/2" 16.6# S-135 CDS-40 (Rental Saxon String) KB Elevation above MSL 84.0 ft GL Elevation above MSL 65.6 ft • BOP Equipment 11" 5M T3-Energy Annular BOP 11" 5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure II demi,:Una n,LLC 2.0 Management of Change Information Hilcorp Alaska, LLC Pansy Hilcomr Changes to Approved Permit to Drill Date: October 24,2016 Subject: Changes to Approved Permit to Drill for KBU 32-06 File#: KBU 32-06 Drilling Program Any modifications to KBU 32-06 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 10 242016 Drilling Engineer Date Page 3 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrorp:11a,ka.i.LC 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 13-1/2" 10-3/4" 9.95" 9.875" 11.75" 45.5 L-80 BTC 5210 . 2480 1040 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 • 4790 683 6-3/4" 4-1/2" 3.958" 3.833" 5.0" 12.6 L-80 DWC/C HT 8430 7500 288 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) All 4.5" 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 October,2016 • • KBU 32-06 Drilling Procedure Hibor!, Chaska.►.Lf. 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • 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. • Ensure time entry adds up to 24 hours total. • 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 • Submit a short operations update each work day to pmazzolini@hilcorp.com; mmyers@hilcorp.com, Ikeller@hilcorp.com, &cdinger@hilcorp.com 5.2 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays,ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.3 EHS Incident Reporting • Notify EHS field coordinator. 1. Matt Hogge: 0: 777-8418 C: 907-227-9829 2. Spills: Keegan Fleming: 0:907-777-8477 C:907-350-9439 • Notify Drlg Manager&Drlg Engineer: 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 2. Luke Keller: 0: 907-777-8395 C: 832-247-3785 3. Monty M Myers: 0: 907-777-8341 C: 907-538-1168 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.4 Casing Tally • Send final"As-Run"Casing tally to mmyers@hilcorp.com&cdinger@hilcorp.com 5.5 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com & cdinger@hilcorp.com Page 5 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure HiIcorp Alaska,LLC 6.0 Planned Wellbore Schematic Kenai Gas Field Proposed Well:KBU 32-06 PTD: XXX-XXX API: 50-133-XXXXX-XX CASING DETAIL SizeType Wt Grade Conn. ID Top Btm \ I Conductor— 16" 1 16" Driven to Set 109 X-56 Weld 15" Surf 120' Depth 10-3/4" Surf.Csg 45.5 L-80 Buttress 9.95" Surf 1500' 10-3 4" '' 7-5/8" Intermediate 29.7 1-80 BTC 6.875" Surf 6,600' 15-W' TUBING TOC=3000' f t'y 4-1/2" Production 12.6 L-80 DWC/C HT 3.958" Surf 10,487' ' r L J ' Hole Section _ Casing MW Workstring 13-1/2" 10-3/4" 8.8—9.3 ppg• 4-1/2" 9-7/8" 7-5/8" 9—9.5 ppg 4-1/2" 6-3/4" 4-1/2" 10—11.7 ppg- 4-1/2" JEWELRY DETAIL No. Depth ID OD Item 1 18' 4.276" 11" Tubing Hanger i 2 6,100 4.276" 6.875" 30 ft Swell Packer(Water Swell) kick.' r- --.S" 1'A "6 4,0` , EXPECTED FLUID MQ DIALED St y A-10 4.185 3,623 4 Sterling A-11 gas" , 4,245 3,677 1 Sterling 8-1 gas " 4.320 3,744 zU`." Sterling Pool 6 gas 5.046 4,427 Upper Beluga gas 5,325 4,692 Lower Beluga gas 6,790 6.085 ti„ Tyonek 18 gas 8,164 7,391 Tyonek 02 gas 9.733 8,912 Tyonek 038 gas -, 10.020 9,199 Tyonek D4A 10.189 9.368 r 41Q �• PBTD=10,400'MD-9;578'TVD TD=10,487'MD/9,665'TVD Page 6 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrm•p:Ua ka.III 7.0 Drilling / Completion Summary KBU 32-06 is a 10,487' MD/9,665' TVD Beluga/Upper Tyonek development well off the 14-06 pad in the Kenai Gas Field. Reservoir analysis and subsurface mapping has identified an undrained area of the Kenai Field that will target reserves in D2, D3B, and D4 sands. Secondary targets include the Lower Beluga-Upper Tyonek. The base plan is a directional wellbore with a kick off point at 500' MD. Maximum hole angle will be 37 deg. Vertical section will be 3457 ft. Drilling operations are expected to commence approximately December 15th,2016. The Saxon Rig # 169 will be used to drill and complete the wellbore. The well will be perforated after the rig has departed. There are two water wells permitted for use on Pad 14-06. One is for water supply to the electrical shop, which was drilled in 2003, and is on the southeast corner of the pad by the access road. This well was drilled to 141 feet and is cased to 139 feet. This well is currently operational. The other water well is referred to as well 309 and is located near KU 21-7. This well was drilled to a depth of 325' and has been capped and the pump was pulled. Surface casing will be run to 1500' MD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste &mud generated during drilling and completion operations will be hauled to the Kenai Gas Field .O&Ifacility for disposal/beneficial reuse depending on test results. This facility is on the same pad as the drill well. General sequence of operations: 1. MOB Saxon Rig# 169 to well site. , 2. N/U 16" diverter riser(No diverter, diverter waiver requested) 3. Drill 13-1/2" hole to 1500' MD. Run and cmt 10-3/4" surface casing. 4. N/D conductor riser,N/U &test 11"x 5M Townsend BOP. 5. Drill (and LWD log) 9-7/8"hole section to 6,600' MD. Run and cmt 7-5/8" intermediate casing. ' 6. Drill (and LWD log) 6-3/4"prod hole section to well TD. Run and cmt 4-1/2" rod. casing. 7. N/D BOP,N/U tree, RDMO. Reservoir Data Acquisition Program: 13-1/2" Surface hole: Mud logging only, no LWD 9-7/8" Intermediate Hole: Mud logging+GR/Res/Den/Neu LWD 6-3/4"Production Hole: Mud logging+ GR/Res/Den/Neu LWD Page 7 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrorp.11a4ka. 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 and completion of KBU 32-06. Ensure to provide AOGCC 24 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. AOGCC Regulation Variance Requests: • Diverter waiver request requested due to the recent drilling of KBU 32-08 and KBU 43-07Y on a nearby pad. No issues were experienced on either well drilling the surface hole. Surface casing will be set at the same depth on KBU 32-06. �ww .0Is z,�^�1,� w t' 4-4'. O. �.�.�...-,0 Z.ocz s":03 Save t AP--"GS r 4'. .m �itc r 4""S Page 8 Revision 0 October,2016 • • KBU 32-06 Drilling Procedure Hilrnrp:11:144.LIT Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 13-1/2" • No diverter Installed N/A • 11"x 5M Townsend Annular BOP • 11"x 5M Townsend Double Ram Initial Test:250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 9-7/8"&6-3/4" • 11"x 5M Townsend Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. 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). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Revision 0 October,2016 • • KBU 32-06 Drilling Procedure Hilum p tla la.LLC 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at a minimum of 120' below ground level. This is required to isolate a problematic gravel bed that occurs from 90— 105'. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M"A" section& 20" adapter bushing. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot& R/U company man&toolpusher offices. 9.7 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix mud for 13-1/2"hole section. 9.9 Set test plug in wellhead prior to N/U conductor riser to ensure nothing is accidentally dropped into the wellbore. 9.10 R/U mud loggers for surface hole section. 9.11 Install 5-1/2"liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm (100%) with 5-1/2" liners. Page 10 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hi!cog. 10.0 N/U 16-3/4" Conductor Riser 10.1 N/U 16-3/4" Conductor Riser • Ensure line does not direct flow from trip tank straight down the flowline. Fill up line and flowline should be oriented 90 degrees to each other at approx. the same height. • Ensure flowline outlet installed so that enough slope exists to carry cuttings to the shakers. • Consider adding additional drainage points at the bottom of the conductor riser if deemed necessary. • R/U fill up line to conductor riser. 10.2 Set 15.375" ID wear bushing in wellhead. 10.3 Rig Orientation on 14-06 Pad: fi ' t r • Staked coca. r^ art ;* • D • ., PAS • w, s.• Stak'eon 101 0 ,. ►- A VW Page Page 11 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hileorp Aln.l a,l i t 11.0 Drill 13-1/2" Hole Section 11.1 P/U below 13-1/2" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Bit TFA should be-0.7 in2. We need to pump at 500 to 510 gpm to clean the hole effectively. • Workstring will be 4.5" 16.6# S-135 CDS40. COMPONENT DATA MIIIIIIIMIIIIMIIIIIIIIIIIIIIIII Item Description Serial Number Conon 8 (in)' ;din) (in) (WO 1H) Length (ft) - HDBSOHCIGRC 13450 3000 13.500 45012 P6-54'REG 1.00 1.00 © 8'SperryDN6 Lobe 4r5.5.3 etg 8.000 5000 121.08 B 6.58'REG 31.83 32.83 - Slabdlzer __®II_--- © B"Dreceoral Comer 7.850 3.500 _ 147 40 B 6-58'REG 8.88 41.71 Kii 8'win,Stablltar its)12 144'gauge 8.000 2 830 ®Iil____ B 6.58 REG 380 4551 © 8'TM HOC(Pulse.) -no 4 1X10 _ 4520 B 6-58'REG 9 40 54.91 • 8'Nan Mag Flex Collar 7.600 .-- 132.48 B&sib'REG 30.00 84.91 0 8'Non Mau Flex Collar 7 670 ECM-EIMIMI B 8-543'REG 30 00 t 14 91 - X-08-5,6"Reg PX4-1.2'IFB -®__ 84-172'!F , 2.25 117.16 © 6.75'Non Mag Flex Cotar .83• 7- 8I 84-t72 F la on 147.16 10 675'Non Mag Flex Cofer 6.700 3000 _ 96.06 8 4-ItT IF 30.00 177.16 E. X,0 4.172"IF P X CDS-40 B 6.520 2.750 _ 93.54 B 4.5"CDS 40 2.75 179.91 ® 6 Joints 4-1,r HWDP cos-so 4.5X1 2 750 ME 41.00 185.00 36401 ® X-0 CDS-40 P X 4 lir IF B 6.520 2.750 _ 93.54 B 4-1.'T IF 2.75 36766 KM 61 i4•Weatherford OAHJar 6250 2250 _ 91.01 84-172'IF 3200 39966 ® X-0 4-172"IF P X CDS-40 B 6.520 2.750 _ 93.54 B 4.5"CDS-40 2.75 402.11 - 13 Joi,NN 4.1t2"HWt1P CDS•40 4,500 2750 _ 41.00 400.00 80241 t%a, 802.4' BIT DATA Cit Numbs, Hordes :1x14.3x16 BR Sire (in) : 13.500 TFA (812) :0.7394 Manuf ctueer :HMS Dull Grade In . Model :OHC1ORC Dull Grade Out Serial Number . MOTOR DATA Meter Number Mal (dp) 1.15 OD(In) :8.000 Names (32nd) : 0.0 Manulaclurx :Sperry DrMng Avg DM Prete Model :SperryDrB Cumuli Cie Pre . Serial Number . 11.2 Hydraulics Summary: Depth- Hole Size Pump Rate Standpipe Est Openhole MW ECD TFA MD(ft) (in) (gpm) Pressure (psi) AV(fpm) (ppg) (ppg) (in2) BHA ' MM + MWD+25 0- 1500 13-1/2" 500 1848 76 9.0 9.2 0.70 HWDP Page 12 Revision 0 October,2016 • S KBU 32-06 Drilling Procedure Hileorp:►Inwkn,LL('. 11.3 Primary bit will be the Security 13-1/2" QHC1GRC Milled Tooth Bit. These are available from Halliburton. 13-'1/2" (343mm) QHC1 GRC PRODUCT SPECIFICATIONS IADC Code 117W Total Tooth Count 61 (lap Row Toth Count11, 3b Journal Angk 33 Offset(11 16") 6 Jet Nozzle Types Standard 53244 Extended 311306 Center Jet (If Center Jetted)501813 Ti.Connection 6-5rd"(API Reg.1 Recommended Make-Up Torque' 2/10001321100 Ft'Ihs. Bit Weight(Boxed'. 260 Lbs.(1 I8 Kg.1 Bit Breaker tMat.Niluegaeyn) 183777164498 01 10 PRODUCT FEATURES • New patented gianutndTM Claw*tooth bit design_ • • Proprietary I)iamund'I`ECH280QTw full tooth hanllac.ingon cutting structure and gage. `.. 1111111.'• Tungsten carbide'surf inserts in gage teeth for added gage protection. 46. `; o • Premium bearing and seal configuration suitable for both rotary and w motor applications. '. • innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal life. • Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. • QuadPaekt Plus Series incorporates its successful`longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems Material#540030 •C•Iculatium tvs.d am recuunmendatium fruin API and tout-iuinl menufaclurers. 0 2014 Halliburton.All rights reserved.Saks of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.hallinurton.com Page 13 Revision 0 October,2016 0 411 KBU 32-06 Drilling Procedure Hilcorp Alakn,IJ E 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 No LWD tools will be run on the 13-1/2"hole section. • 11.6 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.7 Drill 13-1/2" hole section to 1500' MD/ 1455' TVD. • • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 510 gpm. This gives us an annular velocity of 77 fpm, which is borderline for effective hole cleaning. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep API fluid loss < 10. • TD the hole section in a good shale btwn 1450' & 1550' MD. • Take MWD surveys every stand drilled(60' intervals) Page 14 Revision 0 October, 2016 O • KBU 32-06 Drilling Procedure Hilrnrp Alacl.a,LLC 11.8 13-1/2"hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. Pason 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: 8.8—9.3 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: DepthsDensity`, Viscosity , Plastic Viscosity Yield Point API FL LGS 17120-1500' 8.8—9.3) 85-250 20 40 25 45 <10 <15% System Formula Ion: AQUAGEL/freshwater Spud Mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 -20 ppb caustic soda 0.1 ppb(8.5 -9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8-9.3 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb 11.9 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.10 TOH with the drilling assy, handle BHA as appropriate. Page 15 Revision 0 October,2016 • • 14KBU 32-06 Drilling Procedure Hilearp:tlaska.LLC 12.0 Run 10-3/4" Surface Casing 12.1 R/U and pull 15.375"wear bushing. 12.2 R/U Weatherford 10-3/4" casing running equipment. • Ensure 10-3/4" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location 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. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on(thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end&thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 10-3/4" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 10-3/4" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 10-3/4" 10,750 ft-lbs Page 16 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrorl,:11aska.li t Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size 12 Wall 0 Grade—0 Connection —0 Unit IMP Pipe Body Data GEOMETRY • Nominal OD 10.750 in Wall Thickness 0.400 in API Drift Diameter 9.794 in Nominal Weight 45.50 Ibslft Nominal ID 9.950 in Alternate Drift Diameter 9.875 in Plain End Weight 44.26 Ibsfft Nominal Cross Section 13.006 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi r-- i- Body Yield Strength 1,04.0,000 lbs Internal Yield Pressure 5,210 psi Collapse Pressure 2,470 psi H i. Connection Data GEOMETRY Regular OD 11.750 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Joint Strength 1,063,000 lbs Internal Pressure 5,210 psi Resistance Tenarisril Premium Connections { Print Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the / hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 17 Revision 0 October,2016 • 14KBU 32-06 Drilling Procedure Hilwrp tia4a.Id.1: 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 18 Revision 0 October, 2016 KBU 32-06 Drilling Procedure Hileorp:11arcka,li t 13.0 Cement 10-3/4" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface,regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 13.2 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.3 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.4 Pump remaining 35 bbls 10 ppg spacer. 13.5 Drop bottom plug. Mix and pump cmt per below recipe. 13.6 Cement volume based on annular volume+ 50% open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: - Section: Calculation: Vol (BBLS) Vol (ft3) LEAD: 120' x .106 bpf= 12.7 71 16" Conductor x 10-3/4" casing annulus: LEAD: (1000' — 120')x .065 bpf x 1.5 = 85.8 482 13-1/2" OH x 10-3/4" Casing annulus: Total LEAD: 98.5 553 -z1-05'nTAIL: (1500'-1000')x .065 bpf x 1.5 = 48.8 274 13-1/2" OH x 10-3/4" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 10-3/4" Shoe track: Total TAIL: 57.5 322.8 2t`1 s>z c) Page 19 Revision 0 October,2016 • • 14 KBU 32-06 Drilling Procedure Hileorp:1laska,LU: -__` Cement Slurry Design: Lead Slurry (1000' MD to surface) Tail Slurry (1500'to 1000' MD) System Blend Conventional Density 12 lb/gal 15.2 lb/gal Yield 2.44ft3/sk '� 1.26 ft3/sk Mixed Water 14.437 gal/sk 5.76 gal/sk Mixed Fluid 14.417 gal/sk 5.76 gal/sk Expected 5 HR 3 HR Thickening Code Description Concentration Code Description Concentration D901 Cement 94 lb/sk D901 Cement 94 lb/sk D046 Antifoam 0.2%BWOC D046 Antifoam 0.2%BWOC D020 Extender 2.6% BWOC D065 Dispersant 0.4% BWOC Additives D079 Extender 2% BWOC D167 Fluid Loss 0.2% BWOC D110 Retarder 0.02 gal/sk cmt S002 Accelerator 0.25% BWOC 13.7 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.8 After pumping cement, drop top plug and displace cement with mud. 13.9 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. Be lined up to displace with rig pumps as well, in the event there is an issue during the displacement with the rig pumps. 13.10 Displacement calculation: 1411' x .0962 bpf= 135.7 bbls V' 13.11 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.12 Do not over displace by more than 1/2 shoe track volume. Total volume in shoe track is 8.7 bbls. Page 20 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hileorp:Uaska,IJ,( 13.13 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 6— 18 hours after CIP. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. 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 Send final "As-Run" casing tally & casing and cement report to mmyers(ahilcorp.com & cdinger@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 21 Revision 0 October, 2016 • • 14KBU 32-06 Drilling Procedure Hilrorli:Alaska. 14.0 BOP N/U and Test 14.1 N/D the conductor riser. 14.2 N/U Seaboard multibowl wellhead assy. Install packoff 10-3/4"P-seals. Test to 3000 psi. 14.3 N/U 11" x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M Townsend annular BOP/11"x 5M Townsend double ram/11"x 5M mud cross/11"x 5M Townsend single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs q_de • N/U bell nipple, install flowline. �' • Install (1) manual valves& (1) HCR 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. 14.4 Run 4-1/2"BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/10 min. Test annular to 250/2500 psi for 5/10 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9 ppg 6% KCl drilling fluid for 9-7/8"hole section. 14.8 Set 10" ID wear bushing in wellhead. 14.9 Ensure mud loggers are R/U for the intermediate hole section. 14.10 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. 14.11 Install 5" liners in mud pumps. • TSM 1000 mud pumps are rated at 4250 psi (85%)/275 gpm (100%)with 5" liners. Page 22 Revision 0 October, 2016 O . KBU 32-06 Drilling Procedure Hilrorp;tla.ka.LL1 15.0 Drill 9-7/8" Hole Section 15.1 Prior to P/U 9-7/8" directional BHA-test casing against blind rams to 2600 psi/30 min. 15.2 P/U below 9-7/8" directional drilling assembly. COMPONENT DATA Item , . I OD ID Gauge Weight Top Length Cumulative Desert' ini�' tr (in) (in) (in) 4Ibpf) Connection 180 Length (1l) - HOBS 11465 POC 811 6.000 2.500 9.875 79.63 P 4-112'REG 0.90 0.90 © 7'SperryDril Lobe 718.6.0 sig 7.000 4.952 93.13 B 4.172'IF 27.00 27.90 3tedlmer -__ 9.625 ---- © 6 374'Non Mag Float Sub 6.500 2.875 90.96 B 4-172'IF 2.45 30.35 - 6 3/4'Inlegrel Blade 9 578'gauge 6.770 2 875 EMI 10056 8 4.173'IF 700 37.35 - 6 3.14"DM Ciller 111111111111111 6.690 3.125 Mill 103 40 III= 925 46.60 - 6 314"EWR=P4 Collar • 6.720 2.000 ® 104.30 8 4.172`IF 14.00 60.60 - 6 314"DGR Collar . 6.760 1 920 - 97.80 P 4-172`IF 8 40 69 00 1131 Inline Stabilizer(ILS( 6.750 3.125 9.750 95.82 B 4-1171F 3.50 72.50 - 6 374'PWD Collar 6.730 1.905 96.30 8 4.172'IF 5 00 77 50 10 6 374'HCIM Cedar 6.840 1.920 101,70 B 4-172'IF 7.00 84.50 - 8 3.'4'TM Collar 6.890 3.250 103 60 8 4.172'IF 980 94.30 ® 6-374"Non Meg Flax Collar 6.750 2.810 _ 100.82 8 4-172'IF 31.00 125.30 ® 6-3'4"NW May Flex Collar 6.750 2.810 - 100.82 B 4-172'IF 31.00 156.30 MI 6-3.W"Non Mag Flex Collar 6.750 2 810 10082 8 4-1O'IF 30,00 186 30 ® 6-314"Non Mag Flex Collar 6.750 2.810 100.82 B 4-172'IF 30.00 216.30 16 X.O 4.117 IF P X CDS•40 5 6.520 2.750 93.54 B 4.5"CDS 40 2.75 219.06 ® 6 Joints 4-112' HWOH CDS-40 4.500 2 687 3686 186.00 404 05 - X-0 CDS•40 P X 4 VT IF B 6.520 2.750 93.54 B 4.172'IF 175 406.80 19 6-114"Weatherford Hyd Jar 6250 2 250 91.01 8 4-112'IF 32.31 439 11 20 X-0 4-112"IF P X CDS-4013 6.520 2.750 - 93.54 B 4.5'COS-40 2.75 ® 13 Joints 4.112'HWDP COS.40 4.500 2.687 38.86 400.00 84186 tBoc 1341.86 Bit Number Menke :6x13 Bit Site (MI : 9.875 ?FA BM) :0.7777 Manufacturer : 14885 Dull Graefe In :NEW Model : 1,4.465 Dull Grade Out Serial Number . 15.3 Ensure BHA components have been inspected previously. 15.4 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.5 Bit TFA should be-0.75 -0.80 in2. We need to pump at -450 - 500 gpm to clean the hole effectively. Have the directional driller run hydraulics calculations to confirm optimum TFA. / Page 23 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrorp.Alaska,Li t 15.6 Primary bit will be the Security 9-7/8" MM65. 9-7/8" (251mm) MM65 PRODUCT SPECIFICATIONS Cutter Type SeleetCutter > IADC Code M323 Body Type MATRIX rr Total Cutter Count Cutter Distribution .LIgual j(= *' Face (I 214 , Gauge 12 0 s t Lip Drill 6 0 Number of Large Nozzles t, t Number of Medium Nozzles fI ter Number of Small Norrles 41 Rh. Number of Micro Nozzles 0 • y Number of Pons(Size) 0 e Number of Replaceable Ports(Sire) 0 Junk Slot Area torr in) 16.71 0k- Nomtahred Face Volume 45.49% API Connection 4-la REG.PIN Recommended Make-Up Torque' 12,461-17,766 Ft'lbs. Nominal Dimensions** Make-Up Face to Nose 10.81 in-275 non Gauge Length 2.5 in 64 torn Sleeve Length 0 in-0 men Shank Diameter 6 in-(52 tom Break Out Plate(Mat.k,Lcgacylt) 11119541340411 Approximate Shipping Weight 2S0Lbs.-113Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads.1±16-Relieved Gage Material#771827 .Bit specific recommended makeup torque is a function of the bit 1111.and actual bit sub O.D.milirai as specified in API RP?G Sectson.A.&2. "Dow dimensions arc nominal and may vary slightly cm manufactured product.IIaltihwtin thrid flits and Servisw models are nommwwaly rrsuewcd and refined. Product specifications may change without notice. C 2013 Halliburton.All rights reserved.Saks of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburtan.com Page 24 Revision 0 October, 2016 • DrillingKBU Proce32-06dure II Hitraria Alaska,1JA 15.7 9-7/8"hole section hydraulic summary: Security DBS BIT HYDRAULIC PROGRAM 0 Prepared For-tlecorp KSU 324E By•Mark erouSOel Odle prepared-115714 Operator. HIIeOrp Web Name*,-NW 3245 6.1 Type- PDC ConlraNar:-- County.-Kent Bit Diameter.- 9.875 m Surwy_rAbsnaot:-x S1a8s1Counby-ANOXIA MO Out;- 64008 Mud W119h0 6.5 PHI COMPONENTS ID(In.) To(n) 1 13 PV 22 to Casing 9,951 1500 2 13 VP 25Ibf100te Open Hole 9.5751 5400 3 13 Fluid Madel -,o-Ns- Aa:cr Basad Fuc- j 4 13 Plow Hate 500 gpm 5 5 13 Max.Pump Poses. 400_9410 6 13 Surface equip.?i i 7 Motor bypass? a 1 TVD" 545511 ¢ 9 N of Nimes(..10):. ..Mruar ri+tUlatxn 10.. _... Min.TFA 0.3634 Inn Drell String 1288.30 psi 47.62% Total TFA in' Annulus TB 10 psi 2.89% Jet Velocity 206.37 his Surface 77 46 psi 2.88% Press.Drop 961.02 per Speciel' 900.00 psi 93.27% an Hyd.Power 105.49 hp OH 361.x,:.psi 13.37% H.S. hlkinr Impact Force 507.37 141 ECO 9.78 ppg Tots/SPP, 2765.48 psi 100.00% OD ID Tool Joint , Length Cap. Pressure Loss DRILL STRING COMPONENTS an in 00t°1 n bbls psi Drill Pipe(S)(CDS 40 Corrections 4.6 3.626 6.376 3.5 5550 78.65 593.35 MYDP(CDS 40 connections.13 Jte) 4.5 2.68 6.26 255'': 403 2.60 199.60 Weethatord Hyd Jet(COS 401 8 2.25 0 215 91 0.15 32.50 HWOP(CDS 40 connections,8 AM 4.5 2.65 6.25 250 106 1.29 92.12 R-0 Sob(CDS 40 Sox 114-H2"IF Pin) 6,5 2.75 8.5 2.75 4 0.03 I 76 4 Joints 6J14"NM nes OHM Collars 6.75 2.613 6.75 2.813 126 092 47.85 Integral Slad.Stablkzer(9.76'Gauge) 6.75 2.76 6.78 275 5 0.04 2.20 MWDTM HOC(P14ser) 6.75 '•"`•••"" 6.75 ""••"'••'i 18 450.00 MWD HCIM Collar 0.75 1.42 6.75 1.42i 5 0.01 36.46 MWD-PWD Collar 6.75 1.42 6.75 142f 5 0,01 38,46 MWD EWRP4rGamma Colter 6.75 1.42 6.75 1.421 22 0.04 169.24 MWD Directional Collar 6.76 1.42 6.78 1.42¢/ 9 0.02 09.23 Integral 8ladeStablkzer(9.75"Gauge) 6.75 2.76 8.75 2.795 5 0.04 2.20 Float Sub 6.75 2.75 6.75 2.751 3 0.02 1.32 7 SperryCrMl Lobo 703-6.0&g. T """-""' 7 ^"'^"^') 25 450.00 ANNUUIR. Hole 10 Pipe 04 Length Cum_ Cap. Annular Critical Type of Pressure Loss SECTIONB in., in. ft Depth .,._, 664s 1Mmin fifmin Flow pa+. Casinos 9.95 4.51 1500 1500 114.75 166-61 309.43 L 16.62 Open Hole 9.515 4.5 4056 5666 304.59 968.61 305.05 L 46.43 Open Hole 9.575' 4.5 403 5961 30.25 166.61 305.05 L 4.61 Open Hole 9.875 6.25 31 5992 1.76 2119-66 354.73 L 0.77 Open Hole 9.875. 4.5 786 6178 13.96 158.61 305.05 L 2.13 Open Hole 9.515. 0 5 4 6t82� 0.21 121.76 364 56 L 0.11 Open Hole 9.575 675 110 6307 6.06 235.69 375 49 L 4.00 Open Hole 9.875 6.75 5 6307 0-25 23559 375 49 L 0.7 1 Open Hole 9.875 6 75 16 6303 0.81 235.69` 375 49 L 0.53 Open Hole 9.875'.' 6 75 5 6328 0.25 235.89E 375 49 L 0.17 Open Hole 9.875 675 5 6333 025 23589 37549 L 0.17 Open Hole 9.875 6.75. 22 6355 1.11 235.59 37519 L 073 Open Hole 9.875 6.75 9 6364 0.45 235.59 375.49 L 0.30 Open Hole 5.675 6.75 5 6369 0.25 235.69 375.49 L 0 17 Open Hole SSTI 6.75 1 6372 0.15 23549 375.49 L 0.10 Open Hole CM 7 26 6400 1.32 252.60 367.67 L 1,70 Page 25 Revision 0 October, 2016 • S KBU 32-06 Drilling Procedure Hilrnrp.u..k i.LLf. 15.8 9-7/8"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1) ppg above highest anticipated MW. Pason 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—9.5 ppg 6%KCUPHPA fresh water based drilling fluid. Properties: ud Plastic MD eight 1")ViscositY Viscosity Yield Point pH HPHT 1,500'- 6,600' .0—9.5, 40-53 15-25 15-25 8.5-9.5 < 11.0 System Formulation: 6% KCL/PHPA Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-499 4 ppb EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 5—10 ppb(3.3 ppb of each) BAROTROL PLUS 2—4 ppb SOLTEX 2—4 ppb BAROID 41 as required for a 9.0—9.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) Page 26 Revision 0 October, 2016 S • KBU 32-06 Drilling Procedure [Iilrorp Aln.kn,LLf. 15.9 Close blinds and test 10-3/4 casing to 2500 psi. 15.10 PU BHA and TIH, Conduct shallow hole test of MWD and confirm Gamma Ray LWD functioning properly. 15.11 Continue in hole and tag TOC. Note depth tagged on AM report. 15.12 Drill out plugs and shoe track. Clean out rat hole and drill an additional 20' of new formation. 15.13 CBU and condition mud for FIT. 15.14 Conduct FIT to 12.5 ppg EMW. 15.15 Drill 9-7/8"hole section to 6,600' MD/5,904' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 gpm. Ensure shaker screens are set up to handle this flowrate. • 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. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Shales in the Beluga formations are notorious for swelling and causing tight hole. Most of the time, backreaming them on a short trip is the only solution. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss< 11. • Take MWD surveys every other stand drilled. Surveys can be taken more frequently if deemed necessary. • Ensure to pre-treat the active system with 10 ppg Calcium carbonate. Have additional fibrous and other bridging material on location in the event lost returns are encountered. There are many stacked sands that are severely depleted that will be penetrated in the 9-7/8" hole section. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4" shoe. 15.17 TOH with the drilling assy, handle BHA as appropriate. Page 27 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Nikorp:%Ias:k..LLC 15.9 TIH, Conduct shallow hole test of MWD and confirm Gamma Ray LWD ' ctioningi1properly. 15.10 Continue in hole and tag TOC. Note depth tagged on AM report. 6,4).410 t' �rtis � (� €:3 4, � 15.11 Drill out plugs and shoe track. Clean out rat hole and drill an •ditional 20' of new formation. 15.12 CBU and condition mud for FIT. ( / z �--- \ SgoY 15.13 Conduct FIT t pp EMW. I .s 54( . i< 15.14 Drill 9-7/8"hole section to 6,600' MD/ 5,904' ' D. 3 7,4 f 72 • Pump sweeps and maintain mud rheology o ensure effective hole cleaning. • Pump at 500 gpm. Ensure shaker screes are set up to handle this flowrate. • Utilize inlet experience to drill throw , coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try • avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressure ow when tripping. • Make wiper trips every 500' 4r every couple days unless hole conditions dictate otherwise. If tight hole is encountere. screw in and begin backreaming connections until hole conditions improve. Sh. -s in the Beluga formations are notorious for swelling and causing tight hole. Most of the ime, backreaming them on a short trip is the only solution. • Ensure shale shakers . e functioning properly. Check for holes in screens on connections. • Adjust MW as nee,ssary to maintain hole stability. Keep HTHP fluid loss < 11. • Take MWD surv'ys every other stand drilled. Surveys can be taken more frequently if , deemed necess.ry. • Ensure to pr- treat the active system with 10 ppg Calcium carbonate. Have additional fibrous an. other bridging material on location in the event lost returns are encountered. There ar- any stacked sands that are severely depleted that will be penetrated in the 9-7/8" hole se• ion. 15.15 At TD pump sweeps, CBU, and pull a wiper trip back to the 10-3/4" shoe. 15.16 TO ' with the drilling assy, handle BHA as appropriate. 8161F3E.RCEDEL Page 27 Revision 0 October, 2016 • KBU 32-06 Drilling Procedure H i leor1 :11a.ka. 16.0 Run 7-5/8" Intermediate Casing 3 S,- ` 16.1 R/U and pull 10" ID wear bushing. Install and test 7-5/8" casing ram in top ram cavity. Test to 250/3500 psi. 16.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8" BTC x CDS-40 XO on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck 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. 16.3 P/U 7-5/8" 29.7# L-80 BTC shoe joint, visually verify no debris inside joint. 16.4 Continue M/U &thread locking the shoe track assy consisting of: • (1) Float shoe joint w/float shoe bucked on. Install (2) bow spring centralizers at 10' from each end over a stop collar. • (1) Baker locked joint. Install (1) centralizer mid tube over a stop collar. • (1) Float collar joint w/float collar bucked on pin end. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float shoe and float collar. 16.5 Run 7-5/8" 29.7# L-80 BTC casing. • 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. • Install centralizers over couplings on every other joint to 1550' MD. 16.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.7 Slow in and out of slips. 16.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approximately 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. yr` Page 28 Revision 0 October, 2016 • KBU 32-06 Drilling Procedure HiIcorp Alaska,LLC Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY Outside Diameter 7.625 in Wall Thickness 0.375 in API Drift Diameter 6.750 in Nominal Weight 29.70 lbs/ft Nominal ID 6.875 in Alternative Drift Diameter n.a. Plain End Weight 29.06 lbs/ft Nominal cross section 8.541 in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Tension Yield 683,000 in Internal Pressure Yield 6,890 psi Collapse Pressure 4,790 psi Available Seamless Yes Available Welded No CONNECTION DATA TYPE:BTC GEOMETRY Coupling Reg OD 8.500 in Threads per in 5 Thread turns make up 1 PERFORMANCE Steel Grade L80 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 6,890 psi 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 7,630 ft-lbs 16.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat(slightly)to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.11 Continue circulating until required properties achieved for cmt operations. 16.12 After circulating, lower string and land hanger in wellhead again. Page 29 Revision 0 October, 2016 I • KBU 32-06 Drilling Procedure Hilcorp:tlaska.LLC 17.0 Cement 7-5/8" Cement Procedure 17.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. • Pump minimum of 15 bbls thru SLB lines to clear any debris • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2 R/U cmt head (if not already done so). Ensure top and bottom plugs are loaded correctly. 17.3 Pump 5 bbls 10 ppg spacer. Close low torque valve on plug dropping head, test surface cmt lines to 4000 psi. 17.4 Pump remaining 35 bbls 10 ppg spacer and drop bottom plug. 17.5 Mix and pump slurry per below calculations: iC( i. Section: Calculation: Vol(BBLS) Vol(ft3) LEAD: (6,100'- 3'000') x .038 bpf x 1.25 = 147 825 9-7/8" OH x 7-5/8" csg: Total Lead: 147 bbls 825 ft3 `> '` TAIL: 500' x .038 bpf x 1.25 = 24 135 9-7/8" OH x 7-5/8" csg: TAIL: 7-5/8" Shoe Track: 90' x .046 bpf= 4.1 23 Total Tail: 28.1 bbls 158 ft3 /ZS S A Page 30 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrorp,11a,ka, Slurry Information Lead Tail System LiteCRETE Conventional Density 11 lb/gal 15.2 lb/gal Yield 1.92 ft3/sk 1.26 ft3/sk Mixed Water 6.794 gal/sk 5.76 gal/sk Mixed Fluid 6.834 gal/sk 5.76 gal/sk Expected 5:02 HR:MIN 3 HR Thickening Code Description Concentration Code Description Concentration D-046 Antifoam 0.2% BWOB D901 Cement 94 lb/sk D-065 Dispersant 0.35% BWOB D046 Bonding Agent 10% BWOC Additives D167 Fluid Loss 0.25% BWOB D065 Anti-Static 0.005 lbs/sk D177 Retarder 0.04%gal/sk D167 Anti Foam 1 gal/100 sks S002 Retarder 0.4%BWOC 17.7 After pumping cement, drop flexible shut-off plug and displace cement with mud. Use the cement unit to displace with as volumes can be tracked much more accurately. Displacement calcs: • 6,520' x .0459 bpf= 300 bbls. o • Displace with 10 ppg 6% KC1 drilling fluid out of mud pits. 17.8 Monitor returns closely while displacing cement. Adjust pump rate if necessary. 17.9 Do not over displace by more than 1/2 shoe track volume. Total volume in shoe track is 4.1 bbls 17.10 There should be no cmt returns to surface. TOC is planned to be at 3000' MD. 17.11 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Page 31 Revision 0 October, 2016 S KBU 32-06 Drilling Procedure Hilror!,Alaaka.LLC 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 Send final "As-Run" casing tally & casing and cement report to mmyers@hikorp.com com & cdinger@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 17.1 R/D cement equipment. Flush out wellhead with FW. 17.2 Back out and L/D landing joint, flush out wellhead with FW. 17.3 M/U pack-off running tool and pack-off to bottom of landing joint. Set casing hanger pack-off. Run in lock downs and inject plastic packing element. Test void to 250/3000 psi for 10 min. 17.4 Lay down landing joint and pack-off running tool. 17.5 Run CBL on 7-5/8" casing prior to drilling out float equipment. And minimum of 24 hours after cement is in place. Page 32 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure HiIcorp 18.0 Drill 6-3/4" Hole Section 18.1 Remove 7-5/8" casing rams from BOP. Install 2-7/8" x 5" VBRs in top cavity. BOP configuration should be (from top down): Annular/VBR/Blind/Mud cross/VBR. 18.2 Test BOPs on 4-1/2"test joint. 18.3 R/U Mud loggers for the 6-3/4"production hole section. They need to be set up to generate mud log, pixler plots, and collect(3) sets of samples every 20 ft. 18.4 Pull test plug, run and set wear bushing. 18.5 Ensure BHA Components have been inspected previously. Rack enough 4-1/2" DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 18.6 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 18.7 Ensure TF offset is measured accurately and entered correctly into the MWD software. 18.8 Confirm that the bit is dressed with a TFA of 0.46 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 270 gpm. Page 33 Revision 0 October, 2016 • 0 KBU 32-06 Drilling Procedure Hilrnri,Alasha.LLC 18.9 P/U below 6-3/4" directional drilling assy: COMPONENT DATA 111111.11111=1110r1.1111.111.1111101k 111.1.111111 Item ,,,.�"s. otl'iir 'di i�ig Top. �n.: umutative Description eriai Num Conneotro-n {in) tin) (in) (IdpQ (ft) ngth {ft) Mall HDBS EM65D POC bit 4.500 1.563 6.750 47 67 GIMEM 0.75 0.75 ® 5'SPerryDrill Lobe 617-8-0 e*g 5.000 3.120 48.00 B 3-'ii2"IF 24.00 24.75 Ell Stabilizer 6.5511 ® Float Sub MIEN 4.750 2.25{) MU= it 3-1,2"II- 2.25 111.21311111 ME Welded Blade Sl.ebilite- 4 840 2.000 6.500 52 00 B 3-1/2"IF 5 00 32.04 ® 4 3:4'DM Collar 4.730 1.250 47 00 B 3-1'2"IF a 20 4120 ® 4 314'Slim Phase 4 Colla- 4.750 1.250 48 20 8 3-1i2"IF 24.50 65.70 Inline Stabilizer IILSi 4.740 1.920 6.000 51.1 27 S 3-1i2"IF :3 50 69.20 1131111111111111111131=1111111111- 4.750 1.250 5.625 45 sn 13 3.1/7"IF 1490 83.20 _ Stadxi:crtr -__ 5675 _--- ® 4 3;4'CTN Collar - 4.750 1.250 50 50 3 3-1.2"IF 11.00 94.20 10 43,.4"PWD 4.750 1.250 47 90 13 3-1.2"IF 9.20 103.40 ® 4:3+4'TM HOC lPulaeri ' 4.760 1.250 40 90 El 3-1!2"IF 11.00 114 40 ® 4 3.'4'HAT'Collar - IIIIIIIIII 4 750 1.251) 45 711 8 NC 38 213 42 140 tit ® 4 75' FIFO Collar 4 750 2.253 46 04 B 34/2"IF 31 00 171 62 MI 4 75"Flex Collar 4.750 2.250 46 84 8 3-1i2"IF 31.00 202 82 IBM 3-1,2'IF Pin X 4-1'2'CDS 40 Box 5.250 2.253 G0.22 B 4.5'CJS-40 2.75 205.67 M 6 Joints 4-112'HWDP 4.600 2.750 41 00 185.00 390.57 ® x 0 4 112'COS-40 Pm X:i 1.2'If hos 5 too 2,250 51 h4 B 3-1/2"IF 2 75 :193:37 18 4 304"Weatherford HO Jar - 4 750 2.250 41 64 3000 ® N-O 3-1,'2"IF Fire X 4-112"CDS-40 Box'- 5.300 2.750 54 94 B 4.5'CDS-40 2 75 420 07 20 13 Joints 4-1"2'1-1W DP 4.600 2.750 41 00 400.00 826.07 rokt 826.07 BIT DATA Bit Number Nozzles : 6x10 Bit Size {in) : 6.7'x3 TFA (In21 . 0.4602 Manufacturer : H[)fi:, Dull Grade In Model : i LIEF fl Dull Grade Out Serial Number . Page 34 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilcurp Alaska,LLC 18.10 Hydraulics Summary: Security DBS BIT HYDRAULIC PROGRAM Prepared For-Hilcorp KBU 3248 By-Mark Broultst Dale prepared:-119114 Operate:-lMleorp € Welt Naroe:No-10311 32-06 Bit Type:- PDC Contractor:- County.-Kenai BitDiemeler:- 6.75 in SurveylAbabracL- 1..__TState Country:-MUSA MD Out:- 6350 ft Mud Weight 10.5 ppg COMPONEMTS ID(In.), To III) 1 10 PV' 13 cp paling 6.675= 0400 2 10 YP- 19 161100112 Open Hole 6,75::: 9354 3 10 Fluid Model ;Ow We't eJ 4 10 Flow Rate 275 gpm 5 10 Max.Pump prom, 4000 psi 6 10 Surface equip.?: 7 Motor bypass'? a TVD 765311 9 Al o1 Nozzle(,;101 a 'la,.n r n ,.u.:, 10 Min.TFA 0.1974 in' Drill String 873.90 psi 35.40% Total TFA -'in Annulus 369 97 psi 14.99% Jet Velocity 191.62 his Surface 29.19 psi 1.18% Press.Drop 345.31 psi Special' 850.00 psi 34.44% Bit Hyd.Power 55.40 hp Iii .i., psi 13.99% H.S.1. , 4467 hpAn' Impact Force 286.69 Ib1 ECD 11.41 ppg TotatiSPP 2468.37 pal 100.00% OD ID Tool Jaid Length Cap. Pressure Loss DRILL STRING COMPONENTS In to. co ID11 bola Psi Drill Pipe(S)(CDS 40 Camec/kons 4.5 3.826 8.373 3.5' 8517.5 120.53 319.99 IIWOP(CDS 40 connectlons,13 Jts) 4.6 2-68 6162651 403 2.69 68.41 4-Sl4-Weatherford Hyd Jar wt X-0'6 3 2.26 5 225' 35 0.17 12.43 HWDP(CDS 40 connections,6 Jt$ 4.5 2.68 6.25 2.55 188 1.29 31.60 X-0 Sub[CDB 40 Dox X 3-172"IF Pln) 4,7 2.5 S 2,3 4 0,02 0 92 2 Joints NM Flax DMI Collars 4,75 2.3 4.76 2.5 60 0.39 13.61 M WD I Bat Sonic 4.75 1.26 4.75 1.25![ 26 0.04 112.32 MWD ITM HOC(Pulsar) 4.75 ^•'•...•'•" 4..75 '......."`" 11 400.00 MWDIPM. 4.75 1.25 4.75 1.251: 9 0.01 39.05 MWDJAW-CID[tiukes' 1.75 1,25 4.75 1.25 25 0,04 101.43 Inane Stabilizer(ILS 0"Gauge) 4.73 1.25 4.75 1.25` 3,5 0.01 15.19 MWDI Dlnctional4Slim Phase 4 4.76 1.26 4.75 1.25 34 0.05 147.54 NM String SNtbillzer(8.826Gauge) 4.75 2 4.75 2` 5.5 0.02 3.23 Float Sub 4.75 2.5 4.75 2,5"' 2,5 0.02 0.57 5'SperryOr ll Lobe 647-6.0 slg(W(A81) S """' S •""".• 28 45000 ANNULAR Hole ID', Pipe OD Length Cum" Cap. Annular Cate& Type o1 Preseurs L04s SECTIONS in. in. ft Depth _ bbla film in, (Yroin Flow Pei Casing 6.875 4.5 6400 6400 167.96 249.49 310.59 L 242.12 Open Hole 6.75 4.5 2117.6 8517.5 52.07 266.28 316.12 L 89.88 Open Hole 6.75' 4.5 403 8920.5 9.91 266.28 316.12 L 17.07 Open Hole 6.75 4.7 36 8956.5 0.80 281.16 325.86 L 1.77 Open Hale 5.76 4.5 186 9141.6 4.57 266.28 318.12 L 7.66 Open Hole 6.75 4.7 4 9115.5 0.09 287.10 325.86 L 0.20 Open Hole 6.75. 4.75 60 9705.5 1.34 293.05 328.50 L 3.18 Open Hole 6.75 4.75 26 9231.5 0.58 293.05 328 50 L 1.38 Open Hole 6,75 4,75' 11 9242.5 0.25 293 05 378 50 1. 0.58 Open Hole 6.75 4.75 9 9251.5 0 20 293 05 328 50 L 0.48 Open Hole 6.75 4.75 25 9276.5 0.56 293 05 328.50 L 1.32 Open Hole 6.75 4.75 3.5 9280 0.08 293 05 328.50 L 0 19 Open Hole 6.75. 4.75 34 9314 0.76 293.05 328.50 L 1 80 Open Hole 6.75 4.75 5.5 9319.5 0.12 293.05 328.50 L D 29 Open Hole 8.75'. 4.75 2.6 9322 0.06 293.05 328.50 L 0 1 Open Hole 6.75 5 26 9350 0.56 327.79 343.12 L 1.91 Page 35 Revision 0 October, 2016 • KBU 32-06 Drilling Procedure Hilrorp AIa.J 18.11 Primary bit will be the Security EM65D. 6-3/4" (171t„m) EM65D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling Oath IARC Code M323 Body Type MATRIX Total('utter Count 33it ... Cutter Distribution 11 1LmuI 4 Face 4 13 Gauge II 0 4 Up Chill 5 0 Number of Large Nozzles 0 Number of Medium Nozzles 0 +� Number of Small Nozzles 6 Number of Micro Nozzles * 0 Number of Poem(Size) 0 Number of Replaceable Ports(Size) 0 Junk Slot Area i sq in) 8.68 Normalized Face'Volume 34.69% API Connection 3-1/2 REG.PIN Reacrnunendtvl Make-Up Torque 5.173-7,665 Wit's,. Nominal Dimensions** Make-Up Face to Nose 9.42 in-239 mat Gauge Length 2 in-51 nen Sleeve Length 0 in-0 min Shank Diameter 4S in-114 men Break Out Plate IMat.4/Legacy t) 1119531440311 Approximate Shipping Weight 90Lbs.-41 Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads.1+16"Stepped Gage,Optimized Dual Raw-"D"Feature Material#761302 'Bit specific recommended makc-up torque is a I'um lion ut the bit I.D.and actual hit u&.0.D.utilired as specified in API RP7D Section A.g.2. **i}isgn hintentaona are nomina and tray vary slightly on manufactured preduq.Haliihwton Drill Ftitx and Sen•iccs models arc conunuotrcly reviewed and refined. Product ep,<elhcatiass may chanee+without nonce. IC 2013 Halliburton.All rights reserved_Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.haliiburtorr corn Page 36 Revision 0 October,2016 F,J • • 14KBU 32-06 Drilling Procedure Hdeorp Ala kx,I.Lf. 18.12 TIH to TOC. Shallow test MWD on trip in. Note depth TOC tagged at on AM report. 18.13 Conduct casing test to 3500 psi/30 min. 18.14 Drill out shoe track and additional 20' new formation. CBU and prep for FIT. 18.15 Perform FIT to 12.5 ppg equivalent. 18.16 Drill 6-3/4"hole to 10,487' MD/9,665' TVD • 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 adequate LCM is available on location in the event returns are lost. • 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 HTI-IP fluid loss. • Maintain HTI-IP fluid loss < 10. • Take MWD surveys every other stand drilled. • Pull wiper trips every 500— 1000 ft drilled. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Page 37 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrnrl'Alaska,LLf. 18.12 TIH to TOC. Shallo' test MWD on trip in. Note depth TOC tagged at on report. - 1 18.13 Conduct casing test to 3,00 psi/30 min. `'S .% . cs?- 1 I re ' 18.14 Drill out shoe track and ads'tional 20' new formation. CBU an. .rep for FIT. 18.15 Drill 6-3/4"hole to 10,487' M I /9,665' TVD • Pump sweeps and maintain d rheology to ensure e ective hole cleaning. • Utilize Inlet experience to drill•hrough coal seam -fficiently. Coal seam log will be provided by Hilcorp Geo team, to avoid slid' g through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures lo when t '.ping. • See attached mud program for hole . ea ' g and LCM strategies. Ensure adequate LCM is available on location in the event retu,. are lost. • Ensure solids control equipment fun. is ing properly and utilized to keep LGS to a minimum without excessive diluti. . • Adjust MW as necessary to mai. ain hole ability. • Ensure mud engineer set up to serform HT ' fluid loss. • Maintain HTHP fluid loss 0. • Take MWD surveys every ether stand drilled. - • Pull wiper trips every 51 1 — 1000 ft drilled. If tig' hole is encountered, screw in and begin backreaming connecti. s until hole conditions impr,ve. Page 37 Revision 0 October, 2016 • 14KBU 32-06 Drilling Procedure Hilror1,Alaska,LLC 18.16 6-3/4"hole section mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. Pason 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: 10— 11.5 ppg 6% KC1/PHPA fresh water based drilling fluid. • Properties: MD ( 1dht \Viscosity aic yield Point pH HPHT Viscosity 6,600'- 10,487'\\ 10-11.5 ppg� ;` 40-53 15-25 15-25 8.5-9.5 < 10.0 System Formulation: 6% KCL/PHPA Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-499 4 ppb EZ MUD DP 0.75 ppb DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 15-20 ppb(5 ppb of each) BAROID 41 as required for a 10.0—11.0 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 18.17 Hilcorp Geologists will follow LWD log closely to determine exact TD. 18.18 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 18.19 TOH with drilling assy and handle BHA as appropriate. Page 38 Revision 0 October, 2016 • I KBU 32-06 Drilling Procedure HiIrorp Alaska.l,Ll 19.0 Run 4-1/2" Production Long String 19.1 R/U Weatherford 4-1/2" casing running equipment. • Ensure 4-1/2"DWC/C HT x 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 on the deck prior to running. • Be sure to count the total # of joints on the deck 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. 19.2 P/U shoe joint, visually verify no debris inside joint. 19.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on&threadlocked (coupling also thread locked). • (1) Joint with float collar bucked on pin end &threadlocked(coupling also thread locked). • (1) Joint with landing collar installed INSIDE pin end. • Solid body centralizers will be pre-installed on shoe joint& FC joint. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe. 19.4 Continue running 4-1/2" prod casing. • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 6,700' MD. Leave the centralizers free floating. • Ensure to install swell packer joint so that it is 500' inside the 7-5/8" shoe when landed out. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 4-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5,800 ft-lbs 6,500 ft-lbs 7,200 ft-lbs Page 39 Revision 0 October, 2016 i . KBU 32-06 Drilling Procedure Hilrnrp Alaska,LLC Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Tubing 4-1/2 in 12.60 lb/ft (0.271 in) L-80 standard Material L-80 Grade 80.000 Minimum Yield Strength (psi) 11111111111111111111WUSA 95,000 Minimum Ultimate Strength (psi) VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Pipe Dimensions Houston,TX 77041ne: ' 4.500 Nominal Pipe Body 0.D. (in) Fax713.479-323400 3.958 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesi vamaisa.com 0.271 Nominal Wall Thickness (in) 12.60 Nominal Weight (lbs/ft) 12.25 Plain End Weight(lbs/ft) 3.600 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties ME 288,000 Minimum Pipe Body Yield Strength (lbs) a, 7,500 Minimum Collapse Pressure (psi) 8,430 Minimum Internal Yield Pressure (psi) 7,700 Hydrostatic Test Pressure (psi) Connection Dimensions 5.000 Connection 0.D. (in) 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter (in) 3.94 Make-up Loss (in) 3.600 Critical Area (sq in) 100.0 Joint Efficiency (%) Connection Performance Properties 288,000 Joint Strength (lbs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (lbs) 288,000 Compression Rating (lbs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] '' Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-lbs) 6,500 Maximum Final Torque (ft-lbs) 7,200 Connection Yield Torque (ft-lbs) Page 40 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hileorp AIn Aa.l,l.l: 19.5 M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approximately 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 19.6 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 19.7 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat (slightly)to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 19.8 After circulating, lower string and land hanger in wellhead again. Page 41 Revision 0 October,2016 • ! KBU 32-06 Drilling Procedure 20.0 Cement 4-1/2" Production Long String 20.1 Hold a pre job safety meeting over the upcoming cmt operations. Ensure the below is covered during the meeting: • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 20.2 Attempt to reciprocate the long string during cmt operations. 20.3 Pump 5 bbls 12 ppg MUDPUSH II spacer. 20.4 Test surface cmt lines to 4500 psi. 20.5 Pump remaining 15 bbls 12 ppg MUDPUSH II spacer. 20.6 Mix and pump 15.3 ppg class"G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 100%OH excess. Section: Calculation: BLS) Vol(ft3) (B7-5/8"x 4-1/2" long string 500' x 0.02624= 13.12 74 Overlap: 6-3/4" OH x 4-1/2"Longstring: (10,487—6,600')x 0.0246 x 1.5 = 143 805 Shoe Track: 90' x 0.01522= 1.37 7.7 Total Volume: 157 bbls 887 ft3 Page 42 Revision 0 October, 2016 • KBU 32-06 Drilling Procedure Hikor j,Alaska. 20.0 Cement 4-1/2" Production Long String 20.1 Hold a pre job safety meeting over the upcoming cmt operations. Ensur- he below is covered during the meeting: • How to handle cmt returns at surface, regardless of how unlike it is that this should occur. • Which pump will be utilized for displacement, and how flui• will be fed to displacement pump. • Positions and expectations of personnel involved with e cmt operation. • Document efficiency of all possible displacement pups prior to cement job. 20.2 Attempt to reciprocate the long string during cmt ope .tions. 20.3 Pump 5 bbls 12 ppg MUDPUSH II spacer. 20.4 Test surface cmt lines to 4500 psi. 3 20.5 Pump remaining 15 bbls 12 ppg MUDP H II spacer. 3s 1L sX 20.6 Mix and pump 15.3 ppg class"G" c : per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump o OH excess. (-el, 3 s C}7s,‹ Vol Section: Calculation: (BLS) Vol (ft3) 7-5/8"x 4-1/2" long string -4'1"a" i t 500' x 0.02624 = 13.12 74 Overlap: szifiget 6-3/4" OH x 4-1/2" Longstrin_: (10,487—6,600') x 0,D246 1.5 = EYi't`/3 -5-31 .7 Shoe Tr. k: 90' x 0.01522 = 1.37 7.7 Total Vo I me: 111 bbls 23-ft3 Ito I sh go 6s-75x 4. y-' r4 Page 42 Revision 0 October, 2016 KBU 32-06 Drilling Procedure Hilrnrp Aln.ka,LLC Slurry Information: Tail System Blend Density 15.3 lb/gal Yield 1.35 ft3/sk Mixed Water 5.889 gal/sk Mixed Fluid 5.929 gal/sk Expected Blend Thickening Code Description Concentration D046 Antifoam 0.2%BWOC D202 Dispersant 1.5% BWOC Gas Additives D400 0.8% BWOC Migration D154 Extender 8.0% BWOC D174 Expanding 1.0% BWOC agent D177 Retarder 0.04 gps o or-Ft ,t',/it. 20.7 Drop top plug and displace with filtered 60/o KC1. 10,397 ft x .01522 = 158.3 bbls. 20.8 Do not overdisplace by more than V2 shoe track. Shoe track volume is 1.37 bbls. 20.9 Bleed pressure to zero to check float equipment. 20.10 Pressure up again to 3500 psi and hold for 30 min to test production bore. Page 43 Revision 0 October,2016 S KBU 32-06 Drilling Procedure Hilenrp AIa.ka.LLC 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 Send final "As-Run" casing tally & casing and cement report to mmyers(a,hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 21.0 RDMO 21.1 Install back pressure valve in hanger neck. N/D BOP. 21.2 N/U tree. 21.3 RDMO Saxon Rig#169. 21.4 After rig has departed, pull BPV &run CBL to determine TOC behind 4-1/2"production casing. s- rs `) t te- .0:2- re-7 r Page 44 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilror1,Alla..ka.1.1.1: 22.0 BOP Schematic I.1 a.a 1.1 I.I I.1 OF Saxon#169 11"x5M I!1 ul ISI ISl rSl Townsend BOP .11111 • • i Manual Manual .'.I . Valve Valve III ISI III LII ' Kllle a /1 yri t% r'yF1 '460 e � . *S 'ri�.l11l.l�ldilair•= . 13-Energy Model 60111 Itll1/Ilil 1!I 191 Spacer spool 11 5M X 11 5M lit I!i ltl ltl Ial Seaboard-MBS s vY 91e611 . i� i 16 1/4 �: 4C:"�••• •2. ti -.i.4 11=11111•- 1, It:I[Wile rill 11;f: „Ate -11 1."111 a=G.- 11..16 Page 45 Revision 0 October,2016 0 0 KBU 32-06 Drilling Procedure Hilrorp Alaska.LIT 23.0 Wellhead Schematic Kenai Gas Field KBU 32-06 Proposed .0 ^. 10.2512016 Kenai Gas Field Tubing hanger,SMB-22 KBU 32.06 ported,11 X 4 1/2"DWC 16 X 10%X 7 5/8 X 4 1/2 susp X 5.250-4 stub acme left hand lift,4"H BPV,3.998" min bore,7"extended neck BHTA,Otis,4 1/16 5M FE X 6.5"Otis Quick Union NIA 'DO Valve,Swab,WKM-M, ,pc c, t �.,to.0 4 1/16 5M FE,HWO, D trim 1$ $�� e F" ca,Not • :To ' Valve,Upper Master WKM-M,4 1/16 5M FE, sr, HWO,DD trim Valve,Master,WKM-M, dir 4 1/16 5M FE,HWO,DD trim w 4. : o;:t! Multibowl Wellhead,SMB-22, I } ;- 115MX16'%3M,w/ :! , �:• • V • 4-2 1/16 5M SSO iIII 4Y e's.w Starting head,Seaboard, 3 � OPIUM a:.:. 16%3M X 16"SOW,w/ 2-2 1/16 5M EFO 9III I' Ihir 116„ 10'''A" 7 5/8" , 4%" Page 46 Revision 0 October, 2016 • KBU 32-06 Drilling Procedure Hilrorp Alaska.LLC 24.0 Days Vs Depth Days Vs Depth 0 KBU 22-06Y KBU 42-06Y —KBU 32-06 2000 4000 E -o0 6000 IB 2 8000 10000 12000 - 0 5 10 15 20 25 30 35 Days Page 47 Revision 0 October, 2016 S 0 II KBU 32-06 Drilling Procedure Hileorp Alaska,UT 25.0 Geoprog GEOLOGICAL PROGNOSIS WELL NAME: KBU 32-06 FIELD: Kenai Gas Feld SURFACE LOCATION X=272,168.44 BHL: X=274,400.00 AFE: (PROPOSED): Y=2,362,578.00 Y=2,365,219.00 PAD: KGF 14-06 PROPOSED TD: 10,487'MD 9,479'TVD EST.KB: 82.69 API: TBD Rig RKB. 18.00 Saxon 169 GL: 64.69 Drill a 10,487 MD grass roots well at Kenai Field that will target reserves in D2,D3B,and 04 sands.Secondarytargets include the Lower Objective: Beluga-Upper Tyonek. ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED FLUID MD TVD(FT) SUBSEA DEPTH Est.Pressure X Y EMW SterlingA-10 gas AN 4,185 3,623 (3540) 187 273374 2363989 1.0 SterlingA-11 gas ® 4,245 3,677 (3594) 270 273385 2364003 1.4 SterlingB-1 gas 1111 4,320 3,744 (3661) 119 273399 2364019 0.6 Sterling Pool 6 gas • 5,046 4,427 (4344) 220 273545 2364194 1.0 Upper Beluga gas go 5,325 4,692 (4609) 560 273601 2364262 2.3 Lower Beluga gas MIN 6,790 6,085 (6002) 2739 273900 2364619 8.7 Tyonek 1B gas Arr 8,164 7,391 (7308) 2626 274179 2364954 6.8 Tyonek D2 gas 9,733 8,912 (8829) 500 274400 2365219 1.1 Tyonek D3B gas 10,020 9,199 (9116) 1200 274400 2365219 2.5 Tyonek D4A gas 10,189 9,368 (9285) 500 274400 2365219 1.0 Reservoir Objectives =Possible Geo Hazards DATA COLLECTION REQUIREMENTS: 1 Mud Logging: Surface Csg.To TD,samples collected at 30'intervals LWD Data LWD Triple Combo Other Log Data. N/A COMPLETION TYPE IP ` Chance of Success&Anticipated Rate 95% ARTIFICIAL LIFT EQUIPMENT OD 16" 136' PROSED PIPE SET DEPTHS 10-3/4" .. 1500' 7-5/8" 6600 4-1/2" I I I I I 111 I I I I I I I I I 111 TD TUBING SIZE This well is to be driled from the 41-06 pad and will initially be drilled to the north.We would like to set intermediate casing above the Lower Beluga at 6750'MD. OTHER COMMENTS NO INFORMATION CONCERNING THIS WELL IS TO BE RELEASED TO ANYONE EXCEPT THE EMPLOYEES OF HILCORP OR THEIR PARTNERS. Page 48 Revision 0 October, 2016 • O 111 KBU 32-06 Drilling Procedure Hi!carp:Uaa.a.LLC 26.0 Anticipated Drilling Hazards 13-1/2" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. BARACARB 5, 25, 50, 150, 400, and 1200. Ensure STEELSEAL, WAL-NUT, and BARAFIBRE are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of BARACARB 5 and 25 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or BARAZAN sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 - —60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 20—30 prior to cement operations. Do not lower the YP beyond 20 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheology can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 49 Revision 0 October,2016 • KBU 32-06 Drilling Procedure HiIrorp:11asla.LLC 9-7/8" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous 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/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 - —60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 50 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Harm p:11a.Aa.II 6-3/4" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscosifier as necessary. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20- 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KC1 in system for shale inhibition. 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. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 51 Revision 0 October, 2016 • • KBU 32-06 11 Drilling Procedure Hileorp AIa.ka,1,IA 27.0 Saxon Rig 169 Layout 1,0,--� .r.,l II = 1I w� I'o II = = --, IIII Mimi;„ 71.' __ = =_— ` -E.,,T<k I_I==I_II I=I-I III!�i -- Ilii II PP3111iIII I _ I.Lu.rt LL1I ! \IY1.1— 01.4.! FHS - I 11MV "a �� - _ _.1111 iii: 1ii '=: dD r.,-, . 'HaIG TnAg El M. ,.. 'IIIIIIII EIEZ 7��, - - — '1_ ,i �} �_ inE �..+TncLh .4!A • iI 17l�M i.c 11= I I ._ _,-- IIIIIIIIII�� S ! - r:aelwrdn:N,111:14, _ I [. I . _ K .. --I. IIIIII -0 III 'LEI _....... Page 52 Revision 0 October, 2016 • KBU 32-06 Drilling Procedure Hdenrp 11.1.k:1.111 28.0 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 53 Revision 0 October, 2016 • • II KBU 32-06 Drilling Procedure Hileorp Ala.ka,LLC 29.0 Choke Manifold Schematic g I v l ND 0 P n et.yy. 1�•i —1 13 il�r ! i cl L .4■ : !�:-tilt• a 1= _ __. - 1 1.11= 1.1.1111111 i o a<p s N � • IfI 0444.1h iiii •11.1 IN N •11• 1.1 N Of ' 111.10.174 I 1 N Ngy 44. e it " AA ll t. ® ® iii I rem I a ' 1 i .I ! ! ,+�..�0 Iirr n 1 } 85, _ ic. . p 71' • 1171 1 7 11 f AS Gy,i 0 1 0 TOO; aol i111lrjiaii{I o 1 �i� a rr il. IV It e 101 .11111 MI xAA... ill ( 1 1 O o 1 a ::: : .1 iii. lldhe -011001.11 o L� " I A ra 1' 4 ? yl 1 f. t _ F. gf 6(!I, it iris it Page 54 Revision 0 October, 2016 KBU 32-06 Drilling Procedure Ilileorp LLC 30.0 Casing Design Information Calculation &Casing Design Factors Kenai Beluga Unit DATE: 10-24-2016 WELL: KBU 32-06 FIELD: Kenai Gas Field DESIGN BY:Monty M Myers Design Criteria: Hole Size 9-7/8" Mud Density: 9.5 ppg Hole Size 6-3/4" Mud Density: 11.5 ppg Hole Size Mud Density: Drilling Mode MASP(sec 1): 2230 psi(see attached MASP determination&calculation) MASP(sec 2): 1064 psi(see attached MASP determination&calculation) Production Mode MASP: 2030 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1, 2, 3 Max MW gradient external stress and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 Casing OD 10-3/4" 7-5/8" 4-1/2" Top(MD) 0 0 0 Top(TVD) 0 0 0 Bottom (MD) 1,500 6,600 10,487 Bottom (TVD) 1,455 5,904 9,665 Length 1,500 6,600 10,487 Weight(ppf) 45.5 29.7 12.6 Grade L-80 L-80 L-80 Connection BTC BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 68,250 196,020 132,136 Tension at Top of Section(lbs) 68,250 196,020 132,136 Min strength Tension(1000 lbs) 1040 721 568 Worst Case Safety Factor(Tension) 15.24 3.68 - 4.30 Collapse Pressure at bottom (Psi) 719 2,917 5,026 Collapse Resistance w/o tension(Psi) 2,480 4,790 6,601 Worst Case Safety Factor(Collapse) 3.45 1.64 • 1.31 MASP (psi) 480 2,230 1,064 Minimum Yield(psi) 5,210 6,890 8,430 Worst case safety factor(Burst) 10.85 - 3.09 7.92 Page 55 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure Hilrnrp 31.0 9-7/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 9-7/8"Hole Section KBU 32-06 MD ND Planned Top: 1500 1455 Planned TD: 6600 5904 Anticipated Formations and Pressures: — Formation ND Est Pressure Oil/Gas/Wet PPG Grad Sterling A-10 3,623 187 gas 1.0 0.052 Sterling A-11 _ 3,677 270 gas 1.4 0.073 Sterling B-1 3,744 119 gas 0.6 0.032 Sterling Pool 6 4,427 220 gas 1.0 0.050 Upper Beluga 4,692 560 gas 2.3 0.119 Lower Beluga 6,085 2739 gas 8.7 0.450 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date KBU 11-17X 9-9.2 1,587 5,464 2009 KBU 14-08 9-9.2 1,510 5,432 2008 KBU 41-18X 9-9.2 1,500 5,391 2008 KBU 24-7X 9-9.7 1,502 5,326 2006 KBU 32-08 9.3-9.8 1,446 5,401 2014 KBU 43-07Y 9.5-9.7 1,540 5,738 2014 Assumptions: 1. Fracture gradient at 1,500'MD/1,455'ND is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 10-3/4"shoe considering a full column of gas from shoe to surface: 1455(ft)x 0.936(psi/ft)= 1362 1362(psi)-[0.1(psi/ft)*1455(ft)]= 1217 psi „y MASP from pore pressure(unknown gas sand at TD,at 9.2 ppg(0.4784 psi/ft) 5,904(ft)x 0.4784(psi/ft)= 2824 psi Downhole L 2824(psi)-[0.1(psi/ft)*5940(ft)]= 2230 psi Surface Summary: 1. MASP while drilling 9-7/8"intermediate hole is governed by fracture gradient at the 10-3/4"casing shoe Page 56 Revision 0 October, 2016 • • KBU 32-06 Drilling Procedure I i.� 32.0 6-3/4" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 6-3/4"Hole Section KBU 32-06 MD TVD Planned Top: 6600 5904 Planned TD: 10487 9665 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Tyonek 1B 7,391 2626 gas 6.8 0.355 Tyonek D2 8,912 500 gas 1.1 0.056 Tyonek D3B 9,199 1200 gas _ 2.5 0.130 Tyonek D4A 9,368 500 gas 1.0 0.053 TD 9,665 2000 gas 4.0 0.207 Offset Well Mud Densities Well Max Drlg MW Top(ND) Bottom(ND) Date KBU 11-17X 10.7 5,464 7,919 2009 • KBU 14-08 10.3 5,432 7,746 2008 KBU 41-18X 11.6 5,391 8,651 2008 KBU 24-7X - 9.7 5,326 7,550 2006 KBU 32-08 10.70 5,401 8,183 2014 KBU 43-07Y 12.10 5,738 9,280 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8"hole section is 11.5 ppg. 3. Calculations assume"D4"Sand contains 100%gas(worst case). 4. Calculations assume worst case event is 2/3 evacuation of wellbore to gas. Fracture Pressure at 7-5/8"shoe considering a full column of gas from shoe to surface: 5904(ft)x 0.936(psi/ft)= 5526 psi 5,526(psi)-[0.1(psi/ft)*5,940(ft)]= 4932 psi Drilling Mode MASP MASP from pore pressure(2/3 wellbore evacuated to gas from"D"at.21 psi/ft) 9,665(ft)x 0.21(psi/ft)= 2030 psi 2,030(psi)-[[0.1(psi/ft)*9,665(ft)*2/3]+[0.21(psi/ft)*9,665(ft)*1/3]]= 709 psi Production Mode MASP MASP from pore pressure(entire wellbore evacuated to gas from TD): 9,665(ft)x 0.21(psi/ft)= 2030 psi Downhole 2,030(psi)-[0.1(psi/ft)*9,665(ft)]= 1064 psi Surface Summary: 1. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TD. Page 57 Revision 0 October, 2016 • i II KBU 32-06 Drilling Procedure HiIrorp A1aiki.LLC 33.0 Spider Plot (NAD 27) j' .,ADL3926 8,„ FEE AA093808 / -005N011W.- \`� ,Itu SOOSN0W 34-32 BI-IL 11 004N01r2W mil, ` +'- .� J .\ KUV-06 BHL ``` .r KU 21.06RD BPI, • \ `` ` KU 21-06 BHL KBU 41-06 BHL • ADL392670 �.\ ~ \`50KDU 05(KU 31-61 BHL ` i \ I \ I \ I ‘ND KU 22-06X BHL KBU 31-065 BHL I t I 1 I 1 I 1 I KBU 22-06Y BHL KBU 22-06 BHL 1 KBU 42-06Y BNL 1� IMil 12-04, } 1 / I 1 I KBU 42-06516/ I / TTT I • / 1 / I I I 1 I 1 / 1 :-- 1 I / KBU 42-06 BAIL 1 KTU 43-06XRdg4�1• / 1 - t I KBU 12-05 BHL eKU 13-06 BAILI / ; • ',,KU(43-06 BHL / \\ I'KBU 23X-O6 BH S004N011 W .' 1 t U 4K?: RD BHL ' I ; �Sy0-�0-�41N�01 \\ I //(,.,,� /� ,ttt,,, \ �1 _-SKT( 3.06XRD2 8H/ G.:A'�G // \ i C�.�ISb V KBU 33-06 1HL \;` 111 II ; / `\ I / KM 1_'-IIP' •Il�133-01lD(8HL\) I 1 1 KU41-06ABHL // I / • \ I 1 `\ 1 / \�•'• \ `� 14 t\ II I 1 / 19/1113-05 BHL \ / / 1 1 \ I 1 1 0°' `\ \� 1/I I I, //i \ 1 i o \ I / °0•W(TU 24-06H 8HL \\ 1,1 I 1 ; / /I/ \ I I / 0 .` 5 Il I p I I I I / // `\ 1 ;K8/24O RD BHL LJt4IT \\11\ ,I 1 I/ 1 .;' ,,' \ / / 0°1 ,-- KDUD1\BHL \1 \/ I II I // S 1 / o \1 I/ I // ` I I 1°0 1�''FEE A028142 '5 t 1 1 1 II Kt�ld 44-06 BHL ,'KU 24-05RD 8HL \‘ ./ ..-� ' KBU 24-06 BM.' (\1 I \ 11 4 /I,/ �' /, Mil -1 V,•\i �..• •` 1151 I \ /I / Ij/ ' /i • _'-----------ice 4-IIB gR ...............>"::, `\ �( 1 U I\4f I / Y ',/ i f' 1".. \ \ � \% `t I IIN ' I✓ KU 21,67X BHL I l •\ 5+ ( % I A 14-0✓1VHL , \ KBU 34-06 13111. 1‘ 1 4 11 i// / / I 1 ♦ \ ♦ 1' K// / / KBU 11-08X BHL j - `21.07 BHL \ I 1/ 111' t I.` / f a! `\ KBU 41-01X131-1.17.16.-_ ..gt �r-�.g / \ \\ `\ 1 iI . .`sic `\ 1 t S '(\ " \ \:- 110 ' \1 \ '\, A,' 1 ` \\ \\\Legend 1 • � _KBUt137BHL � KBU31-07120BHLL `� ''1,` KBU 32-06_SHL \;"• \ 1 1 14 KBU 32-06_TPH 1 \\ KBU as\ BHL S004N011 W 1 KTU 32-07H BHL \ KBU 3T-07 / I KBU 32-06_BHL ` /- • � "kB:j�-071213 BHL © \ ` ` \ Other Surface Hole Location l '� / I S 110�(KU 13-7)BHL / I • Other Bottom Hole Location S / 1 I / —-- Well Paths 1\ Sy0,�0,4N011 W pi,32.117 8HL yi cpOil and Gas Unit Boundary t . t i I KBU 32-06 0 500 1.000 1.500 2.000 Feet Alaska State Plane Zone 4.NAD27 A 1111.1.1.11 %IA•L..I I 1 Map Date 10,25/2016 Page 58 Revision 0 October, 2016 0 i HKBU 32-06 Drilling Procedure Hileorp.Im,ka.I,1A 34.0 Surface Plat (As Built) (NAD 27) 1 --_ I.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD27 yr+�f A�.4• it� __ ZONE 4 DETERMINED BY A MEC TIE TO USCEGS TRI STA AUDRY HAVING A y":',0',, // �� PUBLISHED POSITION LAT.691010 569'N LONG 151'1E37.6651V / ._ N�2J82045 42 E-269066.75 *i 49 * NORTH 2)BASH of VERTICAL DATUM Is MEAN SEA LEVEL V�jyfy�f,�__ i �.•w� 3)SOUTHWEST CORNER SEC.6 COORDINATE DETERMINED FROM DIRECT �...... ... maNa SURVEY TIE TO T TO EXISTING BIM WC FORE NW CORNER SEC.7 AND / A 5 TAN A.M L IE.' �L� WC/.CORNER SECTIONS 6 8 7 RECOVERED ANO NOT THE PROTRACTED //� ''., �J7-5 SECTIONCORNER VALUES. // •MM. SCALE it.1, `o`, ..,;• u loo 200 \-- J I I 1 , FEET I __ LOGE AO FOOTPRNI CONTROL PI GP 3 ( Tc.,......, '—► , N. Y.2.3112.z2ce \EtF7.nr• \ 1250'FWL(NTS) n I\ Ns. \ ,–KBU 32-06 N°1:T _ _ ASBUILT SURFACE LOCATION •A-A->"'„y 0K„21.7K N. NAD 27 ASP ZONE 4 982,I1' $ d10 ',,� N:2362578.000' 4. K T U'3I $` Z E:272168.440' [� .2 x.”" \ LAT:60°27'39.31041"N Col °,°;K6U),%, LON: 151' 15'44.02142"W cv \ 2. ,.,614 526'FSL ..01121" CC 1250'FWL ELEV:64.69 MSL I ; ° u ,� A ��OE KBU I17 Y • Z I K]M.gYM KIU N! \ i x*m MAX W • ♦•2AN9NAs Q MAISNMT Z_ -J K ',c Z ® ®`.',''` 526'FSI. O A ` I:: IMF TIO PAD T 6 U C 0 ELEVATION=65 611.1S 'M S L. I� C. ;1'.:,%''''' �$ GL\ 0,u 4�12 �, EDGE PT CIAO wKN* \ "iP•'•P' CONTROL PT.CP2 T4N W.C. �E e, �»_, ,,.. r I x.2n,1E•.E p �u,K>e P.2.9F22U.7S S7 I S6 N inr, PIXY*SST S12 S7 % I R12W Ri1W \ "❑ , �, No. t921 •� �� 1i . 5ii aim 'OW7itwC1CR t SW COR I - ❑tir.. •. "�� I 04 N 2362069.27 1 R ' I 1 6 E 270908.10 1 12� 7 — — — — — — — — :�rxrn \ ,„„ cri AN ,,, PROJECTREvsK7N 0 HILCORP ALASKA LLC GATE ISM/10 Consulting Int KBU 32-06 AS-BUILT SURFACE LOCATION DRAWN IPP ICS I�C�1l?1 . KENAI GAS FIELD PAD 14-6 $c E. 1,100NAD27 PRareCTNO ,ex,,: t,nRIPE9G/MAPPING.SURA DIG/TESTING I.,,..K NO. 1643 P O BOA Add SOIAOT 44 Nt.99!49 IOWA" :,,ICE.W7)204214 TM,'907)2611265 '+{• EMWI SANUANAMIAC..WEGOCO2 Ili1E•urp Alaska,1.LC. S6 T4N R11W SEWARD MERIDIAN,ALASKA 1 OP 1 Page 59 Revision 0 October, 2016 i i KBU 32-06 Drilling Procedure Hilrorp Ma.ka,LLE 35.0 Offset MW vs TVD Chart MW vs TVD Offsets 0 -KBU 32-06 1000 — � KBY 43-07Y 2000 -KBU 11-082 — -KBU 23-05 30 -KDU 14 — I KBU 42-05v 4000 5000 6400 l` O 111111111 7000 8004 4', 9000 10000 11000 12000 13000 6 7 8 9 10 11 12 13 14 Mud Weight(PPG) Page 60 Revision 0 October,2016 • • KBU 32-06 Drilling Procedure Halm p:11:,Aa,In 36.0 Directional Plan Page 61 Revision 0 October, 2016 w Hilcorp Energy Company Kenai Gas Field KGF 14-6 Pad Plan KBU 32-06 KBU 32-06 Plan: KBU 32-06 wp05 Standard Proposal Report 24 October, 2016 HALLIBURTON Sperry Drilling Services HALLIBUNTON - Hilcorp Energy Company REFERENCE INFORMATION 1 ,l I e. r�) Calculation Method: Minimum Curvature mate(N/E)Reference: Well Plan KBU 32-06,True North Sperry Drilling Error System: ISCWSA Vertical(TVD)Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Scan Method: Closest Approach 3D Measured Depth Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Error Surface: Elliptical Conic Project: Kenai Gas Field Warning Method: Error Ratio Calculation Method: Minimum Curvature Site: KGF 14-6 Pad SECTION DETAILS Well: Plan KBU 32-06 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Wellbore: KBU 32-06 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 Design: KBU 32-06 wp05 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 3 800.00 9.00 34.00 798.77 19.49 13.15 3.00 34.00 23.39 4 1744.38 37.27 39.77 1658.48 306.41 242.06 3.00 7.37 390.36 5 3705.43 37.27 39.77 3218.99 1219.31 1001.74 0.00 0.00 1578.01 6 4319.61 25.00 38.78 3743.69 1464.38 1202.76 2.00 -178.04 1894.96 KBU 32-06 wp05 ST B1 7 4664.02 18.11 38.73 4063.82 1562.99 1281.94 2.00 -179.88 2021.41 8 8827.60 18.11 38.73 8021.11 2572.67 2091.81 0.00 0.00 3315.53 DDI = 5.620 9 9733.19 0.00 0.00 8911.69 2683.40 2180.62 2.00 180.00 3457.45 KBU 32-06 wp05 TY D2 10 10189.19 0.00 0.00 9367.69 2683.40 2180.62 0.00 0.00 3457.45 KBU 32-06 wp05 TY D4 11 10486.50 0.00 0.00 9665.00 2683.40 2180.62 0.00 0.00 3457.45 CASING DETAILS WELL DETAILS: Plan KBU 32-06 I TVD TVDSS MD Size Name Ground Level: 64.69 1455.09 1372.40 1500.00 10-3/4 10 3/4"x 13 1/2" +N/-S +E/-W Northing Easting Latittude Longitude I 5903.88 5821.19 6600.00 7-5/8 7 5/8"x 9 7/8" 0.00 0.00 2362578.00 272168.44 60°27'39.310 N 151°15 44.021 W 9665.00 9582.31 10486.50 4-1/2 4 1/2"x 8 1/2" SURVEY PROGRAM Date:2016-05-13700:00:00 Validated:Yes Version: Depth From Depth To Survey/Plan Tool 18.00 1500.00 KBU 32-06 wp05 MWD+SC+sag 1500.00 6600.00 KBU 32-06 wp05 MWD+SC+sag -1000- 6600.00 10486.50 KBU 32-06 wp05 MWD+SC+sag _ A Start Dir 3°/100':500'MD,500'TVD FORMATION TOP DETAILS 0-- TVDPath TVDssPath MDPath Formation 3622.69 3540.00 4184.57 Sterling A-10 X003676.69 3594.00 4245.22 Sterling A-11 - End Dir :1744.38'MD,1658.48'ND 3743.69 3661.00 4319.61 Sterling B-1 4426.69 4344.00 5045.81 Sterling Pool 6 1000- 10p0 4691.69 4609.00 5324.62 Upper Beluga - s.lypp - 7390 .69 084.69 7308. 00 8164.32 Tyonek 002.00 6790.24 Lower 61 B Beluga -- " p0 8911.69 8829.00 9733.19 Tyonek D2 10 3/4"x 13 1/2" tip 9198.69 9116.00 10020.19 Tyonek D3B 2000_ Start Dir 2°/100':3705.43'MD,3218.99'TVD 9367.69 9285.00 10189.19 Tyonek D4A 3000 KBU 32-06 wp05 ST B1 -_' pp End Dir :4664.02'MD,4063.82'ND • =Sterling A-10 ap -- w - - 0) _�`Sterling A-H = ASo° o a000--Sterling B-1 o5p00 L -- Sterling Pool 6-- 5500 - w• 5000- Upper Beluga p - 5000 o - 7 5/8"x 9 7/8" 5°0 f - ---, ° N 6000 1p00 Lower Beluga 1500 Start Dir 2°/100':8827.6'MD,8021.11'TVD 7000- - 5000 - - Tyonek 1B 6500 -- 8000-- g000 End Dir :9733.19'MD,8911.69'ND -- T onek D2 KBU 32-06 wp05 TY D2 - -- Y 9500---" 9000 Tyonek D3B - - - 10000 Total Depth:10486.5'MD,9665'TVD Tyonek D4A KBU 32-06 wp05 TY D4 `,1-0-87 10000- 4 1/2"x 8 1/2" KBU 32-06 wp05 11000- I I I T.. r I 1 1 I I I I I 11 1 I I I I I I T r I I I I I I -r7 1 J• T I I I I I I T I T I I I I I I I I 1 F I I I I I I 11r I ill -2000 -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Vertical Section at 39.79°(2000 usft/in) HALLIBURTON Project: Kenai Gas Field •WELL DETAILS: PIanKBU32-06 Site: KGF 14-6 Pad Ground Level: 64.69 Sperry Llrini ne.1 Well: Plan KBU 32-06 +NI-S +E/-W Northing Easting Latittude Longitude Wellbore: KBU 32-06 0.00 0.00 2362578.00 272168.44 60°27'39.310 N 151°15'44.021 W p�� Plan: KBU 32-06 wp05 REFERENCE INFORMATION Hilco [' Co-ordinate(N/E)Reference:Well Plan KBU 32-06,True North Vertical(TVD)Reference:KBU 32-06 wp05 @ 82.69usft(Saxon 169) Measured Depth Reference: KBU 32-06 wp05©82.69usft(Saxon 169) Calculation Method:Minimum Curvature 3500- 3250- 3000— Total Depth:10486.5114D,9665'TVD KBU 32-06 wp05 2750— 4 1/2"x 8 1/2" End Dir:9733.19'MD,8911.69'TVD QIP 9665 Start Dir 2°/100':8827.6'MD,8021.11'TVD-- 'PO s KBU 32-06 wp05 TY D4 2500— 00 ,r00 KBU 32-06 wp05 TY D2 2250— 000 • 6p 7 5/8"x 9 7/8" `00 2000— /000 ss OO 1750 s End Dv:4664.02'MD,4063.82'TVD 000 a*" pS0 y _ O ca 1500— 9% - .+.iO KBU 32-06 wp05 ST BI = Start Dir 2°/100':3705.43'MD,3218.99'TVD ,2U� 1250- 0 250_O 1000- - "so 750— 2So0 22s0 500- - End Dir :1744.38'MD,1658.48'TVD 2Q70 CASING DETAILS �j TVD TVDSS MD Size Name 10 3/4"x 13 1/2" so 1455.09 1372.40 1500.00 10-3/4 10 3/4"x 13 1/2" 250— 5903.88 5821.19 6600.00 7-5/8 7 5/8"x 9 7/8" Start Dir 3°/100':500'MD,500'TVD /U% 9665.00 9582.31 10486.50 4-1/2 4 1/2"x 8 1/2" 0— '>s0 -250— -500— -750— -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 West(-)/East(+)(500 usft/in) • 0 Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan KBU 32-06 Company: Hilcorp Energy Company TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Project: Kenai Gas Field MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) • Site: KGF 14-6 Pad North Reference: True Well: Plan KBU 32-06 Survey Calculation Method: Minimum Curvature Wellbore: KBU 32-06 Design: KBU 32-06 wp05 Project Kenai Gas Field Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 - Using geodetic scale factor Site KGF 14-6 Pad I Site Position: Northing: 2,362,394.10 usft Latitude: 60°27'37.354 N'I From: Map Easting: 271,396.69 usft Longitude: 151°15'59.339 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.10 ° Well Plan KBU 32-06 Well Position +N/-S 0.00 usft Northing: 2,362,578.00 usft • Latitude: 60°27'39.310 N +El-W 0.00 usft Easting: 272,168.44 usft - Longitude: 151°15'44.021 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 64.69 usft . 1 Wellbore KBU 32-06 I Magnetics Model Name Sample Date Declination Dip Angle Field Strength I (0) (0) (nT) BGGM2015 5/13/2016 16.15 73.43 55,344 Design KBU 32-06 wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 18.00 0.00 0.00 39.79 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (usft) (°) (") (usft) usft (usft) (usft) (°/100usft) (1100usft) ('/100usft) (0) 18.00 0.00 0.00 18.00 -64.69 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 417.31 0.00 0.00 0.00 0.00 0.00 0.00 800.00 9.00 34.00 798.77 716.08 19.49 13.15 3.00 3.00 0.00 34.00 1,744.38 37.27 39.77 1,658.48 1,575.79 306.41 242.06 3.00 2.99 0.61 7.37 3,705.43 37.27 39.77 3,218.99 3,136.30 1,219.31 1,001.74 0.00 0.00 0.00 0.00 4,319.61 25,00 38.78 3,743.69 3,661.00 1,464.38 1,202.76 2.00 -2.00 -0.16 -178.04 4,664.02 18.11 38.73 4,063.82 3,981.13 1,562.99 1,281.94 2.00 -2.00 -0.01 -179.88 8,827.60 18.11 38.73 8,021.11 7,938.42 2,572.67 2,091.81 0.00 0.00 0.00 0.00 9,733.19 0.00 0.00 8,911.69 8,829.00 2,683.40 2,180.62 2.00 -2.00 0.00 180.00 10,189.19 0.00 0.00 9,367.69 9,285.00 2,683.40 2,180.62 0.00 0.00 0.00 0.00 10,486.50 0.00 0.00 9,665.00 9,582.31 2,683.40 2,180.62 0.00 0.00 0.00 0.00 10/24/2016 12:01:49PM Page 2 COMPASS 5000.1 Build 81 • 4111 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan KBU 32-06 Company: Hilcorp Energy Company TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Project: Kenai Gas Field MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad North Reference: True Well: Plan KBU 32-06 Survey Calculation Method: Minimum Curvature Wellbore: KBU 32-06 Design: KBU 32-06 wp05 Planned Survey Measured Vertical Map Map 1 Depth Inclination Azimuth Depth TVDss +N/-s +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 44.69 18.00 0.00 0.00 18.00 -64.69 0.00 0.00 2,362,578.00 272,168.44 0.00 0.00 100.00 0.00 0.00 100.00 17.31 0.00 0.00 2,362,578.00 272,168.44 0.00 0.00 200.00 0.00 0.00 200.00 117.31 0.00 0.00 2,362,578.00 272,168.44 0.00 0.00 300.00 0.00 0.00 300.00 217.31 0.00 0.00 2,362,578.00 272,168.44 0.00 0.00 400.00 0.00 0.00 400.00 317.31 0.00 0.00 2,362,578.00 272,168.44 0.00 0.00 500.00 0.00 0.00 500.00 417.31 0.00 0.00 2,362,578.00 272,168.44 0.00 0.00 Start Dir 3°/100':500'MD,500'TVD 600.00 3.00 34.00 599.95 517.26 2.17 1.46 2,362,580.14 272,169.94 3.00 2.60 700.00 6.00 34.00 699.63 616.94 8.67 5.85 2,362,586.56 272,174.46 3.00 10.41 800.00 9.00 34.00 798.77 716.08 19.49 13.15 2,362,597.24 272,181.96 3.00 23.39 900.00 11.98 35.85 897.09 814.40 34.39 23.60 2,362,611.93 272,192.70 3.00 41.53 1,000.00 14.97 36.97 994.32 911.63 53.13 37.45 2,362,630.40 272,206.90 3.00 64.80 1,100.00 17.96 37.73 1,090.21 1,007.52 75.65 54.66 2,362,652.59 272,224.54 3.00 93.11 1,200.00 20.96 38.27 1,184.49 1,101.80 101.89 75.18 2,362,678.43 272,245.56 3.00 126.41 1,300.00 23.95 38.69 1,276.89 1,194.20 131.78 98.95 2,362,707.86 272,269.90 3.00 164.59 1,400.00 26.95 39.02 1,367.18 1,284.49 165.24 125.91 2,362,740.79 272,297.49 3.00 207.55 1,500.00 29.95 39.28 1,455.09 1,372.40 202.18 155.99 2,362,777.14 272,328.27 3.00 255.18 10 3/4"x 13 1/2" 1,600.00 32.94 39.50 1,540.40 1,457.71 242.49 189.09 2,362,816.81 272,362.14 3.00 307.34 1,700.00 35.94 39.69 1,622.86 1,540.17 286.06 225.14 2,362,859.68 272,399.02 3.00 363.89 1,744.38 37.27 39.77 1,658.48 1,575.79 306.41 242.06 2,362,879.71 272,416.32 3.00 390.36 End Dir :1744.38'MD,1658.48'TVD 1,800.00 37.27 39.77 1,702.74 1,620.05 332.31 263.61 2,362,905.18 272,438.35 0.00 424.04 1,900.00 37.27 39.77 1,782.32 1,699.63 378.86 302.34 2,362,950.98 272,477.98 0.00 484.61 2,000.00 37.27 39.77 1,861.89 1,779.20 425.41 341.08 2,362,996.78 272,517.60 0.00 545.17 2,100.00 37.27 39.77 1,941.47 1,858.78 471.96 379.82 2,363,042.58 272,557.22 0.00 605.73 2,200.00 37.27 39.77 2,021.04 1,938.35 518.51 418.56 2,363,088.37 272,596.84 0.00 666.29 2,300.00 37.27 39.77 2,100.62 2,017.93 565.06 457.30 2,363,134.17 272,636.47 0.00 726.85 2,400.00 37.27 39.77 2,180.19 2,097.50 611.62 496.04 2,363,179.97 272,676.09 0.00 787.41 2,500.00 37.27 39.77 2,259.77 2,177.08 658.17 534.78 2,363,225.77 272,715.71 0.00 847.98 2,600.00 37.27 39.77 2,339.34 2,256.65 704.72 573.52 2,363,271.57 272,755.33 0.00 908.54 2,700.00 37.27 39.77 2,418.92 2,336.23 751.27 612.25 2,363,317.37 272,794.96 0.00 969.10 2,800.00 37.27 39.77 2,498.49 2,415.80 797.82 650.99 2,363,363.17 272,834.58 0.00 1,029.66 2,900.00 37.27 39.77 2,578.07 2,495.38 844.37 689.73 2,363,408.97 272,874.20 0.00 1,090.22 3,000.00 37.27 39.77 2,657.65 2,574.96 890.93 728.47 2,363,454.76 272,913.82 0.00 1,150.79 3,100.00 37.27 39.77 2,737.22 2,654.53 937.48 767.21 2,363,500.56 272,953.44 0.00 1,211.35 3,200.00 37.27 39.77 2,816.80 2,734.11 984.03 805.95 2,363,546.36 272,993.07 0.00 1,271.91 3,300.00 37.27 39.77 2,896.37 2,813.68 1,030.58 844.69 2,363,592.16 273,032.69 0.00 1,332.47 3,400.00 37.27 39.77 2,975.95 2,893.26 1,077.13 883.43 2,363,637.96 273,072.31 0.00 1,393.03 3,500.00 37.27 39.77 3,055.52 2,972.83 1,123.68 922.16 2,363,683.76 273,111.93 0.00 1,453.60 3,600.00 37.27 39.77 3,135.10 3,052.41 1,170.24 960.90 2,363,729.56 273,151.56 0.00 1,514.16 3,700.00 37.27 39.77 3,214.67 3,131.98 1,216.79 999.64 2,363,775.36 273,191.18 0.00 1,574.72 3,705.43 37.27 39.77 3,218.99 3,136.30 1,219.32 1,001.75 2,363,777.84 273,193.33 0.00 1,578.01 Start Dir 2°/100':3705.43'MD,3218.99'TVD 3,800.00 35.38 39.65 3,295.18 3,212.49 1,262.41 1,037.54 2,363,820.24 273,229.94 2.00 1,634.03 10/24/2016 12:01:49PM Page 3 COMPASS 5000.1 Build 81 • • Halliburton HALLIBLiRTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan KBU 32-06 Company: Hilcorp Energy Company TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Project: Kenai Gas Field MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad North Reference: True Well: Plan KBU 32-06 Survey Calculation Method: Minimum Curvature Wellbore: KBU 32-06 Design: KBU 32-06 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) 3,295.01 3,900.00 33.38 39.52 3,377.70 3,295.01 1,305.93 1,073.53 2,363,863.06 273,266.76 2.00 1,690.50 4,000.00 31.39 39.38 3,462.15 3,379.46 1,347.28 1,107.56 2,363,903.75 273,301.57 2.00 1,744.06 4,100.00 29.39 39.22 3,548.40 3,465.71 1,386.42 1,139.60 2,363,942.27 273,334.36 2.00 1,794.64 4,184.57 27.70 39.06 3,622.69 3,540.00 1,417.76 1,165.11 2,363,973.11 273,360.46 2.00 1,835.04 Sterling A-10 4,200.00 27.39 39.03 3,636.37 3,553.68 1,423.30 1,169.60 2,363,978.57 273,365.06 2.00 1,842.18 4,245.22 26.49 38.94 3,676.69 3,594.00 1,439.23 1,182.49 2,363,994.24 273,378.25 2.00 1,862.66 Sterling A-11 4,300.00 25.39 38.82 3,725.95 3,643.26 1,457.88 1,197.53 2,364,012.60 273,393.65 2.00 1,886.62 4,319.61 25.00 38.78 3,743.69 3,661.00 1,464.38 1,202.76 2,364,019.00 273,399.00 2.00 1,894.96 Sterling B-1 4,400.00 23.39 38.77 3,817.02 3,734.33 1,490.07 1,223.40 2,364,044.29 273,420.12 2.00 1,927.91 4,500.00 21.39 38.76 3,909.47 3,826.78 1,519.77 1,247.25 2,364,073.52 273,444.54 2.00 1,965.99 4,600.00 19.39 38.74 4,003.20 3,920.51 1,546.94 1,269.06 2,364,100.27 273,466.86 2.00 2,000.83 4,664.02 18.11 38.73 4,063.82 3,981.13 1,562.99 1,281.94 2,364,116.07 273,480.05 2.00 2,021.41 End Dir :4664.02'MD,4063.82'TVD 4,700.00 18.11 38.73 4,098.02 4,015.33 1,571.72 1,288.94 2,364,124.66 273,487.21 0.00 2,032.59 4,800.00 18.11 38.73 4,193.06 4,110.37 1,595.97 1,308.39 2,364,148.53 273,507.12 0.00 2,063.67 4,900.00 18.11 38.73 4,288.11 4,205.42 1,620.22 1,327.84 2,364,172.41 273,527.03 0.00 2,094.75 5,000.00 18.11 38.73 4,383.15 4,300.46 1,644.47 1,347.29 2,364,196.28 273,546.95 0.00 2,125.84 5,045.81 18.11 38.73 4,426.69 4,344.00 1,655.58 1,356.20 2,364,207.21 273,556.07 0.00 2,140.07 Sterling Pool 6 5,100.00 18.11 38.73 4,478.20 4,395.51 1,668.72 1,366.74 2,364,220.15 273,566.86 0.00 2,156.92 5,200.00 18.11 38.73 4,573.24 4,490.55 1,692.97 1,386.19 2,364,244.02 273,586.77 0.00 2,188.00 5,300.00 18.11 38.73 4,668.29 4,585.60 1,717.22 1,405.64 2,364,267.89 273,606.68 0.00 2,219.08 5,324.62 18.11 38.73 4,691.69 4,609.00 1,723.19 1,410.43 2,364,273.77 273,611.58 0.00 2,226.73 Upper Beluga 5,400.00 18.11 38.73 4,763.34 4,680.65 1,741.47 1,425.10 2,364,291.77 273,626.59 0.00 2,250.16 5,500.00 18.11 38.73 4,858.38 4,775.69 1,765.72 1,444.55 2,364,315.64 273,646.50 0.00 2,281.25 5,600.00 18.11 38.73 4,953.43 4,870.74 1,789.97 1,464.00 2,364,339.51 273,666.42 0.00 2,312.33 5,700.00 18.11 38.73 5,048.47 4,965.78 1,814.22 1,483.45 2,364,363.38 273,686.33 0.00 2,343.41 5,800.00 18.11 38.73 5,143.52 5,060.83 1,838.47 1,502.90 2,364,387.25 273,706.24 0.00 2,374,49 5,900.00 18.11 38.73 5,238.56 5,155.87 1,862.72 1,522.35 2,364,411.13 273,726.15 0.00 2,405.57 6,000.00 18.11 38.73 5,333.61 5,250.92 1,886.97 1,541.80 2,364,435.00 273,746.06 0.00 2,436.65 6,100.00 18.11 38.73 5,428.65 5,345.96 1,911.22 1,561.25 2,364,458.87 273,765.97 0.00 2,467.74 6,200.00 18.11 38.73 5,523.70 5,441.01 1,935.47 1,580.70 2,364,482.74 273,785.88 0.00 2,498.82 6,300.00 18.11 38.73 5,618.74 5,536.05 1,959.72 1,600.16 2,364,506.61 273,805.80 0.00 2,529.90 6,400.00 18.11 38.73 5,713.79 5,631.10 1,983.97 1,619.61 2,364,530.49 273,825.71 0.00 2,560.98 6,500.00 18.11 38.73 5,808.83 5,726.14 2,008.22 1,639.06 2,364,554.36 273,845.62 0.00 2,592.06 6,600.00 18.11 38.73 5,903.88 5,821.19 2,032.47 1,658.51 2,364,578.23 273,865.53 0.00 2,623.15 7 518"x 9 7/8" 6,700.00 18.11 38.73 5,998.92 5,916.23 2,056.72 1,677.96 2,364,602.10 273,885.44 0.00 2,654.23 6,790.24 18.11 38.73 6,084.69 6,002.00 2,078.61 1,695.51 2,364,623.64 273,903.41 0.00 2,682.28 Lower Beluga 6,800.00 18.11 38.73 6,093.97 6,011.28 2,080.97 1,697.41 2,364,625.97 273,905.35 0.00 2,685.31 10/24/2016 12:01:49PM Page 4 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan KBU 32-06 Company: Hilcorp Energy Company TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Project: Kenai Gas Field MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad North Reference: True Well: Plan KBU 32-06 Survey Calculation Method: Minimum Curvature Wellbore: KBU 32-06 Design: KBU 32-06 wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (usft) (°) (') (usft) usft (usft) (usft) (usftj (usft) 6,106.32 6,900.00 18.11 38.73 6,189.01 6,106.32 2,105.22 1,716.86 2,364,649.84 273,925.27 0.00 2,716.39 7,000.00 18.11 38.73 6,284.06 6,201.37 2,129.47 1,736.31 2,364,673.72 273,945.18 0.00 2,747.47 I 7,100.00 18.11 38.73 6,379.10 6,296.41 2,153.72 1,755.77 2,364,697.59 273,965.09 0.00 2,778.56 7,200.00 18.11 38.73 6,474.15 6,391.46 2,177.97 1,775.22 2,364,721.46 273,985.00 0.00 2,809.64 7,300.00 18.11 38.73 6,569.19 6,486.50 2,202.22 1,794.67 2,364,745.33 274,004.91 0.00 2,840.72 7,400.00 18.11 38.73 6,664.24 6,581.55 2,226.47 1,814.12 2,364,769.20 274,024.82 0.00 2,871.80 7,500.00 18.11 38.73 6,759.28 6,676.59 2,250.72 1,833.57 2,364,793.08 274,044.74 0.00 2,902.88 7,600.00 18.11 38.73 6,854.33 6,771.64 2,274.97 1,853.02 2,364,816.95 274,064.65 0.00 2,933.97 7,700.00 18.11 38.73 6,949.37 6,866.68 2,299.22 1,872.47 2,364,840.82 274,084.56 0.00 2,965.05 7,800.00 18.11 38.73 7,044.42 6,961.73 2,323.47 1,891.92 2,364,864.69 274,104.47 0.00 2,996.13 7,900.00 18.11 38.73 7,139.46 7,056.77 2,347.72 1,911.38 2,364,888.56 274,124.38 0.00 3,027.21 8,000.00 18.11 38.73 7,234.51 7,151.82 2,371.97 1,930.83 2,364,912.44 274,144.29 0.00 3,058.29 8,100.00 18.11 38.73 7,329.55 7,246.86 2,396.22 1,950.28 2,364,936.31 274,164.21 0.00 3,089.38 8,164.32 18.11 38.73 7,390.69 7,308.00 2,411.82 1,962.79 2,364,951.66 274,177.01 0.00 3,109.37 Tyonek 1B 8,200.00 18.11 38.73 7,424.60 7,341.91 2,420.47 1,969.73 2,364,960.18 274,184.12 0.00 3,120.46 8,300.00 18.11 38.73 7,519.64 7,436.95 2,444.72 1,989.18 2,364,984.05 274,204.03 0.00 3,151.54 8,400.00 18.11 38.73 7,614.69 7,532.00 2,468.97 2,008.63 2,365,007.92 274,223.94 0.00 3,182.62 8,500.00 18.11 38.73 7,709.73 7,627.04 2,493.22 2,028.08 2,365,031.79 274,243.85 0.00 3,213.70 8,600.00 18.11 38.73 7,804.78 7,722.09 2,517.48 2,047.53 2,365,055.67 274,263.76 0.00 3,244.79 8,700.00 18.11 38.73 7,899.83 7,817.14 2,541.73 2,066.98 2,365,079.54 274,283.67 0.00 3,275.87 1 8,800.00 18.11 38.73 7,994.87 7,912.18 2,565.98 2,086.44 2,365,103.41 274,303.59 0.00 3,306.95 8,827.60 18.11 38.73 8,021.10 7,938.41 2,572.67 2,091.80 2,365,110.00 274,309.08 0.00 3,315.53 Start Dir 2°1100':8827.6'MD,8021.11TVD 8,900.00 16.66 38.73 8,090.19 8,007.50 2,589.55 2,105.34 2,365,126.61 274,322.94 2.00 3,337.16 9,000.00 14.66 38.73 8,186.47 8,103.78 2,610.61 2,122.23 2,365,147.34 274,340.23 2.00 3,364.15 9,100.00 12.66 38.73 8,283.64 8,200.95 2,629.03 2,137.01 2,365,165.48 274,355.36 2.00 3,387.77 9,200.00 10.66 38.73 8,381.57 8,298.88 2,644.80 2,149.66 2,365,181.01 274,368.31 2.00 3,407.98 9,300.00 8.66 38.73 8,480.14 8,397.45 2,657.90 2,160.17 2,365,193.90 274,379.06 2.00 3,424.77 9,400.00 6.66 38.73 8,579.25 8,496.56 2,668.30 2,168.51 2,365,204.14 274,387.60 2.00 3,438.10 9,500.00 4.66 38.73 8,678.75 8,596.06 2,676.00 2,174.68 2,365,211.72 274,393.92 2.00 3,447.97 9,600.00 2.66 38.73 8,778.54 8,695.85 2,680.98 2,178.68 2,365,216.62 274,398.02 2.00 3,454.36 9,700.00 0.66 38.73 8,878.50 8,795.81 2,683.25 2,180.50 2,365,218.85 274,399.88 2.00 3,457.26 9,733.19 0.00 0.00 8,911.69 8,829.00 2,683.40 2,180.62 2,365,219.00 274,400.00 2.00 3,457.45 End Dir :9733.19'MD,8911.69'TVD-Tyonek D2 9,800.00 0.00 0.00 8,978.50 8,895.81 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 9,900.00 0.00 0.00 9,078.50 8,995.81 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 10,000.00 0.00 0.00 9,178.50 9,095.81 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 10,020.19 0.00 0.00 9,198.69 9,116.00 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 Tyonek D3B 10,100.00 0.00 0.00 9,278.50 9,195.81 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 10,189.19 0.00 0.00 9,367.69 9,285.00 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 Tyonek D4A 10,200.00 0.00 0.00 9,378.50 9,295.81 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 10,300.00 0.00 0.00 9,478.50 9,395.81 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 10/24/2016 12:01:49PM Page 5 COMPASS 5000.1 Build 81 II0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan KBU 32-06 Company: Hilcorp Energy Company TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Project: Kenai Gas Field MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad North Reference: True Well: Plan KBU 32-06 Survey Calculation Method: Minimum Curvature Wellbore: KBU 32-06 Design: KBU 32-06 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) 9,495.81 10,400.00 0.00 0.00 9,578.50 9,495.81 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 10,486.50 - 0.00 0.00 9,665.00 9,582.31 2,683.40 2,180.62 2,365,219.00 274,400.00 0.00 3,457.45 Total Depth:10486.5'MD,966571/D-4 112"x 8 1/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) KBU 32-06 wp05 ST B1 0.00 0.00 3,743.69 1,464.38 1,202.76 2,364,019.00 273,399.00 -plan hits target center -Circle(radius 50.00) KBU 32-06 wp05 TY D2 0.00 0.00 8,911.69 2,683.40 2,180.62 2,365,219.00 274,400.00 -plan hits target center -Circle(radius 50.00) KBU 32-06 wp05 TY D4 0.00 0.00 9,367.69 2,683.40 2,180.62 2,365,219.00 274,400.00 -plan hits target center -Circle(radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") ('•) 1,500.00 1,455.09 10 3/4"x 13 1/2" 10-3/4 13-1/2 6,600.00 5,903.88 7 5/8"x 9 7/8" 7-5/8 9-7/8 10,486.50 9,665.00 4 1/2"x 8 1/2" 4-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (`) 4,319.61 3,743.69 Sterling B-1 5,324.62 4,691.69 Upper Beluga 8,164.32 7,390.69 Tyonek 1B 6,790.24 6,084.69 Lower Beluga 5,045.81 4,426.69 Sterling Pool 6 4,245.22 3,676.69 Sterling A-11 9,733.19 8,911.69 Tyonek D2 10,189.19 9,367.69 Tyonek D4A 10,020.19 9,198.69 Tyonek D3B 4,184.57 3,622.69 Sterling A-10 10/24/2016 12:01:49PM Page 6 COMPASS 5000.1 Build 81 • • Halliburton H AL L I B U R T!I N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan KBU 32-06 Company: Hilcorp Energy Company TVD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Project: Kenai Gas Field MD Reference: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Site: KGF 14-6 Pad North Reference: True Well: Plan KBU 32-06 Survey Calculation Method: Minimum Curvature Wellbore: KBU 32-06 Design: KBU 32-06 wp05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 Start Dir 3°/100':500'MD,500'TVD 1,744.38 1,658.48 306.41 242.06 End Dir :1744.38'MD,1658.48'TVD 3,705.43 3,218.99 1,219.32 1,001.75 Start Dir 2°/100':3705.43'MD,3218.99'TVD 4,664.02 4,063.82 1,562.99 1,281.94 End Dir :4664.02'MD,4063.82'TVD 8,827.60 8,021.10 2,572.67 2,091.80 Start Dir 2°/100':8827.6'MD,8021.11'TVD 9,733.19 8,911.69 2,683.40 2,180.62 End Dir :9733.19'MD,8911.69'TVD 10,486.50 9,665.00 2,683.40 2,180.62 Total Depth:10486.5'MD,9665'TVD 10/24/2016 12:01:49PM Page 7 COMPASS 5000.1 Build 81 • • 1 Hilcorp Energy Company Kenai Gas Field KGF 14-6 Pad ��q4 , Plan KBU 32-06 sl by 3 . KBU 32-06 KBU 32-06 wp05 Sperry Drilling Services Clearance Summary Anticollision Report 24 October,2016 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 14-6 Pad-Plan KBU 32-06-KBU 32-06-KBU 32-06 wp05 Well Coordinates:2,362,578.00 N,272,168.44 E(60°27'39.31"N.151°15'44.02"W) r Datum Height: KBU 32-06 wp05 @ 82.69usft(Saxon 169) Scan Range:0.00 to 10,486.50 usft.Measured Depth. Scan Radius is 1,246.85 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 81 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference "? Scan Type: 25.00 t . HALLIBURTON ,, lismy .._. :41111118 Sperry Drilling Services 0 i Hilcorp Energy Company HALLI B U RTO N Kenai Gas Field Anticollision Report for Plan KBU 32-06-KBU 32-06 wp05 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 14-6 Pad-Plan KBU 32-06-KBU 32-06-KBU 32-06 wp05 Scan Range: 0.00 to 10,486.50 usft.Measured Depth. Scan Radius is 1,244.52 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 KGF 14-6 Pad KBU 11-07-KBU 11-07-KBU 11-07 18.00 184.04 18.00 182.63 22.31 130.888 Centre Distance Pass- KBU 11-07-KBU 11-07-KBU 11-07 275.00 185.20 275.00 181.44 277.20 49.246 Ellipse Separation Pass- KBU 11-07-KBU 11--07-KBU 11-07 575.00 191.38 575.00 184.83 574.54 29.248 Clearance Factor Pass- KBU 14-06Y-KBU 14-06Y-KBU 14-06Y 523.83 130.96 523.83 123.96 529.46 18.710 Centre Distance Pass- KBU 14-06Y-KBU 14-06Y-KBU 14-06Y 550.00 131.10 550.00 123.76 555.71 17.867 Ellipse Separation Pass- KBU 14-06Y-KBU 14-06Y-KBU 14-06Y 900.00 160.93 900.00 149.13 903.96 13.649 Clearance Factor Pass- KBU 22-06-KBU 22-06-KBU 22-06 647.12 32.25 647.12 28.22 653.88 8.002 Centre Distance Pass- KBU 22-06-KBU 22-06-KBU 22-06 675.00 32.41 675.00 28.20 681.42 7.715 Ellipse Separation Pass- KBU 22-06-KBU 22-06-KBU 22-06 8,500.00 855.51 8,500.00 727.53 8,856.94 6.685 Clearance Factor Pass- KBU 22-06Y-KBU 22-06Y-KBU 22-06Y 796.93 118.09 796.93 113.82 816.04 27.708 Centre Distance Pass- KBU 22-06Y-KBU 22-06Y-KBU 22-06Y 825.00 118.16 825.00 113.79 845.35 27.010 Ellipse Separation Pass- KBU 22-06Y-KBU 22-06Y-KBU 22-06Y 1,300.00 179.23 1,300.00 158.11 1,316.60 8.485 Clearance Factor Pass- KBU 23-07-KBU 23-07-KBU 23-07 546.52 247.46 546.52 240.25 556.98 34.357 Centre Distance Pass- KBU 23-07-KBU 23-07-KBU 23-07 575.00 247.64 575.00 240.07 586.10 32.733 Ellipse Separation Pass- KBU 23-07-KBU 23-07-KBU 23-07 1,000.00 297.21 1,000.00 284.43 1,006.05 23.247 Clearance Factor Pass- KBU 23X-6-KBU 23X-6-KBU 23X-6 18.00 244.80 18.00 243.67 28.87 217.431 Centre Distance Pass- KBU 23X-6-KBU 23X-6-KBU 23X-6 50.00 244.87 50.00 243.57 59.77 188.327 Ellipse Separation Pass- KBU 23X-6-KBU 23X-6-KBU 23X-6 6,375.00 1,242.56 6,375.00 1,080.81 6,29922 7.682 Clearance Factor Pass- KBU 24-06-KBU 24-06-KBU 24-06 502.17 215.82 502.17 209.90 506.71 36.489 Centre Distance Pass- KBU 24-06-KBU 24-06-KBU 24-06 525.00 215.94 525.00 209.74 529.38 34.865 Ellipse Separation Pass- KBU 24-06-KBU 24-06-KBU 24-06 1,075.00 290.38 1,075.00 277.43 1,070.76 22.436 Clearance Factor Pass- KBU 24-06-KBU 24-06RD-KBU 24-06RD 502.17 215.82 502.17 209.90 506.71 36.489 Centre Distance Pass- KBU 24-06-KBU 24-06RD-KBU 24-06RD 525.00 215.94 525.00 209.74 529.38 34.865 Ellipse Separation Pass- KBU 24-06-KBU 24-06RD-KBU 24-06RD 1,075.00 290.38 1,07500 277.43 1,070.76 22.436 Clearance Factor Pass- KDU 1-KDU 1-KDU 1 500.00 316.33 500.00 1.50 507.31 1.005 Centre Distance Pass- KDU 1-KDU 1-KDU 1 - - - - KDU 1-KDU 1-KDU 1 - - 11111011111101 MIII - - KDU 1-KDU 1 PB-KDU 1 PB 500.00 316.33 500.00 1.50 507.31 1.005 Centre Distance Pass- 24 October,2016- 11:58 Page 2 of 6 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan KBU 32-06-KBU 32-06 wp05 Closest Approach 30 Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 14-6 Pad-Plan KBU 32-06-KBU 32-06-KBU 32-06 wp05 Scan Range:0.00 to 10,486.50 usft.Measured Depth. Scan Radius is 1,244.52 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 KDU 1-KDU 1 PB-KDU 1 PB 11.111111111 II. IIMMI KDU 1-KDU 1 PB-KDU 1 PB - - - S MI= 111111=11111= KU 13-6-KU 13-6-KU 13-6 799.80 71.03 799.80 64.78 824.71 11.357 Centre Distance Pass- KU 13-6-KU 13-6-KU 13-6 800.00 71.03 800.00 64.78 824.92 11.353 Ellipse Separation Pass- KU 13-6-KU 13-6-KU 13-6 925.00 78.96 925.00 71.33 948.14 10.353 Clearance Factor Pass- KU 14X-6-KU 14X-6(KDU 8)-KU 14X-6 18.00 149.99 18.00 148.87 22.31 133.205 Centre Distance Pass- KU 14X-6-KU 14X-6(KDU 8)-KU 14X-6 500.00 150.63 500.00 147.43 504.01 47.057 Ellipse Separation Pass- KU 14X-6-KU 14X-6(KDU 8)-KU 14X-6 1,000.00 217.23 1,000.00 209.62 997.37 28.546 Clearance Factor Pass- KU 21-7X-KU 21-7X-KU 21-7X 719.39 96.47 719.39 92.67 724.72 25.410 Centre Distance Pass- KU 21-7X-KU 21-7X-KU 21-7X 750.00 96.56 750.00 92.62 755.18 24.494 Ellipse Separation Pass- KU 21-7X-KU 21-7X-KU 21-7X 1,000.00 109.82 1,000.00 104.55 1,001.02 20.852 Clearance Factor Pass- KU 31-7X-KU 31-7X-KU 31-7X 521.84 218.82 521.84 212.26 527.54 33.371 Centre Distance Pass- KU 31-7X-KU 31-7X-KU 31-7X 575.00 219.12 575.00 211.88 581.34 30.269 Ellipse Separation Pass- KU 31-7X-KU 31-7X-KU 31-7X 2,100.00 458.66 2,100.00 421.59 2,090.62 12.374 Clearance Factor Pass- KGF 41-7 Pad KBU 31-06X-KBU 31-06X-KBU 31-06X 6,325.00 555.00 6,325.00 471.76 6,693.21 6.668 Clearance Factor Pass- KBU 31-06X-KBU 31-06X-KBU 31-06X 6,600.00 537.95 6,600.00 460.22 6,940.87 6.921 Ellipse Separation Pass- KBU 31-06X-KBU 31-06X-KBU 31-06X 6,711.31 536.65 6,711.31 461.89 7,046.65 7.179 Centre Distance Pass- KBU 33-06-KBU 33-06-KBU 33-06 6,925.00 595.30 6,925.00 530.82 6,851.53 9.233 Clearance Factor Pass- KBU 33-06-KBU 33-06-KBU 33-06 6,979.68 594.82 6,979.68 530.42 6,899.89 9.235 Ellipse Separation Pass- KBU 33-06x-KBU 33-06x-KBU 33-065 6,691.94 742.11 6,691.94 642.78 6,678.43 7.471 Centre Distance Pass- KBU 33-06x-KBU 33-06x-KBU 33-06x 6,750.00 742.71 6,750.00 642.44 6,723.27 7.407 Ellipse Separation Pass- KBU 33-065-KBU 33-06x-KBU 33-06x 7,400.00 797.25 7,400.00 684.48 7,312.09 7.070 Clearance Factor Pass- KBU 42-6-KBU 42-6-KBU 42-6 8,750.00 1,048.34 8,750.00 934.53 8,624.00 9.212 Clearance Factor Pass- KBU 42-6-KBU 42-6-KBU 42-6 8,768.76 1,048.17 8,768.76 934.45 8,624.00 9.217 Ellipse Separation Pass- KBU 42-6X-KBU 42-6X-KBU 42-6X 9,425.00 926.90 9,425.00 797.20 10,278.00 7.147 Clearance Factor Pass- KBU 42-6X-KBU 42-6X-KBU 42-6X 9,434.19 926.84 9,434.19 797.16 10,278.00 7.147 Ellipse Separation Pass- KTU 43-06X-KTU 43-6X-KTU 43-6X 8,450.00 644.33 8,450.00 479.97 8,420.00 3.920 Clearance Factor Pass- KTU 43-06X-KTU 43-6X-KTU 43-6X 8,500.00 640.40 8,500.00 478.36 8,420.00 3.952 Ellipse Separation Pass- KTU 43-06X-KTU 43-6X-KTU 43-6X 8,525.43 639.90 8,525.43 479.39 8,420.00 3987 Centre Distance Pass- 24 October,2016- 11:58 Page 3 of 6 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan KBU 32-06-KBU 32-06 wp05 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: KGF 14-6 Pad-Plan KBU 32-06-KBU 32-06-KBU 32-06 wp05 Scan Range: 0.00 to 10,486.50 usft.Measured Depth. Scan Radius is 1,244.52 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 KTU 43-06X-KTU 43-6XRD-KTU 43-6XRD 9,650.00 560.54 9,650.00 382.73 9,535.00 3.152 Clearance Factor Pass- KTU 43-06X-KTU 43-6XRD-KTU 43-6XRD 9,675.00 559.79 9,675.00 382.36 9,535.00 3.155 Ellipse Separation Pass- KTU 43-06X-KTU 43-6XRD-KTU 43-6XRD 9,679.99 559.76 9,679.99 382.45 9,535.00 3.157 Centre Distance Pass- KTU 43-06X-KTU 43-6XRD2-KTU 43-6XRD2 7,900.00 758.13 7,900.00 577.81 7,816.65 4.204 Clearance Factor Pass- KTU 43-06X-KTU 43-6XRD2-KTU 43-6XRD2 8,000.00 753.46 8,000.00 574.83 7,888.18 4.218 Ellipse Separation Pass- KTU 43-06X-KTU 43-6XRD2-KTU 43-6XRD2 8,073.39 752.44 8,073.39 575.24 7,940.76 4.246 Centre Distance Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.00 1,500.00 KBU 32-06 wp05 MWD+SC+sag 1,500.00 6,600.00 KBU 32-06 wp05 MWD+SC+sag 6,600.00 10,486.50 KBU 32-06 wp05 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. 24 October,2016- 11:58 Page 4 of 6 COMPASS • • Hilcorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan KBU 32-06-KBU 32-06 wp05 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to KBU 32-06 wp05 t 82.69usft(Saxon 169). Northing and Easting are relative to Plan KBU 32-06. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is:-1.10°. Ladder Plot LEGEND � L\ Q f� KBU22-06,KBU22-06KBU2206V0 9/-------- IhiJ ,1 -. . p I $ KBU22-06Y,KBU22-06Y,KBU22-06YVO 050 0,ri rf4 A700—.._ ! �\ ,, r e $ KBU 31-06X,KBU31-06X,KBU 31-06XV0 co i :it i i \\, ► c, I C- $KBU33-06,KBU33-06,KBU33-06V0 tv ,` 6'��rl -G-KBU33O6x,KBU33-06x,KBU33-06xV0 1L -- - + �a a -, $ KBU 42-6,KBU42-0,KBU42-6 V0 1.12 c i'Ir{ i —3-- KBU42-6X,KBU42-6X,KBU42-0X VO a) / ' I i $ K1U43-06X,KTU43-6X,KTU43-6XVO 350 'A''UO , i.; i $ KTU43-06X,KTU43-0XRD,KTU43-6XRDV0 r!' .i i i i -f KTU4306X,KTU43-0XRD2,KTU43-0XRD2V0 L - i i $ KBU 11-07,KBU 11-07,KBU 11-07 V0 5) ^ f, i I $ KBU 2307,KBU23-07,KBU23-07V0 U -X- KBU24-06,KBU24-06,KBU24-06V0 0 -A- KBU 24-06,KBU 24-06RD,KBU 24-06RD VO 0 2000 4000 6000 8000 10000 9•• KDU1,KDU1,KDU1VO -e- KDU1,KDU1PB,KDU1PBVS Measured Depth(2000 usft/in) $ KBU 32-06wp05 24 October,2016- 11:58 Page 5 of 6 COMPASS i • Hikorp Energy Company HALLIBURTON Kenai Gas Field Anticollision Report for Plan KBU 32-06-KBU 32-06 wp05 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor _ 44> ►1I /I I 1 `t I I \ LEGEND 10.00 _ -- 111 11.... M II \ S 0.:=,12 ,�//�� -W KBU 14-06Y,KBU 14-06Y,KBU 14-06Y VO ,' i, 0 $ KBU 22-06,KBU 22-06,KBU 22-06V0 8.75 i, 11 -d- KBU 22-06Y,KBU 22-06Y,KBU22-06YVO „...... II Ilk $ KBU 23X-6,KBU 23X-6,KBU 23X-6V0 7.50 �� -I-go KU13-6,KU13-6,KU13-6V0 ,, 0�e `�vi� $ KU 14X-6,KU 14X-6(KDU 8),KU 14X-6 VO ILI. s - 7 -1- KU 21-7X,KU 21-7X,KU 21-7X V0 6.25 ---- - $- KU 31-7X,KU 31-7X,KU 31-7X VO `o - s,. ti - -e- KBU 31-06X,KBU 31-06X,KBU 31-06XV0 LL - -B- KBU33-06,KBU33-06,KBU33-06V0 p 5 .00 " ----- -0- KBU 33-06x,KBU 33-06x,KBU 33-06xV0 -e- KBU 42-6,KBU 42-6,KBU 42-6 VO cu A - KBU42-6X,KBU42-6X,KBU42-6XVO fn 3.75 - -rt- KTU 43-06X,KTU 43-6X,KTU43-6X VO _ $ KTU 43-06X,KTU 43-6XRD,KTU 43-6XRD VO 2.50 i .___ _-__ _ _____ ___ ___ $ KTU43-06X,KTU43-0XRD2,KTU43-6XRD2V0 -6- KBU 11-07,KBU 11-07,KBU 11-07V0 Collision Avoidance Req -No-GoZone-stopDdlling -4- KBU 23-07,KBU 23-07,KBU 23-07V0 1.25 litm $ KBU24-06,KBU24-06,KBU24-06V0 111........., ®® -r}- KBU 24-06,KBU 24-06RD,KBU 24-06RD VO - .....:.e.. _ $ KDU1,KDU1,KDU1V0 0.00 , iii 1111 1111 ' 1111 1111 1111 1111 1111 1111 1111 1111 iiia $ KDUI,KDUIPB,KDU1PBV0 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 $ KBU 32-06%05 Measued Depth(2000 usiVin) 24 October,2016- 11:56 Page 6 of 6 COMPASS Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Tuesday, December 20, 2016 1:01 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: KBU 32-06 drilling permit(PTD 216-137) Attachments: KBU 32-06 Drilling Program (rev0).pdf Follow Up Flag: Follow up Flag Status: Flagged Guy, Sorry it took me so long to get back to you on your questions for this permit. Attached are the documents with the corrections. For the KDU-01, Halliburton assumes a vertical well with blind tool codes in their planning,so it is absolutely the worst case scenario.We were unable to achieve a gyro survey in this well. However, it will not be an issue while drilling. Let me know if you have any additional questions. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 Darn.. I just saw there is some close crossing failures with KDU 01 but there don't make sense based on the data (400 ft away at 1200 ft and doesn't sound like much an issue). Can you follow-up on this? I thought we ran an E-line gyro on this well recently (KDU-01)so this would not be an issue? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or 1 forwarding it,and,so that the AOGCIaware of the mistake in sending it to yolt5ntact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov). Original Message From:Schwartz,Guy L(DOA) Sent:Wednesday, November 30,2016 1:47 PM To: Monty Myers<mmyers@hilcorp.com> Cc: Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: KBU 32-06 drilling permit(PTD 216-137) Just noticed that there is no casing test mentioned for the 10 3/4"(should be at step 15.10 .. ) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov). Original Message From: Monty Myers (mailto:mmyers@hilcorp.com] Sent:Wednesday, November 30,2016 1:29 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: Re: KBU 32-06 drilling permit(PTD 216-137) I will get those corrected and sent to you. Will email copies of those sheets be sufficient? Monty M Myers 907.538.1168 On Nov 30,2016, at 1:26 PM,Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov» wrote: Monty, A couple issues on the permit: 1) The cement calculations for the 4.5"casing seem to be off quite a bit. Please review and send me updated volumes. 2) FIT for the 10(3/4)"shoe is a little low.Would like to see 12.5 ppg vs 12 ppg EMW(step 15.13) 3) FIT value for the 7 5/8"shoe is not stated in step 18.14 2 • 0 Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov<mailto:Guy.schwartz@alaska.gov>). 3 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: k / PTD: Z l 3 7 Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: A ,.e_., POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 • 0 E N 0) o a) a , 2 E 4 0 Lo 8' E, = W V) O) , 0 c c, a �, o p ° 'v. Y, o, c c 0 ca ai Or E O c y w, y. �, ca 3 ca g. _;, " a o, Q -0 o s ca o, -oc o m o m u�i o, w' 3, �, y. c. N 4 Q- , 3 ifs a). QI �, V, (1) yNN7 , , �, aa) yo o ,o, 0' a V .o, o, , u; , o o, a o o. c �, O' n, (a �, € c .a o 0) C-. y, •V� @ M�. O� �, .c y, .N � os , O, -� 0 0. , _ , m O, .o r)' a m' U. 3, M ^ L y N U, 0 Y, O' O. O. O,0. -o y' O' 0 fa H •N co' , c N �, M, CU 3, N, y o N °o, „ 3,0 .0o ., w, CI �, y oQ a, W, y. 4' a 8; cd aE ' ai ° c' c o 3 g 0. CCP -co0ai m 03' a , ' , aiN,0a0) a cli W 0% o, N, w• a) , to.' V). a a), = Q; a y, O, ;, • ' d, rn °c, y 0 o, o. ; , ' o. V' L a co a), U, o, co„ y rn a w, , 0, 0. w 89 c Q) o O' O1 �' ' y. N, O �� '4i ti 3 N' c' a' o air .6.), -0-0 0- a`) co °' o' E' �' 3' o' .?' 0' t' M' a U V' V E a) o, y, �, a. 8' 0. y, y, 3, (0, N, ai, m, E. $i c Z0 � m. a0 c' : y, C. O, � 1.y, 00' �� €, .-� II, ca O, •p, � > 0 N ca. pp � �� _ c. y, � O. O p a, p c. a). O, N. _ a' 0 ' .�. c �� O. a U� cn• (a, coy -� � L, 0 D a c, X' C/? � (' U, C' 01 0. 3 Z ' c m O y ZD' O 0 L L) 0) m. 0 > cu a) Q, ' N N' m 0 a)' N U..1, Y 0 0) < y N.• v' 0) Y 0 �, co, 2, I _, a 0 0 N rl 0 0 r) Q, Q, a, a, ai, ai. N, 0, co, N, 0, 0, 0, ), < < <, 0. 0,, N, 0, 0 0 0 Q, 0 < N, 0,, N, a), 0. 0, Q, 0 0, < < <,, a Z, z >- >- >- >- >- >-. >- >- >- >- >-, >- z Z Z >- >- >- Z >- }. >- Z >- Z >- >- >- � >-, Z Z >- >- Z Z, oco y 6 . , , C. , E, , , , , , , , , , , o, U 'Z, G y, a) • , I '0 �. to E ' ' , � • O) • Ey, ' o(tea' • �r Lu . ia oa) o ci) �� -p _ o A o, c. `o = m T ..- ° 4 0 -p o, `o atS E W 5 O M d N y o J o •c o) w, 2 0 C, 0 ;, 2 ( c 01 t a y, o, 0` = , <' y, y, y. w E 0 O a) ,c V, N, a). a O. `, N m. 0) O, a s. c, C' y, c, g' 0:1 M' - a) 0, a). ;4 >, c' 0. •> H c 4 2 �, . ayi a y t' a) e 0 r n'. rn I N E, cc) o. -, V, c• , c E o- 0 o c. y ,, c L _ c, 0 Cl) . m y E Q a), w w c u' c $ m a, y o o' 0c of 3 U 'o 0. c w o, ar 0- 0 ;, > 4' YZ a ' ' -0 O' E' o > > °' V' co - ae co o' o' N o c m, 'a, m Q. m. -0 y >: o, rn a y, cW U y, ' o, c' °o c, c�c 3) : m, a o' o c' �'. m. � 0 c, a °,' Z' c) 'm, ac), 50' 4 3' a c s; fD' , .a J C, ca, c o «O. co, N, a a .0. r, w, -0 N o. -o. N N c ra N, CM ca 0 t, N O`, y. O, 0, Ow o Tc o a a yN !� 33 � , 'v, •°�, o, �, o uo, 4 .a �, o, 3, o, ° W a (n o, V, o, =; 'o v o a) a 00, ami O m E 0 o o °' o, Y, Fri ° o' y' •o' E. w' 0, E' t °) o ate)' °, y, 6,, o, uo 6:.0, , .0 Cl)` C> = v _ V ai •o ' N' 6:=' g co 0,, co E a. o 0 •0? a)' oa, ,N, .y co =, ,- '�, of a is m m f°' co, o' o E, 0, >; --�' c''' 3, 2, V' D, o' y' o, a Q a' a a CO ;' (a O a). ; C C, O`' 7 7 C, _SC, N -, '5 o' a) 2, - 7 w o, '0' •y, ' N a 0) N E• N >6 N a) N, -O '� c. 0' 0r N c m 5 0. a tom,' o 0 O 0 0 a) 2. -0 a) LL (a' Q _ V0 -O V 0 c. l6• �� V Y W •y, a) a), > .� �, t y. y U• C, fa, c E Oas a) E a;. u� ns. o. L, m c' 3 `o, �' �' w ai = CI) v, m o. `� N, �, I- O G, w' c'' ' ad a f. to' o o`, U `�' Ertl y .8 o o, p V m m, a)' "' a E -' 0 •E U 2 u. V \ U) . 0 a). a o' 0 ° .v .1., m (.0 :� a 0 .) a o a > > 3' 0) 'v �' a y c w, w > 3' a), CO' o-2. 'E, a> al, ai N Y T o Ci)) a00 .c m m' a' a, V 0. n a`> a`), co, a) 3' 2, o, �; �' d, .', o V. as -0 V •= O 0, t, 0 0, a a€) m, a, a), o, 0p N U c> z a, _ D, �. 5, 5; cn, »-, 0, 0' a, a, 0, 5' Q. o. 0, v), 0, 0, U, 0, < < °-, 0, m, m, 0, �, y, 2; a 0, ca, co, 0, rt.) W r O N M V CO 'c-'" W O N M V (n CO I,- CO 0) O e- N M U, CO t•%. M 0 Z' EN N N N N N N N N N M M M c) c M M M M co V U co o co .. 0 0 o a`) G O c O N -0+ N 0, N U 0 c M 0 0 CO N 0) 0 CO O RI N O N �J W fa O C O 0 E � Q. W O •E `oa 0 0) a J o Q O U W ›.; a s a v) Lu < c� 0 a (n • • 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 Well History file and to simplify 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. KBU 32-06 50-133-20658-00-00 Kenai Gas Field Kenai Peninsula Borough, Alaska February 1, 2017 – March 15, 2017 Provided by: Approved by: Jacob Dunston Compiled by: Ralph Winkelman Paul Webster Garnet Knopp Dylan Muller Distribution Date: April 25, 2017 KU 32-06 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 ........................................................................................................................................ 4 2.3 Daily Activity Summary ................................................................................................................... 4 3 GEOLOGICAL DATA ............................................................................................................................. 9 3.1 Lithostratigraphy ............................................................................................................................. 9 3.2 Lithology Details ........................................................................................................................... 10 3.3 Sampling Program ........................................................................................................................ 26 4 DRILLING DATA .................................................................................................................................. 27 4.1 Surveys ......................................................................................................................................... 27 4.2 Bit Record ..................................................................................................................................... 32 4.3 Mud Record .................................................................................................................................. 33 4.4. Drilling Progress ........................................................................................................................... 35 5 SHOW REPORTS ............................................................................................................................... 36 6 DAILY REPORTS ................................................................................................................................ 37 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD KU 32-06 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computers – Surface Logging (3) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 Ditch gas QGM gas trap; Flame ionization total gas & chromatography. Hook Load / Weight on bit WITS from Pason 1.0 hour total Pason locked up and reboot. Mud Flow In Calculated value derived from Strokes/Minute and Pump Output 0 Mud Flow Out WITS from Pason “ Pit Volumes, Pit Gain/Loss WITS from Pason “ Pump Pressure WITS from Pason “ Pump Stroke Counters (2) WITS from Pason “ Rate of Penetration Calculated from Pason “ RPM WITS from Pason “ Torque WITS from Pason “ WITS To/ From Pason Rigwatch Remote (HP Compaq) 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML038 Logging Geologists Years1 Days2 Sample Catchers/Loggers Years Days2 Dylan Muller 7 33 Garnet Knopp <1 12 Ralph Winkelman 27 25 Albert Bertram <1 21 Paul Webster 37 28 Marquel Mosebay 18 15 *1 Years’ experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. KU 32-06 3 2 GENERAL WELL DETAILS 2.1 Well Objectives KBU 32-06 is a 10,487’MD/ 9,665’TVD Beluga/ Upper Tyonek development well off the 14-06 pad in the Kenai Gas Field. Reservoir analysis and subsurface mapping has identified an undrained area of the Kenai Field that will target reserves in the D2, D3B and D4 sands. Secondary targets include the Lower Beluga – Upper Tyonek. The base plan is a directional wellbore with a kickoff point at 500’ MD. Maximum hole angle will be 37 deg. The vertical section will be 3457’. Operator: HILCORP ALASKA, LLC Well Name: KBU 32-06 Field: Kenai Gas Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Rance Pederson, Robert Wall , Clint Montague, Adam Dorr Location: Surface Coordinates 526’ FSL, 1250’ FWL, Sec 6, T4N, R11W, SM, AK Ground ( Pad ) Elevation 65.6’ AMSL Rotary Table Elevation 20.2’ RKB – 85.6’ AMSL Classification: Development – Gas API #: 50-133-20658-00-00 Permit #: 216-137 Rig Name/Type: Saxon 169 / Land / Double Spud Date February 1, 2017 Total Depth Date: February 25, 2017 Total Depth 10560’MD/ 9722.70’TVD Primary Targets Tyonek D2 9733’MD/ 8912’, Tyonek D3B 10020’MD/ 9199’TVD Tyonek D4A 10189’MD/ 9368’TVD Total Depth Formation: Tyonek Completion Status: 4 1/2” Casing LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service Schlumberger RFT, Halliburton CBL KU 32-06 4 2.2 Hole Data 2.3 Daily Activity Summary January 30, 2017: Rig up mudlogging unit January 31, 2017: Complete rigging up. Pick up and rack back pipe. February 1, 2017: Drill from 138’ to 360’. Circulate hole clean. Pull out of hole to 113’. Rack back HWDP. Pick up 2-Flex DC, run in hole w/ Jars & HWDP to 360’. Drill ahead to 795’. Kick off directional @ 488’. Pump sweep/circulate hole clean. Wiper trip from 795’ to 240’. Run in hole to 795’. Pull out of hole to 240’. Service rig. Wait on cuttings removal to G&I. Waiting on cuttings removal at report time. February 2, 2017: Wait on cuttings removal. Run in hole to 796’. Resumed drilling at 03:30. Drill from 796’ to 1509’. TD surface hole at 09:00. Circulate hole clean. Pull out of hole to 275’. Service rig. Run in hole to TD. Pump sweep & circulate bottoms up 3x. Pull out of hole. Rig down elevators/bails. Rig up casing bails & power tongs. Commence surface casing run w/ casing @ 524’ at report time. February 3, 2017: Continue running in hole w/ casing from 524’, landed at 1499’ at 03:00am. Rig up cement head & manifold lines. Circulate & prep for cement, build mud push. Pressure test lines. Pumped cement. Blow down cementer’s lines, rig down cementers. Clean rig components & pump out cellar. Install wellhead & begin nipple up BOP. February 4, 2017: Continue nipple up BOP. Rig down casing running equip. Rig up BOP testing equip. Test BOP. Rig down BOP testing equip. Begin picking up drill pipe and racking back in derrick. Picking up drill pipe at report time. February 5, 2017: Continue pick up drill pipe. Change out gooseneck, reattach Kelly hose. Move heavywall drill pipe in derrick. Continue picking up drill pipe. Frost/icing issues. Blow back Kelley hose/stand pipe. Pump spud mud through top drive, close manual IBOP, pressure test Kelley hose/gooseneck connections, break top drive off stump, install blowback swedge. Blow back Kelley hose/standpipe, break off blowback swedge. Prep floor to make up BHA#2. Making up BHA @ report time. February 6, 2017: Continue making up BHA #2. Run in hole w/ BHA #2 to 1412’ TAG. Drill out float equip and shoe track; drill to 1529’. Circulate hole clean. Displace mud to 6% KCL. Perform FIT test. Directional drill ahead from 1529’ to 2545’, back reaming/MADD passing every slide @ 180’/hr. Condition mud & circulate. Begin short trip to shoe @ 23:15. Short tripping @ report time. Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth LOT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 13 ½” 1509 1460.61 Sterling 8.9 30.64 10.75 1499 1452.01 12.5 9 7/8” 6810 6098.13 Middle Beluga 9.2 18.18 7.625 6802 6090.47 13.1 6 ¾” 10560 9722.70 Tyonek 11.8 7.96 4.5 KU 32-06 5 February 7, 2017: Continue trip to 1425’. Service rig. Run in hole from 1425’ to 2545’. Drill from 2545’ to 2890’. Pump sweep, no increase. Drill ahead from 2890’ to 3540’, back reaming/MADD passing every slide @ 180’/hr. Circulate hole clean 2x bottoms up. Wiper trip from 3540’ to 2487’. Service rig. Run in hole from 2487’ to 3540’. Pump sweep; 10% increase in cuttings. Drill ahead from 3540’. Drilling ahead at report time. February 8, 2017: Drill from 3540’ to 3971’. Pull out of hole to 3790’ and repair mud pump #2. Run in hole to 3971’. Drill from 3971’ to 4533’, reaming every stand, MADD pass all slides. Circulate 2x bottoms up. Wiper trip from 4533’ to 3474’. Service rig. Run in hole from 3474’ to 4533’. Drill ahead per directional plan from 4533’. Drilling ahead at 4710’ @ report time. February 9, 2017: Drill ahead from 4710’ to 5526’, backreaming every stand, MADD passing every slide. Circulate 2x bottoms up. Wiper trip from 5526’ to 4460’. Service rig. Run in hole from 4460’ to 5526’. Drill ahead as per directional plan from 5526’. Drilling ahead at 5651’ @ report time. February 10, 2017: Drill ahead from 5651’ to 6672’, backreaming every stand, MADD passing every slide. Drilling ahead at 6672’ @ report time. February 11, 2017: Drill to 6810’. CBU hole clean. POOH on elevators 6810’ to 6510’. Backream 6510’ to 5150’. POOH to casing shoe. Slip and cut drill line. Service rig. RIH 1 stand. CBU @ shoe. RIH at report time. February 12, 2017: Finish RIH to bottom. CBU, pump sweep. CBU hole clean. POOH on elevators. L/ D BHA. Rig up wireline. Run dummy tools to bottom. P/U RFT tools. February 13, 2017: Finish RFT tests. POOH with wireline and rig down. Make up clean out BHA. RIH. CBU at 1245’. Continue RIH to 2492’, CBU. February 14, 2017: Continue RIH to 3731’ CBU. RIH to 4969’, CBU. RIH to bottom, CBU. Pump sweep. CBU and raise pH. POOH. L/ D BHA. Change out rams. Test same. Rig up casing tools. Dummy run hanger. February 15, 2017: Run casing to MD 6802'. CBU at 1260’, 3305’, 5352’ and land casing at 6802’. Circulate mud for cement job. Rig down casing equipment. Rig up cementing equipment. February 16, 2017: Condition and circulate mud. Pump 5 bbls water to fill lines, low pressure test 2000 psi and high pressure test 3440 psi. Pump 41 bbls 10 ppg mud push with rig pumps. Pump 82 bbls 11 ppg lead cement, cement pump plugged off. Trouble shoot/repair plugged cement line. Pump 10 bbls 11 ppg lead cement, cement pump plugged off/unable to pump. Trouble shoot/repair plugged line/unable to repair. Pump out cement with rig pumps. Blow down mud lines back to mud pumps. Rig down cement head and mud lines. Flush out BOPE’s with black water. Circulate and condition mud. February 17, 2017: Circulate and condition mud. Cement casing (CIP @ 16:20 hours). Prepare for next stage of operations and BOP test. February 18, 2017: Continue to prepare for next stage of operations and BOP test. Test BOP. Test casing to 3500 psi for 30 minutes. Run casing bond log from 6688’ to 1600’. Make up BHA. February 19, 2017: Continue to make up BHA. Single in hole to 4420’. RIH and displace to 10.0ppg mud. Drill out shoe and make 20’ of new hole to 6830’. Perform FIT to 13.1 EqMW. Drill from 6830’ to 7066’. KU 32-06 6 February 20, 2017: Drill from 7066' to 7828'. Pump sweep, CBU, Begin Wiper trip to shoe. Pull on elevators to 7517'. Encounter tight hole and backream to inside shoe. February 21, 2017: RIH to ~6894’, pump sweep, work pipe and circulate sweep out. POOH to 6788’. Put well on trip tank, service rig. RIH on elevators. Safety ream last stand to bottom. Drill from 7828’ to 7830’, pump sweep (chasing sweep at ~7833’). Drill from 7830’ to 8510’ (pumping sweeps at 7955’, 8448’). February 22, 2017: Drill from 8510’ to 8819’. Pump and circulate out high viscosity sweep. Wipe hole from 8819’ to 7676’ (tight spots 8504’, 8191’, 8010’). Service rig. RIH from 7676’ to 8819’ (wash last stand down). Drill from 8819’ to 9106’ (pumping sweeps at 8820’, 9091’). February 23, 2017: Drill from 9106’ to 9803’ (pumping sweeps at 9504’, 9548’). February 24, 2017: Drill from 9803’ to 9817’, pump and circulate out sweep. Wipe hole to 8702’. Service rig. RIH from 8702’ to 9817’ (pumping sweep while washing last stand to bottom). Drill from 9817’ to 10335’. February 25, 2017: Drill from 10335’ to TD 10560’. Pump sweep, circulate and mud, while raising MW to 12.1 ppg. Wipe hole to shoe. Cut drilling line 116 feet. Service rig. RIH to 10503’. Wash last stand to bottom (15 feet of fill). Pump sweep, circulate and mud. February 26, 2017: Circulate and condition mud. POOH to 6647’. Pump dry job. POOH from 6647’ to 491’. Handle and lay down directional BHA. Make up bit, bit sub, and stabilizer for future clean-out run. Rig up Schlumberger wireline run. RIH with dummy run on wireline/rig down dummy run tools. February 27, 2017: Pick up RFT assembly and Gamma tool. RIH from surface to 10560’. Log out from 10560’ to 6800’, RIH from 6800’ to 10400’. Log from 10400’ to 6837’, collecting formation pressure samples. POOH with wireline. RIH with sidewall coring assembly to 9500’. February 28, 2017: Logging core samples from 9500’ to 6000’. POOH with wireline (retrieve 44 sidewall cores, 6 missed). Pick up Caliper tool/Gamma ray/Tel Status tools. RIH with CTEM/GR/Tel Status to 10481’. Log from 10481’ to 7700’. POOH with wireline. RIH with Gamma ray/Tel Status tools to 7700’. Begin logging from 7700’. March 1, 2017: Log up to 6802’. POOH with wireline. Rig down Schlumberger wireline. Service rig. Make up BHA and RIH to 6789’. Circulate bottoms up at 6789’ (Max Gas = 70u). RIH from 6789 to 8649’. Circulate bottoms up at 8649’ (Max Gas = 153u). RIH from 8649’ to 10454’. Wash from 10454’ to 10560’. Circulate bottoms up at 10560’ (Max Gas = 235u). Pump sweep, spot nut plug, POOH to 6784’. March 2, 2017: POOH from 6784’ to 380’, laying down drill pipe. RIH from 380’ to 4183’. Circulate bottoms up at 4183’. POOH from 4183’ to 380’, laying down drill pipe. Lay down BHA. Prepare to run 4.5” casing. Run 4.5” casing from 127’ to 1490’. March 3, 2017: Run 4.5” casing from 1490’ to 6780’. Circulate bottoms up (Max Gas = 24u) while changing out bails and elevators. Run 4.5” casing from 6780’ to 8853’. Circulate bottoms up (Max Gas = 38u). Run 4.5” casing from 8853’ to 9685’. Casing stuck at 9685’. Circulate and bring MW down to ~11.5 ppg (Max Gas = 45u). Spot brine/lube pill, let soak for one hour. Circulate, while working stuck pipe (Max Gas = 14u). March 4, 2017: Circulate, lowering MW to 11.0 ppg. Pump and spot Black Magic pill. Let pill work 1.5 hours. Work stuck casing (gained around a foot). Change out casing bails back to drilling bails, slip and cut 112’ of drill line. Work stuck casing. Let Black Magic work one hour. Work stuck casing. Let Black Magic work 0.5 hours. KU 32-06 7 March 5, 2017: Alternatively, let Black Magic work for 1 to 1.5 hours and work stuck casing. Lay out pup, remove drilling bails. Install long bails and elevators. Rig up Pollard wireline. Run free point with Pollard wireline. Lay down free point tool. Pick up 2nd free point tool. March 6, 2017: Run 2nd free point tool. Attempt to locate free point. POOH with free point wireline. Lay down free point tool. Rig up and RIH with Gamma ray/chemical cutter tool to 9455’. Fire off chemical cutter at 9455’. Pull up on stuck casing to 220K, still stuck. POOH with Pollard wireline. Lay out Pollard tools. Circulate casing (Max Gas 901u). Rig up and RIH with free point tool. POOH with free point tool. Adjust bow springs on tool. RIH with free point tool. Attempt to free point casing string. POOH with free point tool. March 7, 2017: Lay down free point tool. Pick up and RIH with Gamma ray/chemical cutter tool. Fire chemical cutter at 7262’ (Lost 60K of string weight). POOH with Gamma ray/chemical cutter tool on wireline. Cutter tool stuck in casing (at approximately 457’). Part wireline from rope socket. Rig Pollard wireline. POOH with 4.5” casing from 7260’ to 6645’ (did not locate cutter tool). Change out long bails to drilling bails and side door elevator. POOH with 4.5” casing from 6645’ to 4946’. Pump dry job. POOH with 4.5” casing from 4946’ to surface. Rig down Weatherford. Monitor well on trip tank. Clear rig floor and prepare to pick up drill pipe. Pick up drill pipe and rack back in derrick. March 8, 2017: Continue to pick up drill pipe and rack back in derrick (50 stands total). Rig up and prepare for BOP test. Perform shell test. Blow down choke manifold, test lines, and drain BOP. Fill BOP and choke manifold with water, work air out of lines and choke manifold. Test BOP. Rig down from BOP testing. Rig up Pollard wireline. RIH with impression tool to 7290’, tagged up at 7290’, POOH and it appeared that a turbolizer was on top of casing stub. Made second impression tool run and saw more marks indicating a turbolizer. Make up 4.5” magnet, RIH and POOH with 4.5” magnet (tagged up @ 7290’, unsuccessful). RIH and POOH with 2nd attempt (tagged up @ 1870’, unsuccessful). RIH and POOH with 3rd attempt 4.5” magnet (tagged up @ 7290’, unsuccessful). RIH and POOH with 4th attempt but with 3.5” magnet (tagged up @ 7290’, unsuccessful). Remove magnet, install single-arm wireline grabber in order to attempt to flip turbolizer up to fall around casing stub. RIH to 7309’, POOH with single- arm wireline grabber. March 9, 2017: Finish POOH with single-arm wireline grabber. RIH with impression tool, tagged up @ 7307’. POOH with impression tool (no impressions). RIH and POOH with impression tool (tagged up @ 7305’, 5 impressions of turbolizer). RIH with 3.5’ magnet (tagged up @ 7305’). POOH with 3.5 inch magnet slowly (unsuccessful). Remove magnet. Install single-arm wireline grabber in order to attempt to flip turbolizer. RIH with 4.5” magnet, could only get to 1640’. POOH. RIH with 4.5” magnet to 7305’. POOH, no fish. Rig down Pollard wireline. Make fishing BHA to 225’. RIH (single in) from 225’ to 3338’. Service rig. RIH (single in) from 3338’ to 4276’. RIH out of derrick from 4276’ to 6755’. Circulate bottoms up (Max Gas = 1493u). RIH from 6755’ to 7251’. Circulate bottoms up (Max Gas = 1157u). Work down to attempt to catch fish (pressured up to 3100 psi at 7255’). Caught fish, set 60K down, pulled up to 140K, set off jars. Set 60K down, pulled up to 140K, set off jars again. Rack back stand, pick up working single, set down to 48K, pick up to 160K. Taper tap slipped out of fish, went down and stung back into fish (20K down). Reengaged fish at 10 RPM, 13000 Torque, 1840 psi, 33% Flow. Pull up to 150K, taper tap slipped out again. Pump out of hole from 7255’ to 6789’. Circulate bottoms up at shoe (Max Gas = 1195u). March 10, 2017: POOH with taper tap. RIH with spear to 6754’. Circulate bottoms up (Max Gas = 568u). RIH from 6754’ to 7262’, break circulation and sting into fish (Max Gas = 1147u). Jar on fish to 300K, fish came loose. POOH with fish from 7262’ to 4609’ (top of fish inside casing). Circulate bottoms up (2 gas peaks, 1543u and 1319u). POOH with fish from 4609’ to 253’. Lay down single/XO/Intensifier/XO. Rack back 3 stands of HWDP. Make 5’ pup to fishing tools, secure fish, lay down XO/Jars/Bumper sub. Install lift sub in spear, pick up and set slips/collar clamp on casing. Rig up casing equipment. Lay down 4 ½” casing. KU 32-06 8 March 11, 2017: Continue to lay down 4.5” casing. Rig down casing equipment. Inspect and service rig. Make up overshot fishing assem bly. Single in from 224’ to 3212’. RIH out of derrick to 5200’. Circulate bottoms up (Max Gas = 1186u). RIH from 5200’ to 6758’. Circulate bottoms up (Max Gas = 1640u). RIH from 6758’ to 7869’. Circulate bottoms up (Max Gas = 1281u). RIH from 7869’ to 9742’. Circulate bottoms up (Max Gas = 1047u). Wash down from 9742’ to 10307’. Circulate and work pipe. Pump sweep, circulate, and prepare to engage fish. W ash/Ream down to fish, pick up (no overpull), lay down single, and pick up full stand. March 12, 2017: Work down, engage fish, set 70K down, pump pressure increased to 3000 psi, shut down pump, pick up 240K, fired jars, fish came free. Move fish up hole freely, stopped pipe movement briefly while circulating, got differentially stuck, worked pipe free. Pump out of hole from 10330’ to 6500’. Circulate bottoms up and condition mud. POOH on elevators to overshot, no fish. Clear floor and service rig. Lay down overshot fishing tools. Slip and cut 76’ drill line. Make up taper tap fishing assembly to 24’. Pick up 3 stands of HWDP to 224’. RIH from 224’ to 5514’. March 13. 2017: RIH from 5514’ to 6756’. Circulate surface to surface (Max Gas = 1179u). RIH from 6756’ to 8627’. Circulate bottoms up (Max Gas = 1452u). RIH from 8627’ to 10308’. Circulate bottoms up (Max Gas = 1390u). Work down and screw into fish. POOH from 10340’ to 6580’. Blow down top drive. POOH from 6580’ to fish. Lay down fish, change elevators, lay down fishing tools. Clean rig floor, clean/send down casing centralizers, and swap elevators. RIH from mule shoe to 5600’. March 14, 2017: RIH from 5600’ to 6791’. Circulate bottoms up (Max Gas = 1357u). Lay down drill pipe from 6791’ to 189’. RIH out of derrick to 3726’. Circulate bottoms up (Max Gas = 476u). Lay down drill pipe from 3726’ to 0’. Rig up to run 4.5” casing. Run 4.5” casing from surface to 3149’. March 15, 2017: Run 4.5” casing from 3149’ to 6779’. Circulate inside shoe (Max Gas = 1706u). Run 4.5” casing from 6779’ to 10548.2’. Circulate bottoms up with max gas of 1784u. Rig up for cement and pump cement. Canrig released 17:30. KU 32-06 9 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geo, Jacob Dunston FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Primary Tyonek D2 9733 8912 -8829 9,746 8,917 -8,834 Tyonek D3B 10020 9199 -9116 10,060 9228 -9,145 Tyonek D4A 10189 9368 -9285 10,254 9,420 -9,337 Secondary Upper Beluga 5325 4692 -4609 5,305 4,668 -4,585 Lower Beluga 6790 6085 -6002 6,793 6,082 -5,999 Tyonek 1B 8164 7391 -7308 8178 7403 -7320 KU 32-06 10 3.2 Lithology Details As per Hilcorp direction, a Canrig/NDS-provided full service mudlogging program, with lithology descriptions of interval-collected rock cuttings samples in the Sterling, Beluga and Tyonek Formations, was initiated at the 9 7/8” intermediate interval at 1509’. The Kenai Group formations of Alaska’s Cook Inlet Basin, which include the Sterling, Beluga, and Tyonek were deposited in a variable-energy fluvial system within a large closed fore-arc basin. The stratigraphic column consists of very dominant thin to massive sections of sandstone and claystone-siltstone, which are interrupted by extensively-distributed thinner zones of coal and carbonaceous rocks, locally to generally abundant thin layers of original and re-deposited volcanic ash, and minor beds of basal or modal conglomerate. Gradational upward-fining sequences and bi-modal zones are abundant within the sandstones. Stratovolcanoes, perpetually forming along the fore-arc’s margins; produced abundant widely-distributed deposits of vitric air fall volcanic ash; which became a major directly-derived source, and/or a consistent lithogenic influence, for all Tertiary soft-sediment rocks in the Cook Inlet Basin. Note that the special modifying term “tuffaceous” in Canrig/NDS Lithology Descriptions was created to address the diversity of volcanic-origin rocks in the Cook Inlet basin, and its use may include everything from discernible micro-shard concentrations of disaggregated volcanic glass to rare layers of vitric ignimbrite. Sand (1509' - 1590') = medium to medium light gray overall with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, green, orange, dusky red, pale rose; fine lower to coarse lower, dominantly fine upper to medium upper; angular to subrounded, dominantly subangular; poor to fair sorting; unconsolidated. Sand (1590' - 1650') = medium to medium light gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, light to dark green to greenish gray, pale rose, rust, orange, yellow and dusky red; very fine upper to very coarse lower, dominantly fine upper to medium upper; angular to subangular, trace subrounded; poor to fair sorting; dominantly disaggregated; non calcareous. Sand (1650' - 1700') = medium to medium light gray overall, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, green, orange, dusky red, pale rose; fine lower to coarse lower, dominantly fine upper to medium upper; angular to subangular with trace subrounded; fair to good sorting; unconsolidated. Tuffaceous Claystone (1700' - 1740') = light to very light gray; soft to slightly firm and fragile; irregular to wedge shaped cuttings; silty to clayey texture; dull luster; hydrophilic; moderately soluble; non expansive; fair cohesiveness; poor adhesiveness; non calcareous; very minor component of dominantly unconsolidated sand formation. Sand (1740' - 1800') = medium to medium light gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, light to dark green to greenish gray, pale rose, rust, orange, yellow and dusky red; very fine upper to trace coarse upper, dominantly fine upper to medium upper; angular to subangular, trace subrounded; poor to fair sorting; dominantly disaggregated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (1800' - 1860') = light gray with very light brownish gray secondary hues; soft to slightly firm; fragile; irregular wedge shaped; silty to clayey texture; dull to earthy luster; slightly soluble and expansive; fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. KU 32-06 11 Sand (1860' - 1920') = medium to medium light gray overall with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, green, orange, dusky red, pale rose; very fine upper to medium upper, dominantly fine lower to medium lower; angular to subangular; fair to good sorting; disaggregated; non calcareous. Tuffaceous Claystone (1920' - 1970') = light to very light gray; soft to slightly firm and fragile; irregular to wedge shaped cuttings; silty to clayey texture; dull luster; hydrophilic; moderately soluble; non expansive; fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (1970'-2030') = medium dark gray to medium gray with a strong salt and pepper appearance with abundant varicolored liths, dominantly medium to dark gray to black, clear to translucent quartz and volcanic glass, dusky red, rust, light to dark green to greenish gray and pale rose; very fine upper to coarse lower, dominantly fine lower to medium lower; angular to subangular; fair to good sorting; unconsolidated; non calcareous. Sand (2030' - 2080') = medium to medium light gray overall with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, green, orange, dusky red, pale rose; very fine upper to coarse lower, dominantly fine upper to medium lower; angular to subangular; fair to good sorting; disaggregated; non calcareous. Sand (2080' - 2140') = medium to medium dark gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, light to dark green, greenish gray, dusky red, rust, pale rose and yellow to yellowish green; very fine upper to very coarse upper, dominantly medium lower to coarse lower; angular to subangular; poor to fair sorting unconsolidated; non calcareous. Sand (2140' - 2200') = medium to medium dark gray overall with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, green, orange, dusky red, pale rose; very fine upper to coarse lower, dominantly fine upper to medium lower; angular to trace subrounded, dominantly subangular; fair to good sorting; unconsolidated; non calcareous. Sand (2200'-2260') = medium dark gray to medium gray with a strong salt and pepper appearance with abundant varicolored liths, dominantly medium to dark gray to black, clear to translucent quartz and volcanic glass, dusky red, rust, light to dark green to greenish gray and pale rose and yellow; very fine upper to coarse lower, dominantly medium upper to lower; angular to subangular; moderately well sorted; disaggregated; non calcareous. Sand (2260' - 2320') = medium to medium light gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, light to dark green to greenish gray, pale rose, rust, orange and dusky red; very fine upper to coarse lower, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poor to fair sorting; unconsolidated; non calcareous. Sand (2320'-2380') = medium dark gray to medium gray with a strong salt and pepper appearance with abundant varicolored liths, dominantly medium to dark gray to black, clear to translucent quartz and volcanic glass, dusky red, rust, light to dark green to greenish gray and pale rose; very fine upper to trace very coarse upper, dominantly fine upper to medium upper; angular to subangular; poor to fair sorting; disaggregated. Sand/ Coal (2380'-2410') = 75% sand medium gray/ salt and pepper appearance predominantly quartz with minor feldspar and lithic fragments; fine to medium grained; subangular to angular; poor to fair sorting; clayey matrix. 25% coal. KU 32-06 12 Sand (2410'-2470') = medium gray/ salt and pepper appearance; predominantly quartz with minor lith and very minor feldspar fragments; upper fine to lower coarse grained; subangular; fair to poor sorting, clay matrix. Sand/ Tuffaceous Claystone (2470'-2530') = light gray with minor salt and pepper appearance; fine to lower coarse grain size; fair to poor sorting; subrounded to subangular; predominantly quartz with minor lithic fragments; silt and tuffaceous clay aggregations and translucent clayey matrix. Tuffaceous Claystone (2530'-2590') = light gray/ milky with clayey texture; with abundant quartz grains and dark gray/ black lithic fragments of lower medium to lower coarse grain size; subrounded to subangular; poorly sorted. Tuffaceous Claystone (2590'-2650') = soft and fragile clumps, light gray/ milky with clayey texture with occasional black and buff colored lithic grains from silt to medium sand grain size; subangular; trace black microthin laminations and inclusions. Tuffaceous Claystone (2650'-2710') = pale gray fragile clumps with occasional coal fragments and minor black and buff colored clasts and very minor quartz and pyrite clasts with grain size from silt to lower medium sand, subrounded to subangular; fair to poor sorting; micro bedding apparent; coal content increasing downward. Tuffaceous Claystone (2710'-2770') = pale gray to buff colored; fragile clumps with occasional black and white microbedding. minor multicolored clasts mostly black, buff and light blue, ranging in size from silt to medium sand sized grains; subrounded to subangular; poorly sorted; larger clasts decreasing downward. Tuffaceous Claystone (2770'-2830') = cream to buff colored fragile clumps with some multicolored black/ buff/ white microbedding present. minor carbonaceous material indicated by HCl. occasional black and buff colored grains visible from silt to very fine sand grained; mostly lithic with very minor quartz; subrounded to subangular; poor sorting. Tuffaceous Claystone (2830'-2890') = milky-white to tan colored and occasionally light to medium blue fragile clumps, some black/ white microbedding and white/ black/ multicolored grains from silt sized to very fine sand, subrounded to subangular; poor sorting; trace quartz grains of similar size range; trace coal fragments. Tuffaceous Claystone (2890'-2920') = cream to buff colored clumps very friable with some micro laminations of black and white and occasionally blue; individual quartz and minor lithic grains visible from very fine to upper fine grained; minor coal fragments and trace pyrite grains. Sand (2920'-2970') = multicolored sand, predominantly gray and black colored with minor rust and blue colored grains, and minor fragile clumps of tuffaceous claystone decreasing downward; sand is dominantly quartz with minor lithics; upper very fine to upper fine grained; subrounded, fair sorting. Sand (2970' - 3030') = medium light gray to light gray overall with abundant multicolored liths, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, light green to greenish gray, rust, dusky red and pale rose; very fine upper to coarse lower, dominantly fine upper to medium lower; angular to subangular; poorly sorted; unconsolidated. Coal/ Carbonaceous Shale (3030'-3080') = black with brownish black secondary hues; firm to moderately hard and brittle; wedge shaped to flaky; platy; planar fracture dominant; smooth to silty texture; resinous to earthy luster; poorly developed; sub lignitic; coal grading to carbonaceous shale/ material; no outgassing observed. KU 32-06 13 Tuffaceous Claystone/ Tuffaceous Siltstone (3080' - 3130') = light gray with light yellowish gray and light olive gray secondary hues; soft to slightly firm; irregular shaped cuttings; silty to clayey texture; dull luster; hydrophilic; moderate to very soluble; slightly expansive; fair cohesiveness; poor adhesiveness; non calcareous. Coal/ Carbonaceous Shale (3130'-3170') = black with brownish black secondary hues; firm to moderately hard and brittle; wedge shaped to flaky; platy; planar fracture dominant; smooth to silty texture; resinous to earthy luster; poorly developed; sub lignitic; coal grading to carbonaceous shale/ material; no outgassing present. Tuffaceous Claystone/ Tuffaceous Siltstone (3170' - 3230') = light gray with very light brownish gray secondary hues; soft to slightly firm; fragile; irregular to wedge shaped cuttings; silty to clayey texture; dull luster; hydrophilic; slight to moderately soluble and expansive; fair to good cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds throughout interval. Sand (3230' - 3300') = medium light gray to light gray overall with abundant multicolored liths, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, light green to greenish gray, rust, dusky red and pale rose; very fine upper to medium upper, dominantly fine; angular to trace subrounded, dominantly subangular; fair to good sorting; disaggregated; non calcareous Sand (3300' - 3360') = medium to medium light gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, light to dark green, greenish gray, dusky red, rust, pale rose and yellow to yellowish green; very fine upper to coarse lower, dominantly medium lower to fine lower; angular to subangular; poor to fair sorting; unconsolidated; non calcareous. Sand (3360' - 3420') = medium light gray to light gray overall with abundant multicolored liths, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, light green to greenish gray, rust, dusky red and pale rose; very fine upper to very coarse upper, dominantly fine upper to medium upper; angular to subangular; poorly sorted; unconsolidated; non calcareous. Sand (3420'-3470') = medium gray to medium light gray with strong salt and pepper appearance with abundant varicolored liths, dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, dusky red, rust, light to dark green to greenish gray and pale rose; very fine upper to very coarse upper, dominantly medium lower to upper; angular to subangular; poorly sorted; unconsolidated; non calcareous. Sand (3470' - 3540') = medium to medium light gray overall with abundant multicolored liths, dominantly clear to translucent quartz and volcanic glass, light to dark gray, black, light to dark green, greenish gray, dusky red, rust, pale rose and bluish green; very fine upper to very coarse upper, dominantly fine upper to coarse lower; angular to trace subrounded, dominantly subangular; poorly sorted; unconsolidated; non calcareous. Sand (3540' - 3620') = medium light gray to light gray overall with abundant multicolored liths, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, light green to greenish gray, rust, dusky red and pale rose; very fine upper to coarse lower, dominantly fine upper to medium lower; angular to subangular; fair to good sorting; disaggregated; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (3620' - 3670') = light to very light gray with very light yellowish gray secondary hues; soft to very firm; irregular shaped cuttings; silty to clayey texture; dull to earthy luster; moderately soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. KU 32-06 14 Tuffaceous Claystone/ Coal (3670'-3730') = milky-white to buff-colored fragile clumps, black and white micro laminations present. some light blue hues present; individual grains visible from very fine to medium sand sized; angular to subangular; mostly lithic with trace quartz; poorly sorted; coal fragments. Sand (3730'-3770') = salt and pepper colored; roughly equal proportions of quartz and lithics; lower to upper fine grained; poorly sorted; angular to subangular clasts; heavily matrix-supported by milky white clayey matrix; tendency to appear in fragile clumps; some occasional microbedding apparent. Coal (3770'-3800') = coal dominated with some milky white/ banded tuffaceous claystone clumps present and some multicolored sand grains of fine to lower medium grain size; mostly quartz with some black and buff colored lithics; subangular to subrounded Tuffaceous Claystone/ Tuffaceous Siltstone (3800'-3840') = fragile clumps of salt and pepper colored, clay supported grains ranging from silt to lower medium sand sized clasts; quartz abundant with lesser black and tan colored volcanic lithics; subrounded to subangular; poor to fair sorting. Coal/ Tuffaceous Siltstone (3840'-3900') = coal dominated with abundant fragile to firm clumps of milky- white to mottled tuffaceous claystone and siltstone; minor grains visible from very fine to medium sand sized, equal proportions of quartz and volcanic lithics; subrounded to subangular; poorly sorted; intermittent micro bedding present in clumps. Tuffaceous Siltstone (3900'-3950') = aggregations of multi-colored (white, black, tan, lesser blue) grains ranging from silt to medium sand sized; subrounded to subangular; poorly sorted; supported by dominant clayey matrix; coal fragments. Sand (3950'-4050') = olive black to olive grey to medium dark grey; grain supported trending to tuffaceous clay matrix supported by 4050'; fair to poor sorting; subangular to rounded; low to high sphericity; 70% quartz, frosted surface on more rounded grains, remainder lithics and 5% coal fragments; unconsolidated; moderately calcareous. Tuffaceous Siltstone (4050'-4100') = olive grey to light olive grey; very soft, occasional firm to very firm; crumbly to slightly malleable; blocky fracture when visible; dull luster; gritty to silty texture; abundant inclusions of medium to small sand grains and carbonaceous material; sporadic microlaminae of carbonaceous material; slightly to moderately calcareous Tuffaceous Siltstone (4100'-4160') = olive black to greenish black; mostly pulverized by bit and annulus action; when visible, malleable to crumbly; irregular fracture massive to wedged cuttings habit; earthy luster; abrasive to gritty texture; abundant microlaminae of carbonaceous material/ coal up to 1 mm thick; very arenaceous; many loose sand grains; predominately quartz, secondary lithics; mildly calcareous. Tuffaceous Siltstone (4160'-4220') = greenish black to greyish black; mostly pulverized cuttings; well hydrated; crumbly; irregular fracture; wedged to tabular cuttings; earthy luster; silty to gritty texture; massive to laminae structure when visible; very arenaceous, predominately quartz, secondary lithics; microlaminae of coal and carbonaceous material, mild to non calcareous; abundant unconsolidated sand grains same as imbedded in preserved cuttings. Coal (4220' - 4280') = black; hard; brittle at times; flaky to platy to blocky; massive; planar fracture dominant with conchoidal and birdeye present; smooth texture; resinous luster; trace prolonged outgassing bubbles observed; well developed; subbituminous to bituminous; occasionally grading to brownish black carbonaceous shale; firm to fragile; earthy luster; silty texture. KU 32-06 15 Sand (4280' - 4350') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace amounts of light to dark gray, black, green to greenish gray; pale rose, dusky red; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; dominantly unconsolidated with scattered sandstone; very light yellowish gray; very fine; fragile; commonly grading between sandy siltstone and silty sandstone; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (4350' - 4410') = light gray to very light gray with very light brownish gray and very light greenish gray secondary hues; very soft to moderately firm; irregular, tabular cuttings; silty to clayey texture; dull luster; moderately soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand/ Tuffaceous Sandstone/ Tuffaceous Siltstone (4410' - 4490') = very light gray with very light olive gray secondary hues overall; individual grains dominantly clear to translucent quartz and volcanic glass with trace amounts of multicolored liths; very fine lower to fine upper; angular to subangular; well sorted; disaggregated; non calcareous; trace sandstone with ashy supporting matrix; grayish white; very fragile; common very light brownish gray sandstone very fine lower; soft to firm; fragile at times; commonly grades between silty sandstone and sandy siltstone. Tuffaceous Claystone/ Tuffaceous Siltstone (4490' - 4530') = very light gray with light yellowish gray secondary hues; soft to slightly firm; fragile to pulverulent; irregular to wedge shaped with trace pdc bit action "scooped" appearance; silty to clayey; dull to waxy luster; non calcareous. Sand (4530'-4590') = multicolored sand with abundant clear and translucent quartz grains and black, rusty and buff-colored lithics and grains of aggregated siltstone; lower fine grained to lower coarse grained; rounded to subangular; moderate sphericity; poorly sorted; grain supported but matrix becoming increasingly clay-dominated downward. Sand/ Tuffaceous Siltstone (4590'-4660') = multi-colored sand with abundant clear subspherical quartz and lesser black and rust colored volcanic lithics; lower medium to coarse grained; rounded to subangular; fair sorting; firm to fragile clayey clumps and nodules of tuffaceous siltstone, with some micro bedding present; clay matrix increasing with depth. Sand (4660'-4720') = salt and pepper colored sand with dominant clear subspherical quartz and white, rust, and black colored lithics; lower medium to lower coarse grained; subrounded; fair sorting; mixed with subspherical nodules of semi consolidated, finer grained sandstone and siltstone with a clayey matrix clay content appears to be increasing with depth. Sand (4720'-4780') = multicolored sand with equal quartz and lithic components; lower to upper medium grained; subangular to subrounded; poorly sorted with clayey and silty matrix; increasing firm to fragile nodules of fine grained, semi-consolidated sandstone present with clayey matrix. Sand (4780'-4830') = medium dark grey to slightly olive grey; upper very fine to lower medium; poor sorting; subangular to subrounded; moderate to low sphericity; tuffaceous clay-silt matrix when clasts visible; easily friable; mostly unconsolidated; dominate quartz grains with secondary lithics; non to very mildly calcareous. Sand/ Tuffaceous Sandstone (4780' - 4910') = medium dark grey to slightly olive grey; upper very fine to lower medium, occasional lower coarse quartz grains; very poor sorting; subround to subangular, rare angular; low to moderate sphericity; mostly disaggregated, secondary easily friable clasts with tuffaceous clay/silt matrix; dominate quartz but with increasing secondary lithic clasts and increasing carbonaceous inclusions; rare microlaminae coal and carbonaceous material; very mildly calcareous decreasing with depth. KU 32-06 16 Tuffaceous Sandstone/ Siltstone (4910'-4980') = olive black to medium dark grey to slightly olive grey; upper very fine to lower coarse; poor sorting; subrounded to subangular, rare angular; very low to moderate sphericity; very easily friable, tuffaceous silt/clay matrix; dominate quartz with increasing secondary lithics and abundant carbonaceous material; increasing to mildly calcareous. Sand (4980'-5050') = medium dark grey to dark grey to olive black; upper very fine to upper medium, increasing to common upper coarse by md 5040'; very poor sorting; smaller grains low sphericity and subangular to subrounded, coarse grains high sphericity and subrounded to well rounded; increasing tuffaceous clay matrix; dominant quartz with secondary lithics and carbonaceous material increasing with depth; moderately calcareous, decreasing with depth. Tuffaceous Siltstone (5050' - 5130') = medium dark grey to slightly medium grey; mostly well hydrated, amorphous cuttings with increasing definition with depth; crumbly; irregular fracture when visible; wedged, tabular cuttings; earthy luster; abrasive to granular texture; occasional microlaminae of carbonaceous material; abundant imbedded sand grains dominant lithics; secondary quartz grains; upper coarse to upper medium; moderate to high sphericity; subrounded; also upper to lower medium quartz grains; low sphericity, subangular to subrounded; Tuffaceous Sandstone (5150' - 5205') = olive grey to medium dark grey to slightly medium grey; upper very fine to lower very coarse; very poorly sorted; smaller grains very low to moderate sphericity, larger grains increasing moderate to high sphericity; smaller grains subrounded to subangular, rounded to subrounded with increasing grain size; tuffaceous clay matrix supported; dominant quartz, abundant lithics; very easily friable, much already disaggregated from annular action; moderately calcareous. Sand/ Tuffaceous Sandstone/ Conglomerate (5205' - 5280') = light gray to very light gray overall with individual liths dominantly clear to translucent quartz and volcanic glass with trace amounts of multicolored liths; very fine lower to trace very coarse upper, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poorly sorted; dominantly unconsolidated with ashy supporting matrix common; grayish white with abundant multicolored secondary hues; very fragile; non calcareous. Tuffaceous Claystone/ Tuffaceous Siltstone (5280' - 5340') = light to very light gray with very light olive gray and light brownish gray secondary hues; soft to fragile; silty to clayey texture; dull to waxy luster; moderately soluble; poor to fair cohesiveness; poor adhesiveness; non calcareous; trace black microthin carbonaceous laminations and inclusions. Sand (5340' - 5400') = medium to medium light gray with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, greenish gray, black and trace colored liths; very fine upper to trace very coarse upper, dominantly fine lower to medium lower; angular to trace subrounded, dominantly subangular; moderately well sorted; unconsolidated with trace ashy matrix supported grains; pulverulent; non calcareous; trace thin coal beds. Sand (5400' - 5450') = medium gray with greenish gray secondary hue, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, black; very fine upper to medium lower, dominantly fine; angular to subangular; moderately well to very well sorted; disaggregated; non calcareous. Sand (5450' - 5500') = medium to medium dark gray with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, greenish gray and black, very fine lower, trace very coarse lower, dominantly fine lower to medium lower; angular to subrounded, dominantly subangular; fair to good sorting; disaggregated; non calcareous. KU 32-06 17 Tuffaceous Claystone/ Tuffaceous Siltstone (5500' - 5525') = medium gray; soft to very firm; irregular shaped; silty to clayey texture; dull luster; moderately soluble; fair cohesiveness; poor adhesiveness; non calcareous. Tuffaceous Siltstone/ Tuffaceous Claystone (5525' - 5585') = loose clumps of milky-white to light gray tuffaceous siltstone and powdery white tuffaceous claystone; with occasional sand-sized clear quartz and dark lithic grains from fine to medium sand sized; subrounded to subangular; poorly sorted; abundant clayey matrix; some micro bedding of glass and other volcanic material. Tuffaceous Siltstone/ Tuffaceous Claystone (5585' - 5645') = medium gray/salt and pepper colored fragile to firm clumps of siltstone with occasional clear quartz, white feldspar, and black volcanic lithic sand grains of fine to coarse sand sized; lithics more angular while quartz more subrounded; poorly sorted; abundant clayey matrix. Tuffaceous Siltstone (5645' - 5700') = firm to fragile clumps of light to dark gray tuffaceous siltstone; occasionally with some micro bedding present, some fine to medium sand sized clear to light blue quartz grains and buff colored and black volcanic lithics; clay matrix abundant; minor coal fragments. Tuffaceous Siltstone/ Tuffaceous Claystone (5700' - 5760') = dark grey to medium dark grey; very hydrated cuttings, mostly amorphous globules; very tuffaceous clay with abundant sand and lithics in cuttings; sand dominant quartz: lower very fine to lower medium; moderate to low sphericity; subangular to subrounded; secondary lithics: upper coarse to lower medium; very mildly calcareous. Tuffaceous Claystone (5760' - 5835') = dark grey to medium dark grey; very well hydrated cuttings from annular action - no discernable shape, fracture, or other characteristics; amorphous globules of tuffaceous clay intermixed with lithics and quartz grains: lower coarse to lower medium; lower to moderate sphericity in smaller grains, subangular to subrounded increasing to moderate to high sphericity in larger grains, subrounded; mildly calcareous. Sand (5835' - 5900') = medium gray with a salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray and black; very fine lower to trace very coarse lower, dominantly fine lower to medium lower; angular to subangular; poor to fair sorting; unconsolidated; non calcareous; present as minor component in dominantly claystone formation; trace to common thin coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (5900' - 5960') = medium light gray with very light brownish gray secondary hues; very soft to slightly firm; irregular to shapeless cuttings; silty to clayey texture; dull luster; hydrophilic; very soluble; moderately expansive; poor to fair cohesiveness and adhesiveness; non calcareous; trace thin coals. Coal/ Carbonaceous Shale (5960'-6010') = black with brownish black secondary hues; firm to moderately hard and brittle; splintery to blocky planar fracture dominant with trace conchoidal and birdeye; smooth to slightly silty texture; resinous to earthy luster; poorly developed; subbituminous; no outgassing observed; present as very thin beds in dominantly claystone/ siltstone formation. Sand (6010' - 6070') = medium light to light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray and black; very fine upper to trace very coarse lower, dominantly fine; angular to subrounded, dominantly subangular; moderately well sorted; disaggregated; slight to moderately calcareous, (baracarb mud additive, crushed marble). KU 32-06 18 Tuffaceous Claystone/ Tuffaceous Siltstone (6070' - 6130') = medium light gray with very light brownish gray secondary hues; very soft to slightly firm; irregular to shapeless cuttings; silty to clayey texture; dull luster; hydrophilic; very soluble; moderately expansive; poor to fair cohesiveness and adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds throughout interval. Sand/ Conglomeratic Sand (6130'-6200') = medium gray with faint dark greenish gray secondary hues and salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black and light to medium greenish gray; very fine lower to very coarse upper, dominantly fine lower to medium upper; angular to subrounded, dominantly subangular; poorly sorted; disaggregated; non to slightly calcareous (baracarb contamination); trace thin coal beds throughout interval. Tuffaceous Claystone/ Tuffaceous Siltstone (6200' - 6270') = medium to medium light gray with light brownish gray secondary hues; soft to slightly firm; irregular to wedge shaped to shapeless, globular cuttings; silty to clayey texture; dull luster; hydrophilic; moderate to very soluble; slightly expansive; poor to fair cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds throughout interval. Sand/ Conglomeratic Sand (6270'-6330') = medium gray with weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray, black and light to medium greenish gray; very fine lower to very coarse upper, dominantly fine lower to medium upper; angular to subrounded, dominantly subangular; poorly sorted; disaggregated; non to slightly calcareous; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (6330' - 6400') = medium to medium light gray with light brownish gray secondary hues; soft to slightly firm; irregular to wedge shaped to pdc bit action shaped cuttings; silty to clayey texture; dull luster; hydrophilic; moderate to very soluble; slightly expansive; poor to fair cohesiveness; fair to good adhesiveness; non calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Sand (6400' - 6450') = medium gray with individual grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray and black; very fine upper to coarse lower, dominantly fine lower to medium lower; angular to subangular; poor to fair sorting; unconsolidated; non calcareous. Tuffaceous Siltstone/ Tuffaceous Claystone (6450' - 6500') = soft clumps of medium gray/salt and pepper siltstone and very fine to fine grained sand with abundant quartz and occasional larger (medium sand sized) grains of buff color and black volcanic lithics; quartz grains are subrounded and clear while lithics are subangular to angular; poorly sorted, ample clayey matrix. Sand (6500' - 6550') = subequal quantities of light to dark gray sand and clay-supported tuffaceous siltstone; sand has abundant upper fine to upper medium sized, subrounded quartz grains and slightly lesser dark gray to black subangular volcanic lithics of similar size; fair sorting, minor coal fragments. Tuffaceous Siltstone/ Sand (6550' - 6610') = medium to dark gray tuffaceous siltstone and sand with abundant clayey matrix, subrounded clear quartz grains from silt to lower medium sand sized; lesser black, white, and tan grains up to coarse sand sized; and more sub-angular, poor to fair sorting, minor coal fragments; clay content increasing and sand decreasing with depth. Tuffaceous Siltstone (6610' - 6670') = milky gray to salt and pepper soft lumps of tuffaceous siltstone, with abundant clayey matrix and clear quartz and white feldspar grains ranging from silt to upper fine sand sized; subrounded; and larger angular to subangular black lithic clasts up to very coarse grained, poorly sorted, occasional buff colored firm to fragile nodules of siltstone to very fine grained sandstone. KU 32-06 19 Tuffaceous Siltstone/ Claystone (6670' - 6730') = fragile clumps of milky white to light gray tuffaceous siltstone with some firmer clumps of darker gray - buff colored, micro bedded siltstone and claystone, occasional light blue hues among the bedded clumps; some angular to subangular grains visible up to fine sand sized; mostly black lithic but lesser subrounded quartz; minor coal fragments. Tuffaceous Claystone/ Siltstone (6730' - 6810') = medium dark grey to dark grey; hydrophilic cuttings, mostly amorphous globules exhibiting indiscernible characteristics; when visible, light grey tabular wedged cuttings with microlaminae carbonaceous material and coal; abundant fragments of same; globules imbedded with sand, possibly from annular travel; sand dominant quartz, poorly sorted lower medium to lower coarse; subrounded larger grains to subangular smaller. Tuffaceous Claystone / Tuffaceous Siltstone (6810' - 6950') = medium light to light gray with very light brownish gray and light yellowish gray secondary hues; very soft; very sticky; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; slimy to mushy; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair to good adhesiveness; non-calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in rare firm fragments; trace thin coal beds throughout interval. Sand (6965' - 7005') = dominant clear, common translucent, black, occasional greenish, gray; lower fine to lower coarse, dominant medium; dominant angular to subangular, occasional subround; dominant low to occasional high sphericity; dominant quartz, common misc. meta lithics, biotite, occasional feldspar. Tuffaceous Claystone (7015' - 7055') = dominant medium with trace to occasional moderate brown when carbonaceous; soft and mushy to moderately firm and crumbly; dull luster; grainy to finely grainy texture; occasionally thinly bedded coal seams; grading to tuffaceous siltstone; non to moderately calcareous. Sandstone (7065' - 7120') = very light to medium gray; hard to very firm; tough to moderately friable; lower very fine to upper medium; moderately sorted; angular to subround; low to moderate sphericity; densely grain packed to moderate matrix support; matrix is dominant argillaceous material to occasionally moderately bentonitic; common to abundant calcite cement; dominant quartz, common meta lithics, biotite, occasional feldspar. Tuffaceous Claystone / Tuffaceous Siltstone (7150' - 7200') = dominant medium to very occasional light gray; blocky to rounded cuttings; dominant soft and mushy to occasional moderately firm and crumbly; dull luster; finely grainy to grainy texture; common to occasional thinly bedded coals and sands; non calcareous; tuffaceous siltstone occasionally grades upward to sandstone. Sand (7210' - 7255') = dominant clear to translucent, occasional light gray, gray, white, black; lower fine to lower coarse, dominant medium grained; moderately to poorly sorted; dominant angular to subangular, occasionally subround; dominant low to occasional moderate sphericity; dominant quartz, occasional miscellaneous lithics and feldspar. Tuffaceous Claystone / Tuffaceous Siltstone (7255' - 7330') = medium to medium light gray with very light gray and very light brownish gray secondary hues; very soft; very sticky; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; slimy to mushy; hydrophilic; moderate to very soluble; slight to moderately expansive; poor cohesiveness; good adhesiveness; non-calcareous; trace to common dark brown to black microthin carbonaceous laminations and inclusions in firmer fragments; trace thin coal beds throughout interval. Coal / Carbonaceous Shale (7330' - 7390') = black with brownish black and grayish black secondary hues; firm to hard and brittle; platy, flaky to blocky; planar fracture dominant with trace conchoidal and KU 32-06 20 birdeye; smooth to silty texture; resinous to earthy luster; coal commonly grades to an earthy carbonaceous shale; trace outgassing bubbles observed from large and hard fragments. Tuffaceous Claystone / Tuffaceous Siltstone (7390' - 7450') = medium light to light gray with very light brownish gray and light yellowish gray secondary hues; very soft; very sticky; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; slimy to mushy; hydrophilic; very soluble; moderately expansive; poor cohesiveness; fair to good adhesiveness; non-calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions. Tuffaceous Claystone / Tuffaceous Siltstone (7450' - 7520') = medium light to light gray with very light brownish gray secondary hues; very soft, sticky; shapeless to trace PDC bit action shaped cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble moderately expansive; poor to fair cohesiveness; fair to good adhesiveness; non-calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds. Coal / Carbonaceous Shale (7520' - 7570') = black with brownish black and grayish black secondary hues; firm to hard and brittle; platy, flaky to blocky; planar fracture dominant with trace conchoidal and birdeye; smooth to silty texture; resinous to earthy luster; coal commonly grades to an earthy carbonaceous shale; bituminous to subbituminous; trace outgassing bubbles observed. Tuffaceous Claystone/ Tuffaceous Siltstone (7570' - 7640') = medium light to light gray with very light brownish gray secondary hues; very soft, sticky; shapeless to trace PDC bit action shaped cuttings; silty to clayey texture; dull to waxy luster; hydrophilic; very soluble; moderately expansive; poor to fair cohesiveness; fair to good adhesiveness; non-calcareous; trace to common thin coal beds throughout interval. Sand (7640' - 7700') = light gray overall with individual grains clear to translucent quartz and volcanic glass, light to dark gray; very fine lower to trace very coarse lower, dominantly fine lower angular to trace subrounded, dominantly subangular; poorly sorted; unconsolidated; non-calcareous; present in trace amounts in dominantly a tuffaceous claystone formation with trace thin coal bed throughout interval. Tuffaceous Claystone / Tuffaceous Siltstone (7700' - 7760') = medium light to light gray with very light brownish gray secondary hues; very soft, sticky; shapeless to trace PDC bit action shaped cuttings; silty to clayey texture; dull to greasy luster; hydrophilic; very soluble moderately expansive; poor to fair cohesiveness; fair to good adhesiveness; non-calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace thin coal beds. Tuffaceous Claystone / Tuffaceous Siltstone (7760' - 7820') = medium light to light gray; very soft; very sticky; shapeless, globular cuttings; silty to clayey texture; dull to greasy luster; slimy to mushy; very soluble; hydrophilic; poor cohesiveness; fair to good adhesiveness; non-calcareous; trace thin coal beds throughout interval. Sandstone (7845' - 7880') = medium to light gray; globular to rounded cuttings; very soft and mushy; lower fine to ultrafine grained; well sorted; consists of sand grains suspended and disseminated in abundantly argillaceous matrix; dominant quartz, common miscellaneous lithics. Tuffaceous Siltstone (7890' - 7915') = medium to light gray; rounded, globular cuttings; soft; mushy; dull luster; finely grainy texture; no evident structure; grades to tuffaceous claystone. Tuffaceous Claystone (7925' - 7950') = overall medium gray; slightly blocky cuttings; soft to slightly firm; mushy to easily crumbly; dull luster; very finely grainy texture; grades to tuffaceous siltstone. KU 32-06 21 Tuffaceous Claystone / Tuffaceous Siltstone (7950' - 8020') = light to very light gray with very light olive gray secondary hues; soft; sticky; shapeless to irregular, wedge shaped; silty to clayey texture; dull luster; very soluble poor to fair cohesiveness and adhesiveness; non calcareous; trace thin coals. Tuffaceous Sandstone / Sand (8020' - 8080') = very light gray to grayish white with a mottled appearance; irregular shaped; crunchy; fragile to pulverulent; noncalcareous; ashy matrix commonly supports loose sand grains; dominantly clear to translucent quartz and volcanic glass with trace darker lithologies; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted trace thin coal beds throughout interval. Tuffaceous Claystone / Tuffaceous Siltstone (8080' - 8130') = medium light to light gray with very light olive gray and light yellowish gray secondary hues; soft; sticky; irregular shaped; silty to clayey texture; dull luster; very soluble fair cohesiveness and adhesiveness; non-calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions; trace to common coal beds. Coal / Carbonaceous Shale (8130' - 8190') = black with brownish black secondary hues hard to brittle; flaky to massive; platy planar fracture dominant with scattered conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster; moderately well developed; bituminous; occasionally grading to an earthy carbonaceous shale; common, vigorous outgassing bubbles observed. Tuffaceous Sandstone / Sand (8190' - 8260') = light gray to grayish white with abundant varicolored secondary hues for a mottled appearance; very soft; crunchy; fragile to pulverulent; ashy matrix acts as a supporting matrix for sand; dominantly clear to translucent quartz and volcanic glass with trace darker lithologies; very fine lower to medium lower, dominantly fine; angular to subangular; moderately well sorted; very loosely supported by ashy matrix; non-calcareous; trace thin coal beds. Tuffaceous Claystone/ Tuffaceous Siltstone (8260' - 8320') = medium light to light gray with very light brownish gray and light yellowish gray secondary hues; very soft; irregular, shapeless to trace PDC bit action shaped cuttings; silty to clayey texture; dull to earthy to waxy luster; hydrophilic; moderately soluble and expansive; non-calcareous; trace dark brown to black microthin carbonaceous laminations and inclusions in firm fragments; trace thin coal beds. Coal / Carbonaceous Shale (8320' - 8380') = black with brownish black secondary hues hard to brittle; flaky to splintery; planar fracture dominant with scattered conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster; very well developed; bituminous; occasionally grading to earthy, carbonaceous shale; abundant outgassing bubbles. Sand / Tuffaceous Sandstone (8380' - 8440') = very light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, trace light to dark gray and pale rose; very fine upper lower medium; moderately sorted; sandstone with ashy to occasionally bentonitic matrix. Sand ( 8425' - 8460') = dominant clear to translucent, common white, black, occasional grays; lower fine to lower coarse, dominant medium; moderately sorted; dominant subangular to angular, common subround, occasional well rounded; dominant quartz, common metavolcanic lithics; occasional feldspar. Tuffaceous Siltstone (8470' - 8505') = medium to light gray; ovate to slightly blocky cuttings; soft and mushy; dull luster; occasional bedding structure with visible layers of more arenaceous and argillaceous material, fining downward and upward to claystone and sandstone; occasionally bentonitic. Tuffaceous Sandstone (8515' - 8555') = very light gray; rounded, moderately hydrated cuttings; very soft and mushy; ultrafine to lower fine, dominant lower very fine; moderately sorted; angular to subround, dominant subangular; moderate to low sphericity; bentonitic matrix support; dominant quartz, common metavolcanic lithics, occasional feldspar. KU 32-06 22 Tuffaceous Siltstone (8565' - 8585') = overall medium to light gray, occasional moderate when carbonaceous; soft and mushy; dull luster; finely grainy texture; grades to tuffaceous claystone. Coal (8595') = black; hard; moderately tough and brittle; silky luster; moderately smooth texture; common slightly fissile, dominant homogeneous; breaks angularly (across bedding when slightly fissile). Tuffaceous Sandstone (8650' - 8695') = light to very light gray; rounded, hydrated cuttings; soft; mushy; lower fine to lower medium; moderately sorted; subangular to round, overall moderate sphericity; suspended and disseminated in primarily bentonitic to partially kaolinitic matrix; dominant quartz, common volcanic shards/meta lithics, occasional feldspar. Coal (8705' - 8730') = black; hard; tough to moderately tough; silky, shiny luster; smooth texture; no evident structure; occasional associated carbonaceous material; angular random fracturing when crushed. Sand (8740' - 8785') = dominant clear to translucent, common gray, occasional white; upper very fine to lower medium, dominant upper fine; moderately sorted; dominant subangular to subround, common angular and round; dominant moderate, common low and high sphercity; dominant quartz, common (occasionally shardy) volcanic quartz and lithics, occasional feldspar. Tuffaceous Claystone (8795' - 8815') = medium gray; ovate cuttings; mushy to slightly firm; mushy to very easily crumbly; dull luster; very finely grainy; probably as thin stringers. Tuffaceous Sandstone / Sand (8820' - 8890') = light gray to grayish white with abundant varicolored secondary hues for a mottled appearance; very soft; crunchy; fragile to pulverulent; ashy matrix acts as a supporting matrix for sand; dominantly clear to translucent quartz and volcanic glass with trace darker lithologies; very fine lower to fine upper, dominantly fine; angular to subangular; moderately well sorted; dominantly disaggregated with ashy supported sandstone dominant. Coal (8890' - 8940') = black with brownish black secondary hues; hard to brittle flaky to platy and massive; planar fracture dominant with conchoidal and birdeye common; smooth to matte texture; resinous to slightly earthy luster; abundant and prolonged outgassing bubbles. Tuffaceous Siltstone (8940' - 8980') = very light brown with grayish orange hue very soft; very fragile; irregular shaped silty to clayey texture; earthy luster; non-calcareous. Sand (8980' - 9020') = dominant clear to translucent, common yellowish brown, occasional white, gray; lower fine to lower medium; moderate to well sorted; angular to subround, dominant subangular; dominant moderate to common low sphericity; dominant quartz, occasional to common lithics, occasional feldspar. Tuffaceous Sandstone (9030' - 9075') = very light gray; rounded cuttings; soft; mushy to easily friable; lower fine to upper medium; moderately sorted; angular to subround, dominant subangular; dominant moderate, occasional low sphericity (finer grains with higher sphericity); bentonitic matrix support; dominant quartz, common miscellaneous lithics, occasional feldspar. Tuffaceous Siltstone (9085' - 9115') = brownish gray; blocky to slightly platy cuttings; slightly firm to soft; easily crumbly to mushy; dull luster; finely to very finely grainy texture; no evident structure; fines downward to tuffaceous claystone. Tuffaceous Sandstone (9145' - 9175') = very light gray; soft; mushy to easily friable; lower fine to upper medium; moderate sorting; angular to subround; bentonitic matrix support, commonly very calcareous; dominant quartz, common lithics, occasional feldspar. KU 32-06 23 Coal / Carbonaceous shale (9175' - 9230') = black with brownish black secondary hues hard to brittle; flaky to splintery; planar fracture dominant with scattered conchoidal and birdeye; smooth to matte texture; resinous to slightly earthy luster; very well developed; bituminous; occasionally grading to earthy, carbonaceous shale; abundant outgassing bubbles. Tuffaceous Siltstone / Tuffaceous Claystone (9230' - 9290') = light to very light gray with very light brown and light brownish gray secondary hues; very soft; fragile; pulverulent; irregular, rounded with pdc bit action shaped cuttings; silty to clayey texture; dull to earthy luster; hydrophilic; moderately soluble; poor adhesiveness; poor to fair cohesiveness; non-calcareous; trace thin coal beds throughout interval. Sand / Tuffaceous Sandstone / Tuffaceous Siltstone (9290' - 9380') = light to very light gray overall with light yellowish brown and yellowish gray secondary hues; individual grains dominantly clear to translucent quartz and volcanic glass, light to dark gray and black; very fine lower to medium lower; angular to subangular; moderately well sorted; dominantly unconsolidated with ashy supporting matrix common; very fragile; light gray to grayish white; non-calcareous; common light yellowish gray siltstone; soft; earthy; very silty to gritty; grades between sandy siltstone and silty sandstone; trace dark brown to black microthin carbonaceous laminations and inclusions; scattered coal beds. Tuffaceous Sandstone / Sand (9380' - 9450') = light gray to grayish white with abundant varicolored secondary hues for a mottled appearance; very soft; crunchy; fragile to pulverulent; ashy matrix acts as a supporting matrix for sand; dominantly clear to translucent quartz and volcanic glass with trace darker lithologies; very fine lower to medium upper, dominantly fine upper; angular to subangular; fair sorting; dominantly disaggregated to friable; very ashy supporting matrix non-calcareous. Tuffaceous Sandstone / Sand (9450' - 9520') = very light gray to grayish white with a mottled appearance; irregular shaped; crunchy; fragile to pulverulent; non-calcareous; ashy matrix commonly supports loose sand grains; dominantly clear to translucent quartz and volcanic glass with trace darker lithologies; very fine lower to coarse lower, dominantly fine upper to medium lower; angular to trace subrounded, dominantly subangular; poor to fair sorting; disaggregated; ashy supporting matrix dominant. Tuffaceous Claystone / Tuffaceous Siltstone (9520' - 9570') = medium light gray with light brownish gray secondary hues; soft to slightly firm; irregular, discoidal with PDC bit action shaped cuttings; silty to clayey texture; earthy luster; non-calcareous; trace dark brown to black microthin carbonaceous laminae. Coal (9575' - 9590') = black; hard to very firm; tough to moderately tough, commonly brittle; moderately smooth texture; no evident structure. Tuffaceous Sandstone (9600' - 9660') = very light gray; irregular cuttings; soft to slightly firm; very easily friable; lower fine to upper medium, dominant upper fine to lower medium; unconsolidated individual grains to upper coarse; moderate sorting; angular to subround, dominant subangular; dominant moderate to common low sphericity; bentonitic matrix support; dominant quartz, common lithics, mafic- rich grains, occasional biotite, feldspar. Sand (9670' - 9710') = dominant clear to translucent, common black, gray, occasional white; lower fine to lower coarse, dominant lower medium to upper fine; angular to subround, dominant subangular; dominant moderate to occasional low sphericity; dominant quartz, com mafic-rich grains, occasional volcanic clastics, feldspar. Tuffaceous Sandstone (9720' - 9765') = very light gray; soft to slightly firm; easily friable; lower fine to lower medium; moderate to well sorted; angular to subround, dominant subangular; dominant moderate to common low sphericity; bentonitic matrix support; dominant quartz, common mafic-rich grains, volcanic clastics, occasional lithics, feldspar. KU 32-06 24 Tuffaceous Siltstone (9815' - 9860') = dominant medium to occasional brownish gray; slightly firm; easily crumbly; dull luster; finely grainy texture; occasional very thin seams of lignite; brownish with moderate amounts of nontuffaceous argillaceous material; fines down to tuffaceous claystone and up to ultrafine, marginal, rarely bentonitic tuffaceous sandstone. Tuffaceous Siltstone (9870' - 9950') = medium dark grey to medium grey to slightly olive grey; pulverulent tenacity; earthy to slightly planar fracture; tabular to wedge-like cuttings; earthy luster; gritty to granular texture; massive and sometimes slightly planar structure; rare microlaminae non-tuffaceous argillaceous material and coal less than 1 mm; included sand grains increasing with depth: dominant upper fine to lower medium, secondary lower fine and lower medium; low to moderate sphericity, well to subrounded, dominant quartz, secondary lignite fragments and lithics; mildly calcareous. Tuffaceous Siltstone (9950' - 10025') = olive grey grading to medium light grey with depth; pulverulent to crumbly, sometimes crumbly tenacity; dominant earthy fracture, occasional planar; tabular and wedge- like cuttings; earthy luster; abrasive to granular texture; massive and occasionally planar; trace to abundant imbedded sand: dominant quartz, secondary lithics; quartz lower fine to lower medium, low to moderate sphericity; well to subrounded; moderately calcareous. Tuffaceous Sandstone (10025' - 10110') = medium light grey to light grey to slightly light olive grey; lower very fine to upper medium; poor sorting; moderate to low sphericity in all grain sizes; subrounded to subangular; dominant quartz up to 80% with secondary lithics with occasional abundant lignitic fragments of similar size; grain supported tuff matrix clasts, easily friable and much disaggregated loose sands grains, possibly from annular travel; trace microlaminae carbonaceous material; mildly calcareous. Tuffaceous Sandstone (10120' - 10170') = light olive grey, olive grey, and olive black; lower fine to upper fine; trace lower medium; 90+% quartz; low to moderate sphericity; subrounded to subangular; grain supported clasts tuff matrix; easily friable with abundant loose sand, possibly disaggregated from annular travel; trace to 10% lithics, mostly lower to upper fine lignitic fragments; mildly calcareous. Sand (10170' - 10230' ) = olive grey to olive black; 80% quartz loose grains, 20% lithics, dominant lignitic fragments; quartz dominant lower very fine to upper very fine, secondary grading to upper medium; poor sorting; very low to low sphericity trace highly spherical; subangular to sub rounded, occasional very angular smaller and very rounded larger grains; mildly calcareous. Tuffaceous Sandstone (10230' - 10285') = light grey; lower very fine to upper medium; poor sorting; very low to moderate sphericity; angular to round, occasional very angular and very round in all grain sizes; easily friable tuff matrix supported; very low visible porosity; dominant quartz, common mafic-rich grains, lithics, occasional feldspar. Sandstone (10295' - 10355') = medium gray; blocky, rounded cuttings; slightly firm; easily friable to slightly mushy; lower very to upper fine; well sorted; angular to subround, dominant subangular; dominant moderate to occasional low sphericity; primarily consists of argillaceous matrix support, occasional grading to tuffaceous sandstone with bentonitic matrix; trace grain-packed calcite cemented hard, dense sandstone; dominant quartz, common mafic-rich grains, lithics, occasional feldspar. Sand (10385' - 10430') = dominant clear to abundant translucent; lower fine to upper coarse, dominant upper fine to lower medium; moderate sorting; dominant subangular to subround, common angular and round; dominant moderate, common low and high sphericity (well-rounded confined to finer grains); overall quartz with very minor amounts of other minerals. Tuffaceous Sandstone (10440' - 10485') = very light gray; blocky cuttings; slightly firm; easily friable; lower fine to upper medium; dominant subangular to subround, common angular, occasional rounded; KU 32-06 25 dominant moderate, common low, occasional high sphericity; bentonitic matrix support; individual grains dominant quartz, occasional lithics, feldspar. Coal (10495' - 10510') = black; hard to very firm; moderately to slightly tough but brittle; subbituminous; no evident structure. Sand (10520' - 10560') = dominant clear to abundant translucent; lower fine to upper coarse, dominant upper fine to lower medium; moderate sorting; dominant subangular to subround, common angular and round; dominant moderate, common low and high sphericity (well-rounded confined to finer grains); overall quartz with very minor amounts of other minerals. KU 32-06 26 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution 1 Washed and Dried Reference 1509’ – 10560’ 30’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 2 Washed and Dried Reference 1509’ – 10560’ 30’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 3 Washed and Dried Reference 1509’ – 10560’ 30’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 4 Washed, wet coal samples 3725’, 3780’, 4060’, 8134’ Spot sample Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 KU 32-06 27 4 DRILLING DATA 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) 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 109.17 0.07 95.44 109.17 -0.01 0.06 0.03 0.08 201.64 0.13 190.89 201.64 -0.11 0.09 -0.03 0.17 260.10 0.10 259.00 260.10 -0.19 0.03 -0.12 0.22 325.36 0.13 32.76 325.36 -0.14 0.02 -0.09 0.32 386.59 0.03 15.66 386.59 -0.06 0.06 -0.01 0.17 448.82 0.09 186.06 448.82 -0.10 0.06 -0.04 0.20 509.77 0.81 35.94 509.77 0.20 0.31 0.35 1.47 571.20 1.48 28.32 571.19 1.25 0.94 1.56 1.11 632.45 2.55 30.79 632.40 3.12 2.01 3.68 1.75 693.76 3.99 26.98 693.60 6.19 3.68 7.11 2.39 756.05 5.66 31.88 755.68 10.74 6.28 12.27 2.75 818.92 7.75 31.77 818.11 16.97 10.15 19.54 3.33 880.36 11.11 32.00 878.71 25.52 15.47 29.51 5.46 942.50 12.38 37.66 939.55 35.87 22.72 42.10 2.76 1004.11 15.00 39.33 999.41 47.26 31.81 56.67 4.31 1065.87 16.51 37.42 1058.84 60.41 42.20 73.43 2.58 1128.59 18.97 36.02 1118.58 75.74 53.62 92.51 3.99 1191.38 20.69 36.51 1177.64 92.91 66.22 113.77 2.75 1252.88 25.11 37.24 1234.28 112.04 80.59 137.66 7.19 1315.01 25.43 37.99 1290.47 133.05 96.78 164.17 0.74 1377.34 27.66 38.78 1346.22 154.88 114.08 192.02 3.62 1440.26 29.88 38.19 1401.37 178.58 132.92 222.28 3.55 1469.66 30.64 39.81 1426.77 190.09 142.24 237.10 3.79 1513.71 28.43 39.82 1465.09 206.77 156.14 258.81 5.00 1574.88 30.74 40.90 1518.28 229.77 175.70 289.00 3.86 1636.17 34.87 39.91 1569.79 255.07 197.21 322.20 6.81 1698.23 36.73 39.12 1620.12 283.07 220.30 358.50 3.09 1759.73 36.67 39.39 1669.43 311.54 243.56 395.26 0.28 1822.40 37.37 40.24 1719.47 340.51 267.72 432.99 1.39 1884.27 37.35 40.41 1768.64 369.13 292.02 470.52 0.16 1946.31 37.10 39.59 1818.05 397.89 316.14 508.06 0.89 2008.04 37.48 39.38 1867.15 426.75 339.92 545.46 0.65 2070.07 37.25 38.96 1916.45 455.94 363.70 583.10 0.56 KU 32-06 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2132.56 37.34 39.91 1966.16 485.18 387.75 620.96 0.94 2194.17 37.38 40.03 2015.13 513.83 411.77 658.35 0.14 2257.06 37.41 40.50 2065.10 542.97 436.45 696.54 0.46 2320.61 37.26 40.21 2115.63 572.34 461.41 735.08 0.36 2380.80 37.18 39.79 2163.57 600.23 484.82 771.48 0.44 2444.16 37.38 41.11 2213.98 629.43 509.71 809.86 1.30 2505.51 37.50 40.08 2262.69 657.75 533.99 847.15 1.04 2567.10 38.37 40.39 2311.26 686.66 558.44 885.02 1.44 2629.59 38.90 40.41 2360.07 716.37 583.73 924.03 0.84 2691.43 38.12 40.63 2408.46 745.64 608.74 962.53 1.27 2753.84 37.54 40.41 2457.75 774.74 633.61 1000.80 0.96 2816.61 36.99 40.60 2507.71 803.64 658.30 1038.81 0.90 2879.62 37.09 39.75 2558.01 832.64 682.78 1076.76 0.83 2940.85 37.01 39.48 2606.87 861.06 706.31 1113.65 0.29 3002.69 37.19 40.53 2656.20 889.63 730.29 1150.95 1.06 3064.63 37.25 39.83 2705.52 918.25 754.46 1188.42 0.70 3126.92 37.71 39.73 2754.95 947.38 778.71 1226.32 0.75 3187.94 37.26 39.67 2803.38 975.95 802.43 1263.45 0.75 3250.72 36.74 39.87 2853.51 1004.99 826.60 1301.23 0.85 3312.33 36.96 39.76 2902.81 1033.37 850.26 1338.18 0.37 3374.73 37.34 39.67 2952.55 1062.36 874.34 1375.87 0.63 3435.96 37.58 39.70 3001.16 1091.02 898.12 1413.11 0.39 3498.03 36.73 39.32 3050.62 1119.94 921.97 1450.60 1.43 3560.57 36.90 39.95 3100.69 1148.80 945.88 1488.07 0.66 3622.71 36.98 40.07 3150.36 1177.41 969.89 1525.42 0.17 3684.53 37.46 39.01 3199.58 1206.25 993.69 1562.81 1.28 3746.19 36.87 38.54 3248.72 1235.28 1017.02 1600.05 1.06 3808.65 36.18 39.11 3298.92 1264.25 1040.32 1637.22 1.23 3870.46 34.98 39.31 3349.18 1292.11 1063.06 1673.18 1.95 3931.79 33.57 39.16 3399.87 1318.86 1084.90 1707.71 2.30 3994.17 32.64 38.89 3452.12 1345.33 1106.36 1741.78 1.50 4056.89 31.40 38.64 3505.30 1371.25 1127.18 1775.03 1.98 4118.52 30.74 38.21 3558.08 1396.17 1146.95 1806.83 1.13 4180.45 28.61 38.32 3611.88 1420.25 1165.94 1837.48 3.44 4243.11 27.11 38.33 3667.27 1443.22 1184.10 1866.76 2.40 4305.53 25.62 38.94 3723.20 1464.87 1201.40 1894.47 2.43 4368.22 24.40 39.35 3780.02 1485.43 1218.13 1920.97 1.96 4429.89 22.50 40.05 3836.59 1504.31 1233.80 1945.51 3.11 KU 32-06 29 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4491.25 21.44 39.62 3893.50 1521.93 1248.50 1968.46 1.75 4552.18 20.36 38.61 3950.41 1538.79 1262.22 1990.19 1.87 4615.38 18.40 37.04 4010.04 1555.35 1275.09 2011.15 3.21 4677.66 18.00 37.91 4069.20 1570.79 1286.92 2030.58 0.77 4738.25 17.84 37.73 4126.85 1585.52 1298.35 2049.22 0.28 4800.26 17.56 38.63 4185.92 1600.33 1310.00 2068.06 0.63 4861.79 17.46 38.32 4244.60 1614.83 1321.52 2086.57 0.22 4923.90 17.35 38.78 4303.86 1629.36 1333.10 2105.14 0.28 4985.74 17.06 39.73 4362.94 1643.52 1344.67 2123.43 0.66 5047.23 17.62 40.14 4421.64 1657.57 1356.44 2141.76 0.93 5109.48 17.72 39.84 4480.96 1672.05 1368.58 2160.65 0.23 5172.82 17.17 40.99 4541.37 1686.50 1380.89 2179.64 1.03 5233.18 17.10 40.59 4599.06 1699.97 1392.51 2197.42 0.23 5295.23 17.48 41.31 4658.31 1713.89 1404.59 2215.85 0.70 5357.91 17.43 40.44 4718.10 1728.11 1416.90 2234.65 0.42 5420.69 18.15 39.33 4777.88 1742.83 1429.20 2253.83 1.26 5482.91 18.38 38.81 4836.96 1757.97 1441.49 2273.33 0.46 5546.22 18.32 38.91 4897.05 1773.49 1454.00 2293.27 0.11 5607.52 18.22 39.44 4955.26 1788.39 1466.14 2312.49 0.32 5670.54 17.97 40.28 5015.17 1803.42 1478.68 2332.06 0.58 5731.67 18.00 39.48 5073.31 1817.90 1490.78 2350.93 0.41 5794.27 18.12 40.21 5132.82 1832.80 1503.22 2370.34 0.41 5856.25 18.13 39.37 5191.72 1847.62 1515.56 2389.62 0.42 5919.12 18.21 39.34 5251.46 1862.78 1527.99 2409.22 0.14 5981.36 18.03 39.54 5310.61 1877.72 1540.28 2428.58 0.31 6043.11 17.95 40.40 5369.35 1892.34 1552.54 2447.65 0.45 6105.38 18.34 39.04 5428.52 1907.26 1564.92 2467.04 0.93 6167.14 18.26 38.64 5487.16 1922.37 1577.09 2486.43 0.24 6228.29 18.24 38.69 5545.23 1937.32 1589.05 2505.58 0.04 6290.68 17.92 39.40 5604.54 1952.36 1601.25 2524.94 0.63 6351.71 18.11 38.88 5662.58 1967.00 1613.17 2543.82 0.42 6414.92 18.18 38.94 5722.64 1982.31 1625.53 2563.50 0.10 6477.00 18.20 38.78 5781.62 1997.40 1637.69 2582.88 0.09 6540.61 18.34 39.29 5842.03 2012.90 1650.25 2602.82 0.34 6603.87 18.11 39.22 5902.11 2028.22 1662.77 2622.61 0.36 6665.95 18.04 39.77 5961.12 2043.08 1675.02 2641.87 0.30 6729.29 18.04 40.14 6021.35 2058.12 1687.61 2661.48 0.18 6769.43 18.18 39.48 6059.51 2067.70 1695.60 2673.96 0.63 KU 32-06 30 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 6860.04 19.11 40.12 6145.35 2089.95 1714.14 2702.92 1.05 6923.37 19.54 41.05 6205.12 2105.86 1727.78 2723.87 0.83 6985.60 19.82 40.77 6263.72 2121.70 1741.50 2744.82 0.48 7047.55 19.81 40.41 6322.00 2137.65 1755.16 2765.82 0.20 7109.82 19.66 39.73 6380.61 2153.74 1768.70 2786.85 0.44 7171.77 19.72 38.13 6438.94 2169.97 1781.81 2807.71 0.88 7234.38 19.80 36.39 6497.86 2186.82 1794.63 2828.86 0.95 7295.77 17.87 33.94 6555.97 2203.00 1806.05 2848.61 3.39 7357.63 16.22 34.08 6615.10 2218.03 1816.19 2866.65 2.67 7420.15 15.84 33.85 6675.20 2232.35 1825.84 2883.82 0.61 7481.68 15.72 33.78 6734.41 2246.25 1835.15 2900.46 0.20 7543.71 15.74 33.55 6794.12 2260.25 1844.47 2917.18 0.11 7605.31 15.59 33.72 6853.43 2274.09 1853.68 2933.72 0.24 7668.74 15.82 34.35 6914.49 2288.32 1863.29 2950.80 0.45 7730.48 15.93 35.19 6973.87 2302.20 1872.93 2967.63 0.41 7790.97 15.77 34.20 7032.06 2315.78 1882.33 2984.08 0.52 7853.08 15.73 34.43 7091.84 2329.71 1891.84 3000.87 0.12 7917.57 15.96 34.05 7153.88 2344.27 1901.75 3018.39 0.39 7979.46 16.47 36.53 7213.31 2358.37 1911.73 3035.62 1.39 8041.22 16.66 36.79 7272.50 2372.49 1922.25 3053.20 0.33 8103.40 17.73 37.22 7331.90 2387.17 1933.31 3071.56 1.72 8164.90 17.58 37.67 7390.51 2401.98 1944.65 3090.20 0.32 8227.41 18.37 38.53 7449.96 2417.16 1956.55 3109.48 1.32 8288.91 17.93 38.63 7508.41 2432.13 1968.50 3128.63 0.71 8350.05 17.66 38.31 7566.62 2446.62 1980.12 3147.31 0.48 8412.06 17.81 38.50 7625.69 2461.56 1991.86 3166.19 0.26 8473.96 17.70 38.67 7684.00 2476.16 2003.50 3184.86 0.19 8536.06 18.41 39.42 7743.68 2491.26 2015.76 3204.31 1.20 8597.96 18.15 40.14 7802.46 2506.19 2028.18 3223.73 0.56 8659.59 18.02 39.24 7861.04 2520.90 2040.40 3242.85 0.50 8720.99 17.71 39.09 7919.48 2535.51 2052.29 3261.69 0.52 8782.51 17.55 39.26 7978.11 2549.95 2064.06 3280.32 0.27 8845.28 17.73 39.11 8037.93 2564.70 2076.08 3299.34 0.30 8907.40 16.01 38.37 8097.37 2578.76 2087.37 3317.37 2.79 8969.20 15.53 38.90 8156.84 2591.88 2097.85 3334.16 0.81 9031.86 15.56 37.66 8217.22 2605.07 2108.26 3350.95 0.53 9094.46 15.76 37.88 8277.49 2618.61 2118.61 3367.84 0.33 9158.15 15.35 38.43 8338.84 2631.85 2129.16 3384.91 0.68 KU 32-06 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) 9219.24 13.97 41.47 8397.94 2643.72 2139.07 3400.37 2.59 9282.44 11.87 40.55 8459.55 2654.37 2148.34 3414.50 3.35 9341.71 10.51 39.65 8517.68 2663.16 2155.76 3425.99 2.30 9404.49 8.76 40.80 8579.58 2671.19 2162.53 3436.50 2.82 9466.40 8.57 41.49 8640.78 2678.21 2168.67 3445.82 0.34 9527.45 8.71 41.02 8701.14 2685.11 2174.72 3454.99 0.26 9592.02 8.44 40.34 8764.99 2692.41 2180.99 3464.62 0.45 9654.90 8.48 41.32 8827.18 2699.41 2187.04 3473.86 0.24 9715.71 8.49 41.24 8887.33 2706.15 2192.96 3482.83 0.02 9777.61 8.54 41.47 8948.55 2713.02 2199.01 3491.99 0.10 9841.27 8.56 41.18 9011.50 2720.13 2205.26 3501.44 0.07 9900.98 8.78 41.55 9070.52 2726.88 2211.20 3510.44 0.39 9962.50 8.82 41.69 9131.32 2733.92 2217.46 3519.85 0.08 10024.04 8.38 43.41 9192.17 2740.70 2223.68 3529.04 0.83 10087.91 8.12 42.30 9255.38 2747.42 2229.91 3538.19 0.49 10150.88 8.25 40.12 9317.71 2754.16 2235.81 3547.15 0.54 10213.61 8.32 39.40 9379.79 2761.11 2241.60 3556.19 0.54 10275.74 8.09 39.19 9441.28 2767.97 2247.21 3565.06 0.37 10339.66 8.01 41.33 9504.57 2774.80 2253.00 3574.01 0.49 10404.57 8.22 38.78 9568.83 2781.82 2258.89 3583.17 0.64 10467.40 8.26 39.04 9631.01 2788.83 2264.55 3592.18 0.08 10522.33 7.96 38.84 9685.39 2794.85 2269.42 3599.93 0.54 10560.00 7.96 38.84 9722.70 2798.92 2272.69 3605.14 0.01 KU 32-06 32 4.2 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drille d HRS AVE ROP (Ft/HR) CONDITION 1 13.5 Varel DT1GJMRS 1462253 3x16, 14 138 1509 1371 8.3 165.2 1-1-WT-A-E-YES-NONE-TD 2 9.875 HDBS MM65 12611378 6x13 1509 6810 5301 54.9 96.6 1-2-CT-G-X-1-WT-TD 3 6.75 Smith MM65D 12273690 6x10 6810 10560 3750 75.5 49.7 1-1-WT-A-X-1-NO-TD KU 32-06 33 4.3 Mud Record Contractor: Baroid Date Depth MW (ppg) VIS (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) MBT pH Cl (mg/l) Ca (mg/l) MD (ft) TVD (ft) Spud Mud 1/31/17 120 120 8.85 227 36 53 29/60/0 10.0 2/0 3.8 0/95.9 20.0 10.2 1000 2/1/17 796 796 8.8 105 29 41 12/33/40 9.8 2/0 3.4 0/96.3 0.25 20.0 9.2 1000 2/2/17 1509 1460 8.9 44 17 11 3/4/6 10.0 2/0 3.9 0/95.8 0.10 15.0 8.7 800 2/3/17 1509 1460 8.9 37 11 4 2/3/4 12.0 2/0 3.9 0/95.8 10.0 8.6 700 2/4/17 1509 1460 8.9 37 11 4 2/3/4 12.0 2/0 3.9 0/95.8 10.0 8.6 700 2/5/17 1509 1460 8.8 34 10 6 2/3/4 11.0 2/0 3.4 0/96.3 10.0 8.9 700 6% KCl Polymer 2/5/17 1509 1460 9.1 65 9 17 8/11/13 5.2 1/2 3.1 0/94.2 10.7 33000 120 2/6/17 2545 2295 9.0 47 10 18 9/11/15 4.8 1/2 2.0 0/95.0 0.25 1.0 10.2 36000 240 2/7/17 3850 3332 9.05 47 9 21 10/12/14 6.6 1/2 2.5 0/94.9 0.25 2.5 10.1 32000 180 2/8/17 4657 4050 9.0 45 10 19 7/0/0 6.3 1/2 2.6 0/94.9 0.50 6.5 9.5 30000 160 2/9/17 5618 4965 9.02 43 10 16 6/7/10 5.9 1/2 2.7 0/94.8 0.50 6.3 10.4 30000 120 2/10/17 6644 5940 9.2 47 12 18 6/7/10 4.5 1/2 4.1 0/93.4 0.50 5.0 10.2 30500 60 2/11/17 6810 6098 9.25 47 11 16 6/7/11 4.9 1/2 4.5 0/93.1 0.50 5.0 10.5 30000 40 2/12/17 6810 6098 9.25 51 11 17 6/7/10 4.9 1/2 4.1 0/93.0 0.50 5.5 10.0 35500 40 2/13/17 6810 6098 9.2 50 10 17 7/9/12 5.4 1/2 4.1 0/93.4 0.10 5.5 10.0 30000 40 2/14/17 6810 6098 9.25 49 10 16 5/8/12 5.2 1/2 4.2 0/93.0 0.10 5.5 11.5 34500 40 2/15/17 6810 6098 9.35 52 11 16 7/8/13 5.2 1/2 5.3 0/92.3 0.10 5.5 10.9 30000 40 2/16/17 6810 6098 9.35 51 13 18 7/8/10 4.9 1/2 4.9 0/92.3 0.10 5.0 11.1 35000 440 2/17/17 6810 6098 9.35 50 11 18 6/7/10 5.1 1/2 5.3 0/92.3 0.10 5.0 10.9 30000 440 2/18/17 6810 6098 10.0 48 12 19 6/8/11 5.2 1/2 7.4 0/90.2 0.10 5.5 10.1 31500 200 2/19/17 7065 6339 10.0 46 13 18 6/7/8 4.8 1/2 7.2 0/90.2 0.15 4.2 10.1 33500 280 2/20/17 7828 7069 10.1 53 18 18 7/9/10 3.8 1/2 6.9 0/90.4 0.15 3.8 10.1 35000 200 KU 32-06 34 2/21/17 8504 7714 10.8 54 23 20 5/7/10 3.5 1/2 11.0 0/86.4 0.25 4.3 10.3 35000 80 Date Depth MW (ppg) VIS (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) MBT pH Cl (mg/l) Ca (mg/l) MD (ft) TVD (ft) 6% KCl Polymer 2/22/17 9097 8281 11.3 51 25 19 7/9/10 3.2 1/2 13.2 0/84.0 0.25 4.5 9.8 35000 120 2/23/17 9774 8945 11.5 53 26 20 7/9/13 3.0 1/2 13.4 1.0/83.0 0.25 5.3 9.7 36500 120 2/24/17 10325 9492 11.8 52 26 23 7/9/11 3.0 1/2 14.4 1.5/81.5 0.15 5.0 10.0 36000 120 2/25/17 10560 9723 12.15 51 24 23 7/9/12 3.0 1/2 16.0 1.5/80.2 0.15 5.5 10.2 33500 120 2/26/17 10560 9723 12.3 55 24 25 7/9/12 3.0 1/2 16.5 1.3/79.5 0.15 5.5 10.2 39000 120 2/27/17 10560 9723 12.1 59 21 21 5/8/10 2.0 1/2 15.8 1.3/80.3 0.10 5.5 10.3 38000 200 2/28/17 10560 9723 12.1 58 22 19 6/8/10 2.5 1/2 15.9 1.3/80.3 0.10 5.5 10.2 37000 120 3/1/17 10560 9723 12.1 58 22 20 7/11/12 2.6 1/2 16.1 1.3/80.3 0.10 5.5 10.3 34000 120 3/2/17 10560 9723 12.1 63 22 26 9/11/13 2.6 1/2 16.1 1.3/80.3 0.10 5.5 10.2 34000 120 3/3/17 10560 9723 11.6 46 16 19 6/8/9 3.0 1/2 13.8 0.6/83.2 0.10 5.5 10.2 33000 120 3/4/17 10560 9723 11.05 46 13 21 7/9/12 3.6 1/2 11.4 0.3/85.5 0.10 5.0 10.0 37000 40 3/5/17 10560 9723 11.05 45 14 20 7/9/12 3.5 1/2 11.4 0.3/85.5 0.10 5.0 10.1 36000 80 3/6/17 10560 9723 11.05 46 16 24 8/13/15 3.4 1/2 11.4 0.3/85.5 0.10 5.0 10.1 37500 80 3/7/17 10560 9723 11.05 46 16 22 7/10/12 3.4 1/2 11.4 0.3/85.5 0.10 5.0 10.1 37500 160 3/8/17 10560 9723 11.2 50 15 24 7/10/12 3.4 1/2 12.1 0.3/84.9 0.10 5.0 9.9 37000 160 3/9/17 10560 9723 11.05 46 13 20 6/8/10 3.5 1/2 11.4 0.3/85.5 0.10 5.0 10.3 37000 160 3/10/17 10560 9723 11.05 44 14 20 6/7/9 4.2 1/2 11.5 0.3/85.5 0.10 5.0 10.0 36000 160 3/11/17 10560 9723 11.1 45 14 19 6/8/9 3.4 1/2 11.7 1.0/84.6 0.10 5.0 10.0 36000 120 3/12/17 10560 9723 11.0 45 13 18 5/7/7 3.7 1/2 11.4 1.0/85.1 0.10 5.0 10.1 35000 120 3/13/17 10560 9723 11.0 45 13 18 5/7/8 3.7 1/2 11.3 1.0/85.1 0.10 5.0 10.1 35000 120 3/14/17 10560 9723 11.0 47 13 18 5/6/7 3.6 1/2 11.3 1.0/85.1 0.10 5.0 10.0 35000 120 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 KU 32-06 35 4.4. Drilling Progress 0 2000 4000 6000 8000 10000 1/30/20172/1/20172/3/20172/5/20172/7/20172/9/20172/11/20172/13/20172/15/20172/17/20172/19/20172/21/20172/23/20172/25/20172/27/20173/1/20173/3/20173/5/20173/7/20173/9/20173/11/20173/13/20173/15/201713 1/2" 9 7/8" 6 3/4" KU 32-06 36 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number Field: Date: Rig: Time: County: Depth Start End State:20 5436'MD 5551'MD Country:20 4792'TVD 4902'TVD Averages Before During After Maximum ROP (fph)74 ft/hr 100 ft/hr 68 ft/hr 135 ft/hr WOB 4 klbs 6 klbs 7 klbs 8 klbs RPM 38 rpm 57 rpm 60 rpm 61 rpm PP 1622 psi 1593 psi 1678 psi 1679 psi Mud Weight 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal 9.0 lbs/gal Chloride 30,000 30,000 30,000 30,000 Total Gas 13 109 15 181 C1 (ppm)3,488 30,112 4,042 49,738 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color None Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Paul Webster None Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Hilcorp Alaska, LLC 50-133-20658-00-00KBU 32-06 Kenai Gas Field Saxon 169 2/26/2017 2:15 AM Residual Cut Sand = Medium to medium dark gray with individual grains grains dominantly clear to translucent quartz and volcanic glass, medium to dark gray, greenish gray and black, very finer lower, trace very coarse lower, dominantly fine lower to medium lower; angular to subrounded, dominantly subangular; fair to good sorting; dissaggregated; non-calcareous. 1 10 100 1000 10000 1234ppmPixler 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 8174'MD 8310'MD Country:20 7399'TVD 7528'TVD Averages Before During After Maximum ROP (fph)79 ft/hr 103 ft/hr 90 ft/hr 163 ft/hr WOB 11 klbs 7 klbs 8 klbs 12 klbs RPM 70 rpm 62 rpm 70 rpm 72 rpm PP 2437 psi 2351 psi 2522 psi 2599 psi Mud Weight 10.3 lbs/gal 10.3 lbs/gal 10.3 lbs/gal 10.3 lbs/gal Chloride 33,800 33,800 33,800 33,800 Total Gas 52 90 59 176 C1 (ppm)11,595 20,575 13,647 40,579 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color None Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Paul Webster None Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Hilcorp Alaska, LLC 50-133-20658-00-00KBU 32-06 Kenai Gas Field Saxon 169 2/26/2017 5:05 AM Residual Cut Tuffaceous Sandstone/Sand = light gray to grayish white with abundant varicolored secondary hues for a mottled appearance; very soft; crunchy; fragile to pulverulent; ashy matrix acts as a supporting matrix for sand; dominantly clear to translucent quartz and volcanic glass with darker liths; very fine lower to medium lower; dominantly fine; angular to subangular; moderately well sorted; very loosely supported by ashy matrix; non-calcareous; trace thin coal beds. 1 10 100 1000 10000 1234ppmPixler 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 9606'MD 9724'MD Country:20 8779'TVD 8895'TVD Averages Before During After Maximum ROP (fph)89 ft/hr 106 ft/hr 89 ft/hr 183 ft/hr WOB 10 klbs 11 klbs 13 klbs 16 klbs RPM 74 rpm 74 rpm 74 rpm 75 rpm PP 3101 psi 3124 psi 3172 psi 3260 psi Mud Weight 11.5 lbs/gal 11.5 lbs/gal 11.5 lbs/gal 11.5 lbs/gal Chloride 36,500 36,500 36,500 36,500 Total Gas 329 118 86 185 C1 (ppm)65,939 23,798 17,322 36,437 C2 (ppm)- - - - C3 (ppm)3 - - - C4 (ppm)- 2 36 95 C5 (ppm)- 0 - 20 Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color None Color Intesity Color Color Comments Report by: Residual Cut Sand = dominant clear to translucent, common black, gray, occasional white; lower fine to lower coars, dominant lower medium to upper fine; moderately sorted; angular to subround, dominant subangular; dominant moderate to occasional low sphericity; dominant quartz, common mafic-rich grains, occasional volcanic clastics, feldpsar. Hilcorp Alaska, LLC 50-133-20658-00-00KBU 32-06 Kenai Gas Field Saxon 169 2/26/2017 5:36 AM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Paul Webster None Oil Show Rating 1 10 100 1000 10000 1234ppmPixler 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:5 9740'MD 9754'MD Country:5 8911'TVD 8925'TVD Averages Before During After Maximum ROP (fph)78 ft/hr 102 ft/hr 104 ft/hr 129 ft/hr WOB 13 klbs 13 klbs 4 klbs 14 klbs RPM 74 rpm 74 rpm 74 rpm 74 rpm PP 3154 psi 3099 psi 3161 psi 3203 psi Mud Weight 11.5 lbs/gal 11.5 lbs/gal 11.5 lbs/gal 11.5 lbs/gal Chloride 36,500 36,500 36,500 36,500 Total Gas 62 249 52 344 C1 (ppm)12,633 48,041 11,519 66,729 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color None Color Intesity Color Color Comments Report by: Residual Cut Tuffaceous Sandstone = very light gray; soft to slightly firm; easily friable; lower fine to lower medium; moderate to well sorted; angular to subround, dominant subangular; dominant moderate to common low sphericity; bentonitic matrix support; dominant quartz, comm on mafic-rich grains, volcanic clastics, occasional lithics, feldspar. Hilcorp Alaska, LLC 50-133-20658-00-00KBU 32-06 Kenai Gas Field Saxon 169 2/26/2017 6:36 AM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Paul Webster None Oil Show Rating 1 10 100 1000 10000 1234ppmPixler 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 9740'MD 9754'MD Country:20 9180'TVD 9332'TVD Averages Before During After Maximum ROP (fph)86 ft/hr 86 ft/hr 82 ft/hr 160 ft/hr WOB 8 klbs 7 klbs 8 klbs 12 klbs RPM 72 rpm 72 rpm 72 rpm 74 rpm PP 3203 psi 3152 psi 3134 psi 3312 psi Mud Weight 11.8 lbs/gal 11.8 lbs/gal 11.8 lbs/gal 11.8 lbs/gal Chloride 36,000 36,000 36,000 36,000 Total Gas 193 120 31 344 C1 (ppm)34,877 21,875 14,836 62,089 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color None Color Intesity Color Color Comments Report by: Residual Cut Tuffaceous Sandstone = medium light grey to light grey to slightly light olive grey; lower very fine to upper medium; poor sorting; moderate to low sphericity in all grain sizes; subrounded to subangular; dominant quartz up to 80% with secondary lithics with occasional abundant lignitic fragments of similiar size; grain supported tuff matrix clasts, easily friable and much disaggregated loose sand grains, possibly from annular travel; trace microlaminae carbonaceous material; mildly calcareous. Hilcorp Alaska, LLC 50-133-20658-00-00KBU 32-06 Kenai Gas Field Saxon 169 2/27/2017 11:30 PM Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Paul Webster None Oil Show Rating 1 10 100 1000 10000 1234ppmPixler 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 10214'MD 10225'MD Country:20 9380'TVD 9391'TVD Averages Before During After Maximum ROP (fph)75 ft/hr 84 ft/hr 37 ft/hr 162 ft/hr WOB 8 klbs 8 klbs 9 klbs 8 klbs RPM 72 rpm 72 rpm 72 rpm 72 rpm PP 3039 psi 3026 psi 3036 psi 3113 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal Chloride 36,000 36,000 36,000 36,000 Total Gas 39 171 27 250 C1 (ppm)23,553 101,864 15,950 149,628 C2 (ppm)- - - - C3 (ppm)- - - - C4 (ppm)- - - - C5 (ppm)- - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color None Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Paul Webster None Oil Show Rating Cut Free Oil in Mud Kenai Peninsula Borough Alaska United States of America Stain Fluorescence Cut Fluorescence Hilcorp Alaska, LLC 50-133-20658-00-00KBU 32-06 Kenai Gas Field Saxon 169 2/26/2017 6:36 AM Residual Cut Sand = olive grey to olive black; 80% quartz loose grains, 20% lithics, dominant lignitic fragments; quartz dominant lower very fine to upper very fine, secondary grading to upper medium; poor sorting; very low to low sphericity, trace highly spherical; subangular to subrounded, occasional very angular smaller and very rounded larger grains; mildly calcareous. 1 10 100 1000 10000 1234ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 KU 32-06 37 6 DAILY REPORTS Hilcorp Alaska, LLC Kenai gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pedersen, A Dorr DATE , Jan 31, 2017 DEPTH 138 PRESENT OPERATION Pick up and rack back pipe TIME 23:59 YESTERDAY 138 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 138' 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 13.5" Varel DT1GJMRS 1462253 3x16, 14 138 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 Complete rigging up. Pick up and rack back pipe. CANRIG PERSONNEL ON BOARD 2 DAILY COST $1925 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 01, 2017 DEPTH 795' PRESENT OPERATION Waiting on cuttings removal TIME 23:59 YESTERDAY 138' 24 HOUR FOOTAGE 657' CASING INFORMATION 16" @ 138' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 509.77 0.81 35.94 509.77 571.20 1.48 28.32 571.19 632.45 2.55 30.79 632.40 693.76 3.99 26.98 693.60 756.05 5.66 31.88 755.68 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" Varel DT1GJMRS 1462253 3x16, 14 138' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 359.6 @ 530 6.9 @ 485 152.6 204.29 FT/HR SURFACE TORQUE 6330 @ 213 0 @ 618 2925.5 0.00 AMPS WEIGHT ON BIT 18 @ 754 0 @ 662 3.5 1.99 KLBS ROTARY RPM 58 @ 468 1 @ 627 32.5 0.00 RPM PUMP PRESSURE 1549 @ 758 139 @ 172 1126.2 1421.56 PSI DRILLING MUD REPORT DEPTH 796' MW 8.8 VIS 105 PV 29 YP 41 FL 9.8 Gels 12/33/40 CL-1K FC 2/0 SOL 3.4 SD 0.25 OIL 0 MBL 20 pH 9.2 Ca+ CCI MWD SUMMARY INTERVAL 138' TO TOOLS MWD, Mud motor w/ 1.50 bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 787 0 @ 405 1.4 TRIP GAS 0u CUTTING GAS 0 @ 795 0 @ 795 0.0 WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 1230 @ 788 162 @ 605 297.7 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 795 0 @ 795 0.0 AVG PROPANE (C-3) 0 @ 795 0 @ 795 0.0 CURRENT 0u BUTANE (C-4) 0 @ 795 0 @ 795 0.0 CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) 0 @ 795 0 @ 795 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill from 138’ to 360’. Circulate hole clean. Pull out of hole to 113’. Rack back HWDP. Pick up 2-Flex DC, run in hole w/ Jars & HWDP to 360’. Drill ahead to 795’. Kick off directional @ 488’. Pump sweep/circulate hole clean. Wiper trip from 795’ to 240’. Run in hole to 795’. Pull out of hole to 240’. Service rig. Wait on cuttings removal to G&I. Waiting on cuttings removal at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $1,925.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 02, 2017 DEPTH 1509' PRESENT OPERATION Running surface casing TIME 23:59 YESTERDAY 795' 24 HOUR FOOTAGE 714' CASING INFORMATION 16" @ 138' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1252.88 25.11 37.24 1234.28 1315.01 25.43 37.99 1290.47 1377.34 27.66 38.78 1346.22 1440.26 29.88 38.19 1401.37 1469.66 30.64 39.81 1426.77 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" Varel DT1GJMRS 1462253 3x16, 14 138' 1509' 1371' 08:19 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 607.9 @ 946 2.3 @ 1229 259.4 278.97 FT/HR SURFACE TORQUE 7013 @ 1284 0 @ 1464 598.0 0.00 AMPS WEIGHT ON BIT 27 @ 1254 0 @ 1067 8.9 5.71 KLBS ROTARY RPM 58 @ 911 0 @ 936 5.2 0.00 RPM PUMP PRESSURE 1938 @ 1150 1421 @ 795 1666.8 1564.89 PSI DRILLING MUD REPORT DEPTH MW 8.9 VIS 44 PV 17 YP 11 FL 10.0 Gels 3/4/6 CL- 800 FC 2/0 SOL 3.9 SD 0.10 OIL 0 MBL 15 pH 8.7 Ca+ CCI MWD SUMMARY INTERVAL 138' TO 1509' TOOLS MWD, Mud motor w/ 1.50 bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 37 @ 1337 0 @ 929 12.4 TRIP GAS 32u CUTTING GAS 0 @ 1509 0 @ 1509 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 8757 @ 1341 162 @ 916 2830.1 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 1509 0 @ 1509 0.0 AVG PROPANE (C-3) 0 @ 1509 0 @ 1509 0.0 CURRENT 0u BUTANE (C-4) 0 @ 1509 0 @ 1509 0.0 CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) 0 @ 1509 0 @ 1509 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Wait on cuttings removal. Run in hole to 796’. Resumed drilling at 03:30. Drill from 796’ to 1509’. TD surface hole at 09:00. Circ hole clean. Pull out of hole to 275’. Service rig. Run in hole to TD. Pump sweep & circ bottoms up 3x. Pull out of hole. Rig down elevators/bails. Rig up casing bails & power tongs. Commence surface casing run w/ casing @ 524’ at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $1,925.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederon, A. Dorr DATE Feb 03, 2017 DEPTH 1509' PRESENT OPERATION Nipple up BOP TIME 23:59 YESTERDAY 1509' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 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 Continue running in hole w/ casing from 524’, landed at 1499’ at 03:00am. Rig up cement head & manifold lines. Circulate & prep for cement, build mud push. Pressure test lines. Pumped cement. Blow down cementer’s lines, rig down cementers. Clean rig components & pump out cellar. Install wellhead & begin nipple up BOP. CANRIG PERSONNEL ON BOARD 2 DAILY COST $1,925.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 04, 2017 DEPTH 1509' PRESENT OPERATION Pick up and rack back pipe TIME 23:59 YESTERDAY 1509' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 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 Continue nipple up BOP. Rig down casing running equip. Rig up BOP testing equip. Test BOP. Rig down BOP testing equip. Begin picking up drill pipe and racking back in derrick. Picking up drill pipe at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $1,925.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 05, 2017 DEPTH 1509' PRESENT OPERATION Making up BHA TIME 23:59 YESTERDAY 1509' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 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 2 9 7/8" HDBS MM65 12611378 6x13 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 1509/SPUD MUD MW 8.8 VIS 34 PV 10 YP 6 FL 11.0 Gels 2/3/4 CL- 700 FC 2/0 SOL 3.4 SD 0 OIL 0 MBL 10.0 pH 8.9 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS 7" SperryDrill motor 7/8 lobe 6.0 stage w/ 1.50 bend 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 Continue pick up drill pipe. Change out gooseneck, reattach Kelly hose. Move heavywall drill pipe in derrick. Continue picking up drill pipe. Frost/icing issues. Blow back Kelley hose/stand pipe. Pump spud mud through top drive, close manual IBOP, pressure test Kelley hose/gooseneck connections, break top drive off stump, install blowback swedge. Blow back Kelley hose/standpipe, break off blowback swedge. Prep floor to make up BHA#2. Making up BHA @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 06, 2017 DEPTH 2527' PRESENT OPERATION Tripping TIME 23:59 YESTERDAY 1510' 24 HOUR FOOTAGE 1017' CASING INFORMATION 10 3/4" @ 1499' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2257.06 37.41 40.50 2065.10 2320.61 37.26 40.21 2115.63 2380.80 37.18 39.79 2163.56 2444.16 37.38 41.11 2213.97 2505.51 37.50 40.08 2262.69 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6x13 1499' 05:28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 385.4 @ 1749 1.1 @ 1708 209.9 177.55 FT/HR SURFACE TORQUE 9727 @ 2401 0 @ 2432 4406.1 7846.94 AMPS WEIGHT ON BIT 24 @ 1579 0 @ 1676 3.7 4.15 KLBS ROTARY RPM 69 @ 2402 0 @ 2373 37.6 66.26 RPM PUMP PRESSURE 1330 @ 1518 881 @ 1555 1022.4 1070.53 PSI DRILLING MUD REPORT DEPTH 2545' MW 9.0 VIS 47 PV 10 YP 18 FL 4.8 Gels 9/11/15 CL- 36k FC 1/2 SOL 2.0 SD 0.25 OIL 0.0/95.0 MBL 1.0 pH 10.2 Ca+ CCI MWD SUMMARY INTERVAL 1499' TO 2527' TOOLS 7" SperryDrill motor 7/8 lobe 6.0 stage w/ 1.50 bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 13 @ 2211 1 @ 1921 7.2 TRIP GAS CUTTING GAS 0 @ 2527 0 @ 2527 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 3704 @ 2216 275 @ 1924 1854.7 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 2527 0 @ 2527 0.0 AVG 4u PROPANE (C-3) 0 @ 2527 0 @ 2527 0.0 CURRENT 0u BUTANE (C-4) 0 @ 2527 0 @ 2527 0.0 CURRENT BACKGROUND/AVG 0u/4u PENTANE (C-5) 0 @ 2527 0 @ 2527 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation / Predominantly sand PRESENT LITHOLOGY 60% sand, 30% tuffaceous claystone, 10% tuffaceous siltstone DAILY ACTIVITY SUMMARY Continue making up BHA #2. Run in hole w/ BHA #2 to 1412’ TAG. Drill out float equip and shoe track; drill to 1529’. Circulate hole clean. Displace mud to 6% KCL. Perform FIT test. Directional drill ahead from 1529’ to 2545’, back reaming/MADD passing every slide @ 180’/hr. Condition mud & circulate. Begin short trip to shoe @ 23:15. Short tripping @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 07, 2017 DEPTH 3793' PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 2545' 24 HOUR FOOTAGE 1248' CASING INFORMATION 10 3/4" @ 1499' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3622.71 36.98 40.07 3150.36 3684.53 37.46 39.01 3199.58 3746.19 36.87 38.54 3248.72 3808.65 36.18 39.11 3298.92 3870.46 34.98 39.31 3349.18 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6x13 1499' 14:16 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 366.2 @ 3295 3.5 @ 3204 178.3 156.38 FT/HR SURFACE TORQUE 10652 @ 3030 0 @ 3679 6777.2 9098.21 AMPS WEIGHT ON BIT 11 @ 3310 0 @ 3686 4.1 4.29 KLBS ROTARY RPM 81 @ 3205 0 @ 2933 55.8 76.99 RPM PUMP PRESSURE 1517 @ 3780 977 @ 2546 1147.5 1401.88 PSI DRILLING MUD REPORT DEPTH 3850' MW 9.05 VIS 47 PV 9 YP 21 FL 6.6 Gels 10/12/14 CL- 32k FC 1/2 SOL 2.5 SD 0.25 OIL 0.0/94.9 MBL 2.5 pH 10.1 Ca+ CCI MWD SUMMARY INTERVAL 1499' TO 3793' TOOLS 7" SperryDrill motor 7/8 lobe 6.0 stage w/ 1.50 bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 24 @ 3778 2 @ 2547 9.5 TRIP GAS CUTTING GAS 0 @ 3793 0 @ 3793 0.0 WIPER GAS 4u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6709 @ 3778 184 @ 2657 2494.1 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 3793 0 @ 3793 0.0 AVG 7u PROPANE (C-3) 0 @ 3793 0 @ 3793 0.0 CURRENT 0u BUTANE (C-4) 0 @ 3793 0 @ 3793 0.0 CURRENT BACKGROUND/AVG 0u/7u PENTANE (C-5) 0 @ 3793 0 @ 3793 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation / Sand and Tuffaceous Claystone PRESENT LITHOLOGY 40% sand, 40% tuffaceous siltstone, 10% tuffaceous claystone, 10% coal DAILY ACTIVITY SUMMARY Continue trip to 1425’. Service rig. Run in hole from 1425’ to 2545’. Drill from 2545’ to 2890’. Pump sweep, no increase. Drill ahead from 2890’ to 3540’, back reaming/MADD passing every slide @ 180’/hr. Circulate hole clean 2x bottoms up. Wiper trip from 3540’ to 2487’. Service rig. Run in hole from 2487’ to 3540’. Pump sweep; 10% increase in cuttings. Drill ahead from 3540’. Drilling ahead at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 08, 2017 DEPTH 4710' PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 3793' 24 HOUR FOOTAGE 917' CASING INFORMATION 10 3/4' @ 1499' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4368.22 24.40 39.35 3780.02 4429.89 22.50 40.05 3836.59 4491.25 21.44 39.62 3893.50 4552.18 20.36 38.61 3950.41 4615.38 18.40 37.04 4010.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6x13 1499' 3211' 23:53 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 227.1 @ 3980 7.6 @ 4604 108.6 120.13 FT/HR SURFACE TORQUE 11787 @ 4152 0 @ 3918 7260.4 10217.81 AMPS WEIGHT ON BIT 16 @ 4121 0 @ 4296 3.3 2.20 KLBS ROTARY RPM 80 @ 4194 0 @ 4299 49.3 59.39 RPM PUMP PRESSURE 1670 @ 4121 1109 @ 3951 1398.3 1485.84 PSI DRILLING MUD REPORT DEPTH NO NEW INFO AT REPORT TIME MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 1499' TO 4710' TOOLS 7" SperryDrill motor 7/8 lobe 6.0 stage w/ 1.50 bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 64 @ 4709 2 @ 4362 15.6 TRIP GAS CUTTING GAS 0 @ 4710 0 @ 4710 0.0 WIPER GAS 10u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 17792 @ 4710 418 @ 4361 4206.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 4710 0 @ 4710 0.0 AVG 20u PROPANE (C-3) 0 @ 4710 0 @ 4710 0.0 CURRENT 26u BUTANE (C-4) 0 @ 4710 0 @ 4710 0.0 CURRENT BACKGROUND/AVG 26u/20u PENTANE (C-5) 0 @ 4710 0 @ 4710 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation / Sand and Tuffaceous Siltstone PRESENT LITHOLOGY 50% sand, 40% tuffaceous siltstone, 10% tuffaceous claystone DAILY ACTIVITY SUMMARY Drill from 3540’ to 3971’. Pull out of hole to 3790’and repair mud pump #2. Run in hole to 3971’. Drill from 3971’ to 4533’, reaming every stand, MADD pass all slides. Circulate 2x bottoms up. Wiper trip from 4533’ to 3474’. Service rig. Run in hole from 3474’ to 4533’. Drill ahead per directional plan from 4533’. Drilling ahead at 4710’ @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 09, 2017 DEPTH 5651' PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 4710' 24 HOUR FOOTAGE 941' CASING INFORMATION 10 3/4" @ 1499' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5295.23 17.48 41.31 4658.31 5357.91 17.43 40.44 4718.10 5420.69 18.15 39.33 4777.88 5482.91 18.38 38.81 4836.96 5546.22 18.32 38.91 4897.05 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6x13 1499' 4152' 36:06 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 180.0 @ 4839 6.4 @ 5034 100.2 38.69 FT/HR SURFACE TORQUE 12833 @ 5650 0 @ 5410 10476.8 11893.52 AMPS WEIGHT ON BIT 15 @ 5342 0 @ 5044 4.7 6.80 KLBS ROTARY RPM 78 @ 5158 0 @ 5296 58.0 64.42 RPM PUMP PRESSURE 1826 @ 5649 1076 @ 5343 1614.5 1730.80 PSI DRILLING MUD REPORT DEPTH 5618' MW 9.02 VIS 43 PV 10 YP 16 FL 5.9 Gels 6/7/10 CL- 30k FC 1/2 SOL 2.7 SD 0.5 OIL 0.0/94.8 MBL 6.3 pH 10.4 Ca+ 120 CCI 1.20 MWD SUMMARY INTERVAL 1499' TO 5651' TOOLS 7" SperryDrill motor 7/8 lobe 6.0 stage w/ 1.50 bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 181 @ 5503 3 @ 5340 37.5 TRIP GAS CUTTING GAS 0 @ 5651 0 @ 5651 0.0 WIPER GAS 150u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 49737 @ 5503 653 @ 5339 10272.2 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 5651 0 @ 5651 0.0 AVG 20u PROPANE (C-3) 0 @ 5651 0 @ 5651 0.0 CURRENT 20u BUTANE (C-4) 0 @ 5651 0 @ 5651 0.0 CURRENT BACKGROUND/AVG 20u/20u PENTANE (C-5) 0 @ 5651 0 @ 5651 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation / Tuffaceous Siltstone and Claystone PRESENT LITHOLOGY 50% tuffaceous siltstone, 40% tuffaceous clay, 10% sand DAILY ACTIVITY SUMMARY Drill ahead from 4710’ to 5526’, backreaming every stand, MADD passing every slide. Circulate 2x bottoms up. Wiper trip from 5526’ to 4460’. Service rig. Run in hole from 4460’ to 5526’. Drill ahead as per directional plan from 5526’. Drilling ahead at 5651’ @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR R. Pederson, A. Dorr DATE Feb 10, 2017 DEPTH 6672' PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 5651' 24 HOUR FOOTAGE 1021' CASING INFORMATION 10 3/4" @ 1499' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6351.71 18.11 38.88 5662.58 6414.92 18.18 38.94 5722.64 6477.00 18.20 38.78 5781.62 6540.61 18.34 39.29 5842.03 6603.87 18.11 39.22 5902.11 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6x13 1499' 5173' 51:10 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 129.1 @ 6403 4.9 @ 6091 82.4 36.11 FT/HR SURFACE TORQUE 14264 @ 5786 0 @ 6093 11985.6 12753.79 AMPS WEIGHT ON BIT 11 @ 5716 0 @ 6334 5.7 6.27 KLBS ROTARY RPM 77 @ 5824 0 @ 6086 55.7 57.68 RPM PUMP PRESSURE 2105 @ 6340 1223 @ 5715 1756.6 1854.37 PSI DRILLING MUD REPORT DEPTH 6644' MW 9.20 VIS 47 PV 12 YP 18 FL 4.5 Gels 6/7/10 CL- 30,500 FC 1/2 SOL 4.1 SD 0.5 OIL 0.0/93.4 MBL 5.0 pH 10.2 Ca+ 60 CCI 0.70 MWD SUMMARY INTERVAL 1499' TO 6672' TOOLS 7" SperryDrill motor 7/8 lobe 6.0 stage w/ 1.50 bend GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 105 @ 6066 2 @ 5836 18.3 TRIP GAS CUTTING GAS 0 @ 6672 0 @ 6672 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 29025 @ 6067 558 @ 5836 4831.5 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 6672 0 @ 6672 0.0 AVG 18u PROPANE (C-3) 0 @ 6672 0 @ 6672 0.0 CURRENT 7u BUTANE (C-4) 0 @ 6672 0 @ 6672 0.0 CURRENT BACKGROUND/AVG 7u/18u PENTANE (C-5) 0 @ 6672 0 @ 6672 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation / Tuffaceous Siltstone and Claystone PRESENT LITHOLOGY 40% tuffaceous siltstone, 40% tuffaceous claystone, 20% sand DAILY ACTIVITY SUMMARY Drill ahead from 5651’ to 6672’, backreaming every stand, MADD passing every slide. Drilling ahead at 6672’ @ report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785.00 REPORT BY Garnet Knopp Hilcorp Alaska, LLC DAILY WELLSITE REPORT KBU32-06 REPORT FOR ROBERT HALL; RANCE PEDERSON DATE Feb 11, 2017 DEPTH 6810' PRESENT OPERATION WIPER TRIP TIME 00:00 YESTERDAY 6672' 24 HOUR FOOTAGE 138' CASING INFORMATION 10 3/4" @ 1499' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6769.43 18.18 39.48 6059.51 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6x13 1499' 5173' 51:10 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 89.5 @ 7.8 @ 6804 53.4 45.8 FT/HR SURFACE TORQUE 14105 @ 6775 12294 @ 6680 12523.6 12936 AMPS WEIGHT ON BIT 7 @ 6744 2 @ 6801 5.4 4.9 KLBS ROTARY RPM 61 @ 6705 56 @ 6775 57.9 58 RPM PUMP PRESSURE 1854 @ 6672 1582 @ 6705 1694.2 1791 PSI DRILLING MUD REPORT DEPTH 6810' MW 9.25 VIS 47 PV 11 YP 16 FL 4.9 Gels 6/7/11 CL- 30000 FC 1/2 SOL 4.5 SD 0.5 OIL 0.0/93.1 MBL 5.0 pH 10.5 Ca+ 40 CCI 1.20 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 21 @ 6685' 4 @ 6771' 10.6 TRIP GAS CUTTING GAS 0 @ 6810' 0 @ 6810' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 5698 @ 6685' 1132 @ 6771' 2717.4 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 6810' 0 @ 6810' 0.0 AVG PROPANE (C-3) 0 @ 6810' 0 @ 6810' 0.0 CURRENT PUMPS OFF BUTANE (C-4) 0 @ 6810' 0 @ 6810' 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 6810' 0 @ 6810' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE / SILTSTONE (6730' - 6810') MEDIUM DARK GREY TO DARK GREY; HYDROPHILIC CUTTINGS, MOSTLY AMORPHOUS GLUBULES EXHIBITING INDISCERNIBLE CHARACTERISTICS; WHEN VISIBLE, LIGHT GREY TABULAR WEDGED CUTTINGS WITH MICROLAMINAE CARBONACEOUS MATERIAL AND COAL; ABUNDANT FRAGMENTS OF SAME; GLOBULES IMBEDDED WITH SAND, POSSIBLY FROM ANULAR TRAVEL; SAND DOMINANT QUARTZ, POORLY SORTED LOWER MEDIUM TO LOWER COARSE; SUBROUNDED LARGER GRAINS TO SUBANGULAR SMALLER. DAILY ACTIVITY SUMMARY CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785.00 REPORT BY D. MULLER DATE: 2/12/2017 DEPTH: 6810'PRESENT OPERATION: TIME: 12:00 AM YESTERDAY: 6810' 24 Hour Footage ' 10 3/4" @ 1499' DEPTH INCLINATION 6749' 18.18 CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS MIN T / B / C PULLED NB#2 8.5 MM65 12611378 6*13 1509' 6810' 5301' 54.9 1,2,CT,G,X,1,WT,TD TD HIGH LOW AVERAGE 0 @ 0 0 @ 0 ft/hr 0 @ 0 0 @ 0 ft/lbs 0 @ 0 0 @ 0 Klbs 0 @ 0 0 @ 0 RPM 0 @ 0 0 @ 0 psi DEPTH 562' MW 10.0 F- VIS 48 PV YP GELS CL- FC SOL SD Oil / H2O Ca++ TOOLS: HIGH LOW UNITS 0 @ 0 0 @ 0 0 TRIP GAS@=8 WIPER GAS@=0 SURVEY GAS@=0 0 @ 0 0 @ 0 0 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH=0 0 @ 0 0 @ 0 0 AVG=0 0 @ 0 0 @ 0 0 CURRENT=P.Off 0 @ 0 0 @ 0 0 0 AVG=0 INTERVAL LITHOLOGY 60% SOME THROUGH SCREENS) PRESENT LITHOLOGY: Report by: DAILY WELLSITE REPORT TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY: METHANE(C-1) CANRIG Personnel On Board= Dylan Muller ETHANE(C-2) 4 $2,785.00Daily Cost: DESCRIPTION GAS UNITS TUFFACEOUS SILTSTONE Currently logging RFT lithics possibly from annular travel. wedged, tabular cuttings with microlaminae carbonaceous material and coal; abundant fragments of same. Amorphous globules contain sand and some Dark grey hydrophilic cuttings, mostly amorphous globules exhibing indiscernible characteristics. When visible, light grey CHROMATOGRAPHY(ppm) FL LITHOLOGY/REMARKS HYDROCARBON SHOWS 0 30% 0 0 0 0 0 0 WEIGHT ON BIT 0 TOP DRIVE RPM SAND 10% (PROBABLY LOSING PENTANE(C-5) AVERAGE BUTANE(C-4) CONNECTION GAS DITCH GAS PROPANE(C-3) CURRENT BACKGROUND AZIMUTH PUMP PRESSURE GAS SUMMARY (UNITS) DRILLING MUD REPORT TOOL\ SUMMARY MUD TYPE KCL (Polymer) SURFACE TORQUE On Bottom Hrs. RATE OF PENETRATION 0 Hillcorp Alaska, LLC Kenai Gas Field Rig Saxon 169 SURVEY DATA CASING INFORMATION REPORT FOR: Robert Hall, Rance Pederson CURRENT AVG INTERVAL 0 VERTICAL DEPTH BIT INFORMATION KBU 32-06 pH RFT logging 39.48 6059.5 DRILLING PARAMETERS DATE: 2/14/2017 DEPTH: 6810'PRESENT OPERATION: TIME: 12:00 AM YESTERDAY: 6810' 24 Hour Footage ' 10 3/4" @ 1499' DEPTH INCLINATION 6749' 18.18 CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS MIN T / B / C PULLED NB#2 8.5 MM65 12611378 6*13 1509' 6810' 5301' 54.9 1,2,CT,G,X,1,WT,TD TD HIGH LOW AVERAGE 0 @ 0 0 @ 0 ft/hr 0 @ 0 0 @ 0 ft/lbs 0 @ 0 0 @ 0 Klbs 0 @ 0 0 @ 0 RPM 0 @ 0 0 @ 0 psi DEPTH 6,810' MW 9.2+ F- VIS 47 PV 11 YP 16 CL- 30k GELS 6/7/11 FC 1/2 SOL 4.5 SD .5 Oil / H2O 0/93.1 Ca++ 40.0 TOOLS: HIGH LOW UNITS 0 @ 0 0 @ 0 0 TRIP GAS@= WIPER GAS@=0 SURVEY GAS@=0 0 @ 0 0 @ 0 0 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH=0 0 @ 0 0 @ 0 0 AVG=0 0 @ 0 0 @ 0 0 CURRENT=0 0 @ 0 0 @ 0 0 AVG=0 INTERVAL LITHOLOGY 60% SOME THROUGH SCREENS) PRESENT LITHOLOGY: Report by: RIH W/CLEAN OUT 39.48 6059.5 ASSEMBLY VERTICAL DEPTH Ph 10.5 0 0 DRILLING PARAMETERS Hillcorp Alaska, LLC Kenai Gas Field Rig Saxon 169 SURVEY DATA CASING INFORMATION REPORT FOR: Robert Wall, Rance Pederson KBU 32-06 DAILY WELLSITE REPORT CLEAN OUT ASSEMBLY MUD TYPE KCL (Polymer) SURFACE TORQUE On Bottom Hrs. RATE OF PENETRATION 0 CURRENT AVG INTERVALBIT INFORMATION DITCH GAS PROPANE(C-3) CURRENT BACKGROUND AZIMUTH PUMP PRESSURE GAS SUMMARY (UNITS) DRILLING MUD REPORT TOOL\ SUMMARY WEIGHT ON BIT 0 TOP DRIVE RPM 0 0 0 0 0 SAND 10% (PROBABLY LOSING 0 CONNECTION GAS CHROMATOGRAPHY(ppm) FL LITHOLOGY/REMARKS HYDROCARBON SHOWS PENTANE(C-5) AVERAGE BUTANE(C-4) Daily Cost: DESCRIPTION GAS UNITS to 2489 +/- break circlation, continue to monitor well, slight mud losses to formation, TUFFACEOUS SILTSTONE Finish running RFT tests, Slight losses to formation durning trips, POOH w/Wire line Tools, M/U Clean Out Assembly, RIH lithics possibly from annular travel. wedged, tabular cuttings with microlaminae carbonaceous material and coal; abundant fragments of same. Amorphous globules contain sand and some Dark grey hydrophilic cuttings, mostly amorphous globules exhibing indiscernible characteristics. When visible, light grey 30%TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY: METHANE(C-1) CANRIG Personnel On Board= Marquel Mosebay ETHANE(C-2) 4 $2,785.00 DATE: DEPTH: 6810'PRESENT OPERATION: TIME: 23:59 YESTERDAY: 6810' 24 Hour Footage 0' 10 3/4" @ 1499' DEPTH INCLINATION 6749' 18.18 CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS MIN T / B / C PULLED NB#2 8.5 MM65 12611378 6*13 1509' 6810' 5301' 54.9 1,2,CT,G,X,1,WT,TD TD HIGH LOW AVERAGE 0 @ 0 0 @ 0 ft/hr 0 @ 0 0 @ 0 ft/lbs 0 @ 0 0 @ 0 Klbs 0 @ 0 0 @ 0 RPM 0 @ 0 0 @ 0 psi DEPTH 6,810' MW 9.2+ F- VIS 47 PV 11 YP 16 CL- 30k GELS 6/7/11 FC 1/2 SOL 4.5 SD .5 Oil / H2O 0/93.1 Ca++ 40.0 TOOLS: HIGH LOW UNITS 0 @ 0 0 @ 0 0 TRIP GAS@=19u WIPER GAS@=0 SURVEY GAS@=0 0 @ 0 0 @ 0 0 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH=0 0 @ 0 0 @ 0 0 AVG=0 0 @ 0 0 @ 0 0 CURRENT=0 0 @ 0 0 @ 0 0 AVG=0 INTERVAL LITHOLOGY 60% PRESENT LITHOLOGY: SOME THROUGH SCREENS) Report by: Feb 14, 2017 Rigging down BOP test 39.48 6059.5 equipment. VERTICAL DEPTH Ph 10.5 0 0 DRILLING PARAMETERS Hillcorp Alaska, LLC Kenai Gas Field Rig Saxon 169 SURVEY DATA CASING INFORMATION REPORT FOR: Robert Wall, Clint Montague KBU 32-06 DAILY WELLSITE REPORT CLEAN OUT ASSEMBLY MUD TYPE KCL (Polymer) SURFACE TORQUE On Bottom Hrs. RATE OF PENETRATION 0 CURRENT AVG INTERVALBIT INFORMATION DITCH GAS PROPANE(C-3) CURRENT BACKGROUND AZIMUTH PUMP PRESSURE GAS SUMMARY (UNITS) DRILLING MUD REPORT TOOL\ SUMMARY WEIGHT ON BIT 0 TOP DRIVE RPM 0 0 0 0 0 SAND 10% (PROBABLY LOSING 0 CONNECTION GAS CHROMATOGRAPHY(ppm) FL LITHOLOGY/REMARKS HYDROCARBON SHOWS PENTANE(C-5) AVERAGE BUTANE(C-4) GAS UNITS 1499', 635'. Change out upper rams, test BOP. Rig down test equipment. TUFFACEOUS SILTSTONE RIH from 2500 to TD at 6810' for clean out run. Circulate bottoms up and pump sweep. TIH checking flow at 6810', 30%TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY: Dark grey hydrophilic cuttings, mostly amorphous globules exhibing indiscernible characteristics. When visible, light wedged, tabular cuttings with microlaminae carbonaceous material and coal; abundant fragments of same. Amorphous grey wedged, tabular cuttings with microlaminae carbonaceous material and coal; abundant fragments of same. Amorphous lithics possibly from annular travel. METHANE(C-1) CANRIG Personnel On Board= Dylan Muller ETHANE(C-2) 4 $2,785.00Daily Cost: DESCRIPTION Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Client Montague, Robert Wall DATE Feb 15, 2017 DEPTH 6810.0 PRESENT OPERATION Rig up cementing equipment TIME 23:59 YESTERDAY 6810.0 24 HOUR FOOTAGE 0 CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ XXXX' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6749' 18.18 39.48 6059.5 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6X13 1509' 6810' 5301' 54.9 1,2,CT,G,X,1,WT,TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 AMPS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS ROTARY RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH 6810' MW 9.35 VIS 51 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 0 @ 0 0 @ 0 0 TRIP GAS CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE 60%, TUFFACEOUS SILTSTONE 30%, SAND 10% PRESENT LITHOLOGY No new footage drilled at time of report DAILY ACTIVITY SUMMARY Run Casing to MD 6802', Circulate mud for cement job. Rig down casing equipment. Rig up cementing equipment. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Client Montague, Robert Wall DATE Feb 16, 2017 DEPTH 6810' PRESENT OPERATION MONITOR WELL TIME 23:59 YESTERDAY 6810' 24 HOUR FOOTAGE 0 CASING INFORMATION 10 3/4" @ 1499'.................... 7 5/8" @ 6761' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6749' 18.18 39.48 6059.5 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6X13 1509' 6810' 5301' 54.9 1,2,CT,G,X,1,WT,TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 AMPS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS ROTARY RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH Monitor Well MW 9.3+ 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 0 @ 0 0 @ 0 0 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 0 @ 0 0 AVG 0 PROPANE (C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE (C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE 60%, TUFFACEOUS SILTSTONE AND SAND 40% PRESENT LITHOLOGY No new lithology to report. DAILY ACTIVITY SUMMARY Finish rigging up cementers. Pump 80bbls of lead cement, pump truck sanded off and unable to pump. Attempt to free pump truck pack off, unable to free up cement truck, circulate out 80bbls out of hole, Rig down cement head. Build black water and flush out stack. Circulate and condition mud, wait on new batch to complete cement operations. Circulate and remain landed on load shoulder. Monitor Well while making regular mud checks. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2,785 REPORT BY Marquel Mosebay Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Robert Wall DATE Feb 17, 2017 DEPTH 6810' PRESENT OPERATION MONITOR WELL TIME 24:00 YESTERDAY 6810' 24 HOUR FOOTAGE 0 CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6749' 18.18 39.48 6059.5 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6X13 1509' 6810' 5301' 54.9 1,2,CT,G,X,1,WT,TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 AMPS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS ROTARY RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH Monitor Well MW 9.3+ 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 0 @ 0 0 @ 0 0 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 0 @ 0 0 AVG 0 PROPANE (C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE (C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE 60%, TUFFACEOUS SILTSTONE AND SAND 40% PRESENT LITHOLOGY No new lithology to report. DAILY ACTIVITY SUMMARY Circulate and condition mud. Cement well (CIP 16:40). Prepare for next stage of operations. Begin BOP test. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2785 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Robert Wall DATE Feb 18, 2017 DEPTH 6810' PRESENT OPERATION Make up BHA TIME 24:00 YESTERDAY 6810' 24 HOUR FOOTAGE 0 CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6749' 18.18 39.48 6059.5 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HDBS MM65 12611378 6X13 1509' 6810' 5301' 54.9 1,2,CT,G,X,1,WT,TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0 @ 0 0 @ 0 0 0 FT/HR SURFACE TORQUE 0 @ 0 0 @ 0 0 0 AMPS WEIGHT ON BIT 0 @ 0 0 @ 0 0 0 KLBS ROTARY RPM 0 @ 0 0 @ 0 0 0 RPM PUMP PRESSURE 0 @ 0 0 @ 0 0 0 PSI DRILLING MUD REPORT DEPTH MW 9.3+ 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 0 @ 0 0 @ 0 0 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 0 @ 0 0 AVG 0 PROPANE (C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE (C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE 60%, TUFFACEOUS SILTSTONE AND SAND 40% PRESENT LITHOLOGY No new lithology to report. DAILY ACTIVITY SUMMARY Prepare for next stage of operations and BOP test. Test BOP. Test casing to 3500 psi for 30 minutes. Run casing bond log from 6688' to 1600'. Make up BHA. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2785 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Robert Wall DATE Feb 19, 2017 DEPTH 7066' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 6810' 24 HOUR FOOTAGE 256' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6749' 18.18 39.48 6059.5' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6X10 6810' 256' 3.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 156.5 @ 6931' 4.0 @ 6813' 93.9 27.3 FT/HR SURFACE TORQUE 13440 @ 7018' 4401 @ 7057' 12320.6 0.0 AMPS WEIGHT ON BIT 12 @ 6856' 1 @ 6836' 7.0 4.6 KLBS ROTARY RPM 58 @ 7022' 26 @ 6834' 38.8 0.0 RPM PUMP PRESSURE 2190 @ 6925' 1634 @ 7005' 2027.3 1710.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 6810' TO 7066' TOOLS Directional BHA with MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 123 @ 7046' 4 @ 6876' 47.8 TRIP GAS 13 @ 6810' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 28517 @ 7046' 857 @ 6873 10863.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 @ 0.0 AVG 0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 3-11/6 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone; Tuffaceous Claystone/Tuffaceous Siltstone; Coal/Carbonaceous Material PRESENT LITHOLOGY 20% Sand; 10% Sandstone; 20% Tuffaceous Siltstone; 50% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Continue to make up BHA and single in hole to 4420'. RIH and displace to 10.0ppg mud. Drill out shoe and 20' of new hole to 6830'. Perform FIT to 13.1 EqMW. Drill from 6830' to 7066'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2785 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Robert Wall DATE Feb 20, 2017 DEPTH 7828' PRESENT OPERATION Wiper trip TIME 24:00 YESTERDAY 7066' 24 HOUR FOOTAGE 762' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7790.97' 15.77 34.20 7032.06' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6X10 6810' 1018' 13.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 184.2 @ 7598' 5.5 @ 7297' 106.2 119.7 FT/HR SURFACE TORQUE 14309 @ 7590' 0 @ 7649' 12525.3 13611.1 AMPS WEIGHT ON BIT 12 @ 7215' 0 @ 7121' 6.5 9.3 KLBS ROTARY RPM 78 @ 7311' 55 @ 7172' 65.0 57.9 RPM PUMP PRESSURE 2693 @ 7701' 1720 @ 7121' 2305.8 2586.9 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 278 @ 7678' 5 @ 7216' 77.4 TRIP GAS CUTTING GAS @ @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 63242 @ 7679' 1110 @ 7216' 17445.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 @ 0.0 AVG 0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 5-24/10 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand/Sandstone/Tuffaceous Sandstone; Coal/Carbonaceous Shale; Tuffaceous Siltstone/Tuffaceous Claystone PRESENT LITHOLOGY @ 7828': 10% Sandstone; 50% Tuffaceous Siltstone; 40% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drill from 7066' to 7828'. Pump sweep, CBU, Begin Wiper trip to shoe. Pull on elevators to 7517'. Encounter tight hole and backream to inside shoe. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2785 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Dorr DATE Feb 21, 2017 DEPTH 8510' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 7828' 24 HOUR FOOTAGE 682' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8412.06' 17.81 38.50 7625.69' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 1700' 26.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 183.1 @ 8160' 4.3 @ 8404' 76.5 137.8 FT/HR SURFACE TORQUE 14790 @ 8409' 0 @ 8209' 12534.0 14635.8 AMPS WEIGHT ON BIT 18 @ 8013' 0 @ 8401' 8.7 12.6 KLBS ROTARY RPM 71 @ 8211' 57 @ 7842' 61.2 67.9 RPM PUMP PRESSURE 2878 @ 8510' 1927 @ 7829' 2350.4 2878.7 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 327 @ 8338' 4 @ 7845' 69.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 29 @ 7828' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 65256 @ 8340' 1083 @ 7845' 15841.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 @ 0.0 AVG 0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 7-16/13 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone/Tuffaceous Sandstone/Sand; Coal/Carbonaceous Shale; Tuffaceous Siltstone/Tuffaceous Claystone; Tuff PRESENT LITHOLOGY @ 8510': 10% Sandstone; 60% Coal; 20% Tuffaceous Siltstone; 10% Tuffaceous Claystone DAILY ACTIVITY SUMMARY RIH one stand, pump sweep, work pipe and circulate out swwep. Pull to 6788'. Service rig. RIH on elevators. Safety ream last stand to bottom. Drill from 7828' to 8510' (Pumping sweeps at 7830', 7955', and 8448'). CANRIG PERSONNEL ON BOARD 4 DAILY COST 2785 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Dorr DATE Feb 22, 2017 DEPTH 9106' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8510' 24 HOUR FOOTAGE 596' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9031.86' 15.56 37.66 8217.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 2296' 38 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 194.4 @ 8598' 4.3 @ 8836' 89.1 16.6 FT/HR SURFACE TORQUE 15130 @ 8770' 22 @ 8889' 14094.8 11781.5 AMPS WEIGHT ON BIT 18 @ 8832' 1 @ 8883' 8.5 16.7 KLBS ROTARY RPM 77 @ 8820' 0 @ 8884' 69.2 52.3 RPM PUMP PRESSURE 3035 @ 9021' 2401 @ 8634' 2805.0 2714.9 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 845 @ 8825' 5 @ 8861' 134.2 TRIP GAS CUTTING GAS @ @ 0.0 WIPER GAS 1848u @ 8819' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 130230 @ 9027' 1104 @ 8861' 26381.6 C ONNECTION GAS HIGH 25 ETHANE (C-2) 0 @ 0 @ 0.0 AVG Tr PROPANE (C-3) 37 @ 8595' 0 @ 1.6 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 26-43/30 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone/Carbonaceous Shale; Tuff; Coal PRESENT LITHOLOGY @ 9105': 10% Tuffaceous Sandstone; 30% Sand; 50% Tuffaceous Siltstone; 10% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Drill from 8510' to 8819'. Pump and circulate high viscosity sweep. Wipe hole from 8819' to 7676' (tight spots 8504', 8191', 8010'). Service rig. RIH from 7676' to 8819' (wash last stand down). Drill from 8819' to 9106' (pumping sweeps at 8820', 9091'). CANRIG PERSONNEL ON BOARD 4 DAILY COST $2750 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Dorr DATE Feb 23, 2017 DEPTH 9803' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9106' 24 HOUR FOOTAGE 697' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9715.71' 8.49 41.24 8887.33' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 2993' 54.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 182.9 @ 9641' 5.6 @ 9189' 75.8 23.2 FT/HR SURFACE TORQUE 16049 @ 9347' 0 @ 9387' 12969.2 14044.7 AMPS WEIGHT ON BIT 25 @ 9170' 0 @ 9231' 10.3 9.1 KLBS ROTARY RPM 77 @ 9404' 0 @ 9336' 64.6 74.0 RPM PUMP PRESSURE 3282 @ 9776' 2451 @ 9142' 2974.2 2858.8 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 717 @ 9584' 11 @ 9164' 85.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 142622 @ 9584' 2233 @ 9164' 17181.6 CONNECTION GAS HIGH 12u @ 9254' ETHANE (C-2) 0 @ 0 @ 0.0 AVG Tr PROPANE (C-3) 18 @ 9585' 16 @ 9588' 0.2 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 28-46/36 PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONE/SANDSTONE/SAND; TUFFACEOUS CLAYSTONE/TUFFACEOUS SILTSTONE; TUFF; CARBONACEOUS SHALE; COAL PRESENT LITHOLOGY @ 9800': 40% TUFFACEOUS SANDSTONE; 50% SAND; 10% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY Drill from 9106' to 9803' (pummping sweeps at 9504', 9548'). CANRIG PERSONNEL ON BOARD 4 DAILY COST $2750 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Door DATE Feb 24, 2017 DEPTH 10335' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9803' 24 HOUR FOOTAGE 532' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10275.74' 8.09 39.19 9441.28' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 3525' 69.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 162.4 @ 10221' 6.0 @ 9838' 60.6 16.3 FT/HR SURFACE TORQUE 16383 @ 10259' 12751 @ 9873' 14852.7 13565.5 AMPS WEIGHT ON BIT 18 @ 9878' 1 @ 10000' 9.9 16.5 KLBS ROTARY RPM 75 @ 9822' 48 @ 10322' 71.0 50.8 RPM PUMP PRESSURE 3487 @ 9968' 2568 @ 10316' 3114.3 2950.6 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 410 @ 9993' 10 @ 9902' 71.4 TRIP GAS CUTTING GAS @ @ WIPER GAS 335' @ 9817' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 149627 @ 10218' 1832 @ 9902' 15971.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 @ 0.0 AVG 0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 13/ PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone; Coal/Carbonaceous Shale PRESENT LITHOLOGY 50% Tuffaceous Sandstone; 10% Sandstone; 30% Sand; 10% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drill from 9803' to 9817', pump and circulate out sweep. Wipe hole to 8702'. Service rig. RIH from 8702' to 9817' (pumping sweep while washing last stand to bottom). Drill from 9817' to 10335'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2750 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Dorr DATE Feb 25, 2017 DEPTH 10560' PRESENT OPERATION Circulating TIME 24:00 YESTERDAY 10335' 24 HOUR FOOTAGE 225' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10522.33' 7.96 38.84 9685.39' Projected @ 10560' 7.96 38.84 9722.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 10560' 3750' 75.1 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 101.1 @ 10397' 8.2 @ 10556' 47.9 9.9 FT/HR SURFACE TORQUE 16435 @ 10503' 12881 @ 10333' 15348.6 14485.0 AMPS WEIGHT ON BIT 17 @ 10364' 3 @ 10511' 9.3 11.9 KLBS ROTARY RPM 74 @ 10326' 47 @ 10343' 57.0 58.7 RPM PUMP PRESSURE 3181 @ 10372' 2376 @ 10354' 2955.5 2774.7 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 172 @ 10511' 10 @ 10362' 35.0 TRIP GAS CUTTING GAS @ @ WIPER GAS 236u @ 10560' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 33807 @ 10511' 1949 @ 10362' 7011.5 CONNECTION GAS HIGH 15u @ 10437' ETHANE (C-2) 0 @ 0 @ 0.0 AVG >0 PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT 0 BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG 6-8u (when started WT) PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone; Coal/Carbonaceous Shale PRESENT LITHOLOGY @ 10560': 30% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Drill from 10335' to 10560'TD. Pump sweep, circulate hole (while raising MW to 12.1ppg). Wipe hole to shoe. Cut drilling line 116', service rig. RIH to 10503'. Wash last stand to bottom (15' of fill). Pump sweep, circulate and condition mud. CANRIG PERSONNEL ON BOARD 4 DAILY COST $2750 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Dorr DATE Feb 26, 2017 DEPTH 10560' PRESENT OPERATION E log dummy run TIME 24:00 YESTERDAY 10560 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10522.33' 7.96 38.84 9685.39' Projected @ 10560' 7.96 38.84 9722.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 10560' 3750' 75.5 1-1-WT-A-X-1-NO-TD TD 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 6-8 (when finished circ before POOH) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone; Coal/Carbonaceous Shale PRESENT LITHOLOGY @ 10560': 30% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Circulate and condition mud. POOH to 6647'. Pump dry job. POOH from 6647' to 491'. Handle and lay down directional BHA. Make up bit, bit sub, and stabilizer for future clean-out run. Rig up Schlumberger wireline run. RIH with dummy run/Rig down dummy run tools. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Dorr DATE Feb 27, 2017 DEPTH 10560' PRESENT OPERATION Running sidewalls TIME 24:00 YESTERDAY 10560 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10522.33' 7.96 38.84 9685.39' Projected @ 10560' 7.96 38.84 9722.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 10560' 3750' 75.5 1-1-WT-A-X-1-NO-TD TD 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 6-8 (when finished circ before POOH) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone; Coal/Carbonaceous Shale PRESENT LITHOLOGY @ 10560': 30% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Make and run RFT/Gamma to 10560'. Log out from 10560' to 6800'. RIH to 10400'. Log from 10400' to 6837', collecting formation pressure samples. POOH with wireline. RIH with sidewall coring assembly to 9500'. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Adam Dorr DATE Feb 28, 2017 DEPTH 10560' PRESENT OPERATION Running E logs TIME 24:00 YESTERDAY 10560 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10522.33' 7.96 38.84 9685.39' Projected @ 10560' 7.96 38.84 9722.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6 3/4" Smith MM65D 12273690 6x10 6810' 10560' 3750' 75.5 1-1-WT-A-X-1-NO-TD TD 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 6-8 (when finished circ before POOH) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone; Coal/Carbonaceous Shale PRESENT LITHOLOGY @ 10560': 30% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Logging core samples from 9500' to 6000'. POOH with wireline (retrieve 44 sidewall cores, 6 missed). Pick up Caliper tool/Gamma ray. RIH with CTEM/GR. Log from 10481' to 7700'. POOH with wireline. RIH with Gamma ray/Tel Status tools to 7700'. Logging from CANRIG PERSONNEL ON BOARD 7700'. DAILY COST Dylan Muller, Paul Webster REPORT BY $1925 Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Adam Dorr DATE Mar 01, 2017 DEPTH 10560' PRESENT OPERATION POOH TIME 24:00 YESTERDAY 10560 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10522.33' 7.96 38.84 9685.39' Projected @ 10560' 7.96 38.84 9722.70' 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 235u @ 10560' 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 4 (when finished circ before POOH) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone; Coal/Carbonaceous Shale PRESENT LITHOLOGY @ 10560': 30% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY Log up with GR/Tel Status to 6802'. POOH with wireline. Rig down wireline. Service rig. Make up BHA and RIH to 6789'. CBU (Max Gas=70u). RIH to 8649'. CBU (Max Gas=153u). RIH to 10454. Wash to 10560'. CBU (Max Gas=235u). Pump sweep, spot nutplug. POOH. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Adam Dorr DATE Mar 02, 2017 DEPTH 10560' PRESENT OPERATION Running 4.5" Casing TIME 24:00 YESTERDAY 10560 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10522.33' 7.96 38.84 9685.39' Projected @ 10560' 7.96 38.84 9722.70' 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 4 (when finished circ before POOH) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone/Sandstone/Sand; Tuffaceous Siltstone/Tuffaceous Claystone; Coal/Carbonaceous Shale PRESENT LITHOLOGY @ 10560': 30% Tuffaceous Sandstone; 20% Sandstone; 20% Sand; 30% Tuffaceous Siltstone DAILY ACTIVITY SUMMARY POOH from 6784' to 380', laying down drill pipe. RIH from 380' to 4183'. CBU. POOH from 4183' to 380', laying down pipe. Lay down BHA. Prepare to run 4.5" casing. Run 4.5" casing from 127' to 1490'. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Adam Dorr DATE Mar 03, 2017 DEPTH 10560' PRESENT OPERATION Stuck (@9685') 4.5" Casing TIME 24:00 YESTERDAY 10560 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 2 (Currently) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run 4.5" casing from 1490' to 6780'. Circulate bottoms up (Max Gas = 24u) while changing out bails and elevators. Run 4.5" casing from 6780' to 8853'. Circulate bottoms up (Max Gas = 38u). Run 4.5" casing from 8853' to 9685'. Casing stuck at 9685'. Circulate and bring MW down to ~11.5 ppg (Max Gas = 45u). Spot brine/lube pill, let soak for one hour. Circulate, while working stuck pipe (Max Gas = 14u). CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Adam Dorr DATE Mar 04, 2017 DEPTH 10560' PRESENT OPERATION Stuck (@ 9685') 4.5" Casing TIME 24:00 YESTERDAY 10560 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 1 @ Tr @ 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 Tr/Tr PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Circulate, lowering MW to 11.0. Pump and spot Black Magic pill. Let pill soak for 1.5 hrs. Worked stuck casing (gained about 1'). Work stuck casing. Let pill work 1 hr. Work stuck casing. Currently letting pill work. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Adam Dorr DATE Mar 05, 2017 DEPTH 10560' PRESENT OPERATION Stuck (@ 9685') 4.5" Casing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 Tr @ Tr @ 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 Tr PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Alternatively, let Black Magic work for 1 to 1.5 hours and work stuck casing. Lay out pup, remove drilling bails. Install long bails and elevators. Rig up Pollard wireline. Run free point with Pollard wireline. Lay down free point tool. Pick up 2nd free point tool. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Adam Dorr DATE Mar 06, 2017 DEPTH 10560' PRESENT OPERATION Stuck 4.5" Casing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 Tr @ Tr @ TRIP GAS 901u 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 9u (when pumps killed) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run Pollard free point. Cut casing at 9455'. Pull on stuck casing to 220K (still stuck). Fish below 9455' apparently dropped down hole. Circulate casing (Max Gas = 901u). Run free point. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Robert Wall DATE Mar 07, 2017 DEPTH 10560' PRESENT OPERATION Pick up drill pipe TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 42 @ 17 @ 21 TRIP GAS 42u 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 17u (when pumps killed) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Lay down free point tool. Pick up and RIH with GR/Cutter tool. Fire cutter at 7262' (lose cutter tool in hole). POOH with 4.5" casing. Monitor well on trip tank. Pick up drill pipe and rack back in derrick. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Robert Wall DATE Mar 08, 2017 DEPTH 10560' PRESENT OPERATION Fishing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 17u (when pumps killed) PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish picking up drill pipe. Test BOP. RIH and POOH with impression tool. Appears turbolizer on top of casing stub. Make repeated, unsuccessful magnet runs to retrieve turbolizer. RIH with single-arm wireline grabber to try to flip turbolizer. POOH with wireline grabber. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Robert Wall DATE Mar 09, 2017 DEPTH 10560' PRESENT OPERATION POOH TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 See remarks 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 Make 2 impression tool runs and 3 magnet runs. Rig down wireline unit. Make up Fishing BHA. Single in 225'-4276'. RIH from derrick 4276'- 6755'. CBU (Max Gas=1493u). RIH to 7251'. CBU (Max Gas=1157u). Attempt to catch fish, apparently caught & lost 3 times. Pump out to 6789'. CBU (Max Gas=1195u). CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Robert Wall DATE Mar 10, 2017 DEPTH 10560' PRESENT OPERATION Lay down 4.5" Casing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 See remarks 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 POOH with taper tap. RIH with spear to 6754'. CBU (Max gas=568u). RIH to 7262'. Break circ and sting into fish (Max Gas=1147u). Jar fish to 300K, free came free. POOH with fish to 4609'. C BU (2 Max Gases = 1543u, 1319u). POOH with fish to 253'. Rack back 3 stands HWDP. Lay down down fishing tools. Lay down 4.5" casing. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Robert Wall DATE Mar 11, 2017 DEPTH 10560' PRESENT OPERATION Fishing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 See Daily Activity Summary 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 Currently 23 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to lay down 4.5" casing. Rig down casing equipment. Make up overshot fishing assembly. Single in from 224' to 3212'. RIH out of derrick to 5200'. CBU (Max Gas = 1186u). RIH from 5200' to 6758'. CBU (Max Gas = 1640u). RIH from 6758' to 7869'. (\CBU (Max Gas = 1281u). RIH from 7869' to 9742'. CBU (Max Gas = 1047u). Wash down from 9742' to 10307' (Max Gas = 103u). Circulate and work pipe. Pump sweep, circulate, and prepare to engage fish. Work down to fish, pick up, and lay down single. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Robert Wall DATE Mar 12, 2017 DEPTH 10560' PRESENT OPERATION RIH with taper tap TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 Currently 12 at last circ PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Work down, engage fish, set 70K down, pump pressure increased to 3000 psi, shut down pump, pick up 240K, fired jars, fish came free. Move fish up hole freely, stopped pipe movement briefly while circulating, got differentially stuck, worked pipe free. Pump out of hole from 10330' to 6500'. Circulate bottoms up and condition mud. POOH on elevators to overshot, no fish. Clear floor and service rig. Lay down overshot fishing tools. Slip and cut 76' drill line. Make up taper tap fishing assembly, 3 stands HWDP to 224'. RIH from 224' to 5853'. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Rance Pederson, Robert Wall DATE Mar 13, 2017 DEPTH 10560' PRESENT OPERATION RIH TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 See Daily Activity Summary 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 Currently 24u at last circ PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RIH from 5514' to 6756'. Circulate surface to surface (Max Gas = 1179u). RIH from 6756' to 8627'. CBU (Max Gas = 1452u). RIH from 8627' to 10308'. CBU (Max Gas = 1390u). Work down and screw into fish. POOH from 10340' to 6580'. Blow down top drive. POOH from 6580' to fish. Lay down fish, change elevators, lay down fishing t ools. Clean rig floor, clean/send down casing centralizers, and swap elevators. RIH from mule shoe to 5600'. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Robert Wall DATE Mar 14, 2017 DEPTH 10560' PRESENT OPERATION Running 4.5" casing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 See Daily Activity Summary 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 Currently 15u at last circ PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RIH from 5600' to 6791'. CBU (Max Gas = 1357u). Lay down drill pipe from 6791' to 189'. RIH out of derrick to 3726'. CBU (Max Gas = 476u). Lay down drill from 3726' to 0'. Rig up to run 4.5" casing. Run 4.5" casing from suface to 3149'. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster Hilcorp Alaska, LLC Kenai Gas Field DAILY WELLSITE REPORT KBU32-06 REPORT FOR Clint Montague, Robert Wall DATE Mar 15, 2017 DEPTH 10560' PRESENT OPERATION Done TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 10 3/4" @ 1499' 7 5/8" @ 6802' 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 See Daily Activity Summary 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 Run 4.5" casing from 3149' to 6779'. CBU (Max Gas = 1706u). Run 4.5" casing to 10548.5'. Circulate (Max Gas = 1784u) and cement casing. CANRIG PERSONNEL ON BOARD Dylan Muller, Paul Webster DAILY COST $1925 REPORT BY Paul Webster