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Home My WebLink About214-019Nolan 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 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.16 10:52:24 -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 9,855 feet See Schematic feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,445 feet 5,774 feet true vertical 8,891 feet 5,221 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker 5" Swell Pkr; N/A 5,774' MD 5,221' 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 10,500psi 5,210psi 6,890psi 10,140psi 1,600'1,532' Burst Collapse 2,470psi 6,257' 9,833' Casing Structural 5,723' 9,297' 6,277' 9,850' 135'Conductor Surface Intermediate 16" 10-3/4" 135' 1,600' measured TVD 7-5/8" 5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 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 A022330 / FEE A028142 Kenai - Beluga/Upper Tyonek Gas Kenai Beluga Unit (KBU) 43-07Y 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) Gas-Mcf MD 150 Size 135' 7 1505500 623 67 Production Stefan Reed, Operations Engineer 325-335 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 519 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 Liner 0 stefan.reed@hilcorp.com 206-518-0400 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 Gavin Gluyas at 12:31 pm, Jun 27, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.27 11:57:16 - 08'00' Noel Nocas (4361) RBDMS JSB 070325 BJM 9/23/25 Page 1/1 Well Name: KEU KBU 43-07Y Report Printed: 6/26/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20625-00-00 Field Name:Kenai Gas Field State/Province:ALASKA Permit to Drill (PTD) #:214-019 Sundry #:325-335 Rig Name/No: Jobs Actual Start Date:5/28/2025 End Date: Report Number 1 Report Start Date 5/16/2025 Report End Date 5/16/2025 Last 24hr Summary MIRU SL. PT PCE. Tagged top of fill at 9023'KB- Cleared fill to 9148'KB Report Number 2 Report Start Date 6/12/2025 Report End Date 6/12/2025 Last 24hr Summary PTW/PJSM, MIRU PWL, PT250/2500. Bail from 9118' SLM (9137' KB)-9135' SLM (9154' KB) in 4 runs W/ 2.0", 2.50" & 3.0" bailers. Minimal returns of clay. Report Number 3 Report Start Date 6/13/2025 Report End Date 6/13/2025 Last 24hr Summary PTW/PJSM, PT 250/2500. Ran multiple bailers to 9135' SLM (9154' KB) (recovered ~ 6 cups of dry clay), ran 2 different spears and pushed clay bridge plug from 9135' - 9146' SLM (9165' KB) Report Number 4 Report Start Date 6/14/2025 Report End Date 6/14/2025 Last 24hr Summary PTW/PJSM, PT 250/2500. Ran 2.75" cent, 6'x1.50" DD SD @ 9138' SLM (9157' KB), work to 9142' SLM. plug moving when pulling out of it ~5" plug of clay in btm. Ran 2.75" starbit SD @ 9139' SLM, & work to 9145' SLM, jar to come free, SD @ 9142' SLM, Ran 5'x3.0" DD W/O a bottom, SD @ 9142' SLM, Work to 9145' SLM (empty) Ran 2.25"x3' tube W/ mule shoe, SD @ 9144' SLM Work to 9151' SLM in 50 jar downs, Jar up several times to come free, SD @ 9147' SLM, (empty) Ran 5'x3.0" DD W/ flapper btm, SD @ 9145' SLM, work to 9149' in 25mins, (~2 cups of sandy dry clay & fluid) Ran 2.75" cent, 5'x1,50" WB, flat spear, SD @ 9148' SLM, Make hole & pull out with 1-3 jar up. Work for 1 hr to 9169' SLM, jar out & retag at 9167' SLM,(9186' KB) Report Number 5 Report Start Date 6/15/2025 Report End Date 6/15/2025 Last 24hr Summary PTW/PJSM. PT 250/2500. Ran 2.75" cent, 5'x1,50" WB, flat spear, SD @ 9136' SLM, work to 9164',overpull, come free SD @ 9157' SLM ran 5'x1.75" WB, 3.0" G-ring, SD @ 9157' SLM, work to 9164' SLM, PUH SD @ 9158' & work to 9163' repeat same results, Ran 2.59"cent,5'x1.50"WB, flat spear, SD @ 9159' SLM, in 1 hr work to 9187' SLM, PUH & retag @ 9183' SLM, 9202' KB, Ran 5'x1.75" WB, 3 1/2" BLB (tight), 2.81" parrafin cutter, SD @ 9187' SLM, see slight resistance from 9170'-9187' SLM, make several passes from 9130'-9187' SLM, Ran 5'x1.75"WB, loose 4 1/2" BLB, 3.0" g-ring, SD @ 9188' SLM (9207' KB), work tight spot from 9178'-9188' SLM Ran 9.5'x2.875" D. gun, 3.0" G-ring, SD @ 9186' SLM, (9205' KB) Report Number 6 Report Start Date 6/16/2025 Report End Date 6/16/2025 Last 24hr Summary PTW/PJSM, MIRU AK E-line, PT250/4000. Ran 10'x2.75" (6' loaded) perf gun, SD @ 9136.7' unable to pass. MIRU PWL, PT250/4000, Ran 3.0" G-ring SD @ 9129' SLM. ran 2.59" cent, 5' WB, flat spear, SD @ 9132' SLM, work to 9189' SLM in ~10mins, not making hole after 10 more mins jarring, PUH & retag 9187' SLM. Report Number 7 Report Start Date 6/17/2025 Report End Date 6/17/2025 Last 24hr Summary PTW/PJSM, MIRU PWL, PT250/4000. Tagged obstruction W/ 2.75" cent, flat spear @ 9188' SLM. MIRU AK Eline, PT250/4000. Perforate well shut in TY 86-2A 9181'-9187' & 9135'-9145' gg , p @ Perforate well shut in TY 86-2A 9181'-9187' & 9135'-9145 _____________________________________________________________________________________ Updated by SAR 06-20-25 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,470’CIBP w/ 25ft of cement on 10/6/23 6 9,735’CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 7 9,780’CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Pool Date Status / Allocated Gas Beluga Upper Tyonek Gas pool Top: 5245’MD, 4704’ TVD LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty 8/3/2022 Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open TY 72-8 7,790’7,813’7,236’7,259’23’Blga/Upr Ty 6/12/2024 Open TY 72-8 7,790’7,813’7,236’7,259’23’Blga/Upr Ty 9/9/2024 Open TY 75-8 8,088’8,103’7,534’7,549’15’Blga/Upr Ty 6/10/2024 Open TY 75-8 8,088’8,103’7,534’7,549’15’Blga/Upr Ty 9/92024 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/6/2024 Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open UT 2B 8,138’8,176’7,594’7,259’38’Blga/Upr Ty 6/5/2024 Open TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open TY 86-2A 9,135’9,145’8,581’8,591’10’Blga/Upr Ty 6/17/2025 Open TY 86-2A 9,181’9,187’8,627’8,633’6’Blga/Upr Ty 6/17/2025 Open D1 Coal 9,255’9,273’8,701’8,719’18 Blga/Upr Ty 10/7/23 Open Tyonek Gas Pool 1 top: 9432’ MD, 8879’ TVD D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 Isolated 10/6/23 D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 Isolated 10/6/23 D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated 8/12/20 D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated 3/27/15 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 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,855'9,825 (RKB) Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A 9,301'9,445'8,891' Kenai Beluga/Upr Tyonek Gas 16" 10-3/4" See Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 43-07YCO 510C Same 9,297'5" ~3,942psi 9,833' See Schematic Length June 12, 2025 N/A 9,850' Perforation Depth MD (ft): 6,277' See Schematic 6,890 psi 5,210 psi 135' 5,723' 135' 1,600' Size 135' 7-5/8"6,257' 1,577' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,140 psi 1,532' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEEA022330 | FEEA028142 214-019 50-133-20625-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Stefan Reed, Operations Engineer AOGCC USE ONLY Tubing Grade: stefan.reed@hilcorp.com 206-518-0400 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s t 2 N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:20 pm, Jun 02, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.02 12:09:10 - 08'00' Noel Nocas (4361) 325-335 A.Dewhurst 06JUN25BJM 6/9/25 10-404 DSR-6/3/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.10 11:57:13 -08'00'06/10/25 RBDMS JSB 061025 Add Perf Rev. 1 Well: KBU 43-07Y Date: 5/28/25 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Permit to Drill Number: 214-019 First Call Engineer: Stefan Reed (907) 777-8433 (O) (206) 518-0400 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: ~ 4,800 psi @ 8,581’ TVD (Based on offset well data) Max. Predicted Surface Pressure: ~ 3,942 psi (0.10 psi/ft gas gradient) Applicable Frac Gradient: 0.7 psi/ft using 13.5 ppg EMW FIT at the intermediate casing 4/06/24 Shallowest Potential Perf TVD: NA for proposed perf zones, already open above proposed perfs Top of Pools per CO 510C: Beluga/Upper Tyonek Gas pool: 5,245' MD, 4,704' TVD Tyonek Gas Pool 1: 9,432’ MD; 8,879’ TVD Brief Well Summary: KBU 43-07Y was drilled and completed in the Tyonek D sands in 2014 by Hilcorp. It was perf’d and produced in the D3C and the D3B. In May 2019, the D3A and D2 sands were perf’d adding about 300 mcfd. In early June 2020, the Tyonek 2A and 2B were perf’d coming online with an additional 500 mcfd. In August and September 2020, several Lower Beluga sands were perforated, and the Pools were commingled in hopes to get the rate up above 1.0 MMCFD. The Tyonek Gas Pool 1 sands were plugged back in 2024 and it is no longer a commingled producer. Additional perforations were added in the UT sands in 2024 adding a slight increase to rate. The well is only open in the Beluga/Upper Tyonek gas pool, per CO 510C. The purpose of this work is to add additional perfs in the Upper Tyonek Sand package. Current Status: Producing ~529mcfd with 7 bwpd at 59 psi FTP Notes Regarding Wellbore Condition x Monobore 5” completion x 5/16/2025 – Slickline tagged @ 9,148’ w/ 3.85” GR E-Line Procedure: 1. MIRU E-line, PT lubricator to 250 psi low and 4,000 psi high 2. Perforate the proposed sands bottoms up, testing each sand as desired by RE/GEO. Proposed Perforated Intervals Pool Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Feet Beluga/UT Gas TY 86-2A ±9,135’ ±9,145’ ±8,581’ ±8,591’ ±10’ Beluga/UT Gas TY 86-2A ±9,181’ ±9,187’ ±8,627’ ±8,633’ ±6’ Beluga/UT Gas TY D1 ±9,405’ ±9,425’ ±8,851’ ±8,871’ ±20’ a. Send the correlation pass to the Reservoir Engineer (Joleen Oshiro), and Geologist (McKenzie Neely) for confirmation. b. Verify PTs are open to SCADA before perforating. Record tubing pressures at 5, 10 and 15 minutes after each perforating run. 4600 3742 -bjm See attached email from Stefen Reed -bjm Add Perf Rev. 1 Well: KBU 43-07Y Date: 5/28/25 c. Pending well production, all perf intervals may not be completed. Reperf zones as requested by RE/GEO. d. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations e. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations. f. These sands are in the Beluga/Upper Tyonek Gas Pool per CO 510C. 3. RDMO e-line 4. Turn well over to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Standard Nitrogen Procedure _____________________________________________________________________________________ Updated by DMA 09-12-24 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,470’CIBP w/ 25ft of cement on 10/6/23 6 9,735’CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 7 9,780’CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Pool Date Status / Allocated Gas Beluga Upper Tyonek Gas pool Top: 5245’MD, 4704’ TVD LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty 8/3/2022 Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open TY 72-8 7,790’7,813’7,236’7,259’23’Blga/Upr Ty 6/12/2024 Open TY 72-8 7,790’7,813’7,236’7,259’23’Blga/Upr Ty 9/9/2024 Open TY 75-8 8,088’8,103’7,534’7,549’15’Blga/Upr Ty 6/10/2024 Open TY 75-8 8,088’8,103’7,534’7,549’15’Blga/Upr Ty 9/92024 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/6/2024 Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open UT 2B 8,138’8,176’7,594’7,259’38’Blga/Upr Ty 6/5/2024 Open TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open D1 Coal 9,255’9,273’8,701’8,719’18 Blga/Upr Ty 10/7/23 Open Tyonek Gas Pool 1 top: 9432’ MD, 8879’ TVD D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 Isolated 10/6/23 D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 Isolated 10/6/23 D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated 8/12/20 D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated 3/27/15 _____________________________________________________________________________________ Updated by SAR 05-29-25 PROPOSED Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,470’CIBP w/ 25ft of cement on 10/6/23 6 9,735’CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 7 9,780’CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Pool Date Status / Allocated Gas Beluga Upper Tyonek Gas pool Top: 5245’MD, 4704’ TVD LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty 8/3/2022 Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open TY 72-8 7,790’7,813’7,236’7,259’23’Blga/Upr Ty 6/12/2024 Open TY 72-8 7,790’7,813’7,236’7,259’23’Blga/Upr Ty 9/9/2024 Open TY 75-8 8,088’8,103’7,534’7,549’15’Blga/Upr Ty 6/10/2024 Open TY 75-8 8,088’8,103’7,534’7,549’15’Blga/Upr Ty 9/92024 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/6/2024 Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open UT 2B 8,138’8,176’7,594’7,259’38’Blga/Upr Ty 6/5/2024 Open TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open TY 86-2A ±9,135’±9,145’±8,581’±8,591’±10’Blga/Upr Ty NA Proposed TY 86-2A ±9,181’±9,187’±8,627’±8,633’±6’Blga/Upr Ty NA Proposed D1 Coal 9,255’9,273’8,701’8,719’18 Blga/Upr Ty 10/7/23 Open TY D1 ±9,405’±9,425’±8,851’±8,871’±20’Blga/Upr Ty NA Proposed Tyonek Gas Pool 1 top: 9432’ MD, 8879’ TVD D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 Isolated 10/6/23 D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 Isolated 10/6/23 D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated 8/12/20 D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated 3/27/15 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 Christianson, Grace K (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, June 9, 2025 4:16 PM To:Stefan Reed Subject:RE: [EXTERNAL] KBU 43-07 perf sundry Stefan, I agree with your assessment below, given the corrected reservoir pressure, the risk is low. I’ll attach this email to the sundry and recommend it be approved. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Stefan Reed <stefan.reed@hilcorp.com> Sent: Monday, June 9, 2025 3:39 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] KBU 43-07 perf sundry Bryan, ConƱrmed with the RE, there was a typo in the perf sheet I was using for pressures, below are the estimated reservoir pressures for the sands we propose to perforate: TY 86-2A = 4600psi @ 8581’ TVD (No nearby RFT data in the 86-2 sand. Using 84-6 sand RFT from well KU 41-08 from 2024. This is likely pretty conservative (high side)). TY D1 = 3569psi @ 8851’ TVD (RFT 2014 in 43-07Y) Using a 0.1 gas gradient I get the following shallowest perf TVDs: TY 86-2: MPSP 3742psi 3742psi/(.7-.1psi/ft) = 6236’ TVD TY D1: MPSP 2684psi 2684psi/(.7-.1psi/ft) = 4473’ TVD CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Our highest perforation is currently @ 6,181’TVD. Back calculating for highest RE pressure @ 8581’ TVD: 6181’*(.7-.1psi/ft) = 3709psi 3709psi + (0.1psi/ft*8581’) = 4567psi With our estimated reservoir pressure on the high side (4600psi) and being less than 50psi and 55’ TVD away from an acceptable value Hilcorp does not believe there is any risk in fracturing shallow formations. The well will be on production after perforating and draw down the formation pressure further reducing the risk. Regards, Stefan Reed Operations Engineer Kenai Asset Team Cell: 206-518-0400 Hilcorp Alaska, LLC From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 9, 2025 11:49 AM To: Stefan Reed <stefan.reed@hilcorp.com> Subject: [EXTERNAL] KBU 43-07 perf sundry Stefan, x Is the reservoir pressure in the TY D1 sand correct in the sundry application? It’s saying 10.6 ppg EMW, which would create a fracture pressure issue with the shallower open perfs. x The Shallowest Potential Perf TVD is not NA in this case. You just need to change the calculation and work down to Ʊnd the deepest potential perf. Or just run the calculation as you normally do and you’ll see that the open perfs are already above what would be allowed. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 9,470; Total Depth measured 9,855 feet 9,735; 9,780 feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,445 feet 5,774 feet true vertical 8,891 feet 5,221 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker 5" Swell Pkr; N/A 5,774' MD 5,221' 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 324-282 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 433 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 chelgeson@hilcorp.com 907-777-8405 N/A Liner 0 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) Gas-Mcf MD 125 Size 135' 0 1606200 557 63 Production measured TVD 7-5/8" 5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 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 A022330 / FEE A028142 Kenai / Beluga/Upper Tyonek Gas - Tyonek Gas Kenai Beluga Unit (KBU) 43-07Y Plugs Junk measured Length 6,257' 9,833' Casing Structural 5,723' 9,297' 6,277' 9,850' 135'Conductor Surface Intermediate 16" 10-3/4" 135' 1,600' 4,790psi 10,500psi 5,210psi 6,890psi 10,140psi 1,600' 1,532' Burst Collapse 2,470psi 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 3:40 pm, Sep 18, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.09.18 12:07:06 - 08'00' Noel Nocas (4361) Page 1/1 Well Name: KEU KBU 43-07Y Report Printed: 9/12/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:5/13/2024 End Date: Report Number 1 Report Start Date 5/10/2024 Report End Date 5/10/2024 Last 24hr Summary Drift and Tag - Perform Survey Report Number 2 Report Start Date 6/5/2024 Report End Date 6/6/2024 Last 24hr Summary PTW/PJSM. MIRU AK E-line. P-test 250/2,500 psi. Perforate UT2B Sand from 8,138' - 8,176' in two runs. Initial SITP: 874 psi. Final SITP: 871 psi. Turn well over to Production to flow test. Report Number 3 Report Start Date 6/6/2024 Report End Date 6/7/2024 Last 24hr Summary PTW/PJSM. Safety stand-down meeting. PU wireline lubricator and MU gun string. Perforate UT2A Sand from 8,119' - 8,129'. Initial SITP: 771 psi. Final SITP: 774 psi. Turn well over to Production to flow test. RDMO. Report Number 4 Report Start Date 6/10/2024 Report End Date 6/10/2024 Last 24hr Summary PTW/PJSM. MIRU AK E-line. Pressure test 250/2,500 psi. SI well and perforate the Ty75-8 interval (8088'-8103') twice with EquiFrac guns. Initial SITP: 738 psi. Final SITP: 780 psi. Turn well over to Production to flow test. Report Number 5 Report Start Date 6/12/2024 Report End Date 6/12/2024 Last 24hr Summary Well SI at 0400. AK E-line PTW and PJSM, mobe to location and RU. M/U 23' perf gun loaded with EquiFrac charges and PT 250 psi/2500 psi. Perforate Ty72-8 interval (7990'-7813'). M/U second perf gun and reshoot same interval. Secure well and turn over to production to flow test. Report Number 6 Report Start Date 9/9/2024 Report End Date 9/10/2024 Last 24hr Summary PTW/PJSM. MIRU AK-E-line, PT 250/2500, reperforate TY 75-8 from 8088'-8103' & TY 72-8 from 7790'-7813'. No significant pressure change. Field: Kenai Gas Field Sundry #: 324-282 State: Alaska Rig/Service:Permit to Drill (PTD) #:214-019Permit to Drill (PTD) #:214-019 Wellbore API/UWI:50-133-20625-00-00 _____________________________________________________________________________________ Updated by DMA 09-12-24 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850 JEWELRY DETAIL No Depth Item 1 5,7745 Swell Packer 2 6,561RA Marker with 5 Pup 3 7,258RA Marker with 5 Pup 4 9,212RA Marker with 5 Pup 5 9,470CIBP w/ 25ft of cement on 10/6/23 6 9,735CIBP w/ 5ft of cement TOC @ 9,730 8/11/20 7 9,780CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4" 164BBLs of cement in 13.5 Hole. Returns to Surface 7-5/8"254BBLs of cement in 9-7/8 Hole. Returns to Surface 5156BBLs of cement in 6-3/4 Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Pool Date Status / Allocated Gas Beluga Upper Tyonek Gas pool Top: 5245MD, 4704 TVD LB 1B 6,735'6,745'6,1816,19110'Blga/Upr Ty 8/31/2021 Open LB 1C 6,7816,7966,2286,24315Blga/Upr Ty 9/15/2020 Open LB 1E 6,8486,8686,2946,31420Blga/Upr Ty 9/15/2020 Open LB 2 6,9536,9636,3996,40910Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,4786,48810'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,5146,5228'Blga/Upr Ty 8/31/2021 Open LB 2D 7,0877,0176,5336,55320Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,5796,5889'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,6526,66412'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,6956,71520'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306' 7,319'6,752 6,76513' Blga/Upr Ty 8/19/2021 Open LB 3C 7,327' 7,336'6,773 6,7829' Blga/Upr Ty 8/19/2021 Open LB 4 7,356 7,364 6,802 6,810 8Blga/Upr Ty 8/13/2020 Open LB 4A 7,379 7,383 6,825 6,829 4Blga/Upr Ty 8/13/2020 Open LB 4B 7,406 7,413 6,852 6,859 7Blga/Upr Ty 8/13/2020 Open LB 4C 7,459 7,473 6,905 6,859 14Blga/Upr Ty 8/13/2020 Open LB 4B 7,460 7,474 6,906 6,920 14Blga/Upr Ty 8/3/2022 Open LB 4D 7,517' 7,523'6,963 6,9696' Blga/Upr Ty 8/19/2021 Open LB 5 7,534' 7,538'6,980 6,6644' Blga/Upr Ty 8/19/2021 Open LB 5A 7,578' 7,585'7,024 7,0317' Blga/Upr Ty 8/19/2021 Open LB 5B 7,620' 7,639'7,066 7,08519' Blga/Upr Ty 8/17/2021 Open LB 5C 7,643' 7,650'7,089 7,0967' Blga/Upr Ty 8/17/2021 Open LB 5C 7,652' 7,655'7,098 7,1013' Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665 7,671 7,111 7,117 6Blga/Upr Ty 8/3/2022 Open LB 6A 7,708' 7,714'7,154 7,1606' Blga/Upr Ty 8/17/2021 Open TY 72-8 7,790 7,813 7,236 7,259 23Blga/Upr Ty 6/12/2024 Open TY 72-8 7,790 7,813 7,236 7,259 23Blga/Upr Ty 9/9/2024 Open TY 75-8 8,088 8,103 7,534 7,549 15Blga/Upr Ty 6/10/2024 Open TY 75-8 8,088 8,103 7,534 7,549 15Blga/Upr Ty 9/92024 Open UT 2A 8,119 8,129 7,564 7,574 10Blga/Upr Ty 6/5/2020 Open UT 2A 8,119 8,129 7,564 7,574 10Blga/Upr Ty 6/6/2024 Open UT 2B 8,138 8,148 7,584 7,594 10Blga/Upr Ty 6/5/2020 Open UT 2B 8,138 8,176 7,594 7,259 38Blga/Upr Ty 6/5/2024 Open TY_84_6C 9,002 9,042 8,449 8,489 40Blga/Upr Ty 1/22/2021 Open D1 Coal 9,255 9,273 8,701 8,71918 Blga/Upr Ty 10/7/23 Open Tyonek Gas Pool 1 top: 9432 MD, 8879 TVD D2 9,477 9,490 8,923 8,936 13Tyonek 5/21/2019 Isolated 10/6/23 D3A 9,704 9,714 9,150 9,160 10Tyonek 5/6/2019 Isolated 10/6/23 D3B 9,746 9,766 9,192 9,212 20Tyonek 7/15/2014 Isolated 8/12/20 D3C 9,804' 9,824' 9,250' 9,270'20Tyonek 5/14/2014 Isolated 3/27/15 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: 9/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240912 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 7/22/2024 BAKER RPM Blossom 1 50133206480000 215015 8/31/2024 READ Coilflag Blossom 1 50133206480000 215015 9/2/2024 READ MemoryRadialCementBondLog KBY 43-07Y 50133206250000 214019 9/9/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/29/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/4/2024 AK E-LINE Plug/Perf NCIU A-20 50883201960000 224065 8/29/2024 AK E-LINE Perf NCIU A-20 50883201960000 224065 9/3/2024 AK E-LINE Plug/Perf PBU N-21A (REVISED) 50029213420100 196196 3/28/2024 BAKER SPN PBU N-02 50029200830000 170055 7/25/2024 BAKER SPN PBU S-104 50029229880000 200196 7/7/2024 BAKER SPN PBU Z-68 50029234930000 213093 7/6/2024 BAKER SPN Pearl 11 50133207120000 223032 6/24/2024 BAKER SPN Revision explanation: OmniView .las file was the same as the carbo/oxygen .las file, omniview file has been replaced with the correct file and data. Please include current contact information if different from above. T39545 T39546 T39546 T39547 T39548 T39548 T39549 T39549 T39550 T39551 T39552 T39553 T39554 KBY 43-07Y 50133206250000 214019 9/9/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.12 12:52:42 -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: 6/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240627 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 43-07Y 50133206250000 214019 6/6/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/10/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/12/2024 AK E-LINE Perf MPU F-6650029226970ϭ00 1961ϲϮ 5/17/2024 AK E-LINE Perf MRU K-03RD2 50733200740200 217029 5/25/2024 AK E-LINE TubingPunch PAXTON 2 50133205730000 207164 5/16/2024 AK E-LINE Pref PAXTON 2 50133205730000 207164 5/30/2024 AK E-LINE TubingPatch PAXTON 11 50133207040000 221114 5/20/2024 AK E-LINE Perf SCU 13-09 50133203430000 181098 6/2/2024 AK E-LINE Cement/JetCut SDI 3-07A 50029219110100 198147 5/28/2024 AK E-LINE Pkr/Poglm SRU 14B-27 50133206040000 212089 6/15/2024 AK E-LINE JewelryLog SRU 32C-15 50133206130000 213070 6/13/2024 AK E-LINE TubingCut Revision Explanation: There are additional images added to the final report and a few new .las files. In the Emeraude folder there are 2 new .las files and in the Field Data folder the RIH and POOH are new .las files Please include current contact information if different from above. T39076 T39076 T39076 T39077 T39078 T39079 T39079 T39080 T39081 T39082 T39083 T39084 KBU 43-07Y 50133206250000 214019 6/6/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/10/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/12/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.27 13:09:17 -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: 6/21/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240621 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 5/17/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 10/19/2023 AK E-LINE PLT END 2-72 50029237810000 224016 6/10/2024 HALLIBURTON RBT Paxton 3 50133205880000 209168 3/14/2023 AK E-LINE GPT/JBGR/RBP PBU E-12A 50029207820100 216127 6/4/2024 HALLIBURTON RBT PBU-GNI-03 50029228200000 197189 5/21/2024 READ CaliperSurvey Please include current contact information if different from above. T38984 T38985 T38986 T38987 T38988 T38989 KBU 43-07Y 50133206250000 214019 10/19/2023 AK E-LINE PLT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.21 13:35:29 -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: N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,855'9,825 (RKB) Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEEA022330|FEEA028142 214-019 50-133-20625-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,140 psi 1,532' Size 135' 7-5/8"6,257' 1,577' MD See Schematic 6,890 psi 5,210 psi 135' 5,723' 135' 1,600' May 22, 2024 N/A 9,850' Perforation Depth MD (ft): 6,277' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 43-07YCO 510C Same 9,297'5" ~1,747psi 9,833' 9,735; 9,780 Length Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A 9,301'9,730'9,176' Kenai Beluga/Upr Tyonek Gas 16" 10-3/4" See Schematic m n P s t 2 N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:35 pm, May 09, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.05.08 15:16:24 - 08'00' Noel Nocas (4361) 324-282 SFD 5/13/2024BJM 5/29/24 Perforate 10-404 DSR-5/13/24*&:JLC 5/29/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.05.30 09:23:20 -08'00'05/30/24 RBDMS JSB 060424 Well Prognosis Well: KBU 43-07Y Date: 5/8/24 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Permit to Drill Number: 214-019 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) Maximum Expected BHP: ~ 2,500 psi @ 7,534’ TVD (Based on offset well data) Max. Predicted Surface Pressure: ~ 1,747 psi (0.10 psi/ft gas gradient) Applicable Frac Gradient: 0.7 psi/ft using 13.5 ppg EMW FIT at the intermediate casing 4/23/24 Shallowest Potential Perf TVD: NA for proposed perfs zones already open above proposed perfs Top of Pools per CO 510C:Beluga/Upper Tyonek Gas pool: 5,245' MD, 4,704' TVD Tyonek Gas Pool 1: 9,432’ MD; 8,879’ TVD Brief Well Summary: KBU 43-07Y was drilled and completed in the Tyonek D sands in 2014 by Hilcorp. It was perf’d and produced in the D3C and the D3B. In May 2019, the D3A and D2 sands were perf’d adding about 300 mcfd. In early June 2020, the Tyonek 2A and 2B were perf’d coming online with an additional 500 mcfd. In August and September 2020, several Lower Beluga sands and the Pools were commingled and added in hopes to get the rate up above 1.0 MMCFD. The Tyonek Gas Pool 1 sands were plugged back in 2024 and no longer a commingled producer and the well is only open in the Beluga/Upper Tyonek gas pool, per CO 510C. The purpose of this work is to add additional perfs in the Upper Tyonek Sand package. Current Status: Producing ~460mcfd with 7 bwpd at 54 psi FTP Notes Regarding Wellbore Condition x Monobore 5” completion E-Line Procedure: 1. MIRU E-line, PT lubricator to 250 psi low and 2,500 psi high 2. Perforate the proposed sands with phased perf guns. Proposed Perforated Intervals Pool Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Feet Beluga/UT Gas TY 72-8 ±7,790’ ±7,813’ ±7,236’ ±7,259’ ±23’ Beluga/UT Gas TY 75-8 ±8,088’ ±8,103’ ±7,534’ ±7,549’ ±15’ Beluga/UT Gas UT 2A ±8,119’ ±8,129’ ±7,564’ ±7,574’ ±10’ Beluga/UT Gas UT 2B ±8,138’ ±8,176’ ±7,594’ ±7,259’ ±28’ a. Proposed perfs also shown on the proposed schematic in red font. b. Send the correlation pass to the Reservoir Engineer (Reid Edwards), and Geologist (Daniel Yancey) for confirmation. c. Verify PTs are open to SCADA before perforating. Record tubing pressures at 5, 10 and 15 minutes after each perforating run. Beluga/Upper Tyonek Gas pool: 5,245' MD well is only open in the Beluga/Upper Tyonek gas pool Well Prognosis Well: KBU 43-07Y Date: 5/8/24 d. Pending well production, all perf intervals may not be completed e. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations f. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations. g. These sands are in the Beluga/Upper Tyonek Gas Pool per CO 510C. 3. RDMO e-line 4. Turn well over to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Standard Nitrogen Procedure _____________________________________________________________________________________ Updated by CAH 11-10-23 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,470’CIBP w/ 25ft of cement on 10/6/23 6 9,735’CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 7 9,780’CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD)Ft Pool Date Status / Allocated Gas LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty 8/3/2022 Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open D1 Coal 9,255’9,273’8,701’8,719’18 Blga/Upr Ty 10/7/23 Open D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 Isolated (10/6/23) D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 Isolated (10/6/23) D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated (3/27/2015) _____________________________________________________________________________________ Updated by DMA 05-07-24 PROPOSED Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,470’CIBP w/ 25ft of cement on 10/6/23 6 9,735’CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 7 9,780’CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Pool Date Status / Allocated Gas Beluga Upper Tyonek Gas pool Top: 5245’MD, 4704’ TVD LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty 8/3/2022 Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open TY 72-8 ±7,790’±7,813’±7,236’±7,259’±23’Blga/Upr Ty Proposed TBD TY 75-8 ±8,088’±8,103’±7,534’±7,549’±15’Blga/Upr Ty Proposed TBD UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open UT 2A ±8,119’±8,129’±7,564’±7,574’10’Blga/Upr Ty Proposed TBD UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open UT 2B ±8,138’±8,176’±7,594’±7,259’±38’Blga/Upr Ty Proposed TBD TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open D1 Coal 9,255’9,273’8,701’8,719’18 Blga/Upr Ty 10/7/23 Open Tyonek Gas Pool 1 top: 9432’ MD, 8879’ TVD D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 Isolated 10/6/23 D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 Isolated 10/6/23 D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated 8/12/20 D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated 3/27/15 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. 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: 1/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240112 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-35 50283201930000 223077 11/4/2023 AK E-LINE CBL END 1-27 50029216930000 187009 11/16/2023 YELLOWJACKET PERF KALOTSA 4 50133206650000 217063 9/28/2023 YELLOWJACKET PERF KALOTSA 8 50133207050000 222003 11/29/2023 YELLOWJACKET PERF KBU 13-8 50133203040000 177029 11/5/2023 YELLOWJACKET PERF KBU 22-06Y 50133206500000 215044 11/9/2023 YELLOWJACKET GPT KBU 22-06Y 50133206500000 215044 11/17/2023 YELLOWJACKET PLUG-PERF KBU 11-08Z 50133206290000 214044 8/24/2023 AK E-LINE GPT/CIBP/PERF KBU 22-06Y 50133206500000 215044 10/9/2023 AK E-LINE CBL KBU 23-05 50133206300000 214061 10/10/2023 AK E-LINE PLT KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF MPU I-01 50029220650000 190090 11/18/2023 YELLOWJACKET PERF PAXTON 12 50133207100000 223014 11/20/2023 YELLOWJACKET PERF PAXTON 7 50133206430000 214130 9/18/2023 YELLOWJACKET CBL PAXTON 7 50133206430000 214130 10/7/2023 YELLOWJACKET PERF SRU 224-10 50133101380100 222124 12/27/2023 YELLOWJACKET GPT-PLUG-PERF SRU 224-10 50133101380100 222124 11/4/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 11/8/2023 YELLOWJACKET PERF-PLUG-GPT SRU 231-33 50133101630100 223008 11/3/2023 YELLOWJACKET PERF SRU 231-33 50133101630100 223008 10/17/2023 YELLOWJACKET PLUG-PERF-GPT SRU 232-15 50133207140000 223091 12/6/2023 YELLOWJACKET GPT-PERF SRU 232-15 50133207140000 223091 12/2/2023 YELLOWJACKET SCBL Please include current contact information if different from above. T38273 T38275 T38277 T38278 T38279 T38280 T38280 T38281 T38282 T38283 T38284 T38285 T38286 T38287 T38288 T38288 T38289 T38289 T38289 T38290 T38290 1/18/2024 T38287 KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.18 11:52:00 -09'00' 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: N2 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: 9,470; Total Depth measured 9,855 feet 9,735; 9,780 feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,445 feet 5,774 feet true vertical 8,891 feet 5,221 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker 5" Swell Pkr; N/A 5,774' MD 5,221' 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 10,500psi 5,210psi 6,890psi 10,140psi 1,600' 1,532' Burst Collapse 2,470psi 6,257' 9,833' Casing Structural 5,723' 9,297' 6,277' 9,850' 135'Conductor Surface Intermediate 16" 10-3/4" 135' 1,600' measured TVD 7-5/8" 5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 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 A022330 / FEE A028142 Kenai / Beluga/Upper Tyonek Gas - Tyonek Gas Kenai Beluga Unit (KBU) 43-07Y 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) Gas-Mcf MD 178 Size 135' 0 1705050 600 57 Production Chad Helgeson, Operations Engineer 323-465 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 486 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 chelgeson@hilcorp.com 907-777-8405 N/A Liner 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 Samantha Carlisle at 10:15 am, Nov 14, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.10 17:28:24 - 09'00' Noel Nocas (4361) Rig Start Date End Date 9/7/23 10/19/23 09/07/2023 - Thursday Ops SI well @ 0300. Pressure built from 60psi to 924psi @ 1200 AK Eline arrive in office, completed permit to work, conducted a PJSM Spot and RU on well 43-07Y. PT Equipment, 1000 L/ 4000 H MU GPT equipment, RIH to 9500ft. See a density change from 0.04 psi/ft to 0.2 psi/ft @ 6600ft. Fluid level (density = 0.4 psi/ft) at 7350' MIRU Fox N2 unit, hardline connected to pump in sub, PT piping to 4000 psi. Started N2 push into well at 1000scfm, starting pressure 924 psi 1:30 pm FL at 7116' 2:00 pm FL at 7158' 2:30 pm FL at 7189' 3:00 pm FL at 7222' N2 pressure of 2075 psi (increased N2 rate to 1250 scfm) 3:30 pm FL at 7260' N2 pressure of 2226 psi (increased N rate to 1502 scfm) 4:00 pm, N2 tank empty, connected transport, while N2 SD Eline RIH to 9500ft, BHP = 3806 psi, Surface = 2283 psi. 4:06 pm FL at 7296' while N2 pump down and TP 2100 psi 4:25 pm FL at 7303' with 1800 psi on surface 4:30 pm started pumping new load of N2 with tubing at 1707 psi Decision made to pump rest of N2 at 1250 scfm, & Eline POOH and SDFN and will check fluid level in morning. ELine rig down, continued pumping N2 for a total of 4641 gal of N2 and final pressure of 2460 psi. Shut-in and secured well for the night. 09/08/2023- Friday 10/06/2023- Friday Travel to KGF office. PJSM & permit. Travel to location. R/U AK E-Line. RIH w/ GPT. Found FL at 7345'. Town decided to flow well as is for now. POOH. OOH. RDMO AK E-Line from KBU 43-07Y. Move to KBU 23-05. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 PJSM and PTW. SIMOPS with production Well flowing 513MCFD @ 32psi. RU AK Eline MU gamma, and 5" CIBP (3.71OD) (CCL to plug 14.4ft) RIH, pull correlation log and send to town. Shift down 1ft Pull on depth and set CIBP at 9,470'. PU, and tag plug, good tag. POOH. MU CCL and 4"x 40ft cement dump bailer. RIH and set down at 7,408'. Cannot work bailer free. Shut in well, flow well, pump 2bbl diesel while shut in. No luck getting free. SITP slowly climbing to 650psi. Mobilize Fox N2. PJSM with Fox and AK E-line. R/U N2 to pump in sub. Pressure test N2 iron to 250psi/4,000psi - Test good Come online with N2 at 800SCFM and pressure up well to 1500psi. Working E-line periodically, tools came free. POOH Cement was still in the dump bailer. Secure well Lay down lubricator for the night. Pull on depth and set CIBP at 9,470'. PU, and tag plug, goodPull on depth and set CIBP at 9,470'. PU, and tag plug, good Rig Start Date End Date 9/7/23 10/19/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 10/19/2023 - Thursday Arrive at KGF, Complete Safety meeting, JSA, and sign permit. Spot equipment and rig up equipment on KBU 43-07Y, Turn on tools, and perform ops check of tools (FN/Centralizer, Weight Bar, centralizer, PLT tools - OAL 30ft w/ Max OD 2"), PU and Stab on well. Pressure test lub 250L/2500H. Good test. Open Swab and RIH. Perform Production log per Engineers procedure. Logged at 60, 90, 120 fpm between 6700- 9300'. Make station stops as per engineer request. POOH at 180fpm. Close swab and master, unstab from well, install tree cap, RDMO, sign out of field. 10/07/2023 - Saturday PJSM, PTW, Re-head, M/U tool string w/3.65" GR/junk basket. Stab lubricator, P/T same t/4000 good, RIH to top of CIBP 9470', tag w/no issues. POOH. M/U 20' of 3 1/2" bailer filled with 9.5 gal CMT, RIH t/ top of CIBP, @9470' dump cmt, POOH. Re-fill Baiiler w/ 9.5 gal CMT, RIH dump CMT @ 9457', POOH. M/U 3 38" x 18' gun RIH pull correlation pass, send to town for correlation, verify good, pull up to CCL depth of 9242.2', ccl to top shot 12.8', shots @ 9255-9273' In D1 zone, fired shot good indication gun fired, Pre-shot pressure 820psi inital 820 psi 5 mni 820 psi 10 min 820 psi 15 min 820 psi OOH all shots fired. R/D e-line, secure well, turn over to production. POOH. Re-fill Baiiler w/ 9.5 gal CMT, RIH dump CMT @ 9457', POOH. M/U 3 38" to top shot 12.8', shots @ 9255-9273' In D1 zone, fired shot good indication gun fired, 9470', tag w/no issues. POOH. M/U 20' of 3 1/2" bailer filled with 9.5 gal CMT, RIH t/ top of CIBP, @9470' dump cmt, Logged at 60, 90, 120 fpm between 6700- 9300'. Make station stops as per engineer request. POOH _____________________________________________________________________________________ Updated by CAH 11-10-23 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850 JEWELRY DETAIL No Depth Item 1 5,7745 Swell Packer 2 6,561RA Marker with 5 Pup 3 7,258RA Marker with 5 Pup 4 9,212RA Marker with 5 Pup 5 9,470CIBP w/ 25ft of cement on 10/6/23 6 9,735CIBP w/ 5ft of cement TOC @ 9,730 8/11/20 7 9,780CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4" 164BBLs of cement in 13.5 Hole. Returns to Surface 7-5/8"254BBLs of cement in 9-7/8 Hole. Returns to Surface 5 156BBLs of cement in 6-3/4 Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD)Ft Pool Date Status / Allocated Gas LB 1B 6,735'6,745'6,1816,19110'Blga/Upr Ty 8/31/2021 Open LB 1C 6,7816,7966,2286,24315Blga/Upr Ty 9/15/2020 Open LB 1E 6,8486,8686,2946,31420Blga/Upr Ty 9/15/2020 Open LB 2 6,9536,9636,3996,40910Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,4786,48810'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,5146,5228'Blga/Upr Ty 8/31/2021 Open LB 2D 7,0877,0176,5336,55320Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,5796,5889'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,6526,66412'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249' 7,269'6,695 6,71520' Blga/Upr Ty 8/21/2021 Open LB 3C 7,306' 7,319'6,752 6,76513' Blga/Upr Ty 8/19/2021 Open LB 3C 7,327' 7,336'6,773 6,7829' Blga/Upr Ty 8/19/2021 Open LB 4 7,356 7,364 6,802 6,810 8Blga/Upr Ty 8/13/2020 Open LB 4A 7,379 7,383 6,825 6,829 4Blga/Upr Ty 8/13/2020 Open LB 4B 7,406 7,413 6,852 6,859 7Blga/Upr Ty 8/13/2020 Open LB 4C 7,459 7,473 6,905 6,859 14Blga/Upr Ty 8/13/2020 Open LB 4B 7,460 7,474 6,906 6,920 14Blga/Upr Ty 8/3/2022 Open LB 4D 7,517' 7,523'6,963 6,9696' Blga/Upr Ty 8/19/2021 Open LB 5 7,534' 7,538'6,980 6,6644' Blga/Upr Ty 8/19/2021 Open LB 5A 7,578' 7,585'7,024 7,0317' Blga/Upr Ty 8/19/2021 Open LB 5B 7,620' 7,639'7,066 7,08519' Blga/Upr Ty 8/17/2021 Open LB 5C 7,643' 7,650'7,089 7,0967' Blga/Upr Ty 8/17/2021 Open LB 5C 7,652' 7,655'7,098 7,1013' Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665 7,671 7,111 7,117 6Blga/Upr Ty 8/3/2022 Open LB 6A 7,708' 7,714'7,154 7,1606' Blga/Upr Ty 8/17/2021 Open UT 2A 8,119 8,129 7,564 7,574 10Blga/Upr Ty 6/5/2020 Open UT 2B 8,138 8,148 7,584 7,594 10Blga/Upr Ty 6/5/2020 Open TY_84_6C 9,002 9,042 8,449 8,489 40Blga/Upr Ty 1/22/2021 Open D1 Coal 9,255 9,273 8,701 8,71918 Blga/Upr Ty 10/7/23 Open D2 9,477 9,490 8,923 8,936 13Tyonek 5/21/2019 Isolated (10/6/23) D3A 9,704 9,714 9,150 9,160 10Tyonek 5/6/2019 Isolated (10/6/23) D3B 9,746 9,766 9,192 9,212 20Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270'20Tyonek 5/14/2014 Isolated (3/27/2015) 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: 11/01/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231101 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 10/10/2023 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/21/2023 AK E-LINE Plug/Perf BRU 242-04 50283201640000 212041 10/13/2023 AK E-LINE Perf/PL KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/Perf MPU L-62 50029236850000 220059 10/18/2023 HALLIBURTON MFC24 PBU 06-20B 50029207990200 223075 10/19/2023 HALLIBURTON RBT PBU W-26A 50029219640100 199081 12/16/2022 AK E-LINE CBL Please include current contact information if different from above. T38113 T38113 T38114 T38115 T38116 T38117 T38118 11/1/2023 KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.01 14:36:12 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz; Roby, David S (OGC) Subject:RE: KBU 43-07Y (PTD# 214-019) Sundry# 323-465 additional perf depths Date:Thursday, September 21, 2023 2:12:00 PM Attachments:KBU 43-07Y PROPOSED 08-30-23.doc Chad, Hilcorp has approval to perform the work described below and in the attached wellbore diagram as part of sundry 323-465. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Thursday, September 21, 2023 8:04 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: KBU 43-07Y (PTD# 214-019) Sundry# 323-465 additional perf depths Bryan, We have a very similar request that you approved yesterday for KBU 11-08Z. We have a coal that we would like to perforate and test in the Kenai Gas Field well # KBU 43-07Y (PTD# 214-019), current open sundry # 323-465. We have not added any perforations yet or set the plug that are proposed in the sundry, but based on the results of 2 other wells we have tested the D1 Sands in, we want to perforate the coals before we set a plug or perf the Tyonek D1 sands in this well. We would like to add a 18ft zone of coal that are above the D1 sand package (9255-9273’). If these are successful and we do not set the plug, we will still complete a new Production log between Pools, however recent temp logs do not show that we have any production coming from the Tyonek Pool. Also attached is the updated schematic showing these perfs. Let me know if you have any questions or need additional information on this request. Thank you. Chad Helgeson Operations Engineer Kenai Asset Team 907-777-8405 - O 907-229-4824 - C The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. 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No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Updated by CAH 8-30-23 PROPOSED Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,470’ CIBP w/ 25ft of cement 6 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 7 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1B 6,735' 6,745' 6,181’ 6,191’ 10' Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’ 6,796’ 6,228’ 6,243’ 15’ Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’ 6,868’ 6,294’ 6,314’ 20’ Blga/Upr Ty 9/15/2020 Open LB 2 6,953’ 6,963’ 6,399’ 6,409’ 10’ Blga/Upr Ty 9/15/2020 Open LB 2C 7,032' 7,042' 6,478’ 6,488’ 10' Blga/Upr Ty 8/31/2021 Open LB 2C 7,068' 7,076' 6,514’ 6,522’ 8' Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’ 7,017’ 6,533’ 6,553’ 20’ Blga/Upr Ty 9/11/2020 Open LB 2E 7,133' 7,142' 6,579’ 6,588’ 9' Blga/Upr Ty 8/21/2021 Open LB 3A 7,206' 7,218' 6,652’ 6,664’ 12' Blga/Upr Ty 8/21/2021 Open LB 3B 7,249' 7,269' 6,695’ 6,715’ 20' Blga/Upr Ty 8/21/2021 Open LB 3C 7,306' 7,319' 6,752’ 6,765’ 13' Blga/Upr Ty 8/19/2021 Open LB 3C 7,327' 7,336' 6,773’ 6,782’ 9' Blga/Upr Ty 8/19/2021 Open LB 4 7,356’ 7,364’ 6,802’ 6,810’ 8’ Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’ 7,383’ 6,825’ 6,829’ 4’ Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’ 7,413’ 6,852’ 6,859’ 7’ Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’ 7,473’ 6,905’ 6,859’ 14’ Blga/Upr Ty 8/13/2020 Open LB 4B 7,460’ 7,474’ 6,906’ 6,920’ 14’ Blga/Upr Ty 8/3/2022 Open LB 4D 7,517' 7,523' 6,963’ 6,969’ 6' Blga/Upr Ty 8/19/2021 Open LB 5 7,534' 7,538' 6,980’ 6,664’ 4' Blga/Upr Ty 8/19/2021 Open LB 5A 7,578' 7,585' 7,024’ 7,031’ 7' Blga/Upr Ty 8/19/2021 Open LB 5B 7,620' 7,639' 7,066’ 7,085’ 19' Blga/Upr Ty 8/17/2021 Open LB 5C 7,643' 7,650' 7,089’ 7,096’ 7' Blga/Upr Ty 8/17/2021 Open LB 5C 7,652' 7,655' 7,098’ 7,101’ 3' Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665’ 7,671’ 7,111’ 7,117’ 6’ Blga/Upr Ty 8/3/2022 Open LB 6A 7,708' 7,714' 7,154’ 7,160’ 6' Blga/Upr Ty 8/17/2021 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ Blga/Upr Ty 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ Blga/Upr Ty 6/5/2020 Open TY_84_6C 9,002’ 9,042’ 8,449’ 8,489’ 40’ Blga/Upr Ty 1/22/2021 Open D1 Coal ±9,255’ ±9,273’ ±8,701’ ±8,719’ ±18 Blga/Upr Ty TBD Proposed D1 ±9,300’ ±9,426’ ±8,746 ±8,872’ ±126 Blga/Upr Ty TBD Proposed D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ Tyonek 5/21/2019 Isolated (TBD) D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ Tyonek 5/6/2019 Isolated (TBD) D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ Tyonek 5/14/2014 Isolated (3/27/2015) Note: Comingled production from Tyonek and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510B: 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 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,855'9,825 (RKB) Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEEA022330|FEEA028142 214-019 50-133-20625-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,140 psi 1,532' Size 135' 7-5/8"6,257' 1,577' MD See Schematic 6,890 psi 5,210 psi 135' 5,723' 135' 1,600' August 31, 2023 N/A 9,850' Perforation Depth MD (ft): 6,277' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Kenai Beluga Unit (KBU) 43-07YCO 510B Beluga/Upr Tyonek Gas 9,297'5" 3,391 9,833' 9,735; 9,780 Length Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A 9,301' 9,730' 9,176' Kenai Beluga-Up Tyonek Gas & Tyonek Gas 16" 10-3/4" See Schematic Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test No Wellbore schematic Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:56 pm, Aug 16, 2023 323-465 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.08.15 16:36:28 - 08'00' Noel Nocas (4361) DSR-8/18/23MDG 8/23/2023 10-404 BJM 8/25/23($8 08/28/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.28 15:29:43 -08'00' RBDMS JBS 082923 Well Prognosis Well: KBU 43-07Y Date: 8/15/2023 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Permit to Drill Number: 214-019 Regulatory Contact: Donna Ambruz 777-8305 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) Maximum Expected BHP: ~ 4,267 psi @ 8,762’ TVD (Based on RFT data from 2014) Max. Predicted Surface Pressure: ~ 3,391 psi (0.10 psi/ft gas gradient) Brief Well Summary: KBU 43-07Y was drilled and completed in the Tyonek D sands in 2014 by Hilcorp. It was perf’d and produced in the D3C and the D3B. In May 2019, the D3A and D2 sands were perf’d adding about 300 mcfd. In early June 2020, the Tyonek 2A and 2B were perf’d coming online with an additional 500 mcfd. In August and September 2020, several Lower Beluga sands and the Pools were commingled and added in hopes to get the rate up above 1.0 MMCFD. Additional Beluga/Upper Tyonek sands have been added in 2021 and 2022. The purpose of this work is to plug back Tyonek Gas Pool 1 sands and add the Tyonek D-1 sand, which is in the Beluga/upper Tyonek gas pool and add rate, per CO 510B. Current Status: Producing ~530mcfd with 2 bwpd at 58 psi FTP Notes Regarding Wellbore Condition x Monobore 5” completion x SL tagged fill @ 9,675’ & fluid level at 8,181ft x Current flowing BHP – 153.7 psi Pool Tops in KBU 43-07Y based on KU 41-18 reference well in CO 510B - Tyonek Gas Pool 1: 9,432’ MD; 8,879’ TVD E-Line Procedure: 1. SI well (allow to build for at least 24hrs prior to Eline) 2. MIRU N2 Unit, test flowline to 3,000 psi 3. Pressure up well with N2 to push water away 4. MIRU E-line, PT lubricator to 250 psi low and 4,000 psi high 5. RIH w/ CIBP and set at 9470’ (Collar at ~9464’) 6. RIH and dump 25ft of cement on plug (19 gal of cement) a. Tyonek Gas Pool 1 isolation plug 7. Perforate the proposed sands with 3-3/8” 6 SPF 60 deg phased perf guns. Proposed Perforated Intervals Pool Sands Top (MD) Btm (MD) Total Top (TVD) Bottom (TVD) Beluga/Upper Tyk D1 ±9,300’ ±9,426’ ±126’ ±8,746’ ±8,872’ Well Prognosis Well: KBU 43-07Y Date: 8/15/2023 a. Proposed perfs also shown on the proposed schematic in red font. b. Send the correlation pass to the Reservoir Engineer (Reid Edwards), and Geologist (Daniel Yancey) for confirmation. c. Verify PTs are open to SCADA before perforating. Record tubing pressures at 5, 10 and 15 minutes after each perforating run. d. These sands are in the Beluga/Upper Tyonek Gas Pool per CO 510B. 8. RDMO e-line 9. Turn well over to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Standard Nitrogen Procedure _____________________________________________________________________________________ Updated by CAH 8-22-23 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 TD =9,855’(MD) /9,301’(TVD) 16” 5’ of cement RKB: MSL = 18.6’ 5” 3 4 10-3/4”44 7-5/8” 1 2 TY D3C LB 1B-1E PBTD =BB 9,730’(M00D) /9,176’(TVD)66 TY D3B 6 Tag spent perf guns/wire @ 9,825’ RKB on 3/18/2015 5 5TT LB 2C-2E LB 3A-3B LB 3C LB 4-4D LB 5-5C LB 6A UT 2A-2B TY 84-6C TY D2 TY D3A CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 /BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 /DWC/C-HT4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement –TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open / 3.3% LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open /35.2% LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 *Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 *Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 *Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open / 0.4% LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open / 14.5% LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open / 3.3% LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 *Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open / 7.7% LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 *Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open / 2.1 % LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open / 7.9% LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 *Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open / 0.3% LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open / 0.9% LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open / 0.3% LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open / 2.1% LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 *Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 *Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open / 2% LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open / 6.4% LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 *Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty 8/3/2022 *Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open / 7.2% UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 *Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open / 2.4% TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open / 4.1% D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 *Open D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 *Open D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated (3/27/2015) *no established flow rate from latest production log (9/7/22) Note: Comingled production from Tyonek and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510B: _____________________________________________________________________________________ Updated by DMA 08-05-23 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 TD =9,855’(MD) /9,301’(TVD) 16” 5’ of cement RKB: MSL = 18.6’ 5” 3 4 10-3/4”44 7-5/8” 1 2 TY D3C LB 1B-1E PBTD =BB 9,730’(M00D) /9,176’(TVD)66 TY D3B 6 Tag spent perf guns/wire @ 9,825’ RKB on 3/18/2015 5 5TT LB 2C-2E LB 3A-3B LB 3C LB 4-4D LB 5-5C LB 6A UT 2A-2B TY 84-6C TY D2 TY D3A CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 /BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 /DWC/C-HT4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement –TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open / 3.3% LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open /35.2% LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 *Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 *Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 *Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open / 0.4% LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open / 14.5% LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open / 3.3% LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 *Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open / 7.7% LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 *Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open / 2.1 % LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open / 7.9% LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 *Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open / 0.3% LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open / 0.9% LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open / 0.3% LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open / 2.1% LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 *Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 *Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open / 2% LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open / 6.4% LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 *Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty Proposed *Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open / 7.2% UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 *Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open / 2.4% TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open / 4.1% D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 *Open D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 *Open D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated (3/27/2015) *no established flow rate from latest production log (9/7/22) Note: Comingled production from Tyonek and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510B: SUPERSEDED _____________________________________________________________________________________ Updated by CAH 8-22-23 PROPOSED Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 TD =9,855’(MD) /9,301’(TVD) 16” 5’ of cement RKB: MSL = 18.6’ 5” 3 4 10-3/4”44 7-5/8” 1 2 TY D3C LB 1B-1E PBTD =9,730’(MD) /9,176’(TVD) TY D3B 6 Tag spent perf guns/wire @ 9,825’ RKB on 3/18/2015 5 5 LB 2C-2E LB 3A-3B LB 3C LB 4-4D LB 5-5C LB 6A UT 2A-2B TY 84-6C TY D2 55 TY D3A 7 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 /BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 /DWC/C-HT4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,470’CIBP w/ 25ft of cement 6 9,735’ CIBP w/ 5ft of cement –TOC @ 9,730’ 8/11/20 7 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open LB 4B 7,460’7,474’6,906’6,920’14’Blga/Upr Ty 8/3/2022 Open LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 5C Lwr 7,665’7,671’7,111’7,117’6’Blga/Upr Ty 8/3/2022 Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open D1 ±9,300’±9,426’±8,746 ±8,872’±142 Blga/Upr Ty TMD Proposed D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 Isolated (TBD) D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 Isolated (TBD) D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated (3/27/2015) Note: Comingled production from Tyonek and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510B: _____________________________________________________________________________________ Updated by CAH 8-15-22 PROPOSED Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 TD =9,855’(MD) /9,301’(TVD) 16” 5’ of cement RKB: MSL = 18.6’ 5” 3 4 10-3/4”44 7-5/8” 1 2 TY D3C LB 1B-1E PBTD =9,730’(MD) /9,176’(TVD) TY D3B 6 Tag spent perf guns/wire @ 9,825’ RKB on 3/18/2015 5 5 LB 2C-2E LB 3A-3B LB 3C LB 4-4D LB 5-5C LB 6A UT 2A-2B TY 84-6C TY D2 55 TY D3A 7 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 /BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 /DWC/C-HT4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,470’CIBP w/ 25ft of cement 6 9,735’ CIBP w/ 5ft of cement –TOC @ 9,730’ 8/11/20 7 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 Open LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open LB 4 7,356’7,364’6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open LB 4A 7,379’7,383’6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open LB 4B 7,406’7,413’6,852’6,859’7’Blga/Upr Ty 8/13/2020 Open LB 4C 7,459’7,473’6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open LB 4B ±7,460’±7,474’±6,906’±6,920’14’Blga/Upr Ty 8/3/2022 Open LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 5C Lwr ±7,665’±7,671’±7,111’±7,117’6’Blga/Upr Ty Proposed Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open D1 ±9,300’±9,426’±8,746 ±8,872’±142 Blga/Upr Ty TMD Proposed D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 Isolated (TBD) D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 Isolated (TBD) D3B 9,746’9,766’9,192’9,212’20’Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804'9,824'9,250'9,270'20’Tyonek 5/14/2014 Isolated (3/27/2015) Note: Comingled production from Tyonek and Beluga/Upper Tyonek pools. Requires a production log each calendar year, and not more than 13 months between logs per CO 510B: SUPERSEDED 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. Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221123 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PAXTON 6 50133207070000 222054 8/1/2022 Yellowjacket PERF BCU-7A 50133202840100 214060 8/2/2022 Yellowjacket GPT-PERF KBU 43-07Y 50133206250000 214019 8/3/2022 Yellowjacket PERF KBU 22-06Y 50133206500000 215044 8/4/2022 Yellowjacket GPT-PERF SRU 32A-33 50133101640100 191014 8/21/2022 Yellowjacket GPT-PERF HVB 16A 50231200400100 222070 8/23/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/26/2022 Yellowjacket PERF HVB-16A 50231200400100 222070 8/27/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/29/2022 Yellowjacket PERF KALOTSA 4 50133206650000 217063 9/1/2022 Yellowjacket GPT-PERF KALOTSA 4 50133206650000 217063 9/6/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. By Meredith Guhl at 9:26 am, Nov 29, 2022 T37305 T37306 T37306 T37307 T37307 T37308 T37309 T37310 T37311 T37311 T37312 KBU 43-07Y 50133206250000 214019 8/3/2022 Yellowjacket PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 09:43:24 -09'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. T37103 T37104 T37105 T37106 T37107 T37108 T37109 T37110 T37111 T37112 T37113 T37114 T37115 T37116 T37117 T37118 T37119 T37120 KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.05 11:39:32 -08'00' From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz Subject:RE: [EXTERNAL] RE: KGF well KBU 43-07Y Sundry Date:Wednesday, August 3, 2022 11:11:00 AM Chad, You have verbal approval to perforate well KBU 43-07y (PTD 214-019) per the Sundry submitted to AOGCC on July 26, 2022. FYI, this has been assigned sundry # 322-441. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday, August 3, 2022 9:11 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: KGF well KBU 43-07Y Sundry We didn’t see the approval yesterday. Can I get a verbal today for perforating 2 zones on KBU 43- 07Y? Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, August 2, 2022 10:29 AM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] RE: KGF well KBU 43-07Y Sundry Yes, you should have it soon. You can schedule the work and I’ll give you a verbal if you don’t have the signed copy by the time you rig up. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, August 2, 2022 10:01 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: KGF well KBU 43-07Y Sundry Bryan, I am scheduling my work this week and wondering if I should expect to see the approved sundry for KBU 43-07Y. I checked with the team and we don’t have any other urgent sundries that I know about, I think you are caught up and have us questions or getting details on other projects we are looking to execute. Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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ϭϬͲϯͬϰΖ^ƵƌĨĂĐĞϰϱ͘ϱͬ>ͲϴϬͬdϵ͘ϵϱϬ^ƵƌĨϭ͕ϲϬϬΖ ϳͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞϮϵ͘ϳͬ>ͲϴϬͬdDŽĚϲ͘ϴϳϱ^ƵƌĨϲ͕ϮϳϳΖ ϱΗWƌŽĚƵĐƚŝŽŶϭϴͬ>ͲϴϬͬtͬͲ,dϰ͘Ϯϳϲ^ƵƌĨϵ͕ϴϱϬ͛ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭϱ͕ϳϳϰ͛ϱ͟^ǁĞůůWĂĐŬĞƌ Ϯϲ͕ϱϲϭ͛ZDĂƌŬĞƌǁŝƚŚϱ͛WƵƉ ϯϳ͕Ϯϱϴ͛ZDĂƌŬĞƌǁŝƚŚϱ͛WƵƉ ϰϵ͕ϮϭϮ͛ZDĂƌŬĞƌǁŝƚŚϱ͛WƵƉ ϱϵ͕ϳϯϱ͛/WǁͬϱĨƚŽĨĐĞŵĞŶƚʹdKΛϵ͕ϳϯϬ͛ϴͬϭϭͬϮϬ ϲϵ͕ϳϴϬ͛/WǁͬϱĨƚŽĨĐĞŵĞŶƚ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟Ηϭϲϰ>͛ƐŽĨĐĞŵĞŶƚŝŶϭϯ͘ϱ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϳͲϱͬϴΗϮϱϰ>͛ƐŽĨĐĞŵĞŶƚŝŶϵͲϳͬϴ͟,ŽůĞ͘ZĞƚƵƌŶƐƚŽ^ƵƌĨĂĐĞ ϱ͟ϭϱϲ>͛ƐŽĨĐĞŵĞŶƚŝŶϲͲϯͬϰ͟,ŽůĞ͘dKϱ͕ϳϬϬĂůĐƵůĂƚĞĚ WZ&KZd/KEd/> ^ĂŶĚdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ&ƚWŽŽů ĂƚĞ ^ƚĂƚƵƐͬůůŽĐĂƚĞĚ'ĂƐ >ϭϲ͕ϳϯϱΖϲ͕ϳϰϱΖϲ͕ϭϴϭ͛ϲ͕ϭϵϭ͛ϭϬΖůŐĂͬhƉƌdǇϴͬϯϭͬϮϬϮϭKƉĞŶ >ϭϲ͕ϳϴϭ͛ϲ͕ϳϵϲ͛ϲ͕ϮϮϴ͛ϲ͕Ϯϰϯ͛ϭϱ͛ůŐĂͬhƉƌdǇϵͬϭϱͬϮϬϮϬKƉĞŶͬϲϬ͘ϰй >ϭϲ͕ϴϰϴ͛ϲ͕ϴϲϴ͛ϲ͕Ϯϵϰ͛ϲ͕ϯϭϰ͛ϮϬ͛ůŐĂͬhƉƌdǇϵͬϭϱͬϮϬϮϬΎKƉĞŶ >Ϯϲ͕ϵϱϯ͛ϲ͕ϵϲϯ͛ϲ͕ϯϵϵ͛ϲ͕ϰϬϵ͛ϭϬ͛ůŐĂͬhƉƌdǇϵͬϭϱͬϮϬϮϬΎKƉĞŶ >Ϯϳ͕ϬϯϮΖϳ͕ϬϰϮΖϲ͕ϰϳϴ͛ϲ͕ϰϴϴ͛ϭϬΖůŐĂͬhƉƌdǇϴͬϯϭͬϮϬϮϭKƉĞŶ >Ϯϳ͕ϬϲϴΖϳ͕ϬϳϲΖϲ͕ϱϭϰ͛ϲ͕ϱϮϮ͛ϴΖůŐĂͬhƉƌdǇϴͬϯϭͬϮϬϮϭKƉĞŶ >Ϯϳ͕Ϭϴϳ͛ϳ͕Ϭϭϳ͛ϲ͕ϱϯϯ͛ϲ͕ϱϱϯ͛ϮϬ͛ůŐĂͬhƉƌdǇϵͬϭϭͬϮϬϮϬKƉĞŶͬϭϭ͘ϳй >Ϯϳ͕ϭϯϯΖϳ͕ϭϰϮΖϲ͕ϱϳϵ͛ϲ͕ϱϴϴ͛ϵΖůŐĂͬhƉƌdǇϴͬϮϭͬϮϬϮϭKƉĞŶ >ϯϳ͕ϮϬϲΖϳ͕ϮϭϴΖϲ͕ϲϱϮ͛ϲ͕ϲϲϰ͛ϭϮΖůŐĂͬhƉƌdǇϴͬϮϭͬϮϬϮϭKƉĞŶ >ϯϳ͕ϮϰϵΖϳ͕ϮϲϵΖϲ͕ϲϵϱ͛ϲ͕ϳϭϱ͛ϮϬΖůŐĂͬhƉƌdǇϴͬϮϭͬϮϬϮϭKƉĞŶ >ϯϳ͕ϯϬϲΖϳ͕ϯϭϵΖϲ͕ϳϱϮ͛ϲ͕ϳϲϱ͛ϭϯΖůŐĂͬhƉƌdǇϴͬϭϵͬϮϬϮϭKƉĞŶ >ϯϳ͕ϯϮϳΖϳ͕ϯϯϲΖϲ͕ϳϳϯ͛ϲ͕ϳϴϮ͛ϵΖůŐĂͬhƉƌdǇϴͬϭϵͬϮϬϮϭKƉĞŶ >ϰϳ͕ϯϱϲ͛ϳ͕ϯϲϰ͛ϲ͕ϴϬϮ͛ϲ͕ϴϭϬ͛ϴ͛ůŐĂͬhƉƌdǇϴͬϭϯͬϮϬϮϬKƉĞŶͬϳ͘ϴй >ϰϳ͕ϯϳϵ͛ϳ͕ϯϴϯ͛ϲ͕ϴϮϱ͛ϲ͕ϴϮϵ͛ϰ͛ůŐĂͬhƉƌdǇϴͬϭϯͬϮϬϮϬKƉĞŶͬϭ͘ϭй >ϰϳ͕ϰϬϲ͛ϳ͕ϰϭϯ͛ϲ͕ϴϱϮ͛ϲ͕ϴϱϵ͛ϳ͛ůŐĂͬhƉƌdǇϴͬϭϯͬϮϬϮϬΎKƉĞŶ >ϰϳ͕ϰϱϵ͛ϳ͕ϰϳϯ͛ϲ͕ϵϬϱ͛ϲ͕ϴϱϵ͛ϭϰ͛ůŐĂͬhƉƌdǇϴͬϭϯͬϮϬϮϬKƉĞŶͬϭ͘ϱй >ϰϳ͕ϱϭϳΖϳ͕ϱϮϯΖϲ͕ϵϲϯ͛ϲ͕ϵϲϵ͛ϲΖůŐĂͬhƉƌdǇϴͬϭϵͬϮϬϮϭKƉĞŶ >ϱϳ͕ϱϯϰΖϳ͕ϱϯϴΖϲ͕ϵϴϬ͛ϲ͕ϲϲϰ͛ϰΖůŐĂͬhƉƌdǇϴͬϭϵͬϮϬϮϭKƉĞŶ >ϱϳ͕ϱϳϴΖϳ͕ϱϴϱΖϳ͕ϬϮϰ͛ϳ͕Ϭϯϭ͛ϳΖůŐĂͬhƉƌdǇϴͬϭϵͬϮϬϮϭKƉĞŶ >ϱϳ͕ϲϮϬΖϳ͕ϲϯϵΖϳ͕Ϭϲϲ͛ϳ͕Ϭϴϱ͛ϭϵΖůŐĂͬhƉƌdǇϴͬϭϳͬϮϬϮϭKƉĞŶ >ϱϳ͕ϲϰϯΖϳ͕ϲϱϬΖϳ͕Ϭϴϵ͛ϳ͕Ϭϵϲ͛ϳΖůŐĂͬhƉƌdǇϴͬϭϳͬϮϬϮϭKƉĞŶ >ϱϳ͕ϲϱϮΖϳ͕ϲϱϱΖϳ͕Ϭϵϴ͛ϳ͕ϭϬϭ͛ϯΖůŐĂͬhƉƌdǇϴͬϭϳͬϮϬϮϭKƉĞŶ >ϲϳ͕ϳϬϴΖϳ͕ϳϭϰΖϳ͕ϭϱϰ͛ϳ͕ϭϲϬ͛ϲΖůŐĂͬhƉƌdǇϴͬϭϳͬϮϬϮϭKƉĞŶ hdϮϴ͕ϭϭϵ͛ϴ͕ϭϮϵ͛ϳ͕ϱϲϰ͛ϳ͕ϱϳϰ͛ϭϬ͛ůŐĂͬhƉƌdǇϲͬϱͬϮϬϮϬKƉĞŶͬϭϲ͘ϵй hdϮϴ͕ϭϯϴ͛ϴ͕ϭϰϴ͛ϳ͕ϱϴϰ͛ϳ͕ϱϵϰ͛ϭϬ͛ůŐĂͬhƉƌdǇϲͬϱͬϮϬϮϬKƉĞŶͬϬ͘Ϯй dzͺϴϰͺϲϵ͕ϬϬϮ͛ϵ͕ϬϰϮ͛ϴ͕ϰϰϵ͛ϴ͕ϰϴϵ͛ϰϬ͛ůŐĂͬhƉƌdǇϭͬϮϮͬϮϬϮϭKƉĞŶͬϬ͘ϰй 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KƉĞŶͬϭϲ͘ϵй hdϮ ϴ͕ϭϯϴ͛ ϴ͕ϭϰϴ͛ ϳ͕ϱϴϰ͛ ϳ͕ϱϵϰ͛ ϭϬ͛ ůŐĂͬhƉƌdǇ ϲͬϱͬϮϬϮϬ KƉĞŶͬϬ͘Ϯй dzͺϴϰͺϲ ϵ͕ϬϬϮ͛ ϵ͕ϬϰϮ͛ ϴ͕ϰϰϵ͛ ϴ͕ϰϴϵ͛ ϰϬ͛ ůŐĂͬhƉƌdǇ ϭͬϮϮͬϮϬϮϭ KƉĞŶͬϬ͘ϰй Ϯ ϵ͕ϰϳϳ͛ ϵ͕ϰϵϬ͛ ϴ͕ϵϮϯ͛ ϴ͕ϵϯϲ͛ ϭϯ͛ dǇŽŶĞŬ ϱͬϮϭͬϮϬϭϵ ΎKƉĞŶ ϯ ϵ͕ϳϬϰ͛ ϵ͕ϳϭϰ͛ ϵ͕ϭϱϬ͛ ϵ͕ϭϲϬ͛ ϭϬ͛ dǇŽŶĞŬ ϱͬϲͬϮϬϭϵ ΎKƉĞŶ ϯ ϵ͕ϳϰϲ͛ ϵ͕ϳϲϲ͛ ϵ͕ϭϵϮ͛ ϵ͕ϮϭϮ͛ ϮϬ͛ dǇŽŶĞŬ ϳͬϭϱͬϮϬϭϰ /ƐŽůĂƚĞĚ;ϴͬϭϮͬϮϬϮϬͿ ϯ ϵ͕ϴϬϰΖ ϵ͕ϴϮϰΖ ϵ͕ϮϱϬΖ ϵ͕ϮϳϬΖ ϮϬ͛ dǇŽŶĞŬ ϱͬϭϰͬϮϬϭϰ /ƐŽůĂƚĞĚ;ϯͬϮϳͬϮϬϭϱͿ QRHVWDEOLVKHGIORZUDWHIURPODWHVWSURGXFWLRQORJ-XO\ 1RWH&RPLQJOHGSURGXFWLRQIURP7\RQHNDQG%HOXJD8SSHU7\RQHNSRROV5HTXLUHVDSURGXFWLRQORJ HDFKFDOHQGDU\HDUDQGQRWPRUHWKDQPRQWKVEHWZHHQORJVSHU&2%/DVWUDQ 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: 10/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 43-7Y (PTD 214-019) Perf 08/31/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/19/2021 By Abby Bell at 12:51 pm, Oct 19, 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: 10/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 43-7Y (PTD 214-019) Perforation Record 08/21/2021 Please include current contact information if different from above. Received By: 10/11/2021 37' (6HW By Abby Bell at 1:14 pm, Oct 11, 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: 10/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 43-07Y (PTD 214-019) Perforation Record 08/19/2021 Please include current contact information if different from above. Received By: 10/11/2021 37' (6HW By Abby Bell at 1:15 pm, Oct 11, 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: 10/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 43-7Y (PTD 214-019) Perforation Record 08/17/2021 Please include current contact information if different from above. Received By: 10/11/2021 37' (6HW By Abby Bell at 1:16 pm, Oct 11, 2021 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 9,855 feet 9,735; 9,780 feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,730 feet 5,774 feet true vertical 9,176 feet 5,221 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker 5" Swell Pkr; N/A 5,774' MD 5,221' TVD N/A; 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: Taylor Wellman 777-8449 Contact Name:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 WINJ WAG 650 Water-Bbl MD 135' 1,600' 19 Oil-Bbl measured true vertical Packer 5"9,850' 5,723' 9,297' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai / Beluga / Upper Tyonek Gas - Tyonek GasN/A measured TVD Tubing Pressure 8117 Kenai Beluga Unit (KBU) 43-07Y N/A FEE A022330 / FEE A028142 6,277' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-393 74 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 117 Authorized Signature with date: Authorized Name: 114 Casing Pressure Liner 800 0 Representative Daily Average Production or Injection Data 135' 1,577' 6,257' 9,833' Conductor Surface Intermediate Production 10,500psi Casing Structural 16" 10-3/4" 7-5/8" Length 6,890psi 5,210psi Collapse 2,470psi 4,790psi jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,140psi 135' 1,532' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 2:19 pm, Sep 10, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.10 14:04:05 -08'00' Taylor Wellman (2143) BJM 11/2/21 RBDMS HEW 9/10/2021 DSR-9/13/21 SFD 9/20/2021 Rig Start Date End Date 8/17/21 8/31/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 08/17/2021 - Tuesday Meet on location. Spot Equip. PTW and JSA. Rig up equipment and lubricator. PT to 250 psi low and 2,500 psi high. Check Sundry to confirm depth and gun size. RIH w/#1 gas gun, 2-7/8" x 21' carrier loaded with 6' of charges at bottom of carrier and tie into Schl PNL log. Run correlation log and send to town. Get ok to perforate from 7,708' to 7,714'. Spot and fire #1 gun w/73.2 FTP/511.5K. After 5 min - 73.2/557.9K, 10 min - 71.8/537.9K and 15 min - 73.5/604.2K. Pull up in lubricator and couldn't get swab to hold. Call and got grease coming this way. Greased swab valve and finally, had to close middle master for 15 min to get shot gun out of lub off and new gun on well. RIH w/#2 gas gun, 2-7/8" x 7' carrier loaded with 3' of charges at bottom of carrier and tie into Perf correlation log (Gun #1). Run correlation log and send to town. Told to add 1' to shift down. Added 1' and spotted gun from 7,652' to 7,655'. Fired gun with 72.1 FTP/559.1MCFD. After 5 min - 72.9/566.9 MCFD, 10 min - 75.1/602.4 MCFD and 15 min - 74.0/564.8 MCFD. POOH. All shots fired/Gun wet. RIH w/#3 gas gun, 2-7/8" x 21'' carrier loaded with 7' of charges at bottom of carrier and tie into Perf correlation log (Gun #1). Run correlation log and send to town. Get ok to perf from 7,643' to 7,650'. Spot and fired gun with 75psi/549mcfd. After 5 min - 76 FTP/586 mcfd, 10 min - 81 FTP/704 mcfd and 15 min - 77FTP/768 mcfd. POOH. All shots fired/gun wet. RIH w/#4 gas gun, 2-7/8" x 21'' carrier loaded with 19' of charges at bottom of carrier and tie into Perf correlation log (Gun #1). Run correlation log and send to town. Get ok to perf from 7,620' to 7,639' with 75 FTP/592K. Spot and fire gun. After 5 min - 78FTP/583K rate, 10 min - 81FTP/676K rate and 15 min - 82FTP/663 rate. 3.2 bbls water since first shot. POOH/all shots fired/gun wet. Rig down lubricator off well. Turn well over to field and rig down rest of equipment. Daily Operations: spotted gun from 7,652' to 7,655'. Fired gun w o perf from 7,643' to 7,650'. Spot and fired gun w Get ok to perforate from 7,708' to 7,714'. Spot and fire #1 gun w perf from 7,620' to 7,639' with 75 FTP/592K. Spot and fire gun. Rig Start Date End Date 8/17/21 8/31/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 Daily Operations: 08/21/2021 - Saturday Spot equip. PTW and JSA. Rig up lubricator. PT to 250 psi low and 2,500 psi high. FTP/Rate. RIH w/ Gun #1, 2-7/8" x 20' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 7,249' to 7,269' w/FTP - 73.6/728.7K rate. Spot and fire gun. After 5 min - 77.2/801.8K, 10 min - 72.3/746.8K and 15 min - 76.6/772.7K. POOH LB3B sand. RIH w/ Gun #2, 2-7/8" x 12' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Told to subtract 1'. Subtract 1', spot and fire gun from 7,206' to 7,218' with 77/807K. After 5 min - 78/840K, 10 min - 75/763K and 15 min - 81/879K. POOH. All shots fired and gun wet. LB3A sand. RIH w/ Gun #3, 2-7/8" x 9' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 7,133' to 7,142' w/77 psi/805K rate, spotted and fired gun. After 5 min - 80/847K, 10 min - 74/801K and 15 min - 80/844K. POOH. All shots fired/Gun Wet. LB2E sand. Rig down lubricator and equip and turn well over to field. 08/19/2021 - Thursday Spot equip. PTW and JSA. Rig up equipment. PT to 250 psi low and 2,500 psi high. FTP - 74.6/663 mcfd. RIH w/Gun #1, 2- 7/8" x 21' carrier (Bottom 7' loaded w/gas charges ), 6 spf, 60 deg phase perf gun and tie into Perf log. Run correlation log and send to town. Get ok to perforate from 7,578' to 7,585'. Spotted and fired gun #1 with FTP 75.5/625.1K Rate. After 5 min - 79.1/669.9K rate, 10 min- 79.8/731.7K rate and 15 min - 76.8/701.4K. POOH . All shots fired/Gun wet. LB5A sand. RIH w/Gun #2, 2-7/8" x 7' carrier (Bottom 4' loaded w/gas charges ), 6 spf, 60 deg phase perf gun and tie into Perf log. Run correlation log and send to town., Told to add 1'. Added 1' to correlation log and spotted gun from 7,534' to 7,538'. Fired gun w/FTP 78.2 and rate at 649.9K. After 5 min - 79.9/750.3K, 10 min - 76.3/688.5K and 15 min - 79.7/717.2K. POOH. All shots fired/Gun wet. LB5 sand. RIH w/Gun #3, 2-7/8" x 21' carrier (Bottom 6' loaded w/gas charges ), 6 spf, 60 deg phase perf gun and tie into Perf log. Run correlation log and send to town. Told to add 1'. Added 1' and spotted gun from 7,517' to 7,523'. Fired gun w/FTP 77.5/689.2K rate. After 5 min - 80.3/743.2K, 10 min - 78.5/755.7K and 15 min - 80.6/725.3K rate. POOH. All shots fired/gun was wet. LB4D sand. RIH w/Gun #4, 2-7/8"x21' carrier (Bottom 9' loaded w/gas charges ), 6 spf, 60 deg phase perf gun and tie into Perf log. Run correlation log and send to town. Told to add 2'. Added 2' and spotted and fired gun from 7,327' to7,336' with 79.6/759.6K rate. After 5 min - 80.5/753.4K, 10 min - 79.4/752.2K and 15 min - 83.1/761.6K. POOH. All shots fired/Gun wet. LB3C sand (Next sand is also a LB3C sand). RIH w/Gun #5, 2-7/8" x 21' carrier (Bottom 13' loaded w/gas charges ), 6 spf, 60 deg phase perf gun and tie into Perf log. Run correlation log and send to town. Get ok to perf from 7,306' to 7,319' with 79.3/742.9K. After 5 min - 81/775.9K, 10 min - 78/769.9K and 15 min - 77.4/679.4. POOH. All shots fired and gun wet. LB3C sand. Rig down off well, turn well back to field and finish rig down. spotted gun from 7,534' to 7,538'. Fired gun w fired gun from 7,327' to7,336' o perf from 7,133' to 7,142' perf from 7,306' to 7,319' fire gun from 7,206' to 7,218' w perf from 7,249' to 7,269' w/FTP - 73.6/728.7K rate. Spot and fire gun o perforate from 7,578' to 7,585'. Spotted and fired gun #1 with gun from 7,517' to 7,523'. Fired gun w Rig Start Date End Date 8/17/21 8/31/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 Daily Operations: 08/31/2021 - Tuesday Mobe to location. Spot equipment. Rig up lubricator. PT to 250 psi low and 2,500 psi high. FTP -77.6 psi/833K Rate. NOTE: ALL GUNS SHOT WITH WELL FLOWING!!!. RIH w/ Gun #1, 2-7/8" x 8' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Told to add 2'. Added 2' and spotted gun from 7,068' to 7,076'. Fired gun w/76.4 psi FTP/791.7mcf. After 5 min - 76.9/796.0mcf, 10 min - 74.1/692mcf and 15 min - 78.3/789.4mcf. POOH. All shots fired/Gun wet. RIH w/ Gun #2 , 2-7/8" x 10' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Told to subtract 3'. Subtract 3' and spotted gun from 7,032' to 7,042'. Fired gun with 78.5 psi/818.3mcf. After 5 min - 79.4/833.3mcf, 10 min - 76.2/787.2mcf and 15 min - 75.8/735.0mcf. POOH. All shots fired/Gun wet. RIH w/ Gun #3 , 2-7/8" x 10' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Told to add 1'. Add 1' and spot gun from 6,735' to 6,745'. Fired gun w/79.4FTP/821.6 mcf. After 5 min - 81.9/880.8mcf, 10 min - 80.6/867.6mcf and 15 min 77.2/815.9mcf. POOH. All shots fired/Gun Wet. Rig down off well. Rig down equipment and turn well over to field. spot gun from 6,735' to 6,745'. Fired gun w spotted gun from 7,068' to 7,076'. Fired gun w spotted gun from 7,032' to 7,042'. Fired gun w _____________________________________________________________________________________ Updated by DMA 09-02-21 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1B 6,735' 6,745' 6,181’ 6,191’ 10' Blga/Upr Ty 8/31/2021 Open LB 1C 6,781’ 6,796’ 6,228’ 6,243’ 15’ Blga/Upr Ty 9/15/2020 Open / 60.4% LB 1E 6,848’ 6,868’ 6,294’ 6,314’ 20’ Blga/Upr Ty 9/15/2020 *Open LB 2 6,953’ 6,963’ 6,399’ 6,409’ 10’ Blga/Upr Ty 9/15/2020 *Open LB 2C 7,032' 7,042' 6,478’ 6,488’ 10' Blga/Upr Ty 8/31/2021 Open LB 2C 7,068' 7,076' 6,514’ 6,522’ 8' Blga/Upr Ty 8/31/2021 Open LB 2D 7,087’ 7,017’ 6,533’ 6,553’ 20’ Blga/Upr Ty 9/11/2020 Open / 11.7% LB 2E 7,133' 7,142' 6,579’ 6,588’ 9' Blga/Upr Ty 8/21/2021 Open LB 3A 7,206' 7,218' 6,652’ 6,664’ 12' Blga/Upr Ty 8/21/2021 Open LB 3B 7,249' 7,269' 6,695’ 6,715’ 20' Blga/Upr Ty 8/21/2021 Open LB 3C 7,306' 7,319' 6,752’ 6,765’ 13' Blga/Upr Ty 8/19/2021 Open LB 3C 7,327' 7,336' 6,773’ 6,782’ 9' Blga/Upr Ty 8/19/2021 Open LB 4 7,356’ 7,364’ 6,802’ 6,810’ 8’ Blga/Upr Ty 8/13/2020 Open / 7.8% LB 4A 7,379’ 7,383’ 6,825’ 6,829’ 4’ Blga/Upr Ty 8/13/2020 Open / 1.1% LB 4B 7,406’ 7,413’ 6,852’ 6,859’ 7’ Blga/Upr Ty 8/13/2020 *Open LB 4C 7,459’ 7,473’ 6,905’ 6,859’ 14’ Blga/Upr Ty 8/13/2020 Open / 1.5% LB 4D 7,517' 7,523' 6,963’ 6,969’ 6' Blga/Upr Ty 8/19/2021 Open LB 5 7,534' 7,538' 6,980’ 6,664’ 4' Blga/Upr Ty 8/19/2021 Open LB 5A 7,578' 7,585' 7,024’ 7,031’ 7' Blga/Upr Ty 8/19/2021 Open LB 5B 7,620' 7,639' 7,066’ 7,085’ 19' Blga/Upr Ty 8/17/2021 Open LB 5C 7,643' 7,650' 7,089’ 7,096’ 7' Blga/Upr Ty 8/17/2021 Open LB 5C 7,652' 7,655' 7,098’ 7,101’ 3' Blga/Upr Ty 8/17/2021 Open LB 6A 7,708' 7,714' 7,154’ 7,160’ 6' Blga/Upr Ty 8/17/2021 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ Blga/Upr Ty 6/5/2020 Open / 16.9% UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ Blga/Upr Ty 6/5/2020 Open / 0.2% TY_84_6C 9,002’ 9,042’ 8,449’ 8,489’ 40’ Blga/Upr Ty 1/22/2021 Open / 0.4% D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ Tyonek 5/21/2019 *Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ Tyonek 5/6/2019 *Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ Tyonek 5/14/2014 Isolated (3/27/2015) *no established flow rate from latest production log (18July2021) Note: Comingled production from Tyonek 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: 7/4/20 LB 2C 7,032'7,042'6,478’6,488’10'Blga/Upr Ty 8/31/2021 Open LB 2C 7,068'7,076'6,514’6,522’8'Blga/Upr Ty 8/31/2021 Open ,,,,g/p y //p LB 2E 7,133'7,142'6,579’6,588’9'Blga/Upr Ty 8/21/2021 Open LB 3A 7,206'7,218'6,652’6,664’12'Blga/Upr Ty 8/21/2021 Open LB 3B 7,249'7,269'6,695’6,715’20'Blga/Upr Ty 8/21/2021 Open LB 3C 7,306'7,319'6,752’6,765’13'Blga/Upr Ty 8/19/2021 Open LB 3C 7,327'7,336'6,773’6,782’9'Blga/Upr Ty 8/19/2021 Open ,,,,g/p y //p LB 4D 7,517'7,523'6,963’6,969’6'Blga/Upr Ty 8/19/2021 Open LB 5 7,534'7,538'6,980’6,664’4'Blga/Upr Ty 8/19/2021 Open LB 5A 7,578'7,585'7,024’7,031’7'Blga/Upr Ty 8/19/2021 Open LB 5B 7,620'7,639'7,066’7,085’19'Blga/Upr Ty 8/17/2021 Open LB 5C 7,643'7,650'7,089’7,096’7'Blga/Upr Ty 8/17/2021 Open LB 5C 7,652'7,655'7,098’7,101’3'Blga/Upr Ty 8/17/2021 Open LB 6A 7,708'7,714'7,154’7,160’6'Blga/Upr Ty 8/17/2021 Open ()()()() LB 1B 6,735'6,745'6,181’6,191’10'Blga/Upr Ty 8/31/2021 Open (MD) (MD)(TVD) (TVD) 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/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,855'Tru Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 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 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: 8/27/2021 N/A 9,850' Perforation Depth MD (ft): 6,277' See Attached Schematic 9,833' 9,297'5" 16" 10-3/4" 135' 7-5/8"6,257' 1,577'5,210 psi 135' 1,532' 5,723' 135' 1,600' N/A TVD Burst N/A 10,140 psi MD 6,890 psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A022330 / FEE A028142 214-019 50-133-20625-00-00 Kenai Beluga Unit (KBU) 43-07Y Kenai / Beluga / Upper Tyonek Gas - Tyonek Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 9,301'9,730'9,176'582 N/A Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:11 am, Aug 10, 2021 321-393 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.09 15:18:06 -08'00' Taylor Wellman (2143) DSR-8/10/21DLB 08/10/2021 X 10-404 BJM 8/11/21 dts 7/11/2021 JLC 8/12/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.12 13:26:47 -08'00' RBDMS HEW 8/13/2021 Well Prognosis Well: KBU 43-07Y Date: 8/9/2021 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 8/27/2021 Rig: E-line Reg. Approval Req’d: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-019 First Call Engineer: Jake Flora (907) 777-8442 (O) (720)-988-5375 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) AFE Number Estimated Current BHP: ~800 psi at 6,228’ TVD (Calc.from Current Well conditions ) Max Expected BHP: ~1200 psi at 6184’ TVD (From RFT Data during Drilling) Max. Potential Surface Pressure: ~582 psi (based on 0.1 psi/ft. gas gradient to surface) Current Status: Producing 550 mcfd with 0 water with 72 psi FTP Brief Well Summary: A grassroots well drilled and completed in the Tyonek D in 2014 by Hilcorp. It was perf’d and produced in the D3C (sucker sand) and the D3B. In May 2019, the D3A and D2 sands were perf’d adding about 300 mcfd. In early June 2020, the Upper Tyonek 2A and 2B were perf’d coming online with an additional 500 mcfd. In August and September, several Lower Beluga sands were added in hopes to get the rate up above 1.0 MMCFD. The rate jumped from 400 MCFD to just under 1.0 MMCFD and has declined off since then. Another attempt to add rate was in January 2021 by perfing the Upper Tyonek 84_6C sand. No actual increase in rate or pressure was observed. The well is making only about 550 MCFD and has cum’d 7.2 BCF and 12 MBW to date. The purpose of this work is to add rate by perforating several Lower Beluga sands with the well flowing. Note: This well is part of a yearly production profile program to disclose where the gas is coming from between the two pools to the AOGCC. The last PLT was performed in July 2021. Wellbore Notes: 01/11/2021 Drift and tag with 2-7/8 dummy gun to 9775’. E-Line Procedure: 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/2500 psi high. 2. Perforate the below sands from the bottom up with the well flowing: Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom LB1B ±6,735' ±6,745' 10' ±6,184' ±6,194' LB2C ±7,032' ±7,042' 10' ±6,479' ±6,489' LB2C ±7,068' ±7,076' 8' ±6,514' ±6,522' LB2E ±7,133' ±7,142' 9' ±6,579' ±6,588' LB3A ±7,206' ±7,218' 12' ±6,652' ±6,664' Note:This well is part of a yearly production profile program to disclose where the gas is coming from between the two pools to the AOGCC. The last PLT was performed in July 2021. Well Prognosis Well: KBU 43-07Y Date: 8/9/2021 LB3B ±7,249' ±7,270' 21' ±6,695' ±6,716' LB3C ±7,306' ±7,319' 13' ±6,752' ±6,765' LB3C ±7,327' ±7,336' 9' ±6,773' ±6,782' LB4D ±7,517' ±7,523' 6' ±6,963' ±6,969' LB5 ±7,534' ±7,538' 4' ±6,980' ±6,984' LB5A ±7,578' ±7,585' 7' ±7,025' ±7,032' LB5B ±7,620' ±7,639' 19' ±7,066' ±7,085' LB5C ±7,643' ±7,650' 7' ±7,090' ±7,097' LB5C ±7,652' ±7,655' 3' ±7,098' ±7,101' LB6A ±7,708' ±7,714' 6' ±7,154' ±7,160' a. Use GR/CCL to correlate to Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. b. Plan on perforating the well with the well flowing. A 2’ gun may be utilized to equalize pressure. c. It should not be necessary to call out nitrogen. 3. POOH. RD e-line. 4. Turn well over to production. Attachments Current Well bore Diagram Proposed Well Bore Diagram _____________________________________________________________________________________ Updated by CRR 6-29-21 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 TD =9,855’(MD ) /9,301’(TVD) 16” 5’ of cement RKB: MSL = 18.6’ 5” 3 4 10-3/4” 7-5/8” 1 2 Tyonek D3C PBTD =9,730’(MD) /9,176’(TVD) Tyonek D3B 6 Tag spent perf guns/wire @ 9,825’ RKB on 3/18/2015 Tyonek D3A Tyonek D2 UT 2A & 2B TY_84_6C LB 4C LB 4B LB 4A LB 4 5 5 LB 1C LB 1E LB 2 LB 2D CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD)Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1C 6,781’ 6,796’ 6,228’ 6,243’ 15’ Blga/Upr Ty 9/15/2020 Open/ 60.4% LB 1E 6,848’ 6,868’ 6,294’ 6,314’ 20’ Blga/Upr Ty 9/15/2020 *Open LB 2 6,953’ 6,963’ 6,399’ 6,409’ 10’ Blga/Upr Ty 9/15/2020 *Open LB 2D 7,087’ 7,017’ 6,533’ 6,553’ 20’ Blga/Upr Ty 9/11/2020 Open/ 11.7% LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ Blga/Upr Ty 8/13/2020 Open / 7.8% LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ Blga/Upr Ty 8/13/2020 Open / 1.1% LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ Blga/Upr Ty 8/13/2020 *Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ Blga/Upr Ty 8/13/2020 Open/ 1.5% UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ Blga/Upr Ty 6/5/2020 Open/ 16.9% UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ Blga/Upr Ty 6/5/2020 Open / 0.2% TY_84_6C 9,002’ 9,042’ 8,449’ 8,489’ 40’ Blga/Upr Ty 1/22/2021 Open / 0.4% D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ Tyonek 5/21/2019 *Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ Tyonek 5/6/2019 *Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ Tyonek 5/14/2014 Isolated (3/27/2015) *no established flow rate from latest production log (18July2021) Note: Comingled production from Tyonek 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: 7/4/20 _____________________________________________________________________________________ Updated by CRR 6-29-21 PROPOSED Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 TD =9,855’(MD) /9,301’(TVD) 16” 5’ of cement RKB: MSL = 18.6’ 5” 3 4 10-3/4”44 7-5/8” 1 2 Tyonek D3C Proposed Lower Beluga perfs PBTD =BB 9,730’(M00D) /9,176’(TVD)66 Tyonek D3B 6 Tag spent perf guns/wire @ 9,825’ RKB on 3/18/2015 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16"Conductor N/A Surf 135' 10-3/4'Surface 45.5 /L-80 /BTC 9.950 Surf 1,600' 7-5/8"Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5"Production 18 / L-80 /DWC/C-HT4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’5” Swell Packer 2 6,561’RA Marker with 5’ Pup 3 7,258’RA Marker with 5’ Pup 4 9,212’RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement –TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”"164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8"254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5”156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL TO BE UPDATED WITH 10-404 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Pool Date Status / Allocated Gas LB 1C 6,781’6,796’6,228’6,243’15’Blga/Upr Ty 9/15/2020 Open /60.4% LB 1E 6,848’6,868’6,294’6,314’20’Blga/Upr Ty 9/15/2020 *Open LB 2 6,953’6,963’6,399’6,409’10’Blga/Upr Ty 9/15/2020 *Open LB 2D 7,087’7,017’6,533’6,553’20’Blga/Upr Ty 9/11/2020 Open / 11.7% LB 4 7,356'7,364'6,802’6,810’8’Blga/Upr Ty 8/13/2020 Open / 7.8% LB 4A 7,379'7,383'6,825’6,829’4’Blga/Upr Ty 8/13/2020 Open / 1.1% LB 4B 7,406'7,413'6,852’6,859’7’Blga/Upr Ty 8/13/2020 *Open LB 4C 7,459'7,473'6,905’6,859’14’Blga/Upr Ty 8/13/2020 Open / 1.5% UT 2A 8,119’8,129’7,564’7,574’10’Blga/Upr Ty 6/5/2020 Open / 16.9% UT 2B 8,138’8,148’7,584’7,594’10’Blga/Upr Ty 6/5/2020 Open / 0.2% TY_84_6C 9,002’9,042’8,449’8,489’40’Blga/Upr Ty 1/22/2021 Open / 0.4% D2 9,477’9,490’8,923’8,936’13’Tyonek 5/21/2019 *Open D3A 9,704’9,714’9,150’9,160’10’Tyonek 5/6/2019 *Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’Tyonek 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’Tyonek 5/14/2014 Isolated (3/27/2015) *no established flow rate from latest production log (18July2021) Note: Comingled production from Tyonek 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: 7/4/20 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/03/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL KBU 43-07Y (PTD 214-019) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 08/03/2021 37' (6HW By Abby Bell at 5:16 pm, Aug 03, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company KBU 11-08Y 50133205520000 205091 1/28/2021 SET PLUG Yellowjacket KBU 23-7 50133205320000 203217 12/20/2020 JET CUT Yellowjacket KBU 23-7 50133205320000 203217 1/4/2021 PERF GAMMA RAY Yellowjacket KBU 41-6 50133205550000 205141 2/8/2021 SET PLUG Yellowjacket KBU 43-07Y 50133206250000 214019 1/22/2021 PERF GAMMA RAY Yellowjacket KBU 44-06 50133204980000 200179 2/22/2021 SET PLUG - JET CUT Yellowjacket KBU 42-07RD 50133204880100 208052 5/31/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/2/2020 PERF GAMMA RAY/GPT Yellowjacket KBU 42-07RD 50133204880100 208052 6/7/2020 PERF GAMMA RAY/GPT Yellowjacket KDU 09 50133205780000 208106 11/25/2020 JET CUT Yellowjacket KDU 09 50133205780000 208106 5/17/2021 PERF / GPT Yellowjacket KTU 13-05 50133203700000 184108 1/12/2021 SET PLUG Yellowjacket KTU 24-06H 50133204900000 199073 6/19/2020 PERF Yellowjacket KTU 24-06H 50133204900000 199073 6/20/2020 GPT Yellowjacket KU 44-08 50133206940000 220068 1/15/2021 SET PLUG Yellowjacket KU 44-08 50133206940000 220068 2/4/2021 PERF GAMMA RAY/GPT Yellowjacket KU 44-08 50133206940000 220068 4/6/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:23 pm, Jun 28, 2021 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 9,855 feet 9,735; 9,780 feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,730 feet 5,774 feet true vertical 9,176 feet 5,221 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker 5" Swell Pkr; N/A 5,774' MD 5,221' TVD N/A; 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: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,140psi 135' 1,532' 6,890psi 5,210psi Collapse 2,470psi 4,790psi 10,500psi Casing Structural 16" 10-3/4" 7-5/8" Length 135' 1,577' 6,257' 9,833' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 828 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-012 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 480 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 670 Kenai Beluga Unit (KBU) 43-07Y N/A FEE A022330 / FEE A028142 6,277' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai / Beluga / Upper Tyonek Gas - Tyonek GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5"9,850' 5,723' 9,297' WINJ WAG 377 Water-Bbl MD 135' 1,600' 0 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 8:56 am, Feb 16, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.02.15 11:12:55 -09'00' Taylor Wellman (2143) DSR-2/16/21 RBDMS HEW 2/16/2021 BJM 3/31/21 SFD 2/17/2021 Rig Start Date End Date E-Line 1/22/21 1/22/21 01/22/2021 - Friday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2500 psi high. We will perf well flowing 653K/72 psi. RIH w/ 2-7/8" x 20' HC, 6 spf, 60 deg phase and tie into RST Log. Run correlation log and send to town. Town said to add 2' to log and perf from 9,022' to 9,042' w/flow 634K/72.1 psi. Spotted and perf zone. After 5 min - 690K/72.9 psi, 10 min - 657.1K/71.2 psi and 15 min - 557K/65.2 psi. POOH. All shots fired and bull plug full of moist sand but gun was dry and not much sand.;RIH w/ 2-7/8" x 20' HC, 6 spf, 60 deg phase and tie into Gun 1 Perf Log. Run correlation log and send to town. Got ok from town to perf from 9,002' to 9,022' w/flow 687K/76 psi. Spotted and perf zone. After 5 min - 692.8K/77.7 psi, 10 min - 684K/74.3psi and 15 min - 622.1K/71.9 psi. POOH. All shots fired. Bull plug full of water (no sand) and outside of gun was sandy and wet. Rig down lubricator and equipment. Turn well over to field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 _____________________________________________________________________________________ Updated by DMA 01-31-21 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status LB 1C 6,781’ 6,796’ 6,228’ 6,243’ 15’ 9/15/2020 Open LB 1E 6,848’ 6,868’ 6,294’ 6,314’ 20’ 9/15/2020 Open LB 2 6,953’ 6,963’ 6,399’ 6,409’ 10’ 9/15/2020 Open LB 2D 7,087’ 7,017’ 6,533’ 6,553’ 20’ 9/11/2020 Open LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ 8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ 8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ 8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ 8/13/2020 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open TY_84_6C 9,002’ 9,042’ 8,449’ 8,489’ 40’ 1/22/2021 Open D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) TY 84 6C 9,002’ 9,042’8,449’8,489’40’1/22/2021 Open 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/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,855'Tru Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 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 tkramer@hilcorp.com 9,301'9,730'9,176'351 N/A Baker 5" Swell Packer; N/A 5,774' MD / 5,221' 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 A022330 / FEE A028142 214-019 50-133-20625-00-00 Kenai Beluga Unit (KBU) 43-07Y Kenai / Beluga / Upper Tyonek Gas - Tyonek Gas Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 10,140 psi MD 6,890 psi 5,210 psi 135' 1,532' 5,723' 135' 1,600' 9,297'5" 16" 10-3/4" 135' 7-5/8"6,257' 1,577' 9,850' Perforation Depth MD (ft): 6,277' See Attached Schematic 9,833' 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: 1/22/2021 N/A m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:08 pm, Jan 11, 2021 321-012 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.11 10:18:46 -09'00' Taylor Wellman 10-404 SFD 1/13/2021 *MIT-IA to 1500 psi (30 min) GAS Perforate DSR-1/12/21gls 1/12/21 q es C 1/14/21 dts 1/14/2021 JLC 1/14/2021 RBDMS HEW 1/26/2021 Well Prognosis Well: KBU 43-07Y Date: 1/7/2021 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 1/22/2021 Rig: E-line Reg. Approval Req’d: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-019 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985)-867-0665 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) AFE Number Estimated Current BHP: ~800 psi at 6,228’ TVD (Calc.from Current Well conditions ) Max Expected BHP: ~1,200 psi at 8,489’ TVD (From RFT Data during Drilling) Max. Potential Surface Pressure: ~351 psi (based on 0.1 psi/ft. gas gradient to surface) Brief Well Summary: KBU 43-07Y is a commingled Tyonek D and Upper Tyonek gas producer currently producing about 500 MCFD with small amounts of water. On July 4th, 2020, a production log was run identifying where the majority of the gas is coming from (UT 2A) as well as showing 100% of the water influx is coming from one sand (Tyonek D3B) bringing in little to no gas with it. On August 12, 2020 The D3B was isolated and additional perforations (LB4) were added uphole. In September 2020, the LB2, LB 1E, and the LB 1C were added. Note: This well is part of a yearly production profile program to disclose where the gas is coming from between the two pools to the AOGCC. The next PLT is due July 2021. The purpose of this work is to perforate TY-84-6C sand. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/2500 psi high. 2. Perforate the TY-84 Sand with 2-7/8” 6 SPF 60 deg phased perf guns. a. Use GR/CCL to correlate to Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. b. Plan on perforating the well with the well flowing. A 2’ gun may be utilized to equalize pressure. c. It should not be necessary to call out nitrogen. 3. Proposed Perforated Intervals Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom TY 84 6C ±9,002' ±9,042' 40' ±8,449' ±8,489' 4. POOH. RD e-line. 5. Turn well over to production. TY 84 6C ±9,002' ±9,042' 40'±8,449'±8,489' NOTE: Pressure test IA ( cement packer completion) to 1500 psi - 30 min /chart Well Prognosis Well: KBU 43-07Y Date: 1/7/2021 Attachments Current Well bore Diagram Proposed Well Bore Diagram _____________________________________________________________________________________ Updated by DMA 09-16-20 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status LB 1C 6,781’ 6,796’ 6,228’ 6,243’ 15’ 9/15/2020 Open LB 1E 6,848’ 6,868’ 6,294’ 6,314’ 20’ 9/15/2020 Open LB 2 6,953’ 6,963’ 6,399’ 6,409’ 10’ 9/15/2020 Open LB 2D 7,087’ 7,017’ 6,533’ 6,553’ 20’ 9/11/2020 Open LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ 8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ 8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ 8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ 8/13/2020 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) 6277 ft _____________________________________________________________________________________ Updated by TRH 01/06/2021 PROPOSED Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status LB 1C 6,781’ 6,796’ 6,228’ 6,243’ 15’ 9/15/2020 Open LB 1E 6,848’ 6,868’ 6,294’ 6,314’ 20’ 9/15/2020 Open LB 2 6,953’ 6,963’ 6,399’ 6,409’ 10’ 9/15/2020 Open LB 2D 7,087’ 7,017’ 6,533’ 6,553’ 20’ 9/11/2020 Open LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ 8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ 8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ 8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ 8/13/2020 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open TY_84_6C ±9,002’ ±9,042’ ±8,449’ ±8,489’ 40’ TBD PROPOSED D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) TY_84_6C ±9,002’ ±9,042’ ±8,449’±8,489’40’TBD PROPOSED Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/30/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 43-07Y (PTD 214-019) Production Profile 07/04/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. PTD: 2140190 E-Set: 34146 Received by the AOGCC 10/30/2020 Abby Bell 10/30/2020 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 9,855 feet 9,735; 9,780 feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,730 feet 5,774 feet true vertical 9,176 feet 5,221 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker 5" Swell Pkr; N/A 5,774' MD 5,221' TVD N/A; 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: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 377 Water-Bbl MD 135' 1,600' 0 Oil-Bbl measured true vertical Packer 5"9,850' 5,723' 9,297' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai / Beluga / Upper Tyonek Gas - Tyonek GasN/A measured TVD Tubing Pressure 670 Kenai Beluga Unit (KBU) 43-07Y N/A FEE A022330 / FEE A028142 6,277' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-343 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 480 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 828 0 Representative Daily Average Production or Injection Data 135' 1,577' 6,257' 9,833' Conductor Surface Intermediate Production 10,500psi Casing Structural 16" 10-3/4" 7-5/8" Length 6,890psi 5,210psi Collapse 2,470psi 4,790psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,140psi 135' 1,532' 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 8:45 am, Sep 23, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.22 16:51:50 -08'00' Taylor Wellman Perforate SFD 9/24/2020 RBDMS HEW 9/23/2020 DSR-9/24/2020gls 10/14/20 Rig Start Date End Date E-Line 9/11/20 9/15/20 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 09/11/2020 - Friday 09/15/2020 - Tuesday Sign in. Mobe to Pad 14-6. PTW and JSA. Used crane to lift electric motor on the roof of a building and bring old one down. Rig down and move to KBU 43-07Y. Spot and rig up equipment. PT lubricator 250 psi low and 3,000 psi high, Well flow 615K at 65 psi. RIH w/ 2-7/8" x 10' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send back to town. Get ok to perf from 6,953' to 6,963' flowing at 614.5K at 66.4 psi. Spot and fire gun. After 5 min - 629.9K at 66.5 psi, 10 min - 619K at 66.7 psi and 15 min - 618.3K at 66.7 psi. POOH. All shots fired/Gun was dry. RIH w/ 2-7/8" x 20' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send back to town. Get ok to perf from 6,848' to 6,868' with 67 psi/flow 621.1K. After 5 min - 71.5 psi/933.3K 10 min - 70.8 psi/flow 878.7K and 15 min - 70.2 psi/flow 844.5K. POOH All shots fired/gun was dry. RIH w/ 2-7/8" x 15' Razor HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send back to town. Get ok to perf from 6,781' to 6,796' with 68.6 psi/flow 731.9K 5 min - 70 psi/flow 826.4K 10 min - 70 psi/Flow 834.1K and 15 min - 70 psi/flow825K. POOH All shots fired/gun dry Rig down equipment and turn well over to field Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up equipment and lubricator. PT lubricator to 250 psi low and 3,000 psi high. Well flowing 359.8 MCF at 64.8 psi. Cut an O-ring and had to lay down lubricator so thats why it took a little longer to rig up. RIH w/ 2-7/8" x 20' HC Razor, 6 spf, 60 deg phase and tie into OHL. Run correlation log and spent about 45 min trying to get it to save an LAS file. AKE-Line has a new truck with new warrior system. It would change the LAS file to PDF file when trying to save to my thumb drive. Called Ben and he said to send both anyway. Sent correlation log to Ben and the Las file worked on his computer. Got ok to perf from 7,087' to 7,107' with well flowing 359.8 MCF at 64.8 psi. Spotted gun and fired with 66 psi flowin g 350 mcf. After 5 min - 71 psi flow 755 mcf, 10 min - 71 psi, flowing 728 mcf, 15 min - 71 psi at flowing 706 mcf and 30 min - 71 psi flowing 698 mcf. POOH. All shoots fired and gun wasn't real wet. Rig down equipment and turn well over to field. Daily Operations: Got ok to perf from 7,087' to 7,107' with w Get ok to perf from 6,781' to 6,796' Get ok to perf from 6,953' to 6,963 Well flowing 359.8 MCF at 64.8 Get ok to perf from 6,848' to 6,868' with _____________________________________________________________________________________ Updated by DMA 09-16-20 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status LB 1C 6,781’ 6,796’ 6,228’ 6,243’ 15’ 9/15/2020 Open LB 1E 6,848’ 6,868’ 6,294’ 6,314’ 20’ 9/15/2020 Open LB 2 6,953’ 6,963’ 6,399’ 6,409’ 10’ 9/15/2020 Open LB 2D 7,087’ 7,017’ 6,533’ 6,553’ 20’ 9/11/2020 Open LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ 8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ 8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ 8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ 8/13/2020 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) LB 1C 6,781’6,796’6,228’6,243’15’9/15/2020 Open LB 1E 6,848’6,868’6,294’6,314’20’9/15/2020 Open LB 2 6,953’6,963’6,399’6,409’10’9/15/2020 Open LB 2D 7,087’7,017’6,533’6,553’20’9/11/2020 Open // 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 9,855 feet 9,735; 9,780 feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,730 feet 5,774 feet true vertical 9,176 feet 5,221 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker 5" Swell Pkr; N/A 5,774' MD 5,221' TVD N/A; 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: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 448 Water-Bbl MD 135' 1,600' 0 Oil-Bbl measured true vertical Packer 5"9,850' 5,723' 9,297' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai / Beluga / Upper Tyonek Gas - Tyonek GasN/A measured TVD Tubing Pressure 640 Kenai Beluga Unit (KBU) 43-07Y N/A FEE A022330 / FEE A028142 6,277' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-313 72 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 541 0 Representative Daily Average Production or Injection Data 135' 1,577' 6,257' 9,833' Conductor Surface Intermediate Production 10,500psi Casing Structural 16" 10-3/4" 7-5/8" Length 6,890psi 5,210psi Collapse 2,470psi 4,790psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,140psi 135' 1,532' 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 10:43 am, Aug 19, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.19 09:54:33 -08'00' Taylor Wellman SFD 8/19/2020 RBDMS HEW 8/19/2020 gls 9/11/20 DSR-8/20/2020 Rig Start Date End Date E-Line 8/11/20 8/12/20 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 08/12/2020 - Wednesday Sign in. Mobe to location. Spot and rig up equipment. Rig up location. PT to 250 psi low and 3,000 psi high. Field PT the IA to 1,500 psi for 30 min. Good Pass. NOTE: We are shooting this flowing. RIH w/ 2-7/8" x 14' Razor HC, 6 spf. 60 degree phase and tie into OHL. Run calibration and send to town. Told to add 4' to our log. Added four foot to our log. Added 4' to log and spotted Gun from 7,459' to 7,473' with well flow 303K at 66 psi. Fired gun and lost 50 lb of line tension. After 5 min - Scada went down. POOH All shots fired, gun was dry. RIH w/ 2-7/8" x 7' Razor HC, 6 spf. 60 degree phase and tie into OHL. Run calibration and send to town. Get ok to perf. Spotted gun from 7,406' to 7,413' with well flow 450K at 72 psi. Fired gun and lost 50 lb of line tension. 5 min - -454K at 73.6 psi, 10 min - 454 at 73.4 psi, 15 min - 451K at 73.6 psi . POOH All shots fired, gun was dry. RIH w/ 2-7/8" x 4' Razor HC, 6 spf. 60 degree phase and tie into OHL. Run calibration and send to town. Get ok to perf. Spotted gun from 7,379' to 7,383' with well flow 424K at 74 psi. Fired gun and lost 50 lb of line tension. After 5 min - 475K at 74.4 psi, 10 min - 464K at 74.1 psi . 15 Min - 464K at 74.6 psi. POOH All shots fired, gun was dry. RIH w/ 2-7/8" x 8'' Razor HC, 6 spf. 60 degree phase and tie into OHL. Run calibration and send to town. Get ok to perf. Spotted gun from 7,356' to 7,364' with well flowing 773K at 74 psi. Fired gun and lost 50 lb of line tension. After 5 min - 792K at 79.3 psi, 10 min - 771.2K at 79.1 psi . 15 Min - 771K at 74.6 psi. POOH All shots fired, gun was dry. Rig down and turn well over to field. 08/11/2020 - Tuesday Sign in. Mobe to location. Spot equipment and rig up lubricator. Rig up lubricator, PT to 250 psi low and 3,000 psi high. RIH w/ 3.75" GR and tie into OHL and tag at 9,765'. Ran correlation log and send to town. Was told we were on depth. POOH. RIH w/ 3.29"OD CIBP and tie into OHL. Run correlation log and send to town. Get ok to set plug at 9,735' with 60 psi flowing 425K. Spotted and set plug. Lost 50 lb of line tension wen gun went off. Picked up 30 and back down and tagged plug. POOH. Tools looked good. RIH w/ 3' x 10' of 17 ppg pm top of plug. Dump 5' of cement on top of plug. POOH. Good Dump. CIP - 1300 hrs, TOC - 9730' Rig down equipment and lubricator. Secure well. Will be back in morning to perforated. Daily Operations: _____________________________________________________________________________________ Updated by DMA 08-17-20 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ 8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ 8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ 8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ 8/13/2020 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) new perfs LB 4 7,356' 7,364' 6,802’ 6,810’ 8’8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’8/13/2020 Open 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/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,855'9,825' (RKB) Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 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 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: 9/1/2020 N/A 9,850' Perforation Depth MD (ft): 6,277' See Attached Schematic 9,833' 9,297'5" 16" 10-3/4" 135' 7-5/8"6,257' 1,577'5,210 psi 135' 1,532' 5,723' 135' 1,600' N/A TVD Burst N/A 10,140 psi MD 6,890 psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A022330 / FEE A028142 214-019 50-133-20625-00-00 Kenai Beluga Unit (KBU) 43-07Y Kenai / Beluga / Upper Tyonek Gas - Tyonek Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 9,301'9,780'9,226'1,867 N/A Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:43 am, Aug 19, 2020 320-343 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.19 09:52:53 -08'00' Taylor Wellman DLB 08/19/2020 Perforate X gls 9/3/20 DSR-8/20/2020 10-404 Comm ption Required? Yes 9/3/2020 dts 9/3/2020 JLC 9/3/2020 RBDMS HEW 9/8/2020 Well Prognosis Well: KBU 43-07Y Date: 8/17/2020 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 8/30/2020 Rig: Rigless Reg. Approval Req’d: 10-403 Sundry Number: 320-313 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-019 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (907) 865-0665 (C) AFE Number Estimated Current BHP: ~1561 psi at 7564 TVD (From RFT ran 4/4/17) Max Expected BHP: ~2499 psi at 6320’ TVD Max. Potential Surface Pressure: ~1867 psi (based on gas gradient to surface) Brief Well Summary: KBU 43-07Y is a commingled Tyonek D and Upper Tyonek gas producer currently producing about 500 MCFD with small amounts of water. On July 4th, 2020, a production log was run identifying where the majority of the gas is coming from (UT 2A) as well as showing 100% of the water influx is coming from one sand (Tyonek D3B) bringing in little to no gas with it. On August 12, 2020 The D3B was isolated and additional perforations were added uphole. The purpose of this work is to perforate four intervals in the LB1 and LB2 sands. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/2500 psi high. 2. Perforate the Beluga sands with 2-7/8” 6 SPF 60 deg phased perf guns. a. Use GR/CCL to correlate to Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. b. Plan on perforating the well with the well flowing FOC. c. It should not be necessary to call out nitrogen. 3. Proposed Perforated Intervals Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom LB 1C ±6,781' ±6,796' 15' ±6,228' ±6,243' LB 1E ±6,848' ±6,868' 20' ±6,294' ±6,314' LB 2 ±6,953' ±6,963' 10' ±6,399' ±6,409' LB 2D ±7,087' ±7,107' 20' ±6,533' ±6,553' 4. POOH. RD e-line. 5. Turn well over to production. The purpose of this work is to perforate four intervals in the LB1 and LB2 sands. _____________________________________________________________________________________ Updated by DMA 08-17-20 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ 8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ 8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ 8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ 8/13/2020 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) RA 7258' _____________________________________________________________________________________ Updated by TCS 08-18-20 PROPOSED SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,735’ CIBP w/ 5ft of cement – TOC @ 9,730’ 8/11/20 6 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status LB 1C ~6,781’ ~6,796’ ~6,228’ ~6,243’ 15’ TBD - LB 1E ~6,848’ ~6,868’ ~6,294’ ~6,314’ 20’ TBD - LB 2 ~6,953’ ~6,963’ ~6,399’ ~6,409’ 10’ TBD - LB 2D ~7,087’ ~7,017’ ~6,533’ ~6,553’ 20’ TBD - LB 4 7,356' 7,364' 6,802’ 6,810’ 8’ 8/13/2020 Open LB 4A 7,379' 7,383' 6,825’ 6,829’ 4’ 8/13/2020 Open LB 4B 7,406' 7,413' 6,852’ 6,859’ 7’ 8/13/2020 Open LB 4C 7,459' 7,473' 6,905’ 6,859’ 14’ 8/13/2020 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Isolated (8/12/2020) D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) RA 7258' 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/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,855'9,825' (RKB) Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 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 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: 8/15/2020 N/A 9,850' Perforation Depth MD (ft): 6,277' See Attached Schematic 9,833' 9,297'5" 16" 10-3/4" 135' 7-5/8"6,257' 1,577'5,210 psi 135' 1,532' 5,723' 135' 1,600' N/A TVD Burst N/A 10,140 psi MD 6,890 psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A022330 / FEE A028142 214-019 50-133-20625-00-00 Kenai Beluga Unit (KBU) 43-07Y Kenai / Beluga / Upper Tyonek Gas - Tyonek Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 9,301'9,780'9,226'2,312 N/A Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 2:32 pm, Jul 28, 2020 320-313 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.07.28 11:57:12 -08'00' Taylor Wellman gls 7/30/20 10-404 *MIT-IA to 1500 psi prior to perforating. SFD 7/28/2020 DSR-7/29/2020 Perforate Plug Perforations dts 7/30/2020 7/31/2020Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.07.31 10:31:10 -08'00' RBDMS HEW 8/3/2020 Well Prognosis Well: KBU 43-07Y Date: 7/22/2020 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 8/10/2020 Rig: Rigless Reg. Approval Req’d: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-019 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (907) 865-0665 (C) AFE Number Current Bottom Hole Pressure: ~1561 psi at 7,564 TVD (From RFT ran 4/4/17) Max. Expected BHP: ~2997 psi @ 6859’ TVD (using 0.437 psi/ft gradient) Max. Potential Surface Pressure: ~2312 psi (based on gas gradient to surface) Brief Well Summary: KBU 43-07Y is a commingled Tyonek D and Upper Tyonek gas producer currently producing about 500 MCFD with small amounts of water. On July 4th, 2020, a production log was run identifying where the majority of the gas is coming from (UT 2A) as well as showing 100% of the water influx is coming from one sand (Tyonek D3B) bringing in little to no gas with it. The purpose of this work is to set a plug in order to isolate the D3B interval below and perforate four intervals in the LB 4 above the plug. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,000 psi high. 2. RIH with BHA including CCL and 5” CIBP. Set CIBP at ~9735’ MD (do not set in a collar). Dump bail 5’ of cement on top of the plug. 3. Perforate the Tyonek sands with 3-3/8” 6 SPF 60 deg phased perf guns. a. Use GR/CCL to correlate to Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. b. Plan on perforating the well with the well flowing chocked back to 300 psi WHP. c. There are open perforations above the plug so it will not be necessary to call out nitrogen. The purpose of this work is to set a plug in order to isolate the D3B interval below and perforate four intervals in gls Note: MIT-IA to 1500 psi to verify cement packer integrity before adding additional perfs. the LB 4 above the plug. Set CIBP at ~9735’ MD Well Prognosis Well: KBU 43-07Y Date: 7/22/2020 4. Proposed Perforated Intervals Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom LB 4 ±7,356' ±7,364' 8' ±6,802’ ±6,810’ LB 4A ±7,379' ±7,383' 4' ±6,825’ ±6,829’ LB 4B ±7,406' ±7,413' 7’ ±6,852’ ±6,859’ LB 4C ±7,459' ±7,473' 14’ ±6,905’ ±6,859’ 5. POOH. RD e-line. 6. Turn well over to production. Proposed Perforated Intervals Well Prognosis Well: KBU 43-07Y Date: 7/22/2020 Well Prognosis Well: KBU 43-07Y Date: 7/22/2020 Set CIBP CIBP Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8339 Fax: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/27/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL KBU 43-07Y (PTD 214-019) Please include current contact information if different from above. Received by the AOGCC 07/27/2020 PTD: 214019 E-Set: 33625 Abby Bell 07/27/2020 Holly Tipton Hilcorp Alaska, LLC Regulatory Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/06/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Production logs as required by Rule No. 5 of CO 510A for KBU 43-07Y and KU 24-05B are saved in the following folders on the AOGCC FTP Site: Please include current contact information if different from above. Received by the AOGCC 07/07/2020 PTD: 2140190 E-Set: 33477 Abby Bell 07/07/2020 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 9,855 feet N/A feet true vertical 9,301 feet 9,825 (RKB) feet Effective Depth measured 9,780 feet 5,774 feet true vertical 9,226 feet 5,221 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A Packers and SSSV (type, measured and true vertical depth)Baker 5" Swell Pkr; N/A 5,774' MD 5,221' TVD N/A; 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: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,140psi 135' 1,532' 6,890psi 5,210psi Collapse 2,470psi 4,790psi 10,500psi Casing Structural 16" 10-3/4" 7-5/8" Length 135' 1,577' 6,257' 9,833' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 825 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-213 70 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-019 50-133-20625-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 590 Kenai Beluga Unit (KBU) 43-07Y N/A FEE A022330 / FEE A028142 6,277' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Kenai / Beluga / Upper Tyonek Gas - Tyonek GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5"9,850' 5,723' 9,297' WINJ WAG 440 Water-Bbl MD 135' 1,600' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 2:19 pm, Jun 26, 2020 ManagerManagerDigitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.26 10:22:31 -08'00' Taylor Wellman Perforate RBDMS HEW 6/29/2020 GLS 9/2/20 Other: N2 DSR-6/26/2020 SFD 7/2/2020 Rig Start Date End Date E-Line 6/5/20 6/5/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name KBU 43-07Y 50-133-20625-00-00 214-019 Sign in. Mobe to location. PTW and JSA and SIMOPS with AKE-Line and SLB N2. Rig up equipment and PT hard lines and lubricator to 250 psi low and 4,000 psi high. RIH w/GPT, tie into SLB RST and stop at 8,400'. Run correlation log and send to town. Shows no fluid. Told to add 3'. POOH RIH w/ 2-7/8" x 2' HC Razor, 6 spf, 60 deg phase perf gun and start pressuring up on tubing. Ran correlation log and send to town. Get ok to shot from 8,142' to 8,144' w/850 psi after SLB pressured up with N2. Fired gun with 853 psi on tubing. After 5 min - 738 psi, 10 min - 630 psi and 15 min - 586 psi. POOH. All shots fired and gun dry. Used 1,800 gals N2. RIH w/ 2-7/8" x 10' HC Razor, 6 spf, 60 deg phase perf gun and tie in with RST log. Ran correlation log and send to town. Get ok to shot from 8,138' to 8,148' w/192 psi on tubing. Spotted and fired gun. After 5 min - 191 psi, 10 min - 190 psi and 15 min - 189 psi. POOH. All shots fired and gun dry. RIH w/ 2- 7/8" x 10' HC Razor, 6 spf, 60 deg phase perf gun and tie in with RST log. Ran correlation log and send to town. Get ok to shot from 8,119' to 8,129' w/181 psi on tubing. Spotted and fired gun. After 5 min - 200 psi, 10 min - 214 psi and 15 min - 225 psi. POOH. All shots fired and gun dry. Rig down lubricator and turn well over to field. 06/05/2020 - Friday Get ok to shot from 8,142' to 8,144' w/850 psi after SLB pressured up with N2. t from 8,138' to 8,148' RIH w/GPT, tie into SLB RST and stop at 8,400'. Run c m 8,119' to 8,129' w/181 psi on tubing. _____________________________________________________________________________________ Updated by DMA 06-16-20 SCHEMATIC Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’ 6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’ 6/5/2020 Open D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Open UT 2A 8,119’ 8,129’ 7,564’ 7,574’ 10’6/5/2020 Open UT 2B 8,138’ 8,148’ 7,584’ 7,594’ 10’6/5/2020 Open 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 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): 9,855'9,825' (RKB) Casing Collapse Structural Conductor Surface 2,470 psi Intermediate 4,790 psi Production 10,500 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: Christina Twogood Operations Manager Contact Email: Contact Phone: 777-8443 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 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: June 8th, 2020 N/A 9,850' Perforation Depth MD (ft): 6,277' See Attached Schematic 9,833' 9,297'5" 16" 10-3/4" 135' 7-5/8"6,257' 1,577'5,210 psi 135' 1,532' 5,723' 135' 1,600' N/A TVD Burst N/A 10,140 psi MD 6,890 psi Length Size CO 510A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE A022330 / FEE A028142 214-019 50-133-20625-00-00 Kenai Beluga Unit (KBU) 43-07Y Kenai / Beluga / Upper Tyonek Gas - Tyonek Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic ctwogood@hilcorp.com 9,301'9,780'9,226'~ 3,423 psi N/A Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A Perforation Depth TVD (ft): Tubing Size: m n P 66 t 2 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:44 am, May 26, 2020 320-213 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.05.26 10:26:23 -08'00' Taylor Wellman SFD 5/27/2020 DLB 05/26/2020 DSR-5/26/2020 X 10-404 gls 5/27/20 q C 5/27/2020 dts 5/27/2020 RBDMS HEW 5/27/2020 Well Prognosis Well: KBU 43-07Y Date: 5/22/2020 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: June 8th, 2020 Rig: E-Line Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-019 First Call Engineer: Christina Twogood (907) 777-8443 (O) (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Current BHP: ~600 psi @ 8,923’ TVD (Calc. from RFT data from 4/4/2017) Max. Expected BHP: 4,178 psi @ 7,564’ TVD (Based on normal pressure gradient) Max. Potential Surface Pressure: 3,422 psi (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) Brief Well Summary KBU 43-07Y was drilled and completed in 2014 in the Tyonek D. It was perf’d and produced in the D3C (sucker sand) and the D3B. In May 2019, the D3A and D2 sands were perf’d. The purpose of this work/sundry is to add perforations in (2) intervals of the Upper Tyonek. Notes Regarding Wellbore Condition x Currently producing approx. 400 MCFD x Minimum ID is 4.27” x Last tag @ 9,775’ KB w/ 3.5” GR on 5/1/2019, was followed by a 2-7/8” x 15’ spent dummy gun to 9,775’ MD Safety Concerns 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 job authority. E-Line Procedure 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 4,000 psi High. 2. RIH with GPT tool and find fluid 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 perf. 4. RU perf guns. The purpose of this work/sundry is to add perforations in (2) intervals of the Upper Tyonek. RIH with GPT tool and find fluid level. Well Prognosis Well: KBU 43-07Y Date: 5/22/2020 5. RIH and perforate the following intervals: Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Upper Tyonek UT 2A +8,119’ +8,129' +7,564' +7,574' 10' Upper Tyonek UT 2B +8,138’ +8,148' +7,584' +7,594' 10' a. Pressure up to approx. 300 psi before shooting the well while flowing. 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 Beluga / Upper Tyonek Gas Pool based on Conservation Order No. 510A. 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 / 4,000 psi High. 3. RIH and set 5” Casing Patch or set 5” CIBP above the zone and dump 35’ of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure – N2 Operations Perf interval Upper Tyonek UT 2A +8,119’+8,129'+7,564'+7,574'10' Upper Tyonek UT 2B +8,138’+8,148'+7,584'+7,594'10' _____________________________________________________________________________________ Updated by DMA 05-29-19 SCHEMATIC __________ Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 ____________ ____________________________________________________ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Open D3C 9,804' 9,824' 9,250' 9,270' 20’ 5/14/2014 Isolated (3/27/2015) _____________________________________________________________________________________ Updated by CMT 5-22-2020 PROPOSED SCHEMATIC ________________________ Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 ____________ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5 /L-80 / BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surf 6,277' 5" Production 18 / L-80 / DWC/C-HT 4.276 Surf 9,850’ JEWELRY DETAIL No Depth Item 1 5,774’ 5” Swell Packer 2 6,561’ RA Marker with 5’ Pup 3 7,258’ RA Marker with 5’ Pup 4 9,212’ RA Marker with 5’ Pup 5 9,780’ CIBP w/ 5ft of cement OPEN HOLE / CEMENT DETAIL 10-3/4”" 164BBL’s of cement in 13.5” Hole. Returns to Surface 7-5/8" 254BBL’s of cement in 9-7/8” Hole. Returns to Surface 5” 156BBL’s of cement in 6-3/4” Hole. TOC 5,700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status UT 2A ±8,119’ ±8,129’ ±7,564’ ±7,574’ 10’ TBD Proposed UT 2B ±8,138’ ±8,148’ ±7,584’ ±7,594’ 10’ TBD Proposed D2 9,477’ 9,490’ 8,923’ 8,936’ 13’ 5/21/2019 Open D3A 9,704’ 9,714’ 9,150’ 9,160’ 10’ 5/6/2019 Open D3B 9,746’ 9,766’ 9,192’ 9,212’ 20’ 7/15/2014 Open UT 2A ±8,119’ ±8,129’ ±7,564’ ±7,574’ 10’ TBD Proposed UT 2B ±8,138’ ±8,148’ ±7,584’ ±7,594’ 10’ TBD Propose 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 3 0 2019 it nr+r%r% 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing —O a ns utdown LJ Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic ❑ Exploratory ❑ Service ❑ 214-019 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20625-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE A028142 Kenai Beluga Unit (BRU) 43-07Y 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai / Beluga/Up Tyonek Gas-Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 9,855 feet Plugs measured N/A feet true vertical 9,301 feet Junk measured 9,811 (RKB) feet Effective Depth measured 9,840 feet Packer measured 5,774 feet true vertical 9,286 feet true vertical 5,221 feel Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,577' 10-3/4" 1,600' 1,532' 5,210psi 2,470psi Intermediate 6,257' 7-5/8" 6,277' 5,723' 6,890psi 4,790psi Production 9,833' 5" 9,850' 9,297' 10,140psi 10,500psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Baker 5" Swell Pkr 5,744' MD 5,221' 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: 0 545 0 0 58 Subsequent to operation: 0 803 0 0 65 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory[] Development El Service ❑ Slratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ✓ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 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: 319-213 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerJ2hf' coro.c0m Authorized Signature: Date: 3 O lb I q Contact Phone: 777-8420 10, Form 10-404 Revised 4/2017 jr� 1 BDMS-qP�MAY 3 121.119 17 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KBU 43-07Y E-Line 50-133-20625-00-00 1 214-019 5/6/19 1 5/21/19 Daily Operations: 05/06/2019 - Monday Sign in. PTW and JSA. Mobe to location. Rig up lubricator and GPT tool. Attempted to PT but top of lubricator had O-ring failure. Lay lubricator back down. Put new O-ring on. PT to 250 psi low and 3,000 psi high. RIH w GPT and tied into SLB RST log dated 27 mar 14. Tagged at 9,772'. Found fluid level at 9,394' with 215 psi on well. POOH. Send log to town. RIH w/ 2-7/8" x 20' (Bottom 10' loaded) MaxForce HC, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Was told to down shift 1' to log. Down shifted 1' and spotted and fired gun from 9,704' to 9,714' with 215.9 psi on tubing. After 5 min - 216.6 psi, 10 min - 216.9 psi and 15 min - 217.4 psi. POOH All shots fired. Rig down lubricator and turn well over to field. 05/21/2019-Tuesday PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,000 psi high. TP - 256 psi. RIH w/ 2-7/8" x 13' Razar HC, 6 spf, 60 deg phase pert gun. Run correlation log and send to town. Got ok from town to pert from 9,477'to 9,490' with 266 psi on well. Spotted and fired shot. Lost 150 lbs line tension. Pressure stayed at 266 psi for 15 min. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field. TP - 262.5 psi. rf 16' 103/4" 7-5/8" RKB: MSL =18.6 3 4 5dcered on -I D2 ,21 Ty \ .M Tyuck MA✓ TO=9,855'(MD) /9,301'(TVD) PBTD=9,84(Y(MD) /9,286 OW) SCHEMATIC CASING DETAIL Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A 3 Surf 135' 10-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surf 6,277' 5" Production 18/L-80/DWC/C-HT 4.276 1 Surf I 9,850' JEWELRY DETAIL No Depth Item 1 5,774' 5" Swell Packer 2 6,561' RA Marker with 5' Pup 3 7,258' RA Marker with 5' Pup 4 9,212' RA Marker with 5' Pu 5 9,784 CIBP w/Sit of cement OPEN HOLE/ CEMENT DETAIL 10-3/4"" 164BBL's of cement in 13.5" Hole. Returns to Surface 7-5/8" 254BBL's of cement in 9-7/8" Hole. Returns to Surface 5" 156BBL's of cement in 6-3/4" Hole. TOC 5,700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status D2 9,477' 9,490' 8,923' 8,936' 13' 5/21/2019 Open D3A 9,704' 9,714' 9,150' 9,160' 10' 5/6/2019 Open D38 9,746' 9,766' 9,192' 9,212' 20' 7/15/2014 Open 33C 9,804' 9,824' 9,250' 9,270' 20' 5/14/2014 Isolated (3/27/2015) Updated by DMA 05-29-19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operation 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 v .aogcc.alasko.gov Re: Kenai Field, Beluga/ Upper Tyonek and Tyonek Gas Pool, KBU 43-07Y Permit to Drill Number: 214-019 Sundry Number: 319-213 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, Daniel T. Seamount, Jr. Commissioner 4111— DATED this�� day of April, 2019. R msyt �/ APR 7 6 2619 EKED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 3 2019 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A /'1 <`• r� f-% 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ _per. wns shutdown ❑ Suspend ❑ Perforate ❑D . 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: Hilcorp Alaska, LLC Exploratory ❑ Development ❑� , Strati ra hic ❑ g p ❑ Service 214-019 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API N�mberL_,�- ! ',j -OG, Anchorage Alaska 99503 50-'133-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 510A Will planned perforations require a spacing exception? Yes ❑ No Kenai Beluga Unit (KBU) 43-07Y 9. Property Designation (Lease Number): 10. Field/Pool(s): FEEA022330IFEEA028142 Kenai / Beluga/Up Tyonek Gas-Tyonek Gas it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,855' 9,301' 840' 9,286' -2,530 psi N/A 9,825' (RKB) Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,57T 10-3/4" 1,600' 1,532' 5,210psi 2,470P si Intermediate 6,257' 7-5/8" 6,277' 5,723' 6,890psi 4,790P si Production 9,833' 5' 9,850' 9,297' 10,140psi 10,500P si Liner Perforation Depth MD (ft):Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A NIA Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker 5" Swell Packer; N/A 5,774' MD / 5,221' TVD; N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 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: May 12, 2019 Commencing Operations: OIL E]WINJ E]WDSPL F] Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 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: Ted Kramer Authorized Title: Operations Manager Contact Email: ikramer�dhilcoro com Contact Phone: 777-8420 Authorized Signature: Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31q- Z 13 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test E]Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required. Yes ❑ No Q' Subsequent Form Required: o — y (7 \ APR 2 6 2019 �BD�J� APPROVED BY�� Approved by: COMMISSIONER THE COMMISSION Date' ^` PP R Ja&I Submit Form and 17- R�_.1 ori Form -403 evised 4/201 Approved a I INIAL.. the date of approval. � (//� Attachments in Duplicate if^ i",�/ f // n Hilmrp Alaska, LU Well Prognosis Well: KBU 43-07Y Date: 4/22/2019 Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Gas Well Leg: N/A Estimated Start Date: 5/12/2019 Rig: N/A Reg. Approval Req'd? 10-403 Sundry Number: ±9,150' Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-019 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (C) Measured Bottom Hole Pressure: —650 psi at 9,107' ND Calc. from RFT Data 4/4/17 Max. Anticipated Surface Pressure: —2,530 psi. (0.1 psi/ft gas gradient) Brief Well Summary: KBU 43-07Y was drilled and completed in April 2014. It is currently producing from the Tyonek Gas Pool D -3B and D3C sands. Objective: Add Perforations in the D3A and D2 Sands. V/ Summary Procedure: 1. MIRU a -line and pressure control equipment. PT lubricator to 250 psi low/3,000 psi high. 2. PU Perf guns, RIH and Log on depth. Perforate the following intervals: Sands Top (MD) Btm (MD) Top (TVD) Bottom (TVD) FT D -3A ±9,704' ±9,714' ±9,150' ±9,160' 10 D-2 I ±9,477 ±9,490' ±8,923' ±8,936' 13 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. c. Use Gamma/CCL/ to correlate. d. Spacing allowance is based on CO 510A, Tyonek Gas Pool 1. e. If interval is wet, it may be permanently isolated with a casing patch and/or plug. f. Record 5, 10, 15 min. pressures after firing guns. 3. RDMO a -line. 4. Turn well over to production to test. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic B caro Alaska, LLC RKB: MSL =18.6' R" 10.3/4" 2 ;f ' 3 y' t ry r. s 4 5 of Cement Tyanek D3B � a 5 Tag sped per gure, ire @9,825 u TWrak D 3 F3Ban 3'18�27i5 _ TD=9,855'(MD) /9,301'(T/D) PBTD=9,840'(MD) /9,286(TVD) SCHEMATIC CASING DETAIL Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A 3 Surf 135' 10-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surf 6,277' 5" Production 18/L-80/DWC/C-HT 4.276 Surf 9,850' JEWELRY DETAIL No Depth Item 1 5,774' 5" Swell Packer 2 6,561' RA Marker with 5' Pup 3 7,258' RA Marker with 5' Pup 4 9,212' RA Marker with 5' Pup 5 9,780' CIBP w/Sft of cement Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date I Status D-313 1 9,746' 1 9,766' 1 9,192' 9,212' 20' 7/15/2014 1 Open D -3C 9,804' 9,824' 9,250' 9,270' 20' 5/14/2014 Isolated (3/27/2015) OPEN HOLE/ CEMENT DETAIL 10-3/4"" 164BBL's of cement in 13.5" Hole. Returns to Surface 7-5/8" 254BBL's of cement in 9-7/8" Hole. Returns to Surface 5" 156BBUS of cement in 6-3/4" Hole. TOC 5,700 Calculated Updated by TRH 03/25/2019 B Hilcary Alaska, IdC RKB: MSL =1&6' C 16" ' S 10,14 i 7 5/S' 2 4 i7 R 5'of artvrt� �. - TMiek D2 - 5 Tag=l paf guisMiM 49.875',. TWwk D3C I® Rm 311&2015 TD-9,855'(MD) /9,301'MM) PBTD-3,840'(MD) /9,286(TVD) PROPOSED SCHEMATIC CASING DETAIL Kenai Gas Field Well: KBU 43-7Y Last Completed: 5/14/2014 PTD: 214-019 Size Type Wt/Grade/Conn ID Top atm 16" Conductor N/A ±9,477' Surf 135' 30-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surt 6,277' 5" Production 18/L-80/DWC/C-HT 4.276 Surf 9,854 JEWELRY DETAIL OPEN HOLE / CEMENT DETAIL 10-3/4"" 1648BL's of cement in 13.5" Hole. Returns to Surface 7-5/8" _ 254BBL's of cement in 9-7/8" Hole. Returns to Surface 5" 156BBL's of cement in 6-3/4" Hale. TOC 5.700 Calculated Sand Top (MD) em Top (TVD) Btm (TVD) Swell Packj5'Pu Date W9,212'RA A Marker wip ±9,477' ±9,490' Marker wip ±8,936' 13' Marker wiIBP TBD D3A w/ Sft of OPEN HOLE / CEMENT DETAIL 10-3/4"" 1648BL's of cement in 13.5" Hole. Returns to Surface 7-5/8" _ 254BBL's of cement in 9-7/8" Hole. Returns to Surface 5" 156BBL's of cement in 6-3/4" Hale. TOC 5.700 Calculated Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status D2 ±9,477' ±9,490' ±8,923' ±8,936' 13' Proposed TBD D3A ±9,704• ±9,714' ±9,150' ±9,160' 10' Proposed TBD 133B 9,746' 9,766' 9,192' 9,212' 20' 7/15/2014 Open D3C 9,804' 9,824' 9;250' 9,270' 20' 5/14/2014 Isolated (3/27/2015) Updated by DMA 04-22-19 10,000,000 1,000,000 10 HILCORP ALASKA LLC, KENAI BELUGA UNIT 43-07Y (214-019) KENAI, BELUGA/UP TYONEK GAS Monthly Production Rates Cum. Prod Oil (bbls): 0 Cum. Prod Water (bbls): 15,058 - Cum. Prod Gas (mcf): 8,449,936 �.. I 1 - 10,000,000 d 1,000,000 CD O -M 0 100,000 m 3 C! 3 10,000 S 0 W d Z 1,000 0 O m ro 100 rD fD z 0 O 3 10 - 1 Jan -2010 Jan -2011 Jan -2012 Jan -2013 Jan -2014 Jan -2015 Jan -2016 Jan -2017 Jan -2018 Jan -2019 Jan -2020 � Produced Gas (MCFM) • GOR - Produced Water (BOPM) —e— Produced Oil (BOPM) SPREADSHEET_2140190_KBU_43-07Y_Prod-Inject_Curves_Well_Gas_V120_20190405.xlsx 4/24/2019 STATE OF ALASKA AL ..CA OIL AND GAS CONSERVATION COMB,__,,ION REPORT OF SUNDRY WELL OPERATIONS L 1 Operations Abandon U Repair Well U Plug Perforations U .Pe vferatc-e- -1'Z Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory ❑ 214-019 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20625-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE A028142 Kenai Beluga Unit(KBU)43-07Y 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kenai Unit Field/Upper Tyonek&Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,855 feet Plugs measured N/A feetRECEIVED true vertical 9,301 feet Junk measured 9,811 (RKB) feet APR 14 2015 Effective Depth measured 9,840 feet Packer measured 5,774 feet true vertical 9,286 feet true vertical 5,221 feet CC Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,577' 10-3/4" 1,600' 1,532' 5,210psi 2,470psi Intermediate 6,257' 7-5/8" 6,277' 5,723' 6,890psi 4,790psi Production 9,833' 5" 9,850' 9,297' 10,140psi 10,500psi Liner Perforation depth Measured depth See Attached Schematic C p f► SEEI ;'.PR 2 4 2 U I5 True Vertical depth See Attached Schematic �•f!!� Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Baker 5"Swell Pkr 5,744'MD 5,221'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 5,793 0 0 189 Subsequent to operation: 0 4,648 0 0 646 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service ❑ Stratigraphic E Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑' WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-157 Contact Chad Helgeson EmailCheIaeson( hiIcorD.Com Printed Name Chad Helgeson Title Operations Manager Signature �i2 ,7 Phone 907-777-8405 Date 0 V/fir ie._ 4,-,0 -' s RBDMS-Ai APR 1 8 2015 Form 10-404 Revised 10/2012Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date KBU 43-7Y 50-133-20625-00-00 214-019 3/27/15 3/30/15 Daily Operations: 03/27/2015 - Friday PTW,JSA SIMOPS with Saxon Drilling. Spot equipment and rig up. Pressure test lubricator to 250 psi low and 4,000 psi high. Shut well in. RIH w/3.75" GR, tied into SLB RST log dated 27 Apr 2014 and set down at 9,324'. Picked up and went down a little faster and seemed like we were pushing something down hole. Stopped at 9,800'. Picked back up to 9,300' and back down to 9,800' with no problems. POOH. RIH w/5" CIBP (Plug is 3.74" OD) and tied into SLB RST log dated 27 Apr 2014. Run correlation log and send to town. Get nk to set plug at 9,785'.Spot plug and set.plug. Lost 150 lbs on wt indicator. Picked up 30' and went back and set down on plug. POOH. TP-900 psi. Pressure came up to 1,500 psi by the time we got out of hole. RIH w/3" x 20' bailer with 4.2 gals cement and dump cement on top of plug. Est top cement 9,780'. Cement in place at 1715 hrs. POOH. Rig down lubricator and turn well back over to field. TP-1,650 psi. 03/30/2015- Monday RU slickline unit. PT lubricator to 1,000 psi -test OK. RIH w/2.80" GR and tag cement at 9,794' SLM. POOH. RIH w/ press/temp gauges. POOH. RD slickline unit. Kenai Gas Field 11 Well: KBU 43-7Y SCHEMATIC Last Completed: 5/14/2014 Hilcorp Alaska,LLC PTD: 214-019 CASING DETAIL 1 RKB:MSL=18.6' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surf 6,277' 5" Production 18/L-80/DWC/C-HT 4.276 Surf 9,850' 16" r 6* ✓ 4 1, JEWELRY DETAIL i L v A' Yi i 1 ' No Depth Item , d 1 5,774' 5"Swell Packer io-3/4" ;+ 2 6,561' RA Marker with 5'Pup 0 v 3 7,258' RA Marker with 5'Pup 4 9,212' _ RA Marker with 5'Pup r l 5 9,780' CIBP w/5ft of cement a a • ti PERFORATION DETAIL 4 ` 4, Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Status Date J D-3C 9,746' 9,766' 9,192' 9,212' 20' Open D-3B 9,804' 9,824' 9,250' 9,270' 20' Isolated 03-27-15 ✓ r OPEN HOLE/CEMENT DETAIL % i i -10-3/4"" 164881's of cement in 13.5"Hole.Returns to Surface %L V 7-5/8" 254BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 156881's of cement in 6-3/4"Hole. TOC 5,700 Calculated 4 f �+ 44 id" o7-5/8" > t Y t 1 �e 142 ` v: � .,11 5'� i' " `-. C, i; te,,.." VI 70 t t i 3 j. 1; 4 5'd cement it 5 Tycnek D3C 5 / « Tag spent P 4011 Tyonek D3B 9ur>siwre @ 9,825 RKB cn3/18IB)5' 1 g TD=9,855'(MD)/9,301'(1VD) PBTD=9,840'(MD)/9,286(TVD) Updated by DMA 04-13-15 � OF Ty 0,,\11/7 ,t,,,,•‘-'.: ,ST THE STATE Alaska Oil and Gas �� of Conservation Commission _ _____ ALASIc:A ' 1Lz_�=.�y = 333 West Seventh Avenue nh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF P Main: 907 279 1433 ALAS Fax. 907.276.7542 www.aogcc alaska.gov Chad Helgeson SCANNED /',0`,. 1 : , ,J; ail"' -D J 9 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Kenai Field, Upper Tyonek and Beluga Gas Pool, KBU 43-7Y Sundry Number: 315-157 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, i //' ' .9t5t_r.,)4, 1 Cathy P oerster Chair DATED this 1$ day of March, 2015 Encl. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION �,R 2 2015 APPLICATION FOR SUNDRY APPROVALS �(s� 3/zq-1 L520 MC 25.280 A'^''G Li`' 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Change Approved Program 0 Suspend❑ Plug Perforations 0 . Perforate❑ Pull Tubing❑ Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. [1 2.Operator Name: 4.Current Well Class: 5.Permit to Dril Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ - 214-019 • 3.Address: Stratigraphic 0 Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20625-00-00 • 7.If perforating: LL��,, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.510/ j ? Will planned perforations require a spacing exception? Yes ❑ No ❑, l a /ti' Kenai Beluga Unit(KBU)43-7Y • 9.Property Designation(Lease Number): 10.Field/Pool(s): FEE A028142 Kenai Unit Field/Upper Tyonek&Beluga Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,855 • 9,301 • 9,840 9,286 N/A 9,825'(RKB) — Casing Length Size MD TVD Burst Collapse Structural Conductor 135' 16" 135' 135' Surface 1,577' 10-3/4" 1,600' 1,532' 5,210psi 2,470psi Intermediate 6,257' 7-5/8" 6,277' 5,723' 6,890psi 4,790psi Production 9,833' 5' 9,850' 9,297' 10,140psi 10,500psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker 5"Swell Packer;N/A 5,774'MD/5,221'ND;N/A 12.Attachments: Description Summary of Proposal ❑✓ 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: 3/25/2015 Commencing Operations: Oil ❑ Gas ❑r WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ El WAG 0 Abandoned 0 Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Email chelgesoni hilcorp.com Printed Name ChadChadHelgeson Title Operations Manager f Signature _�%�/ Phone 907-777-8405 Date 3/LO//5— COMMISSION COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315—I sl Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No IA' Subsequent Form Required: /U ! 47 7e1A...) APPROVED BY 3 Approved by:(0.-D, � COMMISSIONER THE COMMISSION ,y Date: -25.-/s— .- ZS-/' - opRvf N, A ' the d I pp /„�3 2�I� ents i Fop and Form 10 403(Revised 10/2012) I /�"M, id for 12 m0 r m the date of a rOVil. Attachments i Du plicate BD SA, APR - 3 2015 0�3/ 10-.�� . 2c, -/i' Well Prognosis Well: KBU 43-07Y Hilcorp Alaska,LL Well Name: KBU 43-07Y API Number: 50-133-20625-00-00 Current Status: Flowing Gas Well Leg: N/A Estimated Start Date: 3/25/15 Rig: N/A Reg.Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-019 (0) First Call Engineer: Chad Helgeson (907)777-8405(0) (907) 229-4824(C) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 351-8228(M) Current Bottom Hole Pressure: 368 psi @ 9,240'ND flowing (Based on Survey on 3/18/15) Maximum Expected BHP: —2,250 psi @ 9,240 ND (Based on offset wells) Max. Allowable Surface Pressure: — 1,877 psi (Based on actual reservoir conditions and gas gradient to surface(0.10psi/ft) Brief Well Summary: KBU 43-07Y was drilled and completed April 2014. It was perforated originally in June 2015. Additional perforations were made in July 2014. The well started making water, spinner logs confirmed water from the • lower zone(Tyonek D3B). Notes Regarding Wellbore Condition • Well is loaded with fluid to 170' RKB. Current SITP is 205 psi. • Bridge plug at 11,130' possibly leaking. Summary Procedure: Plug Back D-3B Sand in well,currently making water and little to no gas. v E-line Procedure: 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. a. Tree connection is 7"OTIS. 2. SI well. 3. RU 5-1/2" CIBP and GR/CCL tools. 4. RIH and set CIBP at+/-9,780' MD in the 5" 18#casing(set at least 3-5 ft above a casing collar). • 5. POOH. LD setting tool. 6. RU 3"x20' bailer. 7. RIH tag plug and dump bail 5'of cement on tubing plug(4 gallons of cement)to achieve a cement r/ top at 9,775'. POOH. 8. RD E-line 9. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic Kenai Gas Field Well: KBU 43-7Y SCHEMATIC Last Completed:5/14/2014 na ,r,r:v,r.k r.1.1.1: PTD: 214-019 CASING DETAIL RKB:MSL=18.6' Size Type Wt/Grade/Conn ID Top Btm • 16" Conductor N/A Surf 135' 10-3/4' Surface 45.5/L-80/BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surf 6,277' 18, 5" Production 18/L-80/DWC/C-HT 4.276 Surf 9,850' JEWELRY DETAIL No Depth Item -{ 1 5,774' 5"Swell Packer 1.0-3/4" 2 6,561' RA Marker with 5'Pup 3 7,258' RA Marker with 5'Pup 4 9,212' RA Marker with 5'Pup PERFORATION DETAIL t. Sand Top(MD) Btm(MD) Top(TVD) Btm(ND) Ft J D-3C 9,746' 9,766' 9,192' 9,212' 20' D-3B 9,804' 9,824' 9,250' 9,270' 20' OPEN HOLE/CEMENT DETAIL 10-3/4"" 164BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 254BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 156BBL's of cement in 6-3/4"Hole. TOC 5,700 Calculated 7-5/8" 32 3 Tag spent pelf gms a 4 @9,811'/ <Bm 6/262014 , .{ Tyco*63C Tyonek D38 5- TD=9,855'(ND)/9,301'(TVD) PBTD=9,840'(MD)/9,286'(TVD) Updated by DMA 08-11-14 Kenai Y Well: KBUGasFieldY 43 7 • PROPOSED Last Completed: 5/14/2014 Hilcorp Alaska,LII PTD: 214-019 CASING DETAIL RKB:MSI.=18.6' Size Type Wt/Grade/Conn ID Top Btm 16" Conductor N/A Surf 135' • 10-3/4' Surface 45.5/L 80/BTC 9.950 Surf 1,600' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surf 6,277' 16„ 5" Production 18/L-80/DWC/C-HT 4.276 Surf 9,850' F JEWELRY DETAIL ,. li ' No Depth Item • 1 5,774' 5"Swell Packer 10-3/4" 4 11. 2 6,561' RA Marker with 5'Pup 3 _ 7,258' RA Marker with 5'Pup 4 9,212' RA Marker with 5'Pup 5 9,780' CIBP w/5ft of cement PERFORATION DETAIL Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Status • D-3C 9,746' 9,766' 9,192' 9,212' 20' Open D-3B 9,804' 9,824' 9,250' 9,270' 20' Plugged OPEN HOLE/CEMENT DETAIL 10-3/4"" 164BBL's of cement in 13.5"Hole.Returns to Surface 7-5/8" 254BBL's of cement in 9-7/8"Hole.Returns to Surface 5" 156BBL's of cement in 6-3/4"Hole. TOC 5,700 Calculated • , 1 .. 17-5/8" 02 d 3 • ' d 4 5'aF cement Tyanek D3C 5 Tag spent P —___;,* T a36 gunsMire @9,825' Tv n"*.--- on 3/18/2015 5" a to TD=9,855'(MD)/9,301'(TVD) PBTD=9,840'(MD)/9,286'(TVD) Updated by CAH 03-20-15 02/L-/- 0/ c/ Davies, Stephen F (DOA) From: Janise Barrett[jbarrett@hilcorp.com] Sent: Friday, February 14, 2014 2:19 PM To: Davies, Stephen F (DOA) Subject: FW: KBU 43-07Y- Request and Question Steve Please see Luke's notes below—do we need to have GEO update their prog? Thank you! Janise Barrett I Drilling Technician Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage,Alaska 99503 SCANNED tM -� Office: 907-777-8389 Mobile: 907-365-9856 jbarrett@hilcorp.com From: Luke Keller Sent: Friday, February 14, 2014 2:12 PM To: Janise Barrett Subject: RE: KBU 43-07Y - Request and Question Janise, We are running quad combo LWD instead of wireline logs (step 18.6), and R/U mud loggers is mentioned in step (18.3). 1 18.3 RU Mud loggers for the 6-314' 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, nun and set wear bushing. 18.5 Run CBL on 7-5/8" casing. 18.6 PIU 6-3'4" directional drilling assy consisting of: • 6-3/4" PDC bit (Smith MDi613). • Mud Motor (1.18 deg, consult with DD for optimum setting) • Non-Mag Stab (6-5/8" OD) • NMPC • Impulse MWD (D&I, GR,Res) • VDN(Vision DeniNeu) • SonicScope (Sonic) • (3) Non-Mag Flex collars • XO • (5) 4-1:'2" HWDP • Dailey Jar • (15) 4-1/2" HWDP • 4-1/2" DP to surface. From: Janise Barrett Sent: Friday, February 14, 2014 1:31 PM To: Luke Keller Subject: FW: KBU 43-07Y - Request and Question Importance: High Luke, The geologic prognosis notes that quad combo with dipole sonic open-hole wireline logs will be run across the production hole and that section will be mud logged but these are not mentioned in the text of the Drilling Procedure— AOGCC Steve inquires I have already sent him the planned survey. Thank you! Janise Barrett Drilling Technician Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage,Alaska 99503 Office: 907-777-8389 Mobile: 907-365-9856 jbarrett@hilcorp.com 2 From: Davies, Stephen F (DOA) Sent: Thursday, February 13, 2014 5:34 PM To: 'Janise Barrett' Subject: KBU 43-07Y Janise, To speed my review of this Permit to Drill application,could Hilcorp please provide a copy of the proposed directional survey in electronic format (text or Excel spreadsheet)? Please send the data by a method that conforms to Hilcorp's security protocols. Another question: the geologic prognosis notes that quad combo with dipole sonic open-hole wireline logs will be run across the production hole and that section will be mud logged. But I don't see these mentioned in the text of the Drilling Procedure. Or have I missed something? Thanks, Steve Davies AOGCC 907-793-1224 3 Hilcorp Alaska, LLC KBU 43-07Y FINAL WELL REPORT DML LOGGING DATA Provided by: Approved by: Sarah Rittenhouse Compiled by: Larry Resch Michael Strawn C r a i g S i l v a Distribution: 5/12/2014 TD Date: April 15, 2014 KBU 43-07Y 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Well Synopsis. ................................................................................................................................3 2.4 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................6 3.1 Lithostratigraphy .............................................................................................................................6 3.2 Lithologic Details.............................................................................................................................7 3.3 Connection Gases ........................................................................................................................14 3.4 Trip Gases ....................................................................................................................................16 3.5 Sampling Program / Sample Dispatch..........................................................................................16 4 DRILLING DATA..................................................................................................................................17 4.1 Directional Survey Data................................................................................................................17 4.2 Bit Record.....................................................................................................................................21 4.3 Mud Record ..................................................................................................................................22 5 DAILY REPORTS ................................................................................................................................25 Enclosures: 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD KBU 43-07Y 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Mudlogging Unit Computer System Canrig: 3 HP Compaq Workstations (DML, RigWatch, and Sample Catcher) 0 Ditch Gas Canrig: (2) QGM Gas Traps (with High RPM Electric-Powered Agitators) Canrig: E-Series FID THA Analysis and Chromatography. Pason EDR All Drilling Parameters Block Height / Depth Pason WITS Feed Hookload / WOB Pason WITS Feed RPM Pason WITS Feed Torque Pason WITS Feed Return Flow Pason WITS Feed Pit Volumes Pason WITS Feed Mud Gain/Loss Pason WITS Feed Pump Pressure Pason WITS Feed Pump Strokes Pason WITS Feed Rate of Penetration Calculated from Block Position tracking Mud Flow In Calculated from Pump Output/Rate tracking 1.2 Crew Unit Number : ML030 Unit Type : Arctic Steel Skid Unit Mudloggers Years* Days*2 Sample Catchers Years Days*2 Technician Days Larry Resch 13 14 Ishrat Farooqui 6 8 Michael Strawn 8 21 James Adams 1 8 Craig Silva 36 10 Kirk Wallander 4 4 Justin Boutte 2 4 *1 Years of experience. *2 Days at well site. KBU 43-07Y 3 2 WELL DETAILS 2.1 Well Summary Well: KBU 43-07Y API Number: 50-133-20625-00-00 Field: Kenai Beluga Unit Surface Co-Ordinates: 425’ FEL, 552’ FNL Sec. 18, T4N, R11W SM Borough: Kenai Borough Primary Targets: Middle Beluga to Tyonek State: Alaska TD Depth: 9855’ Rig Name / Type: Saxon 147/ Land/ Double Suspension Date: N/A Primary Target: Tyonek Permit to Drill: 214-019 Spud Date: 03/23/2014 Ground Elevation: 66.66’ AMSL Completion Status: RKB Elevation: 85.26 AMSL Classification: Gas Development, Multiple Zone Secondary Targets Sterling to Upper Beluga TD Formation: Tyonek TD Date: April 15, 2014 Days Drilling: 24 Days Testing: N/A 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Wt (ppg) Dev. (oinc) Casing/ Liner MD (ft) TVDSS (ft) FIT (ppg) 29.69 10.75” 1600 1446.55 9.875” 6287’ 5648.04 Beluga 9.7 0.89 7.625” 6277 5638.04 13.5 6.75” 9855’ 9301.00 Tyonek 12.1 1.41 5” 9850 9210.74 2.3 Well Synopsis. KBU 43-07Y is a Multiple Zone Development well off the 41-18 pad in the Kenai Gas Field, which targeted Mid-Lower Beluga and Upper Tyonek Pool reserves on the eastern flank of the field. This well offset several successful field wells, including KBU 41-18X, KBU 24-7X and KBU 11-17X, and will include deeper tests of the 84-6, 86-2, and D-1 Sands. Drilling operations commenced from surface on March 23, 2014, and Total Measured Depth was reached at 9,855’ on April 15, 2014. The well bore is “S”-shaped, its path following a shallow kick off from 266’ MD, a build up to a 32 deg tangent, then a drop initiated at 4,832’ MD that returned to vertical at 5,888’ MD. The Saxon Rig # 147 was used to drill and complete the wellbore. The well will be perforated after the rig has departed. There were no outstanding hole issues during the drilling. All waste and mud generated during the drilling and completion operations was transferred to the Kenai Gas Field G&I Facility, located on the same pad as the well, for disposal or potential beneficial reuse (depending on test results). Surface casing was run to 1600’ MD and cemented to the surface, to ensure that this well isolated any usable ground water KBU 43-07Y 4 2.4 Daily Activity Summary March 29, 2014 Drilling ahead from 2888’ to 3632’, circulating hole clean, pumping sweep, pulling out of hole from 3632’ to shoe working tight spots at 2568’ and 2023’, servicing rig, tripping in hole from shoe to 3632’, Drilling ahead from 3632’ to 4773’ at report time. Max gas last 24 hours 569 units at 4686’ connection. March 30, 2014 Drilling ahead sliding as needed from 4773’ to 4935’MD, circulating hole clean, pulling out of hole from 4935’ to 1590’, servicing rig, tripping to bottom, trip gas 260u, drilling ahead sliding as needed from 4935’ to 5568’MD. Max gas last 24 hours 416 units at 5447’MD. March 31, 2014 Drilling ahead from 5568’ to 6287’MD, circulating to clean hole, pulling out of hole from 6287’ to 4590’MD reaming tight spots from 5497’ to 5150’MD. Max gas last 24 hours 612 units at 5908’MD. April 1, 2014 Pulling out of hole from 4590’ to 1522’MD, cutting and slipping drill line, tripping in hole from shoe to bottom, circulating bottoms up and pumping hi-viscosity sweep, starting pulling out of hole from 6285’ to 420’MD. Max gas last 24 hours 120 units trip gas. April 2, 2014 Pulling out of hole from 420’ and laying down BHA, download MWD data, pulling wear ring, picking up and testing 7.625” landing joint, changing and testing pipe rams, laying down bales, guide and elevators, rigging up CRT, started running 7.625” casing to 4278’ at report time. April 3, 2014 Running 7.625” casing from 4278’ to 6283’, circulating and conditioning mud, rigging up cement crew, pumping cement, rigging down casing equipment, installing pack off, removing landing joint, changing upper rams, rigging up test equipment and starting to test BOP’s. April 4, 2014 Testing BOP’s and attempting to test BOP’s. April 5, 2014 Rigging up wireline tools, running cement bond logs, changing out and testing choke, rigging up test equipment and testing casing, testing BOP’s, rigging down test equipment, installing wear bushing and elevators, service rig, picking up BHA and tripping in hole to 6186’, circulating at report time. April 6, 2014 Tagging float collar at 6186’MD, drilling shoe and 20’ of formation to 6307’MD, displacing mud, performing FIT, pulling out of hole, laying down BHA, picking up new BHA, tripping in hole and drilling ahead from 6307’ to 6466’MD. Max gas last 24 hours 79 units. April 7, 2012 Drilling ahead sliding as needed to maintain vector from 6466’ to 7819’MD, circulating to clean hole, pulling out of hole from 7819’ to 6565’MD at report time. Max gas last 24 hours 812 units at 7712’MD. April 8, 2014 Pulling out of hole from 6565’ to inside shoe at 6269’MD, servicing rig, tripping in hole to 7819’, drilling ahead sliding as needed to maintain vector from 7819’ to 9129’ at report time. Max gas last 24 hours 1960 units at 8688’ connection. KBU 43-07Y 5 April 9, 2014 Drilling ahead from 9129’ to 9308’MD, circulate and condition mud, weighting up mud to 11.3ppg in and out, flow checking well, pulling out of hole to shoe at 6205’MD, servicing rig, tripping in hole from 6205’ to 8063’MD, circulating and condition mud at report time. Max gas last 24 hours 2299 units at 8063’. April 10, 2014 Tripping in hole from 8063’MD to bottom, circulating and conditioning mud (wiper gas 2299u), drilling ahead from 9308’ to TD at 9835’MD, circulating and conditioning mud, pulling out of hole to 7753’MD, tripping in hole to bottom, circulating and conditioning hole (wiper gas 2380u). Max gas last 24 hours 2380 units wiper gas @ 9835’. April 11, 2014 Circulating and conditioning mud, pumping slug, pulling out of hole to 7819’ and circulating, pulling out of hole and laying down BHA, rigging up wireline crew, running wireline, pulling out of hole with survey tools. Max gas last 24 hours circulating @ 7819’MD. April 12, 2014 Pulling out of hole with wireline tools and rigging down wireline, picking up BHA #RR4 and tripping in hole to bottom circulating at 685’ 450u, 1978’ 2061u, 4086’ 2039u, 6134’ 2077u, 7807’ 1870u, 8747’ 1980u, and 8865’ 2364u, weighting up mud to 11.9ppg and tripping in hole to TD at 9835’, circulating and conditioning mud 1238u peak gas. Max gas last 24 hours 2364 units circulating at 8865’MD. April 13, 2014 Circulating and conditioning mud, pull out of hole from 9835’ to 6153’, cut and slip drill line and change out saver sub, trip in hole to 9773;, wash and ream from 9773’ to 9835’, circulate and condition mud max gas 1262 units, check flow, pull out of hole from 9835’ to 2597’MD. Max gas last 24 hours 1262 units trip gas. April 14, 2014 Pulling out of hole from 2597’ to surface, rigging up and running wireline survey, running in hole for second wireline, running wireline at report time. Max gas last 24 hours 3 units. April 15, 2014 Finished running wireline survey, rigging down wireline crew, testing BOP’s, picking up BHA and running in hole to 6267’, circulating bottoms up peak gas 95u, running in hole to 8400’, circulating bottoms up peak gas 944u, running in hole to bottom circulating bottoms up peak trip gas 1328u, drilling ahead from 9835’ to 9845’, circulating bottoms up, drilling ahead from 9845’ to 9855’, circulating bottoms up, still circulating at report time. April 16, 2014 Circulating and conditioning mud, Checking flow and servicing rig, pulling out of hole to 6273’ laying down pipe, monitoring well, pulling out of hole to 1807’ laying down pipe, running in hole to 6460’ out of derrick, pulling out of hole laying down pipe, laying down BHA at report time. Max gas last 24 hours 23 units circulating at 9855’. April 17, 2014 Servicing rig, rigging up to run casing, running 5” 18ppf casing from surface to 6249’, circulating, continue to run in hole with casing to 7601’MD. Max gas last 24 hours 101 units circulating at 6249’ April 18, 2014 Running in hole with 5” 18ppf casing to 9849’MD, circulating and conditioning mud max gas 842units, rigging up cement crew, pressure testing cement lines, pumping 4.2bbls 13.5ppg cement, spacer and 158.8bbl 15.7ppg slurry and 176bbls and 176 bbls of 8.6ppg brine, bump plug and hold pressure, rig down cement crew, servicing rig and preparing for rig move. . KBU 43-07Y 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops were provided by Hilcorp geologist Sarah Rittenhouse. OBSERVED Alternative Tops FORMATION TOPS MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Sterling_A0 2460 2276 -2191 2460 2276 -2191 A1 2550 2353 -2267 2550 2353 -2267 A2 2651 2440 -2354 2651 2440 -2354 A3 2868 2626 -2541 2868 2626 -2541 A4 3192 2908 -2823 3192 2908 -2823 A5 3343 3040 -2954 3343 3040 -2954 A6 3694 3347 -3262 3694 3347 -3262 A7 3769 3413 -3327 3769 3413 -3315 A10_(POOL_3) 4026 3634 -3548 4026 3634 -3536 A11_(POOL_3) 4077 3677 -3592 4077 3677 -3592 B1_(POOL_4) 4296 3865 -3780 4296 3865 -3780 B2_(POOL_4) 4341 3904 -3818 4341 3904 -3818 B3_(POOL_5_1) 4415 3967 -3882 4415 3967 -3882 B4_(POOL_5_1) 4481 4024 -3939 4481 4024 -3939 B5_(POOL_5_2) 4685 4202 -4117 4685 4202 -4117 C1_(POOL_6) 5010 4488 -4403 5010 4488 -4403 C2_(POOL_6) 5097 4567 -4481 5097 4567 -4469 Upper Beluga 5167 4632 -4546 5270 4728 -4643 Middle Beluga 5858 5304 -5219 5690 5137 -5052 Lower Beluga 6580 6027 -5941 6678 6124 -6039 Beluga ->Tyonek 7340 6786 -6701 7340 6786 -6701 Tyonek, Upper 7701 7147 -7062 7701 7147 -7062 72-8 7753 7199 -7114 7778 7224 -7139 73-1 7823 7269 -7184 7830 7276 -7191 75-8 8069 7515 -7430 8078 7524 -7439 UP2A_T 8135 7581 -7495 8135 7581 -7495 76-7 8189 7636 -7550 8189 7636 -7550 84-6 Sand 8958 8404 -8318 8958 8404 -8318 86-2 Sand 9124 8570 -8485 9124 8570 -8485 D-1 Sand 9275 8721 -8636 9275 8721 -8636 D-2 9443 8889 -8804 9449 8895 -8810 D-3 9655 9101 -9016 9610 9056 -8971 D3_D 9682 9128 -9043 9682 9128 -9043 D3_C 9723 9169 -9083 9720 9166 -9080 D3_B 9779 9225 -9140 9779 9225 -9140 D3_A 9820 9266 -9181 9820 9266 -9181 Total Depth 9855 9301 -9216 9855 9301 -9216 D-4 (Projected) 9883 9329 -9244 9883 9329 -9244 KBU 43-07Y 7 3.2 Lithologic Details Tuffaceous Claystone, Tuffaceous Siltstone (4950' to 4980') = light gray to very light gray, light bluish gray, occasionally yellowish gray; brittle to firm, pulverulent; irregular fracture; slightly tabular cuttings habit; dull to subwaxy in part; generally smooth, slightly silty in part; noncalcareous; generally massive with subplaty, layered organic microlamina common. Conglomeratic Sand, Conglomerate, Pebbles (4980' to 5130') = loose sand, pebbles and fragments; upper very fine to lower medium grain, medium to coarse grain common; subangular to subrounded in part; subdiscoidal, rarely subprismoidal; fair sorting; no evidence of consolidation or cementation; minor highly soluble clay component seen at shaker; dominantly translucent, very light gray to light gray, grayish white quartz with locally abundant transparent volcanic glass clasts; secondary lithics are dark gray to grayish black, light greenish gray; occasionally locally abundant reddish orange mafic minerals; note rounded subdiscoidal coarse to very coarse grains; 10-30% very coarse rounded fragments with impact-fractured surfaces; note trace poorly cemented sandstone at top of interval; section displays indication of an upward fining sequence. Conglomeratic Sand, Conglomerate, Carbonaceous Shale (5130' to 5190') = light gray to bluish white with dark gray clasts; brittle crunchy tenacity; nodular cuttings; irregular fracture; fine to medium moderately well subangular to subrounded quartz grains with trace calcareous cementation and shaley clasts; conglomerate pebble like nodules with silty shaley composition; some loose sand and carbonaceous shale; translucent to vitreous luster; gritty texture; dull mineral fluorescence in conglomerate. Conglomeratic Sand, Sand, Carbonaceous Shale (5190' to 5280') = light gray to bluish white with dark gray clasts; brittle crunchy tenacity; nodular cuttings; irregular fracture; fine to medium moderately well sorted subangular to subrounded quartz grains with trace calcareous cementation and shaley clasts; conglomerate pebble like nodules with silty shaley composition decreasing in sample interval; some loose sand and carbonaceous shale; translucent to vitreous luster; gritty texture. Conglomeratic Sand, Sand, Carbonaceous Shale (5280' to 5340') = light gray to bluish white with dark gray brown clasts brittle crunchy tenacity; nodular to tabular cuttings; irregular fracture; fine to medium moderately well sorted subangular to subrounded quartz grains with trace calcareous cementation and shaley clasts; some loose sand and carbonaceous shale; translucent to vitreous luster, earthy in shale; gritty texture Conglomeratic Sand, Sand, Carbonaceous Shale (5340' to 5430') = light gray to bluish white with dark gray brown clasts brittle crunchy tenacity; nodular to tabular cuttings; irregular fracture; fine to medium moderately well sorted subangular to subrounded quartz grains with trace calcareous cementation and shaley clasts; some loose sand and carbonaceous shale; translucent to vitreous luster, earthy in shale; gritty texture. Conglomeratic Sand, Sandstone, Carbonaceous Shale (5430' to 5520') = light gray to very light gray with dark gray brown clasts; brittle crunchy tenacity; nodular to cuttings; irregular fracture; very fine to medium moderately well sorted subangular to subrounded quartz grains with trace calcareous cementation and shaley clasts; some loose sand and carbonaceous shale; sandstone very fine close packed subrounded quartz grains with calcareous cementation; translucent to vitreous luster; earthy in shale; gritty texture; no fluorescence. Conglomeratic Sand, Carbonaceous Shale, Siltstone, Sand (5520' to 5610') = light gray to gray brown with light bluish gray; soft to firm crumbly tenacity; nodular cuttings habit; irregular to pulverulent fracture; very fine to medium grain; moderately well sorted subangular to subrounded quartz grains with trace calcareous cementation and shaley clasts in conglomeratic sand decreasing through sample interval; carbonaceous shale decreasing and becoming argillaceous with depth; crumbly blue gray siltstone increasing through interval; vitreous to earthy luster silty to slightly gritty texture. KBU 43-07Y 8 Siltstone, Tuffaceous Sand, Conglomeratic Sand (5610' to 5670') = light gray to gray brown with light bluish gray; soft to firm crumbly tenacity; nodular cuttings habit; irregular to pulverulent fracture; very fine to medium moderately well sorted subangular to sub-rounded quartz grains with poor calcareous cementation and shaley clasts in conglomeratic sand; crumbly blue gray siltstone; sand increasing; vitreous to earthy luster silty to slightly gritty texture. Tuffaceous Claystone (5670’ to 5730’) = light gray to gray brown with light bluish gray; soft to firm; crumbly tenacity; rounded irregular habit; pulverulent; very fine to medium moderately well sorted subangular to subrounded quartz grains with poor calcareous cementation, shaley clasts in conglomeratic sand; crumbly bluish gray siltstone; sand increasing; earthy luster silty to slightly gritty texture. Conglomeratic Sand, Loose Sand (5730' to 5790') = bimodal; upper very fine to lower fine grain, medium to lower coarse grain; subangular to subrounded; subdiscoidal; moderate sorting within modality; no evidence of cementation; interval contains minor component of highly soluble weathered devitrified ash/ tuff; dominantly milky grayish white to very light gray and light gray quartz; secondary clasts are dark gray to grayish black; note trace carbonaceous clasts/ poorly developed sublithic coal. Tuffaceous Claystone (5790' to 5910') = light gray to light bluish gray, very light gray, occasionally slightly brownish gray; firm; crumbly, pulverulent; no definable fracture; cuttings generally tabular to nodular with well rounded edges; dull to subwaxy, occasionally earthy; generally smooth, nongritty to slightly silty in part; no apparent structure; hydrophobic; noncalcareous; occasional thin platy carbonaceous microlayers; locally grades towards an organic claystone/ sublithic coal. Carbonaceous Shale, Coal (5910’ to 5940') = very dark gray to brownish black, often brownish gray, pale yellowish brown with abundant black carbonaceous component; varies from firm to soft; generally earthy; occasionally platy, subfissile; common carbonaceous laminations and particles in argillaceous claystone. Sand, Conglomeratic Sand (5940' to 6030') = 90% loose sand, 10% poorly consolidated argillaceous sandstone; upper very fine to fine grain; subrounded to subangular; subdiscoidal; moderate to well sorted in part; no evidence of cementation; consolidated sand supported by very light gray to grayish white devitrified ashy/ argillaceous matrix; grades towards a sublithic arenite in part; overall sample color is light gray with very light gray, grayish white slightly translucent quartz; minor secondary medium dark gray to medium gray lithics; note well rounded lower coarse pebbles, pebble fragments; trace to rare transparent volcanic glass clasts. Tuffaceous Claystone, Tuffaceous Siltstone (6030' to 6120') = light gray to medium light gray, often with slight bluish hue, light bluish gray; firm but yields easily when probed; dense yet brittle, crumbly, pulverulent; no definable fracture, structure or bedding; subwaxy, dull in part; noncalcareous; hydrophobic; nodular to slightly tabular cuttings habit, often with well rounded edges; generally smooth, nonabrasive; locally silty to sandy in part; some cuttings are soft, mushy with well entrained sand grains; grades towards a tuffaceous sandstone in part; note very fine interbedded carbonaceous material, poorly developed sublithic coals. Loose Sand, Conglomeratic Sand (6120' to 6210') = overall sample color is light gray to medium light gray; upper very fine to fine grain, medium to lower coarse grain common; subrounded to subangular; subdiscoidal; moderate to well sorted; note very coarse well rounded intact pebbles and pebble fragments displaying high impact fracture surfaces; no discernible cementation; quartz dominant with minor non-differentiated medium gray lithics; note thinly bedded carbonaceous claystone, moderately developed coal. Tuffaceous Sandstone, Tuffaceous Claystone (6210' to 6287') = medium light gray to medium gray, often with slight bluish hues; loose fine sand grades to tuffaceous sand with well distributed grains in argillaceous matrix; quartz component grades to smooth, nonabrasive/ nongritty claystone; traces of interbedded coal. Tuffaceous Sandstone, Tuffaceous Claystone (6287’-6360’) = gray to light gray color; soft to firm crumbly tenacity; irregular habit; irregular sometimes planar fracture; massive poorly cemented mostly clay-like tuft with sandy beds; sandy beds have sub-angular to sub-rounded well sorted medium to upper fine poorly cemented quartz grains; traces of carbonaceous shale or lignite in some samples; smooth to gritty texture; earthy luster. KBU 43-07Y 9 Tuffaceous Sandstone, Tuffaceous Claystone (6360’-6440’) = light gray to gray color; soft crumbly tenacity; nodular cuttings habit; irregular to planar fracture; massive poorly consolidated mostly clay-like tuft with sandy beds; sandy beds have sub-angular to sub-rounded well sorted medium to upper fine poorly cemented contact supported quartz grains in a silty matrix; slightly gritty texture; earthy luster; no oil indicators. Tuffaceous Sandstone, Tuffaceous Claystone (6440’-6500’) = gray to light gray color; soft to firm crumbly to brittle tenacity; nodular cuttings habit; irregular to earthy fracture; massive poorly cemented mostly clay-like tuft; some sandy beds; sandy beds decrease through this section and are composed of sub-angular to sub- rounded well sorted medium to upper fine poorly cemented matrix supported quartz grains in a silty matrix; slightly gritty texture; earthy luster; no degassing or fluorescence. Tuffaceous Sandstone, Tuffaceous Claystone (6500’-6560’) = light gray to gray color; soft crumbly to crunchy tenacity; nodular cuttings habit; irregular to planar fracture; massive poorly cemented powdery ash- like tuft matrix supporting sand; sand is sub-angular to sub-rounded well sorted medium to upper fine poorly consolidated quartz grains in a silty matrix; slightly gritty texture; earthy luster; no oil indicators. Tuffaceous Sandstone, Tuffaceous Claystone (6560’-6620’) = light gray to gray; soft crumbly to crunchy tenacity becoming firm in places; nodular cuttings habit; irregular to earthy fracture; massive poorly consolidated clay-like tuft with sandy clasts; sandstone is sub-angular to sub-rounded well sorted medium to upper fine quartz grains; slightly gritty texture; earthy luster; traces of small dark gray bladed glass clasts. Tuffaceous Sandstone, Tuffaceous Claystone (6620’-6700’) = very light gray to gray color; soft crumbly to crunchy tenacity; nodular cuttings habit; irregular occasionally planar fracture; sandstone is thick bedded sub- angular to sub-rounded well sorted medium to upper fine poorly cemented contact supported quartz grains in a silty matrix; claystone is poorly cemented ash-like tuft with sandy and shaley clasts; traces of very thin dark gray brown coal in some samples; slightly gritty texture; earthy luster; no oil indicators. Tuffaceous Claystone, Tuffaceous Sandstone (6700’-6780’) = medium gray to light gray; soft to firm crunchy tenacity; nodular cuttings habit; earthy to irregular fracture; claystone is massive poorly consolidated clay-like tuft with shaley clasts; sandstone is sub-rounded to sub-angular well sorted medium to upper fine poorly cemented contact supported quartz grains in a silty matrix; traces of flakey dark gray brown coal in some samples; slightly gritty texture; earthy luster; low apparent visual porosity. Tuffaceous Claystone (6780'-6840') = light gray with slight bluish hue, light bluish gray to medium light gray; firm; malleable, pulverulent in part; no definable fracture, structure or bedding habit; irregular to tabular cuttings habit, generally with well rounded edges; dull, rarely subwaxy; silty to sandy in part; noncalcareous; occasionally soft, mushy with well entrained, evenly distributed carbonaceous detrital clasts; note rare micro- fine carbonaceous streaks, flakes. Tuffaceous Sandstone (6840'-6940') = up to 40% loose or dissagregated sand; poorly consolidated sand is medium gray; lower fine to upper very fine grain, upper fine grain common; subrounded to subangular; discoidal to subdiscoidal; moderate to well sorted; no evidence of cementation; poorly entrained in soft, mushy tuffaceous/ argillaceous matrix; very light gray, grayish white, opaque light gray quartz dominant; dark gray to grayish black clasts common; with locally interbedded soft to slightly firm tuffaceous claystone; note occasional carbonaceous shale/ poorly developed sublithic coal. Tuffaceous Sandstone, Tuffaceous Claystone (6940'-7040') = loose sand decreasing through interval; medium gray to medium light gray; lower fine to upper very fine; subrounded to subangular; well to moderately well sorted; discoidal to subdiscoidal; noncalcareous; grain supported to matrix supported with pulverulent tuffaceous-argillaceous matrix; no visible porosity; also arenaceous claystone with abundant floating quartz, dark gray and grayish black lithics, carbonaceous detritus; with massive nonabrasive nongritty pulverulent tuffaceous claystone; minor interbedded low grade coal/ organic rich claystone/carbonaceous shale. KBU 43-07Y 10 Tuffaceous Sandstone, Tuffaceous Claystone (7040'-7140') = medium gray to medium light gray; lower fine to upper very fine; subrounded to subangular; well sorted; noncalcareous; grain supported in part with significant weathered tuffaceous/argillaceous fill; matrix supported; lithic to sublithic arenite; quartz dominant with <30% dark gray to grayish black secondary lithic components; claystone often massive, smooth, nongritty, pulverulent, moderately firm to firm; noncalcareous; dull to subwaxy in part; no fracture, bedding or structure; tabular to irregular cuttings habit, generally with rounded edges; trace carbonaceous detritus. Tuffaceous Claystone (7140'-7240') = medium gray to medium light gray; occasionally pale yellowish brown; moderately firm to firm; malleable, sectile, pulverulent in part; massive; no definable fracture, structure or bedding; tabular habit; subwaxy to dull, some slightly sparkly with slight silt-sand component ; noncalcareous; hydrophobic; trace bitumen wisps, streaks, stain; also earthy, slightly silty with slight to strong carbonaceous component; grades to organic claystone/carbonaceous shale; note very shaley, platy to subfissile coal. Tuffaceous Claystone, Carbonaceous Shale (7240'-7300') = medium dark gray to medium gray, medium dark gray to dark gray to grayish black, occasionally brownish gray to pale yellowish brown; lighter colored claystone is generally massive, firm, slightly crumbly in part; nodular cuttings habit with well rounded edges, no definable fracture, structure or bedding; darker gray clay- stone exhibits varying amounts of organic/ carbonaceous material often seen as streaks, platy fragments, micro fine layering; as organic component increases samples become platy to sub-fissile resembling a dull carbonaceous shale/ shaley coal. Tuffaceous Sandstone (7300'-7360') = up to 30% loose or dissagregated sand; overall sample is medium dark gray to medium gray, becoming medium light gray in part; upper very fine to lower fine grain; well sorted; subrounded; discoidal to subdiscoidal; non- calcareous; grain supported equally represented with matrix supported; quartz dominant with minor dark gray to grayish black secondary lithics; no visible porosity. Tuffaceous Claystone, Carbonaceous Shale (7360'-7460') = medium dark gray to medium gray, dark gray to grayish black in part; firm; crumbly, pulverulent, slightly crunchy in part; some subwaxy with increased tuffaceous component; often platy to subfissile, occasionally earthy, varying organic/carbonaceous content. Tuffaceous Sandstone, Tuffaceous Claystone (7460'-7520') = medium dark gray to medium gray; upper very fine to lower fine grain; subrounded; dischoidal; well sorted; noncalcareous; poorly consolidated with significant tuffaceous/ argillaceous matrix; varies from matrix supported to grain supported ; note 20-30% loose or disaggregated sand; quartz dominant with minor grayish black secondary lithics; commonly a sublithic arenite; organic claystone, carbonaceous shale and shaley coals continue to be interbedded. Tuffaceous Claystone, Tuffaceous Sandstone (7520-7600’) = gray to dark gray brown color; firm to soft crumbly tenacity; nodular to platy cuttings habit; irregular fracture; massive; poorly consolidated ashy tuff grading to medium sub-angular to angular matrix supported sandstone in places with thin 1-3mm stringers of coal; glassy volcanic clasts common; smooth silty to slightly gritty texture; earthy luster; low visual porosity. Tuffaceous Claystone (7600’-7660’) = gray to gray brown color with some reddish brown hues: soft to some firm crumbly tenacity; nodular to some blocky cuttings habit; irregular to earthy fracture; massive; floating quartz and grayish black volcanic glass clasts; thin coal beds and traces of carbonaceous shaley stringers present; smooth to slightly gritty texture; earthy luster; no oil indicators present. Tuffaceous Claystone, Coal (7660’-7720’) = gray to dark gray brown; soft crunchy to pulverulent tenacity; sub blocky to platy habit; earthy to irregular fracture; massive with thin interbedded coal; common coal-like shaley clasts; some grayish black chert and quartz sand clasts; smooth to slightly gritty texture; earthy luster. Tuffaceous Claystone, Coal (7660’-7720’) = gray to dark gray brown; soft crunchy to pulverulent tenacity; nodular to platy cuttings habit; earthy to irregular fracture; thick to massive structure with thin interbedded coal; coal-like shaley clasts common with some grayish black volcanic glass clasts and some quartz sand clasts present; smooth to slightly gritty texture; earthy luster; no degassing when wet. KBU 43-07Y 11 Tuffaceous Claystone (7720-7819) = medium gray color with reddish brown hues; soft to firm mostly pulverulent tenacity; nodular to platy cuttings habit; earthy fracture; massive bedded structure grading from ashy to sandy beds; interbedded with thin coal beds; sand clasts common in some beds; small earthy shaley clasts and glassy clasts present; smooth to slightly gritty texture; earthy luster; low apparent visual porosity. Tuffaceous Claystone (7820’-7880’) = light to medium gray color with light brownish gray to reddish brown beds; soft to firm crumbly to pulverulent tenacity; nodular to some tabular cuttings; earthy to some irregular fracture; massive bedded structure mostly silty looking tuff with shaley clasts common grading to beds with sandy clasts; interbedded with some thin brownish black coal beds; smooth visual texture; earthy luster. Tuffaceous Claystone (7880’-7940’) = light to medium gray with some light reddish brown hues; firm to soft crumbly to pulverulent tenacity; tabular to wedge habit; blocky planar fracture; thick bedded structure with coal- like to sandy clasts in a poorly consolidated ashy tuff; traces thin coal beds; slightly gritty texture; earthy luster. Tuffaceous Claystone (7940'-8020') = light gray to light medium gray with occasional brownish hues, pale yellowish brown; firm; crumbly, malleable, rarely pulverulent; irregular, slightly earthy fracture; tabular to nodular cuttings habit; subwaxy to waxy luster in part, often dull to very slightly sparkly when slightly silty, sandy; micro fine carbonaceous layering and streaks common; occasional fine carbonaceous stringers; note carbonaceous shale, lithic coal; no visible outgassing. Tuffaceous Sandstone (8020'-8120') = very light gray to grayish white with occasional yellowish gray hues; fine grain, occasionally upper very fine; subangular to subrounded; subdiscoidal, rarely subprismoidal; moderately well sorted; noncalcareous; poorly consolidated; grain supported with minor ashy/ tuffaceous/ argillaceous matrix and clay fill; trace to fair visible porosity; up to 30% loose or dissagregated sand; very light gray to grayish white, opaque quartz dominant; note translucent well rounded volcanic glass clasts, very fine sharp glass shards; <20% secondary dark gray to grayish black lithics; occasional thin arenaceous claystone interbedding; note trace interbedded carbonaceous shale, lithic coal. Tuffaceous Sandstone (8120'-8260') = grayish white to very light gray, rarely light gray, occasionally yellowish gray; dominantly fine grain with very minor upper very fine and lower medium grain; subangular to subrounded; moderate to well sorted; noncalcareous; friable; poor to fair consolidation; grain supported with devitrified ash/ weathered tuff matrix and clay fill; trace to fair visible porosity; grayish white, milky, opaque quartz dominant; locally abundant translucent volcanic glass clasts, rare glass shards; 10-20% dark gray to grayish black secondary lithic component; note continued minor interbedded carbonaceous shale/ shaley coal. Tuffaceous Claystone, Tuffaceous Siltstone (8260'-8340') = medium light gray to light gray, light bluish gray, pale yellowish brown; moderately firm to firm; massive, malleable to pulverulent with increased tuffaceousness; also crumbly, earthy; no definable fracture, structure or bedding; tabular cuttings, often nodular with well rounded edges; waxy to subwaxy, smooth and nonabrasive; also dull, earthy, slightly silty to sandy in part; ashy/ tuffaceous clays generally clean with little or no organic component; earthier, more silty sediments generally contain varying amounts of carbonaceous streaks, flakes, occasional bitumen stain; locally grades towards an earthy coal/ carbonaceous shale/ lithic coal; trace slight visible outgassing observed. Tuffaceous Sandstone, Tuffaceous Claystone (8340'-8480') = grayish white to very light gray, with slight yellowish brown to pale yellowish brown hues; upper very fine to fine; subangular to subrounded; subdiscoidal; well to moderately sorted; non to very slightly calcareous; friable, brittle; dominantly grain supported with weathered ash, clay fill; also grades to sandy-silty arenaceous claystone; grayish white, very light gray opaque quartz dominant with translucent to transparent clasts common; 10-15% dark gray to grayish black secondary lithics; claystone commonly sandy to silty, earthy in part with varying carbonaceous material; carbonaceous shale and lithic coals continue; coals are becoming increasingly better developed; dull grayish black to subvitreous glossy black; moderately hard; platy to fissile, becoming more massive, dense with Birdseye/ subconchoidal fracture; steady degassing bubbles observed between platy layers. KBU 43-07Y 12 Tuffaceous Sandstone (8480'-8580') = pale yellowish brown, light gray with brownish hues; vine to upper very fine grain; subangular to subrounded; sub- dischoidal; fair to moderate sorting; brittle to friable; very slightly calcareous; grain supported in part with abundant weathered ash/ argillaceous matrix and clay fill; poor to fair visible porosity; note up to 20% loose or dissagregated sand in some samples; quartz dominant sand with minor secondary lithics; very ashy in part grading towards an ash stone/ sublithic arenite; silty to earthy claystone continues; note continued interbedded carbonaceous shale, coal. Carbonaceous Shale, Coal (8580'-8620') = dark gray to grayish black to black; shaley material displays a dull, matte finish; tough yet brittle breaking easily along linear plans; irregular to splintery fracture, occasionally earthy; coal has become more dense, massive; subvitreous to vitreous; hackly with Birdseye/ subconchoidal fracture common; note significant increase in very fine, vigorous outgassing. Tuffaceous Sandstone (8620’-8720’) = light to medium gray with yellowish hues; soft to firm crumbly tenacity; nodular cuttings habit; irregular fracture; massive bedded structure grading to silty tuff; medium to fine sub-angular to sub-rounded matrix supported quartz grains in a tuff matrix with dark glassy to shaley clasts common; interbedded with thin to thick grayish black to brownish black coal; slightly gritty texture; earthy luster; active degassing in coal beds. Tuffaceous Claystone, Coal (8720’-8780’) = light gray to grayish brown color; soft sometimes firm crumbly to crunchy tenacity; nodular to tabular cuttings habit; irregular to planar fracture and sub-conchoidal fracture in coal; thick bedded to massive poorly welded structure interbedded with grayish black to black coal and some brownish gray carbonaceous beds; slightly gritty texture; earthy luster. Tuffaceous Sandstone, Coal (8780’-8860’) = light to medium gray with yellowish gray hues; soft crumbly tenacity; nodular cuttings habit; irregular to planar fracture; thick bedded structure grading to silty tuffaceous claystone in places; medium to fine sub-angular to sub-rounded matrix supported quartz grains in a silty ash matrix with dark gray glassy and shaley clasts; interbedded with grayish black to brownish black coal; slightly gritty texture; earthy luster. Tuffaceous Claystone, Tuffaceous Sandstone (8860’-8940’) = medium light gray to very light gray color with light brownish gray hues; soft crumbly to crunchy tenacity; planar to nodular cuttings habit; planar to irregular fracture; thick to thin bedded structure; lower medium to fine moderately well sorted sub angular matrix supported quartz grains an a silty looking matrix; grades to contact supported in some beds; earthy to vitreous luster; slightly gritty texture; significant coal interbedding in later portion of sample interval. Tuffaceous Sandstone (8940’-9020’) = very light gray to light gray color; soft crumbly to sometimes crunchy tenacity; nodular to platy cuttings; irregular to earthy fracture; thick to massive bedding of fine to very fine sub rounded to sub angular well sorted contact supported quartz grains in a crumbly ash matrix alternating with poorly consolidated fine ash tuff with glassy volcanic clasts; earthy to vitreous luster; slightly gritty texture. Tuffaceous Claystone (9020’-9080’) = very light gray to medium gray with light brownish gray beds; mottled appearance; mostly soft crumbly tenacity with some crunchy beds; nodular to tabular cuttings habit; irregular to earthy fracture; thick to massive bedded structure becoming sandy in places; some interbedding with grayish black to black coal; vitreous to earthy luster, slightly gritty visual texture; vigorous degassing in coal. Tuffaceous Sandstone, Coal (9080’-9160’) = very light to medium gray color with mottled appearance; soft crumbly to crunchy tenacity; irregular fracture; thick bedded structure of very fine sub-rounded to sub-angular moderately well sorted quartz grains in a tuffaceous matrix interbedded with black to grayish black coal; sub- conchoidal to tabular coal fracture and active degassing; gritty texture; vitreous luster is earthy when dry. Tuffaceous Sandstone (9160’-9240’) = light gray to medium gray with yellowish gray hues; soft crunchy to pulverulent tenacity; wedge to tabular cuttings habit; irregular fracture; some planar separation; massive to thinly bedded; very fine to fine sub angular to sub rounded matrix supported quartz grains in a volcanic ash matrix; common carbonaceous shaley clasts; floating black to brownish black coal; some degassing in coal; gritty visual texture; vitreous to earthy luster; low apparent visual porosity. KBU 43-07Y 13 Tuffaceous Sandstone, (9240’-9300’) = light gray to very light gray color with light brownish gray hues; soft crumbly to pulverulent tenacity; nodular cuttings; irregular to earthy fracture; massive bedded structure with coal present in some samples; very fine to some fine well sorted sub rounded quartz grains in a poorly consolidated tuffaceous matrix; gritty texture; vitreous luster. Tuffaceous Sandstone (9300’-9380’) = very light to light gray color with mottled appearance; soft pulverulent tenacity becoming crumbly when dry; curved PDC to nodular cuttings habit; mostly earthy fracture; thick to massive bedded poorly consolidated structure with carbonaceous shaley looking clasts in some beds; traces of coal in samples with connections indicating float from back reaming; vitreous to earthy luster; slightly gritty visual texture; no fluorescence. Tuffaceous Sandstone (9380’-9490’) = light gray to very light gray color with some light brown gray hues;; firm crumbly tenacity; blocky to curved cuttings; earthy fracture; massive structure; very fine sub-rounded to sub-angular matrix supported grains in a silty looking ash matrix with some larger shaley looking clasts giving a mottled appearance; grades to contact support on some beds; slightly gritty texture; vitreous luster. Coal (9490'-9720') = black to brownish black; often shiny black overall appearance; high grade lignite to sub bituminous; smooth to very dense matte texture; dull to prominent resinous and vitreous luster; dominant irregular blocky fractures with fairly flat separation surfaces; also abundant sub splintery fracture and subplaty fracture; occasional (to locally common subconchoidal to conchoidal fracture; brittle and fragile to brittle and tough to marginally hard; note that "shinier" coals are harder; occasional discernible zoning or banding with different coal grades; some separation along coal grade boundaries; locally common with dark yellow to slightly "reddish yellow" resinite (amber); most coals display and often rapid degassing; some of the degassing is strong enough to "pop" along micro fractures. Tuffaceous Sandstone (9500'-9835') = note that most very closely gradational a sandy "ashstone"; major sections of the tuffaceous sandstone have greater matrix volume than percentage of sand grains; note that the matrix is often complex, with inclusive shards that are very fine sand-sized; almost all sands appear to be fluvially re-distributed air fall ash; most of the tuffaceous sandstone displays very subtle laminar zonation that can be represented as slight color changes, faint alternating of colors, changes in lightness value, lineations of similar sized grains, differences in the packing of grains, differences in mineral alteration, differences in contrast of (red-black-gray) mineral groupings, grain size differentiation, or subtle variations in devitrification,. Tuffaceous Sandstone (9500'-9855') = overall light gray with abundant to pervasive very light gray to white flecks; occasionally has mottled appearance when low lightness value medium light gray to medium gray "less ashy" sandstone is present; very fine lower to coarse upper range; note that matrix grains/shards/particles are often very fine lower to very fine upper and well distributed throughout the clay-silt sized ash; most sand is moderately well sorted at fine lower to medium lower; occasionally appears subtle fining upward in massive sands; very dominant matrix supported with traces of grain supported with complex intergrain material; very ashy sublithic arenite to marginal lithic quartz arenite; dominant metalithic rock fragments including distinctive trace to common greenstone lithics, non-differentiated black mafic minerals, distinctive traces of low grade slightly orangish red jasper, dark yellowish brown siderite and yellowish green epidote; after 9815’ the tuffaceous sandstone is prominently coarser sandstone, with minor conglomerate and very complex intergrain material that includes particle ash with micro-shards and larger “macro-shards”, devitrified ash in various stages and combined calcite and silica primary cementation and replacement mineralization. Very Carbonaceous Sandy Siltstone and Carbonaceous Clay/Shale (9805'-9815') = difficult to define lithology at zone of high gas; light grayish brown carbonaceous-rich clay-silt interbedded with tuffaceous sandstone and coal; soft matte texture; earthy luster. KBU 43-07Y 14 3.3 Connection Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) 4068 -3571 0 6702 -6051 0 4130 -3624 0 6764 -6112 0 4192 -3677 28 6826 -6174 0 4254 -3730 42 6889 -6237 0 4317 -3785 50 6950 -6298 0 4377 -3837 66 7012 -6360 0 4439 -3891 53 7074 -6422 0 4501 -3945 32 7136 -6484 0 4562 -3998 82 7198 -6546 0 4624 -4051 288 7261 -6609 0 4686 -4105 377 7322 -6671 0 4749 -4160 42 7385 -6733 0 4811 -4215 238 7446 -6795 0 4873 -4268 130 7508 -6856 0 4999 -4380 0 7570 -6918 0 5059 -4435 0 7632 -6980 0 5121 -4491 0 7695 -7043 0 5182 -4547 0 7757 -7105 0 5244 -4606 2 7881 -7229 2 5308 -4667 0 7943 -7291 0 5370 -4726 0 8004 -7353 0 5431 -4786 0 8097 -7415 0 5493 -4846 0 8128 -7476 0 5556 -4907 0 8190 -7538 0 5618 -4962 0 8253 -7602 0 5680 -5029 0 8315 -7663 0 5741 -5090 0 8377 -7725 20 5804 -5153 0 8439 -7787 1018 5927 -5275 82 8501 -7849 574 5989 -5336 0 8564 -7912 1112 6051 -5400 0 8626 -7974 1283 6113 -5461 0 8688 -8036 1858 KBU 43-07Y 15 Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) 6175 -5523 0 8749 -8097 1400 6232 -5580 0 8811 -8159 1280 6330 -5678 0 8874 -8222 946 6392 -5740 0 8936 8284 961 6454 -5802 0 8998 -8346 1129 6516 -5864 3 8059 -8407 1646 6578 -5926 1 9555 -8903 72 6640 -5988 0 9121 -8469 1654 9183 -8532 1649 9678 -9026 174 9245 -8593 1794 9740 -9088 115 9369 -8518 0 9804 -9152 57 9431 -8779 0 9493 -8841 63 9617 -8965 33 KBU 43-07Y 16 3.4 Trip Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Subsea Total Vertical Depth (feet) Trip to (feet) Maximum Gas (Units) Pumps Off Time (hours) 4935 -4335 Wiper trip to 1590 260 7.5 6287 -5653 Wiper trip to 1522 120 13.9 7819 -7180 Wiper trip to 6296 129 5.75 9308 -8669 Wiper trip to 6205 2299 4.25 9835 -9183 Wiper trip to 7753 2380 5.25 9835 -9183 Trip for wireline to surface 2364 19.5 9835 -9183 Wiper trip to 6153’ 1262 10.25 9835 -9183 Trip to surface 1328 48.5 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency* Interval Dispatched to A Washed and dried reference samples 30 ft 20 ft 4950’ to 6287’ 6287’ to 9855’ Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 Attn.: Debra Oudean (907) 777-8337 B Washed and dried reference samples 30 ft 20ft 4950’ to 6287’ 6287’ to 9855’ Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 Attn.: Debra Oudean (907) 777-8337 C Washed and dried reference samples 30 ft 20 ft 4950’ to 6287’ 6287’ to 9855’ Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 Attn: Debra Oudean (907) 777-8337 Sample frequency occasionally may be supplemented when during zones of interest. KBU 43-07Y 17 4 DRILLING DATA 4.1 Directional Survey Data Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 147.61 0.60 306.77 147.61 0.40 -0.54 0.41 0.46 175.28 0.69 307.18 175.28 0.59 -0.79 0.60 0.35 233.61 0.88 302.82 233.60 1.04 -1.44 1.07 0.33 301.52 1.50 322.89 301.50 2.03 -2.41 2.07 1.08 356.72 1.63 333.13 356.68 3.31 -3.20 3.36 0.56 387.60 2.20 330.50 387.54 4.21 -3.69 4.27 1.87 453.36 2.78 331.36 453.24 6.71 -5.08 6.80 0.88 513.88 3.35 338.65 513.67 9.65 -6.43 9.75 1.14 573.80 5.25 344.05 573.42 13.92 -7.82 14.05 3.24 634.93 6.46 348.09 634.23 19.97 -9.30 20.12 2.08 697.01 8.73 349.39 695.76 28.02 -10.89 28.19 3.67 758.28 10.38 352.39 756.18 38.06 -12.47 38.26 2.82 820.59 11.91 354.14 817.31 50.02 -13.87 50.24 2.51 882.84 14.11 356.15 877.96 63.98 -15.04 64.22 3.62 945.26 16.00 356.74 938.23 80.17 -16.04 80.42 3.04 1006.12 18.34 358.91 996.38 98.12 -16.70 98.38 3.98 1068.04 19.65 359.51 1054.92 118.27 -16.97 118.54 2.13 1131.16 20.93 358.45 1114.13 140.16 -17.37 140.42 2.11 1193.01 22.78 359.30 1171.53 163.17 -17.81 163.44 3.03 1255.18 24.97 000.88 1228.38 188.33 -17.76 188.60 3.68 1315.45 26.87 359.01 1282.58 214.67 -17.80 214.94 3.43 1379.60 27.81 359.58 1339.56 244.13 -18.16 244.40 1.52 1441.83 28.48 359.06 1394.44 273.49 -18.51 273.75 1.15 1501.23 29.82 358.39 1446.31 302.41 -19.16 302.69 2.32 1563.74 30.25 358.36 1500.43 333.69 -20.04 333.97 0.69 1571.56 30.20 357.90 1507.19 337.62 -20.17 337.91 3.06 1608.00 29.69 357.85 1538.76 355.80 -20.85 356.09 1.41 1670.60 27.93 358.41 1593.61 385.95 -21.83 386.25 2.84 1732.52 26.84 358.51 1648.59 414.42 -22.60 414.73 1.76 1793.41 26.69 000.32 1702.96 441.83 -22.88 442.15 1.36 1855.39 27.25 001.14 1758.20 469.94 -22.52 470.25 1.08 1918.40 29.07 001.49 1813.75 499.67 -21.84 499.96 2.90 1980.83 30.60 359.81 1867.90 530.72 -21.49 531.00 2.79 2042.88 32.38 359.31 1920.81 563.13 -21.75 563.41 2.90 2103.89 32.78 000.02 1972.22 595.98 -21.94 596.26 0.91 2167.10 31.93 000.27 2025.62 629.81 -21.85 630.08 1.36 2226.84 31.57 000.28 2076.42 661.25 -21.70 661.51 0.60 2290.40 31.40 000.58 2130.62 694.44 -21.45 694.70 0.36 KBU 43-07Y 18 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 2352.26 30.89 000.60 2183.56 726.43 -21.12 726.68 0.82 2413.21 30.46 000.88 2235.98 757.52 -20.72 757.76 0.74 2475.30 31.30 000.13 2289.27 789.39 -20.44 789.62 1.49 2537.92 31.84 000.34 2342.62 822.17 -20.31 822.40 0.88 2600.01 31.21 359.08 2395.55 854.64 -20.47 854.86 1.47 2660.91 30.76 358.73 2447.76 885.98 -21.07 886.21 0.80 2722.18 30.71 358.84 2500.42 917.29 -21.73 917.52 0.12 2784.42 30.48 358.82 2554.00 948.96 -22.38 949.20 0.37 2846.73 30.06 358.54 2607.81 980.36 -23.10 980.61 0.71 2908.98 29.97 358.96 2661.72 1011.49 -23.78 1011.75 0.37 2971.52 29.96 359.22 2715.90 1042.73 -24.28 1042.98 0.21 3034.18 29.83 359.04 2770.22 1073.95 -24.75 1074.21 0.25 3099.69 29.69 359.16 2827.09 1106.46 -25.26 1106.73 0.23 3163.29 29.36 359.19 2882.43 1137.80 -25.71 1138.07 0.52 3219.35 29.17 359.17 2931.33 1165.21 -26.11 1165.48 0.34 3281.12 29.15 359.46 2985.28 1195.30 -26.47 1195.57 0.23 3345.79 28.92 359.54 3041.82 1226.69 -26.74 1226.96 0.36 3405.80 28.74 359.71 3094.39 1255.62 -26.93 1255.90 0.33 3467.60 28.40 359.75 3148.67 1285.18 -27.07 1285.45 0.55 3529.58 28.17 359.69 3203.24 1314.55 -27.21 1314.82 0.37 3591.50 28.12 359.77 3257.84 1343.76 -27.35 1344.02 0.10 3655.24 28.76 358.38 3313.89 1374.10 -27.84 1374.38 1.44 3716.56 30.21 358.48 3367.27 1404.27 -28.67 1404.56 2.37 3779.83 30.66 358.67 3421.82 1436.31 -29.47 1436.60 0.73 3842.00 30.48 358.67 3475.35 1467.92 -30.20 1468.22 0.29 3901.12 30.14 358.63 3526.39 1497.75 -30.90 1498.06 0.58 3964.04 30.84 359.02 3580.61 1529.67 -31.56 1529.98 1.16 4026.49 31.52 359.23 3634.03 1562.00 -32.05 1562.31 1.10 4090.02 31.24 359.36 3688.27 1595.08 -32.46 1595.39 0.45 4150.33 31.27 359.52 3739.83 1626.37 -32.76 1626.69 0.15 4212.67 30.87 359.26 3793.23 1658.54 -33.11 1658.86 0.68 4272.76 30.53 359.25 3844.89 1689.21 -33.51 1689.54 0.57 4337.39 30.32 359.35 3900.62 1721.94 -33.91 1722.27 0.33 4399.04 30.03 359.23 3953.92 1752.93 -34.29 1753.25 0.48 4460.75 29.88 359.49 4007.39 1783.74 -34.63 1784.07 0.32 4522.85 29.76 359.42 4061.26 1814.62 -34.93 1814.95 0.20 4584.70 29.79 359.40 4114.95 1845.33 -35.24 1845.66 0.05 4647.23 29.67 359.59 4169.25 1876.34 -35.52 1876.67 0.24 4709.38 29.38 359.51 4223.33 1906.96 -35.76 1907.29 0.47 4771.89 29.41 359.55 4277.79 1937.65 -36.01 1937.97 0.06 4832.83 29.43 359.76 4330.87 1967.58 -36.19 1967.91 0.17 KBU 43-07Y 19 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 4894.05 28.13 000.54 4384.53 1997.05 -36.12 1997.38 2.21 4955.29 26.84 001.47 4438.85 2025.31 -35.63 2025.62 2.22 5020.15 25.49 000.99 4497.07 2053.90 -35.01 2054.20 2.11 5082.10 24.06 359.26 4553.31 2079.86 -34.94 2080.15 2.59 5143.85 22.72 358.84 4609.99 2104.37 -35.35 2104.67 2.19 5204.95 20.51 357.21 4666.79 2126.86 -36.11 2127.17 3.75 5266.95 17.65 357.04 4725.38 2147.10 -37.12 2147.42 4.61 5329.25 16.07 356.54 4785.00 2165.14 -38.13 2165.47 2.55 5390.85 14.88 355.80 4844.36 2181.54 -39.22 2181.89 1.96 5452.68 13.88 358.12 4904.26 2196.87 -40.05 2197.23 1.87 5515.00 12.42 000.83 4964.94 2211.04 -40.20 2211.40 2.54 5577.98 10.74 004.04 5026.64 2223.67 -39.68 2224.02 2.86 5639.07 9.45 003.69 5086.78 2234.35 -38.96 2234.69 2.11 5702.20 7.75 003.40 5149.20 2243.77 -38.37 2244.10 2.69 5764.25 5.67 003.22 5210.82 2251.01 -37.95 2251.33 3.35 5824.10 3.48 355.83 5270.48 2255.78 -37.92 2256.09 3.78 5888.19 1.18 333.79 5334.51 2258.31 -38.35 2258.63 3.79 5949.95 0.30 245.08 5396.26 2258.81 -38.78 2259.14 1.96 6012.62 0.50 261.91 5458.93 2258.70 -39.20 2259.04 0.37 6073.53 0.56 264.32 5519.84 2258.64 -39.76 2258.98 0.11 6136.02 0.52 256.77 5582.33 2258.54 -40.34 2258.90 0.13 6198.52 0.67 256.10 5644.82 2258.39 -40.97 2258.76 0.24 6245.15 0.75 258.52 5691.45 2258.26 -41.53 2258.64 0.18 6291.96 0.89 253.84 5738.26 2258.10 -42.18 2258.49 0.33 6354.47 0.68 252.29 5800.76 2257.85 -43.00 2258.25 0.34 6415.85 0.86 244.72 5862.13 2257.54 -43.77 2257.96 0.34 6478.46 0.94 256.62 5924.74 2257.22 -44.69 2257.65 0.32 6540.18 0.97 260.78 5986.45 2257.02 -45.70 2257.47 0.12 6602.51 0.99 264.28 6048.77 2256.89 -46.75 2257.35 0.10 6663.91 1.05 266.73 6110.16 2256.80 -47.84 2257.28 0.12 6725.49 0.60 260.93 6171.73 2256.72 -48.73 2257.21 0.74 6788.21 0.65 268.48 6234.45 2256.66 -49.41 2257.16 0.15 6850.28 0.35 296.75 6296.52 2256.73 -49.93 2257.25 0.61 6912.11 0.55 340.43 6358.35 2257.10 -50.20 2257.62 0.62 6974.02 0.48 348.88 6420.25 2257.63 -50.34 2258.15 0.17 7036.04 0.60 351.89 6482.27 2258.21 -50.44 2258.73 0.20 7098.36 0.82 351.63 6544.58 2258.97 -50.55 2259.50 0.35 7160.54 0.66 058.40 6606.76 2259.60 -50.31 2260.12 1.33 7222.55 0.61 070.03 6668.77 2259.90 -49.70 2260.41 0.22 7284.46 0.52 072.40 6730.67 2260.10 -49.12 2260.60 0.15 7346.37 0.46 073.30 6792.58 2260.25 -48.61 2260.75 0.10 KBU 43-07Y 20 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 7408.16 0.34 074.22 6854.37 2260.37 -48.20 2260.86 0.19 7470.50 0.37 070.86 6916.71 2260.49 -47.83 2260.97 0.06 7533.43 0.56 071.71 6979.64 2260.65 -47.35 2261.13 0.30 7595.48 0.34 064.33 7041.69 2260.83 -46.89 2261.29 0.37 7657.21 0.24 058.21 7103.41 2260.98 -46.62 2261.44 0.17 7719.05 0.45 031.36 7165.25 2261.25 -46.38 2261.71 0.42 7780.11 0.58 017.77 7226.31 2261.75 -46.16 2262.20 0.29 7842.92 1.21 089.97 7289.11 2262.05 -45.40 2262.49 1.86 7905.22 1.44 093.00 7351.40 2262.01 -43.96 2262.43 0.39 7966.92 1.35 081.44 7413.08 2262.08 -42.47 2262.47 0.48 8028.50 0.52 118.84 7474.65 2262.05 -41.51 2262.43 1.61 8091.12 0.30 143.77 7537.27 2261.78 -41.16 2262.16 0.44 8153.13 0.21 109.46 7599.28 2261.62 -40.96 2261.98 0.28 8215.32 0.37 106.61 7661.47 2261.52 -40.66 2261.88 0.26 8276.78 0.13 101.94 7722.93 2261.45 -40.40 2261.81 0.39 8338.69 0.19 039.72 7784.84 2261.51 -40.27 2261.87 0.28 8401.35 0.16 064.90 7847.50 2261.63 -40.12 2261.98 0.13 8463.07 0.15 047.50 7909.22 2261.72 -39.98 2262.07 0.08 8525.33 0.26 035.10 7971.48 2261.89 -39.84 2262.24 0.19 8587.05 0.41 010.43 8033.2 2262.22 -39.31 2266.06 0.20 8648.75 0.43 005.14 8094.89 2262.67 -39.38 2266.9 0.30 8711.93 0.47 006.65 8158.07 2263.17 -39.66 2267.68 0.37 8774.05 0.88 006.96 8220.19 2263.89 -40.01 2268.50 0.21 8835.21 0.87 008.91 8281.34 2264.82 -40.16 2269.27 0.51 8897.10 0.82 001.36 8343.22 2265.72 -40.17 2269.84 0.34 8958.81 0.75 348.58 8404.93 2266.56 -40.18 2270.39 0.26 9020.17 0.80 332.17 8466.28 2267.33 -40.17 2271.00 0.07 9082.52 0.84 340.92 8528.63 2268.15 -40.21 2271.60 0.19 9144.08 0.63 359.50 8590.18 2268.92 -40.33 2272.26 0.15 9206.54 0.42 358.54 8652.64 2269.49 -40.55 2273.14 0.56 9269.17 0.58 359.73 8715.27 2270.03 -40.90 2274.28 0.27 9331.65 0.54 002.22 8777.74 2270.64 -41.30 2275.53 0.14 9393.43 0.58 350.80 8839.52 2271.24 -41.77 2276.87 0.22 9454.52 0.67 348.59 8900.61 2271.90 -42.15 2278.32 0.52 9516.44 1.01 344.35 8962.52 2272.78 -39.31 2266.06 0.20 9579.16 1.17 341.53 9025.23 2273.92 -39.38 2266.90 0.30 9640.76 1.25 342.70 9086.81 2275.16 -39.66 2267.68 0.37 9703.14 1.35 338.47 9149.18 2276.49 -40.01 2268.50 0.21 9765.72 1.41 351.70 9211.74 2277.94 -40.16 2269.27 0.51 *9855.00 1.41 351.70 9301.00 *Projection KB U 4 3 - 0 7 Y 21 4. 2 B i t R e c o r d Bi t S i z e M a k e Ty p e SN Je t s TF A De p t h In De p t h Ou t Fo o t a g e Dr i l l e d Bi t Ho u r s Av g . RO P (f t / h r ) Av g . WO B (kl b s ) Av g . RP M Av g . PP (p s i ) Grade 2 9 - 5 / 8 ” HD B S PD C MM 6 5 / 12 4 0 5 9 8 5 6x 1 3 / 0. 7 7 7 6 16 1 0 ’ 6 2 8 7 ’ 4 6 7 7 ’ 3 3 . 0 4 1 4 1 . 5 8 . 1 3 7 . 9 1 6 4 2 O u t : 2 - 3 - B T - G - X - 1 - C T - T D 3 6 - 3 / 4 ’ HD B S Mi l l To o t h QH 1 R 12 3 0 1 0 4 0 3x 1 4 / 0. 4 5 1 0 62 8 7 ’ 6 3 0 8 ’ 2 0 ’ 0 . 5 3 9 4 . 8 9 . 8 5 7 . 3 2 5 6 6 In: 1-1-WT-A-E-1-NO-LOG Out: 1-1-WT-A-E-1-NO-LOG 4 6 - 3 / 4 ” HD B S PD C EM 6 5 D 12 4 0 1 2 2 5 6x 1 0 / 0. 4 6 0 2 62 8 7 ’ 9 8 3 5 ’ 3 5 2 8 ’ 4 1 . 3 4 9 3 . 8 9 . 5 5 7 . 8 2 6 4 5 In: 1-1-WT-N-X-1-NO-LOG Out: 1-1-ER-S-X-I-NO-TD 4R R 2 6 - 3 / 4 ” HD B S PD C EM 6 5 D 12 4 0 1 2 2 5 6x 1 0 / 0. 4 6 0 2 98 3 5 ’ 9 8 5 5 ’ 2 0 ’ 0 . 6 3 6 1 . 6 1 4 . 2 6 1 . 6 2 0 0 7 In: 1-1-ER-S-X-I-NO-LOG Out: 1-1-ER-S-X-I-NO-TD KB U 4 3 - 0 7 Y 22 4. 3 Mu d R e c o r d Co n t r a c t o r : M I S w a c o Mu d T y p e : K l a - S h e i l d Da t e De p t h (f t ) MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T (p p b eq . ) pH Al k (P m ) Cl (mg/L) Ca (mg/L) 3/ 2 9 / 2 0 1 4 3 1 5 0 9 . . 4 5 6 1 2 1 8 3 / 6 / 9 7 6 T r / 9 4 0 . 2 5 5 1 0 . 0 2 . 2 4 4 , 0 0 0 2 4 0 3/ 2 9 / 2 0 1 4 3 6 3 2 9 . 4 6 0 1 3 2 0 4 / 6 / 9 6 6 T r / 9 4 0 . 2 5 5 9 . 7 2 . 1 4 6 , 0 0 0 2 4 0 3/ 2 9 / 2 0 1 4 3 8 1 9 9 . 4 5 8 1 3 1 9 3 / 6 / 9 5 . 9 6 T r / 9 4 0 . 2 5 5 9 . 7 2 . 1 4 6 , 0 0 0 2 4 0 3/ 2 9 / 2 0 1 4 4 3 1 7 9 . 5 6 0 1 6 1 9 5 / 7 / 1 0 6 . 4 7 T r / 9 3 0 . 2 5 6 8 . 5 1 4 2 , 0 0 0 4 0 0 3/ 3 0 / 2 0 1 4 4 9 3 5 9 . 5 5 9 1 6 1 9 5 / 7 / 1 1 6 . 2 7 . 5 T r / 9 3 0 . 2 5 7 . 5 9 . 4 1 4 0 , 0 0 0 2 0 0 3/ 3 0 / 2 0 1 4 4 9 3 5 9 . 5 7 2 1 6 1 9 2 / 7 / 1 1 6 . 2 7 . 5 T r / 9 3 0 . 2 5 7 . 5 9 . 7 1 3 9 , 0 0 0 2 8 0 3/ 3 0 / 2 0 1 4 5 0 7 8 9 . 5 5 6 1 6 1 8 5 / 7 / 1 2 6 . 4 7 1 / 9 2 0 . 2 5 7 . 5 9 . 7 1 3 8 , 0 0 0 3 6 0 3/ 3 0 / 2 0 1 4 5 3 6 0 9 . 5 6 0 1 6 2 2 4 / 7 / 1 3 5 . 6 7 1 / 9 2 0 . 2 5 7 . 5 1 0 . 0 1 . 4 3 5 , 0 0 0 4 0 0 3/ 3 1 / 2 0 1 4 6 0 6 9 9 . 6 6 0 1 7 2 5 5 / 9 / 1 4 5 . 4 7 2 / 9 1 0 . 2 5 7 . 5 9 . 6 1 . 2 4 5 , 0 0 0 4 0 0 3/ 3 1 / 2 0 1 4 6 2 8 7 9 . 7 6 0 1 8 2 6 5 / 1 1 / 1 7 5 . 6 7 2 / 9 1 0 . 2 5 7 . 5 9 . 5 1 . 1 4 4 , 0 0 0 4 0 0 3/ 3 1 / 2 0 1 4 6 2 8 7 9 . 7 6 0 1 9 2 3 4 / 9 / 1 6 5 . 8 7 2 / 9 1 0 . 2 5 7 . 5 9 . 5 1 . 4 4 2 , 0 0 0 4 0 0 4/ 1 / 2 0 1 4 6 2 8 7 9 . 7 6 0 1 8 2 6 5 / 1 1 / 1 7 5 . 8 7 2 / 9 1 0 . 2 5 7 . 5 9 . 4 1 4 2 , 0 0 0 4 0 0 4/ 1 / 2 0 1 4 6 2 8 7 9 . 9 7 0 2 6 2 0 5 / 1 1 / 1 6 5 . 5 7 2 / 9 1 0 . 2 5 8 9 . 5 1 . 1 4 1 , 0 0 0 4 0 0 4/ 2 / 2 0 1 4 6 2 8 7 9 . 8 5 4 2 1 2 0 4 / 9 / 1 4 5 . 8 7 2 / 9 1 0 . 2 5 8 9 . 5 1 . 1 3 9 , 0 0 0 4 0 0 4/ 2 / 2 0 1 4 6 2 8 7 9 . 6 5 2 2 2 1 7 4 / 8 / 1 2 5 . 8 7 2 / 9 1 0 . 2 5 8 9 . 5 1 . 1 3 8 , 0 0 0 4 0 0 4/ 3 / 2 0 1 4 6 2 8 7 9 . 7 5 0 2 2 1 6 4 / 7 / 1 1 5 . 8 7 2 / 9 1 0 . 2 5 8 9 . 5 1 . 1 3 5 , 0 0 0 4 0 0 4/ 3 / 2 0 1 4 6 2 8 7 9 . 7 5 0 2 1 1 7 4 / 6 / 1 0 5 . 8 7 2 / 9 1 0 . 2 5 8 9 . 5 1 . 2 3 5 , 0 0 0 3 8 0 4/ 4 / 2 0 1 4 6 2 8 7 9 . 7 5 0 2 1 1 7 4 / 7 / 1 1 5 . 6 7 2 / 9 1 0 . 2 5 8 9 . 5 1 . 1 3 5 , 0 0 0 3 2 0 4/ 4 / 2 0 1 4 6 2 8 7 1 0 . 1 7 0 1 6 2 1 4 / 6 / 1 0 4 1 0 1 / 8 9 0 . 2 5 9 1 0 . 0 2 . 2 4 0 , 0 0 0 4 0 0 4/ 5 / 2 0 1 4 6 2 8 7 1 0 . 2 7 0 1 6 2 1 4 / 6 / 1 0 4 9 1 / 9 0 0 . 2 5 5 9 . 5 2 . 2 4 8 , 0 0 0 4 0 0 4/ 5 / 2 0 1 4 6 2 8 7 9 . 7 5 0 2 1 1 8 4 / 7 / 1 1 6 7 2 / 9 1 0 . 2 5 8 9 . 4 1 3 5 , 0 0 0 3 2 0 Ab b r e v i a t i o n s MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y P V = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = F i l t r a t e L o ss F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = C h l o r i d e s C a = H a r d n e s s KB U 4 3 - 0 7 Y 23 Co n t r a c t o r : M I S w a c o Mu d T y p e : K l a - S h e i l d Da t e De p t h (f t ) MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T (p p b eq . ) pH Al k (P m ) Cl (mg/L) Ca (mg/L) 4/ 5 / 2 0 1 4 6 2 8 7 1 0 . 1 6 0 1 7 2 1 6 / 8 / 1 1 4 . 5 7 1 / 9 2 0 . 2 5 6 9 . 5 2 7 0 , 0 0 0 3 2 0 4/ 6 / 2 0 1 4 6 3 0 7 1 0 . 1 5 9 1 7 2 0 6 / 8 / 1 1 4 . 6 7 1 / 9 2 0 . 1 6 9 . 7 2 7 0 , 0 0 0 3 2 0 4/ 6 / 2 0 1 4 6 3 9 2 1 0 . 1 5 0 1 3 1 6 4 / 6 / 8 4 . 6 9 1 / 9 0 0 . 2 5 7 . 5 9 . 7 2 8 2 , 0 0 0 3 2 0 4/ 7 / 2 0 1 4 6 4 5 4 1 0 . 0 4 8 1 3 1 6 4 / 6 / 8 4 . 7 9 1 / 9 0 0 . 2 5 5 9 . 6 1 . 9 8 0 , 0 0 0 3 2 0 4/ 7 / 2 0 1 4 7 1 3 8 1 0 . 1 5 3 1 9 2 3 8 / 1 3 / 2 3 4 1 0 2 / 8 9 0 . 2 5 5 9 . 1 1 . 8 8 3 , 0 0 0 2 8 0 4/ 7 / 2 0 1 4 7 3 8 5 1 0 . 2 5 6 2 0 2 5 1 0 / 1 6 / 2 6 3 . 6 1 0 . 5 2 / 8 8 0 . 2 5 5 9 . 1 1 . 8 8 3 , 0 0 0 2 8 0 4/ 7 / 2 0 1 4 7 8 1 9 1 0 . 4 5 7 2 1 2 7 8 / 1 2 / 1 9 4 . 4 1 2 2 / 8 6 0 . 2 5 5 9 . 5 1 . 8 8 2 , 0 0 0 2 0 0 4/ 8 / 2 0 1 4 7 8 8 1 1 0 . 4 6 0 2 1 2 7 8 / 1 5 / 1 9 4 . 4 1 2 2 / 8 6 0 . 2 5 5 9 . 5 1 . 5 8 2 , 0 0 0 2 0 0 4/ 8 / 2 0 1 4 8 2 6 0 1 0 . 4 5 5 2 3 2 7 9 / 1 6 / 2 1 3 . 8 1 2 2 / 8 6 0 . 2 5 5 9 . 2 1 . 3 8 1 , 0 0 0 2 0 0 4/ 8 / 2 0 1 4 8 5 6 4 1 0 . 4 5 6 2 3 2 8 9 / 1 7 / 2 2 4 1 2 2 / 8 6 0 . 2 5 5 9 . 2 1 . 3 8 1 , 0 0 0 2 0 0 4/ 8 / 2 0 1 4 8 7 4 6 1 0 . 9 5 7 2 2 2 9 5 / 8 / 1 2 4 1 2 2 / 8 6 0 . 2 5 7 . 5 9 . 7 1 . 6 6 0 , 0 0 0 1 0 0 4/ 9 / 2 0 1 4 9 2 9 3 1 1 . 1 5 7 2 3 2 6 5 / 8 / 1 2 4 . 8 1 4 2 / 8 4 0 . 2 5 5 9 . 5 2 7 0 , 0 0 0 1 0 0 4/ 9 / 2 0 1 4 9 3 0 8 1 1 . 3 5 5 2 4 2 7 7 / 9 / 1 5 4 . 6 1 6 2 / 8 2 0 . 2 5 5 9 . 2 1 . 8 7 9 , 0 0 0 1 0 0 4/ 9 / 2 0 1 4 9 3 0 8 1 1 . 3 5 9 2 4 2 8 8 / 9 / 1 6 4 . 8 1 6 2 / 8 2 0 . 2 5 5 9 . 2 1 . 8 7 9 , 0 0 0 1 0 0 4/ 9 / 2 0 1 4 9 3 0 8 1 1 . 4 5 5 2 4 2 4 6 / 8 / 1 0 4 . 6 1 6 2 / 8 2 0 . 2 5 5 9 . 5 1 . 4 7 0 , 0 0 0 1 2 0 4/ 1 0 / 2 0 1 4 9 3 0 8 1 1 . 6 5 8 2 4 2 4 6 / 8 / 1 0 4 . 6 1 6 2 / 8 2 0 . 2 5 5 9 . 5 1 6 2 , 0 0 0 1 2 0 4/ 1 0 / 2 0 1 4 9 7 5 2 1 1 . 5 6 0 2 3 2 8 6 / 1 0 / 1 2 4 . 4 1 6 2 / 8 3 0 . 2 5 5 9 . 1 1 6 4 , 0 0 0 1 2 0 4/ 1 0 / 2 0 1 4 9 8 3 5 1 1 . 5 6 2 2 4 2 7 6 / 1 0 / 1 2 4 . 4 1 6 2 / 8 3 0 . 2 5 5 9 . 1 1 6 3 , 0 0 0 1 2 0 4/ 1 0 / 2 0 1 4 9 8 3 5 1 1 . 5 7 0 3 0 3 1 5 / 7 / 9 3 . 6 1 6 2 / 8 3 0 . 2 5 5 9 . 3 1 6 3 , 0 0 0 2 0 0 4/ 1 1 / 2 0 1 4 9 8 3 5 1 1 . 5 6 4 2 9 2 9 5 / 7 / 9 3 . 6 1 6 2 / 8 3 0 . 2 5 5 9 . 3 1 6 3 , 0 0 0 2 0 0 4/ 1 1 / 2 0 1 4 9 8 3 5 1 1 . 5 7 4 2 4 2 4 5 / 7 / 9 4 1 6 1 / 8 3 0 . 2 5 7 . 5 9 . 5 1 . 4 6 2 , 0 0 0 2 0 0 4/ 1 2 / 2 0 1 4 9 8 3 5 1 1 . 8 7 1 2 8 3 1 5 / 8 / 1 0 4 1 8 1 / 8 1 0 . 2 5 7 . 5 9 . 1 1 . 2 6 1 , 0 0 0 2 0 0 4/ 1 2 / 2 0 1 4 9 8 3 5 1 2 . 0 8 5 2 0 2 8 3 / 5 / 7 4 2 0 1 / 7 9 0 . 2 5 7 . 5 9 . 5 1 . 3 6 1 , 0 0 0 2 0 0 4/ 1 3 / 2 0 1 4 9 8 3 5 1 2 . 1 7 6 2 1 2 9 3 / 6 / 8 4 2 0 1 / 7 9 0 . 2 5 7 . 5 9 . 0 1 . 1 6 1 , 0 0 0 2 0 0 Ab b r e v i a t i o n s MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y P V = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = F i l t r a t e L o ss F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = C h l o r i d e s C a = H a r d n e s s KB U 4 3 - 0 7 Y 24 Co n t r a c t o r : M I S w a c o Mu d T y p e : K l a - S h e i l d Da t e De p t h (f t ) MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T (p p b eq . ) pH Al k (P m ) Cl (mg/L) Ca (mg/L) 4/ 1 3 / 2 0 1 4 9 8 3 5 1 2 . 1 7 0 2 8 3 7 5 / 7 / 8 4 . 6 1 9 1 / 8 0 0 . 2 5 7 . 5 9 . 3 1 . 4 6 2 , 0 0 0 2 0 0 4/ 1 4 / 2 0 1 4 9 8 3 5 1 2 . 1 6 9 2 8 3 3 5 / 8 / 9 4 . 6 1 9 1 / 8 0 0 . 2 5 7 . 5 9 . 1 1 . 4 6 2 , 0 0 0 2 0 0 4/ 1 4 / 2 0 1 4 9 8 3 5 1 2 . 1 7 0 2 5 3 0 5 / 7 / 9 4 . 6 1 9 1 / 8 0 0 . 2 5 7 . 5 9 . 3 1 . 4 6 0 , 0 0 0 2 0 0 4/ 1 5 / 2 0 1 4 9 8 3 5 1 2 . 1 7 3 2 5 2 9 5 / 7 / 9 4 . 8 1 9 1 / 8 0 0 . 2 5 7 . 5 9 . 3 1 . 4 6 0 , 0 0 0 2 0 0 4/ 1 5 / 2 0 1 4 9 8 3 5 1 2 . 1 7 5 2 2 2 6 5 / 7 / 9 4 2 0 1 / 7 9 0 . 2 5 7 . 5 9 . 3 1 . 0 5 9 , 0 0 0 2 0 0 4/ 1 6 / 2 0 1 4 9 8 5 5 1 2 . 2 7 3 2 2 2 6 7 / 8 / 1 0 4 . 2 2 0 1 / 7 9 0 . 2 5 7 . 5 9 . 3 1 . 0 5 8 , 0 0 0 2 0 0 4/ 1 6 / 2 0 1 4 9 8 5 5 1 2 . 2 8 0 2 9 3 0 6 / 8 / 1 1 4 . 2 2 0 1 / 7 9 0 . 2 5 1 0 9 . 3 0 . 7 5 6 , 0 0 0 1 8 0 4/ 1 7 / 2 0 1 4 9 8 5 5 1 2 . 2 8 2 2 5 3 0 8 / 1 0 / 1 2 4 . 4 2 0 1 / 7 9 0 . 2 5 1 0 9 . 2 0 . 7 5 6 , 0 0 0 1 8 0 4/ 1 7 / 2 0 1 4 9 8 5 5 1 2 . 2 8 5 2 5 3 2 8 / 1 0 / 1 2 4 . 4 2 0 1 / 7 9 0 . 2 5 1 0 8 . 9 0 . 6 5 6 0 0 0 1 8 0 4/ 1 8 / 2 0 1 4 9 8 5 5 1 2 . 1 6 1 2 6 3 2 7 / 1 0 / 1 2 4 . 4 2 0 1 / 7 9 0 . 2 5 1 0 9 . 0 0 . 6 5 6 0 0 0 1 8 0 Ab b r e v i a t i o n s MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y P V = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = F i l t r a t e L o ss F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = C h l o r i d e s C a = H a r d n e s s KBU 43-07Y 25 5 DAILY REPORTS KBU 43-07Y 26 KBU 43-07Y 27 KBU 43-07Y 28 KBU 43-07Y 29 KBU 43-07Y 30 KBU 43-07Y 31 KBU 43-07Y 32 KBU 43-07Y 33 KBU 43-07Y 34 KBU 43-07Y 35 KBU 43-07Y 36 KBU 43-07Y 37 KBU 43-07Y 38 KBU 43-07Y 39 KBU 43-07Y 40 KBU 43-07Y 41 KBU 43-07Y 42 KBU 43-07Y 43 KBU 43-07Y 44 KBU 43-07Y 45