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HomeMy WebLinkAbout221-114Nolan 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: 6/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250618 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL Please include current contact information if different from above. T40566 T40567 T40568 T40569 T40570 T40571 T40571 T40572 T40573 T40574 T40574 T40575 T40575 T40576 T40577 T40578 T40579 T40580 T40581 PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -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 7,600 feet N/A feet true vertical 5,023 feet ~7,440' (fish) feet Effective Depth measured 7,440 feet 1,268 feet true vertical 4,900 feet 1,201 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)Tieback 4-1/2" 12.6# / L-80 1,276' MD 1,207' TVD Packers and SSSV (type, measured and true vertical depth)LTP; SSSV 1,268' MD 1,201' TVD 483' MD/492' TVD 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: 7,500psi 2,980psi 6,880psi 8,430psi 1,512'1,380' Burst Collapse 1,410psi 4,790psi Production Liner 6,329' Casing Structural 5,020'7,596' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,512' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 221-114 50-133-20704-00-00 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: Private (SHL) / ADL 384372 Ninilchik / Beluga-Tyonek Gas Ninilchik Unit Paxton 11 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 2145 0 0 0 703 469 Scott Warner, Operations Engineer 325-281 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 971 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 scott.warner@hilcorp.com 907-564-4506 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 4:31 pm, Jun 16, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.06.16 15:00:42 - 08'00' Noel Nocas (4361) RBDMS JSB 061825 DSR-6/18/25BJM 9/23/25 Page 1/1 Well Name: NINU Paxton 11 Report Printed: 6/2/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-133-20704-00-00 Field Name:Ninilchik State/Province:ALASKA Permit to Drill (PTD) #:221-114 Sundry #:325-281 Rig Name/No: Jobs Actual Start Date:4/29/2025 End Date: Report Number 1 Report Start Date 5/14/2025 Report End Date 5/14/2025 Last 24hr Summary PTW/PJSM, MIRU PWL, PT 250/2500. Drift W/ well flowing, 3.72" G-ring, tag @ 7400' KB, no fluid level observed. Report Number 2 Report Start Date 5/26/2025 Report End Date 5/27/2025 Last 24hr Summary PTW/PJSM. MIRU AK E-line. PT 250/2,000 psi. Perforate T-8 Sand (6,698' - 6,708'), T-5B Sand (6,343' - 6,358'), BEL 134 Sand (5,691' - 5,701') with well shut-in. SDFN. Turn well over to Prod Ops to flow test. Report Number 3 Report Start Date 5/27/2025 Report End Date 5/28/2025 Last 24hr Summary PTW/PJSM. Perforating with AK E-line. Perforate BEL 134 Sand (5,653' - 5,663'), BEL 133 Sand (5,612' - 5,618'), BEL 115 Sand (5,448' - 5,454'), BEL 115 Sand (5,418' - 5,428'), BEL 110 Sand (5,372' - 5,378'), BEL 100 Sand (5,302' - 5,312') with well flowing. SDFN. Turn well over to Prod Ops to flow test. Report Number 4 Report Start Date 5/28/2025 Report End Date 5/29/2025 Last 24hr Summary PTW/PJSM. Perforating with AK E-line. Perforate BEL 100 Sand (5,262' - 5,272'), BEL 98 Sand (5,140' - 5,150'), BEL 95 Sand (5,037' - 5,057'), BEL 95 Sand (5,025' - 5,031'), BEL 94 Sand (4,995' - 5,001'), BEL 93 Sand (4,915' - 4,929') with well flowing. SDFN. Turn well over to Prod Ops to flow test. Report Number 5 Report Start Date 5/29/2025 Report End Date 5/30/2025 Last 24hr Summary PTW/PJSM. Perforating with AK E-line. Perforate BEL 88 Sand (4,634' - 4,644'), BEL 80 Sand (4,511' - 4,525'), BEL 78 Sand (4,477' - 4,491') with well flowing. RDMO E-line. Perforate BEL 134 Sand (5,653' - 5,663'), BEL 133 Sand (5,612' - 5,618'), BEL 115 Sand (5,448' - 5,454'), BEL 115 Sandg(,,), (5,418' - 5,428'), BEL 110 Sand (5,372' - 5,378'), BEL 100 Sand (5,302' - 5,312') with well flowing. Perforate T-8 Sand (6,698' - 6,708'), T-5B Sand (6,343' - 6,358'), BEL 134 Sand (5,691' - 5,701') Perforate BEL 88 Sand (4,634' - 4,644'), BEL 80 Sand (4,511' - 4,525'), BEL 78 Sand (4,477' - 4,491') Perforate BEL 100 Sand (5,262' - 5,272'), BEL 98 Sand (5,140' - 5,150'), BEL 95 Sand (5,037' - 5,057'), BEL 95 Sandg(,,), (5,025' - 5,031'), BEL 94 Sand (4,995' - 5,001'), BEL 93 Sand (4,915' - 4,929') with well flowing _____________________________________________________________________________________ Updated by DMA 06-02-25 SCHEMATIC Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 T-3 T-5 T-10 BEL 78-98 BEL 100-134 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2”TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 78 4,477'4,491'2,680'2,689'14'5/29/2025 Open BEL 80 4,511'4,525'2,702'2,711'14'5/29/2025 Open BEL 88 4,634'4,644'2,784'2,791'10'5/28/2025 Open BEL 93 4,915'4,929'2,987'2,997'14'5/28/2025 Open BEL 94 4,995'5,001'3,045'3,050'6'5/28/2025 Open BEL 95 5,025'5,031'3,067'3,072'6'5/28/2025 Open BEL 95 5,037'5,057'3,076'3,091'20'5/28/2025 Open BEL 98 5,140'5,150'3,153'3,160'10'5/28/2025 Open BEL 100 5,262'5,272'3,243'3,251'10'5/28/2025 Open BEL 100 5,302'5,312'3,273'3,281'10'5/27/2025 Open BEL 110 5,372'5,378'3,326'3,330'6'5/27/2025 Open BEL 115 5,418'5,428'3,360'3,368'10'5/27/2025 Open BEL 115 5,448'5,454'3,383'3,388'6'5/27/2025 Open BEL 133 5,612'5,618'3,506'3,511'6'5/27/2025 Open BEL 134 5,653'5,663'3,537'3,545'10'5/27/2025 Open BEL 134 5,691'5,701'3,566'3,574'10'5/26/2025 Open T-3 6,048'6,062'3,836'3,846'14'5/23/2024 Open T-3 6,071'6,077'3,853'3,858'6'5/23/2024 Open T-5 6,212'6,222'3,957'3,964'10'5/23/2024 Open T-5B 6,332'6,342'4,047'4,054'10'5/23/2024 Open T-5B 6,343'6,358'4,055'4,067'15'5/26/2025 Open T-6 6,399'6,419'4,098'4,114'20'5/22/2024 Open T-6 6,442'6,452'4,132'4,140'10'5/22/2024 Open T-6 6,478'6,488'4,160'4,168'10'5/22/2024 Open T-7 6,549'6,558'4,216'4,223'9'5/21/2024 Open T-7 6,562’6,574’4,226’4,235’12’2/14/2022 Open T-7U 6,616’6,623’4,268’4,273’7’2/14/2022 Open T-7L 6,626’6,635’4,275’4,282’9’2/14/2022 Open T-8U 6,663’6,674’4,304’4,313’11’2/14/2022 Open T-8 6,698'6,708'4,331'4,339'10'5/26/2025 Open T-9A 6,779'6,785'4,394'4,399'6'5/21/2024 Open T-9AM 6,786’6,796’4,399’4,407’10’2/14/2022 Open T-9AL 6,798’6,802’4,409’4,412’4’2/14/2022 Open T-10 6,828'6,834'4,432'4,437'6'5/21/2024 Open T-10A 6,884'6,889'4,475'4,479'5'5/21/2024 Open T-10B 6,945'6,953'4,522'4,528'8'5/20/2024 Open T-11U 6,966’6,970’4,538’4,541’4’2/14/2022 Open T-11M 6,988’6,993’4,555’4,559’5’2/14/2022 Open T-11L 7,015’7,020’4,576’4,580’5’2/14/2022 Open T-11A 7,027'7,032'4,585'4,589'5'5/20/2024 Open T-11A 7,056'7,069'4,607'4,617'13'5/20/2024 Open T-12U 7,198'7,215'4,715'4,729'17'2/10/2022 Open T-12U 7,198'7,215'4,715'4,729'17'2/11/2022 Open T-12 7,331'7,336'4,817'4,821'5'5/20/2024 Open FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up @ ~7,440 (5/13/24) 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): 7,600'~7,440' (fish) Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi 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 scott.warner@hilcorp.com 907-564-4506 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 Scott Warner, 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 Private (SHL) / ADL 384372 221-114 50-133-20704-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 1,276' 8,430psi 1,380' Size 120' 1,512' MD See Attached Schematic 2,980psi 6,880psi 120'120' 1,512' May 15, 2025 Tieback 4-1/2" 7,596' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Paxton 11CO 701C Same 5,020'4-1/2" ~1638 psi 6,329' N/A Length LTP; SSSV 1,268' MD/1,201' TVD; 483' MD/492' TVD 5,023'7,440'4,900' Ninilkchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.05.06 14:46:27 - 08'00' Noel Nocas (4361) 325-281 By Grace Christianson at 3:36 pm, May 06, 2025 SFD 5/8/2025 DSR-5/6/25BJM 5/12/25 If plug is set above Tyonek, a plug with 25' of cement must be set between Tyonek and Beluga 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.13 13:56:18 -08'00'05/13/25 RBDMS JSB 051425 Well Prognosis Well: Paxton 11 Date: 5/1/25 Well Name: Paxton 11 API Number: 50-133-20704-00-00 Current Status: Producing Gas Well Permit to Drill Number: 221-114 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2120 psi @ 4817’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 1638 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.86 psi/ft using 16.7 ppg EMW LOT at the surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.868-0.1) = 1638 psi / 0.768 = 2132‘ TVD Top of Applicable Gas Pool: 1645’ MD/ 1468’ TVD Well Status: Online Gas Producer flowing at 970 mcfd, 2 bwpd, 70 psi FTP Brief Well Summary Paxton 11 is a grass roots well drilled in Feb 2022 targeting the Tyonek and Beluga Sands. Initial perforations were added from T-6 to T-12 and the well came online at 2.5 mmscfd. Perforations were added in the TY 3- TY 13 in May 2024 which boosted rate from 445 mcfd to 2.0 mmcfd. The purpose of this sundry is to perforate additional footage in the BEL 60- BEL 135 sands to increase production. Notes Regarding Wellbore Condition x Inclination o Max deviation of 70° @ 2,436’ MD o Max DLS of 5°/100’ @ 1,349’ MD x Min ID o 4-1/2” liner, tubing, and SSSV @ 483’ MD o SSSV min ID – 3.613” x Recent Tags/Fish o 5/23/24 ƒ EL perforated sands from T-3 to T-12. Toolstring consisted of 1-7/16" cable head, 3.60" roller bogie, 2.75" GR/CCL, 2.75" shock sub, 3.60 roller bogie, perf guns, and 3.60” roller bogie o 5/13/24 ƒ SL RIH w/ 1.49” GR to 7440’, did not tag. Ran PT survey o 2/14/22 ƒ Roller bogey assembly fish left in hole while perforating 6663’-6626’. OAL: 28”, Max OD 3.60”. 3” of 1.53 OD stem looking up Pre-Sundry Steps: 1. RU slickline 2. PT lubricator to 250 psi low/ 2,000 psi high 3. D&T to TD w/ large OD in prep for 2-3/4” guns. Drift to find updated tag and ensure wellbore is clean of any sand bridges. Last SL run was down to 7440’ but did not tag. Note if fluid level is seen. 4. RDMO slickline Well Prognosis Well: Paxton 11 Date: 5/1/25 Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,000 psi high 3. RIH and perforate Beluga 60 – BEL 135 sands from bottom up with 2-3/4” 60 deg phased perf guns: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Btm MD Top TVD Btm TVD Interval BEL 60 ±4,092' ±4,102' ±2,469' ±2,474' ±10' BEL 70 ±4,189' ±4,200' ±2,517' ±2,523' ±11' BEL 73 ±4,312' ±4,319' ±2,583' ±2,587' ±7' BEL 73 ±4,321' ±4,327' ±2,587' ±2,591' ±6' BEL 73 ±4,329' ±4,335' ±2,591' ±2,595' ±6' BEL 74 ±4,349' ±4,355' ±2,604' ±2,607' ±6' BEL 74 ±4,357' ±4,363' ±2,607' ±2,611' ±6' BEL 74 ±4,384' ±4,394' ±2,624' ±2,630' ±10' BEL 75 ±4,438' ±4,444' ±2,656' ±2,660' ±6' BEL 75 ±4,447' ±4,453' ±2,662' ±2,665' ±6' BEL 78 ±4,477' ±4,491' ±2,680' ±2,689' ±14' BEL 80 ±4,511' ±4,525' ±2,702' ±2,711' ±14' BEL 80 ±4,530' ±4,536' ±2,714' ±2,718' ±6' BEL 82 ±4,585' ±4,591' ±2,751' ±2,755' ±6' BEL 83 ±4,611' ±4,617' ±2,768' ±2,773' ±6' BEL 88 ±4,634' ±4,644' ±2,784' ±2,791' ±10' BEL 90 ±4,666' ±4,672' ±2,807' ±2,811' ±6' BEL 90 ±4,691' ±4,701' ±2,824' ±2,831' ±10' BEL 90 ±4,723' ±4,743' ±2,847' ±2,862' ±20' BEL 91 ±4,775' ±4,789' ±2,885' ±2,895' ±14' BEL 92 ±4,796' ±4,802' ±2,900' ±2,904' ±6' BEL 92 ±4,824' ±4,830' ±2,921' ±2,925' ±6' BEL 92 ±4,861' ±4,867' ±2,948' ±2,952' ±6' BEL 92 ±4,873' ±4,879' ±2,956' ±2,961' ±6' BEL 92 ±4,881' ±4,887' ±2,962' ±2,967' ±6' BEL 93 ±4,915' ±4,929' ±2,987' ±2,997' ±14' BEL 94 ±4,995' ±5,001' ±3,045' ±3,050' ±6' BEL 95 ±5,025' ±5,031' ±3,067' ±3,072' ±6' BEL 95 ±5,037' ±5,057' ±3,076' ±3,091' ±20' BEL 98 ±5,140' ±5,150' ±3,153' ±3,160' ±10' BEL 100 ±5,262' ±5,272' ±3,243' ±3,251' ±10' BEL 100 ±5,302' ±5,312' ±3,273' ±3,281' ±10' Well Prognosis Well: Paxton 11 Date: 5/1/25 BEL 110 ±5,372' ±5,378' ±3,326' ±3,330' ±6' BEL 115 ±5,418' ±5,428' ±3,360' ±3,368' ±10' BEL 115 ±5,448' ±5,454' ±3,383' ±3,388' ±6' BEL 133 ±5,612' ±5,618' ±3,506' ±3,511' ±6' BEL 134 ±5,653' ±5,663' ±3,537' ±3,545' ±10' BEL 134 ±5,691' ±5,701' ±3,566' ±3,574' ±10' BEL-135 ±5,785' ±5,795' ±3,638' ±3,646' ±10' T-5B ±6,343' ±6,358' ±4,055' ±4,067' ±15' T-8 ±6,676' ±6,709' ±4,315' ±4,340' ±33' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Updated by DMA 05-30-24 SCHEMATIC Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 T-3 T-5 T-10 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2”TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status T-3 6,048'6,062'3,836'3,846'14'5/23/2024 Open T-3 6,071'6,077'3,853'3,858'6'5/23/2024 Open T-5 6,212'6,222'3,957'3,964'10'5/23/2024 Open T-5B 6,332'6,342'4,047'4,054'10'5/23/2024 Open T-6 6,399'6,419'4,098'4,114'20'5/22/2024 Open T-6 6,442'6,452'4,132'4,140'10'5/22/2024 Open T-6 6,478'6,488'4,160'4,168'10'5/22/2024 Open T-7 6,549'6,558'4,216'4,223'9'5/21/2024 Open T-7 6,562’6,574’4,226’4,235’12’2/14/2022 Open T-7U 6,616’6,623’4,268’4,273’7’2/14/2022 Open T-7L 6,626’6,635’4,275’4,282’9’2/14/2022 Open T-8U 6,663’6,674’4,304’4,313’11’2/14/2022 Open T-9A 6,779'6,785'4,394'4,399'6'5/21/2024 Open T-9AM 6,786’6,796’4,399’4,407’10’2/14/2022 Open T-9AL 6,798’6,802’4,409’4,412’4’2/14/2022 Open T-10 6,828'6,834'4,432'4,437'6'5/21/2024 Open T-10A 6,884'6,889'4,475'4,479'5'5/21/2024 Open T-10B 6,945'6,953'4,522'4,528'8'5/20/2024 Open T-11U 6,966’6,970’4,538’4,541’4’2/14/2022 Open T-11M 6,988’6,993’4,555’4,559’5’2/14/2022 Open T-11L 7,015’7,020’4,576’4,580’5’2/14/2022 Open T-11A 7,027'7,032'4,585'4,589'5'5/20/2024 Open T-11A 7,056'7,069'4,607'4,617'13'5/20/2024 Open T-12U 7,198'7,215'4,715'4,729'17'2/10/2022 Open T-12U 7,198'7,215'4,715'4,729'17'2/11/2022 Open T-12 7,331'7,336'4,817'4,821'5'5/20/2024 Open FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up @ ~7,440 (5/13/24) _____________________________________________________________________________________ Updated by DMA 05-01-25 PROPOSED Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 T-3 T-5 T-10 Bel 60 – Bel 135 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2”TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status BEL 60 ±4,092'±4,102'±2,469'±2,474'±10'Proposed TBD BEL 70 ±4,189'±4,200'±2,517'±2,523'±11'Proposed TBD BEL 73 ±4,312'±4,319'±2,583'±2,587'±7'Proposed TBD BEL 73 ±4,321'±4,327'±2,587'±2,591'±6'Proposed TBD BEL 73 ±4,329'±4,335'±2,591'±2,595'±6'Proposed TBD BEL 74 ±4,349'±4,355'±2,604'±2,607'±6'Proposed TBD BEL 74 ±4,357'±4,363'±2,607'±2,611'±6'Proposed TBD BEL 74 ±4,384'±4,394'±2,624'±2,630'±10'Proposed TBD BEL 75 ±4,438'±4,444'±2,656'±2,660'±6'Proposed TBD BEL 75 ±4,447'±4,453'±2,662'±2,665'±6'Proposed TBD BEL 78 ±4,477'±4,491'±2,680'±2,689'±14'Proposed TBD BEL 80 ±4,511'±4,525'±2,702'±2,711'±14'Proposed TBD BEL 80 ±4,530'±4,536'±2,714'±2,718'±6'Proposed TBD BEL 82 ±4,585'±4,591'±2,751'±2,755'±6'Proposed TBD BEL 83 ±4,611'±4,617'±2,768'±2,773'±6'Proposed TBD BEL 88 ±4,634'±4,644'±2,784'±2,791'±10'Proposed TBD BEL 90 ±4,666'±4,672'±2,807'±2,811'±6'Proposed TBD BEL 90 ±4,691'±4,701'±2,824'±2,831'±10'Proposed TBD BEL 90 ±4,723'±4,743'±2,847'±2,862'±20'Proposed TBD BEL 91 ±4,775'±4,789'±2,885'±2,895'±14'Proposed TBD BEL 92 ±4,796'±4,802'±2,900'±2,904'±6'Proposed TBD BEL 92 ±4,824'±4,830'±2,921'±2,925'±6'Proposed TBD BEL 92 ±4,861'±4,867'±2,948'±2,952'±6'Proposed TBD BEL 92 ±4,873'±4,879'±2,956'±2,961'±6'Proposed TBD BEL 92 ±4,881'±4,887'±2,962'±2,967'±6'Proposed TBD BEL 93 ±4,915'±4,929'±2,987'±2,997'±14'Proposed TBD BEL 94 ±4,995'±5,001'±3,045'±3,050'±6'Proposed TBD BEL 95 ±5,025'±5,031'±3,067'±3,072'±6'Proposed TBD BEL 95 ±5,037'±5,057'±3,076'±3,091'±20'Proposed TBD BEL 98 ±5,140'±5,150'±3,153'±3,160'±10'Proposed TBD BEL 100 ±5,262'±5,272'±3,243'±3,251'±10'Proposed TBD BEL 100 ±5,302'±5,312'±3,273'±3,281'±10'Proposed TBD BEL 110 ±5,372'±5,378'±3,326'±3,330'±6'Proposed TBD BEL 115 ±5,418'±5,428'±3,360'±3,368'±10'Proposed TBD BEL 115 ±5,448'±5,454'±3,383'±3,388'±6'Proposed TBD BEL 133 ±5,612'±5,618'±3,506'±3,511'±6'Proposed TBD BEL 134 ±5,653'±5,663'±3,537'±3,545'±10'Proposed TBD BEL 134 ±5,691'±5,701'±3,566'±3,574'±10'Proposed TBD BEL-135 ±5,785'±5,795'±3,638'±3,646'±10'Proposed TBD Perforation Detail continued on following page FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up @ ~7,440 (5/13/24) _____________________________________________________________________________________ Updated by DMA 05-01-25 PROPOSED Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 Perforation Detail continued from previous page PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status T-3 6,048' 6,062' 3,836' 3,846' 14' 5/23/2024 Open T-3 6,071' 6,077' 3,853' 3,858' 6' 5/23/2024 Open T-5 6,212' 6,222' 3,957' 3,964' 10' 5/23/2024 Open T-5B 6,332' 6,342' 4,047' 4,054' 10' 5/23/2024 Open T-5B ±6,343' ±6,358' ±4,055' ±4,067' ±15' Proposed TBD T-6 6,399' 6,419' 4,098' 4,114' 20' 5/22/2024 Open T-6 6,442' 6,452' 4,132' 4,140' 10' 5/22/2024 Open T-6 6,478' 6,488' 4,160' 4,168' 10' 5/22/2024 Open T-7 6,549' 6,558' 4,216' 4,223' 9' 5/21/2024 Open T-7 6,562’ 6,574’ 4,226’ 4,235’ 12’ 2/14/2022 Open T-7U 6,616’ 6,623’ 4,268’ 4,273’ 7’ 2/14/2022 Open T-7L 6,626’ 6,635’ 4,275’ 4,282’ 9’ 2/14/2022 Open T-8U 6,663’ 6,674’ 4,304’ 4,313’ 11’ 2/14/2022 Open T-8 ±6,676' ±6,709' ±4,315' ±4,340' ±33' Proposed TBD T-9A 6,779' 6,785' 4,394' 4,399' 6' 5/21/2024 Open T-9AM 6,786’ 6,796’ 4,399’ 4,407’ 10’ 2/14/2022 Open T-9AL 6,798’ 6,802’ 4,409’ 4,412’ 4’ 2/14/2022 Open T-10 6,828' 6,834' 4,432' 4,437' 6' 5/21/2024 Open T-10A 6,884' 6,889' 4,475' 4,479' 5' 5/21/2024 Open T-10B 6,945' 6,953' 4,522' 4,528' 8' 5/20/2024 Open T-11U 6,966’ 6,970’ 4,538’ 4,541’ 4’ 2/14/2022 Open T-11M 6,988’ 6,993’ 4,555’ 4,559’ 5’ 2/14/2022 Open T-11L 7,015’ 7,020’ 4,576’ 4,580’ 5’ 2/14/2022 Open T-11A 7,027' 7,032' 4,585' 4,589' 5' 5/20/2024 Open T-11A 7,056' 7,069' 4,607' 4,617' 13' 5/20/2024 Open T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/10/2022 Open T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/11/2022 Open T-12 7,331' 7,336' 4,817' 4,821' 5' 5/20/2024 Open 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: 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 PAXTON 11 50133207040000 221114 5/20/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.27 13:09:17 -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 7,600 feet N/A feet true vertical 5,023 feet ~7,440' (fish) feet Effective Depth measured 7,440 feet 1,268 feet true vertical 4,900 feet 1,201 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) Tieback 4-1/2" 12.6# / L-80 1,276' MD 1,207' TVD Packers and SSSV (type, measured and true vertical depth) LTP; SSSV 1,268' MD 1,201' TVD 483' MD/492' TVD 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: Scott Warner, Operations Engineer 324-272 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 499 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 scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 0 01908 0 750 85 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 221-114 50-133-20704-00-00 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: Private (SHL) / ADL 384372 Ninilchik / Beluga-Tyonek Gas Ninilchik Unit Paxton 11 Plugs Junk measured Length Production Liner 6,329' Casing Structural 5,020'7,596' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,512' 7,500psi 2,980psi 6,880psi 8,430psi 1,512' 1,380' Burst Collapse 1,410psi 4,790psi 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 2:07 pm, Jun 14, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.06.14 12:34:30 - 08'00' Noel Nocas (4361) Well Name: NINU Paxton 11 API #:50-133-20704-00-00 Field:Ninilchik Start Date:5/20/2024 Permit #:221-114 Sundry #:324-272 End Date:5/23/2024 5/20/2024 5/21/2024 5/22/2024 5/23/2024 Daily Operations: Activity Report PTW/PJSM, SITP 450 Perforate with well SI. T-10A from 6884'-6889' MD, T-10 from 6828'-6834' MD. T-9A from 6779'-6785' MD and T-7 from 6549'-6558' MD Final SITP 457 PTW/PJSM, PT 250/2000, Perforate shut in well, T-6 from 6478'-6488' MD, T-6 from 6442'-6452' MD, T-6 6399'-6419' MD Final SITP 694 PTW/PJSM. MIRU AK E-line. P-test 250/2,000 psi. SI well. SITP 365 psi. Perforate T-12 from 7,331' - 7,336' MD, T-11A from 7,056' - 7,069' MD, T-11A from 7,027' - 7,032' MD, and T-10B from 6,945' - 6,953' MD with well SI. Final SITP 442 psi. SDFN. PTW/PJSM, WELL SHUT IN. Perforate T-5B from 6332'-6342' MD, T-5 from 6212'-6222' MD. Perforate T-3 from 6071'-6077' & 6048'-6062' MD. Final SITP 545 Page 1 of 1 _____________________________________________________________________________________ Updated by DMA 05-30-24 SCHEMATIC Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 T-3 T-5 T-10 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2” TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status T-3 6,048'6,062'3,836'3,846'14'5/23/2024 Open T-3 6,071'6,077'3,853'3,858'6'5/23/2024 Open T-5 6,212'6,222'3,957'3,964'10'5/23/2024 Open T-5B 6,332'6,342'4,047'4,054'10'5/23/2024 Open T-6 6,399'6,419'4,098'4,114'20'5/22/2024 Open T-6 6,442'6,452'4,132'4,140'10'5/22/2024 Open T-6 6,478'6,488'4,160'4,168'10'5/22/2024 Open T-7 6,549'6,558'4,216'4,223'9'5/21/2024 Open T-7 6,562’6,574’4,226’4,235’12’2/14/2022 Open T-7U 6,616’6,623’4,268’4,273’7’2/14/2022 Open T-7L 6,626’6,635’4,275’4,282’9’2/14/2022 Open T-8U 6,663’6,674’4,304’4,313’11’2/14/2022 Open T-9A 6,779'6,785'4,394'4,399'6'5/21/2024 Open T-9AM 6,786’ 6,796’ 4,399’ 4,407’ 10’2/14/2022 Open T-9AL 6,798’ 6,802’ 4,409’ 4,412’ 4’2/14/2022 Open T-10 6,828' 6,834' 4,432' 4,437' 6' 5/21/2024 Open T-10A 6,884' 6,889' 4,475' 4,479' 5' 5/21/2024 Open T-10B 6,945' 6,953' 4,522' 4,528' 8' 5/20/2024 Open T-11U 6,966’ 6,970’ 4,538’ 4,541’ 4’2/14/2022 Open T-11M 6,988’ 6,993’ 4,555’ 4,559’ 5’2/14/2022 Open T-11L 7,015’ 7,020’ 4,576’ 4,580’ 5’2/14/2022 Open T-11A 7,027' 7,032' 4,585' 4,589' 5' 5/20/2024 Open T-11A 7,056' 7,069' 4,607' 4,617' 13' 5/20/2024 Open T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/10/2022 Open T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/11/2022 Open T-12 7,331' 7,336' 4,817' 4,821' 5' 5/20/2024 Open FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up @ ~7,440 (5/13/24) 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 7,600 feet N/A feet true vertical 5,023 feet ~7,440' (fish) feet Effective Depth measured 7,440 feet 1,268 feet true vertical 4,900 feet 1,201 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) Tieback 4-1/2" 12.6# / L-80 1,276' MD 1,207' TVD Packers and SSSV (type, measured and true vertical depth) LTP; SSSV 1,268' MD 1,201' TVD 483' MD/492' TVD 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: Scott Warner, Operations Engineer 324-272 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 499 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 scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 0 01908 0 750 85 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 221-114 50-133-20704-00-00 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: Private (SHL) / ADL 384372 Ninilchik / Beluga-Tyonek Gas Ninilchik Unit Paxton 11 Plugs Junk measured Length Production Liner 6,329' Casing Structural 5,020'7,596' 120'Conductor Surface Intermediate 16" 7-5/8" 120' 1,512' 7,500psi 2,980psi 6,880psi 8,430psi 1,512' 1,380' Burst Collapse 1,410psi 4,790psi 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 2:07 pm, Jun 14, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.06.14 12:34:30 - 08'00' Noel Nocas (4361) Well Name: NINU Paxton 11 API #:50-133-20704-00-00 Field:Ninilchik Start Date:5/20/2024 Permit #:221-114 Sundry #:324-272 End Date:5/23/2024 5/20/2024 5/21/2024 5/22/2024 5/23/2024 Daily Operations: Activity Report PTW/PJSM, SITP 450 Perforate with well SI. T-10A from 6884'-6889' MD, T-10 from 6828'-6834' MD. T-9A from 6779'-6785' MD and T-7 from 6549'-6558' MD Final SITP 457 PTW/PJSM, PT 250/2000, Perforate shut in well, T-6 from 6478'-6488' MD, T-6 from 6442'-6452' MD, T-6 6399'-6419' MD Final SITP 694 PTW/PJSM. MIRU AK E-line. P-test 250/2,000 psi. SI well. SITP 365 psi. Perforate T-12 from 7,331' - 7,336' MD, T-11A from 7,056' - 7,069' MD, T-11A from 7,027' - 7,032' MD, and T-10B from 6,945' - 6,953' MD with well SI. Final SITP 442 psi. SDFN. PTW/PJSM, WELL SHUT IN. Perforate T-5B from 6332'-6342' MD, T-5 from 6212'-6222' MD. Perforate T-3 from 6071'-6077' & 6048'-6062' MD. Final SITP 545 Page 1 of 1 _____________________________________________________________________________________ Updated by DMA 05-30-24 SCHEMATIC Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 T-3 T-5 T-10 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2” TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status T-3 6,048'6,062'3,836'3,846'14'5/23/2024 Open T-3 6,071'6,077'3,853'3,858'6'5/23/2024 Open T-5 6,212'6,222'3,957'3,964'10'5/23/2024 Open T-5B 6,332'6,342'4,047'4,054'10'5/23/2024 Open T-6 6,399'6,419'4,098'4,114'20'5/22/2024 Open T-6 6,442'6,452'4,132'4,140'10'5/22/2024 Open T-6 6,478'6,488'4,160'4,168'10'5/22/2024 Open T-7 6,549'6,558'4,216'4,223'9'5/21/2024 Open T-7 6,562’6,574’4,226’4,235’12’2/14/2022 Open T-7U 6,616’6,623’4,268’4,273’7’2/14/2022 Open T-7L 6,626’6,635’4,275’4,282’9’2/14/2022 Open T-8U 6,663’6,674’4,304’4,313’11’2/14/2022 Open T-9A 6,779'6,785'4,394'4,399'6'5/21/2024 Open T-9AM 6,786’ 6,796’ 4,399’ 4,407’ 10’2/14/2022 Open T-9AL 6,798’ 6,802’ 4,409’ 4,412’ 4’2/14/2022 Open T-10 6,828' 6,834' 4,432' 4,437' 6' 5/21/2024 Open T-10A 6,884' 6,889' 4,475' 4,479' 5' 5/21/2024 Open T-10B 6,945' 6,953' 4,522' 4,528' 8' 5/20/2024 Open T-11U 6,966’ 6,970’ 4,538’ 4,541’ 4’2/14/2022 Open T-11M 6,988’ 6,993’ 4,555’ 4,559’ 5’2/14/2022 Open T-11L 7,015’ 7,020’ 4,576’ 4,580’ 5’2/14/2022 Open T-11A 7,027' 7,032' 4,585' 4,589' 5' 5/20/2024 Open T-11A 7,056' 7,069' 4,607' 4,617' 13' 5/20/2024 Open T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/10/2022 Open T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/11/2022 Open T-12 7,331' 7,336' 4,817' 4,821' 5' 5/20/2024 Open FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up @ ~7,440 (5/13/24) 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): 7,600' ~7,320' (fish) Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production 7,500psi 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 scott.warner@hilcorp.com 907-564-4506 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 Scott Warner, 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 Private (SHL) / ADL 384372 221-114 50-133-20704-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 1,276' 8,430psi 1,380' Size 120' 1,512' MD See Attached Schematic 2,980psi 6,880psi 120'120' 1,512' May 17, 2024 Tieback 4-1/2" 7,596' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Ninilchik Unit Paxton 11CO 701C Same 5,020'4-1/2" ~1656 psi 6,329' N/A Length LTP; SSSV 1,268' MD/1,201' TVD; 483' MD/492' TVD 5,023' 7,509' 4,953' Ninilkchik Beluga-Tyonek Gas 16" 7-5/8" See Attached Schematic m n P s 66 t 2 N 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 9:48 am, May 06, 2024 BJM 5/9/24 DSR-5/6/24 10-404 Perforate SFD 5/6/2024JLC 5/9/2024 Well Prognosis Well: Paxton 11 Date: 5/3/24 Well Name: Paxton 11 API Number: 50-133-20704-00-00 Current Status: Producing Gas Well Permit to Drill Number: 221-114 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2143 psi @ 4870’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:1656 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.86 psi/ft using 16.7 ppg EMW LOT at the surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.86-0.1) = 1656 psi / 0.76 = 2179‘ TVD Top of Applicable Gas Pool: 1645’ MD/ 1468’ TVD Well Status: Online Gas Producer flowing at 499 mcfd, 0 bwpd, 75 psi FTP Brief Well Summary Paxton 11 is a grass roots well drilled in Feb 2022 targeting the Tyonek and Beluga Sands. Initial perforations were added from T-6 to T-12 and the well came online at 2.5 mmscfd. Production has been on steady decline since. The purpose of this sundry is to perforate additional footage in the Tyonek 3-13 sands to increase production. Notes Regarding Wellbore Condition 4-1/2” liner, tubing, and SSSV @ 483’ MD Inclination o Max deviation of 70° @ 2,436’ MD o Max DLS of 5°/100’ @ 1,349’ MD Recent Tags/Fish o 2/14/22: Roller bogey assembly fish left in hole while perforating 6663’-6626’. OAL: 28”, Max OD 3.60”. 3” of 1.53 OD stem looking up o 3/01/22: Log flowing GPT from surface to 7315’ at 120 FPM. No issues getting to bottom. Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,000 psi high 3. RIH and perforate Tyonek 3 - 13 sands while flowing from bottom up with 2-3/4” 60 deg phased perf guns: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sand Top MD Btm MD Top TVD Btm TVD Interval T-3 ±6,048' ±6,063' ±3,836' ±3,847' ±15' T-3 ±6,071' ±6,077' ±3,853' ±3,858' ±6' T-5 ±6,194' ±6,199' ±3,944' ±3,947' ±5' T-5 ±6,212' ±6,222' ±3,957' ±3,964' ±10' Top of Applicable Gas Pool: 1645’ MD Well Prognosis Well: Paxton 11 Date: 5/3/24 T-5A ±6,255' ±6,260' ±3,989' ±3,992' ±5' T-5B ±6,331' ±6,342' ±4,046' ±4,054' ±11' T-5B ±6,342' ±6,354' ±4,054' ±4,063' ±12' T-6 ±6,399' ±6,419' ±4,098' ±4,114' ±20' T-6 ±6,442' ±6,452' ±4,132' ±4,140' ±10' T-6 ±6,478' ±6,488' ±4,160' ±4,168' ±10' T-6 ±6,503' ±6,512' ±4,180' ±4,187' ±9' T-7 ±6,549' ±6,558' ±4,216' ±4,223' ±9' T-8 ±6,677' ±6,687' ±4,315' ±4,323' ±10' T-8 ±6,690' ±6,707' ±4,325' ±4,338' ±17' T-9A ±6,779' ±6,785' ±4,394' ±4,399' ±6' T-10 ±6,827' ±6,834' ±4,431' ±4,437' ±7' T-10A ±6,884' ±6,889' ±4,475' ±4,479' ±5' T-10B ±6,902' ±6,906' ±4,489' ±4,492' ±4' T-10B ±6,945' ±6,953' ±4,522' ±4,528' ±8' T-11A ±7,027' ±7,032' ±4,585' ±4,589' ±5' T-11A ±7,056' ±7,069' ±4,607' ±4,617' ±13' T-11A ±7,121' ±7,126' ±4,657' ±4,661' ±5' T-12 ±7,218' ±7,250' ±4,731' ±4,756' ±32' T-12 ±7,331' ±7,336' ±4,817' ±4,821' ±5' T-13 ±7,391' ±7,400' ±4,863' ±4,870' ±9' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations _____________________________________________________________________________________ Updated by DMA 05-03-24 SCHEMATIC Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2” TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T-6AL 6,562’ 6,574’ 4,226’ 4,235’ 12’02-14-22 Open T-7U 6,616’ 6,623’ 4,268’ 4,273’ 7’02-14-22 Open T-7L 6,626’ 6,635’ 4,275’ 4,282’ 9’02-14-22 Open T-8U 6,663’ 6,674’ 4,304’ 4,313’ 11’02-14-22 Open T-9AM 6,786’ 6,796’ 4,399’ 4,407’ 10’02-14-22 Open T-9AL 6,798’ 6,802’ 4,409’ 4,412’ 4’02-14-22 Open T-11U 6,966’ 6,970’ 4,538’ 4,541’ 4’02-14-22 Open T-11M 6,988’ 6,993’ 4,555’ 4,559’ 5’02-14-22 Open T-11L 7,015’ 7,020’ 4,576’ 4,580’ 5’02-14-22 Open T-12U 7,198’7,215’4,715’4,729’ 17’ 02-10-22 02-11-22 Open FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up @ ~7,320’ _____________________________________________________________________________________ Updated by DMA 05-03-24 PROPOSED Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2” TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD FT Date Status T-3 ±6,048'±6,063'±3,836'±3,847'±15'Proposed TBD T-3 ±6,071'±6,077'±3,853'±3,858'±6'Proposed TBD T-5 ±6,194'±6,199'±3,944'±3,947'±5'Proposed TBD T-5 ±6,212'±6,222'±3,957'±3,964'±10'Proposed TBD T-5A ±6,255'±6,260'±3,989'±3,992'±5'Proposed TBD T-5B ±6,331'±6,342'±4,046'±4,054'±11'Proposed TBD T-5B ±6,342'±6,354'±4,054'±4,063'±12'Proposed TBD T-6 ±6,399'±6,419'±4,098'±4,114'±20'Proposed TBD T-6 ±6,442'±6,452'±4,132'±4,140'±10'Proposed TBD T-6 ±6,478'±6,488'±4,160'±4,168'±10'Proposed TBD T-6 ±6,503'±6,512'±4,180'±4,187'±9'Proposed TBD T-7 ±6,549'±6,558'±4,216'±4,223'±9'Proposed TBD T-6AL 6,562’6,574’4,226’4,235’12’2/14/2022 Open T-7U 6,616’ 6,623’ 4,268’ 4,273’ 7’2/14/2022 Open T-7L 6,626’ 6,635’ 4,275’ 4,282’ 9’2/14/2022 Open T-8U 6,663’ 6,674’ 4,304’ 4,313’ 11’2/14/2022 Open T-8 ±6,677' ±6,687' ±4,315' ±4,323' ±10' Proposed TBD T-8 ±6,690' ±6,707' ±4,325' ±4,338' ±17' Proposed TBD T-9A ±6,779' ±6,785' ±4,394' ±4,399' ±6' Proposed TBD T-9AM 6,786’ 6,796’ 4,399’ 4,407’ 10’2/14/2022 Open T-9AL 6,798’ 6,802’ 4,409’ 4,412’ 4’2/14/2022 Open T-10 ±6,827' ±6,834' ±4,431' ±4,437' ±7' Proposed TBD T-10A ±6,884' ±6,889' ±4,475' ±4,479' ±5' Proposed TBD T-10B ±6,902' ±6,906' ±4,489' ±4,492' ±4' Proposed TBD T-10B ±6,945' ±6,953' ±4,522' ±4,528' ±8' Proposed TBD T-11U 6,966’ 6,970’ 4,538’ 4,541’ 4’2/14/2022 Open T-11M 6,988’ 6,993’ 4,555’ 4,559’ 5’2/14/2022 Open T-11L 7,015’ 7,020’ 4,576’ 4,580’ 5’2/14/2022 Open T-11A ±7,027' ±7,032' ±4,585' ±4,589' ±5' Proposed TBD T-11A ±7,056' ±7,069' ±4,607' ±4,617' ±13' Proposed TBD T-11A ±7,121' ±7,126' ±4,657' ±4,661' ±5' Proposed TBD T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/10/2022 Open T-12U 7,198' 7,215' 4,715' 4,729' 17' 2/11/2022 Open T-12 ±7,218' ±7,250' ±4,731' ±4,756' ±32' Proposed TBD T-12 ±7,331' ±7,336' ±4,817' ±4,821' ±5' Proposed TBD T-13 ±7,391' ±7,400' ±4,863' ±4,870' ±9' Proposed TBD FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up @ ~7,320 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. DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20704-00-00Well Name/No.NINILCHIK UNIT PAXTON 11Completion Status1-GASCompletion Date2/14/2022Permit to Drill2211140OperatorHilcorp Alaska, LLCMD7600TVD5023Current Status1-GAS9/9/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:LWD, CBL 2-6-22, GPT, Perf, MudlogNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF2/8/202110 7700 Electronic Data Set, Filename: Paxton 11.las36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Daily Reports.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Final Well Report.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log MD 2in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log MD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log TVD 2in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log TVD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log MD 2in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log MD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log TVD 2in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log TVD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log MD 2in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log MD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log TVD 2in.pdf36316EDDigital DataFriday, September 9, 2022AOGCC Page 1 of 5Suppliedby OPSuppliedby OPPaxton 11.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20704-00-00Well Name/No.NINILCHIK UNIT PAXTON 11Completion Status1-GASCompletion Date2/14/2022Permit to Drill2211140OperatorHilcorp Alaska, LLCMD7600TVD5023Current Status1-GAS9/9/2022UICNoDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log TVD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log MD 2in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log MD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log TVD 2in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log TVD 5in.pdf36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log MD 2in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log MD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log TVD 2in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Drilling Dynamics Log TVD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log MD 2in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log MD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log TVD 2in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Formation Log TVD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log MD 2in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log MD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log TVD 2in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Gas Ratio Log TVD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log MD 2in.tif36316EDDigital DataFriday, September 9, 2022AOGCC Page 2 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20704-00-00Well Name/No.NINILCHIK UNIT PAXTON 11Completion Status1-GASCompletion Date2/14/2022Permit to Drill2211140OperatorHilcorp Alaska, LLCMD7600TVD5023Current Status1-GAS9/9/2022UICNoDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log MD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log TVD 2in.tif36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 LWD Combo Log TVD 5in.tif36316EDDigital DataDF2/8/2021 Electronic File: PAXTON_11.dbf36316EDDigital DataDF2/8/2021 Electronic File: paxton_11.hdr36316EDDigital DataDF2/8/2021 Electronic File: PAXTON_11.mdx36316EDDigital DataDF2/8/2021 Electronic File: paxton_11r.dbf36316EDDigital DataDF2/8/2021 Electronic File: paxton_11r.mdx36316EDDigital DataDF2/8/2021 Electronic File: PAXTON_11_SCL.DBF36316EDDigital DataDF2/8/2021 Electronic File: PAXTON_11_SCL.MDX36316EDDigital DataDF2/8/2021 Electronic File: PAXTON_11_tvd.dbf36316EDDigital DataDF2/8/2021 Electronic File: PAXTON_11_tvd.mdx36316EDDigital DataDF2/8/2021 Electronic File: Paxton 11 Show Reports.pdf36316EDDigital Data0 0 2211140 PAXTON 11 LOG HEADERS36316LogLog Header ScansDF2/25/202285 7600 Electronic Data Set, Filename: Paxton 11 LWD Final.las36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 LWD Final MD.cgm36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 LWD Final TVD.cgm36376EDDigital DataDF2/25/2022 Electronic File: Paxton #11_Definitive Survey Report.txt36376EDDigital DataDF2/25/2022 Electronic File: Paxton #11_DSR_GIS.txt36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 - Definitive Survey Report.pdf36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 - Final Surveys.xlsx36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11_DSR Actual_Plan.pdf36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11_DSR Actual_VSec.pdf36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 LWD Final MD.emf36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 LWD Final TVD.emf36376EDDigital DataFriday, September 9, 2022AOGCC Page 3 of 5Paxton 11 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20704-00-00Well Name/No.NINILCHIK UNIT PAXTON 11Completion Status1-GASCompletion Date2/14/2022Permit to Drill2211140OperatorHilcorp Alaska, LLCMD7600TVD5023Current Status1-GAS9/9/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:2/14/2022Release Date:12/30/2021DF2/25/2022 Electronic File: Paxton 11 LWD Final MD.pdf36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 LWD Final TVD.pdf36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 LWD Final MD.tif36376EDDigital DataDF2/25/2022 Electronic File: Paxton 11 LWD Final TVD.tif36376EDDigital DataDF3/8/2022-14 7316 Electronic Data Set, Filename: Paxton 11_GPT_1-Mar-2022_(3673).las36409EDDigital DataDF3/8/2022 Electronic File: Paxton 11_GPT_1-Mar-2022_(3673).pdf36409EDDigital DataDF3/15/2022760 519 Electronic Data Set, Filename: Paxton 11_CBL_06-Jan-2022_(3647).las36415EDDigital DataDF3/15/20227338 7035 Electronic Data Set, Filename: Paxton 11_Switch Gun Perf_14-Feb-2022_(3651).las36415EDDigital DataDF3/15/2022 Electronic File: Paxton 11_CBL_06-Jan-2022_(3647).pdf36415EDDigital DataDF3/15/2022 Electronic File: Paxton 11_Switch Gun Perf_14-Feb-2022_(3651).pdf36415EDDigital Data3/2/20221520 760061801CuttingsFriday, September 9, 2022AOGCC Page 4 of 5 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-133-20704-00-00Well Name/No.NINILCHIK UNIT PAXTON 11Completion Status1-GASCompletion Date2/14/2022Permit to Drill2211140OperatorHilcorp Alaska, LLCMD7600TVD5023Current Status1-GAS9/9/2022UICNoComments:Compliance Reviewed By:Date:Friday, September 9, 2022AOGCC Page 5 of 5M. Guhl9/9/2022 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 03/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 11 (PTD 221-114) CBL 01/06/2022 Switch Gun Perf 02/14/2022 Please include current contact information if different from above. 221-114 T36415 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.15 14:24:20 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Ninilchik Field GL:148.5' BF:N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" X-56 120' 7-5/8" L-80 1,377' 4-1/2" L-80 5,020' 4-1/2" L-80 1,207' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Tieback Assy. Tieback TUBING RECORD SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): L - 485 sx / T - 95 sx Surface Conductor Surface 1,512' L - 215 sx / T - 210 sx Driven STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 2/14/2022 945' FNL, 3092' FEL, Sec 13, T1S, R14W, SM, AK 1094' FNL, 2319' FWL, Sec 12, T1S, R14W, SM, AK 221-114 / 322-022 Beluga / Tyonek Gas Pool 166.5' 7,509' MD / 4,953' TVD HOLE SIZE AMOUNT PULLED 50-133-20704-00-00 Paxton 11 206232 2230420 1717' FNL, 2503' FWL, Sec 12, T1S, R14W, SM, AK CEMENTING RECORD 2234829 SETTING DEPTH TVD 2235456 BOTTOM TOP 6-3/4" 75 bbls 33 bbls Surface 9-7/8"Surface CASING WT. PER FT.GRADE 12.6# 206655 206487 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 12.6# 1,276' 1,200' Surface DEPTH SET (MD) PACKER SET (MD/TVD) 84# 29.7# 120' 1,268' 7,596' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST 2/10/2022 Date of Test: 0 2/26/2022 24 Flow Tubing 0 2582 Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A2582 Flowing *** See attached schematic for perforation detail *** 0 LWD, CBL 2-6-22, GPT, Perf, Mudlog Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 00100 January 29, 2022 January 18, 2022 Private (SHL), ADL 384372 LOCI 04-007 N/A N/AN/A 483' MD / 482' TVD 7,600' MD / 5,023' TVD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 7:47 am, Mar 08, 2022 Completion Date 2/14/2022 MDG RBDMS 3/8/2022 MDG GDLB 04/26/2022 DSR-3/8/22BJM 09/06/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval T-6 6,562' 4,226' 960' 937' 1,045' 1,012' 5,874' 3,706' 6,369' 4,075' 6,590' 4,248' 6,637' 4,284' 6,713' 4,343' 6,955' 4,530' 7,147' 4,677' 7,545' 4,981' T-14 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: FORMATION TESTS Permafrost - Top Sterling 6 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports. Signature w/Date: T-7 Bel A T-6 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): T-12 Bel 136 Formation at total depth: T-8 T-9 Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME T-11 Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). T-14 Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Title: Drilling Manager No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 3.7.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.03.07 15:09:56 -09'00' Monty M Myers _____________________________________________________________________________________ UpdatedBy: CJD03/07/22 SCHEMATIC Ninilchik Unit Paxton 11 PTD: 221-114 API: 50-133-20704-00-00 T-6 1 2 3 PBTD = 7,509’ / TVD = 4,953’ TD = 7,600’ / TVD = 5,023’ F1 T-7 T-8 T-11 T-12 T-9 RKB to GL = 18’ 16” 9-7/8” hole 7-5/8” 6-3/4” hole 4-1/2” CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 7-5/8"Surf Csg 29.7 L-80 CDC 6.875”Surf 1,512’ 4-1/2"Prod Lnr 12.6 L-80 DWC/C HT 3.958”1,268’7,596 4-1/2"Prod Tieback 12.6 L-80 DWC/C HT 3.958”Surf 1,276’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 483’482’3.613”5.500”SSSV 2 1,268’1,201’4.875”6.540”Liner hanger / LTP Assembly 3 1,276’1,207’4.790”6.340”Seal Stem (8’ stung into tieback receptacle) OPEN HOLE / CEMENT DETAIL 7-5/8"TOC @ Surface (100% excess Returns t/surface 1/20/22) 4-1/2”TOC @ 1364’ (CBL 02-06-2022) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status T-6AL 6,562’6,574’4,226’4,235’12’02-14-22 Open T-7U 6,616’6,623’4,268’4,273’7’02-14-22 Open T-7L 6,626’6,635’4,275’4,282’9’02-14-22 Open T-8U 6,663’6,674’4,304’4,313’11’02-14-22 Open T-9AM 6,786’6,796’4,399’4,407’10’02-14-22 Open T-9AL 6,798’6,802’4,409’4,412’4’02-14-22 Open T-11U 6,966’6,970’4,538’4,541’4’02-14-22 Open T-11M 6,988’6,993’4,555’4,559’5’02-14-22 Open T-11L 7,015’7,020’4,576’4,580’5’02-14-22 Open T-12U 7,198’7,215’4,715’4,729’17’02-10-22 02-11-22 Open FISH DETAIL F1 Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up Activity Date Ops Summary 1/13/2022 Held PJSM with rig crews at CCI yard, staged and started light plants around the rig, L/D BOP cradle, double checked mods for road travel, held PJSM with CCI crew.;Tore out boiler skid, pump 2, doghouse/water tank, pump 1, HPU skid, gen skid, spacing jig, pit 3-2-1, spotted cranes, RU and picked derrick and drill line spool off carrier, picked carrier off sub, picked sub off pony walls. Sent one crew to Paxton pad to clear snow off;rig mats ahead of transport rig.;CCI transported sub, pony walls, carrier, derrick, pump 2, gen skid to mile 131.2 (paxton pad), staged pony walls on mats.;Offloaded sub on pad and transferred to bed truck, spotted sub over well, spotted cranes, raised sub and slid pony walls in to position under sub, centered over wellhead, folded out landings, set stairs and handrails. Set carrier on sub, set derrick and pinned on sub, set drill line spool.;Transported 3 pit mods and HPU skid to paxton pad from Nikiski. Raise derrick board windwalls with crane and shut down for the night. 1/14/2022 At CCI yard stacked rig mats, cleaned off and rolled up pit liner, prepped push shack and foremans trailer for transport. On Paxton, fired up light plants, scarified pad and access road due to rain and ice, CCI delivered spacer jig and set same. Set pit 1, spotted crane and flew iron roughneck to;rig floor, raised v door windwall and flew choke house to rig floor. Raised roof on pit 1, stood mast, set both pump skids, set HPU skid, set gen skid, set doghouse/water tank, set pits 2 and 3, raised doghouse. Spot crane and hung windwalls and clam shell. Set boiler skid, set poorboy;degasser, raised vac degasser in pits, cont to string cords, fired up gen and lit up rig, install roof top lights, set cuttings box with crane.;Set centrifuge stand in cuttings box, set 10' connex on pit 3. Received sleeper, push shack and foreman's trailer. Set the three trailers. Set bang box and gen set, wired in and powered up. Brought in gen, change shack and break shack, spotted same. Prep derrick to scope install turnbuckles on;upper torque tube, install cameras around rig, hook up pason system and continue running lines, prep and spool up and slip drilling line on drum, continue prepping derrick to scope up, install weight indicators and guards on draw works, obtain RKB 19.55' Rig floor to flange, hook up pit;interconnects, get heaters going in boiler house, continue hooking up rig systems 1/15/2022 Lay out felt and liner for catwalk, CCI transported rig's loader, Handy Berm connex, bulk fuel tank and catwalk to location. Crew pinned lower torque tube to upper section, held PJSM and scoped up derrick. CCI set catwalk in place, lay over beaver slide. Took on potable water in trailers, spotted;comm tower and RU comm's. Set three service shacks, wired in and powered up mud lab. Set upright water tank, installed vent line on poorboy degasser then raised same. Start install of Handy Berm around rig, adjusted torque tube height in derrick to connect T bar, RU plumbing to degasser, took on rig;water..;Continue adjusting torque tube in derrick, install gas buster lines and hook up choke lines, spot in gen 3 and fuel cell and berm in, build hoses f/ boiler, spot top drive and prep to pick to rig floor, Hoist to floor and stand up in cradle hook to top drive and remove cradle, P/U torque bushing and;attach to top drive and torque tube, hook up extend cylinders, hook up service loop and kelly hose, hang tarps around rig and cellar, R/U and take on water to boiler and begin staging up to pressure and temp, fill hot well, M/U IBOP and saver sub install clamps, change grabber dies, blow air through;water line and pressure test, 1/16/2022 Put steam on line through the rig and worked on a couple leaks, installed steam traps. Dressed rig floor and topdrive with handling equipment. Tied in gen three to fuel and power. RU Pason sensors and weight indicator. Powered up mud log shack and DD shack. RU comm's to mud loggers. RU iron;roughneck HPU, test ran, had to reverse rotation and replace hydraulic hose. Installed valves and squirrel cages in mud pumps. Greased crown, blocks, brake linkage and topdrive. Built mud dock and off loaded spud mud product. Ran 2" water line from wellhouse to rig and start filling rig tank.;Notified Lead OP and got OK for rig electrician to trouble shoot water well breaker issue. Worked through that and got rig water tank filled. set last of windwalls around cuttings box and installed roof top hooch to hold heat in pits. Installed 4" valves on conductor outlets. Chase down conductor;20" riser sections. Cont hanging tarps throughout the pits. Offload 2nd trailer of mud product.;Install rig floor framework for tarps. Thaw suction valves in pits (open valves frozen into sumps), service shakers, dress #2 mud pump, Load 20'' riser on truck and sent to location, continue thaw pit suctions and valves in pits, clean up starting head, install more heaters in cellar;Work on rig acceptance checklist, Install remaining tarps and put up felt in doorways and open areas to keep in heat, riser on location put in cellar and start N/U 20'' Split Riser, continue working on Rig acceptance, test all e stops on mud pumps and generators 1/17/2022 Install control panel for gas alarms in doghouse and power up, installed batteries in all sensors and install those in their dedicated stations. Welder on location and trimming 10" out of upper riser section to lower flow line outlet. Welder repaired crack on centrifuge stand in cuttings box. CCI;covered DP bunk and set up portable heater to warm pipe for PU/rack back. Cont working rig acceptance checklist. Quadco Rep enroute from Anchorage to calibrate and test gas alarm equipment. Sent AOGCC and Jim Regg notifications for inspection/witness alarm testing.;Received 4028 gals diesel for rig, worked upper riser section into cellar and installed same, leveled sub, installed 4 way chains to secure stack, installed flow line to shakers, installed Pason flow paddle and calibrated same. spotted hurricane vac and test ran unit. Expediter located sub basket at;Rig Tenders dock, sorted subs for transport to rig. Start transfer rig water to pit 9 to check surface plumbing and pumps. Checked ESD's on mud pumps. Estimated arrival of centrifuge is this coming Wednesday.;Continue rolling water through pits checking systems, load and strap DP on racks, P/U and stand back 50 jts in derrick, strap and tally 17 jts of HWDP and M/U and stand back, mix spud mud in pits, install pop off valve on #2 boiler fill boiler with water and stage up to pressure and temp, R/U splash;guard around top of riser, trouble shoot Kelly Hose timing issues discuss options with town, hose is rotating on pressed fitting. Witness waived by AOGCC Jim Regg for witnessing alarm testing or inspection at 21:54 on 1-17-21 18 n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Paxton 11 Ninilchik Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00015 Paxton 11 Drilling Spud Date: ppg p Witness waived by AOGCC Jim Regg for witnessing alarm testing or 1/18/2022 Cont building spud mud, cont troubleshooting and tightening loose fittings on kelly hose, received Sperry directional tools, re-installed kelly hose and ran blocks through derrick numerous times with no fittings issue. Cont PU rack back HWDP and jars. Racked and strapped Sperry tools. Quadco Rep;finished testing gas alarms and lights. Cont working rig acceptance checklist.;Re-tuned kelly hose for travel in derrick, received surface casing, centralizers, hanger and landing joint. Rack casing and remove thread protectors. Blew air through surface lines from pumps to topdrive. Tightened swivel packing, rebuilt pop off on pump #1, re- tested line with air, flooded lines;from pumps to topdrive with water, tested to 1800 psi with no issue. Blew down topdrive. Received truckload of barite for well control contingency. Received 2nd load surface casing and shoe track. Accepted rig @ 18:00 hrs.;Racked casing, removed thread protectors and drifted same. Hooked up Pason to Sperry and Geo-log shacks. Strapped & tallied casing. Finished testing MWD surface tools. Staged BHA #1 on catwalk.;Held PJSM w/ rig crew, Halliburton, and DSM on P/U BHA.;P/U 9 7/8" directional surface BHA #1- bit, motor (1.5° bend), DM collar, DGR collar, PWD collar, ALD collar, and TM collar. Plugged in and uploaded tools.;Crew change, held PTSM. Finished uploading data, M/U remainder of first stage of tools.;Spudded 9 7/8" surface hole @ 02:00 hrs. Drilled F/135'-T/211', CBU. P/U-23K S/O-23K ROT-23K GPM-386K SPP-587K WOB-15K TQ-3.8K RPM-30 MW-8.7 ppg ECD-9.0 ppg.;POOH F/211'- T/119', P/U flex collars and 1 std of HWDP.;Cont. directional drilling 9 7/8" surface hole F/211' to current depth of 388'. P/U-27K S/O-30K ROT-27K GPM-406K SPP-906K WOB-10K TQ-3.9K RPM-30 MW-8.7 ppg ECD-9.37 ppg. Distance to well plan: 1.13' 1.12' High .16' Right;Hauled 0 bbls of solids to KGF G&I Cumulative: 0 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 0 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 0 bbls Daily Metal: 0 lbs. Cumulative: 0 lbs. 1/19/2022 Cont directional drilling 9 7/8" surface from 388' to 395', CBU, pulled up hole to 273', MU jar stand, TIH to 395' and filled pipe.;Resumed drilling surface from 395' to 828'. Sliding wob 10K, 450 gpm-1098 psi, 23 psi diff, 190 ft/hr ROP. Rotating wob 12K, 495 gpm-1410 psi, 62 rpm-4781 ft/lbs on bott torque, 200 ft/hr ROP, MW 8.7/vis 206, ECD's at 9.1 ppg, BGG 1-3 units.;At 828' CBU one time, 495 gpm-1400 psi, 61 rpm-3775 ft/lbs off bott torque. Obtained survey on bottom, flow check = static. Received Halliburton cement compressor and pump skid. Received wellhead "B" section and packoff run tool.;Pulled up hole from 828' to top of jars at 338' with no issue, up wt 44K.;Service rig and topdrive.;TIH from 338' to 767' with no issue, MU last stand, fill pipe, wash/ream to bottom. Received and set cement silo, start offload lead cement.;Cont drilling 9 7/8" hole from 828' to 1144' (Beluga C), Rotating wob 10K, 512 gpm-1547 psi, 60 rpm-4700 ft/lbs on bott torque, 20 to 200 ft/hr ROP. Sliding wob 14K, 530 gpm-1636 psi, 104 psi diff, 58 to130 ft/hr ROP, MW 8.9/vis 152, ECD's at 9.5 ppg, BGG 28 units, max gas 40 units.;Cont. drilling 9 7/8" surface hole F/1144' -T/1495'. GPM-530 SPP-1700 psi Diff-80 psi RPM-60 TQ-5.4K WOB-15K Max gas 54 units ECD-9.6 ppg P/U-50K S/O-44K ROT-48K.;Crew change, held PTSM. Cont. drilling 9 7/8" surface hole F/1495' to TD @ 1521'. GPM-530 SPP-1700 psi Diff-32 psi RPM-60 TQ- 5.4K WOB-15K Max gas 16 units ECD-9.6 ppg P/U-50K S/O-48K ROT-48K.;CBU X 2 till shakers cleaned up, shot on bottom survey, flow check (static). Blew down TDS.;POOH on elevators F/1521'-T/300' w/ no issues. P/U-35K S/O-35K. Had calculated hole file for the trip.;Serviced Rig- Greased crown, blocks, TD, DWKS, break linkage, drive shaft, and IR. Checked bolts on TD motor. Cleaned both MP suction and discharge screen. Monitored well on the TT during rig service-Static.;RIH on elevators F/300'-T/1512' w/ no issues, washed last 9' to bottom w/ no fill. Had calculated pipe displacement for the trip.;CBU. Pumped 20 bbls Hi-Vis sweep w/ walnut & condet, sweep came back on time w/ a 50% increase in cuttings. Shut down pumps, flow checked (static).;POOH on elevators F/1521' to current depth 828'. Distance to well plan: 12.07' 11.72' High 2.89' Right.;Hauled 240 bbls of solids to KGF G&I Cumulative: 240 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 0 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 0 bbls Daily Metal: 0 lbs. Cumulative: 0 lbs. 1/20/2022 Cont POOH from 828' to jar stand, LD single HWDP and jars, POOH to NM flex DC's and lay down two singles, POOH to smart tools, plug in and download MWD data, Cont POOH LD remainder Sperry directional tools. Flush motor with water and break off bit. Bit graded a 1-1 and in gauge.;Calculated hole fill = 19.5 bbls, actual hole fill = 22 bbls. Sent notification to AOGCC for up coming BOP test followed with surface casing test (MIT) at 08:01 on 1-20-22.;Drained conductor riser, PU test joint, MU run tool and pulled wear ring. PU landing joint/hanger and dummy ran-marked (landed at 20.21') and LD same. RU fill up hose, staged centralizers. Received notice from AOGCC Rep for witness of BOP test at 09:45 on 1-20-22.;Staged Weatherford equipment on catwalk, PU and RU to run casing, held PJSM.;MU 7 5/8" shoe track, top filled and checked floats (OK), cont PU single in hole with 7 5/8" USS-CDC 29.7# L-80 casing, top filling on the fly, topping off every 10 jnts, installed bowspring centralizer every other joint up to 297'. Torqued to 15,500 ft/lbs. At 1485' MU landing joint/hanger, SO and;landed on hanger. Up wt 55K, down wt 40K. Received centrifuge, feed pump and control panel. Finished building first batch of 6% KCL PHPA mud.;MU circ swedge and topdrive, broke circ at 136 gpm-45 psi, staging up to 213 gpm-0 psi. Staged Halliburton compressor and bulk truck. Tied in hardline from pump skid to rig floor, had issues getting 3 motors started on pump skid but worked through it. Staged plug launcher on rig floor, loaded plugs.;Shut down rig pump, broke off topdrive and swedge, blew down topdrive. Installed plug launcher on landing joint, MU circ hardware and resumed circ with rig while holding PJSM with rig team and cementers.;Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 586 psi low 3620 psi high, good tests. Halliburton pumped 41 bbls 10.5 ppg Tuned Spacer at 4 bpm-72 psi, dropped bottom plug and pumped 92 bbls (215 sx) 12 ppg Type I II lead cement at 4 bpm-110;psi, followed by 45 bbls (210 sx) 15.8 ppg Type I II tail cement at 1.2 bpm-40 psi. Halliburton dropped top plug, then rig displaced with 9.2 ppg Spud Mud at 5 bpm 192 psi. Slowed pump to 3.2 bpm with 20 bbl to go. Did bump the plug at 65.2 bbls into displacement (calculated 66 bbls).;Held 1270 psi (FCP of 469 psi) for 3 minutes, bled off and floats held. Bled back 1.3 bbls to pits. Had 41 bbls of Spacer returns to surface and 60 bbls lead cement to surface. Added LCM to lead cement at 6 ppb (Bridge Maker). Mix water temp 81 deg. Pumped 100% excess on both lead and tail.;Lost 0 bbls throughout the job. Did reciprocate. CIP at 21:18, 1/20/2022. RD, washed up, and released Halliburton.;R/D buddy bails. backed out and pulled landing joint. Flushed stack and cleaned out cellar box. Worked on cleaning out mud pits 1-3 & 6, and hauling off Spud Mud.;M/U pack off and running tool to landing joint, run in and set pack off, RILD's, WHR tested pack off void 2500 psi high for 10 min (ok). B/O landing joint and L/D.;N/D surface riser, cont. cleaning pits and hauling off mud.;Crew change, held PTSM. Finished N/D surface riser. Cont. working on cleaning pits. CCI crane operators arrived on location and spotted crane @ 01:00 hrs.;Installed & N/U B section on wellhead w/ WHR. Tested void on B section (ok). CCI crane operators arrived on location, spotted, set, and R/U crane. Set BOP/cradle w/ winch truck next to cellar. Raised BOP in cradle, installed BOP lifting plates w/ loader. Tailed BOP stack into sub base w/ crane.;Halliburton pump operator was walking next to the pump on the herculite. His feet slipped out from under him and he felt a pop in his right knee. He had instant pain in his knee. As time went on the pain went down. Lead Halliburton cementer informed night DSM at 01:45 hr. on 1/21/2022.;After talking to hand, his knee just felt sore at this point. He decided to go back to the Haliburton camp and rest his knee for the night. Lead Halliburton cementer said he would follow up with the DSM’s on location in the morning on the condition of the hands knee.;R/D BOP cradle. Reinstalled sub base wind wall tarps. Installed trolley beam under rotary table. started N/U BOP to B section. At 05:45 hrs. CCI lead notified night DSM about vehicle accident. Parker electrician slide down the hill coming onto the Paxton pad and came into contact;w/ CCI vac truck in his personal vehicle. No one was hurt. Hilcorp safety and all proper personal were contacted.;Hauled 0 bbls of solids to KGF G&I Cumulative: 240 bbls Hauled 430 bbls of fluid to KGF G&I ;Spudded 9 7/8" surface hole @ gg p 02:00 hrs. Drilled F/135'-T/211', pp p , bled off and floats held. Bled gqp cont PU single in hole with 7 5/8" USS-CDC 29.7# L-80 casing, p yy r electrician slide down the hill coming onto the Paxton pad and came into contact;w/ CCI vac truck in his personal vehicle. No one was hurt. pp Pumped 100% excess on both lead and tail. pp p p g gp Did bump the plug at 65.2 bbls into displacement (calculated 66 bbls))p 60 bbls lead cement to surface. ) gp His feet slipped out from under him and he felt a pop in his right knee. He had instant pain in hisppp g pp pp pp g p knee. As time went on the pain went down. Lead Halliburton cementer informed night DSM at 01:45 hr. on 1/21/2022.;After talking to hand, his knee just felt sore at this point. H CCI lead notified night DSM about vehicle accident. g pp Cont. drilling 9 7/8" surface hole F/1495' to TD @ 1521' p ppgg pumped 92 bbls (215 sx) 12 ppg Type I II lead cement at 4pp ppg p p p pp bpm-110;psi, followed by 45 bbls (210 sx) 15.8 ppg Type I II tail cement at 1.2 bpm-40 psi. pp ;Lost 0 bbls throughout the job. 1/21/2022 Secure BOP stack to wellhead, removed lift plates and leveled up annular flange, hammered up entire stack, installed manual valves. Cont to assemble centrifuge feed pump and motor in it’s stand. Cont cleaning pits.;Hauling off trash fluid was delayed due to weather and road conditions. AOGCC Rep driving down from Anchorage will overnight in Soldotna then be on location by 08:00 tomorrow to witness initial BOP test of 5K, Quadco on the hook for 10:00 tomorrow to test gas alarms/lights with witness.;Install HCR valves, new kill and choke shock hose with whipcheck’s. Installed koomey lines. Prep test joint with TW and dart for shell test while cont NU. Cont building 6% KCL mud in pits 9 and 10. Install VBR and blind rams, function test same. Flood stack in prep to shell test.;RU test equipment for shell test. attempted to shell test T/5000 psi. Double gate flanges leaking, re-tighten bag, double gate, mud cross and single gate flanges. Retested-side outlet blanking flanges on double gate leaking, retighten blanking flanges. Retested- passing test.;R/D testing jt. Bled off koomey hoses, installed BOP lifting plates on annular. Finished building final batch of 6% KCL PHPA mud.;Crew change, held PJSM. Finished N/U BOP. Installed flow box, flow line, hammer seal flange, and riser. Installed chains and binders to secure stack. Greased Mez kill and both HCR valves. Cleaned cellar area of tools and misc. items. Obtained RKM measurements. Racked and strapped 4.5" DP.;Connected HYD lines to annular, energized koomey, function tested rams and HCR's, R/U testing equip. M/U test jt. Set test plug. Flooded stack & choke manifold. Purged out air, Performed shell test against UPR, CMV 11, 12, 13, Mez kill valve. Transducers on choke manifold & test manifold failed.;Rebuilt and reinstalled same. Pressured up again, observed leaks between BOP and wellhead flanges and between choke manifold and electric choke flanges. Bled down and hammered up flanges.;Attempted to pressure up again. started leaking again between the the BOP to well head flanges, hammered up. Pressure up again, leaking on electric choke flanges. Hammered it up and got a good 5000 psi shell test.;P/U test jt. and M/U to test plug, M/U TDS to pump in sub, R/U for BOP test #1. Refilled line/purged air, pressured up to verify electric choke clocking position is correct. Currently working on housekeeping around rig and R/U centrifuge.;Hauled 0 bbls of solids to KGF G&I Cumulative: 240 bbls Hauled 340 bbls of fluid to KGF G&I Cumulative: 770 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 0 bbls Cumulative 0 bbls Daily Metal: 0 lbs. Cumulative: 0 lbs. 1/22/2022 Houseclean around rig, scarify pad and access road, change oil/filters on floor motor. AOGCC Rep Lou Laubenstein on location at 07:00 to witness BOP test.;Tested all BOPE at 250 low and 5000 high for 5 min each with 4 1/2" test joint. Had F/P on choke line flange, bled off, tightened flange, re-tested ok. Had F/P on lower variable rams, replaced variable rams with solid body rams, re-tested ok. Had F/P on shaker LEL sensor. Quadco Rep;replaced batteries and calibrated sensor, re-tested ok. Total test time 5 hrs. Mechanic and motorman changed oil and filters on floor motor transmission. Swapped both mud pumps to 5" liners and swabs.;State inspector witnessed 7 5/8” surface casing test of 3500 psi for 30 min on chart, good test, pumped 37.95 gallons, bled back 37.95 gallons. Got centrifuge feed pump assembled.;RD test equipment and blew down surface equipment. Set 9" ID wear ring, LD test joint. Increase MW of 6% KCL surface volume to 9.0 ppg.;MU stack wash tool on single 4 1/2" jnt, PU singled in total 40 jnts, moved HWDP to drill side of derrick, POOH racked back 20 stands while loading pipe racks with 40 more joints, strapped and tallied those. Cont. w/ same racking back a total of 160 jts. (105 stds in the derrick total).;Strap & tally remaining 4.5" DP. Stage BHA #2 on the racks, prepped rig floor to P/U BHA #2. Installed mouse hole.;Held PJSM w/ rig crew and Sperry. M/U 6.75" directional BHA #2 F/surface -T/121'- Bit, motor (1.50° bend), DM, GM, ADR, ALD, CTN, PWD, TM HOC, and flex collars.;Plugged into MWD tools. Uploaded data, performed shallow pulse test, Hold PJSM on sources. Currently loading sources.;Hauled 0 bbls of solids to KGF G&I Cumulative: 240 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 770 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 0 bbls Cumulative 0 bbls Daily Metal: 0 lbs. Cumulative: 0 lbs. 1/23/2022 PU single in hole NM flex DC's, jars and stands of HWDP to 740'.;PU single in on 4 1/2" DP from 740' to 1360'. MU topdrive and filled pipe.;Washed down and tagged wiper plug at 1429’, CBU one time then began drilling shoe track to 1511’, rathole cement to 1521’ and 20' new formation to 1541’. 213 gpm-1174 psi, 28 rpm-4300 ft/lbs torque. Reamed through FC and shoe numerous times.;CBU 3 times, 292 gpm-1432 psi, 29 rpm-4058 ft/lbs off bott torque. Up wt 55K, rot wt 50K, down wt 45K. Held PJSM on displacing well to KCL mud.;Lined up on pit 6, opened dump line to cuttings box, displaced well to 6% KCL at 9.0 ppg, 225 gpm-750 psi. With good KCL to surface, CBU 3x then shut down to clean suction pit and shakers. Racked back one stand DP and blew down topdrive.;Install pump in sub and TIW on drill string, RU test pump on pump in sub and mezz kill, closed upper rams, flood choke manifold and purge air from choke/kill lines.;With test pump, pumped 12.7 gallons and achieved 888 psi before shut down. Held 15 minutes, well bled down to 495 psi over 15 minutes. Bled back 5 gallons. Notified Drilling Manager and sent in data/chart. LOT at 553 psi giving us an EMW of 16.7 ppg. Decision made to drill ahead. RD test equipment.;Resumed directionally drilling 6 3/4" hole from 1541' to 1811'. Sliding wob 2-3K, 294 gpm-1305 psi, 182 psi diff, 140 to 150 ft/hr ROP. Rot wob 3K, 295 gpm-1290 psi, 43 rpm-4712 ft/lbs on bott torque, 130 ft/hr ROP, MW 9.0/vis 66, ECD's at 9.9 to 10.1 ppg, BGG 7 units, max gas 54 units at 1607'.;Cont. directional drilling 6.75" production hole F/1811' -T/2164'. P/U-54K S/O-42K ROT-49K GPM-290 SPP-1400 psi Diff-100 psi RPM-60 TQ-5.1K WOB-5K Max gas- 178 units ECD-10.2 ppg. Pumped sweep @ 2161', sweep came back on time w/ a 25% increase in cuttings. Obtained SPR's @ 1915'.;Crew change, held PTSM and Sunday safety meeting. Cont. directional drilling 6.75" production hole F/2164' -T/2533'. P/U-54K S/O-41K ROT-47K GPM-290 SPP-1400 psi RPM- 60 TQ-5.3K WOB-5K Max gas-212 units ECD-10.38 ppg.;Circ. hole till shakers cleaned up. shot on bottom survey. Obtained SPR's. Flow check (static). P/U- 55K S/O-46K ROT-48K GPM-290 SPP-1370 psi TQ-5K Max gas-286 units.;POOH on elevators F/2534' to current depth of 1671'. P/U-50K S/O-40K Distance to well plan: 5.49' 1.05' High 5.39' Left.;Hauled 0 bbls of solids to KGF G&I Cumulative: 240 bbls Hauled 170 bbls of fluid to KGF G&I Cumulative: 940 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 0 bbls Cumulative 0 bbls Daily Metal: .5 lbs. Cumulative: .5 lbs. pg p Pressure up again, leaking on electric choke flanges. gpppp ;With test pump, pumped 12.7 gallons and achieved 888 psi before shut down. g observed leaks between BOP and wellhead flanges and between choke manifold and electric choke flanges.g AOGCC Rep Lou Laubenstein on location at 07:00 to witness LOT at 553 psi giving us an EMW of 16.7 ppg. p g ;State inspector witnessed 7 5/8” surface casing test of 3500 psi for 30 min on chart, good test, ppg gg Hammered it up and got a good 5000 psi shell test.; gyp g ;Tested all BOPE at 250 low and 5000 high for 5 min each with 4 1/2" test joint. p p p rathole cement to 1521’ and 20' new formation to 1541’ 1/24/2022 Service rig and topdrive parked at 1485'.;TIH on elevators from 1485' to 2489' with no issue, MU topdrive and filled pipe, washed to bottom at 2535'.;Made hook, CBU one time and started 20 bbl hi-vis nut plug sweep around and resumed drilling from 2535' to 2878'. Sliding wob 3.5K, 288 gpm-1481 psi, 160 psi diff, 126 ft/hr ROP. Rot wob 3-4K, 289 gpm-1517 psi, 70 rpm-5700 ft/lbs on bott torque, 130 ft/hr ROP, MW 9.1/vis 60, ECD's at 10.7 ppg, BGG;22 units, max gas 269 units at 2586'.;Cont drilling 6 3/4" hole from 2878' to 3342'. Rot wob 3-4K, 296 gpm-1678 psi, 80 rpm-6000 ft/lbs on bott torque, 130 ft/hr ROP, MW 9.1+/vis 54, BGG 32 units, max gas 214 units at 3093'.;Cont drilling 6 3/4" hole from 3342' to 3404' MD 2186' TVD and started loosing returns. Racked one stand back. Obtained static loss rate= 35 bph initial dropping to 24 bph. Mixed and pumped 20 bbl LCM pill at 40 lbs per/bbl GPM-113. Racked back 4 more stds (3086') . Blew down TDS.;Monitored static loss rate on TT while allowing LCM pill to soak. Lost rate slowed to 1.7 bph over one hr. Stated building an additional 150 bbl batch of new mud. Brought back ground LCM up to 25 lbs per/bbl in mud system. Broke circ. staged up pump GPM-113 to 230. Dynamic loss rate=10-12 bph.;RIH to bottom and washed last std. down. Staged pump & rotary up. GPM-225 RPM-60.;Attempted to drill ahead at lower pump rate @ GPM-225. Drilled F/3404'-T/3439'. Flow dropped off and lost returns.;P/U and rack 1 std back in derrick. Established static loss rate while build second LCM pill (17.4 bph). Spotted LCM pill out side the pipe GPM-113. Pulled 4 stds and rack back in the derrick. Monitored static loss rate on the TT while letting pill soak. Total losses up till midnight 110 bbls.;Crew change, held PTSM. Cont. monitoring static loss rate on TT and letting pill soak while building volume. Loss rate dropped from 4.52 bph to .08 bph over 2 hrs.;Broke circ. GPM-113 SPP-397, Staged pump up to -GPM-148 SPP-582, GPM-192 SPP-850 , GPM-226 SPP-1143.;TIH F/3125'- T/3406', had calculated pipe displacement. Had 4K drag @ 3290' and 3K drag @ 3360'. Trip speed +/- 25' per/min.;Broke circ. GPM-113 SPP-510, washed down F/3406'-T/3437'. Staged pump up GPM-125 SPP-540 RPM-30 TQ-6K. Shaker couldn't handle flow with new mud, shut down pump, screened down to API 120's across the board.;Resumed pumping GPM 113 SPP-450, staged pump up GPM-170 SPP-720 RPM-30 TQ-6.2K, GPM-230 SPP-1069 RPM-60 TQ- 7K.;Cont. directional drilling 6.75" production hole F/3439' to current depth of 3500'. P/U-60K S/O-41K ROT-49K GPM-233 SPP-1231 RPM-80 TQ-6.5 WOB-5K ECD-10.82 MW-9.15 ppg. Distance to well plan: 6.65' 6.59' Low .89' Left.;Hauled 160 bbls of solids to KGF G&I Cumulative: 400 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 940 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 110 bbls Cumulative 110 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. 1/25/2022 Cont Drlg f/ 3500' md t/ 3758' md, RWOB @ 4K to 7K, 245 gpm w/ 1383 psi, 80 RPM's with 6877 ft/ lbs of tq on bottom, 40 to 70 ft/ hr ROP, MW at 9.1 ppg, Vis @ 63, ECD @ 10.5 ppg, BGG 9 units, Max Gas at 100 units, SWOB @ 2K,, 256 gpm w/ 1290 psi, 168 psi diff, 60 - 80 ft/ hr ROP;Cont Drlg f/ 3758' md t/ 3964' md, RWOB @ 4K to 7K, 245 t/ 270 gpm w/ 1450 psi, 80 RPM's with 7000 ft/ lbs of tq on bottom, 40 to 80 ft/ hr ROP, MW at 9.2 ppg, Vis @ 63, ECD @ 11 ppg, BGG 12 units, Max Gas at 62 units, SWOB @ 2K, 268 gpm w/ 1305 psi, 168 psi diff, 60 - 80 ft/ hr ROP;Cont. directional drilling 6.75" production hole F/3964 to wiper trip depth 4023'. P/U-72K S/O-41K ROT-52K GPM-270 SPP-1440 psi Diff-115 psi RPM-80 TQ-6.9K WOB-4K ECD-10.9 ppg MW-9.3 ppg Vis-52 Max gas- 88 units.;Circ. till shakers cleaned up. shot on bottom survey. Obtained SPR's. Flow checked (slight seepage). GPM-270 SPP-1360 psi RPM-80 TQ-6.2K Off line cont. working drifting 4.5" liner.;POOH on elevators F/4023'-T/2474'. Seen 5-10K drag while pulling through loss area 3439'-3404' MD. Had calculated hole fill for the trip. P/U-73K S/O-48K.;Serviced Rig-Greased crown, blocks, TDS, wash pipe, DWKS, drive shaft, brake linkage, and IR. Monitored hole on the TT. .3 bph static loss rate.;RIH on elevators F/2474'-T/4023' w/ no issues. M/U TDS, broke circ. Washed last std. to bottom GPM-113 w/ no fill. P/U-73K S/O-47K Cal Disp.-28 bbls Act Disp.-26 bbls Diff.-2 bbls.;Staged pump slowly up GPM-270. Pumped 20 bbl Hi-Vis sweep w/ walnut/condet, sweep came back on time w/ a 20% increase in cuttings. Resumed directional drilling 6.75" production hole F/4023'-T/4056'. P/U-72K S/O-41K ROT-52K GPM-270 SPP-1500 psi Diff-140 psi RPM-80 TQ-6.9K WOB-4K ECD-11.0 ppg.;Crew change, held PTSM. Cont. directional drilling 6.75" production hole F/4056' to current depth of 4300'. P/U-76K S/O-44K ROT-55K GPM-287 SPP-1546 psi Diff-120 psi RPM-80 TQ-7.5K WOB-3K ECD-10.74 ppg MW-9.2 Vis-50 Max gas 99 units.;Distance to well plan:10.19' 10.09' Low 1.39' Right.;Hauled 18 bbls of solids to KGF G&I Cumulative: 480 bbls Hauled 80 bbls of fluid to KGF G&I Cumulative: 1020 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 0 bbls Cumulative 110 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. 1/26/2022 Continue directional drilling 6.75" production hole F/4300' md to current depth of 4518' md. P/U-80K S/O-45K ROT-58K GPM-289 SPP-1550 psi Diff-125 psi RPM-80 TQ-7.5K WOB-3K ECD-10.80 ppg MW-9.2 Vis-47 Max gas 333 units at 4518' md, 2707' tvd. Slow Pump Rates @ 4456' md. MW 9.2 ppg, MP#2 300 psi.;Continue directional drilling 6.75" production hole F/4518' md to current depth of 4720' md. P/U-72K, S/O-41K, ROT-52K, GPM-290, SPP-1440 psi, Diff- 115 psi, RPM-80, TQ-6.9K, WOB-4K, ECD-10.90 ppg, MW-9.2 ppg, Vis-49, Max gas 318 units at 4643' md. Finished strap & tally of 4.5" casing.;Cont. directional drilling 6.75" production hole F/4270' to wiper trip depth of 5014'. P/U-94K, S/O-51K, ROT-63K, GPM-290, SPP-1700 psi, Diff-180 psi, RPM-80, TQ-8.5K, WOB-4K, ECD-10.90 ppg, MW-9.2+ ppg, Vis-49, Max gas 371 units at 4949'.;Circ. till shakers cleaned up. shot on bottom survey. Obtained SPR's, flow checked (slight seepage). GPM-290 SPP-1510 psi RPM-80 TQ-8.5K.;Crew change, held PTSM. POOH on elevators F/5014'-T/3956' w/ no issues. Had calculated hole for the trip.;Service rig- Greased blocks, TDS, DWKS, IR, and brake linkage. Monitored hole on the TT (slight seepage). Cleaned both suction and discharge screens on MP's.;RIH on elevators F/3956'-T/ 5014' w/ no issues, M/U TDS, broke circ. staged up pump, washed last std. to bottom, no fill on bottom. Had calculated pipe displacement for the trip.;Pumped 20 bbl Hi-Vis sweep w/ walnut/condet while drilling ahead F/5014', sweep came back on time, w/ a 10% increase in cuttings. P/U-91K, S/O-50K, ROT-66K, GPM-280, SPP-1641 psi, Diff-246 psi, RPM-80, TQ-8.5K, WOB-4K, ECD-10.7 ppg, MW-9.2+ ppg, Vis-45, Max gas 274 units at 5044'.;Current depth of 5175'. Distance to well plan: 7.61' 1.83' High 7.39' Left.;Hauled 32 bbls of solids to KGF G&I Cumulative: 512 bbls Hauled 128 bbls of fluid to KGF G&I Cumulative: 1148 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 0 bbls Cumulative 110 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. Cont Drlg f/ 3500' md t/ 3758' md, gp p p ;Cont drilling 6 3/4" hole from 2878' to 3342' Continue directional drilling 6.75" production hole F/4300' md to current depth of 4518' md. 1/27/2022 Continue Drilling ahead F/ 5175' md T/ 5510' md, WOB 4-6K, GPM 280, SPP 1650 psi, RPM 80, DIFF 250psi, TQ on BTM 9.1K, OFF BTM TQ 9.4K, PUW 110K, SOW 53K, ROT 72K, Max Gas Observed was 282 Units @ 5187'md.;Continue Drilling ahead F/ 5510' md T/ 5754' md, WOB 4-6K, GPM 290, SPP 1700 psi, RPM 80, DIFF 175psi, TQ on BTM 9.8K, OFF BTM TQ 8.8K, PUW 110K, SOW 55K, ROT 75K, Max Gas Observed was 149 Units @ 5602'md. Lubes were added at +/- 5500' md to help slide effectively.;Cont. directional drilling ahead F/5754'-T/5878' and lost returns. P/U-108K S/O-56K ROT-75K GPM-295 SPP- 1700psi Diff-275 psi RPM-80 TQ-10.1K WOB-5K ECD-10.9 ppg MW-9.25 ppg Max 36 units.;Shut down the pump/rotary. Line up and filled the hole through the kill line, Racked back 1 std. Lined up the TT on the hole, monitored hole (static loss rate= 1 bph) while mixing LCM. Pump and spotted a 20 bbl LCM pill w/ 40 lbs per/bbl (Baracarb 5, 50, and Steel seal 50).;on bottom GPM-113 SPP-320. Had minimal losses while spotting pill. Pull and Racked back 4 stds. F/5808'- T/5569'. Lined TT up one the hole, monitored static loss rate for 1 hr. while allowing pill to soak (loss rate =1 bph). Broke circ. Staged up pump- GPM-113 SPP- 441, GPM-170 SPP-737,;GPM-233 SPP-1075, GPM-256 SPP-1240. No losses observed. Shut down pump.;Crew change, held PTSM. TIH F/5569'-T/5878'. Staged up pump & rotary-GPM-113 SPP-456 RPM-30, GPM-254 SPP-1256 RPM-80. Dynamic loss rate=5-10 bph. P/U-113K S/O-57K ROT-76K.;Cont. drilling ahead F/5878'-T/5916'. P/U-113K S/O-57K ROT-76K GPM-256 SPP-1400psi Diff-160 psi RPM-80 TQ-10.1K WOB-3K ECD-10.7 ppg MW-9.3 ppg Max 16 units.;Noticed slow loss of returns @ 5916'. Decreased pump rate to GPM-215. Attempted to drill ahead F/5916'-T/5919' before losing returns. Shut down pump, lined up on the TT and filled back side, racked 1 std back. Well was static, attempted to establish circ. (No luck). Cont. monitoring well on TT;while mixing LCM pill (static loss rate= 20 bph). Worked pipe as needed to avoid differential sticking.;Pumped and spotted a 20 bbl LCM pill w/ 40 lbs per/bbl (Baracarb 5, 50, and Steel seal 50) on bottom GPM-113 SPP-320. Had minimal losses while spotting pill. Pulled and Racked back 5 stds. F/5875'-T/5570'. Had 10-15K over pulls F/5650'-T/5635'. Lined TT up one the hole,;monitored static loss rate for 1 hr. Worked pipe as needed while allowing pill to soak. P/U-115K S/O-60K.;Let LCM pill soak while mixing another LCM pill in the pill pit. Static loss rate over 1 hr.= 1 bph.;RIH F/5570'-T/5919' w/ no tight spots observed. Filled pipe. Staged up pump GPM-208 SPP-955 RPM-37.;Resumed drilling 6.75" production hole F/5919' to current depth of 5980'. P/U-115K S/O-57K ROT-77K GPM-249 SPP- 1370psi Diff-158 psi RPM-55 TQ-9.8K WOB-3K ROP-60 fph ECD-10.72 ppg MW-9.25 ppg Vis-54 Max 16 units. Distance to well plan: 6.86' 5.11 Low 4.56 Left.;Hauled 48 bbls of solids to KGF G&I Cumulative: 560 bbls Hauled 192 bbls of fluid to KGF G&I Cumulative: 1340 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 76 bbls Cumulative 186 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. 1/28/2022 Continue Drilling 6.75" Production Hole F/ 5980' md T/ 6250' md WOB 3/6K, GPM 260, RPM 80, SPP 1550 psi, Diff 250 ps i, TQ on BTM 10.9K ft/ lbs, TQ off BTM 11K ft/ lbs, PUW 121K, SOW 67K, ROT 57K, Max Gas @ 87 Units, SPRs @ 6002' md, 3802' tvd, MW 9.3 ppg, MP#1@47STKS=400psi, MP#2@46STKS=397psi.;Drilling 6.75" Production Hole F/ 6250' md T/ 6309' md 4030' tvd, WOB 3/6K, GPM 260, RPM 80, SPP 1550 psi, Diff 250 psi, TQ on BTM 10.9K ft/ lbs, TQ off BTM 11K ft/ lbs, PUW 121K, SOW 67K, ROT 57K, Max Gas @180 Units, MW 9.3 ppg.;Circulate Bottoms up X 2 to clean up well Pump at 267 GPM with 1472 psi. until shakers are clean while reciprocating and rotating drill string. Shoot Survey. Obtain New SPRs before performing short trip. SPRs MP#1 @ 47STKS=349psi, MP#2 @ 46STKS=341psi.;POOH w/ Drill String to start Short Trip F/ 6309' md T/6247' md. B/O TD & B/D same. Line Up TT & start Trip Tank Pump. PUW 125K SOW 62K POOH F/ 6247' T/ 5425' md Tight spots observed with 20K overpull at 6065' and 6050'. 25K overpull @ 6040, 5965, 5540, 5520, 5490 & 5425 all wiped clean except 5425.;Lower string to 5450' md and make up Top Drive. Line up mud pumps and start circulating by staging mud pump up to 249 GPM with 1260 psi. Back ream F/ 5450' md T/ 5379' md. at 66 RPM and 9.4K Torque.;Cont. BROOH F/5379'-T/4952'. P/U-115K S/O-53K GPM-250 SPP-1180 RPM-60 TQ-9K ECD-10.59 ppg MW-9.2 ppg Vis-47 Max gas 27 units.;CBU. GPM-258 SPP-1172 RPM-80 TQ-7.8K ECD-10.48 ppg MW 9.2.;POOH on elevators 3 stds. checking last wiper trip hole F/4952'-T/4763' (clean hole). P/U-98K S/O-55K.;Blew down TDS. Serviced Rig- Greased crown, TD, blocks, wash pipe, brake linkage, IR, DWKS, and drive shaft. Change out grabber box dies and saver sub.;RIH on elevators F/4763'-T/6250'. Had 2 10-15K drag spots @ 5504' & 5540'. M/U TDS, broke circ. staged up pump. GPM-113 SPP-365, GPM-180 SPP-847 P/U-118K S/O-61K. Washed F/6250' to bottom (6310') w/ no fill. Pipe displacement- Cal Disp.-24 bbls Act Disp.-22 bbls Diff-2 bbls.;Resumed directional drilling 6.75" production hole F/6310'-T/6343'. P/U-123K S/O-59K ROT-81K GPM-270 SPP-1550 RPM-80 TQ-10.9K WOB-5K ECD-10.6 ppg MW-9.2 ppg Vis-48 Max gas 49 units.;Crew change, held PTSM. Cont. directional drilling 6.75" production hole. Added walnut to suction pit to help w/ sliding F/6343'-T/6372'. Current depth at report time 6610'. P/U-122K S/O- 63K ROT-83K GPM-274 SPP-1662 RPM-60 TQ-11K WOB-3K ECD-10.87 ppg MW-9.2+ ppg Vis-50 Max gas 325 units @ 6517'.;Pumped a 20 bbl Hi-Vis sweep w/ walnut/condet @ 6374', sweep came back on time w/ a 10% increase in cuttings. Distance to well plan: 11.49' 11.44' Low 1.03' Left.;Hauled 64 bbls of solids to KGF G&I Cumulative: 624 bbls Hauled 16 bbls of fluid to KGF G&I Cumulative: 1356 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 156 bbls Cumulative 342 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. Continue Drilling 6.75" Production Hole F/ 5980' md T/ 6250' md WOB Continue Drilling ahead F/ 5175' md T/ 5510' md, 1/29/2022 Continue Drilling 6.75" Production Hole F/ 6610' T/ 6995' WOB 3/6K GPM 230/ 270 RPM 65 SPP 1500/1750 psi DIFF 250 psi TQ on BTM 11.7K TQ off BTM 11.8K Max GAS 324 units PUW 140K SOW 63K ROT 87K SPRs @ 6808' md 4416' tvd MW 9.3 MP#1@47STKS=446psi MP#2@46STKS=441psi.;Continue Drilling 6.75" Production Hole F/ 6995' T/ 7367' WOB 5K GPM 290 RPM 80 SPP 2025 psi DIFF 300 psi TQ on BTM 12.8K Max GAS 450 units PUW 148K SOW 63K ROT 90K SPRs @ 7305' md 4800' tvd MW 9.3 MP#1@47SPM=503psi MP#2@46SPM=498psi.;Function Test of BOPE completed at 13:30 hours: 1) Annular Preventer 2) Upper Pipe Rams 3)Choke HCR 4) Kill HCR 5) Lower Pipe Rams. Blind Rams will be function tested when the drill string is out of the hole.;Cont. drilling 6.75" production hole F/7367' to TD @ 7600'. P/U-158K S/O-64K ROT-92K GPM-295 SPP-1875 Diff-300 psi RPM-80 TQ-13.1K WOB-4K Max gas 213 units ECD-11.3 ppg MW-9.3+ ppg Vis-52.;Circ. till shakes cleaned up. Shot on bottom survey. Obtained SPR's. Flow checked (slight seepage). GPM-293 SPP-1875 RPM-80 TQ-13.5K.;Performed wiper trip. POOH on elevators F/7600’ to shoe @ 1511’. Worked through multiple tight spots F/7331’- T/5487’ on elevators w/ 20-30K over pulls. Worked through all tight spots till hole cleaned up. Seen only 1 tight spot on top section of hole @ 2980', 30K over pull, worked though on;elevators. Hole fill- Cal Disp.-44.6 bbls Act Disp.-53.1 bbls Diff-8.5 bbls over.;Flow checked at shoe-slight seepage, Installed TIW. Cleaned floor, prepped for slip & cut. Monitoring wellbore on TT.;Hung off blocks. Currently slip/cut 63' of drill line. 13 Wraps reset and test C. O. M. Distance to well plan: 64.84' 50.51' Low 40.65' Left.;Hauled 48 bbls of solids to KGF G&I Cumulative: 672 bbls Hauled 192 bbls of fluid to KGF G&I Cumulative: 1548 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 47 bbls Cumulative 389 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. 1/30/2022 Grease and Inspect Crown Sheaves, Blocks, Top Drive, Iron Roughneck, Draworks and Linkages. Added Fluid to Gearbox as needed.;RIH with Drilling assembly on elevators F/ 1481' through Surface Casing shoe at 1511' md T/ 2842' md. Observe Iron Roughneck with leaky hose kill hydraulic pump.;Fill pipe and Circulate while replacing hose on Iron Roughneck.;RIH on elevators F/ 2842'md T/ 7430'md seen several 10/15K set downs F/6100' md T/ 7389'md worked through all tight spots and cleared. Continue RIH F/ 7430'md T/ 7554'md. PUW 163K, SOW 73K.;Fill pipe and wash down T/ 7600'md Stage up pumps and rotary, Circulate Bottoms up, 50% increase in cuttings. Pump Hi-Vis sweep STS, Came back 10 bbls late with 10% increase in cuttings. GPM 280, SPP 1700 psi, RPM 80, TQ 12.5K. Flow check well: seepage. Pump Dry Job.;POOH laying down 4-1/2" CDS 40 drill pipe F/ 7600'md T/ 5049'md PUW 163K, few spots with 10 to 15K overpull work spots and all cleaned up.;Cont. POOH L/D singles F/5049'-T/1979'. P/U-56K S/O-46K.;Dropped metal drift on wire (OD-2.4"). POOH racking back 4.5" DP in the derrick F/1979'-T/740' (20 stds). P/U-37K S/O-37K.;POOH L/D HWDP F/740'-T/403". P/U-31K S/O-31K.;Crew change, held PTSM and our weekly safety meeting w/ rig crew. Cont. L/D BHA #2- L/D Jars and flex collars. Held PJSM removed sources. Plugged into MWD tools and down data. L/D remaining MWD tools. Drained motor. B/O and grade same. Bit grade 1-1-WT-A-X-I-NO-TD engage.;Gave 2 hr. notice to Weatherford casing hands and Baker Rep. Covered and put heater on HES cement pump skid.;Cleaned & cleared rig floor. Serviced rig-Greased & inspected crown, TD, IR, DWKS, brake linkage, and blocks. Adjusted TQ on TD T/6.5K.;R/U Weatherford casing handling equip. De-Ice Weatherford power tongs. Currently Loaded out pipe racks w/ 4.5" DWC/C HT 12.6 ppf L-80 liner.;Hauled 0 bbls of solids to KGF G&I Cumulative: 672 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 1548 bbls Hauled 0 bbls of cement to KGF G&I Cumulative: 90 bbls Daily down hole losses 20 bbls Cumulative 409 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. 1/31/2022 PJSM with Weatherford, Baker and rig crew on picking up running the 4-1/2" Production Liner. Pick up and Baker-Lok Float Shoe jt., Float Collar jt. and Landing Collar jt. and test floats. Floats good.;Repair catwalk skate and adjust cable tension.;Continue to RIH with 4-1/2" 12.6# L-80 DWC/C-HT Production Liner F/ 128' T/ 1245' Filling on fly and topping off every ten joints.;Stopped near Surface Shoe and pumped Pipe volume at 114 GPM with 0 Pressure.;Continue to RIH with 4- 1/2" 12.6# L-80 DWC/C-HT Production Liner F/ 1245' T/ 4139' PUW 47K SOW 34K.;Circulate Bottoms Up, bringing pumps up to 210 GPM in a controlled manner while reciprocating pipe. At 210 GPM wit h 156 psi. rotated liner at 10 RPM with Torque at 4.3K ft/ lbs.;Continue to RIH with 4-1/2" 12.6# L-80 DWC/C- HT Production Liner F/ 4139' T/ 6290' PUW 78K SOW 43K.;Swap elevators to 3-1/2" and P/U 5.5" X 7.62" Baker ZXP Production Liner Hanger. Make up to 4- 1/2" 12.6# L-80 DWC/C-HT Production Liner with Baker-Lok. Unwrap Hanger and Confirm 4 shear pins, Confirm 7 shear screws at Packer and 13 Pins for setting Top Set Packer and RIH F/ 6290' T 6328'.;RIH with 4-1/2" CDS 40 Drill Pipe from derrick F/6328' T/6774'. PUW 87K SOW 49K. After first stand installed pumped through bringing pumps up to 212 GPM with 368psi.;Cont. RIH F/6774'-T/7477'. Had 20K set down, attempted to work through on elevators (No luck). M/U TD, broke circ. Staged up pump GPM-177 SPP-453. Washed down F/7477'-T/7515'. P/U-102K S/O-55K.;P/U & M/U Baker cmt head. Broke circ. Washed down F/7515' bottom @ 7600'. Staged up pump GPM-113 SPP-310, GPM-205 SPP-725. Circ. & conditioned mud for cmt job.;Held PJSM on cmt job w/ rig crew, HES, CCI, Baroid, and DSM. Cont. circ. and reciprocating pipe GPM-215 SPP-630. attempted to blow air back through cmt lines and cmt pump (No luck). Thawed cmt pump manifold w/ steam wipe and Tioga heater of ice plug.;Blew down TDS, cementers pumped 6.5 bbls of water to fluid pack lines. PT cmt lines T/740 psi Low, attempted to bring pressure to high PT. Baker cmt head swivel packing started leaking @ 2600 psi. Shut down & bled off cmt pump. Blew down cmt lines. Steamed & grease swivel packing. Cont. to;reciprocate pipe P/U-115K S/O-55K.;Halliburton pumped 2 bbls to fill lines. Shut in at Baker cement head and PT lines at 700 psi low 4700 psi high. Good tests. Lined up Baker cement head to Halliburton, pumped 28 bbls 10.5 ppg Tuned Prime Spacer at 4 bpm-830 psi, followed with 204 bbls (485 sx) 12 ppg Type I/II;Lead cement at 5-3 bpm, 830 to 338 psi, followed with 15 bbls (95 sx) 15.3 ppg Type I/II Tail cement at 1.6 bpm, 132 psi. Had 2 pps of Bridge Maker LCM in lead, none in tail. Baker released dart, Halliburton then displaced with 10 bbls water followed with 9.5+ ppg 6% KCL mud at 3;bpm-500 psi ICP. Saw dart latch wiper plug 17 bbls into displacement. With 10 bbls to go, reduced rate to 2 bpm-1330 psi, set on depth. Bumped wiper plug/landing collar 112 bbls into displacement (calculated at 112 bbls). FCP 1362 psi. CIP at 01:55 on 2-1-22.;Cont. bringing pressure up T/4000 psi, shut down and shut in cement pump (2638 psi over FCP). Held pressure for 2 min. Bled off pressure to truck, floats held, bled back 1 bbl to truck. Slacked off on blocks from 55K to 40K. Seen good indication of hanger setting.;Attempted to release from hanger, S/O down to 15K and P/U to 150K w/ no luck. Made decision to pressure back up. Proceeded to pressure, at 2600 psi Halliburton valve at the bottom of the beaver slide started leaking spilling 10 gals of drilling mud into containment.;Bleed off pressure, blew down cmt lines, and changed out low torque valve. Line back up on the hole, staged up pressure to 4500 psi, held pressure for 3 min. Bled down pressure. P/U and had released from hanger (P/U-50K). Blew down cement lines. Lined up rig MP's on the hole. Pumped down the string,;applied 1000 psi and started P/U on drill string (24'), pressure dropped off, Kicked both pumps in GPM-577 SPP-856, CBU X5. We had 17.7 bbls lost to the hole during the job. Got back 28 bbls of spacer and 33 bbls of cmt. Racked back 1 std. Pumped around wiper ball. Blew down TDS.;POOH racking back DP in the derrick F/1232'-T/ surface. Currently L/D Baker running tool.;Hauled 15 bbls of solids to KGF G&I Cumulative: 687 bbls Hauled 60 bbls of fluid to KGF G&I Cumulative: 1608 bbls Hauled 0 bbls of cement to KGF G&I g ()p Got back 28 bbls of spacer and 33 bbls of cmt. ppg p pp ppg p followed with 204 bbls (485 sx) 12 ppg Type I/II;Lead cement at 5-3 bpm, 830 to 338 psi, followed with 15 bbls (95 sx) 15.3 ppg Type I/II Tail pp cement at 1.6 bpm, 13 p jj ;Continue to RIH with 4-1/2" 12.6# L-80 DWC/C-HT Production Liner F floats held, Wepgppp had 17.7 bbls lost to the hole during the job. G ;Function Test of BOPE completed at 13:30 hours: 1)@@p@pp Annular Preventer 2) Upper Pipe Rams 3)Choke HCR 4) Kill HCR 5) Lower Pipe Rams. Blind Rams will be function tested when the drill string is out of the hole.;Cont. drilling 6.75" production hole F/7367' to TD @ 7600'. )pp p ) ) Continue Drilling 6.75" Production Hole F/ 6610' T/ 6995' 2/1/2022 P/U Baker Cement head and Break out drill pipe and XO pups. Lay down all subs and cement head. Drain stack M/U Stack Washer and Flush out stack of all residual cement. Pump through mudcross and Blow Down same.;P/U Polish Mill assembly and RIH T/ TOL @ 1269' md Polish 5.75" Tie Back Extension. RPM 40, GPM 168, SPP 240psi, TQ 4.1K ft/lbs. Reciprocate and Rotate pipe work 5 times & seen psi increase every time No-Go seated. PUW 35K, SOW 36K, ROT 36K circulate bottoms up @ 240 GPM. Blow Down Topdrive,;and Mud lines. POOH F/ 1269' Lay Down Polish Mill Assembly, L/D Elevators and all unneeded handling equipment. Submit 24 hour notice for MIT test on the AOGCC website @ 09:13 am. Call returned from Brian Bixby whom will be witnessing test.;Grease and inspect Blocks, Topdrive, crown, Draworks, Iron Roughneck, Drive shaft and linkages.;Drain stack, Pull Wear Ring and set Test Plug W/ 2-7/8" Test Joint.;Rig up test equipment and flood stack. Test Annular Preventer T/ 300 psi low and 2500 psi high for 5 minutes each. Test Upper VBRs T/ 300 psi low and 3500 psi high for 5 minutes each.;Rig down test equipment and blow down lines. Pull test plug and install Wear Ring (9" ID). Rig up equipment to run 2-7/8" PH6. Load pipe racks. Strap and Tally PH6. Bring BHA to floor, Strap and Tally BHA.;RIH with 4-1/2" 12.6# scraper assembly with 3.75" Bit on bottom picking up singles and drifting all PH6 T/ 1405' md.;Continue P/U Scraper Assembly f/ 1405' t/ 2954' drifting all PH6.;Lost Teflon drift, search around catwalk and through snow, checked in pipe reverse circulated to ensure pipe clear.;Continue RIH w/ scraper assembly f/ 2954' t/ 4929' drifting PH6 tubing.;Load strap and tally remaining 58 jts of PH6 on racks.;Continue RIH w/ scraper Assembly on 2 7/8'' PH6 f/ 4929' t/ 6290' 207 jts total, drifting PH6 tubing, M/U upper scraper and XO t/ 4.5'' DP Continue RIH on 4.5'' dp t/ TOC @ 7500' 9' high of landing collar @ 7509' set down 10k, kelly up and wash down setting 5k down at same place.;Circulate pipe volume 44 bbls 1400 psi 130 spm, Pump spacer displace w/ 8.6 ppg brine taking returns to cuttings box, shut down and flow check well f/ 20 min well static. 2/2/2022 POOH Laying Down 4-1/2" CDS 40 Drill Pipe F/ 7500' T/ 6332', RIH with remaining drill pipe in derrick T/ 6650' and continue laying down 4-1/2" CDS 40 Drill Pipe T/ 6332.;Rig Up Weatherford Power Tongs and Break Out and Lay Down 7-5/8" Scraper Assembly. Continue Laying Down 2-7/8" PH6 F/ 6332' T/ Surface. Break apart 4-1/2" Scraper Assembly and Bit. Recieved call @ 09:45 from AOGCC Inspector Brian Bixby waived witness.;Clean and Clear rig floor, Move Weatherford equipment to the side of the floor.;Pull Wear Ring.;Flood stack and choke manifold with water and Pressure Test 7-5/8" x 4-1/2" Casing to 3000 psi for 30 Charted Minutes. 1.58 barrels to pressure up to 3110 psi. after 15 minutes pressure at 3100 psi. after 30 minutes pressure at 3095 psi. Good Test Bleed pressure off with 1.58 barrels bled back.;Rig up Weatherford equipment and swap slip segments from 2-7/8" to 4-1/2". Load Seal Assembly on catwalk and bring to floor.;RIH with 4-1/2" 12.6# L-80 DWC/C-HT casing F/ surface T/ 800' Make Up SSSV and test.;Continue RIH w/ 4.5'' Tie Back f/ 800' t/ 1276' installing S.S. Bands on every jt 15 bands total, tag up and space out locator 2.01' off locator M/U hanger and terminate control line, land on Hanger RILDS, R/D Weatherford and Pollard.;Pull landing jt R/U and perform MIT, test tubing t/ 3000 psi f/ 30 min 1.18 bbls pumped 1.18 bbls returned bleed off and R/U and test Annulus t/ 2500 psi leak on fitting on test equipment, C/O and retest t/ 2500 psi f/ 30 min .39 bbls pumped .39 bbls returned, good tests R/D set TWC.;Flush mud lines, choke manifold and pumps w/ baraclean pill, blow down lines.;N/D flow box and flow line pull riser, attach bridge cranes to stack and unbolt choke and kill lines, disconnect koomey lines, Unbolt stack f/ wellhead and trolly out of the way, bring dry hole tree in cellar and hoist with tugger, spot over wellhead and clean ring grooves, fill void with oil.;N/U on wellhead, terminate control line through tree, tests void t/ 500/ 5000 psi f/ 10 min test body t/ 5000 psi f/ 5 min good tests, Release rig t/ Kalotsa 8 @ 0600 hrs.;Hauled 21 bbls of solids to KGF G&I Cumulative: 747 bbls Hauled 424 bbls of fluid to KGF G&I Cumulative: 2698 bbls Hauled 33 bbls of cement to KGF G&I Cumulative: 123 bbls Daily down hole losses 0 bbls Cumulative 437 bbls Daily Metal: 0 lbs. Cumulative: .5 lbs. gp qp p p g ;RIH with 4-1/2" 12.6# L-80 DWC/C-HT casing F/ surface T/ 800' Make Up SSSV and test. p . Good Test Bleed gypyyg Recieved call @ 09:45 from AOGCC Inspector Brian Bixby waived witness.;C qp r 30 Charted Minutes. gp p g g nd perform MIT, test tubing t/ 3000 psi f/ 30 min 1.18 bbls pumped 1.18 bbls returned bleed off and R/U and test Annulus t/ gj p g p p p 2500 psi leak on fitting on test equipment, C/O and retest t/ 2500 psi f/ 30 min .39 bbls pumped .39 bbls returned, good tests R/D p@ p Submit 24 hour notice for MIT test on the AOGCC website g Pressure Test 7-5/8" x 4-1/2" Casing to 3000 g Activity Date Ops Summary 2/6/2022 AKEL crew arrives at facility and obtains permit, TGSM. Rig up eline equipment and pressure test lubricator to 250 psi low / 2500 psi high. RIH with 3.60" gauge ring and CCL to drift SSSV. Drift through SSSV but unable to come back uphole. Contact production to troubleshoot SSSV.,Production arrives and troubleshoots valve. POOH and lay down tools. Make up radial CBL tool and RIH. Log free pipe section from 760' - 520' and calibrate sensors above liner top. RIH to PBTD, and choose to stop tool at 7450' (uncorrected) because we were loosing lots of weight. Pull repeat pass up to 7154' followed by main pass to 1170'. Data looks good. POOH and RDMO eline. 2/8/2022 Fox Energy crew arrives at facility and obtains permit, TGSM. Warm up CT equipment and crane. Break off tree cap and f lange up adapter spool. NU BOPE to tree and start BOPE Test against swab. AOGCC waived witness by Jim Regg on 02/07/22 at 09:52. Function test upper (blind/shear) and lower (pipe/slip) rams.,Pressure test upper rams, lower rams, flow cross valves, choke manifold valves and inner reel valve to 250 psi low / 3500 psi high. All tests passed with no failures. Secure location and SDFN. 2/9/2022 Fox Energy crew arrives at location and obtains permit, TGSM. Fire up coiled tubing equipment. MU BHA and stab lubricator on to BOP stack. Pressure test to 250 psi low / 3500 psi high. Open well and RIH while cooling down N2 pump.,N2 pump deck engine shuts down, troubleshoot problem with fuel transfer pumps. Prime deck engine and re-start. With coil at 3000' come on line down CT with N2 at 1500 scf/min. RIH chasing fluid down to PBTD (7430' CTMD) at ~ 70 fpm taking returns to 400 bbl diffuser tank. Sit off bottom for 15 minutes and POOH at ~90 fpm pumping all the way to surface . Trap 700 psi on well. 115 bbls evacuated with 282 mcf of N2 pumped.,RDMO CTU and secure location. Received CBL approval for perforating from AOGCC (Bryan McLellan). 2/10/2022 AKEL crew arrives at facility and obtains permit, TGSM. Rig up eline equipment and pressure test to 250 psi low / 1500 psi high. Arm and RIH with 17' 2-7/8" HC gun. Bleed down WHP from 700 to 500 psi for perforating while RIH.,Correlate to open hole log and send to town for correction. On depth. Perforate T-12u from 7198-7215'. Initial: 504 psi. 5 min: 507 psi. 10 min: 511 psi. 15 min: 515 psi. POOH and break off lubricator. All shots fired and gun was dry. Stand back eline and flow test well. Well online at 80 mcf. Lay down eline and flow test well overnight. 2/11/2022 AKEL crew arrives at facility and obtains permit, TGSM. Warm up eline equipment and discuss plan forward with town. Arm 14' 2-7/8" HC gun and suck in to lubricator. Pick up lubricator and stab on well. RIH. Correlate to open hole log and send to town for correction. On depth.,Perforate T12u from 7200-7214'. Initial 415 mcf @ 75 psi. 5 min: 515 mcf @ 76.5 psi. 10 min: 500 mcf @ 77 psi. 15 min: 641 mcf @ 78 psi. POOH, break off lubricator and lay down gun. All shots fired and gun was dry. Standby while rate and pressure is monitored. Rate is up ~600 mcf and climbing. Lay down eline, secure well and release crew. 2/14/2022 AKEL crew arrives at facility and obtains permit, TGSM. Fire up eline equipment and pick up lubricator. Pressure test to 250 psi low and 2500 psi high.,Arm and RIH with switched 2-7/8" HC gun assembly loaded at 6 SPF. Gun lengths are bottom: 4', middle: 5' and top: 5'. Correlate to open hole log and send to town for correction. Instructed to add one foot. Perforated T-11L from 7015-7020'. Initial: 1050 mcf @ 92.3 psi. 5 min: 1100 mcf @ 95.0 psi. 10 min: 1110 mcf @ 95.1 psi. 15 min: 1115 mcf @ 95.1 psi.,Perforated T-11M from 6988-6993'. Initial: 1115 mcf @ 95.3 psi. 5 min: 1110 mcf @ 95.2 psi. 10 min: 1106 mcf @ 95.3 psi. 15 min: 1115 mcf @ 95.6 psi. Perforated T-11U from 6966-6970'. Initial: 1415 mcf @ 95.6 psi. 5 min: 1122 mcf @ 95.6 psi. 10 min: 1054 mcf @ 91.9 psi. 15 min: 1111 mcf @ 95.7 psi. POOH, break off and lay down lubricator. All shots fired and guns were wet.,Arm and RIH with switched 2-7/8" HC gun assembly loaded at 6 SPF. Gun lengths are bottom: 4' and top: 10'. Correlate to open hole log and send to town for correction. Instructed to add one foot. Perforated T-9Al from 6798- 6802'. Initial: 1210 mcf @ 110.2 psi. 5 min: 1210 mcf @ 113.8 psi. 10 min: 1217 mcf @ 113.7 psi. 15 min: 1219 mcf @ 113.6 psi.,Perforated T-9Am from 6786- 6796'. Initial: 1219 mcf @ 113.7 psi. 5 min: 1223 mcf @ 113.8 psi. 10 min: 1203 mcf @ 111.9 psi. 15 min: 1210 mcf @ 113.3 psi. POOH, break off and lay down lubricator. All shots fired and guns were wet. Arm and RIH with switched 2-7/8" HC gun assembly loaded at 6 SPF. Gun lengths are bottom: 11' and top: 9'. Correlate to open hole log and send to town for correction.,On depth. Perforated T-8u from 6663-6674'. Initial 1250 mcf @ 118.1 psi. 5 min: 1288 mcf @ 121 psi. 10 min: 1288 mcf @ 120.8 psi. 15 min: 1253 mcf @ 120.3 psi. Perforated T-7l from 6626-6635'. Initial: 1282 @ 120.7. 5 min: 1273 mcf @ 119.6 psi. 10 min: 1269 mcf @ 119.5 psi. 15 min: 1273 mcf @ 119.6 psi. POOH, break off and lay down lubricator. All shots fired and guns were wet.,Bottom roller bogey assembly adapter sheared off at gun bottom nose. Arm and RIH with switched 2-7/8" HC gun assembly loaded at 6 SPF. Gun lengths are bottom: 7' and top: 12'. Correlate to open hole log and send to town for correction. Perforate T-7u from 6616-6623'. Initial: 1292 mcf @ 123 psi. 5 min: 1294 mcf @ 123.0 psi. 10 min: 1297 mcf @ 123.2 psi. 15 min: 1292 mcf @ 123.2 psi.,Perforate T-6Al from 6562-6574'. Initial: 1294 mcf @ 123.3 psi. 5 min: 1376 mcf @ 130.0 psi. 10 min: 1357 mcf @ 128.5 psi. 15: 1356 mcf @ 128.1 psi. POOH, break off and lay down lubricator. All shots fired and guns were wet. RDMO eline, secure well.,** Roller bogey assembly fish left in hole. OAL: 28 inches. Max OD 3.60". 3" of 1.53" OD stem looking up. ** n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NINU Paxton 11 Ninilchik Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00015 Paxton 11 Completion Spud Date: up radial CBL tool and RIH. g Make            ! "# "#$ %&' " () * ) + ,  ) -.  ) )         /) /0 )       1 ,)!""  #$"% &&'() *+ &,- 2)  0)./0   1  )#$"% &&'() *+ &,-     ) 1  / 1 *) 3 *) " ( 14) * *)   ,23*+  -   ,23* ..-    4)5 !    61  667    / /" 2 ,)  ,) 52)   2)   657+/ 67+ "!       3  ,)       )')) )')) 2 28) 52)'2& 2)& 282') 59'()/ ,5) )'() &):(;58',8( ( :8&;85'2&&1 /0   89: ;,  2 8-: * 2 89:   1,*12 <= >2(>2)22 5')) 32',2 (5 ,( ')))))))) " ). )  ,) 2  ') /  .  )  ; *8-.: 8 : 67+ 8 :   89: 657+/ 8 : -< ) 9')) '3,)')))')) 9')) ; * 8 :  " 2 *  -*  8/0 : - 8 :  >8 >2)22   8?!10<= 0!0 6 ) )!@A<=7B"C      0 6 3)',& 592' 8 !10<= 0!0 6* -*  -) >)(>2)22 8?!10<= 0!0 6 ) )!@A<=7B"C      0 6 592' 8 3 (&2'&5 !10<= 0!0 6*2-*  -) >25>2)22 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 :  -. 8 : -. 8 : 1   2 8: 1 52 8: .   8:  897?:  -* 9')) )')) )')) 9')) )')) )'))C 59'() 2 28) 52)'2& 2)& 282') )')) )')) +=<+ 3)',& )' 23(')9 3)',& )') C)' (5'5& 2 28) 52)'29 2)& 28 '9& )')3 )') 8?!10<= 0!0 6* - 28 '2( )'22 &'92 28 '2( )' 8 C)' ,&5'3( 2 28) 52)'5) 2)& 28 '92 )'5 )' 8 8?!10<= 0!0 6* - 2,5' 8 2',8 89'(9 2,5' ) '( )'98 23'&) 2 28) 52 '3( 2)& 282'93 5'83 '(8 8?!10<= 0!0 6* - 8(('8& 5',3 5 ' 8 8((' 9 5'38 8'(( 99'&9 2 28) 525',) 2)& 28('&3 8'85 5'95 8?!10<= 0!0 6* - 52)'(9 3'85 8,'2, 52)')2 )')9 9')52(8'(2 2 28) 58)' ( 2)& 25)'8) 8'&( )'88 8?!10<= 0!0 6* - 59)',9 ,'8( 5 '3) 53,'39 &'38 8'3(8 8'29 2 28) 58&'&( 2)& 25&' 3 8'89 3' & 8?!10<= 0!0 6* - (89'3& )'39 52' 3 (8&'&3 25'25 2)'()83)' 3 2 28) 555')) 2)& 2(8' ) 2'59 25'93 8?!10<= 0!0 6* - &)8'(2 2'&5 5('29 &))')9 88'32 2,'&)588'(9 2 28) 5(8'2( 2)& 2&2'58 8')8 85'&8 8?!10<= 0!0 6* - &&5'89 5'33 52'9, &(,'2) 55'), 8,'&25,2'3) 2 28) 5&8'83 2)& 232'&, 8'&2 5('8 8?!10<= 0!0 6* - 32&'5& 3'88 8&'& 3 9'9& (3'8 ()'(2((2'8& 2 28) 53&'88 2)& 298', 5',9 (9'9& 8?!10<= 0!0 6* - 399'29 ,'52 82'2) 333'(8 38'5) & '5,& ')8 2 28) 5,2' 5 2)& 2,('23 5')& 3('2, 8?!10<= 0!0 6* - 9( ' , 2 '85 8)'&, 98&'() ,2' ) 32',)&3)')) 2 28) ( )'(( 2)& 8)3' 5 8' & ,5'88 8?!10<= 0!0 6* -        " () * ) + ,  ) -.  ) )         /) /0 )       1 ,)!""  #$"% &&'() *+ &,- 2)  0)./0   1  )#$"% &&'() *+ &,-     ) 1  / 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 :  -. 8 : -. 8 : 1   2 8: 1 52 8: .   8:  897?:  -* , 5' , 28'8) 23'(, 9,5'39 8')) 95'(8329'29 2 28) (8 ' 3 2)& 8 ,'2& 8'&8 ('(, 8?!10<= 0!0 6* - ,3&' , 2('59 25')( ,( '2( 8&')( ,('&5395'3( 2 28) ((8',5 2)& 88)',5 5'28 89',3 8?!10<= 0!0 6* - )83'(& 23'99 22'9, ))&')9 & '88 )&'& 98,'(9 2 28) (39',5 2)& 852'( 5')) &5'(9 8?!10<= 0!0 6* - ),,'53 8)'23 2 '82 )&)' 9 9,'2) 3', 9,8'&9 2 28) &)&'(5 2)& 8(5'5, 5')( ,2'3, 8?!10<= 0!0 6* - & '&3 82'(( ,'9& 8'23 2 ,'(( 2,'8),5&'33 2 28) &8&'&) 2)& 8&&'& 8'9& 228'59 8?!10<= 0!0 6* - 22('(5 85'9( 9'5) &&'5) 2(8')8 5)',),,,',) 2 28) &&,'39 2)& 83,')8 8'92 2(3'8 8?!10<= 0!0 6* - 293'(5 83'&) &'9, 2 &'5 293',( ( ',, )5,', 2 28) 3)5'52 2)& 8,)',& 5'&& 2,2'(( 8?!10<= 0!0 6* - 85,'88 5)'3) &'38 2&5'82 82('2, &8'2& ),3'92 2 28) 35 '53 2)& 5)8' ( (')2 88)'28 8?!10<= 0!0 6* - 5 )'83 58'&8 &'83 8),'(& 8&5'(& 35',8 58')& 2 28) 39)'5( 2)& 5 ('33 5'92 8&,'9( 8?!10<= 0!0 6* - 592' 8 5&'(5 ('&& 8&)'28 5 8'5) 99',5 ,8'38 2 28) 929',8 2)& 58)',& 5' 5 ,' ) 8?!10<= 0!0 6* - (3 ' 5 59'&8 ('35 52)'2& 53&'&& 2)&'32 2(8'3& 2 28) 9, '35 2)& 5()'29 2'8( 592'99 8?!10<= 0!0 6*2- &82'(3 ( ')3 ('( 5(,'93 (2 '93 2 ,'83 2,8'83 2 28) ,8&'&5 2)& 5&5')2 8',9 (29'53 8?!10<= 0!0 6*2- &,5'23 (2'59 8'&& 5,9')( (&9'39 28 '(& 88 '(( 2 28) ,98'28 2)& 533'8( 8'29 (3('38 8?!10<= 0!0 6*2- 3(('2( (5'98 '5 (85' , & &'32 252'2 8&3'&, 2 28 )8)',) 2)& 59,' & 5'93 &28',9 8?!10<= 0!0 6*2- 9 3'(, (&'2 ,',3 (&,'59 &&3'2 2( '38 5)2',9 2 28 )9 ' 5 2)& 5,,',2 2',2 &35'3( 8?!10<= 0!0 6*2- 93,'(2 (,'2) )')) &)2'(& 3 9'3& 2&)'9 58&')& 2 28 82'5& 2)& ( )'25 5'98 32&'(& 8?!10<= 0!0 6*2- ,52'82 & '33 )'58 &88'() 332'(5 23)'() 5&3')) 2 28 9(',, 2)& (2 '25 5' 5 39)'&2 8?!10<= 0!0 6*2- 2 ))8'&, &8'39 ,'3, && '(3 92&'2& 29)')9 5,(')3 2 28 28,'5& 2)& (82' 8 8'5) 985'& 8?!10<= 0!0 6*2- 2 )&5'3( &&'22 )',8 &93'89 99)'3) 2,)')8 (2)'99 2 28 2,8'&8 2)& (58'5) 5'85 99,'88 8?!10<= 0!0 6*2- 2 2&'&2 &3'98 )'8( 3 '(8 ,8&'&9 8))'(( (5(')8 2 28 85,'85 2)& ((('29 2'35 ,5('& 8?!10<= 0!0 6*2- 2 99') &9' ) ,'&) 385'(& ,,2'32 8 )'5 (&9')& 2 28 5)(' 8 2)& (&&'() '2 )) ',8 8?!10<= 0!0 6*2- 2 2()'93 &9', ,'&2 3(3'(, )()'8, 82)' 3 (, '), 2 28 5&2'(5 2)& (33'&& '2, )(,'99 8?!10<= 0!0 6*2- 2 8 '9( &,'28 ,'5& 33,'83 )&'(& 82,'& & 2'93 2 28 ( 9'5& 2)& (99'53 )'(9 &'8 8?!10<= 0!0 6*2- 2 838'9& &,'99 ,'23 9) ')8 &8'9, 88,')3 &85'(8 2 28 (3('(5 2)& (,,'82 '), 38', 8?!10<= 0!0 6*2- 2 58&' 9 3)'8) 9'9& 922'2& 22 '3( 859'8) &(('3& 2 28 &88' & 2)& &),',( )', 282')8 8?!10<= 0!0 6*2- 2 5,9' &9'() '2 955')( 239'98 8(9'8, &33'(( 2 28 &9,',9 2)& &2 '58 5'(, 29,'5) 8?!10<= 0!0 6*2- 2 ((,'(, &9'&8 ')9 9&&'(2 885',3 8&,'5( 3))')2 2 28 35('95 2)& &88'9& )'2, 85('9& 8?!10<= 0!0 6*2- 2 &22' 5 &,')8 )'35 99,' 8,2'2( 89)'5, 322'& 2 28 9)2'98 2)& &5&'2, )'92 5)8'5( 8?!10<= 0!0 6*2- 2 &95')5 &,'58 )' 8 , ')& 55,' 3 8,)',3 355'(& 2 28 9(,'59 2)& &(9' & ' 8 5&)'&3 8?!10<= 0!0 6*2- 2 35('&9 &3'&8 )'& ,88'&2 ()('(, 5) '8) 3&3' 2 2 28 , ('&8 2)& &&,'9( 8') ( 3'8, 8?!10<= 0!0 6*2- 2 9)9'52 &3'&8 ')2 ,(3'5, (&2'(9 5 2' 9 3,)',, 2 28 ,32'85 2)& &92' 2 )'&) (35'&, 8?!10<= 0!0 6*2- 2 93 ')( &9'() )'( ,9)'9, & ,'&( 528')8 9 5'8, 2 282 )2,' 8 2)& &,5'8& '(9 &82')9 8?!10<= 0!0 6*2- 2 ,88' 8 &9',9 ,'38 2 ))8'5) &3&'& 588'2) 98&',) 2 282 )9('92 2)& 3)(', '5) &9,'82 8?!10<= 0!0 6*2- 2 ,,&')) &3' )'9) 2 )2&', 388',9 558'(, 9&)'5 2 282 52',2 2)& 3 3'&, 8'83 35&',, 8?!10<= 0!0 6*2- 8 )(&'(, &&'58 '(& 2 )()'9) 399'&) 5(5'89 995'8) 2 282 ,3'2& 2)& 32,'9 '& 9) ',2 8?!10<= 0!0 6*2- 8 9'2, &&'&2 '5 2 )3('89 955')& 5&('&( ,)9'99 2 282 2(2'58 2)& 352'52 )'89 9(3'3 8?!10<= 0!0 6*2- 8 9)'3( &3')8 )'83 2 ),,',& ,))'5( 53&'() ,88'5& 2 282 8)9'(5 2)& 3(5'&5 '&3 , 5'5) 8?!10<= 0!0 6*2- 8 258'89 &3'52 )'59 2 25'2 ,(3'25 59&',5 ,(3'3 2 282 8&(')& 2)& 3&&'53 )'&5 ,3 '() 8?!10<= 0!0 6*2- 8 8)5',5 &3' & '38 2 53',9 2 ) 2',& 5,3'99 ,9 '59 2 282 52)'() 2)& 339'3& ',2 2 )23'(8 8?!10<= 0!0 6*2- 8 8&9'( &3'33 '2) 2 32'85 2 )3)'( (),'((2 ))('95 2 282 533'35 2)& 3, '98 '28 2 )9('5 8?!10<= 0!0 6*2-        " () * ) + ,  ) -.  ) )         /) /0 )       1 ,)!""  #$"% &&'() *+ &,- 2)  0)./0   1  )#$"% &&'() *+ &,-     ) 1  / 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 :  -. 8 : -. 8 : 1   2 8: 1 52 8: .   8:  897?:  -* 8 58)')8 &9'8) ')2 2 ,('8( 2 2&'5, (2)'((2 )29'9( 2 282 (88'55 2)& 9)5' 9 )',) 2 5 '3 8?!10<= 0!0 6*2- 8 5, '39 &9'3& )'3& 2 2 3',( 2 92',2 (8 '5)2 )( '5( 2 282 (9,'(, 2)& 9 &'5 )'95 2 ,9'5& 8?!10<= 0!0 6*2- 8 (( '99 &,'() )'9& 2 28,'8& 2 289')9 (5 ',82 )32'9& 2 282 &55'59 2)& 929'29 '25 2 2(8',2 8?!10<= 0!0 6*2- 8 & ('(( &,'&8 )'2) 2 2& '(, 2 2,&'35 ((2'952 ),('), 2 282 3)2'9( 2)& 95)'& )',, 2 8 2'9, 8?!10<= 0!0 6*2- 8 &3&'5, &3'(9 ,'&9 2 298'92 2 8(2'&8 (&2'&82 3'82 2 282 3(9'59 2)& 9( '3& 8'5& 2 8&,')( 8?!10<= 0!0 6*2- 8 389'3& &3'39 ,'9, 2 8)3'53 2 5),'8, (32'522 5)',3 2 282 9 5',, 2)& 9&2',8 )'5( 2 52&' ) 8?!10<= 0!0 6*2- 8 9) '(9 &('3& ,'88 2 882'2( 2 5&&'8 (92')&2 &('3( 2 282 93 '&& 2)& 938',( 8'82 2 598'29 8?!10<= 0!0 6*2- 8 9&8',9 &8'&8 9'3 2 8(9',2 2 (22')2 (,)', 2 ,2'52 2 282 ,23' 8 2)& 995' & 8'(8 2 (8,'25 8?!10<= 0!0 6*2- 8 ,2(' 8 & '9 3'3& 2 89&',5 2 (3('9) (,9'3)2 22)'55 2 282 ,9)'3 2)& 9,8'2( 8'29 2 (,8'2( 8?!10<= 0!0 6*2- 8 ,9&',5 &)'83 &'(( 2 5 &'92 2 &2,'59 &)('552 2()'82 2 288 )85'22 2)& ,) '8) 2'9, 2 &53' 8?!10<= 0!0 6*2- 5 )59',9 &)'() (',8 2 553'55 2 &98' 8 & '8)2 29)',5 2 288 )93'3) 2)& ,)9'53 )'9, 2 3))', 8?!10<= 0!0 6*2- 5 '), &)')& 5'(8 2 539'28 2 38&'95 & &'222 8 '38 2 288 5 '29 2)& , 5'&, 2')9 2 3(5'3( 8?!10<= 0!0 6*2- 5 32' ( (,', 2'95 2 ()9'33 2 39,'&) & ,'&22 852'23 2 288 ,8',5 2)& , ,'83 2'5 2 9)3'(, 8?!10<= 0!0 6*2- 5 288'( (9'() )',& 2 (5)' , 2 952'23 &2 '832 838'&, 2 288 25&'(( 2)& ,22'5 8'5, 2 9&)'2, 8?!10<= 0!0 6*2- 5 2,5'32 (&'&( 8(,')5 2 (38') 2 9,8',8 &2 '892 5)&'( 2 288 2,9'2) 2)& ,28'&9 5')2 2 , ',8 8?!10<= 0!0 6*2- 5 8(&',8 (('), 8(9' 9 2 &)3',2 2 ,5('5 &2)' 52 55 '52 2 288 85,'&, 2)& ,28'&, 2'3& 2 ,&8'85 8?!10<= 0!0 6*2- 5 5 9',8 (2'3, 8(3'& 2 &55'5 2 ,,('5, & 9'8)2 533', 2 288 8,,'9) 2)& ,28')3 8'39 8 ) 8'8( 8?!10<= 0!0 6*2- 5 59 ')8 ()',3 8(&'&( 2 &92'35 8 )55'2, & ('9&2 ( &'25 2 288 559'&5 2)& ,2 '92 8' 3 8 )&2')5 8?!10<= 0!0 6*2- 5 (52'(5 59'9 8(&')& 2 322'83 8 ), '28 & 2'932 ((('93 2 288 5,('&( 2)& , ,',3 8'(, 8 )9'93 8?!10<= 0!0 6*2- 5 &)5'22 53')& 8((')9 2 3&8'&, 8 8&'99 &),'852 (,3' , 2 288 (5 '83 2)& , 3'(& 8')3 8 (5'8, 8?!10<= 0!0 6*2- 5 &&3')8 5(' 9 8(8'&2 2 9)3'28 8 9 ',8 &)5'9,2 &5)'38 2 288 (9&'( 2)& , 5'2 8'58 8 ,,'23 8?!10<= 0!0 6*2- 5 329'89 58',3 8( '32 2 9()',8 8 225'&8 (,,'5 2 &95'58 2 288 &2,'85 2)& ,),'3& 2',8 8 25 '39 8?!10<= 0!0 6*2- 5 3,)'9) 58' ( 859'23 2 9,&' 3 8 2&&',9 (, ',(2 32,'&3 2 288 &3 '9( 2)& ,)8'88 5')8 8 298'99 8?!10<= 0!0 6*2- 5 9(8'53 52'( 85(',8 2 ,52' 8 8 8)9'( (92'552 33('&8 2 288 3 8'&) 2)& 9,5'95 2'35 8 82('), 8?!10<= 0!0 6*2- 5 , &' & 58' ( 85('8& 2 ,99' 8 85,'3, (3 '932 92 '& 2 288 3((' 8 2)& 99('2, ' , 8 8&&')2 8?!10<= 0!0 6*2- 5 ,33'(9 58'35 855'38 8 )82'3) 8 8,)'&) (&)',32 9&&'2) 2 288 3,&' , 2)& 93('89 ' , 8 5)&'53 8?!10<= 0!0 6*2- ( )89'&( 5 '99 85('&9 8 )33'() 8 58)'32 (()'832 , ')) 2 288 98&'(( 2)& 9&('3& 8'22 8 55&'25 8?!10<= 0!0 6*2- ( ))'9) 5 '9( 85('99 8 28'39 8 53)',8 (5)' 92 ,(3'29 2 288 933')) 2)& 9(&'(( )'22 8 59&' 8?!10<= 0!0 6*2- ( &8')5 52'22 85('(8 8 3)') 8 ( '8 (2,'9,8 ))8'( 2 288 , 3'&2 2)& 953'2( )'3) 8 (2&' ( 8?!10<= 0!0 6*2- ( 225'&& 52'5) 855'(& 8 2 ('(9 8 (( '89 ( ,' ,8 )5,')9 2 288 ,(3',5 2)& 983'(2 ' ) 8 (&('93 8?!10<= 0!0 6*2- ( 29&'95 5 '35 855'), 8 2& '35 8 (, '() ()3',88 ),('25 2 288 ,,9'82 2)& 923'2( ' 9 8 &)('& 8?!10<= 0!0 6*2- ( 859'2 5)',2 85('59 8 8)3'92 8 &8)'&) 5,3'2,8 5 '82 2 285 )83'&3 2)& 9 3'(& 2') 8 &55'8& 8?!10<= 0!0 6*2- ( 5),',) 5 ' 9 85('2 8 8(5'8( 8 &&,'9) 593')58 93'9( 2 285 )33' ) 2)& 9)9'23 )'( 8 &98'22 8?!10<= 0!0 6*2- ( 53)'9, 5 '29 855'(, 8 5))'22 8 3)9'&) 53&'(38 288'32 2 285 &' ( 2)& 3,9'3( )'&, 8 32 '&9 8?!10<= 0!0 6*2- ( (88'5) 5 '9( 855' 3 8 55&',, 8 359'(( 5&('5)8 29)'5, 2 285 (&'8( 2)& 399'(& ') 8 3& '2( 8?!10<= 0!0 6*2- ( (,('8( 5)',) 85&')& 8 5,8'53 8 399' 5(5'998 82&',3 2 285 ,&' 3 2)& 33,')) 2'(8 8 9))'53 8?!10<= 0!0 6*2- ( &(&'(8 5)' 3 85&'&9 8 (8,',3 8 92&'3( 55('( 8 838'53 2 285 28(')2 2)& 33)'(3 '8& 8 989'9) 8?!10<= 0!0 6*2- ( 3 9'3) 5)'( 85&'85 8 (93'8& 8 9&('9, 58&' 28 52)'9& 2 285 235'89 2)& 3&2' 5 )'&( 8 933'&2 8?!10<= 0!0 6*2- ( 39)'(( 8,',9 859'( 8 &85'(3 8 ,)5'99 523'528 5&9')3 2 285 8 8'(3 2)& 3(5'8, 2'52 8 , &'88 8?!10<= 0!0 6*2- ( 952'33 5)'83 859'&) 8 &92' 8 ,55'22 5 ,'5(8 ( ('& 2 285 8(8'), 2)& 353'89 )'&8 8 ,(('5) 8?!10<= 0!0 6*2-        " () * ) + ,  ) -.  ) )         /) /0 )       1 ,)!""  #$"% &&'() *+ &,- 2)  0)./0   1  )#$"% &&'() *+ &,-     ) 1  / 1 8 : = 89: > 89: 657+/ 8 : 67+ 8 :  -. 8 : -. 8 : 1   2 8: 1 52 8: .   8:  897?:  -* ( ,)5')3 5 ')) 859'(2 8 329'&) 8 ,98'8, 5 '(88 (&2' ) 2 285 8,2'55 2)& 35)'5 ')8 8 ,,5'8) 8?!10<= 0!0 6*2- ( ,&('(9 5 '33 853'99 8 335'35 5 )28'2) 5)8'2 8 &)9'25 2 285 582'55 2)& 388')3 '58 5 )88'98 8?!10<= 0!0 6*2- & )23' 9 5 '9, 853'2( 8 92)'&5 5 )&8'8 8,5'8&8 &(5' 5 2 285 532'3& 2)& 32('2) )'3 5 )38'&( 8?!10<= 0!0 6*2- & )9,' 2 52'25 85&',3 8 9&&'&8 5 )8'33 89(' )8 3))' 8 2 285 ( 8'52 2)& 3 &',8 )'&5 5 8'3, 8?!10<= 0!0 6*2- & ()'55 52'9( 85&' ) 8 , '9 5 55'), 83('5(8 35('8 2 285 ((8',3 2)& 3)9'2& '89 5 (8'3, 8?!10<= 0!0 6*2- & 2 2'2( 52'33 85('22 8 ,(3' ( 5 95'39 8&(')(8 3,)'&( 2 285 (,5',) 2)& &,9'9( )',9 5 ,5' 5 8?!10<= 0!0 6*2- & 235')9 52'2) 855'98 5 ))2'3( 5 22(' 2 8(5'2&8 98&'2( 2 285 &8('() 2)& &9,')( ')2 5 285' 8 8?!10<= 0!0 6*2- & 88&'&2 8,',3 853')5 5 )5,'9, 5 2&5',9 855'2(8 998'8, 2 285 &3('(9 2)& &9)')2 5'2( 5 238'&( 8?!10<= 0!0 6*2- & 8,3'99 89' 8()'(2 5 ),3'53 5 8)2'9 88&'328 ,8)',3 2 285 3 8'(, 2)& &38'5 5'&, 5 8 '28 8?!10<= 0!0 6*2- & 5(,',2 89'89 85,',9 5 5&' , 5 85)'&& 88)'228 ,3,'&, 2 285 3( '(9 2)& &&3'98 )'&, 5 859'9( 8?!10<= 0!0 6*2- & (22'2, 89'99 85,'(, 5 ,5',2 5 839',9 828'8 5 )29'52 2 285 3,)')& 2)& && '9& )'9, 5 89&',5 8?!10<= 0!0 6*2- & (9(') 8,' 2 85,'2 5 258'&& 5 5 3'33 8 &')(5 )33' & 2 285 92,')2 2)& &(('(( )'(5 5 52('5, 8?!10<= 0!0 6*2- & &5&'33 8,' ( 859' ) 5 2, '(3 5 5((',, 8)9'8,5 2(')3 2 285 9&3'5 2)& &59'9 ' 5 5 5&8'5( 8?!10<= 0!0 6*2- & 3)9'(3 8,'5) 853'55 5 88,'5 5 5,5'22 8))' )5 32', 2 285 ,)('95 2)& &5 '5& )'3, 5 () '5 8?!10<= 0!0 6*2- & 33)',2 89',, 85&'&( 5 893'38 5 (82'&2 2, '235 22 '28 2 285 ,55'55 2)& &88'(& ')5 5 (8,'( 8?!10<= 0!0 6*2- & 982',( 8,'8) 85('&, 5 58('95 5 (3)'&( 29 ',)5 2&,'85 2 285 ,92'&9 2)& &2(' 8 ' ) 5 (33'22 8?!10<= 0!0 6*2- & 9,('8& 8,'(2 85('5( 5 595')( 5 &),')2 232')85 8 3'(( 2 28( )2 '29 2)& & &' , )'58 5 & ('23 8?!10<= 0!0 6*2- & ,(3'&( 8,',5 855',8 5 (8 ',& 5 &53'( 2& '9(5 8&('5& 2 28( )&)') 2)& &)&',& )'9& 5 &(8'52 8?!10<= 0!0 6*2- 3 ) 3',9 5)' 5 855'38 5 (39' ( 5 &95',3 2( '3)5 5 '&( 2 28( ),3'3) 2)& (,3'32 )'8, 5 &,)'(5 8?!10<= 0!0 6*2- 3 )9)',( 5)' 8 855' 5 &2&'2, 5 325')3 25)'3,5 5(,'3, 2 28( 83')( 2)& (93'33 )'&8 5 32,'29 8?!10<= 0!0 6*2- 3 58',, 8,',3 858'55 5 &35'(( 5 3&8') 22,'5&5 ()9')( 2 28( 3&'2& 2)& (33'8, )'38 5 3&3'9& 8?!10<= 0!0 6*2- 3 2)3' ) 8,',) 852' 3 5 322',5 5 9) '3 2 3'5,5 ((&'55 2 28( 2 ('25 2)& (&&'8& '8) 5 9)&' & 8?!10<= 0!0 6*2- 3 2&9'38 5)'5( 852')2 5 33)')8 5 98,'(( 2)('2&5 &)8'(8 2 28( 2(8'8& 2)& (((')& )', 5 958'&) 8?!10<= 0!0 6*2- 3 88)'3 5)'&& 85 '5, 5 9 3' 2 5 933'92 ,2'&(5 &()'&2 2 28( 2, ',8 2)& (58'89 )'&( 5 99 '5( 8?!10<= 0!0 6*2- 3 8,2')& 5)'8( 85)'3& 5 9&8'33 5 , ('(2 3,'3&5 &,3'23 2 28( 82,',5 2)& (8 '5 )',2 5 , 9'35 8?!10<= 0!0 6*2- 3 5(5')8 5)'29 85)'(2 5 , ')2 5 ,(8'8( &&'5&5 355'(2 2 28( 8&9')9 2)& ( ,')5 )'23 5 ,(&' 8 8?!10<= 0!0 6*2- 3 ( &'8( 8,',3 889'83 5 ,(9'&3 5 ,,)',( (2'835 3,2' 3 2 28( 5)&') 2)& ()('93 2'29 5 ,,8'23 8?!10<= 0!0 6*2- 3 (&2'&5 5)')5 889'2 5 ,,5' 8 ( ) 9'&) 5 '8&5 923'&8 2 28( 588',2 2)& 5,('(5 )'23 ( )2)'(& 8?!10<= 0!0 6*2- 3 &))')) 5)')5 889'2 ( )22'38 ( )5)', 82'555 9(&'28 2 28( 5(&'5( 2)& 593' & )')) ( )52'(, .D+/+/ 7$A 7$A  A        Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.01.31 16:25:39 -09'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.02.02 10:56:52 -09'00' TD Shoe Depth: PBTD: Jts. 2 36 Yes X No X Yes No 5 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Casing (Or Liner) Detail Shoe 8 5/8 Rotate Csg Recip Csg Ft. Min. PPG9.2 Shoe @ 1511.88 FC @ Top of Liner Floats Held Spud Mud CASING RECORD County State Alaska Supv.R Pederson / J Richardson Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Paxton 11 Date Run 20-Jan-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top CDC Innovex 1.50 1,511.88 1,510.38 Csg Wt. On Hook:40 Type Float Collar:Innovex No. Hrs to Run:4.5 9.2 5 100 469FIRST STAGE10.5Tuned 41 65.2/66 1270 75.4 Rig 15.8 45 Bump press Visual Bump Plug? 21:18 1/20/2022 0 1,511.881,521.00 1,430.00 CEMENTING REPORT Csg Wt. On Slips: Spud Mud 12 92 Type of Shoe:Bullnose Casing Crew:Weatherford www.wellez.net WellEz Information Management LLC ver_04818br 1.2 Every other joint up to 297' Casing 7 5/8 29.7 L-80 CDC USS 79.12 1,510.38 1,431.26 Float Collar 7 5/8 CDC Innovex 1.26 1,431.26 1,430.00 Casing 7 5/8 29.8 L-80 CDC USS 1,406.37 1,430.00 23.63 Pup Jnt 7 5/8 29.7 L-80 CDC USS 2.32 23.63 21.31 Casing Hanger 16 CDC Cactus 1.10 21.31 20.21 Type I II 215 2.4 Type I II 210 1.16 4 TD Shoe Depth: PBTD: Jts. 1 2 152 Yes X No X Yes No 60 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?:X Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Casing (Or Liner) Detail Shoe 5 Rotate Csg Recip Csg Ft. Min. PPG9.55 Shoe @ 7598 FC @ Top of Liner 1269.637,553.64 Floats Held 6% KCL PHPA mud CASING RECORD County State Alaska Supv.J Murphy/ J Richardson Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.NINU Paxton 11 Date Run 31-Jan-22 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top BTC Innovex 1.72 7,596.00 7,594.28 Csg Wt. On Hook:115 Type Float Collar:Innovex No. Hrs to Run:24 9.55 3 95 1362FIRST STAGE10.5Tuned 28 112/112 4000 33 HES 15.3 15 Bump press CBL Bump Plug? 1:55 2/1/2022 1,364' 7,596.007,600.00 7,509.22 CEMENTING REPORT Csg Wt. On Slips:100 6% KCL PHPA mud 12 204 Type of Shoe:Innovex Casing Crew:WOTCO Baker HRD-E ZXP Flex lock V hanger. www.wellez.net WellEz Information Management LLC ver_04818br 1.6 Ran 147 centralizers Casing 4 1/2 12.6 L-80 DWC/C HT Vam 41.36 7,594.28 7,552.92 Float collar 5 BTC Innovex 1.28 7,552.92 7,551.64 Casing 4 1/2 12.6 L-80 DWC/C HT Vam 41.42 7,551.64 7,510.22 Landing collar 5 BTC Baker 1.03 7,510.22 7,509.19 Casing 4 1/2 12.6 L-80 DWC/C HT Vam 6,203.82 7,509.19 1,305.37 Pup 4 1/2 12.6 L-80 DWC/C HT Vam 4.78 1,305.37 1,300.59 ZXP Hanger 6 5/8 BTC Baker 32.96 1,300.59 1,267.63 Type I II 485 2.39 Type I II 95 1.24 5 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/08/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Paxton 11 (PTD 221-114) GPT 3/01/2022 Please include current contact information if different from above. 221-114 T36409 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.08 14:06:18 -09'00' 1 Regg, James B (OGC) From:Jay Murphy - (C) <Jay.Murphy@hilcorp.com> Sent:Friday, February 4, 2022 5:32 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Subject:FW: Paxton 11 Final MIT Test Attachments:MIT Paxton 11 02-2-22.xlsx; MIT 4.5 & 7.625 x 4.5 Paxton 11 2-2-22.pdf Here is the Chart.  From: Jay Murphy ‐ (C)   Sent: Friday, February 4, 2022 5:24 PM  To: jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov; chris.wallace@alaska.gov  Subject: Paxton 11 Final MIT Test  Thank You and Best Regards,  Jay Murphy/ DSM  Hilcorp Alaska, LLC HAK Rig 169  Office: 907‐776‐6776  Cell: 907‐715‐9211  Jay.Murphy@Hilcorp.com 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. Some people who received this message don't often get email from jay.murphy@hilcorp.com. Learn why this is important 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. JBR; 2/7/2022 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2211140 Type Inj N Casing 0 3120 3113 3108 Type Test P Packer TVD NA BBL Pump 1.2 IA 0 0 0 0 Interval I Test psi 3000 BBL Return 1.2 OA Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2211140 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 1267 BBL Pump 0.4 IA 0 2620 2615 2615 Interval I Test psi 2500 BBL Return 0.4 OA Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Pumped 16.38 gallons , bled back 16.38 gallons on 7 5/8'' x 4.5'' IA Notes: Notes: Hilcorp Alaska, LLC Ninilchik / Ninilchik Unit / Paxton Pad Witness Waived Josh Riley 02/02/22 Notes:Pumped 49.56 gallons, bled back 49.42 gallons on 4.5'' Liner and tieback Notes: Notes: Notes: Paxton 11 Paxton 11 Form 10-426 (Revised 01/2017)MIT Paxton 11 02-2-22        JBR; 2/7/2022 JBR; 2/7/2022 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. Thanks 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: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, February 9, 2022 10:40 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: Pax-11 CBL (PTD#221-114 Here’s the CBL. We hope to start perf’ing tomorrow. Let us know. Thanks,       Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) 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 herebynotified 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 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 by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 02/28/2022 To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 11  PTD 221-114  API: 50-133-20704-00-00 Washed and Dried Well Samples (TD: 01/29/2022) B Set (6 Boxes): WELL BOX SAMPLE INTERVAL (FEET / MD) PAXTON 11 BOX 1 OF 6 1520’ - 2500’ MD PAXTON 11 BOX 2 OF 6 2500’ - 3500’ MD PAXTON 11 BOX 3 OF 6 3500’ - 4500’ MD PAXTON 11 BOX 4 OF 6 4500’ - 5500’ MD PAXTON 11 BOX 5 OF 6 5500’ - 6500’ MD PAXTON 11 BOX 6 OF 6 6500’ - 7600’ MD (TD) Please include current contact information if different from above. 221-114 1801 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.02 15:57:34 -09'00' 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 by signing and returning one copy of this transmittal. Received By: Date: Date: 2/25/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 11 (PTD 221-114) FINAL LWD FORMATION EVALUATION LOGS (01/18/2022 to 01/31/2022) ROP, DGR, GM, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) Final Definitive Directional Survey Folder Contents: Please include current contact information if different from above. 221-114 T36376 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.02.25 12:33:09 -09'00' From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Todd Sidoti - (C); Juanita Lovett; Matthew Petrowsky Subject:RE: [EXTERNAL] RE: Pax-11 CBL (PTD#221-114 Date:Wednesday, February 9, 2022 12:39:00 PM Ryan, The cement looks good based on the log. You have approval to perforate per the Sundry, no higher than 3000’ TVD. Thanks 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: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, February 9, 2022 12:38 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Matthew Petrowsky <mpetrowsky@hilcorp.com> Subject: RE: [EXTERNAL] RE: Pax-11 CBL (PTD#221-114 No higher than 3000’ TVD / 4933’ MD. This includes the BEL-94 and below sand       Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, February 9, 2022 12:33 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL] RE: Pax-11 CBL (PTD#221-114 Ryan, What is the shallowest interval you are planning to perf? P.I. SupvComm:Rig Coil Tubing Unit? NoRig Contractor Rig RepresentativeOperator Contractor RepresentativeWell Permit to Drill # 2211140 Sundry Approval #Operation Inspection LocationWorking Pressure, W/H Flange P Pit Level Indicators P Working Pressure PP Flow Rate Sensor P Operating Pressure PP Mud Gas Separator P Fluid Level/Condition PFP Degasser P Pressure Gauges PP Separator Bypass P Sufficient Valves PP Gas Detectors FP Regulator Bypass PP Alarms Separate/Distinct P Actuators (4-way valves) PP Choke/Kill Line Connections PBlind Ram Handle Cover PP Reserve Pits P Control Panel, Driller PP Trip Tank P Control Panel, Remote PPFirewallPP2 or More Pumps PP Kelly or TD Valves P Independent Power Supply PP Floor Safety Valves P N2 Backup PP Driller's Console P Condition of Equipment PP Flow Monitor PFlow Rate Indicator PPit Level Indicators P Valves PPPE P Gauges P Remote Hydraulic Choke PWell Control Trained P Gas Detection Monitor P FOV Upstream of Chokes PHousekeeping P Hydraulic Control Panel P Targeted Turns PWell Control Plan P Kill Sheet Current P Bypass Line PFAILURES:2CORRECT BY:CHOKE MANIFOLDPaxton Pad MUD SYSTEMPaxton 11DrillingCLOSING UNITALASKA OIL AND GAS CONSERVATION COMMISSIONRIG INSPECTION REPORTHCR Valve(s)Manual ValvesAnnular PreventerWorking Pressure, BOP StackStack AnchoredChoke LineKill LineTargeted TurnsPipe RamsBlind RamsRance PedersonJon Van EveraLocking Devices, RamsBOP STACKCOMMENTSLou Laubenstein1/22/2022Rig was super clean and everything looked really good. Detials about failures documented in BOPE Test ReportINSPECT DATEAOGCC INSPECTORfailures corrected during BOPE testHilcorp 169ParkerHilcorp Alaska LLCMISCELLANEOUSFlange/Hub ConnectionsDrilling Spool OutletsFlow NippleControl LinesRIG FLOOR2022-0122_BOP_Hilcorp169_Ninilchik_Paxton-11_ll rev. 5-8-189999999-%5 MEMORANDUM TO: Jim Re p'Lv P.I. Supervisor �6 FROM: Lou Laubenstein Petroleum Inspector I Well Name PAXTON 11 IRsp Num: mitLOL220126100949 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 1, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 11 PAXTON ll API Well Number 50-133-20704-00-00 Permit Number: 221-114-0 Src: Inspector Reviewed By: P.I. Supry YC Comm Inspector Name: Lou Laubenstein Inspection Date: 1/22/2022 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I I Type Inj N ' 1TVD Tubing PTD 2211140 _ Type Test SPT'Test psi 3500 - IA - - — BBL Pumped: j 0.9 BBL Returned: 0.9 OA Interval OTHER P/F P Notes' Surface casing test to 3500PSI, Test was charted. �/ Nt7 C !V4 -j— pfvJe` ded 0 1 3570 ' 1 3520 -I 3515 - Tuesday, February 1, 2022 Page 1 of 1 STATE OF ALASKA Reviewed By: _J_&_ OIL AND GAS CONSERVATION COMMISSION P I SupryAZ 7M7_ BOPE Test Report for: PAXTON 11 Comm Contractor/Rig No.: Hilcorp 169 PTD#: 2211140 DATE: 1/22/2022 Inspector Lou Laubenstein Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Rance Pederson Rig Rep: Jon Van Evera Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopLOL220123102530 Rams: Annular: Valves: MASP: Type Test: NIT 250/5000 - 250/5000 250/5000 ' 1753 ' Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: Time/Pressure P/F System Pressure 3075 Visual Alarm Location Gen.: _ P Trip Tank P _ P Housekeeping: P _ Pit Level Indicators P P___ PTD On Location P__ Flow Indicator P P Standing Order Posted - P Meth Gas Detector FP _ FP_ Well Sign P ' H2S Gas Detector P P' Drl. Rig P MS Misc NA NA Hazard Sec. P 1 Blinds P CH Misc 1 Misc NA 0 NA #3 Rams ACCUMULATOR SYSTEM: BOP STACK: Time/Pressure P/F System Pressure 3075 P_ Pressure After Closure 1600 P 200 PSI Attained 20 P " Full Pressure Attained 92 P " Blind Switch Covers: P , Nitgn. Bottles (avg): 4(a), 2475_ ' P ACC Misc 0 NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1, P Stripper _ 0 __ __ NA No. Valves 15 P Lower Kelly 11 P_ " Annular Preventer 1 - 1_1_" P_ Manual Chokes _ I P Ball Type ___-I P #1 Rams -1 " 2-_7_/8" x 5" vb P_'-_ Hydraulic Chokes _ 1 P Inside BOP 1 P #2 Rams 1 Blinds P CH Misc 1 FPS FSV Misc 0 NA #3 Rams 1 2-7/8" x 5" vb F #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3-1/8" P Quantity P/F HCR Valves 2 2-1/16" & 3-1/ P Inside Reel Valves 0_ NA Kill Line Valves 2 246" P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 4 1 Test Results Test Time 5 Remarks: Test completed with 4 1/2" test joint, LEL head in pits needed to be re -calibrated and passed retest, Inlet flange on choke leaks and was tightened, Lower pipe rams failed and were changed out to 4.5" solids and passed. Close times; Annular 23 sec, Upper Pipe Rams 5 sec, Blinds 4 sec, Lower Pipe Rams 5 sec, HCR Kill 2 sec and HCR Choke 2 sec. 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 by signing and returning one copy of this transmittal Received By: Date: DATE: 02/08/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PAXTON 11 (PTD 221-114) MUDLOGS - EOW DRILLING REPORTS (01/19/2022 to 01/29/2022) 1. FINAL EOW REPORT 2. DAILY REPORTS 3. SHOW REPORTS 4. DIGITAL DATA 5. MUDLOG PRINTS (2” and 5” MD and TVD COLOR PRINTS) Formation Log LWD Combo Log Gas Ratio Log Drilling Dynamics Log SFTP Transfer - Data Folders: Please include current contact information if different from above. 37' (6HW Received By: 02/08/2022 By Abby Bell at 9:18 am, Feb 08, 2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Paxton 11 MIT Test Report Date:Tuesday, February 1, 2022 9:56:06 AM Attachments:MIT Paxton 11 01-22-22 Revised.xlsx Paxton 11 (PTD 2211140) Revised surface casing pressure test Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Tuesday, February 1, 2022 8:10 AM To: Rance Pederson - (C) <rpederson@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: Paxton 11 MIT Test Report Rance, Attached is a revised report changing the interval to “O” and moving the data to the IA line (remarks remain the same) based on the inspector’s report. Please update your copy. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Rance Pederson - (C) <rpederson@hilcorp.com> Sent: Sunday, January 23, 2022 1:05 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay 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. <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Paxton 11 MIT Test Report Drilling Engineer requested we notify you of MIT of surface casing. Not positive I entered test data correctly on this form but here are results for our 7 5/8” casing test. Rance Pederson Drilling Foreman Ninilchik Unit 907-776-6776 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. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2211140 Type Inj N Tubing Type Test P Packer TVD BBL Pump 0.9 IA 0 3570 3520 3515 Interval O Test psi 3500 BBL Return 0.9 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska, LLC Ninilchik / Ninilchik Unit / Paxton Pad Lou Laubenstein Rance Pederson 01/22/22 Notes:Pumped 37.95 gallons, bled back 37.95 gallons on 7 5/8" surface casing test. 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ϲͲϯͬϰ͟ ŚŽůĞ Ϯ ϭ ĞůƵŐĂϳʹ dLJŽŶĞŬϭϰ  EMP     ^dEZt>>WZKhZ E/dZK'EKWZd/KE^ ϭϮͬϬϴͬϮϬϭϱ &/E>ǀϭ WĂŐĞϭŽĨϭ ϭ͘Ϳ D/ZhEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Ϯ͘Ϳ EŽƚŝĨLJWĂĚKƉĞƌĂƚŽƌŽĨƵƉĐŽŵŝŶŐEŝƚƌŽŐĞŶŽƉĞƌĂƚŝŽŶƐ͘ ϯ͘Ϳ WĞƌĨŽƌŵWƌĞͲ:Žď^ĂĨĞƚLJDĞĞƚŝŶŐ͘ZĞǀŝĞǁEŝƚƌŽŐĞŶǀĞŶĚŽƌƐƚĂŶĚĂƌĚŽƉĞƌĂƚŝŶŐƉƌŽĐĞĚƵƌĞƐĂŶĚ ĂƉƉƌŽƉƌŝĂƚĞ^ĂĨĞƚLJĂƚĂ^ŚĞĞƚƐ;ĨŽƌŵĞƌůLJD^^Ϳ͘ ϰ͘Ϳ ŽĐƵŵĞŶƚ ŚĂnjĂƌĚƐ ĂŶĚ ŵŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ĂŶĚ ĐŽŶĨŝƌŵ ĨůŽǁ ƉĂƚŚƐ͘ /ŶĐůƵĚĞ ƌĞǀŝĞǁ ŽŶ ĂƐƉŚLJdžŝĂƚŝŽŶ ĐĂƵƐĞĚ ďLJ ŶŝƚƌŽŐĞŶ ĚŝƐƉůĂĐŝŶŐŽdžLJŐĞŶ͘ DŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ŝŶĐůƵĚĞĂƉƉƌŽƉƌŝĂƚĞ ƌŽƵƚŝŶŐŽĨĨůŽǁůŝŶĞƐ͕ĂĚĞƋƵĂƚĞǀĞŶƚŝŶŐĂŶĚĂƚŵŽƐƉŚĞƌŝĐŵŽŶŝƚŽƌŝŶŐ͘ ϱ͘Ϳ ^ƉŽƚWƵŵƉŝŶŐhŶŝƚĂŶĚdƌĂŶƐƉŽƌƚ͘ŽŶĨŝƌŵůŝƋƵŝĚEϮǀŽůƵŵĞƐŝŶƚƌĂŶƐƉŽƌƚ͘ ϲ͘Ϳ ZŝŐƵƉůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚƚŽƚŚĞǁĞůůĂŶĚƌĞƚƵƌŶƐƚĂŶŬ͘^ĞĐƵƌĞůŝŶĞƐǁŝƚŚǁŚŝƉ ĐŚĞĐŬƐ͘ ϳ͘Ϳ WůĂĐĞ ƐŝŐŶƐ ĂŶĚ ƉůĂĐĂƌĚƐ ǁĂƌŶŝŶŐ ŽĨ ŚŝŐŚ ƉƌĞƐƐƵƌĞ ĂŶĚ ŶŝƚƌŽŐĞŶ ŽƉĞƌĂƚŝŽŶƐ Ăƚ ĂƌĞĂƐ ǁŚĞƌĞ EŝƚƌŽŐĞŶŵĂLJĂĐĐƵŵƵůĂƚĞŽƌďĞƌĞůĞĂƐĞĚ͘ ϴ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐĚŽǁŶƐƚƌĞĂŵŽĨůŝƋƵŝĚĂŶĚŶŝƚƌŽŐĞŶƉƵŵƉƐƚŽĂĚĞƋƵĂƚĞůLJŵĞĂƐƵƌĞƚƵďŝŶŐ ĂŶĚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐ͘ ϵ͘Ϳ 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Frank Roach Cc:Regg, James B (OGC) Subject:RE: Paxton 11 BOP Test Frequency Request (PTD 221-114) Date:Wednesday, January 12, 2022 7:58:00 AM Frank, The 14 day BOP test frequency is approved for Paxton 11. 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: Frank Roach <Frank.Roach@hilcorp.com> Sent: Wednesday, January 12, 2022 7:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Paxton 11 BOP Test Frequency Request (PTD 221-114) Bryan, Thank you for the discussion last week about the Paxton 11. As you noted, there was some inconsistent lines in the program regarding BOP test frequency. Paxton 11 is an infill, development well that is not targeting any new reservoirs, nor delineating a new field. As such, we request to have a 14-day test frequency under 20 AAC 25.035 (e)(10)(A). If you need any additional information or have any questions, please let me know. Regards, Frank V Roach Drilling Engineer 907.854.2321 (c) 907.777.8413 (o) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the Žƒ•ƒ‹Žƒ† ƒ• ‘•‡”˜ƒ–‹‘‘‹••‹‘ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov   Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Paxton 11 Hilcorp Alaska, LLC Permit to Drill Number: 221-114 Surface Location: 945’ FNL, 3092’ FEL, SEC. 13, T1S, R14W, SM, AK Bottomhole Location: 1053’ FNL, 2345’ FWL, SEC. 12, T1S, R14W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of December, 2021. 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850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 Vertical Section at 1.79° (850 usft/in) Paxton 11 wp04 tgt1 Paxton 11 wp04 tgt2 20" Casing 7 5/8" Casing 4 1/2" Casing 5 0 0 1 0 0 0 15002000250030003500400045005000550060006500700075007598Paxton #11 wp05 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 450' MD, 449.63'TVD End Dir : 2069.74' MD, 1683.54' TVD Start Dir 3º/100' : 3751.15' MD, 2304.08'TVD End Dir : 4839.06' MD, 2923.17' TVD Total De pth : 7598.36' MD, 4980.06' T Beluga 7 Beluga 10 Beluga 20 Beluga 30 Beluga 41 Beluga 50 Beluga 60 Beluga 70 Beluga 80 Beluga 90A Beluga 100 Beluga 110 Beluga 120 Beluga 135 T-10A Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: Paxton #11 148.50 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2230420.26 206232.01 60° 5' 43.9347 N 151° 36' 34.2659 W SURVEY PROGRAM Date: 2021-12-14T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 1534.00 Paxton #11 wp05 (Paxton #11) 3_MWD+IFR1+MS+Sag 1534.00 7598.36 Paxton #11 wp05 (Paxton #11) 3_MWD+IFR1+MS+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 1420.90 1254.40 1565.93 Beluga 7 1481.98 1315.48 1661.71 Beluga 10 1601.48 1434.98 1878.53 Beluga 20 1646.53 1480.03 1976.89 Beluga 30 1755.31 1588.81 2264.21 Beluga 41 2002.48 1835.98 2933.93 Beluga 50 2452.63 2286.13 4091.12 Beluga 60 2523.82 2357.32 4226.17 Beluga 70 2688.45 2521.95 4501.59 Beluga 80 2811.34 2644.84 4684.49 Beluga 90A 3230.93 3064.43 5251.92 Beluga 100 3304.87 3138.37 5351.11 Beluga 110 3383.07 3216.57 5456.01 Beluga 120 3572.46 3405.96 5710.08 Beluga 135 4457.67 4291.17 6897.57 T-10A REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: Paxton #11, True North Vertical (TVD) Reference:RKB Permit @ 166.50usft (HEC 169) Measured Depth Reference:RKB Permit @ 166.50usft (HEC 169) Calculation Method: Minimum Curvature Project:Ninilchik Unit Site:Paxton Well:Plan: Paxton #11 Wellbore:Paxton #11 Design:Paxton #11 wp05 CASING DETAILS TVD TVDSS MD Size Name 98.00 -68.50 98.00 20 20" Casing 1400.00 1233.50 1534.77 7-5/8 7 5/8" Casing 4980.06 4813.56 7598.36 4-1/2 4 1/2" Casing SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 3 450.00 6.00 43.00 449.63 7.65 7.14 3.00 43.00 7.87 Start Dir 4º/100' : 450' MD, 449.63'TVD 4 650.00 14.00 43.00 646.44 33.03 30.80 4.00 0.00 33.97 5 2069.74 68.34 10.49 1683.54 877.67 289.59 4.00 -36.66 886.26 End Dir : 2069.74' MD, 1683.54' TVD 6 3751.15 68.34 10.49 2304.08 2414.25 574.13 0.00 0.00 2430.96 Start Dir 3º/100' : 3751.15' MD, 2304.08'TVD 7 4503.88 50.00 355.00 2689.92 3053.71 613.20 3.00 -147.80 3071.33 Paxton 11 wp04 tgt1 8 4839.06 41.80 346.86 2923.17 3291.00 576.52 3.00 -147.28 3307.36 End Dir : 4839.06' MD, 2923.17' TVD 9 7598.36 41.80 346.86 4980.06 5082.11 158.40 0.00 0.00 5084.58 Paxton 11 wp04 tgt2 Total Depth : 7598.36' MD, 4980.06' TVD 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 South(-)/North(+) (600 usft/in)-2400 -2000 -1600 -1200 -800 -400 0 400 800 1200 1600 West(-)/East(+) (600 usft/in) Paxton 11 wp04 tgt2 Paxton 11 wp04 tgt1 20" Casing 7 5/8" Casing 4 1/2" Casing 2505 0 0 750 1000 1250 1500 1750 2000 2250 2500 2 7 5 0 3 0 0 0 3 2 5 0 3 5 0 0 3 7 5 0 4 0 0 0 4 2 5 0 4 5 0 0 4 7 5 0 4 9 8 0 Paxton #11 wp05 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 450' MD, 449.63'TVD End Dir : 2069.74' MD, 1683.54' TVD Start Dir 3º/100' : 3751.15' MD, 2304.08'TVD End Dir : 4839.06' MD, 2923.17' TVD Total Depth : 7598.36' MD, 4980.06' TVD Project: Ninilchik Unit Site: Paxton Well: Plan: Paxton #11 Wellbore: Paxton #11 Plan: Paxton #11 wp05 WELL DETAILS: Plan: Paxton #11 148.50 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2230420.26 206232.01 60° 5' 43.9347 N 151° 36' 34.2659 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: Paxton #11, True North Vertical (TVD) Reference:RKB Permit @ 166.50usft (HEC 169) Measured Depth Reference:RKB Permit @ 166.50usft (HEC 169) Calculation Method:Minimum Curvature CASING DETAILS TVD TVDSS MD Size Name 98.00 -68.50 98.00 20 20" Casing 1400.00 1233.50 1534.77 7-5/8 7 5/8" Casing 4980.06 4813.56 7598.36 4-1/2 4 1/2" Casing  & "  ' !  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"!8 ! 9    :     3 45 )&   3  ; &0 3    3 $   &0    <  $ #=  $ )   >&   9  ; ;  &      3 398:3:03 4 3 :&    0.001.002.003.004.00Separation Factor0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 6375 6800 7225 7650 8075Measured Depth (850 usft/in)Paxton #2 SurveysPaxton #8Susan Dionne #4No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: Paxton #11 NAD 1927 (NADCON CONUS)Alaska Zone 04148.50+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002230420.26 206232.01 60° 5' 43.9347 N 151° 36' 34.2659 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Paxton #11, True NorthVertical (TVD) Reference: RKB Permit @ 166.50usft (HEC 169)Measured Depth Reference:RKB Permit @ 166.50usft (HEC 169)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-12-14T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool18.00 1534.00 Paxton #11 wp05 (Paxton #11) 3_MWD+IFR1+MS+Sag1534.00 7598.36 Paxton 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