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Home My WebLink About2025_09_29_325-5331. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 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): 8,013'N/A Casing Collapse Structural Conductor 1,410psi Surface 4,790psi Intermediate Production Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY 8,430psi 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 ADL392666 221-102 50-231-20093-00-00 Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 1,747' 1,879' Size 120' 1,979' MD 4-1/2" See Schematic 2,980psi 6,880psi 120'120' 1,979' October 14, 2025 8,013'6,272' 4-1/2" 7,261' Perforation Depth MD (ft): 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Whiskey Gulch 14CO 799 Same ~600 psi See Schematic Length Liner Top Pkr; N/A 1,741' MD/1,669' TVD; N/A 7,261'2,975'2,750' Whiskey Gulch Whiskey Gulch Undefined 16" 7-5/8" See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:01 am, Sep 29, 2025 8:01 am, Sep 29, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.09.26 16:24:12 - 08'00' Noel Nocas (4361) 325-533 FRAC – WG T-10 Coal Rev 1 Well: Whiskey Gulch 14 PTD: 221-102 API: 50-231-20093-00-00 Well Name:Whiskey Gulch 14 Permit to Drill:221-102 Current Status:Operable, Producer API Number:50-231-20093-00-00 Estimated Start Date:October 14, 2025 Estimated Duration:1 day First Call Engineer:Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (M) Second Call Engineer:Ryan LeMay (661) 487-0871 (M) Current Bottom Hole Pressure:923 psi @ 2148’ TVD (based on 0.43 psi/ft gradient) Max Anticipated Surface Pressure:600 psi 1year Shut-in build up pressure Brief Well Summary: Whiskey Gulch -14 is an exploration well drilled near Anchor Point into the Tyonek and Beluga gas sands. It was drilled in March 2022 and tested without success for commercial gas. The well has been tested in multiple sands and coals and currently plugged back to the Tyonek T10 Coal. The well is currently perforated 6 spf in the Tyonek T10 coal. Last Casing Test: x 4-1/2” liner/tubing tested to 3000 psi under PTD 221-102 on 3/16/22 x Tubing tested to 4500 psi on 1/6/24 Objective: Perform a small slickwater frac on the Tyonek T10 coal and flowback frac fluids from the well. Well Completion Information: Wellhead: Cactus C-29L-HPS, 16-3/4” 3M x 11 5M tubing head Cactus EN 6.25” 11” 5M x 4-1/16” 5M Adapter A Variance is required for 20AAC25.283(C)(1) which requires the fracture string to be stung into a liner or a packer set 100ft below the cement top of the production casing. This fracture will use the tubing string for a frac string, which places the liner top packer and seals for the liner 232ft above the surface casing shoe instead of 100ft below the casing cement. There is cement from the Tyonek T10 Coal (Frac interval) into the liner lap between the 7-5/8” surface casing and the 4-1/2”. The liner top packer that was tested to 3000psi. Frac Procedure: 1. Conduct safety meeting and review sundry. 2. MIRU frac equipment and associated frac tanks. 3. Pressure test surface lines to at least 6,000 psi. 4. Test Tubing Pop-off system to ensure proper function. Tubing Pop-off to be set at 4,500 psi. 5. Test IA Pop-off system to ensure proper function. IA Pop-off to be set at 2,850 psi. 6. Bring IA pressure up to a hold pressure of 2,000 psi. 7. Set pump kickouts staggered between 4,300 – 4,500 psi 8. Pump the fracture stimulation per the proposed pump schedule below. Maximum allowable treating pressure is 4,500 psi. 9. RDMO frac equipment. 10. Flowback well (contingent coiled tubing cleanout if needed). FRAC – WG T-10 Coal Rev 1 Well: Whiskey Gulch 14 PTD: 221-102 API: 50-231-20093-00-00 Pressures MIT-IA 3,000 psi Maximum Anticipated Treating Pressure: 1,900 psi @ 20 BPM IA Pop-off Set Pressure (~95% of MIT-IA): 2,850 psi IA Minimum Hold Pressure (POP-off – 300 psi): 2,000 psi Maximum Allowable Treating Pressure (MATP): 4,500 psi Stagger Pump Kickouts Between 90 – 95% of MATP: 4,300 psi – 4,500 psi Treating Line Test Pressure (MATP + 1000 psi): 6,000 psi Post Frac Procedure: 1. RU well to flowback tank through sand separator to open top 500 BBL tank. 2. MIRU WL & PT Lubricator to 250/3000 psi 3. Open well to Flowback tank through choke and allow well to flow a. Expect well to flowback minimal fluid initially without artificial lift (expect less than 50 bbls) 4. Run GR log for Frac tracer evaluation 5. Once well does not flow on its own, use SL to swab fluid off well. a. Start swabbing in 50 ft increments b. Swab frac fluids off well and SI overnight to see if well flows on its own post frac c. It is not expected to flow on its own, when frac fluids have been recovered, using swabbing to determine the water influx rate post frac. d. Once inflow rate is determined, evaluate long term dewatering plan for well. Key Contacts: Company Contact Phone Comment Aurora Drilling Trevor Wilms 720-891-0045 Frac Consultant Hilcorp Testers Chad Ebenezer 907-301-0683 Field Foreman Hilcorp OE Chad Helgeson 907-229-4824 Hilcorp RE Sierra Becia 907-529-2160 Attachments – Current Wellbore Schematic Frac RU Diagram Frac Wellhead Diagram Stage Fluid Prop Con Rate Prop Vol Cum. Prop Clean Stg Clean Cum.Clean Stg Clean Cum. (lb/gal) (bpm) (lb) (lb) (gal) (gal) (bbl) (bbl) Pad (Get to Rate) Fresh Water 20 0 0 2,500 2,500 60 60 100 mesh Fresh Water 0.50 20 1,000 1,000 2,000 4,500 48 107 20/40 Fresh Water 1.00 20 2,000 3,000 2,000 6,500 48 155 20/40 Fresh Water 2.00 20 4,000 7,000 2,000 8,500 48 202 20/40 Fresh Water 3.00 20 3,000 10,000 1,000 9,500 24 226 Flush Fresh Water 20 0 10,000 1,400 10,900 33 260 _____________________________________________________________________________________ Updated By CAH 9-26-25 SCHEMATIC Anchor Point Unit Whiskey Gulch 14 PTD: 221-102 API: 50-231-20093-00-00 PBTD = 7,877’ MD / 7,127’ TVD TD = 8,013’ MD / 7,261’ TVD 9 12 2 3 4 1 T65L 8 11 T80 T110 10 T65U 7 6 5 T10 - Coal T14U T19 Coal T20 T30 T40 Coal T48L T55 Coal T14L RKB to GL = 18.3’ 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 1,979’ 4-1/2" Prod Lnr 12.6 L-80 DWC/C HT 3.958” 1,741’ 8,013’ TUBING DETAIL 4-1/2” Tubing 12.6 L-80 DWC/C HT 3.958” Surf 1,747’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 1,741’ 1,669’ 4.875” 6.540” Baker Flex-Lock V Liner Hanger HRD-E ZXP, w/ bullet seal assembly 2 2,975’ 2,750’ CIBP set 5/3/24 (25ft of cement placed 9/21/25) 3 3,402’ 3,122’ CIBP set 5/2/24 4 3,550’ 3,252’ CIBP set 4/22/24 5 4,280’ 3,893’ CIBP set 4/3/24 6 4,985’ 4,510’ CIBP set 4/1/24 with 28’ of cement TOC 4957 7 5,470’ 4,934’ CIBP set 3/17/24 8 5,565’ 5,017’ CIBP set 3/15/24 9 5,670’ 5,109’ - - CIBP 01/11/24 10 5,784’ 5,209’ - - CIBP 1/4/24 11 6,120’ 5,505’ - - CIBP 4/7/22 (25ft of cement set at 6030’ set (1/4/24) 12 6,700’ 6,016’ - - CIBP 4/6/22 GAS SAND PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Top of Tyonek Pool is 1770’ MD T10 Coal 2,279’ 2,289’ 2,139’ 2,148’ 10’ 05/9/24 Open T10 Coal 2,285’ 2,286’ 2,144’ 2,145’ 2’- 4 spf 05/3/24 Open T14AU 3,019’ 3,026’ 2,789’ 2,795’ 7’ 05/02/24 Isolated T14AL 3,048’ 3,053’ 2,814’ 2,818’ 5’ 05/02/24 Isolated T19 Coal 3,448’ 3,450’3,162’ 3,164’ 2’ - 4 spf 04/22/24 Isolated T20U 3,575’ 3,585’ 3,474’ 3,283’ 10’ 04/03/24 Isolated T30 4,305’ 4,319’ 3,914’ 3,927’ 14’ 04/02/24 Isolated T40 Coal 5,026’ 5,027’4,546’ 4,547’ 2’ - 4 spf 3/17/24 Isolated T48L 5,514.5’ 5,523.5’ 4,972’ 4,981’ 9’ 03/15/24 Isolated T55 Coal 5,573’ 5,574’5,024’ 5,025’ 2’ - 4 spf 03/7/24 Isolated T65U 5,747’ 5,761’ 5,177’ 5,189’ 14' 01/04/24 Isolated T65L 5,808' 5,845' 5,230' 5,262' 37' 04/07/22 Isolated T80 6,385’ 6,424' 5,738' 5,772' 39’ 04/07/22 Isolated T110U 6,807' 6,823' 6,111' 6,126' 16' 04/06/22 Isolated OPEN HOLE / CEMENT DETAIL 7-5/8" TOC @ Surface (100% excess) Returns to surface 4-1/2” TOC @ TOL (40% excess) Circulated cement off top of liner, CBL 3/31/22 ToC @ 1731’) FB4K Blender 5 0 0 b b l F r a c T a n k 5 0 0 b b l F r a c T a n k M o b i l e F r a c M a n i f o l d IA P R V Sk i d Ch e c k V a l v e 4" P r e s s u r e R e l i e f V a l v e Ti g e r T a n k Li n e t o I A 3" P R V L i n e 2" B l e e d L i n e Fr HT-2000 Pump Fr Fr Fr a c O p e r a t i o n s C a b Wh i s k e y G u l c h F r a c t u r i n g R i g U p We l l HT-2000 Pump HT-2000 Pump BL E E D O F F TA N K 2" hardline to Manifold 11"5000 11" IAsub 11" 5000# 2" hardline to PRV’s & Tiger Tank 3" Treating Lines Master Valve es Master Valve 3" Treating Line Swab Valve Upr Master Valve Whiskey Gulch Fracturing Wellhead WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 1 Date: September 26, 2025 Subject: Whiskey Gulch 14 Coal Fracture Stimulation From: Chad Helgeson O: (907) 777-8405 C: (907) 229 - 4824 To: AOGCC Estimated Start Date: 10/14/2025 Attached is Hilcorp’s proposal and supporting documents to perform a small slickwater fracture stimulation on well Whiskey Gulch 14 (PTD #221-102) in the Tyonek Coals of the Whiskey Gulch Unit. The objective of this program is to perform a single stage slickwater fracture stimulation to the existing Tyonek T10 coal perforations to improve well performance. The WG-14 was drilled targeting Tyonek sands in Whiskey Gulch Field. The T-10 coal was perforated in May of 2024 for a Diagnostic Fracture Injection Test (DFIT). The data was analyzed and determined the entire coal should be shot to see if the coal would flow on its own without stimulation. The entire coal was perforated on May 9, 2024. The coal was then tested to determine if any water or gas produced from the zone. The well slowly builds pressure from gas inflow up to 600 psi. A Variance is required for 20AAC25.283(C)(1) which requires the fracture string to be stung into a liner or a packer set 100ft below the cement top of the production casing. This fracture will use the tubing string for a frac string, which places the liner top packer and seals for the liner 232ft above the surface casing shoe instead of 100ft below the casing cement. There is cement from the Tyonek T10 Coal (Frac interval) into the liner lap between the 7-5/8” surface casing and the 4-1/2”. The liner top packer that was tested to 3000psi. Please direct questions or comments to Chad Helgeson. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 2 SECTION 1 - AFFIDAVIT (20 AAC 25.283, a, 1): Below is an affidavit stating that the owners, landowners, surface owners and operators identified on a plat within one-half mile radius of the current wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283, a 1 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 4 COPY OF NOTIFICATION SENT VIA MAIL: WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 5 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 6 SECTION 2 - PLAT IDENTIFYING ALL WELLS WITHIN ½ MILE (20 AAC 25.283, a, 2): Figure 1. Plat of wells within one-half mile of WG-14 wellbore trajectory. WG - 1 4 F r a c t u r e S t i m u l a t i o n R e v 1 PT D : 2 2 1 - 1 0 2 Pa g e 7 No t i c e o f O p e r a t i o n s w a s s e n t t o t h e f o l l o w i n g o w n e r s , l a n d o w n e r s , s u r f a c e o w n e r s a n d o p e r a t o r s w i t h i n a o n e - h a l f m i l e r a d i u s o f W h i s k e y 1 4 . U S P S Tr a c k i n g n u m b e r s c a n b e p r o v i d e d u p o n r e q u e s t . OW N E R N A M E AD D R E S S CI T Y ST A T E ZI P PA R C E L ID ST A T U S DA T E AL A S K A S T A T E D N R 5 5 0 W 7 T H A V E S T E 6 5 0 A N C H O R A G E A K 9 9 5 0 1 1 6 5 1 6 2 3 4 D e l i v e r e d 4 / 8 / 2 0 2 5 AL E X A N D E R D A R R I N P O B O X 1 1 4 7 A N C H O R PO I N T A K 9 9 5 5 6 1 6 5 1 6 5 1 8 D e l i v e r e d 4 / 1 1 / 2 0 2 5 BE A R L I N D S A Y C L O U D P O B O X 2 6 2 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 4 4 D e l i v e r e d 4 / 1 2 / 2 0 2 5 BE I L K E G A R Y & N E L L I E 1 2 8 3 0 C H A P E L C I R A N C H O R A G E A K 9 9 5 1 6 1 6 5 6 1 0 4 7 D e l i v e r e d 4 / 8 / 2 0 2 5 BE U T L E R K Y L E E D W A R D 2 1 1 0 W A Y N E S T L A N S I N G M I 4 8 9 1 0 1 6 5 6 1 0 7 0 D e l i v e r e d 4 / 1 7 / 2 0 2 5 BE V E G N I D I A M O N D 1 2 6 4 0 F O S T E R R D A N C H O R A G E A K 9 9 5 1 6 1 6 5 6 1 0 6 4 D e l i v e r e d 4 / 8 / 2 0 2 5 BE V E G N I D I A M O N D L E R O Y 1 2 6 4 0 F O S T E R R D A N C H O R A G E A K 9 9 5 1 6 1 6 5 6 1 0 6 5 D e l i v e r e d 4 / 8 / 2 0 2 5 BI B B Y C H R I S T I N P O B O X 4 9 7 A N CH O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 3 0 Re t u r n e d to S e n d e r 4/ 1 4 / 2 0 2 5 BI S H O P B R I A N T P O B O X 9 2 7 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 2 4 D e l i v e r e d 5 / 6 / 2 0 2 5 BL A U V E L T W A L T E R P O B O X 8 5 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 4 7 D e l i v e r e d 4 / 1 2 / 2 0 2 5 BL A U V E L T Z A C H A R Y P O B O X 7 7 0 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 2 2 D e l i v e r e d 4 / 9 / 2 0 2 5 BO L I N G E D W A R D M 9 2 7 F R E E M A N S T K E T C H I K A N A K 9 9 9 0 1 1 6 5 6 1 0 6 6 D e l i v e r e d 4 / 9 / 2 0 2 5 BR E W S T E R Q U A N A H R E N E P O B O X 2 1 1 2 6 5 A N C H O R A G E A K 9 9 5 2 1 1 6 5 6 1 0 7 4 Re t u r n e d to S e n d e r 4/ 2 6 / 2 0 2 5 BR O W N J E D I D I A H P O B O X 5 3 4 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 9 4 D e l i v e r e d 4 / 8 / 2 0 2 5 BR O W N N A T H A N A E L J P O B O X 1 0 6 1 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 9 0 D e l i v e r e d 4 / 2 1 / 2 0 2 5 CO L E D A N N Y D 5 5 4 9 7 F I N C H A V E H O M E R A K 9 9 6 0 3 1 6 5 6 1 0 6 8 D e l i v e r e d 4 / 1 0 / 2 0 2 5 CO L L I N S F L I N T P O B O X 1 3 0 3 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 1 2 D e l i v e r e d 4 / 9 / 2 0 2 5 CO L L I N S T R A C Y P O B O X 1 0 8 6 H O M E R A K 9 9 6 0 3 1 6 5 1 6 5 0 4 D e l i v e r e d 4 / 9 / 2 0 2 5 CO R T E Z K I R K P O B O X 7 0 3 A N C H O R P O IN T A K 9 9 5 5 6 1 6 5 7 0 0 2 7 D e l i v e r e d 4 / 8 / 2 0 2 5 CO U R T R I G H T C A M I L L E A P O B O X 3 1 2 4 H O M E R A K 9 9 6 0 3 1 6 5 6 1 0 6 9 D e l i v e r e d 4 / 9 / 2 0 2 5 CR A I G R O S E T T A J 3 2 7 5 D O R C H E S T E R R D S H A K ER H E I G H T S O H 4 4 1 2 0 1 6 5 0 8 3 2 2 D e l i v e r e d 4 / 7 / 2 0 2 5 CR O N I N K E V I N C 1 3 5 5 B A Y S T A P T 1 0 S A N F R A N C I S C O C A 9 4 1 2 3 1 6 5 7 0 0 3 2 D e l i v e r e d 4 / 1 4 / 2 0 2 5 DA N I E L B R U C E & C L A U D I N E 2 2 0 5 1 U S H I G H W A Y 6 2 S N Y D E R O K 7 3 5 6 6 1 6 5 1 6 5 1 4 D e l i v e r e d 4 / 9 / 2 0 2 5 WG - 1 4 F r a c t u r e S t i m u l a t i o n R e v 1 PT D : 2 2 1 - 1 0 2 Pa g e 8 OW N E R N A M E AD D R E S S CI T Y ST A T E ZI P PA R C E L ID ST A T U S DA T E Da r c y M c B r i d e 10 7 W E S T A V E N I D A GA V I O T A S A N C L E M E N T E C A 9 2 6 7 2 1 6 5 7 4 1 0 1 D e l i v e r e d 4 / 9 / 2 0 2 5 ER W I N S H A W N R 3 6 9 0 7 E V E N L N K E N A I A K 9 9 6 1 1 1 6 5 1 6 5 4 0 D e l i v e r e d 4 / 9 / 2 0 2 5 Es t a t e o f D o u g l a s R . D o n e r 21 0 B R E E A V E A N C H O R A G E A K 9 9 5 1 5 m u l t i p l e D e l i v e r e d 4 / 1 2 / 2 0 2 5 Es t a t e o f D o u g l a s R . D o n e r 59 1 5 P E T E R S B U R G S T A P T 20 9 A N C H O R A G E A K 9 9 5 0 7 D e l i v e r e d 4 / 8 / 2 0 2 5 FR E E M A N T A M M Y J 9 2 0 0 H O M E S T E A D T R L A N C H O R A G E A K 9 9 5 0 7 1 6 5 6 1 0 4 8 D e l i v e r e d 4 / 1 0 / 2 0 2 5 GA E D E C K E R O B E R T K P O B O X 8 3 3 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 3 9 D e l i v e r e d 4 / 1 6 / 2 0 2 5 HA R M O N D O N A L D P O B O X 1 3 3 7 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 1 0 D e l i v e r e d 4 / 1 8 / 2 0 2 5 Ha r r i e t C . R i c h , w i d o w 6 8 6 E L C A M I N O W A Y L Y N D E N W A 9 8 2 6 4 m u l t i p l e D e l i v e r e d 4 / 8 / 2 0 2 5 HA Y E S J E F F R Y N E A L 5 6 2 O C E A N P O I N T D R A N C H O R A G E A K 9 9 5 1 5 1 6 5 6 1 0 4 3 D e l i v e r e d 4 / 1 2 / 2 0 2 5 HI C K E L J A M E S A P O B O X 4 7 0 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 2 1 D e l i v e r e d 4 / 1 4 / 2 0 2 5 HO L M E S J O S H 2 6 8 2 0 A R D E N C T K E N T W A 9 8 0 3 2 1 6 5 7 0 0 3 0 D e l i v e r e d 4 / 9 / 2 0 2 5 HO O P E R B R Y C E A N T H O N Y P O B O X 1 2 9 1 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 3 6 D e l i v e r e d 4 / 1 0 / 2 0 2 5 JE R D E A M A N D A 2 4 8 W P I O N E E R A V E H O M E R A K 9 9 6 0 3 1 6 5 6 1 0 9 8 D e l i v e r e d 4 / 8 / 2 0 2 5 JO H N S O N A N N A M P O B O X 1 4 5 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 2 8 D e l i v e r e d 4 / 9 / 2 0 2 5 KA L U G I N P E T E P O B O X 8 3 5 K E N A I A K 9 9 6 1 1 1 6 5 6 1 0 8 9 Re t u r n e d to S e n d e r 4/ 2 4 / 2 0 2 5 KE R I N L E O J O H N 2 3 2 H E N D E R S O N R D S F A I R B A N K S A K 9 9 7 0 9 1 6 5 0 8 3 2 1 D e l i v e r e d 4 / 9 / 2 0 2 5 KI R C H N E R C O R B I N P O B O X 6 4 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 5 9 D e l i v e r e d 4 / 9 / 2 0 2 5 KU N S M A N T O D D L 1 0 6 5 4 C H A N D O N P L H I G H L A N D S R A N C H C O 8 0 1 2 6 1 6 5 1 6 5 3 5 D e l i v e r e d 4 / 9 / 2 0 2 5 LE I S E K D E B R A K & L O N G JA M E S L P O B O X 4 2 6 2 H O M E R A K 9 9 6 0 3 1 6 5 1 6 5 3 3 D e l i v e r e d 4 / 1 1 / 2 0 2 5 Ma r y E . C l a b o - f k a H o s t 1 0 1 0 H I G H G R O V E D R C H A P E L H I L L N C 2 7 5 1 6 m u l t i p l e D e l i v e r e d 4 / 8 / 2 0 2 5 MA T T R O S E M A R Y A 11 0 0 M E N D E N H A L L PE N I N S U L A R D J U N E A U A K 9 9 8 0 1 1 6 5 6 1 0 1 1 D e l i v e r e d 4 / 9 / 2 0 2 5 MC B R I D E D A R C Y 1 0 7 W A V E N I D A G A V I O T A S A N C L E M E N T E C A 9 2 6 7 2 1 6 5 7 4 1 1 6 D e l i v e r e d 4 / 9 / 2 0 2 5 MC D O N A L D L A U R A 4 3 9 2 2 N O R T H G A T E A V E T E M E C U L A C A 9 2 5 9 2 1 6 5 7 0 0 3 7 D e l i v e r e d 4 / 1 4 / 2 0 2 5 MO R G A N D O U G L A S E 1 6 3 3 9 H E A D L A N D S C I R A N C H O R A G E A K 9 9 5 1 6 1 6 5 6 1 0 3 6 D e l i v e r e d 4 / 8 / 2 0 2 5 WG - 1 4 F r a c t u r e S t i m u l a t i o n R e v 1 PT D : 2 2 1 - 1 0 2 Pa g e 9 OW N E R N A M E AD D R E S S CI T Y ST A T E ZI P PA R C E L ID ST A T U S DA T E Na n c y K . D o n e r 21 0 B R E E A V E A N C H O R A G E A K 9 9 5 1 5 D e l i v e r e d 4 / 1 2 / 2 0 2 5 Na n c y K . D o n e r 59 1 5 P E T E R S B U R G S T A P T 20 9 A N C H O R A G E A K 9 9 5 0 7 m u l t i p l e D e l i v e r e d 4 / 8 / 2 0 2 5 PE A R S O N J A M E S D 2 0 2 0 LI V I N G T R U S T 7 3 7 0 C H U R C H S T A P T C G I L R O Y C A 9 5 0 2 0 1 6 5 6 1 0 7 1 D e l i v e r e d 4 / 9 / 2 0 2 5 PE R K O V I C H J I M P O B O X 7 7 5 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 8 7 D e l i v e r e d 4 / 1 4 / 2 0 2 5 PH E T C H A R A T S O N N Y P O B O X 1 3 0 8 H O M E R A K 9 9 6 0 3 1 6 5 6 1 0 6 3 Re t u r n e d to S e n d e r 4/ 2 3 / 2 0 2 5 PI N K E R T O N D O N A L D R P O B O X 5 0 2 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 4 6 D e l i v e r e d 4 / 9 / 2 0 2 5 PO I N D E X T E R C A R R A R A P O B O X 8 5 0 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 3 1 D e l i v e r e d 4 / 1 4 / 2 0 2 5 PO I N D E X T E R L O G A N P O B O X 8 5 0 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 1 6 D e l i v e r e d 4 / 1 4 / 2 0 2 5 PO I N D E X T E R L O G A N M A R T I N P O B O X 8 5 0 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 3 2 D e l i v e r e d 4 / 1 4 / 2 0 2 5 PY A T T L A R R Y E J r P O B O X 1 3 8 1 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 4 4 Re t u r n e d to S e n d e r 4/ 2 3 / 2 0 2 5 RI C H A R D S O N N E I L P O B O X 1 6 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 4 5 D e l i v e r e d 4 / 8 / 2 0 2 5 RI C H T E R C L A U D I A P O B O X 1 6 9 6 B A R R O W A K 9 9 7 2 3 1 6 5 1 6 5 3 8 Re t u r n e d to S e n d e r 5/ 8 / 2 0 2 5 RI S I N G E R F R A N C I S 3 1 9 7 0 L A D U Q U E S A L N A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 7 0 0 2 9 D e l i v e r e d 4 / 1 8 / 2 0 2 5 RO B E R T J O D Y M I T C H E L L 8 8 7 4 T H A M E S R I V E R A V E F O U N T A I N V A L L E Y C A 9 2 7 0 8 1 6 5 6 1 0 4 2 D e l i v e r e d 4 / 8 / 2 0 2 5 SA R G E A N T J A M E S M P O B O X 5 7 7 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 3 8 D e l i v e r e d 4 / 8 / 2 0 2 5 SA R G E A N T N A T H A N E P O B O X 1 1 0 2 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 3 3 D e l i v e r e d 4 / 8 / 2 0 2 5 SA R G E A N T N A T H A N E D W A R D P O B O X 1 1 0 2 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 6 0 D e l i v e r e d 4 / 8 / 2 0 2 5 SC H L O E S S E R C R A I G P O B O X 3 5 6 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 0 8 3 1 7 D e l i v e r e d 4 / 9 / 2 0 2 5 SC H U L D E N J E F F R E Y M P O B O X 4 6 5 O R E G O N C I T Y O R 9 7 0 4 5 1 6 5 6 1 0 2 7 D e l i v e r e d 4 / 1 4 / 2 0 2 5 SE R E N E W A T E R S L I V I N G TR U S T P O B O X 3 7 6 H O M E R A K 9 9 6 0 3 1 6 5 7 0 0 2 8 D e l i v e r e d 4 / 8 / 2 0 2 5 ST O N E K E N N E T H H O W A R D P O B O X 4 3 4 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 4 3 D e l i v e r e d 4 / 1 1 / 2 0 2 5 ST O V E R M A R Y J O P O B O X 9 4 2 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 7 6 D e l i v e r e d 4 / 9 / 2 0 2 5 WG - 1 4 F r a c t u r e S t i m u l a t i o n R e v 1 PT D : 2 2 1 - 1 0 2 Pa g e 1 0 OW N E R N A M E AD D R E S S CI T Y ST A T E ZI P PA R C E L ID ST A T U S DA T E ST U T E S S T O R M Y C & A S S O C ' S 2 2 3 0 M O N A S H K A W A Y K O D I A K A K 9 9 6 1 5 1 6 5 0 8 4 0 1 D e l i v e r e d 4 / 1 4 / 2 0 2 5 SU T H E R L A N D R I C H A R D A & MA U R A L 65 3 W F A I R V I E W A V E A P T F H O M E R A K 9 9 6 0 3 1 6 5 6 1 0 3 7 Re t u r n e d to S e n d e r 4/ 2 3 / 2 0 2 5 SY N H O R S T N A N C Y P O B O X 4 7 3 H O M E R A K 9 9 6 0 3 1 6 5 1 6 5 2 5 Re t u r n e d to S e n d e r 4/ 2 5 / 2 0 2 5 TE I C H B A R R Y J 1 5 0 2 0 O L D S E W A R D H W Y A N C H O R A G E A K 9 9 5 1 6 1 6 5 6 1 0 9 6 D e l i v e r e d 4 / 8 / 2 0 2 5 TO W N S E N D A L L A N & C H E R Y L 3 1 7 9 5 W H I S K E Y G U L C H S T A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 1 5 D e l i v e r e d 4 / 9 / 2 0 2 5 TR A C Y D I A N E M P O B O X 1 4 4 3 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 4 1 D e l i v e r e d 4 / 1 5 / 2 0 2 5 UM B A R G E R R O N A L D F 2 2 2 0 0 S E R O Y A L A N N E D R A M I T Y O R 9 7 1 0 1 1 6 5 7 0 0 3 6 D e l i v e r e d 4 / 8 / 2 0 2 5 UM B A R G E R R O N A L D F J r 2 2 2 0 0 S E R O Y A L A N N E D R A M I T Y O R 9 7 1 0 1 1 6 5 7 0 0 3 4 D e l i v e r e d 4 / 8 / 2 0 2 5 UN I V E R S I T Y O F A L A S K A 1 8 1 5 B R A G A W S T S T E 1 0 1 A N C H O R A G E A K 9 9 5 0 8 1 6 5 1 6 2 3 3 D e l i v e r e d 4 / 2 2 / 2 0 2 5 WH I T E K A T H E R I N E P O B O X 2 5 5 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 2 6 D e l i v e r e d 4 / 1 0 / 2 0 2 5 WO R M M I C H E L E M 6 3 0 8 B L U E B E R R Y L N N W A L B U Q U E R Q U E N M 8 7 1 2 0 1 6 5 6 1 0 4 9 Re t u r n e d to S e n d e r 4/ 2 7 / 2 0 2 5 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 11 TABLE 1: LIST OF WELLS IN PLAT WITHIN ½ MILES ON SURFACE (20 AAC 25.283, a, 2, C): TABLE 2: LIST OF WATER WELLS(data from WELTS) IN PLAT WITHIN ½ MILES ON SURFACE (20 AAC 25.283, a, 3): WELTS LogId * Subdivision Date Complete OwnerLastName Region Well Depth Static Water Depth Parcel ID# 1548 SPRUCE LAKE ESTATES 5/5/1985 WHITE KPB 53 15 16561026 18752 OLD PIONEER 6 Lot 9A 1/1/1981 STOVER KPB 100 <Null> 16561076 19107 OLD PIONEER 5 Lot 15A 11/1/1985 PERKOVICH KPB 42 <Null> 16561087 19108 OLD PIONEER 5 Lot 16 4/13/1985 PYATT KPB 41 5 16561046 <Null> OLD PIONEER 7 <Null>HOWARD KPB <Null> <Null> 16561069 <Null> OLD PIONEER 13 <Null>HAYES KPB <Null> <Null> 16561043 <Null> ROBERT ESTATES LOT 15 BLK 2 Mar-19 UMBARGER KPB 113 65 16570036 <Null> PACIFIC PARK LOT 10 BLK1 2006 HARMON KPB 80 <Null> 16516510 <Null> PACIFIC PARK LOT 2 BLK3 1993 ALEXANDER KPB 45 <Null> 16516517 Yellow highlighted are residents contacted and requested sampling within ½ mile Well Name Class Well Status PTD# API # Whiskey Gulch 1 Prod SI 221-046 50-231-20079-00-00 Whiskey Gulch 4 Strat Test P&A 220-038 50-231-20071-00-00 Whiskey Gulch 14 Prod SI 221-102 50-231-20093-00-00 Whiskey Gulch 15 Prod SI 223-116 50-231-20106-00-00 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 12 SECTION 3 - EXEMPTION FOR FRESHWATER AQUIFERS (20 AAC 25.283, a, 3): All known freshwater wells within ½ mile radius of WG-14 have been shown in Figure 1. Water well data was collected from WELTS and notifications to all landowners in the area. Table 2 shows the water well names and total depth. The deepest water well within a ½ mile area is 113’. The conductor for the well was set at 120ft. A 1977 DGGS study done by D.L. McGee, shows base of saline/freshwater to between 100’- 200’ at the Whiskey Gulch location (Figure2). McGee defines freshwater as, “water that is usable for community needs”. AOGCC defines freshwater as having a TDS concentration <10,000 mg/L. Adhering to AOGCC definition and McGee’s salinity values in grains/gallon, this depth to freshwater is -5,000’ to -7,000’ SSTVD in the Southern Kenai Peninsula. From numerous wells drilled throughout this area of the Kenai Peninsula, we map the base of water for consumption at 191’ at the Whiskey Gulch Pad. This falls within the expected range of the McGee depth to saline/freshwater map (Figure 2). Higher resistivity values indicate much fresher water above this depth. As you increase in depth, there is a pronounced shift to lower resistivities which is caused by higher salinity values. This coincides with the transition to the Sterling formation. From abundant oil, gas, stratigraphic, and water wells, we know that there is not one mappable freshwater aquifer in this area, but numerous small channel sands. In this fluvial depositional environment, highly stratigraphic sands contain consumable water for private or community use ranging from 17’ to 147’ near Whiskey Gulch Pad. Whiskey Gulch 14 shift in resistivity is interpreted at 191’ MD; +30’ SSTVD. See Figure 3 for WG-14 triple combo log. These fluvial channel facies are in the Sterling Formation. Sterling reservoirs are primarily sandstone, silty sandstone or conglomerate. Figure 4 shows a structural cross section of all 3 whiskey Gulch wells and the interpreted shift in deep resistivity for more context. Above this coal lies more than 2000’ MD of interbedded silt, sand, shale, and coal that make up the Tyonek, Beluga and lower Sterling Formations. From the T10 coal to the base of consumable water pick is 2088’ MD; 1948’ TVD of this section. Multiple confining layers exist within this large vertical section. Numerous extensive coals and large non reservoir claystones/siltstones are interbedded throughout this 2,000’+ gross section. This well is completed with a cemented surface casing to 1979’MD; -1758’ SSTVD with cement to surface. The Tyonek T10 coal is at a depth of 2279’ MD; -2058’ SSTVD. This is 300’MD/SSTVD below surface casing shoe. The cemented surface casing prevents gas from polluting consumable freshwater supplies from tracking along the well path. The frac model shows that the frac height will be less than 10ft and will stay in the coal. Hilcorp will be pumping a radioactive tracer that a gamma ray logging tool will be run post frac to determine how high the frac grew and determine near wellbore if it tracked vertically along the cemented wellbore. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 13 Figure 2: Regional map showing water well locations (blue), strat test locations (green drilled, red planned). Whiskey Gulch area in Red box. Regional depth to brackish water (black lines). Cook Inlet Water Salinities contoured thickness from ground surface to base of salt water / freshwater gradient – after USGS, D.L. McGee 1977 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 14 Figure 3. Whiskey Gulch-14 triple combo log with total gas curve. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 15 Figure 4. Structural Cross Section of the 3 whiskey Gulch wells for more context. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 16 SECTION 4 - PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS (20 AAC 25.283, a, 4): The water well sampling plan is included in Appendix A, which the 1st sampling event occurred the week of September 22nd, 2025.. This frac is considered a small frac or tickle frac ( ~10,000lbs of sand and 350 bbls of fluid) and will not be pumping any typical chemicals used to suspend sand in the fluid during a conventional frac. This is a slickwater frac, what only includes, water, Potassium Chloride (aka water softener), a biocide (stops growth of any microorganisms), proppant (sand) and a small amount (1/2 gallon) of sand that has a decaying radioactive material (included for post frac diagnostic work). This frac will not pump any chemicals that will be testable in the water wells post frac. Hilcorp is pumping a radioactive tracer (ZeroWash®) that will used to determine the fracture height of the job. After the pumping is complete, Hilcorp will use wireline to run a gamma ray tool to determine if the fracture propagated outside the designed fracture growth of the T-10 coal. If the fracture did not go close to the casing shoe (300ft MD away), there is no evidence the frac can affect the consumable fresh water and therefore additional testing of water wells is unnecessary. If the radioactive tracer indicates the fracture propagated above the surface casing shoe. Hilcorp will submit a post frac water well sampling program that will include sampling in the summer 2 years post frac. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 17 SECTION 5 - DETAILED CEMENTING AND CASING INFORMATION (20 AAC 25.283, a, 5): All casing is cemented and tested in accordance with 20 AAC 25.030, g when it was completed. A Variance is required for 20AAC25.283(C)(1) which requires the fracture string to be stung into a liner or a packer set 100ft below the cement top of the production casing. This fracture will use the tubing string for a frac string, which places the liner top packer and seals for the liner 232ft above the surface casing shoe instead of 100ft below the casing cement. There is cement from the Tyonek T10 Coal (Frac interval) into the liner lap between the 7-5/8” surface casing and the 4-1/2”. The liner top packer that was tested to 3000psi. A tubing movement model was run based on worst case scenario of a screen out during the frac and pressure increasing to 5000psi and pumping 50deg fluid. The model indicated that the tubing would shrink 1.3 ft. There is a 10ft seal assembly with approximately 9ft of movement available in the completion. See wellbore schematic for casing details: WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 18 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 19 SECTION 6 - ASSESSMENT OF EACH CASING AND CEMENTING OPERATION (20 AAC 25.283, a, 6): Summary: 7-5/8" Surface Casing Summary: TOC @ Surface (100% excess) Returns to surface Details: Pumped 40 BBLs of 11.5 ppg Spacer at 4.5 BPM with 115 psi., Dropped bottom plug and pumped 145 BBLs (345 sx) 12.0 ppg lead cement at 4.5 BPM with 150 psi., Followed by 42 BBLs (210 sx) 15.8 ppg tail cement at 4 BPM with 240 psi. Pumped displacement at 4.85 bpm. Slowed pump down to 3 BPM with 385 psi with 27 BBLs to go then slowed pumps down to 2 BPM with FCP at 600 psi with 7 BBLs to go and bumped plug with total of 87.5 BBLs pumped into displacement (calculated 87.4 BBLs) and brought pressure up to 1500 psi and held for 3 minutes. Bled off and floats held, bled back excess mud. Had 40 BBLs of Spacer returns to surface and 94 BBLs Lead cement to surface. Mix water Temperature at 74 degrees. 4-1/2” Production Liner Summary: TOC @ TOL. Circulated cement off top of liner, CBL 3/31/22 TOC @ 1731’) Details: Pumped 28 bbls 10.5 ppg Tuned Prime Spacer at 4 bpm-365 psi, followed with 210 bbl bbls (475 sx) 12 ppg VeriCem Lead cement at 4.5 to 5 bpm-115 to 202 psi, followed with 19 bbls (95 sx) 15.3 ppg SwiftCem Tail cement at 3 bpm-200psi. Had 2 pps of Bridge Maker LCM in lead, none in tail. Baker released dart, Halliburton then displaced with 10 bbls water followed with 9.4 ppg 6% KCL mud at 5 bpm-117 psi ICP. Saw dart latch wiper plug 23 bbls into displacement. With 20 bbls to go, reduced rate to 2 bpm-1130 psi, set on depth and stopped rotating string. Bumped wiper plug/landing collar 117 bbls into displacement (calculated at 119 bbls). FCP 1170 psi. CIP at 12:23 on 3-14-22. No losses during cement job. Rotated string right up to reducing pump rate to bump plug. Halliburton increased to and held 2750 psi (1580 psi over FCP) for 1 minute. Slacked off on blocks from 100K to 40K, giving us a good indication hanger was set. Pressured up to 3500 to set packer with push tool, up to 4000 psi to release run tool collet and neutralize pusher tool, held 2 minutes and bled off. PU 6’ to clear dogs from hanger top, up wt 50K and had good indication we released liner string. S/O and set down on liner top, PU 8’, rotated at 15 rpm, 2516 ft/lbs torque, S/O and set down on liner top to 20K to ensure weight transfer to set packer, no indication of shear w/30K. Applied 900 psi and start PU on drill string until pressure dropped. CBU at 291 gpm-370 psi. Had 28 bbls spacer and 27 bbls cement to surface. Shut down pump, broke off topdrive, Tested 4.5" tubing (MIT/T) T/3000 psi on chart for 30 min (ok). Pumped in 1.25 bbls and bled back 1.25 bbls. R/U testing equip on annulus. Tested 6.875” x 4.5” annulus (MIT/IA test) T/3000 psi for 30 min (ok). The CBL shows great cement bond from perfs to the casing shoe at 1,979’ and into the liner lap between the 4-1/2” liner and 7-5/8” casing up to the liner top packer. Below is a section of the CBL from below the proposed frac to liner lap. Based on the data above, Hilcorp is confident that the depth of stimulation is completely isolated from the surface casing. Additionally, the surface casing is cemented properly and isolated. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 20 4-1/2” Cement bond Log WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 21 Frac interval WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 22 SECTION 7 - PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASINGS AND TUBING INSTALLED IN THE WELL (20 AAC 25.283, a, 7): On 3/16/22, the 4-1/2" tubing/liner was pressure tested to 3,000 psi for 30 min with a passing MIT-T, and the 7-5/8” x 4-1/2” annulus was pressure tested to 3,000 psi for 30 min with a passing MIT-IA. Test Chart from MIT-T & MIT-IA The history of the well since drilling in 2022 had multiple interventions in 2024 deeper in the well, All reported in 10-404 report pressure testing the well to over 4500 psi with gas and fluids while monitoring the annulus pressure and there was no evidence of leaks. The well has no history of any leaks or production from the tubing. These tests are all recent and should appease regulation 20AAC25.283(c)(2) for testing the tubing prior to fracking the well. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 23 Anticipated Pressures: Maximum Anticipated Treating Pressure: 1,900 psi @ 20 BPM IA Pop-off Set Pressure (95% of MIT-IA): 2,850 psi IA Minimum Hold Pressure: 2,000 psi Maximum Allowable Treating Pressure (MATP) 4,500 psi Stagger Pump Kickouts Between 90 – 95% of MATP: 4,300 – 4,500 psi Tubing Pop-off Set Pressure (MATP): 4,500 psi Treating Line Test Pressure (MATP + 1000 psi): 6,000 psi The production casing will be pressured up to 2,000psi and will be monitored during the frac, if any change of pressure is seen outside of thermal expansion, the job will be flushed and the pressure source diagnosed before frac operations continue. There will be a pop-off valve on the annulus set to 2,850 psi. With 2,000psi on the annulus and the tubing recently (1/6/24) tested to 4500 psi, this meets the requirement for 110% of the max anticipated treating pressure differential. Hydraulic Stimulation Pressure Testing Plan Fracture design was completed using DFIT data completed in 2024. The testing indicated variable storage in the cleat/fracture network of the coal. An estimated perm in the coal was calculated at 16.9 md. The closure stress calculated at 0.87 psi/ft. This information was used in the frac model. Please see procedure in section 12 of this document. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 24 SECTION 8 - PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD (20 AAC 25.283, a, 8): Wellbore Tubular Ratings Size/Name Weight Grade Burst, psi Collapse, psi 7-5/8” Surface Casing 29.7# L-80 6,890 4,790 4-1/2” Liner 12.6# L-80 8,430 7,500 4-1/2” Production Tubing 12.6# L-80 8,430 7,500 Wellhead Cactus C-29L manufactured wellhead, rated to 5,000 psi. Tubing head adaptor: 11" 5,000 psi x 4-1/16" 5,000 psi Tubing Head: 16-3/4” 5,000psi w/ 2-1/16” side outlets Casing Spool: 16-3/4” 5,000psi w/ 2-1/16” side outlets Tree: WKM 4-1/16” 5,000psi (tested 3/7/24) A tree saver will not be used on this project due to the small volume of sand to be pumped and expected low pressures. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 25 Whiskey Gulch #14 Tree Schematic Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Upper master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, EE trim Valve, Wing, WKM-M, 3 1/8 5M FE, HWO, EE trim BHTA, Otis, 4 1/16 5M FE x 6.5 Otis quick union top 16'’ 7 5/8'’ 4 ½’’ Starting head, Cactus C-29L, 16 3/4 3M x 16 SOW, w/ 2- 2 1/16 5M SSO Tubing head, Cactus C-29L- HPS, 16 3/4 3M x 11 5M, w/ 2- 2 1/16 5M SSO Whiskey Gulch WG #14 16 x 7 5/8 x 4 ½ Tubing hanger, Cactus-EN- CCL, 4 ½ EUE 8rd lift and susp x w 6 ¼ od ext neck, 4'’ type H BPV profile, DD-NL material Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ Hydraulic operator Adapter, Cactus-EN-6.25'’, 11 5M stdd x 4 1/16 5M stdd top, w/ 2- 1'’npt control line exits WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 26 SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES (20 AAC 25.283, a, 9): TOP NAME LITHOLOGY MD TOP SSTVD TOP Est. Pressure Gradient Base "Consumable Water" Gravels 191 30 82 0.43 Sterling C1 Sand/Silt/Gravel 277 (56)119 0.43 Beluga Sand/Silt/Gravel 463 (242)199 0.43 Beluga 112 Sand/Silt/Gravel 1,240 (1,019)533 0.43 Tyonek Sand/Silt/Coal 1,774 (1,553)763 0.43 Surface Casing 1,979 (1,758)851 0.43 Tyonek T9 Coal Coal 2,061 (2,061)886 0.43 Tyonek T10 Coal 2,279 (2,058)980 0.43 *Depths from WG-14. Subsection A: The Tyonek T10 Coal is described as black, subbituminous coal from the mud log. Since coal was not an objective in this well at the time of drilling, detailed descriptions on the coals themselves are not available for this well. A shallower coal in the upper Tyonek from 1840’MD is described as brownish black to black, brittle with sub planar fractures, sub-resinous luster, matte to slight gritty texture with very faint outgassing. Above this coal lies more than 2000’ MD of interbedded silt, sand, shale, and coal that make up the Tyonek, Beluga and lower Sterling Formations. From the T10 coal to the base of consumable water pick is 2088’ MD; 1948’ TVD of this section. Multiple confining layers exist within this large vertical section. Numerous extensive coals and large non reservoir claystones/siltstones are interbedded throughout this 2,000’+ gross section. Below is a description of the 3 primary formations and a log of this interval is seen on Appendix B. The Tyonek consists of abundant coal, siltstone, and sand. The coals are high quality sub-bituminous to bituminous and usually regionally continuous. From WG-14 mudlog description the Tyonek sand is tuffaceous, lt. grey, clear to cloudy, milky quartz abundant feldspar with dark grey lithics; scattered fine bronze mica sheets; f to vf gr lower med to med sorted, sub-ang-ang with occ sub-round with abundant interbeds of tuffaceous claystone light grey to med grey, mushy to soft, malleable, easily hydrated, earthy, with vf sand/silt interbedded. The Beluga consists of similar strata but is commonly darker and contains more clay. The Tyonek/Beluga contact can be hard to consistently pick on logs and is usually picked by the first thick coal in the Tyonek. Lithic components are dominated by more metamorphic fragments and quartz. Beluga coals are lignite to sub-bituminous. The Sterling formation is the youngest non-glacial formation in the basin. The Sterling consists of grey to medium grey, friable fine to coarse grained cross-bedded volcaniclastic sandstones, deposited in large, stacked channels with siltstone and thin lignite coals throughout. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 27 Subsection B: This coal is named the T10 coal. It is upper Tyonek in age. Subsection C: The measure depth of this sand is 2279’ MD with a true depth of -1918’ TVDSS. Subsection D: The measured thickness of this sand is 9’ MD with a true vertical thickness of 7’. Subsection E: The estimated fracture pressure is calculated to be ~2130’ psi at the reservoir. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 28 SECTION 10 – LOCATION, ORIENTATION, AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE (20 AAC 25.283, a, 10): WG - 1 4 F r a c t u r e S t i m u l a t i o n R e v 1 PT D : 2 2 1 - 1 0 2 Pa g e 2 9 Ca s i n g a n d C e m e n t a s s e s s m e n t s f o r a l l w e l l s t h a t t r a n s e c t t h e c o n f i n i n g z o n e ( A O R ) : Na m e P T D # A P I # D i s t a n c e / S t a t u s T O C ( M D ) T O C ( T V D s s ) Z o n a l I s o l a t i o n C o m m e n t s WG - 0 1 2 2 1 - 0 4 6 5 0 - 2 3 1 - 2 0 0 7 9 - 0 0 - 0 0 12 3 ’ a w a y @ T O C Sh u t - i n 1, 4 3 0 ’ 1 , 1 9 3 ’ Ye s , c a s e d a n d ce m e n t e d Di r e c t i o n a l l y d r i l l e d 9 - 7/ 8 ” h o l e c a s e d w i t h 7 - 5/ 8 ” 2 9 . 7 # L - 8 0 c a s i n g s e t at 7 , 7 0 2 ’ . C e m e n t e d w i t h 33 3 b b l 1 2 . 0 p p g T y p e I - I I le a d c e m e n t f o l l o w e d b y 30 b b l 1 5 . 8 p p g T y p e I - I I ta i l c e m e n t . N o l o s s e s . 10 b b l s p a c e r b a c k t o su r f a c e ( 4 0 b b l s p a c e r pu m p e d ) . C B L o n 8/ 2 9 / 2 1 s h o w s T O C @ ~1 , 4 3 0 ’ WG - 1 5 2 2 3 - 1 1 6 5 0 - 2 3 1 - 2 0 1 0 6 - 0 0 - 0 0 68 ’ a w a y @ T O C Sh u t - i n 71 8 ’ 4 9 7 ’ Ye s , c a s e d a n d ce m e n t e d Di r e c t i o n a l l y d r i l l e d 9 - 7/ 8 ” h o l e c a s e d w i t h 7 - 5/ 8 ” 2 9 . 7 # L - 8 0 c a s i n g s e t at 6 , 3 9 0 ’ . C e m e n t e d w i t h 30 2 b b l o f 1 2 p p g T y p e I an d 3 1 b b l o f 1 5 . 3 # T y p e I ta i l . 4 0 b b l o f l e a d re t u r n e d t o s u r f a c e . T O C @ 7 1 8 ’ f r o m C B L o n 2/ 1 1 / 2 4 T1 0 C o a l p e r f o r a t e d f r o m 2, 7 3 0 ’ - 2 , 7 4 0 ’ . P l u g g e d ba c k w i t h C I B P a t 2 , 7 0 5 ’ an d 2 5 ’ c e m e n t . WG - 1 4 F r a c t u r e S t i m u l a t i o n R e v 1 PT D : 2 2 1 - 1 0 2 Pa g e 3 0 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 31 SECTION 11 - LOCATION OF, ORIENTATION OF, AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFING ZONES (20 AAC 25.283, a, 11): There are no known faults that exist in the area or depth of the T-10 Coal at Whiskey Gulch. The nearest known fault is 14,800’ to the south near the Seaview Unit. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 32 SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM (20 AAC 25.283, a, 12): Proposed Procedure: 1. Conduct safety meeting and review sundry. 2. MIRU frac equipment and associated frac tanks. 3. Pressure test surface lines to at least 6,000 psi. 4. Test Tubing Pop-off system to ensure proper function. Tubing Pop-off to be set at 4,500 psi. 5. Test IA Pop-off system to ensure proper function. IA Pop-off to be set at 2,850 psi. 6. Bring IA pressure up to a hold pressure of 2,000 psi. 7. Set Pump Kickouts staggered between 4,300 – 4,500 psi 8. Pump the fracture stimulation per the proposed pump schedule below. Maximum allowable treating pressure is 4,500 psi. 9. RDMO frac equipment. 10. Flowback well (contingent coiled tubing cleanout if needed). Frac Dimensions/info: Frac # MD Location, ft TVD top, ft TVD Bottom, ft 1 2,279’ – 2,289’ 2,139’ 2,148’ Stage Fluid Prop Con Rate Prop Vol Cum. Prop Clean Stg Clean Cum.Clean Stg Clean Cum. (lb/gal) (bpm) (lb) (lb) (gal) (gal) (bbl) (bbl) Pad (Get to Rate) Fresh Water 20 0 0 2,500 2,500 60 60 100 mesh Fresh Water 0.50 20 1,000 1,000 2,000 4,500 48 107 20/40 Fresh Water 1.00 20 2,000 3,000 2,000 6,500 48 155 20/40 Fresh Water 2.00 20 4,000 7,000 2,000 8,500 48 202 20/40 Fresh Water 3.00 20 3,000 10,000 1,000 9,500 24 226 Flush Fresh Water 20 0 10,000 1,400 10,900 33 260 WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 33 Frac Modelling: Maximum Anticipated Treating Pressure: ~1,900 psi Surface pressure and fracture dimensions were modeled using WG-14 logs Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Hilcorp is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. Pre-Job Anticipated Chemicals to be pumped: Product Volume CAS # Supplier Water 350 bbls 7732-18-5 Local water well Potassium Chloride (KCl) 7200lbs 7447-40-7 Mosaic Formula 3004/Biocide Tetrakis(hydroxymethyl) phosphonium sulfate 30 gal 55566-30-8 Garratt Callahan ZeroWash® Tracer 1/2 gal Multiple w/ proprietary proppant ProTechnics Frac sand 100 mesh 1000lbs NA COVIA Ceramic Proppant 20/40 Mesh 9000lbs NA WANLI Group Pressure Safety Systems: There are two overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Global Kickout - Primary control for maximum pressure on a job. Set by the pumping operator in accordance to the procedures as the Maximum allowable pressure. If any pressures exceed the Global Kickout, all pumps will go neutral. 2) Local Kickout - Secondary control on the pumping units. Set on each pump individually, if exceeded that pump goes neutral. Local Kickouts are staggered below maximum treating pressure as determined by the operating parameters. There is a DPM System – which is a standalone device that is an electrically controlled quick to neutral. If engaged pumps will not be able to resume pumping until completely restarted. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored with remote pressure transducers. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 34 SECTION 13 - POST FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN (20 AAC 25.283, a, 13): Post fracture stimulation flow back well to a tank(s) to bleed down pressure and clean up the well. After the well flows back on its own, a wireline unit will be placed on the well to run a post well gamma ray survey and swab frac fluids back to a tank. If the well starts to flow gas, surface production equipment will be installed and the well will flow to sales compressor. If the well will not sustain flow at the compressor suction compressor an additional sundry will be submitted for long term (more than 2 weeks) to unload water from wellbore with equipment to unload the well (possibly a rod pump and an individual well head compressor) for long term testing and dewatering of the coal. All liquids will be captured and either sent to production facilities or diverted to flowback tanks if solids percentage becomes too high for our production facility to manage. Note: All flowback fluids will be taken to Hilcorp’s Susan Dionne disposal facility and injected into SD-08 disposal well (DIO# 47) or if solids are returned, they will be taken to the Kenai Gas Field Class I disposal facility. WG-14 Fracture Stimulation Rev 1 PTD: 221-102 Page 35 APPENDIX A WATER SAMPLING PLAN BASELINE WATER SAMPLING AND ANALYSIS PLAN ANCHOR POINT,ALASKA JUNE 11, 2025 Prepared for: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Prepared by: Accounting Office Managing Office 2400 College Road 3105 Lakeshore Dr, Ste A106 5438 Shaune Dr, Ste B Fairbanks, Alaska 99709 Anchorage, Alaska 99517 Juneau, Alaska 99801 p. 907.452.5688 p. 907.222.2445 p: 907.586.6813 f. 907.452.5694 f. 907.222.0915 f: 907.586.6819 www.nortechengr.com SUSTAINABLE ENVIRONMENT, ENERGY, HEALTH & SAFETY PROFESSIONAL SERVICES Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY .................................................................................................. 1 2.0 INTRODUCTION ............................................................................................................... 2 2.1 Background and Objectives................................................................................... 2 2.2 Scope of Work ....................................................................................................... 2 2.3 Site Descriptions ................................................................................................... 2 2.3.1 Site Climate ............................................................................................... 3 2.3.2 Site Geology .............................................................................................. 3 2.3.3 Site Groundwater and Surface Water ........................................................ 3 2.4 Site History ............................................................................................................ 3 3.0 METHODOLOGY .............................................................................................................. 4 3.1 Site Investigation and Property Information........................................................... 4 3.2 Baseline Parameters and Compounds of Concern ............................................... 4 3.3 Well Sampling ....................................................................................................... 5 3.4 Laboratory Sample Collection ............................................................................... 5 3.5 Quality Control ....................................................................................................... 5 3.6 Field Documentation ............................................................................................. 6 3.7 Sample Handling and Custody .............................................................................. 7 3.8 Investigation Derived Waste Management ............................................................ 7 4.0 REPORTING ..................................................................................................................... 8 4.1 Interim Reporting ................................................................................................... 8 4.2 Final Reporting ...................................................................................................... 8 5.0 LIMITATIONS ................................................................................................................... 9 6.0 SIGNATURES OF ENVIRONMENTAL PROFESSIONALS ............................................. 9 Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page iiHttps://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx LIST OF APPENDICES Appendix 1: Figures Figure 1: Project Site Location Map Figure 2: Site Location Map with Sampling Radius Appendix 2: Site Specific Information SUSTAINABLE ENVIRONMENT, ENERGY, HEALTH & SAFETY PROFESSIONAL SERVICES Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx ACRONYMS AND ABBREVIATIONS °C degrees Celsius ºF degrees Fahrenheit AAC Alaska Administrative Code ADEC Alaska Department of Environmental Conservation AOGCC Alaska Oil and Gas Conservation Commission BTEX benzene, toluene, ethylbenzene and xylenes DRO diesel range organics FSG ADEC Field Sampling Guidance August 2024 GRO gasoline range organics Hilcorp Hilcorp Alaska, LLC IDW investigation derived waste LCS laboratory control spike LDRC Laboratory Data Review Checklist mg/L milligram per liter PAH polycyclic aromatic hydrocarbon PPE personal protective equipment QA quality assurance QC quality control QEP qualified environmental professional SGS SGS North America, Inc. SOP standard operating procedure SUSTAINABLE ENVIRONMENT, ENERGY, HEALTH & SAFETY PROFESSIONAL SERVICES Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx 1.0 EXECUTIVE SUMMARY Hilcorp Alaska, LLC (Hilcorp) contracted NORTECH, Inc. (NORTECH) to prepare this Baseline Water Well Sampling and Analysis Plan in support of Hilcorp’s application to begin hydraulic fracturing on the Kenai Peninsula. The proposed site is northeast of Anchor Point, approximately 14 miles northwest of Homer, Alaska. Per Chapter 20 of the Alaska Administrative code, Section 25.283(a) (20 AAC 25.283(a)), baseline water sampling plan to conduct testing of water wells within a one-half mile radius of the proposed site is required as part of the application. Hilcorp has notified property owner(s) within one-half mile of the projected wellbore (Figures 1 and 2) of the potential hydraulic fracturing project. The notification includes a Water Sampling Participation and Consent Form which allows landowner(s) with a water well to participate in the well sampling program. Site specific information pertaining to the water wells which the property owner(s) agrees to have sampled will be appended to this workplan. Field work is planned for Summer 2025, and upon approval of the workplan NORTECH will contact each property owner who agreed to have their drinking water well sampled to coordinate the onsite inspection and sampling. NORTECH will gauge, purge, and collect samples from each drinking water well according to the Alaska Department of Environmental Conservation (ADEC) Field Sampling Guidance dated August 2024 (FSG). Water samples will be analyzed for the compounds listed in 20 AAC 25.283(a)(4) as well as eight additional compounds requested by Hilcorp including antimony, beryllium, copper, lead, mercury, silver, zinc, and cyanide. Odor, color, sedimentation, bubbles, and effervescence will also be documented. Information about the well, such as well condition, well logs, pump and maintenance information, and applicable treatment data, will be recorded. A comprehensive report will be provided following receipt of laboratory data and will include field investigation information, sample locations, and laboratory data. The report, which will include each test result, analytical result, and sample location, will be shared with the Alaska Oil and Gas Conservation Commission (AOGCC) and ADEC within 90 days of sampling to satisfy 20 AAC 25.283(a)(4)(I). Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 2Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx 2.0 INTRODUCTION 2.1 Background and Objectives Hilcorp is developing an application to begin hydraulic fracturing on the Kenai Peninsula near Anchor Point, Alaska on the Whiskey Gulch Pad (Figure 2) As part of the application process, 20 AAC 25.283 requires development of a workplan to complete baseline water sampling of water wells in the proposed project area. The purpose of water well sampling is to provide a critical baseline for water quality before hydraulic fracturing. The sampled wells will be within one-half mile of the proposed hydraulic fracturing location to satisfy 20 AAC 25.283(a)(4). The objectives of this effort are to: 1. Deliver a water well Sampling Plan as per 20 AAC 25.253(a)(4). 2. Collect water well data and information as per 20 AAC 25.253(a)(4). 3. Submit a Final Baseline Study Report within 90 days after sample collection to include a summary of the observed results with all collected water well analytical data and property information. 2.2 Scope of Work Hilcorp requested the development of a water well sampling plan and collection of water well data, per 20 AAC 25.283(a)(4). Hilcorp has been working to contact well property owners within a one-half mile radius of the proposed hydraulic fracturing site to request permission to conduct water sampling. Hilcorp will provide NORTECH with the location and contact information of the property owners who agreed to the water sampling. Once identified, NORTECH will coordinate with the property owners to initiate the sampling plan. NORTECH will complete onsite inspection and sampling of each well and will provide a report per 20 AAC 283(a)(4)(I). 2.3 Site Descriptions Confirmation of the location and contact information for landowners who agreed to have their water well sampled is in progress. Sampling well specific information will be included and appended to this workplan once sampling locations are known. Site specific information may include: x Well logs x Pump tests x Copies of existing analytical data and associated sample locations x Well pump and maintenance details x Downstream treatment and handling details (if applicable); e.g., water system schematics or a description of the treatment process that is present, such as water softeners, under-sink filters, water storage tanks etc. x Photo(s) of the well x Well latitude and longitude x Sanitary seal presence and condition x Current well condition x Height of water well casing aboveground x Description of the homeowner property noting landscape features and potential contamination sources (e.g., fuel storage tanks, chemical storage, agricultural): proximity of potential contamination sources to the water well x Domestic wastewater management and proximity to the water well Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 3Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx The information above will be included in the site-specific information if available and reasonably obtainable. Some information may be able to be recorded during the onsite sampling effort and will be included in the final report as applicable. Based on the proximity to Anchor Point, climate and geology data for Anchor Point is provided below for geographical context. 2.3.1 Site Climate Anchor Point has a moderate subarctic climate which is characterized by cool summers and long winters. The average years low is 18º F in the winter, and the average yearly high is 62º F in the summer. On average, the area receives 25 inches of rain and 75 inches of snow annually. 2.3.2 Site Geology Anchor Point is located on the southwestern edge of the Kenai Peninsula, approximately 14 miles northwest of Homer, Alaska. The area is underlain by surficial unconsolidated glacial deposits from the Holocene and Pleistocene age. 2.3.3 Site Groundwater and Surface Water Freshwater forested/shrub wetlands and freshwater emergent wetlands are prevalent inland from Anchor Point. The Anchor River flows around Anchor Point before joining Cook Inlet on the western side of the town and is dominantly used for seasonal fishing. 2.4 Site History Based on a review of historical google earth aerial photos, little significant development has occurred in the area surrounding Anchor Point in the past ten years. Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 4Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx 3.0 METHODOLOGY 3.1 Site Investigation and Property Information NORTECH personnel will contact each landowner who agreed to the well sampling to coordinate water well sampling and property access and to gather property information and history.NORTECH will complete a site investigation of each property at the time of arrival to verify site conditions and to observe and document any obvious or potential releases, spills, or other contaminant sources or concerns that may require special handling or sampling. Information will be photo documented and field mapped. Details regarding the sanitary seal presence and condition, well condition, and the height of the well casing above the ground will be documented for each sampled well. NORTECH personnel will also conduct a visual inspection of adjacent areas to evaluate potential off-site sources. If a property owner denies access to their property for the purpose of sampling, NORTECH will document the denial and include documentation that good-faith efforts were taken to secure permission to access the property in the final report. 3.2 Baseline Parameters and Compounds of Concern Water samples will be submitted for analysis of the compounds listed in 20 AAC 25.283(a)(4) and eight additional analytes requested by Hilcorp. The table below lists the required and requested compounds and respective methods of analysis. Shaded analytes and analysis methods will be conducted in the field and may also be completed by the laboratory as confirmation. All other analytes will be sent for laboratory analysis as discussed in Section 3.4. Analyte Analysis Method Analyte Analysis Method pH SM21 4500-NB Alkalinity SM21 2320B Conductivity SM21 2510B Bacteria BART Testing Kit Antimony EPA 200.8 Arsenic EPA 200.8 Barium EPA 200.8 Beryllium EPA 200.8 Bicarbonate SM21 2320B Boron EPA 200.8 Bromide EPA 300.0 Cadmium EPA 200.8 Calcium EPA 200.8 Chloride EPA 300.9 Chromium EPA 200.8 Copper EPA 200.8 Fluoride EPA 300.0 Hydroxide SM21 2320B Iodide 314.0 Iron EPA 200.8 Lead EPA 200.8 Lithium EPA 200.8 Magnesium EPA 200.8 Manganese EPA 200.8 Mercury EPA 245.1 Total Nitrate SM21 4500N03-F Phosphorous EPA 200.8 Potassium EPA 200.8 Ra-226 M903.1 Ra-228 M904.0 Selenium EPA 200.8 Silicon EPA 200.8 Silver EPA 200.8 Sodium EPA 200.8 Strontium EPA 200.8 Zinc EPA 200.8 Sulfate EPA 300.0 Total Dissolved Solids SM21 2540C Benzene, Toluene, Ethylbenzene, Xylenes EPA 8260C Gasoline Range Organics AK101 Diesel Range Organics AK102 PAHs EPA 8270 Dissolved Methane, Ethane, and Propane RSK-175 Cyanide SM 4500-CNC Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 5Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx If free gas or dissolved methane is detected above 1.0 mg/kg during the RSK-175 analysis, further analysis will be conducted on the sample to determine the gas type. The gas type will be determined by a gas compositional analysis and a stable isotope analysis on methane, which includes analysis of carbon-12, carbon-13, hydrogen-1, and hydrogen-2 isotopes. 3.3 Well Sampling NORTECH personnel will purge standing water per ADEC guidance and collect groundwater samples for laboratory analysis using the existing well production method. If the well does not have a pump, NORTECH will use a submersible pump and tubing as necessary to purge and sample. If approved by the homeowner and as feasible, NORTECH will use a water meter to determine the depth of each well and the height of each water column prior to purging and sampling. The water depth and water column height will be used to determine well volume and purge volume. Prior to sampling, NORTECH will purge the wells according to ADEC guidance found in the FSG. Wells will be purged using the existing pump system until temperature, conductivity, and turbidity parameters have stabilized. Water will be purged through the hose bib or other access port closest to the well and prior to any treatment. The purge rate may be controlled to minimize drawdown in the well. The purge hose will be removed, and the hose bib will be decontaminated prior to sampling. In addition to the water sample parameters, NORTECH will document the odor, color, sedimentation, bubbles, effervescence, and any other notable conditions. 3.4 Laboratory Sample Collection Analyses that must be conducted immediately after sample collection will be done in the field by NORTECH personnel. Samples will be collected directly into clean glassware provided by the laboratory, preserved as necessary, and immediately placed in a cooler with ice prior to transportation under chain-of-custody to the laboratory. Each sample will be assigned a unique sample ID. NORTECH will use SGS North America in Anchorage, Alaska, which is a DEC approved laboratory as the analytical laboratory for this work. Isotech Laboratories in Champaign, Illinois (Isotech), an SGS network laboratory, will complete dissolved gas analysis. If free gas is detected or if dissolved gas concentrations above 1.0 mg/kg are detected, Isotech will run the second gas compositional and stable isotope analyses on the remaining water in the Isoflask. Isotech will also assist in determining whether the detected gas is thermogenic or a mixture of thermogenic and biogenic. 3.5 Quality Control NORTECH will use ADEC guidance and data quality objectives for this project. Field activities will be completed with the intent of meeting the FSG. The FSG discusses quality control methods and criteria for field screening, analytical sampling, and other potential quality control concerns.NORTECH will review each laboratory report and complete the ADEC Laboratory Data Review Checklist (LDRC) to evaluate data quality. These criteria will be discussed in the report. Laboratory Samples Field QC samples for this project will consist of field duplicate samples, trip blanks, and temperature blanks. The minimum quality control requirements are presented in Section 9.0, Table 6 of the FSG. They are summarized below for reference. Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 6Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx Field Duplicate Requirements A minimum of one (1) field duplicate shall be collected for every 10 field samples or portion thereof and for each analytical method. For sampling occurring over multiple days, field duplicates must not all be collected in one day and the goal will be to collect a minimum of one field duplicate per day. Duplicate samples will be collected in the same manner as primary samples and at the same time as the primary cohort sample. Duplicate samples will be submitted as blind samples with their own unique sample identifier and collection time. Duplicate sample information shall be adequately documented in the field book by the sampler so their result can be correlated to the correct location. Trip Blanks Laboratory supplied trip blanks will accompany the sample containers to and from the laboratory and remain unopened. One trip blank will be submitted per 20 volatile samples with a minimum of one trip blank analyzed per target volatile analyte and one per laboratory work order. Water trip blanks will consist of volatile-free water preserved with hydrochloric acid. Trip blanks will be submitted for volatile analyses. Water trip blanks will be provided by SGS. Temperature Blanks Temperature blanks are not samples, as such, and are used to determine the samples’ temperature upon receipt at the sample receiving office and at the analytical laboratory. They consist of tap water in a small poly bottle and can be prepared by NORTECH or provided by the laboratory. One temperature blank will be placed in each sample cooler transported from the field. Laboratory Quality Control Samples Quality control in the laboratory is designed to increase the probability that each result reported by the laboratory is valid and can be used with confidence to make a decision. Laboratory QC samples include method blanks, laboratory control samples (LCS), surrogate spikes, matrix spike samples, and spike duplicate samples. These will be identified, analyzed, and reported in accordance with method specific requirements identified in the analytical laboratory’s Standard Operating Procedures (SOP). 3.6 Field Documentation NORTECH will keep a log of field activities in a bound field notebook with numbered pages. Locations of samples will be marked in the field and documented on project drawings or site sketches. Some information during sampling may be documented on forms specific to the project and task. At a minimum, the following information shall be recorded in the field notebook: x Name and location of work site x Date(s) of sample collection/event x Names of field personnel on site x Daily start/stop times x General weather conditions x Pertinent field observations x Daily equipment calibration results x Time/date/location information for all samples collected Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 7Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx x Numbers and types of samples collected daily x Sample Identification number x Sample physical characteristics (depth, color, odor, etc.) x Site sketch with sampling locations x Management or disposal of investigative derived waste x Deviations from original work plan and rationale for those changes 3.7 Sample Handling and Custody Reusable sampling equipment will be decontaminated between each sampling event to help ensure accurate results. Disposable sampling equipment, such as nitrile gloves, will be discarded and replaced between sampling events. Containers will be labeled with laboratory-supplied labels, placed in a cooler and chilled to 4°C (+/- 2°C). Care will be taken by the sampler to maintain appropriate preservation temperature until delivery to laboratory. Sample preservation will be in accordance with the FSG and as described above. 3.8 Investigation Derived Waste Management Investigation derived waste (IDW) consists of used disposable sampling materials (i.e., used gloves, paper towels, used tubing etc.), used personal protective equipment (PPE), decontamination fluids, and development and purge water. Used disposable sampling supplies and PPE will be bagged following use for disposal as municipal waste. Purge water will be disposed of on the property via hose to a location at least 50 feet from the nearest building or other development that could flood. Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 8Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx 4.0 REPORTING 4.1 Interim Reporting NORTECH will provide field notes to Hilcorp upon completion of field work. Deviations from access agreements or other pertinent field activities will be documented and provided as well. NORTECH will notify Hilcorp when laboratory results have been received. If free gas or a dissolved methane concentration greater than 1.0 mg/L is detected in the water sample, the gas type will be determined using a gas compositional analysis and stable isotope analysis of the methane, including an analysis of carbon-12, carbon-13, hydrogen-1, and hydrogen-2 isotopes. AOGCC and ADEC will be notified within 24 hours if any of the following occurs: x Test results indicate thermogenic, or a mixture of thermogenic and biogenic, gas x Samples are required by the plan to be taken within a stated timeframe, and the methane concentration increased by more than 5.0 mg/L between sampling periods x Methane concentration is detected at or above 10 mg/L x Total petroleum hydrocarbons (BTEX, GRO, DRO) are detected 4.2 Final Reporting Following the receipt of laboratory data and within 90 days of the sampling effort, NORTECH will develop a final baseline study report to summarize the observed results and to include all collected analytical data and water well/property information. The report will include copies of the test results, analytical results, and sample locations to meet the requirements of 20 AAC 25.283. Property information such as a description of the homeowner property detailing the landscape features, potential contamination sources (and proximity of potential sources to the water well), and nearby domestic wastewater management sources will be provided. At minimum, the comprehensive report will include: x Descriptions of site characterization activities with a summary of changes from the work plan x Copies of field notes x Tabled data for clarity of review x Site photographs x Site maps and figures documenting sampling locations x Quality assessment/quality control (QA/QC) narrative x LDRCs x Complete laboratory data packages x Any other relevant or required information as described in applicable guidance Baseline Water Sampling and Analysis Plan Anchor Point, Alaska June 11, 2025 Page 9Https://Nortechinc.Sharepoint.Com/00-Jobs/2025/2526/Shared Documents/Workplans/2025-06-11_SAP_V2.Docx 5.0 LIMITATIONS NORTECH believes that the activities and methods described in this work plan are appropriate, but reasonable alternative field procedures may be used to perform the activities necessary under this contract. Alternative procedures may be necessary based on changes that have occurred on the site, unforeseen site conditions, and/or changes in ADEC requirements. If necessary, alternative methodology implemented by NORTECH will be appropriate, safe, and within industry standards. 6.0 SIGNATURES OF ENVIRONMENTAL PROFESSIONALS Megan Smoot Environmental Scientist Haley Michael, PE Environmental Engineer $SSHQGL[ Location Map Baseline Water Sampling and Analysis Plan Anchor Point, Alaska As Shown HEM SPH 25-2526 252526b 06/10/2025 1 PROJECT LOCATION 0 1 2 MILES PROJECT LOCATION 2400 College Road, Fairbanks, AK. 99709, 907-452-5688 3105 Lakeshore Dr., Anchorage, AK. 99517 907-222-2445 5438 Shaune Dr., Juneau, AK. 99801 907-586-6813 ENVIRONMENT, ENERGY, HEALTH & SAFETY CONSULTANTS DATE: DWG: DESIGN: DRAWN: PROJECT NO: SCALE:FIGURE: IMAGE FROM ALASKA DEPARTMENT OF NATURAL RESOURCES GIS DATABASE, ArcGIS USA TOPO MAP Vicinity Map Baseline Water Sampling and Analysis Plan Anchor Point, Alaska As Shown HEM SPH 25-2526 252526b 06/10/2025 2 0 1/4 1/2 MILE 2400 College Road, Fairbanks, AK. 99709, 907-452-5688 3105 Lakeshore Dr., Anchorage, AK. 99517 907-222-2445 5438 Shaune Dr., Juneau, AK. 99801 907-586-6813 ENVIRONMENT, ENERGY, HEALTH & SAFETY CONSULTANTS DATE: DWG: DESIGN: DRAWN: PROJECT NO: SCALE:FIGURE: JO D Y S B L I S S R O A D CAP E N I N I L C H I C K R O A D 1/2 MILE RADIUS IMAGE FROM GOOGLE EARTH, FEBRUARY 2024 AERIAL IMAGE OPP O R T U N I T Y L A N E WHISKEY GULCH PAD WH I S K E Y G U L C H ST R E E T STE R L I N G H I G H W A Y Appendix 2 OW N E R N A M E NO T I C E M A I L I N G A D D R E S S CI T Y ST A T E ZI P PA R C E L I D TY P E Ph o n e N u m b e r Em a i l Ad d r e s s o n R e s p o n s e F o r m Wa t e r W e l l I n f o r m a t i o n o n R e s p o n s e F o r m : NO T E S HA R M O N , D O N A L D PO B O X 1 3 3 7 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 1 0 P r i v a t e ( 3 6 0 ) 9 2 1 - 1 5 8 6 31 9 6 5 W h i s k y G u l c h A n c h o r Po i n t 9 9 5 5 6 We l l d r i l l e d i n 2 0 0 6 ( ? ) D e p t h o f 8 0 f t ( ? ) 3 0 g a l mi n ( ? ) T e s t e d f o r p u r i f i c a t i o n a n d q u a l i t y t h a t sh o p i n S o l d o t n a i n 0 8 - 0 9 ? UM B A R G E R R O N A L D F , a n d A n n 22 2 0 0 S E R O Y A L A N N E D R A M I T Y O R 9 7 1 0 1 1 6 5 7 0 0 3 6 P r i v a t e ( 9 7 1 ) 2 3 7 - 3 2 5 1 ra y s a u t o s v c @ y a h o o . c o m 31 8 8 2 L a D u q u e s a L N A n c h o r Po i n t 9 9 5 5 6 In s t a l l e d M a r c h 2 0 1 9 . A p p r o x D e p t h 1 1 3 f t . Lo c a t i o n a p p r o x 2 5 0 f t f r o m N W c o r n e r o f pr o p e r t y a l o n g N o r t h p r o p e r t y l i n e . T h e n ap p r o x . 2 5 f t s o u t h o f N o r t h p r o p e r t y l i n e . St a t i c w a t e r l e v e l 6 5 - 7 0 f t . N o w a t e r t e s t av a i l a b l e . AL E X A N D E R , D A R R I N PO B O X 1 1 4 7 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 1 6 5 1 8 P r i v a t e ( 9 0 7 ) 2 9 9 - 0 4 3 2 da r r i n . a l e x a n d e r @ y a h o o . c o m 31 8 1 0 W h i s k e y G u l c h S t r e e t An c h o r P o i n t 9 9 5 5 6 In s t a l l e d 1 9 9 3 , 6 i n c h w e l l c a s i n g , w e l l d r i l l i n g ri g w a s t h e p o u n d e r k i n d , 4 5 f t d e e p . Ow n e r a l s o r e q u e s t e d s a m p l i n g o f h i s p e r s o n a l re s i d e n c e w a t e r w e l l l o c a t e d a t p a r c e l s 1 6 5 6 1 0 8 3 / 16 5 6 1 0 8 4 ( C a p e N i n i l c h i k A v e ) . H e w a s n o t i f i e d 7/ 7 / 2 5 t h a t o n l y t h e w e l l at 3 1 8 1 0 W h i s k e y G u l c h St r e e t w o u l d b e t e s t e d . I t i s a s s u m e d , b u t n o t co n f i r m e d t h a t t h e w a t e r w a t e r w e l l i n f o r m a t i o n pr o v i d e d o n t h e r e s p o n s e f o r m w a s f o r t h e N i n i l c h i k Av e l o c a t i o n a n d n o t t h e W h i s k e y G u l c h S t r e e t Lo c a t i o n . WH I T E , K A T H E R I N E PO B O X 2 5 5 A N C H O R P O I N T A K 9 9 5 5 6 1 6 5 6 1 0 2 6 P r i v a t e ( 9 0 7 ) 2 9 9 - 0 1 3 3 wh i t e _ k a t h e r i n e @ h o t m a i l . c o m 31 6 7 5 W h i s k y G u l c h S t r e e t Y o u c a n d o a n y t h i n g y o u w a n t o n m y pr o p e r t y . T h i s w a t e r w e l l w a s p r e l i m i n a r i l y i d e n t i f i e d i n W E L T S . HA Y E S , J E F F R Y N E A L 56 2 O C E A N P O I N T D R A N C H O R A G E A K 9 9 5 1 5 1 6 5 6 1 0 4 3 P r i v a t e ( 9 0 7 ) 8 5 4 - 0 9 7 0 je f f r y . h a y e s 6 4 @ g m a i l . c o m 31 7 7 4 O p p o r t u n i t y L a n e A n c h o r Po i n t , A K 9 9 5 5 6 Ap r i l 2 0 2 1 , A p p r o x . 1 1 7 f t , B l a c k w e l l P u m p Se r v i c e 9 0 7 - 2 3 5 - 6 2 8 0 CO U R T R I G H T , C A M I L L E A PO B O X 3 1 2 4 H O M E R A K 9 9 6 0 3 1 6 5 6 1 0 6 9 P r i v a t e ( 5 4 1 ) 7 2 9 - 5 3 5 5 tc o u r t r @ m s n . c o m PO B o x 3 1 2 4 , H o m e r , A K 9 9 6 0 3 Un k n o w n Th i s w a t e r w e l l w a s p r e l i m i n a r i l y i d e n t i f i e d i n W E L T S . address for water well to be sampled disregard this address