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Home My WebLink About100-009OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 1 Gavin Gluyas Natural Resource Technician 2 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool, Houston Core Hole 2 ASRC Energy Services Alaska. Inc. Permit to Drill Number: 100-009 Surface Location: 2150’ FWL, 710’ FNL, Sec. 20, T18N, R3W, Seward Meridian Bottomhole Location: 2150’ FWL, 710’ FNL, Sec. 20, T18N, R3W, Seward Meridian Dear Mr. Gluyas: Enclosed is the well log file from the casing collar locator log run in the subject well on August 19, 2025. Please acknowledge receipt by e-mailing amcvey@asrcenergy.com. Sincerely, Adrienne McVey Workover Engineer DATED this 12th day of January, 2026. 100-009 T41246 By Gavin Gluyas at 8:08 am, Jan 13, 2026 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:McVey, Adrienne Cc:Hammons, Darrell; Dial, Amanda; Brandenburg, Timothy Subject:RE: Houston Core Hole 2 (PTD 100-009) Plan Forward Date:Friday, November 14, 2025 5:09:00 PM Adrienne, Thanks. I agree with the plan. ASRC has approval to proceed. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Friday, November 14, 2025 4:17 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Hammons, Darrell <dhammons@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: Houston Core Hole 2 (PTD 100-009) Plan Forward Bryan, As discussed on the phone: tomorrow morning we will attempt to back off the Loctited connection at 57', above where we plumbed TOC inside the workstring at 70'. From there, we will circulate in cement from the backed off connection and once finished, retrieve the backed off pipe to surface. We will then cut off the wellhead. Then, after allowing the newly placed cement to harden overnight, we will hopefully be ready for an Inspector on Sunday. We've apprised Guy Cook of the updated timing. Thanks, Adrienne ⚠️CAUTION: EXTERNAL SENDER This email originated from outside of the CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Adrienne McVey Cc:Timothy Brandenburg; danny.kara; Doug Cismoski; Amanda Dial; Darrell Hammons Subject:Re: Houston Core Hole 2 (PTD 100-009) Date:Wednesday, November 12, 2025 9:13:04 PM Adrienne, Procedure looks good. ASRC has approval to proceed. Only things I suggest are 1) hold a drill for picking up safety joint before RIH. 2) discuss max pump pressure, even if it’s limited only by the pump, so everyone knows. Good luck. Bryan Sent from my iPhone On Nov 12, 2025, at 8:15 PM, McVey, Adrienne <amcvey@asrcenergy.com> wrote: Bryan, Thank you! Please see attached detailed procedure for your review. Will follow up with a text. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, November 12, 2025 6:07 PM To: McVey, Adrienne <amcvey@asrcenergy.com> Cc: Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; 'danny.kara' <danny.kara@outlook.com> Subject: Houston Core Hole 2 (PTD 100-009) organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Adrienne, ASRC has verbal approval to proceed with the change of approved permit sundry submitted today. Please take note of the conditions of approval in the attached version. The fully approved version will be sent tomorrow. Please send me a copy of the full procedure when it’s done and send me a text so I know to look for it in my email. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 <image001.jpg> <Core Hole 2 (PTD 100-009) Detailed Cementing Procedure 2025-11-12.pdf> Core Hole 2 Plug and Abandon Detailed Procedure November 12, 2025 API #: 50-009-10023-00-00 PTD: 100-009 Prepared for Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Prepared by 3900 C Street, Suite 701 Anchorage, Alaska 99503 THIS PAGE INTENTIONALLY LEFT BLANK AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC i November 2025 18697-01 Rev. 1 TABLE OF CONTENTS Page Table of Contents ........................................................................................................................................... i 1.0 Introduction ...................................................................................................................................... 2 1.1 Objective .................................................................................................................. 2 1.2 Scope .................................................................................................................. 2 1.3 AOGCC Notification Requirements Summary................................................................... 3 1.4 Waivers to AOGCC Regulations ........................................................................................ 3 1.5 Contacts .................................................................................................................. 4 2.0 Equipment, Supplies, and Services .................................................................................................. 4 2.1 Workstring .................................................................................................................. 5 2.2 Surface Equipment .............................................................................................................. 6 2.3 Cement Program ................................................................................................................. 6 2.4 Waste Management Program .............................................................................................. 7 3.0 Plug and Abandon Procedure ........................................................................................................... 7 3.1 Cementing Procedure .......................................................................................................... 7 3.2 Wellhead Removal .............................................................................................................. 9 List of Tables Table 1.3-1: AOGCC Notification Requirements Summary ........................................................................ 3 Table 1.4-1: Waivers to AOGCC Regulations .............................................................................................. 3 Table 1.5-1: Contacts .................................................................................................................................... 4 Table 2.0-1: Equipment, Supplies and Services Summary Table ................................................................. 4 Table 2.1-1: Workstring Data Table ............................................................................................................. 5 Table 2.3-1: Cement Program Table ............................................................................................................. 6 List of Appendices Appendix A: Current Wellbore Schematic Appendix B: Proposed Wellbore Schematic Appendix C: Coupling Pull Test Appendix D: Modified Polished Rod Clamp Pull Test Appendix E: Sucker Rod Stripper Appendix F: Surface Equipment Schematic Appendix G: Cement Lab Test Results Appendix H: Cement Modeling Results Appendix I: Cement Pumping Diagram Appendix J: Proposed Abandonment Marker AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 2 November 2025 18697-01 Rev. 1 1.0 Introduction Houston Core Hole 2 is planned for plug and abandonment (P&A) as part of the State of Alaska AOGCC Orphan Well Program. The P&A work will be conducted by AES-AK as Operator, on behalf of the AOGCC. Cementing operations on Core Hole 2 are scheduled to begin in November 2025. This cementing program incorporates findings of Slickline (April 2025) and E-line (August 2025) diagnostic operations, which are described below. On 04/22/2025, an attempted Slickline drift run with a 2.24” lead impression block (LIB) identified a previously unknown 1.81” OD pipe stub, likely EX core casing, at 27’ SLM. Slickline drifted inside the pipe stub to a tag depth of 511’ SLM with a 1” sample bailer (returned clay) and a 1.2” LIB. Slickline was unable to enter the stub with a 1.31” OD swage. On 08/18/2025, E-Line diagnostic work was completed per Sundry 325-466. The Casing Collar Locator log showed the end of EX core casing at 217’ ELM, with 292’ of open hole below, down to a tag depth/top of fill at 509’ ELM. Since the EX core casing did not extend all the way down to tag depth, E-Line rigged down after completing the CCL, and did not set a miniature bridge plug. Base of fresh water is estimated at 440’ MD / TVD. Refer to Appendix A: Current Wellbore Schematic and Appendix B: Proposed Wellbore Schematic for additional information. 1.1 Objective The objective of this procedure is to is to permanently abandon the Houston Core Hole 2 wellbore, including isolating and protecting the freshwater aquifer. Base of fresh water is estimated at 440’. 1.2 Scope • Site preparation - completed • Wellhead installation - completed • Slickline diagnostic work – completed • E-line diagnostic work - completed • Place low rheology, gas tight cement from top of fill (509’) to surface • Cut off wellhead, weld on marker plate • Backfill and grade site AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 3 November 2025 18697-01 Rev. 1 1.3 AOGCC Notification Requirements Summary Table 1.3-1: AOGCC Notification Requirements Summary Event Notice Required Notification Method Comments Post-wellhead cutoff, before and after cement top-off 24 hours before Test Witness Notification web form Specified in approved Sundry 325- 692 Final location clearance inspection 10 days before Test Witness Notification web form Specified in approved Sundry 325- 692 1.4 Waivers to AOGCC Regulations Table 1.4-1: Waivers to AOGCC Regulations Regulation Waiver Request AOGCC Response 20 AAC 25.112 (a)(3) Base of fresh water = 440’. E-line tag depth = 509’. Circulate cement from 509’ to surface (69’ below base of fresh water). Do not attempt to clean out deeper to place cement 150’ below base of fresh water. Approved in Sundry 325-692 20 AAC 25.112 (g) Due to exceptionally small wellbore volume, casing and open hole sizes (assume 1.5” from 27’ – 509’), and minimal annular clearance around the workstring, request variance to not place surface plug separately. Plan to place one plug from 509’ – surface and leave workstring in hole. Approved in Sundry 325-692 20 AAC 25.120 Given the exceptionally small size of the largest string to surface (2.875”), rather than install a marker plate, it is proposed to install over the 2- 7/8” casing stub a 3.5” OD sleeve with the required identification information bead welded to the side of it. Conditionally approved in Sundry 325-692; top plate must have some indication that the well information is located on the side of the pipe. 20 AAC 25.286 Due to low and stable shut-in wellhead pressure, and low flow potential of mainly brackish water with small amounts of gas, a variance to the requirements of 20 AAC 25.286. Well control requirements for workstring service operations is requested. Conditionally approved in Sundry 325-692; safety joint with safety valve must be available with correct threads to stab into workstring in the event of flow coming from inside the workstring. AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 4 November 2025 18697-01 Rev. 1 1.5 Contacts Table 1.5-1: Contacts Name Phone Number Email Comment Emergency Response 911 Emergency Response Bryan McLellan 907-250-9193 bryan.mclellan@alaska.gov AOGCC Senior Petroleum Engineer Amanda Dial 907-382-0124 adial@asrcenergy.com AES-AK Drilling Manager Tim Brandenburg 907-252-3923 tbrandenburg@asrcenergy.com AES-AK Project Manager Adrienne McVey 907-980-8623 amcvey@asrcenergy.com AES-AK Drilling Engineer Darrell Hammons 337-368-4425 dhammons@asrcenergy.com AES-AK Wellsite Leader Jeff Kilfoyle 907-440-2354 jkilfoyle@trikilenterprises.com AES-AK HSE Consultant Ben Bittler 907-982-0804 bbitler@cruzconstruct.com Cruz Project Engineer 2.0 Equipment, Supplies, and Services Table 2.0-1: Equipment, Supplies and Services Summary Table Equipment Vendor Contact Origin Crane Cruz Ben Bittler (907) 982-0804 Kenai Workstring Puget Sound Pipe and Supply Brett O’Connor (907) 206-9577 Anchorage Pipe Wrenches Pipe Vise Texas Thread Compound Grainger Industrial Anchorage Polished Rod Clamps Through Tubing Services Robert Ward (918) 441-6199 Oklahoma Lifting Slings ACES Cinnabar Shop Zach Bonser (907) 795-8627 Anchorage 3” Riser ACES Cinnabar Shop Zach Bonser (907) 795-8627 Anchorage Sucker Rod Stripper Howard Supply Billy Lujan (432) 552-9199 Texas Cement Products Schlumberger Mitch Rice (346) 901-3354 Deadhorse Red Dye Halliburton Chan Poonian (360) 325-9910 Sterling Grout Pump (Geo-Loop YP2) Wheaton Water Well Brian Wille (907) 715-1340 Wasilla Hoses, crossovers, JIC tee, needle valve and gauge Have most in inventory; Alaska Rubber Group for remainder Poly-Totes Home Depot Anchorage Gas Meters TTT Anchorage Cuttings boxes, trash pump with hose package, air compressor, heater, light plant MagTec Tyler Timm (907) 398-5255 Kenai AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 5 November 2025 18697-01 Rev. 1 Equipment Vendor Contact Origin Telehandler Coming from Eureka Class II Fluids Disposal Alaska Eco Resources Monofill Vance Larrabee (907) 598-8085 Nikiski Solid Cement Disposal Palmer Landfill Terry (907) 861-7620 Palmer 2.1 Workstring The cementing plan in Approved Sundry 325-466 was to run coiled HDPE pipe into the well with a grouting unit and circulate cement to surface. However, due to concerns about HDPE pressure rating, tensile strength, and “memory” of the coiled HDPE when trying to enter the top of the EX casing stub at 27’, the updated plan is to use ½” Schedule 40 A106B seamless black steel pipe as the workstring, with Class 3000 forged couplings. The couplings will be beveled (top and bottom) to ease entry into the EX casing stub. The couplings do present a packoff risk as cement is circulated into the well. To reduce this risk, 20’ joints of pipe will be pre-welded together into 60’ lengths. This will result in only 8 couplings along the 500’ workstring. The deepest coupling will be at 440’ (base of fresh water). Eliminating couplings below base of fresh water provides the best chance of getting cement up to at least this height. 2 couplings (at 140’ and 260’) will be run without Loctite. These will serve as contingency back- off/circulation points. In the event of packoff/lost returns, the contingency is to back off at one of these connections, then circulate in a surface plug from that depth. Assuming the packoff were to occur at or above the deepest coupling at 440’, this contingency plan still isolates the base of fresh water from the flowing zone below it and allows placement of a surface plug. Table 2.1-1: Workstring Data Table Workstring Description ½” Schedule 40 A106B Black Seamless Pipe Thread Type ½” NPT, 14 threads per inch Wall Thickness 0.109” Weight 0.851 lb/ft (without couplings) OD 0.840” ID 0.622” Capacity 0.000376 bbl/ft = 0.0158 gal/ft Total Workstring Volume 0.192 bbl = 8.050 gal Coupling Description ½” 3M A105 coupling Coupling OD 1.125” Coupling ID 0.7” Total weight of string with couplings (unbuoyed) 450 lb (for 510’ of pipe) Pull test 750 lb Working Pressure 1600 psi Allowable temporary overpressure 2000 psi See Appendix C: Coupling Pull Test for additional information. AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 6 November 2025 18697-01 Rev. 1 2.2 Surface Equipment A crane and modified polished rod clamps with lifting eyes will be used for pipe handling. Clamps were pull tested to 1000 lbs. See Appendix D: Modified Polished Rod Clamp Pull Test for additional information. The workstring will be made up with pipe wrenches. A 3” riser with tee will be flanged up to the wellhead. A spring-assisted sucker rod stripper will be screwed onto the top of the riser to provide a dynamic seal. Below the sucker rod stripper will be gas and water diversion tees. An explosion-proof vacuum will be used at the end of the gas diversion tee. It will likely be necessary to “open hole” when initially running in, to manually work through the top of the casing stub at 27’ and/or until the workstring weight is sufficient to overcome the stripper rubber friction. Water flow will be diverted to either a 15-bbl cuttings box or the Rosetta 1 cellar. See Appendix E: Sucker Rod Stripper and Appendix F: Surface Equipment Schematic for additional information. 2.3 Cement Program The planned cement blend is a 13.5 ppg low rheology gas-tight slurry. The design criteria were: • Minimize friction pressure while pumping through the 0.622” ID workstring • Minimize ECD in the open hole section from 217 – 509’ o Annular clearance between EX core casing and workstring if centered = 0.33” o Coupling annular clearance = 0.1875” • Prevent gas migration as cement sets Table 2.3-1: Cement Program Table Total Workstring Internal Volume 0.192 bbl = 8.050 gal Total Annulus Volume 0.861 bbl = 36.153 gal Total Volume (workstring + annulus) 1.053 bbl = 44.203 gal Planned Volume to Pump 2.5 bbl Planned Pump Rate 0.2 bpm = 8.4 gpm Max Predicted Pump Pressure 463 psi Workstring Rated Working Pressure 1600 psi (2000 psi temporary overpressure OK) Max Predicted ECD 18.8 ppg Estimated Frac Gradient ≥ 18.9 ppg (based on Rosetta 4 annulus cement job) Refer to Appendix G: Cement Lab Test Results and Appendix H: Cement Modeling Results for additional information. AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 7 November 2025 18697-01 Rev. 1 2.4 Waste Management Program • For Class II liquid returns: Alaska Eco Resources (AER) Monofill in Nikiski. An approved Waste Profile Sheet and AER Manifest will accompany each load. • For cement returns: take returns to poly-totes. Allow to harden. Dispose of poly-totes at Palmer Landfill. 3.0 Plug and Abandon Procedure 3.1 Cementing Procedure 3.1.1 Flange up 3” riser with sucker rod stripper to the 4-1/16” dry hole tree. 3.1.2 RIH with workstring to 500’. • Safety joint with safety valve must be available with correct threads to stab into workstring in the event of flow coming from inside the workstring. • Strap and number joints. • Depth reference: top flange of swab valve (zero point for E-line CCL log; tag depth 509’ ELM) • Each ~60’ piece of pipe will have one coupling pre-installed. • Apply Blue LocTite to threads except for the couplings at 140’ and 260’. See Appendix B, Proposed Wellbore Schematic, for coupling depth details. • Make-up torque: 30 ft-lb max, or 2-3 turns from finger-tight. • Do not tag TD due to risk of plugging off. • Divert water and gas flow via tees on riser while RIH. • Take water returns to Rosetta 1 cellar. • Blow forced air across area where pipe is being made up to diffuse any small amount of gas that may be exiting the workstring. • Monitor LEL’s in pipe make-up area. o Action level: 10% o If action level is exceeded, increase forced air flowrate to further disperse gas, and pour water down the workstring until LEL is below action level. 3.1.3 Once at depth, connect grout pump to workstring. • Plan to use Geo-Loop Model YP2 2-tank grout pump. • Install ½” ball valve (1/2” NPT threads) at top of workstring to isolate from pump. • Pump provider will provide hose and fittings to cross over from pump to ½” NPT. • See Appendix I: Cement Pumping Diagram for additional information. 3.1.4 Shut in gas diversion tee. Will take cement returns from water diversion tee. 3.1.5 Break circulation at 0.2 bpm/8 gpm with fresh water, taking returns from water diversion tee to Rosetta 1 cellar. Check for leaks. Record circulating pressure. 3.1.6 Once circulation path is established, add red dye to fresh water in the grout pump mix tank. Circulate red dye to surface, noting volume pumped (mix tank strap) and volume returned (5-gallon buckets with 1-gallon strap marks), to verify wellbore volume. AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 8 November 2025 18697-01 Rev. 1 3.1.7 Once red dye is circulated back to surface, shut in returns. Record SIWHP. • Note: nearby offset Rosetta 1 SIWHP after circulating to a full column of water was 0 psi. 3.1.8 Mix ~2.5 bbl of 13.5 ppg low rheology gas-tight cement. • Mix in grout pump mixing tanks. Can supplement mix volume by mixing some of the slurry in external cement mixer or Poly-Tote, then pouring into grout pump mixing tanks. • Estimated wellbore volume = 1 bbl. • Ordered enough cement product to mix approximately 5 bbl. Plan to mix and pump 2.5 bbl initially (increase this volume if indicated by red dye circulation data), leaving half left over for a second cement job in the event cement is not circulated to surface during the initial job. See CONTINGENCY #2 (Step 11) below. • Dry additives are already mixed into blend. • Use SLB-provided spreadsheet to calculate liquid additives and mix water requirements. • Rheologies tested at 50F, 60F, and 80F. Plan mix water temperature accordingly. Grout pump provider is providing a circulation pump that will enable confirming slurry temperature before pumping downhole. 3.1.9 Pump ~2.5 bbl of cement down workstring, taking returns from water diversion tee. • Wellbore volume ~1 bbl (will confirm with red dye before pumping cement) • Plan to hold back pressure while circulating cement to avoid influx contamination of cement until cement provides enough hydrostatic to balance the reservoir. Maintain 1:1 returns throughout the operation by manipulating return choke/throttle valve. • Maintain constant casing pressure until cement reaches muleshoe (8 gallons). Duration is approximately 1 minute at 8.4 gpm/0.2 bpm. • Maintain constant pump pressure while filling annulus with cement (36 gallons). Duration is approximately 4.5 minutes. • Maintain constant pump pressure while taking cement returns to surface (~61 gallons excess cement planned). Duration is approximately 7.5 minutes. • 1:1 returns tracking is crucial. Take returns to 5-gallon buckets with 1-gallon strap marks. • Record volume pumped, volume returned, pump pressure, wellbore pressure throughout the job. • If packoff is suspected, attempt to clear the pack-off by reciprocating pipe. • Pump until mix tanks are empty. • Once mix tanks are empty, shut in the 3” ball valve on the water diversion tee, and shut in the ½” ball valve installed on the top of the work string. 3.1.10 CONTINGENCY #1: in the event of packoff/lost returns, back off at non-Loctite connection (140’ and 260’), then circulate in a surface plug from that depth. Assuming the packoff were to occur at or above the deepest coupling at 440’, this contingency plan still isolates the base of fresh water from the flowing zone below it and allows placement of a surface plug. 3.1.11 CONTINGENCY #2: in the event circulation cannot be established from the contingency back- off/circulation point, retrieve the workstring above the backoff point to surface. Prepare to perform a second cement job to cement the well to surface above the workstring stub. AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 9 November 2025 18697-01 Rev. 1 3.1.12 Disconnect and wash up grout pump. 3.1.13 Leave workstring in hole. It will be cut off along with the wellhead. 3.1.14 Wait on cement. 3.2 Wellhead Removal 3.2.1 Notify AOGCC Inspector 24 hours in advance to witness wellhead post cut-off, before and after cement top job. Use the Test Witness Notification web form on the AOGCC website. 3.2.2 Remove wellhead and cellar. Complete excavation as needed around the well to allow cutting the 2-7/8” pipe to a minimum depth of 3’ below ground level for final P&A. 3.2.3 Top off 2-7/8” pipe with cement as needed. Photograph casing and cement and include in 10-407. 3.2.4 Weld top plate onto 2-7/8” pipe, with verbiage indicating the well information is located on the side of the pipe. 3.2.5 Weld 3.5” OD sleeve onto the 2-7/8” casing stub with the following information: (see Appendix J: Proposed Abandonment Marker for additional information) State of Alaska AOGCC PTD 100-009 Houston Core Hole 2 API 50-009-10023-00-00 3.2.6 Perform post-P&A methane monitoring and record results for reporting purposes. 3.2.7 Backfill the excavated hole, grade to final elevation, remove any debris and clear location. Photo- document final site clearance and include with 10-407 submittal. • Notify AOGCC Inspector 24 hours in advance to perform final site clearance inspection. Use the Test Witness Notification web form on the AOGCC website. AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 10 November 2025 18697-01 Rev. 1 THIS PAGE INTENTIONALLY LEFT BLANK AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 11 November 2025 18697-01 Rev. 1 Appendices AOGCC Orphan Well Plugging and Remediation Program Houston Core Hole 2 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 12 November 2025 18697-01 Rev. 1 THIS PAGE INTENTIONALLY LEFT BLANK Dry hole tree: (1) 4-1/16" 5M gate valve When well is open, flows ~1 gallon per minute brackish water and gas. 2-7/8" collar at 19' Based on start depth of core log = 19' 2-7/8" collar is cemented or grouted to surface Objectives Open Hole from 19' - 27' Fill well with cement from 509' to surface Isolate fresh water from brackish water and gas zone Top of EX core casing stub at 27' Stop water and gas flow to surface Based on Slickline tag with 2.24" Lead Impression Block on 4/22/2025 Do not broach 2-7/8" open shoe at 19'EX core casing is not cemented Basic Procedure EX Core Casing Dimensional Data: Run 1/2" jointed steel pipe to 505'Outer Diameter = 1.81" Circulate cement to surface Inner Diameter = 1.5" Cut off pipe and leave in hole Largest diameter tool to successfully enter stub = 1.2" lead impression block Could not enter stub with 1.31" swage Bottom of EX core casing stub at 217' Based on E-Line Casing Collar Locator run 08/19/25 Open hole below EX core casing assumed to be 1.5" diameter Based on hole size made by EX core barrel bit Casing Detail Size Weight Grade Top Bottom 2-7/8" 6.4 ppf unknown 0 19' Base Fresh Water at 440'1.81" unknown unknown 27'217' 2-7/8" pipe data: Actual field ID measurements 2.44" - 2.47" 2-1/2" line pipe (2.469" ID) or 2-7/8" 6.4# tbg (2.441" ID, 2.347" drift) Top of Fill = 509' Based on 8/19/25 E-line tag depth 4/22/25 Slickline tag with 1" sample bailer returned clay Top of brackish water and gas zone at 545'Slickline also ran 1.2" LIB to PBTD on 4/22/25 Well develops gas cap when shut in Wellbore not accessible below this depth Shut-in wellhead pressure = 70 psi Gas cap bleeds off thru 1/2" hose in 5-10 minutes Then flows mostly water at ~1 gpm August 1957 Bureau of Mines Report 5350 lists depth as 1142', as Total Depth 1142' 8/5/1952 does the mud log. NO DRILLING OR CASING RECORDS FOUND FOR THIS WELLBORE API # 50-009-10023-00-00 Meridian Township Range Section PTD # 100-009 Spud date: 5/29/1952 Seward 18 N 3W 20 Prepared by ASRC Energy Services 10/15/2025 Houston Core Hole 2 Houston Core Hole 2 FILLAppendix A: Current Wellbore Schematic THIS PAGE INTENTIONALLY LEFT BLANK 2-7/8" collar at 19' Based on start depth of core log = 19' 2-7/8" collar is cemented or grouted to surface Open Hole from 19' - 27' Top of EX core casing stub at 27' Based on Slickline tag with 2.24" Lead Impression Block on 4/22/2025 EX core casing is not cemented EX Core Casing Dimensional Data: Outer Diameter = 1.81" Inner Diameter = 1.5" Largest diameter tool to successfully enter stub = 1.2" lead impression block Could not enter stub with 1.31" swage Bottom of EX core casing stub at 217' Based on E-Line Casing Collar Locator run 08/19/25 Open hole below EX core casing assumed to be 1.5" diameter Based on hole size made by EX core barrel bit Casing Detail Size Weight Grade Top Bottom 2-7/8"6.4 ppf unknown 0 19' 1.81"unknown unknown 27'217' 2-7/8" pipe data: Base Fresh Water at 440'Actual field ID measurements 2.44" - 2.47"P&A Plug:2-1/2" line pipe (2.469" ID) or 2-7/8" 6.4# tbg (2.441" ID, 2.347" drift) Plug #1: 1 bbl cement from 0' - 509' Top of Fill = 509' Based on 8/19/25 E-line tag depth 4/22/25 Slickline tag with 1" sample bailer returned clay Top of brackish water and gas zone at 545'Slickline also ran 1.2" LIB to PBTD on 4/22/25 Wellbore not accessible below this depth August 1957 Bureau of Mines Report 5350 lists depth as 1142', as Total Depth 1142' 8/5/1952 does the mud log. NO DRILLING OR CASING RECORDS FOUND FOR THIS WELLBORE API # 50-009-10023-00-00 Meridian Township Range Section PTD #100-009 Spud date: 5/29/1952 Seward 18 N 3W 20 Prepared by ASRC Energy Services 10/15/2025 Houston Core Hole 2 Houston Core Hole 2FILLWorkstring:1/2" Schedule 40 A106B Black Seamless Pipe 0.840" pipe OD 1.125" coupling OD Coupling depths: 20' (single joint) 80' (triple: 3 joints pre-welded) 140' (triple) 200' (triple) 260' (triple) 320' (triple) 380' (triple) 440' (triple) Muleshoe at 500' 1.5" Open Hole x Workstring Annular Capacity = 6.3 gallons / 100 feet 7.5 gallons of cement in annulus brings TOC to 390' (50' above base of fresh water) Appendix B: Proposed Wellbore Schematic THIS PAGE INTENTIONALLY LEFT BLANK Appendix C: Coupling Pull Test THIS PAGE INTENTIONALLY LEFT BLANK Appendix D: Modified Polished Rod Clamp Pull Test THIS PAGE INTENTIONALLY LEFT BLANK Appendix E: Sucker Rod Stripper THIS PAGE INTENTIONALLY LEFT BLANK Appendix F: Surface Equipment Schematic THIS PAGE INTENTIONALLY LEFT BLANK Page 1 Laboratory Cement Test Report ASRC ENERGY SERVICES ALASKA INC - Core Hole 2 13.5 Low Rheo Gas Tight Slurry – Plug to Abandon Field Blend LAR Name : AKA 2025-102 Client : ASRC ENERGY SERVICES Location : Prudhoe Bay Date : Oct-26-2025 Well Name : Core Hole 2 Rig : Rigless String : PlugToAbandon Signatures Report created by: Daniel Pierce Design input by: Mitch Rice Job Type : Remedial MD : 510.00 ft TVD : 510.00 ft BHST : 45 °F BHCT : 50 °F BHP : 358 psi Starting Temp : 65 °F Time To Temp : 24:00 hr:mn Heating Rate : 0.00 °F/min Starting Pressure : 351 psi Time To Pressure : 24:00 hr:mn Composition Slurry Density : 13.50 lb/gal Yield : 1.88 ft³/sk of blend Mix Fluid : 10.102 gal/sk of blend Solid Vol. Fraction : 27.759 % Slurry Type : Mix Water : 8.842 gal/sk of blend Code Concentration Sack Reference Component Blend Density Lot Number D907 100.000 % BVOB Blend sack: 94.00 lb Cement 3.20 SG Super Sack D047 0.200 gal/sk VBWOC Anti Foam H025070031 D163 10.000 % BWOC Cement Super Sack D079 1.100 % BWOC Extender Super Sack D185A 0.060 gal/sk VBWOC Dispersant H0709S492971 D500 0.600 gal/sk VBWOC Gas Control Agent CY42763057 D186 0.400 gal/sk VBWOC Accelerator 11172021 Fresh Water 8.842 gal/sk of blend Base Fluid N. Slope Borough Rheology S/N: 1159 Surface (Configuration: R1B1 F1.0) Temperature 80 °F (rpm) Up (deg) Down (deg) Average (deg) 300 39 39 39 200 35 35 35 100 30 30 30 60 27 27 27 30 23 24 24 6 20 21 21 3 19 20 20 10 sec Gel 16 deg - 17 lbf/100ft² 10 min Gel 23 deg - 24 lbf/100ft² Rheo. computed PV: 19 cP, Ty: 22 lbf/100ft² S/N: 1159 Downhole (Configuration: R1B1 F1.0) Temperature 50 °F (rpm) Up (deg) Down (deg) Average (deg) 300 35 35 35 200 28 28 28 100 21 20 21 60 19 17 18 30 17 14 16 6 15 12 14 3 14 11 12 10 sec Gel 10 deg - 11 lbf/100ft² 10 min Gel 23 deg - 24 lbf/100ft² Rheo. computed PV: 22 cP, Ty: 13 lbf/100ft² S/N: 1159 Downhole 60degF (Configuration: R1B1 F1.0) Temperature 60 °F (rpm) Up (deg) Down (deg) Average (deg) 300 37 37 37 200 30 30 30 100 25 23 24 60 22 20 21 30 20 17 19 6 18 15 17 3 17 15 16 10 sec Gel 12 deg - 13 lbf/100ft² 10 min Gel 25 deg - 27 lbf/100ft² Rheo. computed PV: 21 cP, Ty: 16 lbf/100ft² Appendix G: Cement Lab Test Results Page 2 Thickening Time S/N: 461 Consistency Time Temp Go/No-Go: On: 01:00 hr:mn Off: 00:20 hr:mn POD Time 02:42 hr:mn 55 °F 30 Bc 04:08 hr:mn 55 °F 50 Bc 06:33 hr:mn 55 °F 70 Bc 07:23 hr:mn 55 °F 100 Bc 08:00 hr:mn 55 °F Free Fluid (0.8%) 2 / 250 mL in 2 hrs At 80 °F and 45 deg inclination Sedimentation: None Fluid Loss S/N: 14-08 #1 API/Calculated Fluid Loss 32.00 mL 16.00 mL in 30 mins at 50 °F Non Stirred Fluid Loss apparatus was utilized Mud Balance S/N: 90308 Slurry Density Verified by Pressurized Fluid Balance: 13.50 lb/gal Comments All slurries prepared and tested in accordance with API RP 10B-2 unless otherwise noted Time to Add Solids : 00:12 mn:sc Vortex Quality: good/visible Thickening Time Thickening Time 1: motor on 60 minutes, motor off 20 minutes; consistency spike = 13 Bc Instrument: 7222-2 Schlumberger Sample Period: 5 seconds Prudhoe Bay Well Services Laboratory Telephone: +1 907-659-6155 Facsimilie: +1 907-659-9221 Customer: ASRC Well ID: Core Hole 2 Engineer:Mitch Rice 30 Bc : 4:08:15 File Name: AKA-2025-102-13.5ppg Low Rheo D500-PlugToAbandon-Field Blend-v2-cell2.tst Density: 13.5 50 Bc : 6:33:35 Additives: G+10%D163+1.1%D079+.2gpsD047+.06gpsD185A+.6gpsD500+.4gpsD186 70 Bc : 7:23:00 Test Started: 10/25/2025 2:39:36 PM BHCT:50 100 Bc : 8:00:55 Test Stopped: 10/25/2025 10:40:32 PM BHST: 45 Rig Name: Rigless Job Type: PlugToAbandon Field Blend Printed: 6:46:13 AM 10/26/2025 0:00 2:00 4:00 6:00 8:00 10:00 Time (HH:MM) 0 40 80 120 160 200 240 280 320 360 400 Temperature (°F)0 2500 5000 7500 10000 12500 15000 Pressure (psi)0 10 20 30 40 50 60 70 80 90 100 Consistency (Bc) Instrument: PAK SGSA Current Compressive Strength: 1098 psi Schlumberger Sampling Period: 10 seconds Final Compressive Strength: 1098 psi at 115:37:50 Prudhoe Bay Well Services Laboratory Compressive strength type A (less than 14 lb/gal)Telephone: +1 907 659 6155 Facsimile: +1 907 659 9221 Location: Core Hole 2 50 psi: 12:57:50File Name: AKA-2025-102-13.5ppg Low Rheo D500-PlugToAbandon-Field Blend-SGSA.tst Customer: ASRC Energy Services 500 psi: 53:12:50 Supervisor: Mitch Rice 1000 psi: 103:41:20 Test Started: 10/26/2025 10:55:23 AM Density: 13.5 lbm/gal 2000 psi: N/A Test Stopped: 10/31/2025 6:33:20 AM System: G+10%D163+1.1%D079+.2gpsD047+.06gpsD185A+.6gpsD500+.4gpsD186 BHCT: 50 degF 12 hr: 44 psi Printed: 10/31/2025 6:33:52 AM BHST: 45 degF 24 hr: 157 psi Job Type: Plug To Abandon Field Blend Page 1 Rig Name: Rigless Static Gel Stregnth (100 lbf/100ft2): 2:03:30 Static Gel Strength (500 lbf/100ft2): 2:58:10 0 30 60 90 120 150 Time (HH) 0 40 80 120 160 200 240 280 320 360 400 Temperature (°F)0 2 4 6 8 10 12 14 16 18 20 Transit Time (microsec/in)0 500 1000 1500 2000 Compressive Strength (psi)0 500 1000 1500 2000 Static Gel Strength (lb/100ft2)0 1 2 3 4 5 6 Acoustic Impedance (Mrayls) Appendix H: Cement Modeling Results Pump Schedule ECD Friction Pressure vs. Flow Rate Appendix I: Cement Pumping Diagram THIS PAGE INTENTIONALLY LEFT BLANK Appendix J: Proposed Abandonment Marker 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Houston Core Hole 2 Yes No 9. Property Designation (Lease Number): 10. Field: Exploratory N/A N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 1142 1142 509 509 100 N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 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: Adrienne McVey Contact Email:amcvey@asrcenergy.com Contact Phone: 907-980-8623 Authorized Title: VP of Drilling, Projects and Engineering 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 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 100-009 3900 C Street, Suite 701, Anchorage, AK 99503 50-009-10023-00-00 ASRC Energy Services Alaska, Inc Length Size Proposed Pools: N/A TVD Burst N/A MD 19' 217' 19'2-7/8" 1.81"190' 19' Perforation Depth MD (ft): 217' N/A N/A Perforation Depth TVD (ft): 11/13/2025 N/A approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Adrienne McVey Contact Email:amcvey@asrcenergy.com Contact Phone: 907-980-8623 le: VP of Drilling, Projoects and Engineering certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date: 15. Well Status after proposed work: OIL WINJ WDSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval:Date: esentative: Date for Operations:11/13/2025 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSSV Type:Packers and SSSV MD (ft) and TVD (ft): N/A Tubing MD (ft): N/A Tubing Grade: N/A Tubing Size: N/AN/A Perforation Depth TVD (ft):epth MD (ft): on 217'217'1.81"190'ate 19'19'2-7/8"19'e or al CollapseBurstTVDMDSizeLengthg Junk (MD): N/AN/A Plugs (MD): 100 MPSP (psi):Effective Depth TVD: 509 Effective Depth MD: 509 Total Depth TVD (ft): 1142 D (ft): 1142 PRESENT WELL CONDITION SUMMARY 10. Field: Exploratory N/A N/A Current Pools:Proposed Pools:esignation (Lease Number): 8. Well Name and Number: Houston Core Hole 2 g: ation or Conservation Order governs well spacing in this pool?N/A Yes Noquire a spacing exception due to property boundaries? 5. Permit to Drill Number: 6. API Number: 100-009 50-009-10023-00-00 4. Current Well Class: Exploratory Development Stratigraphic Service , Suite 701, Anchorage, AK 99503 ame: Services Alaska, Inc quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: r Casing ___________________ Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-692 By Grace Christianson at 9:15 am, Nov 12, 2025 TS 11/12/25BJM 11/12/25 Submit final detailed to procedure to AOGCC and gain approval before RIH with workstring. See variances and additional conditions in section 1.0 and 1.1. 10-407 Provide 24 hrs notice for AOGCC to witness cement in well after cutoff, before and after any top job, and marker pipe. Provide 10 days notice for AOGCC to witness final site clearance JLC 11/12/2025 11/12/25 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 11 November 11, 2025 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request to Change Approved Program to Plug & Abandon Houston Core Hole 2 Well (PTD: 100-009 / API: 50-009-10023-00-00) Dear Commissioners, ASRC Energy Services Alaska, Inc (AES-AK) hereby requests sundry approval to change the approved program for permanently plugging and abandoning the Houston Core Hole 2 well. The original sundry number is 325-466. Please contact me at 907-339-7410 or Adrienne McVey at 907-980-8623 with any questions. Sincerely, Doug Cismoski Vice President of Drilling, Projects, and Engineering ASRC Consulting & Environmental Services, LLC OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 11 1.0 Well Summary Houston Core Hole 2 Houston Core Hole 2 is planned for plug and abandonment (P&A) as part of the State of Alaska AOGCC Orphan Well Program. The P&A work will be conducted by AES-AK as Operator, on behalf of the State of Alaska AOGCC. Cementing operations on Houston Core Hole 2 are scheduled to begin November 2025. General Well Information Status: Orphan Well See attached Current Wellbore Schematic (Figure 1) for details. A slip-on wellhead was installed on the 2-7/8 pipe on 02/26/2025. The 2-7/8 pipe is cemented or grouted; its assumed to be a collar installed before diamond core drilling commenced, with a shoe depth of 19. On 04/22/2025, an attempted Slickline drift run with a 2.24 lead impression block (LIB) identified a previously unknown 1.81 OD pipe stub, likely EX core casing, at 27 SLM. Slickline drifted inside the pipe stub to a tag depth of 511 SLM with a 1 sample bailer (returned clay) and a 1.2 LIB. Slickline was unable to enter the stub with a 1.31 OD swage. On 08/18/2025, E-Line diagnostic work was completed per Sundry 325-466. The Casing Collar Locator log showed the end of EX core casing at 217 ELM, with 292 of open hole below, down to a tag depth/top of fill at 509 ELM. Since the EX core casing did not extend all the way down to tag depth, E-Line rigged down after completing the CCL, and did not set a miniature bridge plug. Base of Fresh Water: Estimated at 440 MD / 440 TVD Reservoir Pressure: The Core Hole 2 lithology/core log notes brackish water and gas while coring from 545 to 697 MD, as well as a not measurable gas channel at 775 MD. Drilling records from the immediate offset Rosetta 1 well (separated by ~100) noted the indication of coal, gas or oil across the same interval and down to ~2115 MD. During coiled tubing P&A operations on Rosetta 1 in July 2025, Rosetta 1s shut- in wellhead pressure was 100 psi initially, and 0 psi after circulating the well over to a full column of fresh water. MASP: The Maximum Anticipated Surface Pressure is 100 psi, which is Core Hole 2s maximum observed stabilized shut-in wellhead pressure since installing the wellhead on 02/26/2025. More recently, the stabilized shut-in wellhead pressure has been approximately 70 psi. Rig for P&A Ops: ½ Schedule 40 A106B seamless black steel pipe with Class 3000 forged couplings, conveyed with crane, lifting slings, and modified polished rod clamps Wellhead: Vault 2-7/8 SOW x 4-1/16 5M BOP Configuration: N/A BOP Test Pressure: N/A OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 3 of 11 Regulatory Variance / Waiver Requests The proposed P&A for Core Hole 2 does not include an attempt to clean out past the E-Line tag depth of 509. The tag depth is in open hole, 69 below the estimated base of fresh water at 440, and 36 above the first indication of gas at 545 noted in the core log. Placing a cement plug from 509 surface will isolate the base of fresh water from hydrocarbon-bearing strata without attempting to clean out deeper, which would present a risk to successfully completing the P&A. Therefore, a variance to the requirements of 20 AAC 25.112 (a) (3) is requested. Note this is the same variance requested in the original Approved Sundry 325-466. The proposed P&A plan is to run in with the ½ workstring to 500, circulate cement to surface, and leave the workstring in the well, rather than attempt to place 2 separate cement plugs. See attached Proposed Wellbore Schematic (Figure 2). Due to the exceptionally small wellbore volume (~1 bbl), casing and open hole sizes (assume 1.5 ID from 27 509), and minimal annular clearance around the workstring, placing 2 separate plugs and/or attempting to retrieve the workstring after pumping cement would present a risk to successfully completing the P&A. Therefore, a variance to the requirements of 20 AAC 25.112 (g) is requested. A variance is requested to 20 AAC 25.120. Given the exceptionally small size of the largest string to surface (2.875), rather than install a marker plate, it is proposed to install over the 2-7/8 casing stub a 3.5 OD sleeve with the required identification information bead welded to the side of it. The sleeve will have a 1/4 plate welded to the top of it and the assembly will be welded to the 2-7/8 pipe body. See attached Proposed Abandonment Marker (Figure 3). Due to low and stable shut-in wellhead pressure, and low flow potential of mainly brackish water with small amounts of gas, a variance to the requirements of 20 AAC 25.286 is requested. Mitigations, and plans for gas and water diversion, are as follows: (see Figure 4, Surface Equipment Schematic) 3 riser will be flanged up to the wellhead, with a sucker rod stripper screwed onto the top of the riser to provide a dynamic seal. It will likely be necessary to open hole when initially running in, to manually work through the top of the EX casing stub at 27 and/or until the workstring weight is sufficient to overcome the stripper rubber friction. o Below the sucker rod stripper will be gas and water diversion tees, to divert gas and water flow away from the wellhead. o Water and gas diversion tees will be equipped with (2) 3 ball valves, an active valve and a master to be used in emergency only. o Water flow from the tee will be diverted into the Rosetta 1 cellar. Cement returns will also be taken from the tee into the Rosetta 1 cellar. o An explosion-proof vacuum will be used at the end of the gas diversion tee, to pull gas away from the wellhead. o LELs will be monitored at the wellhead when making up the workstring connections. Condition of approval: Safety joint with safety valve must be available with correct threads to stab into workstring in the event of flow coming from inside the workstring. -bjm Due to extremely small wellbore ID and small well volume, the plan to pump a single cement plug to fill the entire wellbore is deemed to have the best chance of successfully plugging the well. Variance is approved. -bjm Proposed plan will place cement from PBTD, 69 ft below base of fresh water and cement across entire freshwater interval to surface. Variance is approved. -bjm Variance conditionally approved. Top plate must have some indication that the well information is located on the side of the pipe. -bjm Variance conditionally approved: OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 4 of 11 1.1 P&A Procedure Houston Core Hole 2 The cementing plan in Approved Sundry 325-466 was to run coiled HDPE pipe into the well with a grouting unit and circulate cement to surface. However, due to concerns about HDPE pressure rating, tensile strength, and memory of the coiled HDPE when trying to enter the top of the EX casing stub at 27, the updated plan is to use ½ Schedule 40 A106B seamless black steel pipe as the workstring, with Class 3000 forged couplings. The couplings do present a packoff risk as cement is circulated into the well. To reduce this risk, 20 joints of pipe will be pre-welded together into 60 lengths. This will result in only 8 couplings along the 500 workstring. The deepest coupling will be at 440 (base of fresh water). Eliminating couplings below base of fresh water provides the best chance of getting cement up to at least this height. 2 couplings (at 140 and 260) will be run without Loctite. These will serve as contingency back- off/circulation points. In the event of packoff/lost returns, the contingency is to back off at one of these connections, then circulate in a surface plug from that depth. Assuming the packoff were to occur at or above the deepest coupling at 440, this contingency plan still isolates the base of fresh water from the flowing zone below it and allows placement of a surface plug. The couplings will be beveled (top and bottom) to ease entry into the EX casing stub. Cementing Procedure 1. Flange up 3 riser with sucker rod stripper to the 4-1/16 dry hole tree. 2. RIH with workstring to 500. Divert water and gas flow via tees on riser while RIH. Take water returns to Rosetta 1 cellar. Monitor LELs in pipe make-up area. Each ~60 piece of pipe will have one coupling pre-installed. Apply Blue LocTite to threads except for the couplings at 140 and 260. See Figure 2, Proposed Wellbore Schematic, for coupling depth details. Make-up torque: 30 ft-lb max, or 2-3 turns from finger-tight. 3. Once at depth, connect grout pump to workstring. See Figure 5, Cement Pumping Diagram, for details. Plan to use Geo-Loop Model YP2 2-tank grout pump. Install ½ ball valve (1/2 NPT threads) at top of workstring to isolate from pump. Pump provider will provide hose and fittings to cross over from pump to ½ NPT. 4. Shut in gas diversion tee. Will take cement returns from water diversion tee. 5. Break circulation at 0.2 bpm/8 gpm with fresh water, taking returns from water diversion tee to Rosetta 1 cellar. Check for leaks. Record circulating pressure. 6. Once circulation path is established, add red dye to fresh water in the grout pump mix tank. Circulate red dye to surface, noting volume pumped (mix tank strap) and volume returned (5-gallon buckets with 1-gallon strap marks), to verify wellbore volume. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 5 of 11 7. Once red dye is circulated back to surface, shut in returns. Record SIWHP. Note: nearby offset Rosetta 1 SIWHP after circulating to a full column of water was 0 psi. 8. Mix ~2.5 bbl of 13.5 ppg low rheology gas-tight cement. Mix in grout pump mixing tanks. Can supplement mix volume by mixing some of the slurry in external cement mixer or Poly-Tote, then pouring into grout pump mixing tanks. Estimated wellbore volume = 1 bbl. Ordered enough cement product to mix approximately 5 bbl. Plan to mix and pump 2.5 bbl initially (increase this volume if indicated by red dye circulation data), leaving half left over for a second cement job in the event cement is not circulated to surface during the initial job. See CONTINGENCY #2 (Step 11) below. Dry additives are already mixed into blend. Liquid additives are in 5-gallon buckets. Yield is 1.88 ft3/sack of blend. Mix water requirement is 8.842 gal/sack of blend. Approximately 67 gallons mix water required. Rheologies tested at 50F, 60F, and 80F. Plan mix water temperature accordingly. Grout pump provider is providing a circulation pump that will enable confirming slurry temperature before pumping downhole. 9. Pump ~2.5 bbl of cement down workstring, taking returns from water diversion tee. Wellbore volume ~1 bbl (will confirm with red dye before pumping cement) Plan to hold back pressure while circulating cement to avoid influx contamination of cement until cement provides enough hydrostatic to balance the reservoir. Maintain 1:1 returns throughout the operation by manipulating return choke/throttle valve. o Maintain constant casing pressure until cement reaches muleshoe (8 gallons). Duration is approximately 1 minute at 8.4 gpm/0.2 bpm. o Maintain constant pump pressure while filling annulus with cement (36 gallons). Duration is approximately 4.5 minutes. o Maintain constant pump pressure while taking cement returns to surface (~61 gallons excess cement planned). Duration is approximately 7.5 minutes. 1:1 returns tracking is crucial. Take returns to 5-gallon buckets with 1-gallon strap marks. Record volume pumped, volume returned, pump pressure, wellbore pressure throughout the job. Pump until mix tanks are empty. Once mix tanks are empty, trap pressure on the well by shutting in the 3 ball valve on the water diversion tee, and shutting in the ½ ball valve installed on the top of the work string. 10. CONTINGENCY #1: In the event of packoff/lost returns, back off at non-Loctite connection (140 and 260), then circulate in a surface plug from that depth. Assuming the packoff were to occur at or above the deepest coupling at 440, this contingency plan still isolates the base of fresh water from the flowing zone below it and allows placement of a surface plug. 11. CONTINGENCY #2: in the event circulation cannot be established from the contingency back- off/circulation point, retrieve the workstring above the backoff point to surface. Prepare to perform a second cement job to cement the well to surface above the workstring stub. trap pressure Trapping pressure may not be necessary. -bjm If there's a packoff, may want to reduce pump rate with constant csg pres. -bjm OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 6 of 11 12. Disconnect and wash up grout pump. 13. Leave workstring in hole. It will be cut off along with the wellhead. 14. Wait on cement. Wellhead Removal 1. Notify AOGCC Inspector 24 hours in advance to witness wellhead post cut-off, before and after cement top job. 2. Remove wellhead and cellar. Complete excavation as needed around the well to allow cutting the 2- 7/8 pipe to a minimum depth of 3 below ground level for final P&A. 3. Top off 2-7/8 pipe with cement as needed. Photograph casing and cement and include in 10-407. 4. Weld 3.5 OD sleeve onto the 2-7/8 casing stub with the following information: (see Figure 3, Proposed Abandonment Marker) State of Alaska AOGCC PTD 100-009 Houston Core Hole 2 API 50-009-10023-00-00 5. Perform post-P&A methane monitoring and record results for reporting purposes. 6. Backfill the excavated hole, grade to final elevation, remove any debris and clear location. Photo- document final site clearance and include with 10-407 submittal. Notify AOGCC Inspector 24 hours in advance to perform final site clearance inspection. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 7 of 11 Figure 1. Current Wellbore Schematic OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 8 of 11 Figure 2. Proposed Wellbore Schematic OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 9 of 11 Figure 3. Proposed Abandonment Marker 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:N/A 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: N/A N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 1,142' 1,142'N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): No packer or SSSV No packer or SSSV 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: amcvey@asrcenergy.com Contact Phone: 907-980-8623 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 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Length AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 100-009 3900 C Street, Suite 701, Anchorage, AK 99503 50-009-10023-00-00 ASRC Energy Services Alaska, Inc. Houston Core Hole 2 Size Proposed Pools: Unknown Unknown PRESENT WELL CONDITION SUMMARY Exploratory None TVD Burst None MD 19' 511' 2-7/8" 1.81"484' 19' Perforation Depth MD (ft): None None Tubing Size: VP of Drilling, Projects and Engineering Adrienne McVey 100 N/A 8/18/2025 None m n P s 1 6 5 6 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 Cismoski, Doug Digitally signed by Cismoski, Doug Date: 2025.08.07 16:31:16 -05'00' 325-466 By Grace Christianson at 1:56 pm, Aug 07, 2025 A.Dewhurst 12AUG25 10-407 DSR-8/14/25 X BJM 8/14/25 Review results of wireline work with AOGCC and obtain approval before cementing. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.15 08:33:24 -08'00'08/15/25 RBDMS JSB 081825 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 10 August 7, 2025 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Request to Plug & Abandon Houston Core Hole 2 (PTD: 100-009) Dear Commissioners, ASRC Energy Services Alaska, Inc (AES-AK) hereby requests sundry approval to permanently plug and abandon the Houston Core Hole 2 well. Please contact me at 907-339-7410 or Adrienne McVey at 907-980-8623 with any questions. Sincerely, Doug Cismoski VP of Drilling, Projects and Engineering ASRC Consulting & Environmental Services, LLC Sincerely, DCi ki OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 10 1.0 Well Summary – Houston Core Hole 2 Houston Core Hole 2 is planned for plug and abandonment (P&A) as part of the State of Alaska AOGCC Orphan Well Program. The P&A work will be conducted by AES-AK as Operator, on behalf of the AOGCC. Wireline operations on Core Hole 2 are scheduled to begin in the third quarter (3Q) of 2025. General Well Information Status: Orphan Well – See attached ‘Current Wellbore Schematic’ (Figure 1.1-1) for details. A slip-on wellhead (Figure 1.1-2) was installed on the 2-7/8” pipe on 02/26/2025. The 2-7/8” pipe is cemented or grouted; it’s assumed to be a “collar” installed before diamond core drilling commenced, with a shoe depth of 19’. On 04/22/2025, an attempted Slickline drift run with a 2.24” lead impression block (LIB) identified a previously unknown 1.81” OD pipe stub, likely EX core casing, at 27’ SLM. Slickline drifted inside the pipe stub to a tag depth of 511’ SLM with a 1” sample bailer (returned clay) and a 1.2” LIB. Slickline was unable to enter the stub with a 1.31” OD swage. Base of Fresh Water: Estimated at 440’ MD / 440’ TVD Reservoir Pressure: The Core Hole 2 lithology/core log notesbrackish water and gas while coring from 545’ to 697’ MD, as well as a “not measurable” gas channel at 775’ MD. Drilling records from the immediate offset Rosetta 1 well (separated by ~100’) noted the indication of coal, gas or oil across the same interval and down to ~2115’ MD. During coiled tubing P&A operations on Rosetta 1 in July 2025, Rosetta 1’s shut- in wellhead pressure was 100 psi initially, and 0 psi after circulating the well over to a full column of fresh water. MASP: The Maximum Anticipated Surface Pressure is 100 psi, which is Core Hole 2’s observed stabilized shut-in wellhead pressure since installing the wellhead on 02/26/2025. Rig for P&A Ops: E-line; Coiled HDPE pipe Wellhead: Vault 2-7/8” SOW x 4-1/16” 5M (see Figure 1.1-2 for details). OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 3 of 10 Regulatory Variance / Waiver Requests The proposed P&A for Core Hole 2 does not include an attempt to clean out past the Slickline tag depth of 511’, which is assumed to be inside the uncemented 1.81” OD EX core casing stub. The tag depth is 71’ below the estimated base of fresh water at 440’, and 34’ above the first indication of gas at 545’ noted in the core log. E-line work will be conducted prior to cementing and will determine whether the very small annulus behind the EX core casing stub is packed off, creating a seal/barrier behind the stub that isolates the salt water and gas zone from the base of fresh water. If not, cement will be squeezed behind the EX core casing stub to create this seal. In either case, isolating the base of fresh water from hydrocarbon-bearing strata can be accomplished without attempting to clean out deeper than 511’, which would present a risk to successfully completing the P&A. Therefore, a variance to the requirements of 20 AAC 25.112 (a) (3) is requested. Additionally, the same variance to 20 AAC 25.287 (d)(2) that was granted for April 2025 Slickline work is requested. That variance is summarized as follows: due to low and stable shut-in wellhead pressure, and low flow potential of mainly brackish water with small amounts of gas, propose to test pressure control equipment (PCE) by opening the master valve to expose the PCE to wellhead pressure, and monitoring for leaks before running in hole. The same mitigation will be in place as for April 2025 Slickline work: a bleed hose will be attached to the wellhead or lubricator with the discharge run to a tank so in the event of a leak, the flow can be diverted away from the wellhead. 1.1 Plug and Abandonment Procedure – Houston Core Hole 2 Pre-E-Line Work: 1. Conduct pre-wireline bleed-off test. Note details in Daily Operations Report. Previous bleed-off test details: stabilized shut-in wellhead pressure = 100 psi. When bleeding off the initial gas cap (takes 5-6 minutes through needle valve), up to 30% LEL observed with the sensor held directly in the flow stream. After the gas cap is bled off, fluid is mostly saline water with occasional gas bubbles, and pressure stabilizes at 15 psi. Estimated water flow rate is 34 bpd, based on these bleeds. This is the same flow rate observed in 1971. E-Line Diagnostic Work: 1. Move in and rig up Electric Line unit and equipment. 2.Test PCE by opening the master valve and monitoring for leaks before RIH. Request variance to 20 AAC 25.287(d)(2), same as for April 2025 Slickline work. 3. Run drift & tag/CCL. 3.1.Objective is to find end of 1.81" EX core casing (expect to be at or below tag depth). 3.2.If CCL confirms that EX core casing extends below tag depth, proceed to Step 4. Variance to 20 AAC 25.287(d)(2) is approved. Reference previous emails in the wellfile dated March 12-19, 2025. -bjm OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 4 of 10 4.Set miniature bridge plug just above tag depth. Contingency: dump bail a single load of cement on top of bridge plug. 5. Conduct negative pressure test/no flow test to check if bridge plug shut off flow. 6.If bridge plug did not shut off flow:jet cut EX core casing just above bridge plug. 7. RDMO wireline. Cement Plugging If the bridge plug set inside the EX core casing shut off flow to surface: this indicates the very small annulus behind the EX core casing is packed off, creating a seal/barrier behind the casing that isolates the salt water and gas zone at 545’ – 697’ from the base of fresh water at 440’, and therefore squeezing cement behind pipe is not required. Also, since the system is static, no pressure containment equipment is required. See Figure 1.1-3. If the bridge plug set inside the EX core casing did not shut off flow to surface: this indicates the very small annulus behind the EX core casing is the flow path from the salt water and gas zone at 545’ – 697’ to surface. Therefore, attempting to squeeze cement behind the EX core casing is required (communication with annular space created by jet cut in Step 6 of E-Line Diagnostic Work procedure), and pressure containment equipment (modified wireline valves or similar) is required to ensure a static system when pumping the cement job. See Figure 1.1-4. In either case, the proposed cementing procedure is essentially the same. The coiled HDPE pipe may either be retrieved back to surface, or cut off after running to depth, fittings installed to cross over to a cement pump, and left in hole after cementing. 1. RIH to bridge plug with coiled HDPE pipe (See Figure 1.1.5 as an example; this is a water well driller’s grouting unit with 1” HDPE pipe, and a mixing tub and pump). 2. Circulate cement from top of bridge plug to surface. Total well volume = 1.2 bbl Pipe displacement = 0.2 bbl Cement volume = 1.0 bbl Post-Cementing Work 1. Remove wellhead and well cellar. Complete excavation as needed around the well to allow cutting the 2-7/8” pipe to a minimum depth of 3’ below ground level for final P&A. Notify AOGCC 24 hours prior to final excavation and top-off of surface cement to allow witnessing of the operations. 2. Top-off 2-7/8” pipe with cement as needed. Photograph casing and cement. Bridge plug should be set above top of hydrocarbon zones starting at 545'. -bjm If this contingency is required, submit detailed procedure and pressure containment equipment diagram to AOGCC and obtain approval before proceding. -bjm Discuss results of e-line work with AOGCC and obtain approval before cementing. -bjm OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 5 of 10 3. Weld marker plate on the outermost casing that meets requirements of 20 AAC 25.120 and includes the below information bead-welded directly to the marker plate. Photograph marker plate. State of Alaska AOGCC PTD 100-009 Core Test Hole 2 API 50-009-10023-00-00 4. Perform post-P&A methane monitoring and record results for reporting purposes. 5. Backfill the excavated hole and grade the location to final agreed condition. Remove any remaining debris from the location and dispose of waste materials as required. 6. Notify AOGCC with 24 hours advance notice to perform final site clearance inspection. 7. Include photos of the well before and after cut-off, condition of cement inside the wellbore, installed marker plate, and ground surface after backfill in the 10-407 submission. Houston Core Hole 2. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 6 of 10 Figure 1.1-1. Current Wellbore Schematic OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 7 of 10 Figure 1.1-2. Wellhead Configuration OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 8 of 10 Figure 1.1-3. Proposed P&A Wellbore Schematic, Scenario 1 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 9 of 10 Figure 1.1-4. Proposed P&A Wellbore Schematic, Scenario 2 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 10 of 10 Figure 1.1-5. Coiled HDPE Example (Grouting Unit) 1 From:McVey, Adrienne <amcvey@asrcenergy.com> Sent:Tuesday, August 12, 2025 1:31 PM To:McLellan, Bryan J (OGC) Subject:RE: Houston Core Hole 2 (PTD 100-009) Contingency procedure Bryan, If the CCL indicates open hole below the end of the EX core casing, RDMO wireline. Plan for subsequent cement plugging: x RIH to just above E-line tag depth with coiled HDPE pipe. x Circulate cement to surface. x Perform slow, low-pressure hesitation cement squeeze. Stage up from 25 psi to 150 psi. Cement design details will be worked with Fox, but will include high spurt loss, high 30-minute Ʋuid loss (and thick Ʊlter cake), adequate thickening time, and a gas-blocking additive. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, August 12, 2025 9:16 AM To: McVey, Adrienne <amcvey@asrcenergy.com> Subject: Houston Core Hole 2 (PTD 100-009) Contingency procedure Adrienne, Step 3.2 says to proceed to step 4 and set a bridge plug if CCL indicates casing extends below TD tag. What if TD is in open hole? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 1 From:McVey, Adrienne <amcvey@asrcenergy.com> Sent:Tuesday, August 12, 2025 10:33 AM To:McLellan, Bryan J (OGC) Subject:RE: Houston Core Hole 2 (PTD 100-009) sundry question - cement squeeze Bryan, Given the assumed 19’ depth of the 2-7/8” shoe, we won’t be able to apply much surface pressure initially. Our plan is to perform a slow, low-pressure hesitation squeeze, staging up from 25 psi to150 psi, e Ưectively “stress caging” the shallow shoe. We will work cement design details with Fox, but will want a high spurt loss, high 30- minute Ʋuid loss (and thick Ʊlter cake), adequate thickening time, and a gas-blocking additive. Thanks, Adrienne From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, August 8, 2025 3:45 PM To: McVey, Adrienne <amcvey@asrcenergy.com> Subject: Houston Core Hole 2 (PTD 100-009) sundry question - cement squeeze Adrienne, If we need to squeeze cement outside the cut in the 1.81” tubing, how much volume and what max pressure limits to you plan? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Wednesday, March 19, 2025 1:45 PM To:McVey, Adrienne Cc:Danny Kara; Brandenburg, Timothy; Dial, Amanda Subject:RE: Rosetta 1 and Core Hole 2 Slickline Work Adrienne, ASRC has approval to perform this wireline work as proposed in the emails below as part of approved sundries 324-521for Rosetta 1 (PTD 100-003) and 324-411 for Core Hole 2 (PTD 100-009). A variance to 20 AAC 25.287(d)(2) is approved for the slickline work described below for both wells under 20 AAC 25.287(f) on the condition that a bleed hose is attached to the wellhead or lubricator with the discharge run to a tank so in the event of a leak, the flow can be diverted away from the wellhead. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Wednesday, March 19, 2025 12:05 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Subject: RE: Rosetta 1 and Core Hole 2 Slickline Work Bryan, If the lubricator begins leaking with wireline in the hole, our first action will be to open the bleed hose attached to the PCE and relieve the pressure from the leak into the bleed tank. We would likely continue the wireline run, given the low pressure and low flow potential of mainly salt water you mentioned. In the unlikely event we deemed it necessary to isolate the leak, we’ll have the option of either closing the WLV to evaluate or repair the leak, or, given the shallow run depths (~1700’ for Rosetta 1, ~600’ for Core Hole 2), pulling tools back to surface and closing the master valve. Thanks, Adrienne McVey 2 ASRC Energy Services, LLC 907-980-8623 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, March 17, 2025 4:32 PM To: McVey, Adrienne <amcvey@asrcenergy.com> Cc: Danny Kara <danny.kara@outlook.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Subject: RE: Rosetta 1 and Core Hole 2 Slickline Work Adrienne, This will be a variance request to 20 AAC 25.287(d)(2) which can be authorized under 20 AAC 25.287(f) if the proposal provides equally effective means of well control. I believe that given the shallow, low pressure, low flow potential of mainly salt water and small amounts of gas, that your plan will provide an equally effective means of well control, but for the record, please send me ASRC’s contingency procedure to explain what will be the response if the lubricator begins leaking with wireline in the hole. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Thursday, March 13, 2025 3:46 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Subject: Re: Rosetta 1 and Core Hole 2 Slickline Work Bryan, As a follow-up to our phone conversation, I wanted to provide the following additional information: 1. The slickline PCE will be equipped with a bleed hose. We will have a tank on location suitable for bleeding fluid from the lubricator. 2. For the CTU work, we will be equipped to test BOPE per the approved Sundries. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Thanks, Adrienne Get Outlook for iOS From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Thursday, March 13, 2025 1:51:09 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Subject: RE: Rosetta 1 and Core Hole 2 Slickline Work Bryan, 1. I don’t think it is feasible for a leak to develop that would prevent manually closing the master valve and/or wireline valve. A bit more detail on these wells to establish a worst-credible case leak: a. Rosetta 1: Prior to establishing containment by installing the wellhead on 2/28/25, Rosetta 1 was leaking 12 bpd of salt water to the environment. We didn’t collect bleed-off or build-up rate data for this well after installing the wellhead. But given it has a lower SIWHP and lower water flow rate (with 0% LEL) than Core Hole 2, for which we do have that data (see below), I do not think Rosetta 1 is capable of a lubricator leak that would prevent manually closing the master valve and/or wireline valve. WORST CASE LEAK: salt water at ≤15 psi. b. Core Hole 2: as mentioned below, we bled off the SIWHP into a 5-gallon bucket several times during the wellhead installation work to observe. The 100 psi, which is initially mostly gas with some salt water, bleeds off to 15 psi and mostly salt water within 5-6 minutes. Continued bleeding after this point yields mostly salt water with occasional gas bubbles, and a constant 15 psi pressure. In other words, if the lubricator did leak, after initially leaking a bit of gas, it would quickly de-pressure itself from ~100 psi and then leak salt water at 15 psi. Such a leak would not prevent manually closing the master valve and/or wireline valve. WORST CASE LEAK: salt water at 15 psi. 2. Given the above information, I do not think that waiting for the lubricator to fill/pressure up to 70 or 100 psi is necessary. I would propose a 10-minute observation period after opening the master valve before running in hole. These slickline runs will not change downhole conditions. Our highest wellhead pressures are anticipated to be at rig up. Thanks, Adrienne From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, March 12, 2025 2:15 PM To: McVey, Adrienne <amcvey@asrcenergy.com> Cc: Danny Kara <danny.kara@outlook.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Subject: RE: Rosetta 1 and Core Hole 2 Slickline Work 4 Adrienne, Regarding the second question… 1. What is the contingency plan if there is a leak in the lubricator that prevents a person from accessing the manual master valve to close it? Will a bleed line be rigged up with a remote valve or choke to divert the flow to a tank, thereby relieving pressure so a person can access the valves? 2. Will you plan to wait until the lubricator fills up and pressures up to the max SITP before running tools below the tree? It might take a while, especially in Rosetta 1 with the slow flow rate. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Wednesday, March 12, 2025 11:47 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com> Subject: Rosetta 1 and Core Hole 2 Slickline Work Bryan, As discussed last week, I’m lining up a slickline unit and logging tools to perform the following:  Rosetta 1: Drift and tag. Run Memory CBL to evaluate cement behind 7” casing (possibly add temperature log to CBL run; Bryan to advise)  Core Hole 2: Drift and tag. Run Memory CCL to locate 2-7/8” shoe (possibly add temperature log to CCL run; Bryan to advise) I have 2 questions/requests: 1. Although we now propose to perform the memory logs pre-CTU, I believe this work is covered by the existing approved Applications for Sundry Approvals (324-521 and 324-411). Is that correct? 2. For testing the slickline pressure control equipment: 20 AAC 25.287 (d)(2) states “after each installation of the well control equipment, that equipment must be pressure-tested, before wellbore entry, to the ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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. 5 maximum potential surface pressure to which that equipment may be subjected.” I am requesting to conduct this test by opening the master valve to expose the pressure control equipment to wellhead pressure, and confirming there are no visible or audible leaks, before running in hole. The technical justification for this request is that both wells have low and well-defined MPSP with minimal gas: a. Rosetta 1 shut-in wellhead pressure/MPSP = 70 psi. SIWHP was most recently verified on 3/9/25 and has remained constant since we installed the wellhead on 2/28/25. Prior to wellhead installation, the well was leaking approximately 12 bpd of water and 0% LEL through the pitted hole near the top of the 7” casing. b. Core Hole 2 shut-in wellhead pressure/MPSP = 100 psi. We bled this pressure off several times and observed the following: bleed is initially mostly gas, then mostly water. When bleeding off the initial gas cap (takes 5-6 minutes through a needle valve), up to 30% LEL observed with the sensor held directly in the flow stream. Estimated water flow rate is 34 bpd, based on these bleeds. This is the same flow rate observed in 1971. Please let me know if you would like to set up a call to discuss. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:N/A 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: N/A N/A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 1,142'456 Unknown Casing Collapse Structural Conductor Surface Estimate 5580 psi Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): No packer or SSSV No packer or SSSV 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:Tim Brandenburg Contact Email:tbrandenburg@asrcenergy.com Contact Phone:907-252-3923 Authorized Title: VP of Drilling, Projects and Engineering 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 100-009 3900 C Street, Suite 701, Anchorage, AK 99503 Houston Core Hole 2 50-009-10023-00-00 ASRC Energy Services Alaska, Inc. Will perfs require a spacing exception due to property boundaries? Current Pools: Surface AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 2/25/2025 None MD MPSP (psi):Plugs (MD): Exploratory PRESENT WELL CONDITION SUMMARY Proposed Pools: Subsequent Form Required: Suspension Expiration Date: N/A 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth TVD (ft): None 1,142'Unknown Unknown TVDLength Unknown2-7/8" Authorized Name and Digital Signature with Date: Tubing Size: Estimate 5280 psi Size Burst Unknown Perforation Depth MD (ft): None None P Re- 1 6 5 6 S W N wwwwwnnnn ammmmmmmmmmmmmmmmmmmmm ______ Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Cismoski, Doug Digitally signed by Cismoski, Doug Date: 2025.02.24 16:30:56 -09'00' 325-104 By Gavin Gluyas at 7:54 am, Feb 25, 2025 SFD 2/25/2025BJM 2/25/25 10-407 Yes 2/25/25 Bryan McLellan *&: 2/25/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.25 13:50:37 -09'00' RBDMS JSB 022625 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 3 February 24, 2025 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Change of Approved Program, Houston Core Hole 2 (Approved Sundry 324-411/PTD 100-009) Dear Commissioners, Enclosed is a Sundry 10-403, Change of Approved Program for the wellhead installation on the Houston Core Hole 2 Well. Field work on Core Hole 2 has identified that the tubing is open below a surface cement plug approximately 3’below the top of the tubing. Based on this finding, the plan is to freeze the tubing to form a temporary barrier in the tubing which will allow for the tubing to be cut below the cement plug that is in place at the top of the tubing. Once cut, the originally planned wellhead will be installed on the tubing. Please contact me at 907-339-7410 or Tim Brandenburg at 907-252-3923 with any questions. Sincerely, Doug Cismoski VP of Drilling, Projects and Engineering ASRC Consulting & Environmental Services, LLC Sincerely, OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 3 Background The Core Hole 2 well was hot tapped 40”below the the top of the tubing stub. Upon tapping, it was discovered that the 2-7/8” had 120 psi initial tubing pressure indicating that the surface cement plug was above the hot tap. When bled, the well would bleed gas down to ~15 psi. Now, when bled, the well will bleed gas and then water. The water rate is ~34 bbls per day which is close to what historic rate. The plan is to freeze the tubing below the hot tap valve, cut the tubing above, remove the cement plug and install the wellhead. 1.1 P&A Procedure – Houston Core Hole 2 Pre-Coiled Tubing Work/Wellhead installation –Freeze Tubing 1.Wrap freeze area (1ft of tubing below hot tap hole) with copper tubing & insulate. Note: The 1’ plug inside the 2-7/8” pipe is rated to 3,000 psi differential pressure with a 2:1 safety factor. 2.Mix approx. 10 gallons of bentonite gel & fresh water. 3.Pump 5gal of bentonite gel slurry through hot tap hole into tubing. 4.Begin flowing liquid N2 through copper tubing. 5.Pump small quantities of bentonite gel in 30 min increments until ice plug is realized to ensure gel remains in the freeze area. 6.Once ice plug is realized (positive pressure increase), wait for visible frost lines to form above and below wrapped freeze area. 7.Once frost lines are visible, perform negative test. 8.Open hot tap valve and watch for flow for 30min. 9.If no flow observed, cut tubing above hot tap for correct amount of stickup for wellhead. 10.Weld on wellhead. 11.Install master valve. 12.Fill void above freeze plug with water. 13.Shut master valve. 14.Rig down freeze equipment. 15.Install cellar. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 3 of 3 Figure 1.1-3. Wellhead Configuration 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Tuesday, February 25, 2025 9:23 AM To:Brandenburg, Timothy Cc:Regg, James B (OGC); Dial, Amanda Subject:RE: 10-403 Houston Core Hole 2 (PTD 100-009) - Change Program-Freeze Tim, ASRC has approval to proceed with the freeze operations as outlined in the sundry application submitted yesterday. FYI, sundry number will be 325-104. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Sent: Tuesday, February 25, 2025 6:50 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Dial, Amanda <ADial@asrcenergy.com> Subject: RE: 10-403 Houston Core Hole 2 (PTD 100-009) - Change Program-Freeze Bryan, There will be thermocouples installed on the tubing string and the temperature will be monitored throughout the process. Cudd’s lower limit operating range for freezing is -150 deg F as pipe embrittlement becomes a signiƱcant factor when approaching -250 deg F. Cudd’s operating range for freezing is -100 to -150 deg F. For freezing, Cudd Ʋows N2 through the freeze coil wrapped around the tubing from the bottom up. The plug growth starts from the bottom and propagates up preventing entrapment. Please let me know if you have any other questions. Tim From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, February 24, 2025 5:54 PM To: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> 2 Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Dial, Amanda <ADial@asrcenergy.com> Subject: RE: 10-403 Houston Core Hole 2 (PTD 100-009) - Change Program-Freeze Tim, Does Cudd have a way to control or monitor the pipe temperature so it doesn’t become embrittled? Is there a known embrittlement temperature at which pipe failure becomes a risk? Also, how do they ensure that free water trapped in growing ice can’t lead to pipe burst failure? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Dial, Amanda <ADial@asrcenergy.com> Sent: Monday, February 24, 2025 4:46 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: 10-403 Houston Core Hole 2 (PTD 100-009) - Change Program-Freeze Bryan, Please Įnd aƩached the 10-403 Sundry ApplicaƟon and supporƟng informaƟon for the Change Program required for installing the wellhead on the Houston Core Hole 2 well. Please let us know if you have any questions. Thank you, Amanda Dial Cell: 907-382-0124 ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 1. 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:N/A 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: N/A N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 1,142'456 Unknown Casing Collapse Structural Conductor Surface Estimate 5580 psi Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): No packer or SSSV No packer or SSSV 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:Tim Brandenburg Contact Email:tbrandenburg@asrcenergy.com Contact Phone:907-339-7415 Authorized Title: VP of Drilling, Projects and Engineering 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 Authorized Name and Digital Signature with Date: Tubing Size: Estimate 5280 psi Size 1,142' Unknown Unknown TVD Subsequent Form Required: Suspension Expiration Date: N/A 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): Exploratory PRESENT WELL CONDITION SUMMARY Length Proposed Pools: Surface AOGCC USE ONLY Tubing Grade: Tubing MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 100-009 3900 C Street, Suite 701, Anchorage, AK 99503 Houston Core Hole 2 50-009-10023-00-00 ASRC Energy Services Alaska, Inc. None MD None Unknown Burst 2-7/8"Unknown Perforation Depth MD (ft): None None approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity TestLocation Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name:Tim Brandenburg Contact Email:tbrandenburg@asrcenergy.com Contact Phone:907-339-7415 le:VP of Drilling, Projoectsand Engineering me and ure with Date: certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 15. Well Status after proposed work: OIL WINJ WDSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval:Date: esentative: Datefor Operations: 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSSV Type:Packers and SSSV MD (ft) and TVD (ft): SSSV No packer or SSSV Tubing MD (ft): NoneN/A TubingGrade:TubingSize: None Perforation Depth TVD (ft):epth MD (ft): None on ate Estimate 5580 psEstimate 5280 psiUnknown2-7/8"e Unknown or al CollapseBurstTVDMDSizeLengthg Junk (MD): Unknown Plugs (MD): Surface456 MPSP (psi):Effective Depth TVD: Unknown Effective Depth MD: Unknown Total Depth TVD (ft): 1,142' D (ft): PRESENT WELL CONDITION SUMMARY 10. Field: N/A N/A Current Pools: Exploratory Proposed Pools:signation (Lease Number): 8. Well Name and Number: Houston Core Hole 2 g:N/A ation or Conservation Order governs well spacing in this pool? Yes Noquire a spacing exception due to property boundaries? 5. Permit to Drill Number: 6. API Number: 100-009 50-009-10023-00-00 4. Current Well Class: Exploratory Development Stratigraphic Service Suite 701, Anchorage, AK 99503 ame: Services Alaska, Inc. quest: Abandon Plug PerforationsFracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubi Change Approved Programll Tubing Plugfor Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: r Casing ___________________ Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Cismoski, Doug Digitally signed by Cismoski, Doug Date: 2024.07.16 17:35:22 -08'00' 9/2/24 324-411 By Grace Christianson at 4:15 pm, Jul 17, 2024 Final work procedure to be submitted to AOGCC for approval. Abandon Discuss wellbore conditions and obtain AOGCC approval before commencing cement operations. See additional comments and requirements inserted into the procedure. SFD 7/29/2024 X DSR-7/17/24 XX 10-407 BJM 7/29/24 Waiver to 20 AAC 25.112(a) to leave some of the hydrocarbon bearing interval uncemented if obstruction in wellbore is encountered. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.29 17:22:35 -08'00'07/29/24 RBDMS JSB 073024 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 1 of 9 July 16, 2024 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Mr. Brett Huber, Sr., Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Request to Plug & Abandon Houston Core Hole 2 ( PTD: 100-009 ) Dear Commissioners, ASRC Energy Services Alaska, Inc (AES-AK) hereby requests sundry approval to permanently plug and abandon the Houston Core Hole 2, located in the city of Houston. Please contact me at 907-339-7410 or Tim Brandenburg at 907-339-7415 with any questions. Sincerely, Doug Cismoski VP of Drilling, Projects and Engineering ASRC Consulting & Environmental Services, LLC About ASRC Energy ASRC Energy Services, LLC (AES) is a wholly owned subsidiary of Arctic Slope Regional Corporation (ASRC). With over 2,000 employees and more than 40 years of experience serving Alaska and working in the Arctic, AES has the expertise to handle every phase of an energy project regardless of scale or location. Sincerely, DCi ki OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 9 1.0 Well Summary – Houston Core Hole 2 Houston Core Hole 2 is planned for plug and abandonment (P&A) as part of the State of Alaska AOGCC Orphan Well Program. The P&A work will be conducted by AES-AK as Operator, on behalf of the State of Alaska AOGCC. Operations on Core Hole 2 are scheduled to begin in third quarter (3Q) of 2024. General Well Information Status: Orphan Well – See attached ‘Current Wellbore Schematic’ (Figure 1.1-1) for details. No visible fluid leaks were noted around the well during two separate site visits in June and August 2023, however an active (wet to touch) water/brine ground stain was witnessed on the highway slope ~60’ east of the well. It is unclear if the subsurface condition of Core Hole 2 is contributing to this water flow since the Rosetta 2 well is in the immediate area and displayed water/brine bubbling after excavating to ~4’ below ground level around the well. Gas readings at the Core Hole 2 well were measured at 2% LEL maximum during the June 2023 site visit and 0% during the revisit in August 2023. A wellhead is not in place. Base of Fresh Water: Estimated at 440’ MD / 440’ TVD Reservoir Pressure: No drilling records were found for Core Hole 2, however a lithology/core log does exist with comments on indications of saline water and gas while coring from 545’ to 697’ MD and gas was noted at 775’ MD though it was recorded as not measurable. Records from the immediate offset Rosetta 1 well (separated by ~100’) noted the indication of coal, gas, or oil across the same interval and down to ~2115’ MD. The strata through this interval on Rosetta 1 were said to exist at pore pressures slightly more than normal hydrostatic head and easily over- balanced and contained with a 9.6 ppg mud weight. Abnormal Pressure: As noted above, the intervals with possible hydrocarbons are believed to be at pore pressure slightly above a normal hydrostatic head, with an expected worst case of 9.6 ppg EMW. MASP: The Maximum Anticipated Surface Pressure is calculated as ~456 psi and is based upon a gas gradient to surface from the deepest section reported to possibly contain hydrocarbons at 1,142’ MD/TVD and at a worst-case pore pressure of 9.6 ppg EMW. Rig for P&A Ops: Fox Energy Services Coiled Tubing Unit Wellhead: Vault 2-7/8” Tubing x 4-1/16” 5M (see Figure 1.1-3 for details) BOP Configuration: 4-1/16” 10M BOPE (see Figure 1.1-4 for details). BOP Test Pressure: 1000 psi OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 3 of 9 Regulatory Variance / Waiver Requests As per the ‘Reservoir Pressure’ section, the presence of saline water and gas was noted at various depths from 545’ to 697’ MD and gas was noted at 775’ MD. The proposed P&A for Core Hole 2 assumes the re- entry is only able to reach a depth of ~590’ (150’ below estimated base of fresh water) due to hole conditions and risk to the P&A operation of pushing forward. Based upon reviews of the geological and mud log information, it is believed the potential amount of hydrocarbons present in the section below 590’ is very limit and therefore the risk of migration to other strata lower in the wellbore is low and of limited consequence. A waiver to the requirements of 20 AAC 25.112.(a) is being requested to leave the potential hydrocarbon bearing section from ~590’ to TD uncemented. This same waiver was requested and approved by the Commission for the Rosetta 2 well, which is located approximately 70’ at surface from Core Hole 2 and open to the same strata in the subsurface. 1.1 P&A Procedure – Houston Core Hole 2 Pre-Coiled Tubing Work 1. Prepare location for rig operations and remove any debris / solid waste specified for clean-up. 2. Excavate around the well as required to provide access to the existing 2-7/8” tubing for installation of wellhead and sealed well cellar. Note: During the June & August 2023 site visits no measurable gas levels were recorded (0 to 2% LEL). 3. If required, perform hot tap on 2-7/8” tubing at desired cut-off depth (for wellhead installation) to ensure no trapped pressure exists on the well. 4. Cut 2-7/8” tubing to place stub at desired elevation for installation of new wellhead equipment. 5. Install sealed well cellar and new starting head / wellhead configuration. Coiled Tubing Based Operations 1. Move in and rig-up coiled tubing unit and equipment. Note: Notify AOGCC 24 hours prior to commencing P&A operations and for the upcoming BOP test. 2. Nipple up BOPE and test to 250 psi low / 1000 psi high. 3. Make-up mill cleanout assembly and proceed to drill out the cement plug within the 2-7/8” tubing. No records exist for this plug, however firm cement was found during site visits within the 2-7/8”. x A minimum 9.6 ppg brine or water-based mud will be used to clean-out the cement plug and throughout the P&A operation. 4. Once the plug is drilled proceed to clean out in open hole, monitoring parameters and returns carefully. Cleanout the open hole as conditions allow to 590’ MD for cement plug placement. Notes: x The cement will be drilled with parameters and BHA design to minimize chances that the bit will “jump off” any plug extending into open hole. The desire is to stay within the original hole and not sidetrack into new formation. x There is currently no information regarding the hole size. Recommend approving requested waiver. SFD 7/29/2024 Attempt to identify depth of casing shoe to ensure cementing plan is compliant with 20 AAC 25.112(b). -bjm If CT can proceed unimpeded beyond 590', plan to run in hole until hitting hard obstruction and place cement base at tag depth. Review wellbore conditions with AOGCC and obtain approval before commencing cementing operations. -bjm Hot tap is required. -bjm OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 4 of 9 x Drilling parameters and returns are to be monitored closely. x The desire is to reach a depth of ~590’ MD and back to surface. However, the final cleanout depth reached may be shallower and will be based upon actual hole conditions. 5. Once the cleanout operation has reached the resultant depth, condition the hole as required for cementing operations. Approval of an alternative plan with cement plugs starting at a depth shallower 590’ must be obtained from the AOGCC prior to proceeding with cement operations. Note: Notify AOGCC 24 hours prior to setting cement plugs to allow witnessing of the operations. 6. Rig up cement unit. Mix and pump ~5 bbls of 15.8 ppg cement, laying in the plug from established TD. Pull BHA above plug and circulate clean. Note: The top of cement cannot be calculated at this time given the lack of data regarding hole size. 7. Wait on cement as required. Run in hole and tag cement plug, placing 5K on the plug to confirm competency. Tag set down weight will be driven by depth TOC is found. As per guidance from the AOGCC, weight testing of this plug to requirements of 220 AAC 25.112 (g) will serve as a test of the base for following cement plugs, eliminating need for weight test verification of those plugs. 8. Based on tag depth, calculate open hole volume and calculate estimated cement volume required to reach surface. 9. With bottom of BHA at tag depth of prior plug, lay in cement plug from tag depth to surface (volume and weight to be determined). 10. Pull cementing stinger to base of wellhead near ground level and circulate any cement from the well above that point. 11. Nipple down BOPE. Rig-down and move out coiled tubing unit and associated equipment. Post-Coiled Tubing Work 1. Remove wellhead and well cellar. Complete excavation as needed around the well to allow cutting the 2-7/8” pipe to a minimum depth of 3’ below ground level for final P&A. Note: Notify AOGCC 24 hours prior to final excavation and top-off of surface cement to allow witnessing of the operations. 2. Top-off 2-7/8” pipe with cement as needed. Photograph casing and cement. 3. Weld marker plate on the outermost casing that meets requirements of 20 AAC 25.120 and includes the below information bead-welded directly to the marker plate. Photograph marker plate. State of Alaska AOGCC PTD 100-009 Core Test Hole 2 API 50-009-10023-00-00 4. Perform post-P&A methane monitoring and record results for reporting purposes. Photo document the well before and after cut-off, condition of cement inside the wellbore, installed marker plate and ground surface after backfill. Include photos in 10-407. -bjm Circulation depth and cement top must be no shallower than 250' MD. -bjm Handhold methane detector only. -bjm OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 5 of 9 5. Backfill the excavated hole and grade the location to final agreed condition. Remove any remaining debris from the location and dispose of waste materials as required. Note: Contact the AOGCC with 24 hours advanced notice to perform final site clearance inspection after rig down. Figure 1.1-1 and Figure 1.1-2 on the following pages show the current wellbore schematic and the proposed wellbore schematic after the P&A operation. OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 6 of 9 Figure 1.1-1. Current Wellbore Schematic OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 7 of 9 Figure 1.1-2. Proposed P&A Wellbore Schematic OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 8 of 9 Figure 1.1-3. Wellhead Configuration OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 9 of 9 Figure 1.1-4. BOP Configuration 1 Christianson, Grace K (OGC) From:Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Sent:Friday, July 26, 2024 5:43 PM To:McLellan, Bryan J (OGC) Subject:RE: Houston Core Hole 2 (PTD 100-009) That is a good point, Bryan especially given the memory tool will have Ʊnished the CBL runs on the prior wells. If it is indeed core casing it is either “Ʋush coupled” or “Ʋush joint”. I envision they could pick it up like standard Ʋush joint casing. I will follow up with Halliburton. Thank you! Tim From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, July 26, 2024 4:42 PM To: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Houston Core Hole 2 (PTD 100-009) Memory CCL? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Sent: Friday, July 26, 2024 4:29 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Houston Core Hole 2 (PTD 100-009) Bryan, I am looking into end of tubing locators/methods or the possibility of dyed sweeps. However, with the potential small core hole diameter below the 2-7/8”, it may be highly likely that we will see motor work/di Ưerential upon or soon after entering the open hole. We will have the ability to monitor our returns for formation. One of Cudd’s Thru Tubing representatives is going to be here Tuesday and we are slated to review potential options. I am striving for a method that does not meaningfully increase cost or risk and or mobilizing anything else to the location – i.e. wireline/slickline. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Tim From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, July 26, 2024 11:43 AM To: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Houston Core Hole 2 (PTD 100-009) Sounds good. How do you propose we identify the shoe depth? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Sent: Friday, July 26, 2024 10:24 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Houston Core Hole 2 (PTD 100-009) Bryan, 1. Understood. Since generating the plan, I have found data on Core Hole 1 that provides valuable insight as to the potential construction of Core Hole 2. For Core Hole 1 they noted running “NX” casing to 289’ (which is 3-1/2” core casing) and then coring “AX” (which is 2-1/4” core casing). Core Hole 2 has 2- 7/8” pipe which is the size of “BX” 2-7/8” core casing. It is possible that they started with and cased NX and then stepped down to the 2-7/8” or they possibly started with 2-7/8”. In any case I have a higher degree of belief that the 2-7/8” is likely set deeper as opposed to shallow and that the open hole below the shoe is of a smaller diameter. This information alters, in part, the execution risk proƱle that I was originally considering for the work – in particular it signiƱcantly reduces the likelihood of an extremely shallow shoe and large diameter hole below the shoe. 2. I had left the circulate out depth undeƱned as I thought that we would learn more about the well particularly if we were able to deƱne the end of tubing during execution - that would help inform where we would circulate from. To your point, I did consider the 5 bbls achieving surface if the 2-7/8” is deep(er) which I am now more inclined to believe it is. I concur that 250’ is reasonable. Thank you. ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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. 3 Tim From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, July 26, 2024 8:58 AM To: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: Houston Core Hole 2 (PTD 100-009) Tim, Two items to discuss regarding the sundry: 1. In step 4, if CT is able to proceed unobstructed below 590’ MD, they should continue in the hole until tagging something hard and lay cement in from that depth. 2. In step 6, at what depth do you plan to pull the CT and circulate after laying in sand? That depth represents the minimum allowable depth for this plug. Note that 5 bbls of cement inside 2-7/8” tubing would bring cement all the way to surface, so if you are in cased hole, you’ll need to circulate out the excess cement from some depth below the surface plug. I would say 250’ seems reasonable. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 ❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Davies, Stephen F (OGC) To:McLellan, Bryan J (OGC) Cc:Dewhurst, Andrew D (OGC) Subject:RE: Core Hole 2 Plug Approach Date:Tuesday, July 2, 2024 2:53:55 PM Attachments:image002.png image004.png Bryan, Q: Can you review the log from Core Hole 2 and see if you think the waiver request would be approved in this well? A: Yes. A waiver like that approved for close by well Rosetta 2 is also reasonable for Core Hole 2. In my opinion, freshwater aquifers will still be protected. Q: The mud log for Core Hole 2 mentions gas shows at different depths than what we have listed for Rosetta 2. Does the Core Hole 2 mud log change your opinion on our approval of the Rosetta 2 minimum plug setting depth? A: The variance between the sparse sample descriptions for both wells is not surprising given the technology used at the times that each of these wells were drilled and the fact that they were drilled for different purposes. (Core Hole 2 sought coal information; Rosetta 2 was searching for oil.) Note that the sample descriptions for Core Hole 2 suggest the formation beds are nearly flat between the surface and 543’ MD. So, there should not be a significant elevation (depth) difference for the same rock layer in both wells at depths shallower than about 543’ MD. At about 485’ MD in Rosetta 2, the sample description notes “Water (salt)”. At 545’MD in Core Hole 2, the sample is described as having brackish water with evident gas pressure. So, from this limited sample information, the base of freshwater lies shallower than 485’ MD. The resistivity curve recorded in Rosetta 2 decreases from a rough baseline of 28 ohm-m at 390’ MD to establish a new baseline near 10 ohm-m that begins at about 540’. This appears to represent a transition from freshwater to brackish water between 390’ and 540’ MD. So, I’d place the base of freshwater at about 390’ in this area. ASRC’s estimate of 440’ MD for the base of freshwater is conservative and provides additional protection. Both depths are supported by the sample descriptions noted above. A plug base at 590’ MD results in about 150’ to 200’ of cement below the base of freshwater. Note that there are thick claystone layers described between 410’ and 510’ MD in Rosetta 2 that will provide vertical seals between the brackish, slightly gas-bearing strata and the overlying freshwater aquifers. (See log display, below.) Q: My thoughts are we want, at a minimum, cement across a confining interval between the gas/saline water and fresh water. Does their plan achieve that? A: Yes. A cement plug from 590’ MD to surface in Core Hole 2 will isolate shallow freshwater aquifers from the brackish and slightly gas-bearing strata below. According to the Alaska DNR’s WELTS (water well log) website, water wells in this area range from 28’ to 161’ below ground surface, with the closest reported water well-- which lies 600’ to the NNE--having a depth of 161’. (See map, below.) So, a cement plug from 590’ to the surface will, in all likelihood, adequately protect shallow freshwater aquifers. Please let me know if I can help further. Steve Map Description automatically generated From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, July 2, 2024 11:26 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: FW: Core Hole 2 Plug Approach Steve, Can you review the log from Core Hole 2 and see if you think the waiver request would be approved in this well? My thoughts are 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. we want, at a minimum, cement across a confining interval between the gas/saline water and fresh water. Does their plan achieve that? We approved the same plan for Rosetta 2 which is only 50ish feet away from Core Hole 2. The mud log for core hole 2 mentions gas shows at different depths than what we have listed for Rosetta 2. Does the Core Hole 2 mudlog change your opinion on our approval of the Rosetta 2 minimum plug setting depth? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Sent: Tuesday, July 2, 2024 7:35 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Core Hole 2 Plug Approach Good morning Bryan, Regarding Core Hole 2 which we discussed last week with respect to the plug setting depth, immediately prior to my call with you I had reviewed with Bill Isaacson regarding the status of the Rosetta 2 Sundry and at that time we were under the impression that the Rossetta 2 Sundry was still pending. However, it was then pointed out by Dan Kara during a discussion with him, that the Rosetta 2 sundry had in fact been approved. In that sundry Bill had requested a variance for the plug setting depth in the Rosetta 2 open hole. Given that the Rosetta 2 and Core Hole 2 are separated by approximately 70’ at surface, and both are abandonments across the same strata, we would like to request the same variance for Core Hole 2. Attached is the proposed sundry procedure for Core Hole 2 that is ready for submittal to the AOGCC, however, as this deviates from what you and I discussed regarding the plug depth, I wanted to submit to you first. I will also submit to Dan, but wanted to verify that you are ok with me sending to him or if you want to view these first. I have also attached the Rosetta 2 approved 10-403 for your convenience for comparison. If you have any questions, please let me know. Thank you, Tim (907) 252-3923 Bureau of Mines Report of Investigations 5350 I I /I INVESTIGATION OF SUBBITUMINOUS-COAL BEDS NEAR HOUSTON, WESTWARD EXTREMITY OF MATANUSKA COALFIELD, ALASKA BY R. R. MAY AND R. S. WARFIELD I t United States Department of the Interior-August 1957 I---- INVESTIGATION OF SUBBITUMINOUS-COAL BEDS NEAR HOUSTON, WESTWARD EXTREMITY OF MATANUSKA COALFIELD, ALASKA BY R. R. MAY AND R. S. WARFIELD * * * * * * * * *Report of Investigations 5350 UNITED STATES DEPARTMENT OF THE INTERIOR Fred A. Seaton, Secretary BUREAU OF MINES Marling J. Ankeny, Director Work on manuscript completed November 1956. The Bureau of Mines will welcome reprinting of this paper, provided the following footnote acknowledgment is made: "Reprinted from Bureau of Mines Report of Investigations 5350." August 1957 I INVESTIGATION OF SUBBITUMINOUS-COAL BEDS NEAR HOUSTON, WESTWARD EXTREMITY OF MATANUSKA COALFIELD, ALASKA by R. R. Mayl/ and R. S. Worfield / CONTENTS Page Summary .................. ....................................... 1 Introduction ..... .... .......... ,...... .,... ... ......... 1 Acknowledgments .......... ........ ... ...... .... 0. ......... 2 Description of area............... ............ ........ .. 2 Location and access .................... ...... 2 Topography. ................... ..... ...... .... ....... 2 Climate (as it affects operations).... ..... .............. 2 History and production,.. .. .... ............ ................... 4 Geology .... ................................ ...... .......... .4 The coal ..... .....,,................... ..... .......... 5 Coal sampling and analysis ........................... 5 Mining and preparation...... .... ........ ........... 7 Work by the Bureau of Mines ............ ......................... 7 Preliminary examination... .... ................. ..... 7 Diamond drilling......... ......... ...... ........... ..... 7 Interpretation of drilling results...............,...... 9 Appendix.............. ...................................4..... 12 Logs of drill holes...................................... 12 1/ Solid fuels mining engineer, Bureau of Mines, Region I, Alaska district, Anchorage, Alaska. 2/ Mine examination and exploration engineer, Bureau of Mines, Region I, Juneau, Alaska. Report of Investigations 5350 ii ILLUSTRATIONS Fig. Page 1. Location map, Houston coal-drilling project ................. 3 2. Plan, Houston coal-drilling project......................... 8 3. Section A-A' and graphic logs, Houston coal-drilling project 10 TABLES 1. Section in strip mine near old Evan Jones slope............. 6 2. Section in strip mine 1,200 feet northeast of old Evan Jones slope ............................................... 6 3. Analyses of face samples from section 1,200 feet northeast of old Evan Jones slope .................................. 6 4. Analyses of diamond-drill core samples from Houston coal- drilling project ........................ ......... 11 1 SUMMARY A preliminary examination of the Houston strip-coal mine, situated on the Alaska Railroad at milepost 175 (61 rail miles north of Anchorage, Alaska) and a review of all available information resulting from early coal exploration activities in the area resulted in plans to investigate the coal-bearing formations at depth by means of diamond core drilling to indicate the existence of additional reserves of coal in close proximity to railroad transportation, where it would be quickly available to meet rapidly expanding military and civilian fuel requirements. From the date of mobilization of equipment, August 28, 1951, until date of sus- pension, August 18, 1952, 2-,010 feet of diamond drilling was completed. Ten defin- able coal beds were cut, of which 2 appear to be persistent and minable over an area of approximately 1/2 square mile. Within this area the 2 minable beds contain approximately 5,000,000 tons of coal in place. Of the remaining beds, at least two others may be minable to the eastward near their projected outcrops; however, these and deeper beds (at least in the vicinity of the drill holes) lie beneath a zone of pressurized gas and brackish water. From a practical standpoint, continued develop- ment and utilization of the coal in this vicinity will depend on the operators' in- genuity in developing cheap mining methods and on diligent prospecting for strippable coal under the comparatively light glacial cover. INTRODUCTION Since the advent and expansion of military installations in south central Alaska, coupled with the resultant rapid growth of population, the delineation and development of the Matanuska coal field have assumed considerable importance, particularly in those parts of the field that are accessible by existing transportation facilities. Little work of an evaluating nature had been done before this project was undertaken at the western end of the Matanuska field, which abuts the main line of the Alaska Railroad at Houston, approximately 60 miles north of Anchorage. Although the rank of the exposed beds in the immediate vicinity of Houstin is subbituminous, recent exploration by the Federal Geological Survey indicated a defi- nite tie with the extensive bituminous beds of the Chickaloon coal-bearing formation now in production a few miles eastward. Discovery of additional minable beds not only would augment the Houston-area reserve but might lead to the discovery of nearby reserves which, because of closer proximity to the Talkeetna Mountain uplift, might have bituminous rank. From observation of past and present workings and of the indicated geological attitude of the coal-bearing formation, it appeared that a very limited drilling pro- gram would procure the desired information. The following report presents the data obtained by the drilling program and an interpretation of the data. 2 ACKNOWLEDGMENTS Many of the historical data, as well as cooperation in appraisal and sampling before initiation of the project, were furnished by Dr. George Gates and Dr. Farrell Barnes of the Alaskan Geology Branch, Federal Geological Survey. Core and face sam- ples of coal taken before and during the work were analyzed by the Bureau of Mines Coal-Analysis Section, Pittsburgh, Pa., under the direction of R. F. Abernethy, chief. The engineering department of the Alaska Railroad furnished basic alinement and ele- vation details upon which the survey of the drilling area was based. Tucker & Peter- son, lessors, and Duck Flat Co., production contractors, assisted the work by fur- nishing housing and messing facilities and the occasional use of heavy equipment. DESCRIPTION OF AREA Location and Access The limited area covered by the activities described in this report is within 2 miles of Houston, a station at 240 feet altitude on the main line of the Alaska Rail- road at mile 175 (fig. 1). Houston is 61 miles north of Anchorage, near the western toe of the Talkeetna Range, on the edge of the broad Susitna River Valley. When this project was in progress there was no highway access, but a road from Pittman (mile 167 on the Alaska Railroad) has since made the mine accessible over the Alaska high- way system. Topography The Houston-project area is on the eastern edge of the Susitna River Valley, which is essentially a broad tundra flat cut by many, very small, meandering creeks. The Alaska Railroad follows the toe of the foothills that slope gently upward toward the mountains in an undulating series of benches; the project area is beside the rail- road and at the base of this terraced slope. The Susitna Valley, which at this point is fully 25 miles wide, appears to be covered with a semisubmerged, recessional moraine. Tundra areas on this moraine consist of grassy swamps and pools, with patches of scrubby spruce and brushy willow. The rising ground to the eastward is covered by glacial de- posits of various types and by a thick forest growth; spruce and birch predominate. As might be expected in an area where bedrock is almost completely concealed, the orig- inal coal discovery was made in a cut incidental to railroad construction. Climate (As It Affects Operations) The climate here is suitable for outside operations during only about 6 months of the year, unless shop facilities are heated and insulated and unless all-weather roads are constructed and at considerable expense. January and February are the coldest months, with an average daily low of minus 20°. During June, July, and August the daily high usually is in the 60's, but during calm, clear days the temperature often is in the 80's. Annual precipitation records for the immediate vicinity of Houston are not available, but estimates indicate a combined rain and snow content of about 50 inches. Except where it is drifted, winter snows seldom accumulate to depths of more than 3 feet. Summer rains generally are unpredicatable as to monthly intensity; they seldom are heavy but often are persistent enough during early and late summer to hamper hauling and road-maintenance work with heavy equipment. The outdoor working season for stripping overburden usually is mid-May to mid- October, although much subsidiary work can be done a month or so before and after these dates; however, unless expensive methods are adopted, mining operators seldom 3 Figure 1. -Location map, Houston coal-drilling project. 4 strip overburden until June, because the ground usually freezes to a depth of 5 to 7 feet; thawing produces a tremendous amount of surface water, which bogs down most heavy equipment. HISTORY AND PRODUCTION Coal was discovered in a right-of-way cut on the Alaska Railroad at Houston station in 1917. Although the early history of the development is somewhat clouded, it is known that, between 1917 to 1920, a coal-prospecting permit was granted on the 10-acre tract at the discovery site and that 2 slopes were driven on the coal meas- ures. According to reports, the slopes entered 2 beds of coal, which were 3-1/2 and 5 feet thick, respectively; the beds dipped 6° to 15° northeasterly. Production dur- ing this period is estimated at 10,000 to 15,000 tons of coal, which was sold to the Alaska Railroad and to the domestic market in Anchorage. All of the original work- ings have long been caved; even the caves are completely obscured by brush and slides. The site of this early activity is approximately one-half mile southeasterly of the present workings, from which it is separated by a low-lying muskeg swamp; therefore correlation of the discovery beds with beds in the project area would require consid- erable prospecting work beyond the scope of this project. Between 1920 and 1934 no mining or development work of consequence was done near Houston. In 1934 Arthur Heaven was granted a 160-acre homestead, which included patent rights to underlying coal. In 1935 Evan Jones obtained prospecting permits for 874.82 acres adjoining the homestead in sections 17, 18, and 20; in the same year he started a slope mine near the present position of the southeast corner of the strip pit. About 12,000 tons of coal was produced from the slope and from a few rooms before the operation was suspended in 1940. Between 1938 and 1940 Jones joined in partnership with George Tucker and Ralph Peterson; during this period the Heaven patent was purchased and became the nucleus of later operations. This partnership was terminated in 1940; thereafter permits were allowed to lapse until a revival of interest in 1948, when an expanding military market became apparent. In 1948 Tucker and Peterson organized the Houston Coal Co. and acquired a permit for access to an additional 1,800 acres next to the Heaven patent; from 1949 through the 1952 season approximately 65,000 tons of coal was marketed. Most of the coal was passed through a crushing, screening, and washing plant, which contained a Forrester- type jig capable of handling 15 to 25 tons per hour. Production during 1951 and 1952 was under a management-sales agreement with the Duck Flat Co., a Los Angeles organi- zation. Virtually all production went to the military installations at Anchorage. GEOLOGY The geology of the Matanuska coal field is best known from the writings of Go C. Martin of the Federal Geological Survey, who first made a general reconnaissance of the region in 1905 and subsequently made detailed studies of the lower3/ and upper4/ parts of the field in 1910 and 1913, respectively. As defined in early descriptions, the upper or eastern part of the Matanuska field included the Anthracite Ridge and Chickaloon districts; the lower or western part included the Eska and Moose Creek areas, as well as Wishbone Hill. Recent reconnaissance by the Geological Survey along the lower reaches of the Little Susitna River and its tributaries and the work at Houston by the Bureau of Mines indicate that the Matanuska field extends westward 3/ Martin, G. C., and Katz, F. J., Geology and Coalfields of the Lower Matanuska Valley, Alaska: Geol. Survey Bull. 500, 1912, 98 pp. 4/ Martin, G. C., and Mertie, J. B., Jr., Mineral Resources of the Upper Matanuska and Nelchina Valleys: Geol. Survey Bull. 592, 1914, pp. 273-299. I 5 from Moose Creek and includes the northern edge of the lowlands lying north of Knik Arm. Barnes designates these lowlands as the Little Susitna district of the Matanuska coalfield; Houston and the project area are in this district.5/ The following generalized description of the geology of the Matanuska coalfield is summarized from the above-cited publications, to which the reader is referred for details: All coal measures in the field occur in the Chickaloon formation (Tertiary), which is composed of 3,000 to 5,000 feet of claystone, siltstone, sandstone, thin beds of fine-grained conglomerate, and many beds of coal. The Chickaloon formation is overlain by the Eska conglomerate (Tertiary) and underlain by the Matanuska and Arkose ridge formations (Upper Cretaceous). The Eska conglomerate is not present in the stratigraphic section at Houston. Neither the Matanuska formation nor the Arkose ridge formation is exposed near Houston. At Houston and throughout the field individual beds in the Chickaloon formation, including the coal, tend to thin out or intergrade within relatively short distances. These changes in bed thickness are believed to be due primarily to the original len- ticular structure of the sedimentary deposits but also may be due in part to the crumpling and pinching out of the soft shales incident to folding of parts of the region; correlation of individual beds (including coal) for more than short distances is therefore uncertain or impossible. Correlation of the coal measures between districts, and often between mines in the same district, is complicated further by differences in the character of the coal that result from differences in the amount of faulting and folding from place to place. The coal at Houston is subbituminous; it occurs in relatively flat lying beds that have suffered little or no deformation. THE COAL Coal Sampling and Analysis The following sections and samples were taken by R. R. May, Bureau of Mines min- ing engineer, and F. F. Barnes, geologist, Geological Survey, September 26, 1950. Sections and samples were taken in accordance with Bureau of Mines standard procedure and forwarded to Pittsburgh for analysis. 5/ Barnes, Farrell F., and Payne, Thomas G., The Wishbone Hill District, Matanuska Coal Field, Alaska: Geol. Survey Bull. 1016, 1956, p. 2. Roof: Gray shale, coaly at base. Coal, dull glossy/ ....................................... Bone, bright-coal streaks................................. Coal, bright!/............................................. Coaly shale./............................................. Coaly shale and bone.2/................................... Coaly/ ........................ Coaly shale2./... ............................................. Coal, clay slips./........................................ Bone...................................................... Floor: Coaly shale............................................... 6 TABLE 1. -Section in strip mine, near old Evan Jones slope (top bench of strip-mine bed) Roof: Gray claystone, silty. Feet Inches Coaly shale to bone...................................... 0 2-1/2 Coal .................................. .................. .. 1-1/2 Coaly shale................ ................................ 1 Coal ..................................... 10 Bone ................................................... ... 7 Coal, bright ........................ ........ ............. 1 1-1/2 Bony coal..... ...................................... ......3-1/2 Coaly shale.l/ ............................................. 2 Claystone, thin coal stringers............/ ............ .............. 8 Claystonel/ ................................................. 2 0 Bony coal (top of lower bench) ............................. Partly exposed. 1/ Denotes parting between upper and lower benches. TABLE 2. -Section in strip mine 1,200 feet northeast of old Evan Jones slope (full section, both benches) I Feet Inches 0 9 7 1 0-1/2 1 4 2 4 1 0 4 6 2 Partly exposed. 1/ Included in analysis,lab. No. D-51894 (table 3). 2/ Denotes parting between benches. 3/ Included in analysis,lab. NO. D-51895 (table 3). TABLE 3. -Analyses of face samples from section 1,200 feet northeast of old Evan Jones slope Air-drying Vol. Fixed Sample loss Condition Moisture matter Carbon Ash Sulfur B.t.u. D-51894 7.6 A 20.3 31.6 38.9 9.2 0.4 9,210 B 13.7 34.2 42.1 10.0 .5 9,970 C 39.6 48.9 11.5 .5 11,550 D 44.8 55.2 .6 13,060 D-51895 6.7 A 17.4 32.5 36.6 13.5 .4 9,160 B 11.5 34.8 39.3 14.4 .5 9,820 C 39.3 44.4 16.3 .5 11,090 D 47.0 53.0 .6 13,250 Condition: A -as received. B -air-dried. C -moisture-free. D -moisture- and ash-free. Analyses by H. M. Cooper, Bureau of Mines, Pittsburgh, Pa. 7 Mining and Preparation Coal at the Houston mine (see table 1 for average section) is stripped and then mined in successive benches by drilling vertical blast holes with a portable electric auger on 5-foot centers; these holes are blasted lightly with 20-percent gelatin. After being broken, the coal is loaded by power shovel onto trucks, which haul it to the washing plant approximately 1 mile from the pit. The raw coal tends to be coarse and slabby, with many iron-silica-sulfur concretions; therefore it requires prelimi- nary breaking before being fed to the rolls. This breaking is accomplished by using a small crawler tractor to crush oversize through an 8-inch grizzly into the roll- crusher feed bin. Crushed coal for jig feed is sized to suit current contract spec- ifications, which usually require 2-1/2 inches top size. This product is fed either directly to through surge bins to a steam-driven Forrester-type coal jig with a 4- by 4-foot plunger section and a 4- by 6-foot bed section. The washed-coal discharge passes over a double-deck shaker sizing screen, with impinging sprays. Screen sizing varies with contract purchase specifications; fines may be optionally recovered in an Esperanza-type classifier in closed circuit with washer and screen or discarded sepa- rately. Because the plant level at the screen discharge is 30 feet or more above the car-loading siding, gondolas are loaded by chuting the coal to the cars. For best washing results plant capacity is 15 to 20 tons per hour, but careful mining often permits considerable overloading without appreciable detriment to the quality of finished coal. Observation of the plant operation under varying conditions indicates that the Forrester jig is not an ideal medium for separating this coal and its inherent impu- rities. Although the tendency of this coal to break in thin slabs undoubtedly af- fects jigging separation, it is apparent that there is a rather narrow differential in specific gravity between the shale-bone-coal components in this particular bed system. WORK BY THE BUREAU OF MINES Preliminary Examination In September 1950, accompanied by F. F. Barnes of the Geological Survey, the writer inspected the mining activity at Houston. Bed sections were recorded, and samples were taken from the strip pit (see tables 1, 2, and 3). After the prevalent strike and dip of the measures (which were partly exposed for nearly a mile along the railroad) were ascertained, it was tentatively concluded that numerous beds on very moderate dips probably were present in the area. Before this examination the current lessors had put down several shallow auger holes in a mile-long area that extended a half mile or so from the railroad; these holes penetrated the overburden into bedrock until coaly material was found. Be- cause this coaly material was encountered within narrow ranges in a high percentage of the holes, it was assumed that the coal bed was undulating in some conformance with the existing topography and that the bed would be strippable throughout a large area. However, later evidence disproved this assumption; consequently, it was decided that a core-drilling pattern that would consist of 2 or 3 holes at intervals downdip would be required to clarify the situation. Diamond Drilling A Bureau of Mines diamond drill was shipped to Houston in late August 1951. The first hole was started near the strip pit highwall. This location (see fig. 2) was -9 /\ \.4 Legend Doimond drill hole 8 I I I *^ oMP4qge Ipoo SOC Figure 2. -Plan, Houston coal-drilling project. chosen to establish initial correlation of the coal measures with reference to the existing mine workings. Drilling conditions were difficult from the start; conse- quently, progress was slow. A heavy flow of gas and brackish water, which was en- countered during freezing weather, caused a shutdown November 10 at a hole depth of 481 feet 7 inches. The condition of the hole precluded resumption of drilling at this location at the beginning of the next season. Hole 2 was started May 29, 1952, at a new location; it reached a depth of 1,142 feet, which was considered sufficient to intercept any coal beds likely to outcrop or to come within practical mining depth within a radium of a mile or so. Hole 2 was completed August 5, 1952, and the drill was moved to the third location farther downdip, where drilling was resumed August 10. Hole 3 was completed August 18 at a depth of 386 feet. Termination at this relatively shallow depth was decided upon as soon as it appeared that a positive point of correlation with beds in hole 2 had been reached. Holes 2 and 3 were spaced at intervals of 2,050 and 2,910 feet, respectively, which was considered the maximum distance allowable for accurate correlation. Depths were governed by practical considerations of possible future mining operations within the immediate Houston area. The locations of the drill holes, pit, and washing plant and the topography of the Houston area are shown in figure 2. Graphic logs and a section through the drill holes are shown in figure 3. Analyses of core-drill samples are presented in table 4. Detailed descriptive logs of the drill holes and the results of megascopic examina- tion of coal core sections are given in the appendix. Interpretation of Drilling Results The area of conclusive results, particularly with regard to estimation of re- serves, should be limited to no more than a rectangular area, approximately 1 mile by 1/2 mile, whose long axis is roughly along the line of the 3 holes drilled. A number of thin coal beds dip 5° to 10° northwesterly; these beds may overlie or underlie the strip bed. Within this area no appreciable faulting or folding is apparent, but some minor folds or displacements may be concealed by the cover of glacial deposits and forest growth. Although several beds appear to be minable and an appreciable tonnage is in- dicated, it would be inadvisable to accept the reserve estimates without careful consideration of local peculiarities. Some of the factors that might modify the reserve estimates follow: (1) Washer recovery varies widely according to the type of cleaning equipment and mining practice. (2) It has been many years since underground mining has been practiced at this location; consequently, no accurate recovery factor is assignable. (3) Because of adverse drilling conditions, friability of the cored material, and the haphazard distribution of concretions in the coal measures, considerable difficulty was experienced in recovering core samples for other than visual inspec- tion and for comparison with coal currently being mined; therefore, core-drill sam- ples may not be exactly representative of the thickness and character of the coal beds drilled. 9 300 200 100 0 -100 -200 -300 -400 -500 -600 -700 -800 10 Collar El. 249 Collar El. 330 Collar EL 303 l. ll :::hl'i111,' l : , ,t, .ii: 'li:J',i : : ::llal*. l:l::h :,'lt:'o :;' :':' iI 'r :I.ij : :1 ::l1 I : 't: N I iji ' |: ;' :i : .:O :: :;:: -' :: 0 0 0 0 0 0 0 0Ut o 0 u o --CU T)u'n Od 0 Io Ur ro OI glliiii-:ir:.iil::l/li~llllr~l:i ::1151·:::i"':::lii;l-I rO~jpal-oriir:::::.:.::t:t~f ~i:t-i 'i i ' I ' I .I I I 0 0 0 0- k. L 0 ----I N-- O //O O I 0 0o oo toO 117 0 -0 0-' u ,'t slD 0 0g,0 0'in oIn ;D 0In (0 0 01- 0 0 O 0O r.- cO 0 GOcc :::: ..·.:1,:·:: :· · ·:·:I:::·: :·.·;··.·.· ''' ;:IEYI I· ·r· :I:''`''"'':':::' -.....-.,. ''':::I·] - ··::···:· ···: ·,,,,'Eilli o I·;YI; ;Il·,;r:: ···1:· ....··.·-..·.·.·. : 0 00 00 0 C ± o m 1 C -m --, a o A >0 >0 0 -c 0 t -0 0 0^ o 6 6 In O 0 0 L, o -cN 0 to N 00 Tr o 0 0 ^1- 0 t Figure 3. -Section A-A' and graphic logs, Houston coal-drilling project. I TABLE 4. -Analyses of diamond-drill core samples from Houston coal-drilling project proximate analysis, Ultimate analysis, Fusability of ash, percent -percent O F.___ 0C .4 C i O I i 4o .0 i C 0 g bOZ4J I 1 10.8 329 37.3 .0 5.3 53 1.4 20.8 0.4 19.0 929 2,310 0 2, 740 .5D-74890 2 -3. 32.1 3& .r-C CP 4 1.3 2 .3 15 9,00 (Hole 4) 3 36.9 41.8 21.3 4.6 59.5 1.5 12.7 .4 21.3 10,420 J-J *-4 -0t 0 0 0 3 r M ai ) 4 4a i- N c4 -4 51 .8 75.6 2.0 16. .5 1,240Lab. 0 r 14- 4 4 4- -4 ri g H-4 O4 ctCL O B a0 > Xi 53 c aM No.1 ! c z > E r0 U z M c Zc 'l4.J 4 4 1 10.8 32.9 37.3 19.0 5.3 53.1 1.4 20.8 0.4 19.0 9,290 2,310 2,620 2,740 1.53 D-74890 2 13.0 32.1 36.4 18.5 5.4 51.8 1.3 22.7 .3 18.5 9,070 (Hole 1) 3 36.9 41.8 21.3 4.6 59.5 1.5 12.7 .4 21.3 10,420 4 46.9 53.1 5.8 75.6 2.0 16.1 .5 13,240 1 9.5 30.9 33.2 26.4 4.9 48.0 1.2 19.2 .3 26.4 8,400 2,330 2,620 2,840 1.61 D-74891 2 12.1 30.0 32.2 25.7 5.0 46.7 1.2 21.1 .3 25.7 8,160 (Hole 1) 3 34.1 36.7 29.2 4.2 53.1 1.4 11.8 .3 29.2 9,280 4 48.2 51.8 5.9 75.0 1.9 16.8 .4 13,100 1 D-99651 2 10.2 30.9 38.1 20.8 .2 9,140 2,570 2,690 2,890 (Hole 2) 3 34.5 42.3 23.2 .3 10,180 4 44.8 55.2 ___.3 13,250 1/ 2/ 3/ Pittsburgh laboratory number; see table FoLlowing ana logs tor description 1, Air-dried; 2, as received; 3, moisture-free; 4, moisture- and ash-free. Determined by modified method. ot samples. Description of drill-core samples, Houston project: Lab. No. D-74890: Hole 1; core logged 27 feet 3 inches to 30 feet 3 inches; core received 32 inches;. 3-3/4 inches bone rejected; 4 inches coal loss in drilling; 28-1/4 inches coal in this sample. Lab. No. D-74891: Hole 1; core logged 33 feet 1 inch to 35 feet 8 inches; core received 30 inches; 6-1/2 inches bone rejected, 1 inch bone loss in drilling; 23-1/2 inches coal in this sample. Lab. No. D-99651: Hole 2; core logged 437 feet 6-1/2 inches to 441 feet 0 inch; core received 41-1/2 inches; 8-1/2 inches bone rejected; 33 inches coal in this sample. Ft. Del From- 0 ., 11 22 23 27 27 30 30 30 31 31 32 32 33 0 12 As a basis for calculating tons of coal in place, the common factor for Alaskan subbituminous coals is 1 ton of mined raw coal (plant feed) per cubic yard in place in the mine. Two beds known to average 42 inches and more are the "pit" bed and a bed lying approximately 250 feet (stratigraphically) below. Other beds are simply grouped in the category "14 inches and more"; 2 of these may be 42 or more inches thick; however, the minability of the beds should not be inferred without more thorough investigation. On the above basis, the total amount of coal in the drilled area is estimated to be as follows: Tons in place Pit bed, average 5 ft. of coal .................... 2,580,000 250 bed, average 4 ft. of coal.................... 2,000,000 Otheri/, average total, 19 ft., 6 in. .............. 10000000 Total .... .................................. 14,580,000 1/ Appearance and specific gravity comparable to pit product. Study of the drilling logs, projection of the limited geologic evidence, and consolidation of known historical evidence in this locality indicates that investi- gation to the southeast for 1/2 to 1 mile might expose strippable beds amenable to more economical mining. As noted in the logs and elsewhere in this report, a con- siderable quantity of gas was encountered at a well-defined horizon in holes 1 and 2. Study of this phenomenon was beyond the scope of this investigation. The gas was predominantly methane. APPENDIX Log, Drill Hole 1 Location: 832.5 feet S. and 1,080 feet W. of NE. corner, sec. Seward Meridian, Houston, Alaska. 20, T. 18 N., R. 3 W., Elevation: Collar of hole -303 feet. In. 0 9 1 3 4% 3 9 6 9 2% 4 1 Ft. )th To- 11 22 23 27 27 30 30 30 31 31 32 32 33 35 In. 0 9 1 3 4% 3 9 6 9 2% 4 1 12 Clay overburden. ; Material Interbedded fine sandstone and silty claystone. Ironstone. Interlaminated fine sandstone and silty claystone. Bone. COAL, dull; thin anthraxylon bands and lenses. Bone. Ft. 11 Thickness 11 4 2 1 0 In. 9 4 2 1% 84 2' 6 9 3 51 1% 9 11% t Remarks Thin glacial cover previously stripped. Roof, "Pit" bed. Core loss, 4 in. Core loss, 7 in. Shale, dark gray, coaly streaks Claystone, dark gray, coaly I Shale, dark gray, carbonaceous. COAL, dull, thin anthraxylon lenses. Shale, dark gray, carbonaceous. Claystone, coaly. COAL, dull; thin anthraxylon streaks and lenses. Ft. 35 35 35 38 39 43 46 47 49 52 52 53 53 75 From- 77 80 81 82 86 86 87 90 92 99 109 242 243 258 296 300 302 312 322 323 332 Depth Y2 3 8 0 4 7 8 0 2 2 5 3 8 2 In. 13 Hole 1 (Con.) 35 35 38 39 43 46 47 49 52 52 53 53 75 77 Ft. To- 80 81 82 86 86 87 90 92 99 109 242 243 258 296 300 302 312 322 323 332 333 In. 3 8 0 4 7 8 0 2 2 5 3 8 2 2 10 8 1 2 5 9 5 1 6 6 0 9 9 9 5 6 8 11 7 2 10 Bone, broken. Bone. Claystone, fel Claystone, co. Clays tone. Claystone, si Ironstone. Claystone. Claystone, si Ironstone, coI Claystone, si Bone. Claystone, si. Sandstone, me, upper and lot Claystone, si: Sandstone, sit Claystone, si' Sandstone, si: Claystone, si: Sandstone, si: Claystone. Claystone, si: Ity. dium, grading wer strata. lty. lty. Ity. lty. lty. Ity. Material.., ,,,, .] w coaly streaks. aly. lty streaks. lty streaks. ncretionary. lty. into Ity; sandy streak. 0 Ft. and coal fragments. Claystone, silty; occasional coaly fragments Sandstone, clayey matrix. Sandstone, soft, medium to fine, containing multiple beds 2 1 4 3 2 3 21 2 3 4 1 2 1 7 10 132 1 15 38 3 2 10 10 8 1 Thicknes In. 5 4 4 3 1 4 2 0 3 10 5 6 0 4 of hard pebbles (quartz, chert rhyolite, felsite, basalt) and occasional coal fragments. Claystone, bone streaks. Claystone, silty Interbedded fine sandstone, siltstone, and claystone; occasional coaly streaks. Claystone, coaly; many bright- coal bands. Claystone, coaly; few bright- coal bands up to 1 in. thick. Interbedded claystone and silt- stone; occasional coaly fragments. Siltstone, sandy streaks. Claystone, coaly. Interbedded siltstone and fine sandstone. Interbedded siltstone and claystone. Remarks Core loss, 1 in. Floor, "Pit" bed. Bedding almost hori- zontal; infrequent crossbedding. Core loss, 2 ft. 5 in. Core loss, 111 ft. Core loss, 2 ft. Core loss, 1 ft. Core loss, 2 in. U Ft. 333 334 334 335 336 341 341 342 345 351 353 353 372 376 387 387 388 393 394 402 403 435 453 456 471 De From- In. -L 10 5 9 2 14 Hole 1 (Con.) Ft. 334 334 335 336 341 341 342 345 351 353 353 372 376 387 387 388 393 394 402 403 435 453 456 471 481 )tn- To- In. 5 9 2 0 Material Siltstone. Shale, soft, dark. Claystone. Shale, soft, dark, occasional coal fragments. Interbedded siltstone and fine sandstone. Sandstone, soft. Interbedded siltstone and fine sandstone. Sandstone, soft. Interbedded siltstone and claystone. Claystone, soft, dark. Siltstone. Interbedded claystone, silt- stone, and fine sandstone. Sandstone, soft. Interbedded claystone and shale, silty streaks. COAL, hard, bright; conchoidal fracture. Claystone, coaly. Claystone, silty streaks. COAL, hard, bright, bony streaks. Interbedded claystone and siltstone. Sandstone, medium fine. Sandstone, medium fine; soft layers and occasional coaly Ft. Thickness .-- .... ... . 0 5 2 6 1 18 4 10 1 5 7 1 32 17 3 14 10 7 4 5 10 2 7 6 11 3 7 6 6 9 9 1 1 0 8 9 3 6 6 0 9 6 In.Remarks Core loss, 6 in. 4 10 10 4 4 1 4 4 1 7 streaks. Sandstone, bands. Sandstone, Sandstone, cemented. soft, few pebble soft, medium fine. porous, poorly Core loss, 16 ft. 2 in. Core loss, 8 ft. 9 in. Gas flow accompanied by brackish water, static pressure in excess of 15 lb. per sq. in. Bedding remains almost horizontal; little dis- tortion evident. l Sandstone, alternating soft and dense, pebble bands, bot- tom of hole in hard, fine sandstone. -^--.-- Ft. 0 19 21 21 From- 33 80 105 106 115 116 126 129 173 175 176 181 182 183 184 186 186 204 205 241 244 260 310 313 Deoth 15 Log, Drill Hole 2 Location: 710 feet S. and 2,150 feet E. of NW. corner, sec. 20, T. 18 N., R. 3 W., Seward Meridian, Houston, Alaska. Elevation: Collar of hole -330 feet. 0 0 6 11 In. 19 21 Ft. 21 33 80 105 106 115 116 126 129 173 V 4 175 176 181 182 183 184 186 186 204 205 241 244 260 310 313 320 Tn- In. 0 6 11 6 0 2 0 9 3 2 0 3 1 7 9 3 7 9 4 11 5 2 2 2 9 3 4 9 Material Overburden, soil and gravel. Sandstone, medium coarse; iron stains. Shale, carbonaceous. Interbedded silty claystone and siltstone. Sandstone, soft, occasional pebble bands and coaly streaks. Claystone, occasional iron- stone nodules, coal fragments. Siltstone, dense Claystone. Siltstone, dense. Claystone. Claystone, coaly, frequent coal bands. Interbedded claystone, silt- stone, and very fine sand- stone; occasional pebbles and coaly streaks. Interbedded bony coal and coaly claystone. COAL, dull; bony streaks. Claystone; coal streaks and fragments. Claystone, coaly. COAL, dull; bony streaks. Shale, dark, coal streaks. Claystone. Claystone, coal streaks. Claystone, siltstone bands, and very fine sandstone bands. Shale, dark; coal streaks. Interbedded claystone, silt- stone and very fine sandstone. Sandstone, soft. Claystone, silty; few sandy streaks. Sandstone, soft, occasional pebble bands. Conglomerate, pebble; soft sandstone matrix. Sandstone, soft to dense. Thickness Ft. 19 2 11 46 25 9 9 2 44 1 1 5 1 1 1 17 36 3 16 49 3 7 In. 5 7 6 2 10 9 6 11 10 3 10 6 2 6 4 2 7 7 6 9 0 0 7 6 1 5 0 6 Bedding, where seen, almost horizontal. Core broken, pseudo- coal bed. Roof, "Pit" bed. Floor, "Pit" bed. Core loss, 2 ft. 3 in. Remarks 3 4 Ft. Ue From- 320 340 342 372 -.1. 3 76 383 399 412 432 435 435 435 436 437 437 438 438 440 440 441 441 445 461 461 461 462 462 463 477 484 508 509 511 16 Hole 2 (Con.) 7 9 In. 10 6 11 7 0 4 2% 4 9 10% 1X 6% /2 3 2 8 0 3 7 3 9 11 1 11 8 0 0 1 10 5 342 372 376 383 399 412 432 435 435 435 436 437 437 438 438 440 440 441 441 445 461 461 461 462 462 463 477 484 508 509 511 511 To-To- Ft. 340 11 7 10 7 0 4 2% 4 9 10l 1% 6% 3 2 8 0 3 7 3 9 11 1 11 8 0 0 1 10 5 8 6 In. Sandstone, dense; rew peDbbes and cobbles. Conglomerate, pebble, in soft sandstone matrix. Claystone, silty bands, occasional ironstone concre- tions and coaly streaks. Sandstone, soft, fine to medium. Claystone to silty claystone, occasional ironstone con- cretions. Claystone, carbonaceous; coal fragments. Sandstone, soft; few pebbles | 19 and occasional claystone bands and coaly fragments. Sandstone, soft. 2 Conglomerate, pebble and 29 cobble, soft sandstone matrix. Material Ft. COAL. Siltstone. Bone. COAL. Bone. COAL. Bone. Bone, coal streaks. Bone. COAL. Bone. Claystone, coal streaks. Interbedded claystone, silt- stone, and very fine sand- stone. Sandstone. Claystone. Sandstone, soft. Claystone. Claystone, coaly. Claystone, occasional sandy streaks. Sandstone, crossbedded, fine medium, few clay streaks. Claystone to silty claystone. Sandstone, soft. Claystone. Claystone, coaly. 4 6 15 13 19 3 9 In. Thickness 1 1 4 15 13 7 24 1 1 5 8 3 9 5 4 5 1% 2¼< 5 6 2% 11 6 4 3 4 8 6 2 2 10 9 4 0 1 9 7 3 Remarks Bedding where seen nearly horizontal. Core loss, 2 ft. Roof of bed corres- ponding to log, hole 1, 296 ft. 9 in. to 302 ft. 6 in. Floor. Bedding nearly flat. to Ft. From- I Depth * 511 533 533 543 545 571 605 610 648 652 666 675 692 697 726 728 729 730 733 735 740 742 744 753 805 832 |In. 17 Hole 2 (Con.) 0 8 0 3 11 0 4 4 10 3 0 0 0 3 2 7 11 7 7 7 8 6 3 11 8 To- 533 533 543 545 571 605 610 648 652 666 675 692 697 726 728 729 730 733 735 740 742 744 753 805 832 837 Ft. 0 8 0 In. 3 11 0 4 4 10 3 0 0 0 3 2 7 11 7 7 7 8 6 3 11 Material Claystone and fine sandstone, interbedded and crossbedded. COAL, bony. Interbedded claystone and fine sandstone. _ _ _ _ - Sandstone. Conglomerate, pebble to soft sandstone matrix. Sandstone, soft. Conglomerate, pebble to soft sandstone matrix. Thickness banasUone, claystone incluslons Sandstone, dense; calcite- filled fractures. Conglomerate, soft matrix. Dense sandstone, coaly fragments. Conglomerate, soft matrix. Claystone, silty. Claystone, silty; few bands of fine sandstone and occasional ironstone concretions and coaly streaks. Claystone, coaly. Claystone. Claystone, coaly. Interbedded claystone and fine sandstone. Claystone, coal streaks. Claystone, sandy streaks, and lenses. 26 cobble, 33 5 cobble, 38 21 9 .2 Ft. 4 13 8 17 5 29 1 1 1 2 2 5 In. 8 4 3 8 1 4 0 6 5 9 0 0 3 11 5 4 8 0 0 1 10 9 8 10 3 4 Remarks Transition. Bedding 15°, brackish water with evident gas pressure. Core loss, 28 ft. 8 in. Core loss, 2 ft. 1 in. Core loss, 30 ft. 9 in. Slickensides. Core loss, 12 ft. 11 in. Core loss, 7 ft. 1 in. Core loss, 12 ft. 9 in. Core loss, 7 in. Gas and water increasing down to this stratum. Static pressure up to 45 lb. Another gas channel apparent at 775 ft.; not measurable. I f Sandstone, fine to medium cross- 2 bedded; coaly streaks and occasional included pebbles. Claystone, coaly. 1 Interbedded claystone and fine 8 sandstone. Sandstone, fine to medium and 52 dense to porous, occasional claystone blebs, and pebble band at 794 ft. Claystone, silty and sandy 26 streaks. Sandstone, soft; claystone and 4 coaly streaks. 9 09 Ft. 837 840 843 847 848 850 876 876 880 895 897 Frnm- 903 906 913 917 937 943 979 985 985 986 987 987 988 988 1,013 1,044 Depth U 9 3 18 Hole 2 (Con.) 10 3 8 0 6 8 8 10 IIn. 840 843 847 848 850 876 876 880 895 897 903 Ft. 906 913 917 937 943 979 985 985 986 987 987 988 988 1,013 1,044 1,072 3 8 0 6 8 8 In. 9 3 10 8 To- 10 Material Claystone, sandy and coaly streaks. Claystone, coaly; many bright coal bands. Sandstone, soft; occasional claystone streaks. Claystone. Claystone, dark; bright coal streaks. Interbedded claystone and silt- stone. Sandstone, crossbedded; streaks of iron carbonate. Claystone, dark; occasional coal streaks. Interbedded claystone and silty claystone. Sandstone, fine, dense. Interbedded claystone and siltstone. Claystone, coaly. Interbedded claystone, silt- stone, and fine sandstone. Claystone, coaly; bright streaks. Interbedded claystone and silt- stone; occasional ironstone concretions. Claystone, coaly; many bright coal bands and streaks. Interbedded claystone, silt- stone, and fine sandstone; occasional ironstone con- cretions. Sandstone. COAL, bony and bright. Claystone, coaly. COAL, bright. COAL, bony and bright. COAL. Claystone, coaly. Interbedded claystone and silt- stone; 3-ft. zone of ironstone concretions at 994 ft. Sandstone, fine to medium; occasional claystone streaks. Sandstone; frequent conglom- erate lenses of indeterminate thickness. 3 Chickness 2 4 2 25 4 15 2 5 2 7 4 19 6 35 6 1 25 30 27 Ft.In. 6 7 5 5 4 6 2 0 2 10 5 5 2 11 0 5 0 9 5 0 3 8 5 2 10 6 9 Remarks I Tv Bedding of all above strata varies from 0° to 15°.i Core mangled; no loss. C 43 48 5C 51 53 53 53 55 58 60 87 87 90 96 97 I 0 6 6 5 11 2 5 7 0 7 4 6 9 10 11 6 48 50 51 53 53 53 55 58 60 87 87 90 96 97 103 103 122 123 125 126 126 126 19 Hole 2 (Con.) I t De th .. From- To- Thickness Ft. In. Ft. In. Material Ft. In. Remarks 1,072 0 1,097 1 Interbedded claystone and 25 1 silty claystone. 1,097 1 1,105 10 Claystone, dark; frequent 8 9 bright-coal streaks and scattered sandstone con- cretions. 1,105 10 1,106 2 Claystone. 4 1,106 2 1,112 3 Interbedded claystone, silt- 6 1 stone, and fine sandstone. 1,112 3 1,142 0 Sandstone, occasional clay- 29 9 _ stone streaks. Log, Drill Hole 3 Location: 920 feet N. and 265 feet W. of SE. corner, sec. 18, T. 18 N., R. 3 W., Seward Meridian, Houston, Alaska. Elevation: Collar of hole -249 feet. .43 -i,,, -.-43 6 5 11 2 5 7 0 7 4 6 9 10 11 6 0 11 4 6 Overburden, glacial sand, gravel, and boulders. Sandstone, dense, few included pebbles and cobbles. Claystone. Claystone, soft. Shale, dark. Claystone, coaly. Claystone, coaly streaks. Claystone, coaly. Claystone, dark, silty; occasional coaly streaks. COAL, bony. Interbedded claystone, silty claystone and siltstone. Sandstone. Claystone. Sandstone, porous, fine to medium, frequent clay bands. Sandstone, dense, fine. Claystone, silty, grading down to siltstone. COAL, bony. Interbedded claystone and silty claystone; occasional sandy streaks. Shale, carbonaceous. Claystone. Claystone, coaly. Claystone. Claystone, coaly. 1 3 1 27 3 6 5 18 2 43 5 1 1 1 6 0 11 6 3 3 2 5 7 9 2 3 1 1 7 6 11 5 8 2 10 1 5 Core loss, 3 ft. 4 in. Core loss, 9 in. Core loss, 1 ft., 2 in. 103 103 122 123 125 126 126 0 11 4 0 2 0 1 0 2 0 1 6 Ft. 126 127 127 133 142 145 177 181 182 196 199 217 224 233 236 243 244 244 256 258 260 333 337 From- In. Depth 6 0 11 5 10 8 3 Ft. 20 Hole 3 (Con.) 127 127 133 1 To- 42 145 177 181 182 196 199 217 224 233 236 243 244 244 256 258 260 333 337 386 In. 0 11 5 10 Claystone. Claystone, coaly. Claystone, dark; frequent coal streaks. Claystone to silty claystone, occasional coaly fragments. Interbedded coaly claystone and carbonaceous shale. Interbedded claystone, silty claystone, and very fine sandstone. Interbedded claystone and soft, porous sandstone. Claystone, coaly. Claystone, frequent silty and coaly streaks. Claystone, coaly. Claystone, occasional silty streaks. Sandstone, fine. Claystone. Claystone, coaly. Claystone, occasional thin coaly streaks. COAL, bony. Shale, carbonaceous. Claystone, occasional coaly fragments and ironstone nodules. Claystone, coaly. Shale, dark; few thin coaly streaks. Interbedded claystone, silt- stone, and very fine sand- stone. Sandstone, soft. Sandstone, soft, few pebbles included. ly IThickness 5 9 2 31 4 13 3 18 6 9 3 6 1 11 2 1 72 3 49 Material Ft. 0 6 11 6 In.Remarks Core loss, 1 ft. Core loss, 1 ft. 2 in. Core loss, 42 ft. Bedding throughout is 0° to 150, with mod- erate crossbedding. Regular bedding seldom exceeds 5°. .-..--.---.I .. INT. BU.OF MINES.PGH* ,rA .8485 Ic-apfm lOJan95 PLUGGING & State of Alaska LOCATION CLEARANCE REPORT ALASKA OIL & ~AS CONSERVATION COMMISSION PTD No. Lease Memorandum To File: API No. Well Name Operator Location Spud: ~-/~9/~, TD: ,{{[~ ~ , Completed Note casing size, wt, depth, cmt vol, & procedure. Sfc Csg: Long Csg: Liner: Perf intervals - tops: Review the well file, and comment on plugging, well head status, and location clearance - provide loc. clear, code. Plugs: Well head cut off: Marker post or plate: Location ClearanCe: Code Signed Date. . . Log, hole 1 Location: 1,665 feet S. and 2,160 feet W. of NE. corner Sec. 20, T. 18 N., R. 3 W., Seward Meridian, Houston, Alaska. 1 (1 1{}ù1 S~~t.\) JÚL . Thickness Ft. in. Collar of hole - 303 feet. Eleva,tion: D~th From- in. Ft. 'lo- in. Remarks Ft. Material o 0 1J. 0 Thin glacial cover previously stripped. 11 0 Clay overburden 11 0 Interbedded fine sandstone and silty claystone Ironstone Interlaminated fine sandstone, siltstone and silty claystone 4 Bone 0 COAL, dull with thin anthraxylon bands and lenses 2 Bone 0 Shale, dark gray, coaly streaks 0 Claystone, dark gray, coaly 0 Shale, dark gray, carbonaceous 0 COAL, dull, thin anthraxylon lenses 0 Shale, dark gray, carbonaceous 0 Claystone, coaly 0 COAL, dull with thin anthraxylon streaks and lenses 1 Bone, broken 0 Bone 0 Claystone, few coaly streaks 2 Claystone, coaly 1 Claystone 4 Claystone, silty streaks 3 Ironstone 0 Claystone 2 Claystone, silty streaks 3 Ironstone, concretionary 0 Claystone, silty 0 Bone 0 Claystone, silty 21 Sandstone, medium, grading into upper and lower strata Claystone, silty Sandstone, silty Claystone, silty Sandstone, silty Claystone, silty Sandstone, silty Claystone Claystone, silty, with sandy streaks and coal fragments 22 9 23 1 27 3 27 4~ 30 0-3/4 11 o 9 4 22 9 23 1 27 3 27 4~ 2 Roof, "Pit" bed. l~ ~ Core loss, 4 in. ï 24 6 9 3 0-3/4 30 3 3 30 9 9 31 6 6 31 9 1 9 32 22 30 30 30 31 31 32 32 33 Core loss, 1 in. 51- II 9 21 42 1 32 4 33 1 35 o~ 111. 21 5 4 4 3 1 4 2 o 3 10 5 6 35 ot 35 3 35 8 38 0 39 4 43 7 46 8 47 0 49 2 52 2 52 5 53 3 53 8 75 2 17 2 80 10 81 8 82 1 86 2 86 5 87 9 90 5 35 3 35 8 38 0 39 4 43 7 46 8 47 0 49 2 52 2 52 5 53 3 53 8 75 2 77 2 80 10 81 8 82 1 86 2 86 5 87 9 90 5 92 1 Core loss, 1 in. Floor, "Pit" bed. Bedding is almost horizontal, with infrequent cross- bedding. 2 0 3 8 o 10 o 5 4 1 o 3 1 4 2 8 8 1 ¡IX:> -Clc/if .¡¡ç,-~ ¡IX:> -01 D . . Log, hole 1 ( Cont. ) Depth From- To- Thickness Ft. in. Ft. in. Materia.l Ft. in. Remarks 92 1 99 6 Claystone" silty, with occasional coaly fragments 7 5 99 6 109 6 Sandstone" clayey matrix 10 0 Core loss 2 ft. 5 in. 109 6 242 0 Sandstone, ¡oft, medium to fine, containing multiple beds of hard pebbles (quartz, chert, rhyolite, felsite, basalt) and occasional coal fragments 132 6 Core loss 1ll ft. 242 0 243 9 Claystone bone streaks 1 9 243 9 258 9 Claystone, silty 15 0 Core loss 2 ft. o in. 258 9 296 9 Interbedded tine sandstone, lil tstone a.nd claystone with occasional coaly streaks 38 0 Core loss 1 ft. o in. 296 9 300 5 Claystone" coaly, wi th m~ bright coal bands 3 8 Core loss 2 in. 300 5 302 6 Claystone, coaly, with few bright coal bands up to 1 in. thick 2 1 302 6 312 8 Interbedded claystone and siltstone, with occasional coaly fragments 10 ! 312 8 3ft U Siltstone, sandy streaks 10 3 322 U 323 7 Claystone, coaly 0 8 323 7 332 2 Interbedded siltstone and fine sandstone 8 7 332 2 333 10 Interbedded siltstone and claystone 1 8 333 10 334 5 Siltstone 0 7 334. 5 334 9 Shale, soft, dark 0 4 334 9 335 2 Claystone 0 5 335 2 336 0 Shale, soft, dark, occasionaJ. coal fragments 0 10 336 0 341 2 Interbedded siltstone and fine sandstone 5 2 341 2 341 9 Sandstone, soft 0 7 341 9 342 3 Interbedded siltstone and fine sandstone 0 6 342 3 345 2 Sandstone, soft 2 11 345 2 351 5 Interbedded siltstone and claystone 6 3 351 5 353 0 Claystone, soft, dark 1 7 353 0 353 6 Siltstone 0 6 353 6 372 0 Interbedded claystone, siltstone and fine sandstone 18 6 372 0 376 9 Sandstone, soft 4 9 Core loss 6 in. 376 9 387 6 Interbedded. cla.ystone and shale, silty streaks 10 9 387 6 387 7 COAL, hard, bright, with conchoidal fracture 0 1 . . Log, hole 1 (Cont.) Depth From- To- Thickness Ft. ~. Ft. in. Material Ft. in. Remarks - - 387 7 388 8 Claystone, coaly 1 1 388 8 393 8 Cla.ystone, silty streaks 5 0 393 8 394 4 COAL, hard, bright, with bony streaks 0 8 394 4 402 1 Interbedded claystone and siltstone 7 9 402 1 403 4 Sand~tone medium-fine 1 3 ð 403 4 435 10 Sandstone, medium fine, with soft layers and occasional coaly streaks 3! 6 435 10 453 4 Sandstone, soft, with tew pebble bands 17 (; Core loss 16 ft. 2 in. 453 4 456 4 Sandstone soft, medium-fine 3 0 456 4 471 ¡ SaDdstone, porous, poorly ceJØeuted 14 9 Core loss 8 ft. 9 in. Gas flow acco~anied by brackish water - static ~re6sure in excess of 15 lbs. per sq. ia. 471 1 481 1 Sandstone, alternating soft and dense, pebble bands - bottom of bole in hard, tine sandstone 10 6 Bedd1r¡g remains al- most horizontal - little distortion evident. Log, hole ~ Location: 710 feet S. and 2,150 feet E. of NW. eorner Sec. !O, T. 18 N., R. 3 W., Seward Mer idian, Rous ton Alaska. Elevation: CoUar of hole - 330 feet. Depth T'o- From-- Ft. in. Ft. in. - - 0 0 19 0 19 0 21 6 21 6 21 U 21 11 33 6 33 6 80 0 80 0 105 ~ Thiçkness Material Ft. :in. Remarks - Overburden, soil and gravel 19 0 Saudstone, medium-coarse, With iron stains ~ 6 Shale, carbonaceous 0 5 Inte~bedded silty claystone and siltstone 11 7 Sal1dstone, 50ft, occasional pebble bands and coaly streaks 46 6 Bedding, where seen, almost horizontal. Claystone, occasional iron- stone nodules, coal fragments 25 2 Depth From- Ft. in. Ft. 105 2 106 0 115 9 116 3 126 2 129 0 173 3 175 1 176 7 181 9 182 3 183 7 184 9 186 4 186 11 204 5 205 2 241 2 244 2 260 9 310 3 313 4 320 9 340 6 342 11 372 7 376 10 To- in. 106 0 115 9 116 3 126 2 129 0 173 3 175 1 176 7 181 9 182 3 183 7 184 9 186 4 186 11 204 5 205 2 241 2 244 2 260 9 310 3 313 4 320 9 340 6 342 11 372 7 376 10 383 7 . Log, hole 2 (Cont.) Material Siltstone, dense Claystone Siltstone, dense Claystone Claystone, coaly, frequent coal bands Interbedded claystone, siltstone and very fine sandstone, with occasional pebbles and coaly streaks Interbedded bony coal and coaly claystone COAL, dull with bony streaks Claystone, with coal streaks and fragments Claystone, coaly COAL, dull with bony streaks Shale, dark, coal streaks Claystone Claystone, coal streaks Claystone, siltstone bands and very fine sandstone bands Shale, dark, with coal streaks Interbedded claystone, siltstone and very fine sandstc:le Sandstone, soft Claystone, silty with few sandy streaks Sandstone, soft, occasional pebble bands Conglomerate, pebble with soft sandstone matrix Sandstone, soft to dense Sandstone, soft, with few pebbles and occasional claystone bands and coaly fragments Sandstone, soft Conglomerate, pebble and cobble, soft sandstone matrix Sandstone, dense with few pebbles and cobbles Conglomerate, pebble, in soft sandstone matrix . Thickness Ft. in. Remarks o 10 9 9 o 6 9 11 2 10 Core broken, pseudo- coal bed. 44 3 Roof, "Pit" bed. 1 10 1 6 5 2 o 6 1 4 1 2 Floor, "Pit" bed. 1 7 o 7 17 6 o 9 36 0 3 0 16 7 49 6 3 1 Core loss 2 ft. 3 in. 7 5 19 9 2 5 29 8 4 3 Bedding, where seen, nearly horizontal 6 9 Depth From- To- Ft. in. Ft. in. 383 7 399 0 412 4 432 2~ 435 435 435 436 437 437 438 438 440 440 441 441 445 461 3 461 9 461 11 462 1 462 11 463 8 477 0 484 0 508 1 509 10 511 5 511 8 533 0 533 8 543 0 399 412 432 435 4 435 9 435 10~ 436 0-3/4437 It 437 6~ 438 0"2 438 3 440 2 440 8 441 o 441 3 445 7 461 9 10~ 0-3/4 11- 6f of 2 3 2 8 o 3 7 J 461 9 461 11 462 1 462 11 463 8 477 0 484 0 508 1 509 10 511 5 511 8 533 0 533 8 543 0 545 3 o 4 21- 2 4 . Log, hole 2 (Cont.) Material Claystone, silty bands, occasional ironstone concretions and coaly streaks Sandstone, soft fine to medium Claystone to silty claystone, occasional ironstone concretions Claystone, carbonaceous, with coal fragments COAL Siltstone Bone COAL Bone COAL Bone Bone with coal streaks Bone COAL Bone Claystone, coal streaks Interbedded claystone, siltstone and very fine sandstone Sandstone Claystone Sandstone, soft Claystone Claystone, coaly Claystone, occasional sandy streaks Sandstone, cross-bedded, fine to medium, few clay streaks Claystone to silty claystone Sandstone, soft Claystone Claystone, coaly Claystone and fine sandstone, interbedded and cross-bedded COAL, bony Interbedded claystone and fine sandstone Sandstone, claystone inclusions . Thickness Ft. in. Remarks -- 15 5 13 4 Core loss 2 ft. 0 in. 19 10~ 3 l~ Roof of bed corres- ponding to log, hole 1, 296 ft. 9 in. to 302 ft. 6 in. o 5 o l~ o 2t 1 0-3/4 o 5 o 6 o 2~ 1 11 o 6 o 4 o 3 4 4 Floor 15 8 o 6 o 2 o 2 o 10 o 9 13 4 Bedding nearly flat. 7 0 24 1 1 9 1 7 o 3 21 4 o 8 9 4 2 3 Transition . . Log, hole 2 (Cont.) Depth From- To- Thickness Ft. in. Ft. in. Material Ft. in. Remarks 545 3 571 11 Sandstone 26 8 Bedding 15 degrees. Brackish water with evident gas pressure. 571 11 605 0 Conglomerate, pebble to cobble, soft sandstone matrix 33 1 Core loss 28 ft.& in. 605 0 610 4 Sandstone, soft 5 4 Core loss 2 ft. 1 in. 610 4 648 4 Conglomerate, pebble to cobble, soft sandstone matrix 38 0 Core loss 30 ft.9 in. 648 4 652 10 Sandstone, dense, with calcite-filled fractures 4 6 Slickensides 652 10 666 3 Conglomerate, soft matrix 13 5 Core loss 12 ft.ll in. 666 3 675 0 Dense sandstone with coaly fragments 8 9 Core loss 7 ft. 1 in. 675 0 692 0 Conglomerate, soft matrix 17 0 Core loss 12 ft.9 in. 692 0 697 0 Claystone, silty 5 0 Core loss 0 ft. 7 in. Gas and water increas- ing down to this stratum. Stati c pres- sure up to 45 pounds. 697 0 726 3 Claystone, silty, with few bands of fine sandstone and occasional ironstone con- cretions and coaly streaks 29 3 726 3 728 2 Claystone, coaly 1 11 728 2 729 7 Claystone 1 5 729 7 730 11 Claystone, coaly 1 4 730 11 733 7 Interbedded claystone and fine sandstone 2 8 733 7 735 7 Claystone, coal streaks 2 0 735 7 740 7 Claystone, sandy streaks and lenses 5 0 740 7 742 8 Sandstone, fine to medium, cross-bedded, with coaly streaks and occasional included pebbles 2 1 742 8 744 6 Claystone, coaly 1 10 744 6 753 3 Interbedded claystone and fine sandstone 8 9 753 3 805 11 Sandstone, fine to medium and dense to porous, with occasional claystone blebs, f and pebble band at 794 ft. 52 8 Another gas channel apparent at 775 ft. , not measurable. 805 11 832 9 Claystone, silty and sandy streaks 26 10 . . Log, hole 2 (Cant.) Depth From- To- Thickness Ft. in. Ft. in. Material Ft. in. Remarks 832 9 837 0 Sandstone, soft, with claystone and coaly streaks 4 3 837 0 840 9 Claystone, sandy and coaly streaks 3 9 840 9 843 3 Claystone, coaly, with many bright coal bands 2 6 843 3 847 10 Sandstone, soft, with occasional claystone streaks 4 7 847 10 848 3 Claystone 0 5 848 3 850 8 Claystone, dark, with bright coal streaks 2 5 850 8 876 0 Interbedded claystone and siltstone 25 4 876 0 876 6 Sandstone, cross-bédded, with streaks of iron carbonate 0 6 876 6 880 8 Claystone, dark, with occasional coal streaks 4 2 880 8 895 8 Interbedded claystone and silty claystone 15 0 895 8 897 10 Sandstone, fine, dense 2 2 897 10 903 8 Interbedded claystone and siltstone 5 10 903 8 906 1 Claystone, coaly 2 5 906 1 913 6 Interbedded claystone, siltstone and fine sandstone 7 5 913 6 917 8 Claystone, coaly, with bright coal streaks 4 2 917 8 937 7 Interbedded claystone and siltstone, with occasional ironstone concretions 19 11 937 7 943 7 Claystone, coaly, with many bright coal bands and streaks 6 0 943 7 979 0 Interbedded claystone, silt- stone and fine sandstone, with occasional ironstone concretions 35 5 Bedding of all above strata varies from 0 to 15 degrees 979 0 985 0 Sandstone 6 0 985 0 985 9 COAL, bony and bright 0 9 985 9 986 2 Claystone, coaly 0 5 986 2 987 2 COAL, bright 1 0 987 2 987 5 COAL, bony and bright 0 3 987 5 988 1 COAL 0 8 988 1 988 6 Claystone, coaly 0 5 . . Log, hole 2 (Cont.) Depth From- To- Thickness Ft. in. Ft. in. Ma.terial Ft. in. Remarks 988 6 1013 8 Interbedded claystone and siltstone, with 3 ft. zone of ironstone concretions at 994 ft. 25 2 1013 8 1044 6 Sandstone, fine to medium, occasional claystone streaks 30 10 1044 6 1072 0 Sandstone with frequent conglomerate lenses of indeterminate thickness 27 6 Core mangled, no loss. 1072 0 1097 1 Interbedded claystone and silty claystone 25 1 1097 1 1105 10 Claystone, dark, wi th frequent bright coal streaks and scattered sandstone concretions 8 9 1105 10 1106 2 Claystone 0 4 1106 2 1112 3 Interbedded claystone, siltstone and fine sandstone 6 1 1112 3 1142 0 Sands tone, occasional claystoüe streaks 29 9 Log, hole 3 Location: 920 feet N~ and 265 feet 'VI. of SE. corner Sec. 18, T. 18 N., R. 3 W., Seward Meridian, Houston, Alaska Elevation: Collar of hole - 249 feet. Depth From- To- Thickness Ft. in. Ft. in. Naterial Ft. in. Remarks --- 0 0 43 6 Overburden, glacial sand, gravel and boulders 43 6 43 6 48 6 Sandstone, den.se, few included pebbles and cobbles 5 0 Core loss 3 ft. 4 in. 48 6 50 5 Claystone 1 11 Core loss 9 in. 50 5 51 11 Claystone, soft 1 6 Core loss 1 ft. 2 in. 51 11 53 2 Shale, dark 1 3 53 2 53 5 Claystone, coa.ly 0 3 53 5 53 7 Claystone, coaly streaks 0 2 53 7 55 0 Claystone, coaly 1 5 55 0 58 7 Claystone, dark, silty, with occasional coaly streaks 3 7 58 7 60 4 COAL, bony 1 9 60 4 87 6 Interbedded claystone, silty claystone and siltstone 27 2 . . Log, hole 3 (Cont.) Depth From- To- Thickness Ft. in. Ft. in. Material Ft. in. Remarks 87 6 87 9 Sandstone 0 3 87 9 90 10 Claystone 3 1 90 10 96 11 Sandstone, porous, fine to medium, frequent clay bands 6 1 96 11 97 6 Sandstone, dense, fine 0 7 97 6 103 0 Claystone, silty, grading down to siltstone 5 6 103 0 103 11 COAL, bony 0 11 103 11 122 4 Interbedded claystone and silty claystone, with occasional sandy streaks 18 5 122 4 123 0 Shale, carbonaceous 0 8 123 0 125 2 Claystone 2 2 125 2 126 0 Claystone, coaly 0 10 126 0 126 1 Claystone 0 1 126 1 126 6 Claystone, coaly 0 5 126 6 127 0 Claystone 0 6 127 0 127 11 Claystone, coaly 0 11 127 11 133 5 Claystone, dark, with frequent coaly streaks 5 6 133 5 142 10 Claystone to silty claystone, occasional coaly fragments 9 5 142 10 145 8 Interbedded coaly claystone and carbonaceous shale 2 10 145 8 177 3 Interbedded claystone, silty claystone and very fine sandstone 31 7 177 3 181 8 Interbedded claystone and soft porous sandstone 4 5 Core loss 1 ft. 181 8 182 6 Claystone, coaly 0 10 182 6 196 1 Claystone, frequent silty and coaly streaks 13 7 196 1 199 4 Claystone, coaly 3 3 199 4 217 6 Claystone, occasional silty streaks 18 2 217 6 224 0 Sandstone, fine 6 6 224 0 233 4 Claystone 9 4 233 4 236 9 Claystone, coaly 3 5 236 9 243 0 Claystone, occasional thin coaly streaks 6 3 243 0 244 0 COAL, bony 1 0 244 0 244 3 Shale, carbonaceous 0 3 244 3 2?6 1 Claystone, occasional coaly fragments and ironstone nodules 11 10 256 1 258 8 Claystone, coaly 2 7 258 8 260 4 Shale, dark, with few thin coaly streaks 1 8 Depth From- To- Ft. in. Ft. in. 260 4 333 1 333 1 337 0 337 0 386 0 . Log, hole 3 (Cont.) Material Interbedded claystone, siltstone and very fine sandstone Sandstone, soft Sandstone, soft, few pebbles included . Thickness Ft. in. Remarks 72 9 3 11 Core loss 1 ft. 2 in. 49 0 Core loss 42 ft. Bedding throughout is o to 15 degrees, with moderate cross- bedding. Regular bedding seldom exceeds 5 degrees. Depth ~" F~'om- To- _ ~ L,,og~' hole 2 (Cont.) Thickness Material Ft. in. 988 6 lo13 8 lO13 8 lo44 .' 6 1044 6 lo72 0 1072 o 1097 1 1097 1 11o5 10 11o5 lO 11o6 11o6 2 1112 1L~2 3 1142 o Location: Interbedded claystone and siltstone, with 3 ft. zone of ironstone concretions at 994 ft. 25 2 Sandstone, fine to medium, occasional claystone streaks 30 10 Sandstone with frequent conglomerate lenses of indeterminate thickness 27 Interbedded claystone and silty claystone 25 Claystone, dark, with frequent bright coal streaks and scattered sandstone concretions 8 Claystone 0 Interbedded claystone, siltstone and fine sandstone 6 Sandstone, occasional claystone streaks 29 Log, holm 3 ' 920 feet N. and 265.feet W. of SE. corner Sec. 18, T. 18 N., R. 3 W.,",,~eward Meridian, Houston, Alaska ,: 6 Core mangled, no loss. ., 4 ,';4" . . .~. Elevation: Collar of hole - 249 feet. Depth _ From- To~ -- Ft. in. Ft. in. Material i .1 -- --- -- "' ~ o o 43 6 43 6 48 6 ~8 6 50 5 5o 5 51 n 51 il 53 2 53 2 53 5 53 ? '55 o 55 o ~ 7 58 7 60 4 60 4 87 6 Overburden, glacial sand, gravel and boulders 43 6 Sandstone, dense, few included pebbles and cobbles Claystone Claystone, soft Shale, dark 1 3 Claystone, coaly 0 Cleystone, coaly streaks 0 2 Claystone, coaly 1 5 Olaystone~ dark, silty, with occasional coaly streaks 3 COAL, bony 1 9 Interbedded claystone, silty claystone and siltstone . 27 2 ~.hi.ckness ~' Ft. in. Remarks'_ - - - ~,L , 5 '0 Core loss 3 fti~4 in. 1 11 Core loss 9 in~'.' 1 6 Core loss 1 ft,.2 in. Delq,.t,h From- To- Ft. -in. Ft. i~. 87 9 90 lO \ 90 lO 96 ll ~ · 96 LI 97 '6 97 6 103 0 lO3 o lO3 11 103 11 122 4 122 4 123 o 123 o 125 2 125 ~ 2 126 -0 126 0 126 1 126 1 126 6 126 6 127 o 127 o 127 11 127 11 133 5 133 5 i42 10 14~ lO 145 8 177 3 145 8 177 3 181 8 181 8 182 6 182 6 196 196 1 199 4 199 4 217 6 · Zl7 6 224 0 233 4 ~36 9 243 0 244 0 244 3 224 0 233 -~ 4 236 . 9 243 0 0 3 ~6 '. 2~6 · 2~8 8 256 § ~6o ~ Lo~, ~hole _3 (Con. t, ) Material Sandstone Claystone Sandstone, porous, fine to edium, frequent clay bauds andstSne, dense, fine Claystone, silty, grading down to siltstone COAL, bony Interbedded claystone and silty claystone, with occasional sandy'streaks Shale, carbonaceous Claystone Claystone, coaly ClaYstone Claystone, coaly Claystone Claystone, coaly Claystone, dark, with frequent coaly streaks Claystone to silty claystone, occasional coaly fragments Interbedded coaly claystone and carbonaceous shale Interbedded claystone, silty claystone and very fine sandstone Interbedded claystone and soft porous sandstone Claystone, coaly Claystone, frequent silty and coaly streaks Claystone, coaly Claystone, occasional silty streaks Sandstone, fine Claystone Claystone, coaly Claystone, occasional thin coaly streaks COAL, bony Shale, carbonaceous Claystone, occasional coaly fragments and ironstone nodules Claystone, coaly Shale,. dark, with £ewthln coaly streaks' Thickness Ft. in. 18 5 o 8 2 2 0 10 0 1 o 5 o 6 0 11 31 7 11 10 . Depth '" From- To- - , r, 1, , 111 Ft. in. Ft. in. Log, hole 3 (Cont..) Material Thickness FTYS.' in~.~ Remarks 260 4 333 i 333 1 337 o 337 0 386 0 Interbedded claystone, siltstone and,very fine sandstone Sandstone, soft ' Sandstone, soft, few pebbles included 7~ 9 3 11 Core loss 1 ft,....2 in. ~9 0 Core loss ~2 ft. Bedding throughout is 0 to 15 degrees, with moderate cross- bedding. Regular bedding seldom';exceeds 5 degrees, i.., _