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Home My WebLink About100-0031 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Wednesday, November 5, 2025 12:13 PM To:Brandenburg, Timothy Cc:Regg, James B (OGC); Earl, Adam G (OGC) Subject:RE: Rosetta 1 - Approved Sundry 324-521 and 325-323 Tim, The plan you’ve outlined below is approved. Please provide notice for the AOGCC inspector to have an opportunity to look at the results of the cement job before welding on the marker plate. 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: Wednesday, November 5, 2025 10:15 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Rosetta 1 - Approved Sundry 324-521 and 325-323 Bryan, At Rosetta 1, we encountered a solid base cement around approx. ¼ of the circumference of the 10” ax 12-3/4” annulus at approximately 28”. Beyond that, the annulus was cleaned to an eƯective max depth of ~16’. Pending approval, the proposed plan forward is to run pipe into the annulus as deep as practical and pump cement to surface. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Timothy C. Brandenburg ASRC Energy Services, Inc. tbrandenburg@asrcenergy.com Cell: 907-252-3923 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:20 Township:18N Range:3W Meridian:Seward Drilling Rig:Rig Elevation:Total Depth:4260 ft MD Lease No.:Orphan Well Operator Rep:Suspend:P&A:X Conductor:12-3/4"O.D. Shoe@ Unknown Feet Csg Cut@ Feet Surface:O.D. Shoe@ Feet Csg Cut@ Feet Intermediate:10"O.D. Shoe@ 650 Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 1800 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 1600 ft 177 ft 8.3 ppg C.T. Tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Tagged high. They were looking for 300 ft MD for top of cement but as per the approved procedure anything deeper than 150 ft MD would be good. Next step is tubing punch to circulate the IA with cement to surface for the top cement job per ASRC representative Josh Murphy. There was no pressure test required on this plug. July 3, 2025 Kam StJohn Well Bore Plug & Abandonment Rosetta 1 ASRC Energy Services Alaska Inc. PTD 1000030; Sundry 325-323 none Test Data: Casing Removal: Josha Murphy Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0603_Plug_Verification_Rosetta-1_ksj               From:Lau, Jack J (OGC) To:McVey, Adrienne Cc:McLellan, Bryan J (OGC); Rixse, Melvin G (OGC); Cismoski, Doug; Dial, Amanda; Brandenburg, Timothy; Joshua Murphy Subject:RE: Rosetta 1 (PTD 100-003) Plan Forward for surface plug Date:Thursday, July 3, 2025 3:26:47 PM Thanks for the detailed variance request Adrienne. Variance approved as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement. Jack From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Thursday, July 3, 2025 2:47 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Joshua Murphy <josh@mpactes.com> Subject: RE: Rosetta 1 (PTD 100-003) Plan Forward for surface plug Jack, Per our conversation, when we ran in hole with the Gator Perforator tool (5.70” OD), we tagged at 122’, versus the previous tag depth of 177’ with a 2.375” nozzle. This tag depth with the tool would put the base of our surface cement plug at 108’, which would require a waiver to the requirements of 20 AAC 25.112(d)(1). Justification for this request is as follows: Cement plugs #1 and #2 were placed per the approved Sundry (except for the higher- than-planned TOC of plug #2), and meet requirements for isolating hydrocarbon-bearing strata, isolating fresh water (base of fresh water at 440’), and segregating the cased and uncased portions of the wellbore. Casing and annulus pressures = 0 psi, indicating the cement currently in place is effective. TOC in 7” casing = 122’, based on tag depth with Gator Tool (Plug #2) TOC in 7” x 10” annulus = 350’, based on 4/22/25 memory CBL There is significant operational risk associated with attempting a clean-out of contaminated cement. For these reasons, I am requesting the waiver mentioned above, and proposing the following revised plan forward: ⚠️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. Perforate the 7” casing at 163’ 108’ (perforation depth is 14’ above the tag depth/bottom of toolstring depth of 177’ 122’) Circulate cement plug #3 into 7” casing and 7” x 10” annulus through the perforations at 163’ 108’ I am requesting a waiver to 20 AAC 25.112(d)(1), which requires a surface plug of at least 150’ in length within the smallest diameter casing string. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, July 3, 2025 10:56 AM To: McVey, Adrienne <amcvey@asrcenergy.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Joshua Murphy <josh@mpactes.com> Subject: RE: Rosetta 1 (PTD 100-003) Plan Forward for surface plug Good morning Adrienne, Your proposal detailed below meets the regulations and is approved. A 10-403 for change of approved program is not required as this email will suffice. Jack From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Thursday, July 3, 2025 10:50 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Joshua 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. Murphy <josh@mpactes.com> Subject: Rosetta 1 (PTD 100-003) Plan Forward for surface plug Jack, Per our phone conversation, we tagged cement plug #2 (inside 7” casing above retainer) 123’ higher than planned. Planned TOC = 300’, actual TOC = 177’. Our plan forward: Perforate the 7” casing at 163’ (perforation depth is 14’ above the tag depth/bottom of toolstring depth of 177’) Circulate cement plug #3 into 7” casing and 7” x 10” annulus through the perforations at 163’ This is deep enough to provide a 150’ surface plug. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 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:Lau, Jack J (OGC) To:McVey, Adrienne Cc:McLellan, Bryan J (OGC); Rixse, Melvin G (OGC); Cismoski, Doug; Dial, Amanda; Brandenburg, Timothy; Joshua Murphy Subject:RE: Rosetta 1 (PTD 100-003) Plan Forward for surface plug Date:Thursday, July 3, 2025 10:56:27 AM Good morning Adrienne, Your proposal detailed below meets the regulations and is approved. A 10-403 for change of approved program is not required as this email will suffice. Jack From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Thursday, July 3, 2025 10:50 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Joshua Murphy <josh@mpactes.com> Subject: Rosetta 1 (PTD 100-003) Plan Forward for surface plug Jack, Per our phone conversation, we tagged cement plug #2 (inside 7” casing above retainer) 123’ higher than planned. Planned TOC = 300’, actual TOC = 177’. Our plan forward: Perforate the 7” casing at 163’ (perforation depth is 14’ above the tag depth/bottom of toolstring depth of 177’) Circulate cement plug #3 into 7” casing and 7” x 10” annulus through the perforations at 163’ This is deep enough to provide a 150’ surface plug. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From:McLellan, Bryan J (OGC) To:McVey, Adrienne; Rixse, Melvin G (OGC) Cc:Danny Kara; Cismoski, Doug; Dial, Amanda; Brandenburg, Timothy; Joshua Murphy; Seymour, Len Subject:RE: Rosetta 1 Detailed P&A Procedure Date:Tuesday, July 1, 2025 11:20:00 AM Approved. 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: Saturday, June 28, 2025 10:08 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com>; Joshua Murphy <josh@mpactes.com>; Seymour, Len <lseymour@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure All, Rosetta 1 Final Program, with edits described below, is attached. I also added a step to perform an injectivity test below the cement retainer before starting the downsqueeze, and updated the coiled tubing length in Table to 13,000’. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Thursday, June 26, 2025 2:37 PM ⚠️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. To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure Thank you! Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, June 26, 2025 2:33 PM To: McVey, Adrienne <amcvey@asrcenergy.com> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure Change of fluid type is approved. 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, June 26, 2025 2:31 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure Bryan, Thank you! Please see below. I will send out a Revision 2 pending your responses. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 4.3.1 Tapered mill instead of tri-cone for drift run: the primary areas of concern on the drift run are a weld seam within the wellhead and any restrictions associated with possible perfs at 730-820’. I discussed what sort of bit or mill would be most effective for cleaning up these potential ID restrictions and Yellowjacket recommended a tapered mill. 4.3.4 Fluid type for circulating 2x bottoms up: planning fresh water. I note the original approved Sundry (324-521) specified 9.6 ppg brine or water-based mud. We have since learned: · Prior to wellhead installation, Rosetta 1 was leaking about 10 bbl of brackish water per day with no measurable LEL’s. · Since wellhead installation, the well stacks out to about 90 psi. · If we assume the brackish water currently in the well has a density of 8.4 ppg, SIWHP after we circulate the well to fresh water from 1600’ will be approximately 200 psi. · For these reasons (low pressure, low flow potential of mainly brackish water with small amounts of gas), I do not think KWF is necessary for Rosetta 1. · Since this is now a summertime operation, freeze point is not a concern. · Fluid mixing operations in the field entails handling and hand-cutting 50-lb sacks of salt. · To minimize fluid mixing operations in the field, and for cost efficiency, I am requesting a change to the approved Sundry to use fresh water as our work fluid. 4.5.4 Fluid type left in hole after laying in plug #2 to 300’: planning fresh water. I’ll add this. 4.7.5 If we establish circulation much shallower than the initial Gator perf depth of 300’: · I’ll edit the program to reflect that we’ll work up the hole in 25’ intervals and only contact you if we get up to 150’ and still can’t circulate. · I think this is unlikely since the CBL showed clear TOC at ~350’. · Establishing a base for cement: we can set a contingent CIBP below our CAUTION: This email originated from outside the State of Alaska mail system. Do not ⚠️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. shallowest perf depth before pumping the surface plug. I confirmed Yellowjacket will have one available, and I confirmed with Gator there is no issue running a CIBP past their perfs. · I did look into a cement basket option; that is more expensive than the CIBP. 4.8.4 Cement density for plug #3: 15.3 ppg. Same blend as for plugs #1 and #2. I’ll add this. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 25, 2025 3:42 PM To: McVey, Adrienne <amcvey@asrcenergy.com> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure Adrienne, What’s the reason for using the tapered mill to drift instead of a Tri-cone? Just curious, I don’t feel strongly either way. 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: Tuesday, June 24, 2025 9:10 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure click links or open attachments unless you recognize the sender and know the content is safe. Bryan, Please see attached Rev 1. I realized I hadn’t updated Appendix B: Proposed Wellbore Schematic to reflect base of cement plug #1 at 2115’ (deepest hydrocarbon). Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: McVey, Adrienne Sent: Tuesday, June 24, 2025 8:23 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: Rosetta 1 Detailed P&A Procedure Bryan, Attached is the Rosetta 1 detailed P&A procedure for your review. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 Rosetta 1 Plug and Abandon Detailed Procedure – FINAL June 28, 2025 API #: 50-009-10014-00-00 PTD: 100-003 Prepared for Alaska Oil and Gas Conservation Commission 333 West 7 th 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 Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC i June 2025 18697-01 Rev. 2 TABLE OF CONTENTS Page Table of Contents ........................................................................................................................................... i 1.0 Introduction ...................................................................................................................................... 3 1.1 Objective .................................................................................................................. 5 1.2 Scope .................................................................................................................. 5 1.3 AOGCC Notification Requirements Summary................................................................... 5 1.4 Contacts .................................................................................................................. 6 2.0 Equipment, Supplies, and Services .................................................................................................. 6 2.1 Equipment & Services ........................................................................................................ 6 2.2 Fluids Program .................................................................................................................. 7 2.3 Cement Program ................................................................................................................. 7 2.4 Well Control Program ......................................................................................................... 8 2.5 Waste Management Program .............................................................................................. 8 3.0 Pre-Coiled Tubing Work .................................................................................................................. 9 4.0 Plug and Abandon Procedure ........................................................................................................... 9 4.1 Rig Up .................................................................................................................. 9 4.2 Coiled Tubing Unit Data ................................................................................................... 10 4.3 Drift Run ................................................................................................................ 10 4.4 Set Cement Retainer ......................................................................................................... 11 4.5 Pump Cement Plugs #1 and #2 ......................................................................................... 12 4.6 Tag Cement Plug #2 (AOGCC-Witnessed) ...................................................................... 12 4.7 7” Casing Perforation for Cement Plug #3 ....................................................................... 13 4.8 Cement Plug #3 ................................................................................................................ 14 4.9 Wellhead Removal ............................................................................................................ 15 List of Tables Table 1.3-1: AOGCC Notification Requirements Summary ........................................................................ 5 Table 1.4-1: Contacts .................................................................................................................................... 6 Table 2.1-1: Equipment Table ...................................................................................................................... 6 Table 2.2-1: Fluids Program Table ............................................................................................................... 7 Table 2.3-1: Cement Program Table ............................................................................................................. 7 Table 2.4-1: Well Control Equipment Table ................................................................................................ 8 Table 4.2-1: Coiled Tubing Data Table ...................................................................................................... 10 Table 4.3-1: Drift BHA ............................................................................................................................... 10 Table 4.3-2 Mud Motor Table..................................................................................................................... 11 Table 4.5-1: Cement Retainer BHA ............................................................................................................ 11 Table 4.4-1: Tagging BHA ......................................................................................................................... 13 Table 4.6-1: Gator Mechanical Perforator BHA ......................................................................................... 13 AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC ii June 2025 18697-01 Rev. 2 List of Appendices Appendix A: Current Wellbore Schematic Appendix B: Proposed Wellbore Schematic Appendix C: Cement Lab Test Results Appendix D: Fox Energy BOP Diagram Appendix E: As Built Surface Location Diagram Appendix F: Wellhead and Cellar Diagram Appendix G: Fox Energy Services BOP Test Procedure Appendix H: Drift BHA Drawing Appendix I: Mud Motor Performance Chart Appendix J: FH Cement Retainer BHA Drawing Appendix K: Gator Mechanical Perforator BHA Drawing Appendix L: AES Nitrogen SOP AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 3 June 2025 18697-01 Rev. 2 1.0 Introduction The Rosetta 1 well is planned for plug and abandonment (P&A) as part of the AOGCC Orphan Well Plugging and Remediation Program. The P&A work will be conducted by ASRC Energy Services Alaska, Inc. (AES-AK) as operator, on behalf of the AOGCC. Coiled tubing work on Rosetta 1 is scheduled to begin Summer 2025. Rosetta 1 was spudded in June 1954 as an exploration test well. The well was TD’ed 5 years later, in June 1959, after annual seasonal operations. The original plug and abandonment Sundry (324-521) was approved by the AOGCC on September 23, 2024. Wellhead installation work in February 2025, and Slickline diagnostic work in April 2025, yielded additional information, and a Sundry – Change Approved Program Request (325-323) was approved by the AOGCC on June 5, 2025. The well has a 12-3/4” conductor cemented to surface (conductor shoe depth unknown), 10” surface casing set at 650’ and cemented to surface, and 7” production casing set at 1800’ and cemented to ~350’ (memory CBL run 4/22/25). The 7” production casing is slotted from 1678’ – 1800’. 8-3/4” open hole TD/PBTD is 4260’. The well file indicated an existing cement plug just below the 7” shoe from 1800’ – 1915’; however, a Slickline drift to 2100’ on 4/22/25 showed that plug was not present. A slip-on wellhead was installed on 2/28/25. Prior to wellhead installation a small hole in the 7” casing was leaking approximately 10 bpd water/brine with small gas bubbles (no measurable LEL). Since wellhead installation, the observed shut-in wellhead pressure is 90 psi. The maximum planned depth of coiled tubing operations is 1600’, to stay clear of the slotted 7” casing from 1678’ – 1800’. Given this maximum planned depth is shallower than the Slickline drift to 2100’ on 4/22/25, the realistic Maximum Anticipated Surface Pressure is the stabilized observed shut-in wellhead pressure of 90 psi. As based upon information within the AOGCC & DNR well files from the original drilling of Rosetta 1, the deepest reported indication of coal, gas, or oil is ~2115’ MD. The strata through this interval 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. Strata below this depth have very little likelihood of containing hydrocarbons as indicated from comments within the files and lithology and mud log data captured during drilling. Base of fresh water is estimated at 440’ MD / TVD. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 4 June 2025 18697-01 Rev. 2 Rosetta 1 Wellhead, installed February 28, 2025 10” x 7” annulus access 12-3/4” x 10” annulus access AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 5 June 2025 18697-01 Rev. 2 1.1 Objective The objective of this procedure is to is to permanently abandon the Rosetta #1 wellbore, including isolating and protecting the freshwater aquifer. Base of fresh water is estimated at 440’. 1.2 Scope x Site preparation - completed x Wellhead installation - completed x Evaluate 7” top of cement (TOC) with logging tools – completed with Slickline 4/22/25 x Cement 7” casing, cement 7” x 10” annulus x Cut off wellhead, weld on marker plate x Backfill and grade site Refer to Appendix A: Current Wellbore Schematic and Appendix B: Proposed Wellbore Schematic for additional information. 1.3 AOGCC Notification Requirements Summary Table 1.3-1: AOGCC Notification Requirements Summary Event Notice Required Notification Method Comments BOP test 24 hours before Test Witness Notification web form Tag cement plug #2 24 hours before Test Witness Notification web form Tag cement plug #2 with 5,000 lbs down to verify TOC (~300’). If circulation can’t be established into annulus DW¶after perforating As soon as possible Contact Bryan McLellan Significant change to perforating and cement plan will require a Sundry – Change Approved Program request. Wellhead post-cutoff, before and after cement top-off 24 hours before Test Witness Notification web form Specified in approved Sundry. Final location clearance inspection 10 days Test Witness Notification web form 10 days specified in approved Sundry. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 6 June 2025 18697-01 Rev. 2 1.4 Contacts Table 1.4-1: 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 Len Seymour 907-727-4540 lseymour@asrcenergy.com AES-AK Wellsite Leader Josh Murphy 817-773-5447 josh@mpactes.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 2.1 Equipment & Services Table 2.1-1: Equipment Table Equipment Vendor Contact Origin Coiled tubing unit Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Coiled tubing pump Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Hardline Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Cement pump, silo, blend Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Batch mixer (two 55-bbl pods) Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Coiled tubing BHAs Yellowjacket Oilfield Services Jerry Winfrey (562) 881-5673 Nikiski Cement retainer Alaska Product Solutions Ron Doshier (907) 250-5451 Anchorage Gator Perforator Tool Lee Energy Systems Stuart Butcher (403) 700-5772 Anchorage Fluids handling: frac tank with diffuser, cuttings boxes, dual filter pod, 120-bbl vac truck, hoses MagTec Tyler Timm (907) 398-5255 Kenai Potable water tanker trailer, 130 bbl MagTec Tyler Timm (907) 398-5255 Kenai Rig mats MagTec Tyler Timm (907) 398-5255 Kenai Wellhead stabilizer, 7” riser and flow cross, 7” x 1502 crossover Team Snubbing International Troy LeBlanc (780)446-3658 Nikiski Wellhead equipment Vault Pressure Control Hans Schegel (907) 953-1412 Soldotna AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 7 June 2025 18697-01 Rev. 2 2.2 Fluids Program Table 2.2-1: Fluids Program Table Fluid Vendor Contact Origin Water (work fluid, cement mix water) City of Wasilla Bulk Water Station, 550 N. Weber Drive Public Works Department (907) 373-9010 Wasilla NaCl 9.8 ppg brine – if necessary Halliburton Baroid (mix onsite with Fox batch mixer) Derek Rader (907) 351-3772 Nikiski Gelling agent Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Friction reducer for milling Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Cement retarder Fox Energy Services LLC Terence Rais (907) 887-1766 Nikiski Nitrogen Airgas (907) 376-6000 Wasilla 2.3 Cement Program Table 2.3-1: Cement Program Table Casing Size Type Density Yield Interval Slurry Volume Thickening Time Plug #1: across 7” casing shoe (downsqueeze through cement retainer) Class G + Dispersant + FLAC + Retarder 15.3 ppg 1.24 ft3/sk 1600’ – 2115’ 43 bbl 3:57 Plug #2: 7” Casing (lay in with CTU on top of retainer) Class G + Dispersant + FLAC + Retarder 15.3 ppg 1.24 ft3/sk 1600’ – 300’ 53 bbl 3:57 Plug #3: 7” Casing + 7” x 10” annulus (pump directly into 7” casing with crossover installed on master valve) Class G + Dispersant + FLAC + Retarder 15.3 ppg 1.24 ft3/sk 0’ – 300’ 24 bbl 3:57 Refer to Appendix C: Cement Lab Test Results for additional information. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 8 June 2025 18697-01 Rev. 2 2.4 Well Control Program Table 2.4-1: Well Control Equipment Table Equipment Detail BOPE • 4-1/16” Stripper: 10,000 psi • 4-1/16” Lubricator: 15,000 psi • 4-1/16” Combi BOP: 10,000 psi • Upper rams: Blind / Shear • Lower rams: Pipe / Slip • 7-1/16” Flanged Lubricator: 5,000 psi • 7-1/16” Flow Cross: 5,000 psi • 7-1/16” Gate Valve / Swab: 5,000 psi (will move from well to well) x 7-1/16” Gate Valve / Master: 5,000 psi (pre-installed on wellhead) Choke Manifold • 2-inch, (5) valve choke manifold Accumulator Unit • 4 high pressure accumulator 11 gallon bottles (44 gallons total) Refer to Appendix D: Fox Energy BOP Diagram for additional information. 2.5 Waste Management Program Two options exist for Class I and II waste disposal: x Alaska Eco Resources (AER) Monofill in Nikiski. An approved Waste Profile Sheet (one per waste stream, per well) and AER Manifest will accompany each load. x Hilcorp’s Kenai Gas Field G&I Facility. Disposal will be in accordance with the approved Hilcorp Third-Party Waste Analysis Plan. A Cook Inlet – Kenai Waste Manifest and Third-Party Disposal Approval Letter will accompany each load. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 9 June 2025 18697-01 Rev. 2 3.0 Pre-Coiled Tubing Work x Complete site preparation/pad construction (Cruz Construction). Refer to Appendix E: As Built Surface Location Diagram for additional information. x After excavating around wellhead, perform quantitative methane monitoring per Department of Interior (DOI) procedure to compare with post-P&A monitoring. x Install starting head and well cellar (Cudd Pressure Control). Refer to Appendix F: Wellhead and Cellar Diagram for additional information. 4.0 Plug and Abandon Procedure x Operations to be performed in accordance with Approved 10-403 Sundries #324-521 (original; approved 9/23/24) and 325-323 (change approved program request; approved 6/5/25). x MPSP: the Maximum Potential Surface Pressure is based upon a gas gradient to surface from the deepest section reported to possibly contain hydrocarbons at 2115’ MD/TVD and a worst-case 9.6 ppg formation pressure. MPSP is calculated as 844 psi. However, a more realistic Maximum Anticipated Surface Pressure is the stabilized observed shut-in wellhead pressure of 90 psi. 4.1 Rig Up 4.1.1 Notify AOGCC Inspector 24 hours in advance of upcoming BOP Test. Use the Test Witness Notification web form on the AOGCC website. 4.1.2 Confirm water is being loaded into diffuser tank. x Plan to source water from the City of Wasilla Bulk Water Station at 550 N. Weber Drive. x MagTec 130-bbl water tanker trailer will transport the water to site and offload into frac tank. 4.1.3 MIRU 2” Service CTU. NU 4 1/16” BOPE. x Set up wellhead stabilizer (renting from Team Snubbing International). x Wellhead will be equipped with 7-1/16” 5k gate valve (master valve). x Flange up second 7-1/16” 5k gate valve (“traveling” swab valve). x Fox Energy Services supplying 7-1/16” flanged lubricator to accommodate larger-OD BHA components below the 4-1/16” BOPs: o 6.125” tapered mill for drift run o FH cement retainer (5.687” OD) and setting tool (5.312” OD) o 5.70” Gator Mechanical Perforating Tool for perforating 7” casing x RU return hard line from flow cross to choke manifold. x RU hoses downstream of choke manifold to frac tank with diffuser (active tank) and cuttings box (for any fluid to be disposed instead of recirculated). 4.1.4 Function and pressure test BOPE to 250 psi low / 1000 psi high per Fox Energy Services BOP Test Procedure. Refer to Appendix G: Fox Energy Services BOP Test Procedure for additional information. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 10 June 2025 18697-01 Rev. 2 4.2 Coiled Tubing Unit Data Table 4.2-1: Coiled Tubing Data Table Coiled Tubing Total Length 13,000 ft Wall Thickness 0.175” Coiled Tubing Grade HS-90 Coiled Tubing Weight 3.42 lb/ft Coiled Tubing OD 2.00” Coiled Tubing ID 1.65” Coiled Tubing bbls/ft 0.00264 bpf Coiled Tubing Total Volume 34.3 bbl Coiled Tubing Yield Pressure 14,800 psi Coiled Tubing Yield Strength 90,300 lbs Injector Max Pull 80,000 lbs Injector Max Snub 20,000 lbs Coiled Tubing Unit (with empty reel) 65,000 lbs 4.3 Drift Run 4.3.1 MU drift BHA per below table. x Pull test connector and pressure test BHA per Yellowjacket guidelines. x MU 6-1/8” tapered mill. Table 4.3-1: Drift BHA Description Vendor OD, in ID, in Length, ft 2” external coil connector Yellowjacket 2.875 1.35 0.90 Dual back pressure valve Yellowjacket 2.875 0.85 1.25 Bi-directional jar Yellowjacket 2.875 0.91 6.10 Ball drop disconnect, 3/4" ball Yellowjacket 2.875 0.69 2.12 Dual-acting circulation sub, 5/8" ball Yellowjacket 2.875 0.56 1.20 Crossover (2-3/8” PAC x 2-3/8” REG) Yellowjacket 3.125 1.00 0.60 3-3/8” mud motor, 5:6 lobe, 3.5 stages Yellowjacket 3.375 - 12.85 Crossover (2-3/8” REG x 3-1/2” REG) Yellowjacket 4.30 1.00 0.80 Tapered mill Yellowjacket 6.125 - 2.15 Total Length 27.97 Refer to Appendix H: Drift BHA Drawing for additional information. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 11 June 2025 18697-01 Rev. 2 4.3.2 Stab on, MU flanged connection. Shell test broken connection to 1000 psi. 4.3.3 Drift to 1620’ with 6-1/8” tapered mill. x The objective is to drift the 7” casing for the 5.687” OD cement retainer. x On 4/22/25, Slickline drifted to 2100’ with a 2.25” sample bailer. x Take care on the entire trip in and out of the hole. Areas requiring particular caution: o The 7” casing has a weld seam within the wellhead; prior to wellhead installation, the 7” had an 8 round pin looking up at surface that appears to have been welded on after pipe was run. o Although the well file doesn’t mention it, it is possible that the 7” casing was perforated for testing. The well file notes gas and water at 730’ – 820’; that interval may have been perforated. o Slotted 7” casing starts at 1678’. Stay away from this depth. x If it is necessary to work through obstructions with the bit, establish parameters with Yellowjacket Supervisor. x Dry drift through any areas of motor work to ensure cement retainer will be able to pass freely. Table 4.3-2 Mud Motor Table Flow Rate Range (GPM) Speed Range (RPM) 100 - 230 208 - 480 Refer to Appendix I: Mud Motor Performance Chart for additional information. 4.3.4 Load 5/8” ball for circ sub. Open circ sub. Circulate 2x bottoms up with fresh water. Once clean returns are verified, shut down pump and note shut-in casing pressure. Allow pressure to stabilize if > 0 psi so reservoir pressure can be determined. 4.3.5 Continue circulating while POOH at 80% of annular velocity. 4.4 Set Cement Retainer 4.4.1 MU cement retainer BHA per below table. Table 4.5-1: Cement Retainer BHA Description Vendor OD, in ID, in Length, ft 2” slip-on coil connector Yellowjacket 2.875 1.30 0.90 Crossover (2-3/8” PAC x 2-3/8” PH6) Yellowjacket 2.95 1.48 0.50 2-3/8” PH6 stinger Yellowjacket 2.88 1.80 3.70 Crossover 2-3/8” PH6 x 2-3/8” PAC Yellowjacket 2.81 1.37 0.80 Crossover 2-3/8” PAC x 2-7/8” REG Yellowjacket 3.78 1.20 1.85 Crossover 2-7/8” REG x 3-1/2” IF Yellowjacket 4.70 1.50 2.00 FH Hydraulic Setting Tool (1” ball) Alpha Oil Tools 5.312 N/A 8.45 FH Cement Retainer Alpha Oil Tools 5.687 2.00 1.97 Total Length 20.17 AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 12 June 2025 18697-01 Rev. 2 Refer to Appendix J: FH Cement Retainer BHA Drawing for additional information. 4.4.2 RIH to 1610’. 4.4.3 PUH slowly to 1600’ setting depth. x Memory CCL run 4/22/25 indicates 1600’ is mid-joint. x Depth reference is top of casing head installed 2/28/25; see Appendix F: Wellhead and Cellar Diagram. 4.4.4 Set FH cement retainer at 1600’ per Alpha Oil Tools procedure and Yellowjacket Representative. 4.4.5 Conduct injectivity test below retainer with water to establish parameters for cement downsqueeze. 4.5 Pump Cement Plugs #1 and #2 4.5.1 RU Fox cement unit. PT lines to 1500 psi. 4.5.2 Plug #1: mix and downsqueeze 43 bbl of 15.3 ppg cement below retainer. x This will place cement from the retainer at 1600’ down to the deepest known hydrocarbon zone at 2115’, per Approved Sundry 325-323. o From 1600’ to 1800’ = 8 bbl (retainer to 7” shoe) o From 1800’ to 2115’ = 35 bbl (7” shoe to deepest known hydrocarbon; 50% OH excess) 4.5.3 Unsting from cement retainer per Alpha Oil Tools procedure and Yellowjacket Representative. 4.5.4 Plug #2: lay in 53 bbl of 15.3 ppg cement above retainer. With fresh water, circulate out excess cement to place TOC at 300’. Continue circulating while POH. x Place adequate cement retarder in diffuser tank and cuttings boxes. x Divert downhole cement returns to designated Class II cuttings box, or 330-gallon poly-totes, for disposal. x If taking cement returns to poly-totes, let harden and dispose at the Central Landfill in Palmer. Contacts: Allison (907) 861-7602 / Terry (907) 861-7620. x When washing up cementing equipment, divert cement rinsate to designated Class I cuttings box. x Collect and process lab sample before sending Class I cuttings box for disposal (must meet Non- Hazardous criteria). 4.6 Tag Cement Plug #2 (AOGCC-Witnessed) 4.6.5 Notify AOGCC Inspector 24 hours in advance of cement tag. Use the Test Witness Notification web form on the AOGCC website. 4.6.6 MU Cement Tag BHA per table below. NOTE: intent is to use the same MHA components as the upcoming Gator Mechanical Perforator run. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 13 June 2025 18697-01 Rev. 2 Table 4.4-1: Tagging BHA Description Vendor OD, in ID, in Length, ft 2” slip-on coil connector Yellowjacket 2.875 1.30 0.90 Dual Back Pressure Valve Yellowjacket 2.875 0.85 1.20 Ball drop disconnect, 3/4" ball Yellowjacket 2.875 0.69 2.12 Dual-acting circulation sub, 5/8" ball Yellowjacket 2.875 0.56 1.20 Crossover (2-3/8” PAC x 1-1/2” MT) Yellowjacket TBD TBD TBD Nozzle Fox TBD TBD TBD Total Length TBD 4.6.7 RIH. With AOGCC inspector present, tag existing cement plug #2 with 5,000 lbs weight. POH. 4.7 7” Casing Perforation for Cement Plug #3 4.7.1 MU Gator Mechanical Perforating Tool per below table. Table 4.6-1: Gator Mechanical Perforator BHA Description Vendor OD, in ID, in Length, ft 2” slip-on coil connector Yellowjacket 2.875 1.30 0.90 Dual back pressure valve Yellowjacket 2.875 0.85 1.20 Ball drop disconnect, 3/4" ball Yellowjacket 2.875 0.69 2.12 Dual-acting circulation sub, 5/8" ball Yellowjacket 2.875 0.56 1.20 Crossover (2-3/8” PAC x 2-3/8” EUE) Yellowjacket 2.875 1.75 0.60 Locking Swivel Sub Lee Energy Systems 3.60 2.00 1.48 Crossover (2-3/8” EUE x NC38) Lee Energy Systems 3.50 2.44 1.33 Heavy Wall Gator Tool – 570 HWG Lee Energy Systems 5.70 1.00 3.23 Pistons x14 – Free pipe perforation pressure = 2607 psi With 1x 8/32 nozzle Lee Energy Systems 5.70 1.00 12.80 Bull nose Lee Energy Systems 4.50 - 0.85 Total Length 25.71’ See Appendix K: Gator Mechanical Perforator BHA Drawing for additional information. 4.7.2 RIH with Gator tool. Tag TOC. PU to perforation depth. 4.7.3 Perforate at 300’ per Lee Energy Systems Tool Hand. 4.7.4 Establish circulation through perforations, pumping down 7” casing with returns from 7” x 10” annulus until returns are clean. Annulus volume to 300’ = 10 bbl. x Max Pressure when pumping down 7” casing = 500 psi. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 14 June 2025 18697-01 Rev. 2 x Take returns from red 2” weld-o-let outlet. This outlet accesses the 7” x 10” annulus. x Route returns to Class II cuttings box for disposal until clean returns observed. 4.7.5 If circulation into annulus cannot be established through the perforations at 300’, move uphole 25’ and perforate again. Continue reperforating at 25-ft intervals until circulation is established. x If circulation is established much shallower than the initial 300’ perf depth, set contingent 7” CIBP below the circulation point to provide a base for the upcoming surface cement plug. x If circulation cannot be established by 150’, contact Bryan McLellan, AOGCC Senior Petroleum Engineer, to discuss plan forward. This will require a Sundry – Change Approved Program request. 4.7.6 Once circulation into annulus is confirmed and clean returns at surface, POH. 4.7.7 NOTE: if circulation down coiled tubing is required while POH with the Gator tool, stop POH before pumping down the coiled tubing. 4.7.8 If required, blow down reel with nitrogen. x Review nitrogen safety SOP – See Appendix L: ACES Nitrogen SOP. x Consider pumping drift ball or foam pig. x Pump nitrogen to unload reel volume through choke to closed top diffuser tank. 4.7.9 RDMO coiled tubing unit. 4.8 Cement Plug #3 4.8.1 RU Fox Cement Unit. x NU 7-1/16” 5k flange x 2” 1502 crossover to master valve. x RU treating iron to 1502, PT to 1500 psi against master valve. 4.8.2 Establish circulation down 7” casing with returns from 7” x 10” annulus. x Max Pressure when pumping down 7” casing = 500 psi. x Take returns from red 2” weld-o-let outlet. This outlet accesses the 7” x 10” annulus. 4.8.3 Shut down pump and verify annulus is dead before proceeding with cement job. 4.8.4 Mix and pump 24 bbl of 15.3 ppg cement to cement casing and annulus from 300’ to surface. x Max Pressure when pumping down 7” casing = 500 psi. x Place adequate cement retarder in diffuser tank and cuttings boxes. x Divert downhole cement returns to designated Class II cuttings box, or 330-gallon poly-totes, for disposal. x If taking cement returns to poly-totes, let harden and dispose at the Central Landfill in Palmer. Contacts: Allison (907) 861-7602 / Terry (907) 861-7620. x Stop mixing when good cement returns are observed. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 15 June 2025 18697-01 Rev. 2 4.8.5 SI master valve, flush lines, wash up cement equipment to designated Class I cuttings box. x Flush master valve after breaking off treating line. x Collect and process lab sample before sending Class I cuttings box for disposal (Class I cement rinsate must meet Non-Hazardous criteria). 4.8.6 RDMO cement unit. 4.8.7 Manifest fluids for disposal at Alaska Eco Resources Monofill or Hilcorp Kenai Gas Field G&I. 4.9 Wellhead Removal 4.9.1 ND master valve. 4.9.2 Remove wellhead and cellar. 4.9.3 Excavate for casing cut. 4.9.4 Notify AOGCC Inspector 24 hours in advance to witness wellhead post cut-off, before and after cement top jobs (specified in approved Sundry). Use the Test Witness Notification web form on the AOGCC website. 4.9.5 Cut casing strings at 3’ below ground level. 4.9.6 If cement is not at surface, top off casing and annulus with cement prior to welding on marker plate. Photo-document cement inside casing and annulus and include in 10-407 submittal. 4.9.7 Weld marker plate on the 12-3/4” casing. Photo-document installed marker plate and include in 10- 407. Marker plate to be inscribed with the following information: State of Alaska AOGCC PTD 100-003 Rosetta 1 API 50-009-10014-00-00 4.9.8 Perform post-P&A methane monitoring and record results for reporting purposes. 4.9.9 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. 4.9.10 Notify AOGCC Inspector 10 days in advance (specified in approved Sundry) to perform final site clearance inspection. Use the Test Witness Notification web form on the AOGCC website. AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 16 June 2025 18697-01 Rev. 2 THIS PAGE INTENTIONALLY LEFT BLANK AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 17 June 2025 18697-01 Rev. 2 Appendices AOGCC Orphan Well Plugging and Remediation Program Rosetta 1 Plug and Abandon Detailed Procedure Houston, Alaska AOGCC 18 June 2025 18697-01 Rev. 2 THIS PAGE INTENTIONALLY LEFT BLANK AppendixA: Current Wellbore Schematic THIS PAGE INTENTIONALLY LEFT BLANK All casing strings to be cut off >3' below ground level. 12-3/4" Conductor shoe depth unknown Casing Detail Size Weight Grade Top Bottom Base Fresh Water 440'12-3/4" 51.15 ppf ? 0 ? - Believed 12" line pipe w/ 12.0" ID (3/8" wall measured) 10" Casing at 650'10" ? ? 0 650 7" 23 J55 0 1800 6.366" ID 6.241" drift 8 round 10" Casing Cementing Detail: Cemented with 150 sacks, Calc TOC is at surface 12-1/4" OH x 10" casing annulus from 650' to surface = 143 sack volume w/ gauge hole 7" Casing at 1800'Assumed yield = 1.15 cu ft/sack Casing slotted f/ 1678' - 1800'Visual confirmation of cement at surface when **slots are not cemented cut window in 12-3/4" conductor on 2/23/25, during wellhead install preparation. 7" Casing Cementing Detail: Existing Cement Plugs: 8/31/1958, cemented with 400 sacks, 75 sack cement plug spotted at 1915'cross bar for cement plug just above casing slots 8/29/58 (prior to running casing). TOC at 1678', 122' of slots in bottom of casing hard tag 8/30/58 at 1800' with 30k.Calc TOC is at surface 8-3/4" OH + cased hole annulus Note: Completion Report dated 5/23/1960 volume = 293 sacks w/ gauge OH says "Plugged at 1800 ft", and no mention volume = 333 sacks w/ 30% OH excess of other plugs.Assumed yield = 1.15 cu ft/sack Note: No mention of cement to surface, only "figured 4/22/25: drifted to 2100' SLM with 2.25"fill to shoe at 650'" on completion detail. sample bailer. Cement plug not present TOC approximately 350' based on 4/22/25 CBL. at 1800'. Planned P&A Plugs: Plug #1: 515' (43 bbls) cement plug squeezed below retainer at 1600' to 2115' (deepest hydrocarbon) Plug #2: 1300' (53 bbls) cement plug spotted above retainer from 300' to 1600' Plug #3: 300' (24 bbls) cement plug circulated into 7" x 10" annulus 8-3/4" open hole and 7" casing to surface via perfs at 300' API # 50-009-10014-00 Meridian Township Range Section PTD # 100-003 Spud date: June 1954 Seward 18 N 3W 20 Prepared by ASRC Energy Services 5/15/2025 Rosetta 1 - Well file states 10-3/4" but measured OD is 10" Total Depth 4260' June 1959 Rosetta 1 Proposed P&A Schematic Plug#1 1600Ͳ 2115' Plug#2 300Ͳ 1600' Retainerat 1600' Plug#3 0Ͳ 300' Perforations at300' Appendix B: Proposed Wellbore Schematic THIS PAGE INTENTIONALLY LEFT BLANK %lb sack1) 94 lb/sk Class-G 100% 94 BHST: 80 °F Final Press: 1,000 psiDensity 2) 0 lb/sk 0% 0 BHCT: 70 °F15.3 ppg Base 3) 0 lb/sk 0% 0 TTT @ 70 Bc 3:57 hr:min 50 psi: 8:15 hr4) 0 lb/sk 0% 0 Calc API FL 18 mL/30min 500 psi: 13:14 hr94 lb Sk Wt FF Angle 90 ° 12 hr: 370 psiYield 1) 0.5 %BWOC Free Fluid 0 % 24 hr: 1380 psi1.24 ft3/sk 2) 0.3 %BWOCFCD2003) 0.25 %BWOCFMR210RPM 600 300 200 100 60 30 6 3 PV YP 10 sec 10 minAdditives 4) Temp 80 °F 143 101 61 36 19 5 3 142 6 3 28H20 Reqd 5)5.594 gal/sk 6)RPM 600 300 200 100 60 30 6 3 PV YP 10 sec 10 min7) Temp 80 °F 207 155 91 62 37 11 6 202 15 5 168)TT ChartLab Testing ResultsUCARheology 1Rheology 2Lab ID# 647-3 Slurry RecipeUCA ChartFFL221Appendix C: Cement Lab Test Results THIS PAGE INTENTIONALLY LEFT BLANK Appendix ': Fox Energy BOP Diagram THIS PAGE INTENTIONALLY LEFT BLANK Appendix E: As Built Surface Location Diagram THIS PAGE INTENTIONALLY LEFT BLANK Appendix F: Wellhead and Cellar Diagram THIS PAGE INTENTIONALLY LEFT BLANK &ŽǆŶĞƌŐǇ^ĞƌǀŝĐĞƐKWdĞƐƚWƌŽĐĞĚƵƌĞ dŚŝƐƉƌŽĐĞĚƵƌĞĚŝĐƚĂƚĞƐƚŚĞKWdĞƐƚWƌŽĐĞĚƵƌĞƐĨŽƌ&ŽǆŶĞƌŐǇ^ĞƌǀŝĐĞƐ͘tĞƌĞĐŽŵŵĞŶĚ͞ŽƵƚƐŝĚĞ͟ŝŶ ƚĞƐƟŶŐ͘^ƚĂƌƟŶŐǁŝƚŚƚŚĞĐŚŽŬĞŵĂŶŝĨŽůĚĂŶĚŝŶŶĞƌƌĞĞĚǀĂůǀĞƐĂŶĚŵŽǀŝŶŐŝŶǁĂƌĚƚŽƚŚĞKW͘/ĨĚŽŶĞ ĐŽƌƌĞĐƚůǇ;ĂƐƐƵŵŝŶŐĂƐƚĂŶĚĂƌĚƌŝŐƵƉĚƵĂůĐŽŵďŝKW͕ϱǀĂůǀĞĐŚŽŬĞŵĂŶŝĨŽůĚ͕ŶŽƌĞǀĞƌƐŝŶŐƌĞƚƵƌŶƐƌŝŐ ƵƉͿ͕ƚŚĞƚĞƐƟŶŐĐĂŶďĞĐŽŵƉůĞƚĞĚǁŝƚŚĂƚŽƚĂůŽĨϱƚĞƐƚƐ͘ůůƚĞƐƚƐǁŝůůďĞŝŶĂ͞ůŽǁ͟ƚŚĞŶŚŝŐŚ͟ƉƌĞƐƐƵƌĞ ƚĞƐƚ͘/ƚŝƐƵƉƚŽK'ĂŶĚŽƵƌĐůŝĞŶƚƐǁŚĂƚƚŚĞ͞ůŽǁĂŶĚŚŝŐŚ͟ĂƌĞ͘dǇƉŝĐĂůůǇ͕ůŽǁƐĂƌĞŶŽŵŽƌĞƚŚĂŶϮϱϬ ƉƐŝ͕ĂŶĚŚŝŐŚŝƐƚǇƉŝĐĂůůǇϯ͕ϬϬϬƉƐŝ͕ďƵƚŶŽŵŽƌĞƚŚĂŶƚŚĞŵĂǆŝŵƵŵĂůůŽǁĂďůĞƉƌĞƐƐƵƌĞŽĨƚŚĞƚƌĞĞ ;ƚǇƉŝĐĂůůǇϱ<W^/ŝŶ<ĞŶĂŝ͕<Ϳ͘ ůůϱǀĂůǀĞĐŚŽŬĞƐǁŝůůďĞŶƵŵďĞƌĞĚĂƐĨŽůůŽǁƐ͗ dĞƐƚϭ ǁŝůůďĞĐŚŽŬĞǀĂůǀĞƐ͗ϭ͕Ϯ͕ĂŶĚϯĐůŽƐĞĚ͕ƚŚĞƐƵƉĞƌǀŝƐŽƌŵĂǇƵƐĞƚŚŝƐƚĞƐƚƚŽƉƌĞƐƐƵƌĞƚĞƐƚƚŚĞ ďĂĐŬƐŝĚĞŝƌŽŶ͕ŝŶŶĞƌƌĞĞůǀĂůǀĞ͕ŇƵŝĚƉƵŵƉ͘dŚĞƐƵƉĞƌǀŝƐŽƌŵĂǇĂůƐŽĐŽƵŶƚƚŚŝƐƚĞƐƚĂŐĂŝŶƐƚƚŚĞŬŝůůƉŽƌƚƐ Appendix *: Fox Energy Services BOP Test Procedure ĨŽƌƚŚĞKWŝĨƚŚĞǇĂƌĞďůĂŶŬĞĚ͘dŚŝƐŵĂǇĂůƐŽƉƌĞƐƐƵƌĞƚĞƐƚƚŚĞďŽĚǇŽĨƚŚĞKWĂŶĚƚŚĞĐŽŶŶĞĐƟŽŶƐ ĨƌŽŵƚŚĞKWƚŽƚŚĞƚƌĞĞ͘ dĞƐƚϮ ďĞĐŚŽŬĞǀĂůǀĞƐ͗ϯ͕ϰ͕ĂŶĚϱĐůŽƐĞĚĂŶĚƚŚĞƐƵƉĞƌǀŝƐŽƌĐĂŶĐůŽƐĞƚŚĞďůŝŶĚƐŚĞĞƌƐŽŶƚŚĞKW͘ ZĞĐŽƌĚƚŚĞƟŵĞƚŽĐůŽƐĞĂŶĚŽƉĞŶƚŚĞďůŝŶĚƐŚĞĞƌƐ͘ dĞƐƚϯ ǁŝůůƚĞƐƚƚŚĞKWŽƵƚĞƌŵŽƐƚǀĂůǀĞƐŽŶƚŚĞŇŽǁĐƌŽƐƐ͘sĂůǀĞƐϭĂŶĚϰŽŶƚŚĞKWĂŶĚƚŚĞƉŝƉĞƐůŝƉƐ ĐĂŶďĞƚĞƐƚĞĚ͘ZĞĐŽƌĚƚŚĞƟŵĞƐƚŽĐůŽƐĞĂŶĚŽƉĞŶƚŚĞƉŝƉĞƐůŝƉƐ͘ŶƐƵƌĞƚŚĂƚĂůůƉƌĞƐƐƵƌĞŝƐďůĞĚŽĨ ďĞĨŽƌĞĂŶŽƉĞƌĂƚŽƌĂƩĞŵƉƚƐƉƵůůƐƚŚĞƉŝƉĞƐůŝƉĨƌŽŵƚŚĞKW͘ dĞƐƚϰ ǁŝůůďĞKWŝŶŶĞƌǀĂůǀĞƐŽŶƚŚĞŇŽǁĐƌŽƐƐ͕ǀĂůǀĞƐϮĂŶĚϯ͘ dĞƐƚϱ ;ƚǇƉŝĐĂůůǇĚŽŶĞƚŚĞĨŽůůŽǁŝŶŐĚĂǇŽƌďĞĨŽƌĞƌƵŶŶŝŶŐŝŶŚŽůĞͿǁŝůůďĞƚĞƐƟŶŐƚŚĞƐƚƌŝŶŐ͕ůƵďƌŝĐĂƚŽƌ ĂŶĚƐƚƌŝƉƉĞƌ͘dŚŝƐƚĞƐƚŝƐƚǇƉŝĐĂůůǇĚŽŶĞƚŚĞĨŽůůŽǁŝŶŐĚĂǇĚƵĞƚŽĨƌĞĞǌŝŶŐƚĞŵƉĞƌĂƚƵƌĞƐŝŶ<ĞŶĂŝ͕<͘/ƚŝƐ ƐŽŵĞƟŵĞƐĚŽŶĞǁŝƚŚƚŚĞKzƚĞƐƚŽĨƚŚĞKWĂƐǁĞůů͘ ƌĂǁĚŽǁŶƚĞƐƚ͘ŌĞƌƚĞƐƟŶŐƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚ͕ĂĚƌĂǁĚŽǁŶŽĨƚŚĞŚǇĚƌĂƵůŝĐƐǁŝůůďĞƚĞƐƚĞĚ͘&ŽƌƚŚŝƐ ƚĞƐƚ͕ĞŶƐƵƌĞƚŚĂƚƐǇƐƚĞŵƉƌĞƐƐƵƌĞŝƐǁŽƌŬŝŶŐĐŽƌƌĞĐƚůǇ͘^ǇƐƚĞŵƉƌĞƐƐƵƌĞĨŽƌĐŽŝůηϴĂŶĚηϭϬŝƐϯ͕ϬϬϬƉƐŝ͘ ZĞĐŽƌĚƐǇƐƚĞŵǁŽƌŬŝŶŐƉƌĞƐƐƵƌĞ͘ ^ŚƵƚĚŽǁŶƉŽǁĞƌƉĂĐŬĂŶĚŚǇĚƌĂƵůŝĐƐůĞĂǀŝŶŐƐǇƐƚĞŵƉƌĞƐƐƵƌĞŽŶƚŚĞKWƐ͘ůŽƐĞƚŚĞďůŝŶĚƐŚĞĂƌƐĂŶĚ ƌĞĐŽƌĚƚŚĞƟŵĞĨŽƌƚŚĞďůŝŶĚƐŚĞĂƌƐƚŽĐůŽƐĞ͘ZĞĐŽƌĚƚŚĞƉƌĞƐƐƵƌĞŽŶƚŚĞKWƐ͘KƉĞŶƚŚĞďůŝŶĚƐŚĞĂƌƐ͕ ƌĞĐŽƌĚƚŚĞƟŵĞƚŽŽƉĞŶďůŝŶĚƐŚĞĂƌƐ͘ůŽƐĞďůŝŶĚƐŚĞĂƌƐĂŐĂŝŶ͘ZĞĐŽƌĚƚŚĞĮŶĂůƉƌĞƐƐƵƌĞŽŶƚŚĞKWƐ͘ ^ƚĂƌƚƵƉŚǇĚƌĂƵůŝĐƐĂŶĚƌĞĐŽƌĚƚŚĞƟŵĞƚŽŐĂŝŶϮϬϬƉƐŝ͕ĂŶĚƚŽĨƵůůƐǇƐƚĞŵƉƌĞƐƐƵƌĞ͘ĞƋƵŝĐŬ͕ĂƐƚŚŝƐƐƚĞƉ ŵĂǇďĞůĞƐƐƚŚĂŶϭϬƐĞĐŽŶĚƐ͘ ĐĐƵŵƵůĂƚŽƌƐŽŶƵŶŝƚƐηϴĂŶĚηϭϬĂƌĞĂƋƵĂŶƟƚǇŽĨĨŽƵƌϭϭͲŐĂůĂĐĐƵŵƵůĂƚŽƌďŽƩůĞƐ͘dŚĞǇĂƌĞƉƌĞƐƐƵƌŝǌĞĚ ƚŽϭ͕ϰϬϬƉƐŝĞĂĐŚ͘ Job Type: Customer: State: Date: Lease/Well: County: Serv Sup: Field: Rig: Field Ticket # Project: Casing: Co Rep: Other: Drift: Co Rep Ph: Cust PO#: Workstring Size: Co Rep: Cust AFE#: Proposed OD ID Serial Length Total BHA (inches) (inches) No.(feet) (feet) 2.88 1.35 0.90 0.90 2.88 0.85 1.25 2.15 2.88 0.91 6.10 8.25 2.88 0.69 2.12 10.37 2.88 0.56 1.20 11.57 3.13 1.00 0.60 12.17 3.38 N/A 12.85 25.02 4.30 1.00 0.80 25.82 6.13 N/A 2.15 27.97 27.97 Tapered Mill BHA DRAWING PREPARED BY:Patrick Grant TOTAL LENGTH: Cross Over 2-3/8 REG x 3-1/2 REG Mud Motor 5/8" Ball Cross Over 2-3/8 PAC x 2-3/8 REG Dual Acting Circ Sub TJ Hyd. Disconnect 3/4" Ball Bi-Di-Jar Dual Flapper Check Valve 2" x 2-3/8 PAC External CTC Tapered Mill Milling BHA Equipment & Service Patrick Grant Mill Out Alaska Rosetta ! BHA Schematic FIELD WORKBOOK - THRU TUBING FISHING Appendix H: Drift BHA Drawing THIS PAGE INTENTIONALLY LEFT BLANK Appendix ,: Mud Motor Performance Chart THIS PAGE INTENTIONALLY LEFT BLANK Job Type: Customer: State: Date: Lease/Well: County: Serv Sup: Field: Rig: Field Ticket # Project: Casing: Co Rep: Other: Drift: Co Rep Ph: Cust PO#: Workstring Size: Co Rep: Cust AFE#: Proposed OD ID Serial Length Total BHA (inches) (inches)No.(feet) (feet) 2.88 1.30 0.90 0.90 2.95 1.48 0.50 1.40 2.88 1.8 3.70 5.10 2.81 1.37 0.80 5.90 3.78 1.20 1.85 7.75 4.70 1.50 2.00 9.75 5.31 N/A 8.45 18.20 5.69 2.00 1.97 20.17 BHA Schematic FIELD WORKBOOK - THRU TUBING FISHING Patrick Grant Rosetta 1 5.687 SVCR Equipment & Service 2" Slip on CTC 2-3/8 PH6 Stinger Cross Over 2-3/8 PAC x 2-3/8 PH6 Cross Over 2-3/8 PH6 x 2-3/8 PAC Cross Over 2-3/8 PAC x 2-7/8 REG 5.312 FH Hydraulic Setting Tool Cross Over 2-7/8 REG x 3-1/2 IF 5.687" FH Cement Retainer 20.17 OAL of BHA Stabbed up = 18.8' +/- BHA DRAWING PREPARED BY: TOTAL LENGTH: Appendix J: FH Cement Retainer BHA Drawing THIS PAGE INTENTIONALLY LEFT BLANK Job Type: Customer: State: Date: Lease/Well: County: Serv Sup: Field: Rig: Field Ticket # Project: Casing: Co Rep: Other: Drift: Co Rep Ph: Cust PO#: Workstring Size: Co Rep: Cust AFE#: Proposed OD ID Serial Length Total BHA (inches) (inches)No.(feet) (feet) 2.88 1.30 0.90 0.90 2.88 0.85 1.20 2.10 2.88 0.69 2.12 4.22 2.88 0.56 1.20 5.42 2.88 1.75 0.60 6.02 3.60 2.00 1.48 7.50 3.50 2.44 1.33 8.83 5.70 1.00 3.23 12.06 5.70 1.00 12.80 24.86 4.50 N/A 0.85 25.71 25.71 Bull Nose BHA DRAWING PREPARED BY:TOTAL LENGTH: Pistons -x14 570 HWG Heavy Wall Gator Locking Swivel Sub Cross Over 2-3/8 EUE x NC 38 Cross Over 2-3/8 PAC x 2-3/8 EUE Dual Acting Circ Sub TJ Hydraulic Disconnect Dual Flapper Check Valve 2" Slip on CTC Mechanical Punch BHA Equipment & Service Patrick Grant Rosetta 1 BHA Schematic FIELD WORKBOOK - THRU TUBING FISHING Appendix K: Gator Mechanical Perforator BHA Drawing THIS PAGE INTENTIONALLY LEFT BLANK Safety/Awareness While Working With Nitrogen & Stop Work Authority • To be reviewed prior to job with all personnel on location. • Hold Pre-job safety meetings to discuss nitrogen asphyxiation awareness and note areas in which nitrogen could accumulate and personnel can access. • Recognize tank location and wind direction. Be aware of weather forecast/changes in wind direction. • Make certain ALL work personnel are informed of Stop Work Authority. Safety Procedure While Working With Nitrogen 1. MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2. Notify PadOperator of upcoming Nitrogen operations. 3. Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4. Document ŜĖťôϙŜŕôèĖƱèϙhazards and mitigation measures. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of ƲĺſīĖĲôŜϠϙÍîôŗŪÍťôϙŽôĲťĖĲČϙÍĲîϙÍťıĺŜŕēôŘĖèϙıĺĲĖťĺŘĖĲČϟ 5.ŕĺťϙŪıŕĖĲČϙĲĖťϙÍĲîϙbĖťŘĺČôĲϙÍĲħϟϙĺĲƱŘıϙīĖŗŪĖîϙb͑ϙŽĺīŪıôŜϙĖĲϙťŘÍĲŜŕĺŘťϟ 6. Make up lines from the Nitrogen Pump to the well and return tank. Secure lines with whip checks. 7. Post signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8. Install pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubingand casing pressures. 9. Installpressure gauges upstream and downstream of any check valves. 10. Visually inspect valve alignments and ensure valve position is correct. 11.ĺĲƱŘı portable 4-ČÍŜϙîôťôèťĖĺĲϙôŗŪĖŕıôĲťϙĖŜϙĺĲŜĖťôϠϙèÍīĖæŘÍťôîϠϙÍĲîϙæŪıŕϙťôŜťôî properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12. Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential ŪŘċÍèôϙŘôŜŜŪŘôϽϠϙſēĖèēôŽôŘϙĖŜϙēĖČēôŘϟϙôŜťϙīĖĲôŜϙîĺſĲŜťŘôÍıϙĺċϙſôīīϙϼċŘĺıϙſôīīϙťĺ returns tank)ťĺϙ͐Ϡ͔͏͏ϙŕŜĖϟϙôŘċĺŘıϙŽĖŜŪÍīϙĖĲŜŕôèťĖĺĲϙċĺŘϙÍĲƅϙīôÍħŜϟ 13.īôôîϙĺƯϙťôŜťϙŕŘôŜŜŪŘôϙÍĲîϙŕŘôŕÍŘôϙċĺŘϙŕŪıŕĖĲČϙĲĖťŘĺČôĲϟ 14.ŪıŕϙĲĖťŘĺČôĲϙÍťϙîôŜĖŘôîϙŘÍťôϠϙıĺĲĖťĺŘĖĲČϙŘÍťôϙϼ>aϽϙÍĲîϙŕŘôŜŜŪŘôϙϼIϽϟϙīīϙĲĖťŘĺČôĲ returns are to be routed to the returns tank. 15.®ēôĲϙƱĲÍīϙĲĖťŘĺČôĲϙŽĺīŪıôϙēÍŜϙæôôĲϙÍèēĖôŽôîϠϙĖŜĺīÍťôϙſôīīϙċŘĺıϙbĖťŘĺČôĲϙŪıŕĖĲČϙĲĖť and bleed down lines between well and Nitrogen Pumping Unit. 16.iĲèôϙƅĺŪϙēÍŽôϙèĺĲƱŘıôîϙīĖĲôŜϙÍŘôϙæīôîϙîĺſĲϠϙĲĺϙťŘÍŕŕôîϙŕŘôŜŜŪŘôϙôƄĖŜťŜϠϙÍĲîϙĲĺϙĲĖťŘĺČôĲ has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17. RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Appendix /: Nitrogen Safety Procedure STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________ROSETTA 1 JBR 08/07/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Slow test. I was on location 8 hrs. 1st test IRV had to be greased-Fail/Pass. 2nd test- CMV 3,4,5 leaking, Serviced and passed re-test.3rd test-Isolation valve leaked but not counted as a fail (not well control) 4th test was good. AOGCC orphan well program; work done by ASRC Environmental Services Alaska. Test Results TEST DATA Rig Rep:Jeremy HartOperator:ASRC Consulting & Environmental Servic Operator Rep:Josh Murphy Rig Owner/Rig No.:Fox 10 PTD#:1000030 DATE:6/29/2025 Type Operation:WRKOV Annular: Type Test:INIT Valves: 250/1000 Rams: 250/1000 Test Pressures:Inspection No:bopAGE250708092806 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 844 Sundry No: 325-323 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 0 NA Inside BOP 0 NA FSV Misc 0 NA 5 FPNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 1 2"P Annular Preventer 0 NA #1 Rams 1 Blind P #2 Rams 1 2"pipeslips P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 2 2"P HCR Valves 0 NA Kill Line Valves 2 2"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P2200 200 PSI Attained P4 Full Pressure Attained P15 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)NA ACC Misc NA0 NA NATrip Tank NA NAPit Level Indicators NA NAFlow Indicator NA NAMeth Gas Detector NA NAH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 FP Annular Preventer NA0 #1 Rams P15 #2 Rams P15 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke NA0 HCR Kill NA0        From:McLellan, Bryan J (OGC) To:McVey, Adrienne Cc:Danny Kara; Cismoski, Doug; Dial, Amanda; Brandenburg, Timothy Subject:RE: Rosetta 1 Detailed P&A Procedure Date:Thursday, June 26, 2025 2:33:00 PM Change of fluid type is approved. 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, June 26, 2025 2:31 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure Bryan, Thank you! Please see below. I will send out a Revision 2 pending your responses. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 4.3.1 Tapered mill instead of tri-cone for drift run: the primary areas of concern on the drift run are a weld seam within the wellhead and any restrictions associated with possible perfs at 730-820’. I discussed what sort of bit or mill would be most effective for cleaning up these potential ID restrictions and Yellowjacket recommended a tapered mill. ⚠️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 4.3.4 Fluid type for circulating 2x bottoms up: planning fresh water. I note the original approved Sundry (324-521) specified 9.6 ppg brine or water-based mud. We have since learned: · Prior to wellhead installation, Rosetta 1 was leaking about 10 bbl of brackish water per day with no measurable LEL’s. · Since wellhead installation, the well stacks out to about 90 psi. · If we assume the brackish water currently in the well has a density of 8.4 ppg, SIWHP after we circulate the well to fresh water from 1600’ will be approximately 200 psi. · For these reasons (low pressure, low flow potential of mainly brackish water with small amounts of gas), I do not think KWF is necessary for Rosetta 1. · Since this is now a summertime operation, freeze point is not a concern. · Fluid mixing operations in the field entails handling and hand-cutting 50-lb sacks of salt. · To minimize fluid mixing operations in the field, and for cost efficiency, I am requesting a change to the approved Sundry to use fresh water as our work fluid. 4.5.4 Fluid type left in hole after laying in plug #2 to 300’: planning fresh water. I’ll add this. 4.7.5 If we establish circulation much shallower than the initial Gator perf depth of 300’: · I’ll edit the program to reflect that we’ll work up the hole in 25’ intervals and only contact you if we get up to 150’ and still can’t circulate. · I think this is unlikely since the CBL showed clear TOC at ~350’. · Establishing a base for cement: we can set a contingent CIBP below our shallowest perf depth before pumping the surface plug. I confirmed Yellowjacket will have one available, and I confirmed with Gator there is no issue running a CIBP past their perfs. · I did look into a cement basket option; that is more expensive than the CIBP. 4.8.4 Cement density for plug #3: 15.3 ppg. Same blend as for plugs #1 and #2. I’ll add this. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 25, 2025 3:42 PM To: McVey, Adrienne <amcvey@asrcenergy.com> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure 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. content is safe. Adrienne, What’s the reason for using the tapered mill to drift instead of a Tri-cone? Just curious, I don’t feel strongly either way. 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: Tuesday, June 24, 2025 9:10 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 Detailed P&A Procedure Bryan, Please see attached Rev 1. I realized I hadn’t updated Appendix B: Proposed Wellbore Schematic to reflect base of cement plug #1 at 2115’ (deepest hydrocarbon). Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: McVey, Adrienne Sent: Tuesday, June 24, 2025 8:23 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Danny Kara <danny.kara@outlook.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: Rosetta 1 Detailed P&A Procedure Bryan, Attached is the Rosetta 1 detailed P&A procedure for your review. 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:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Rosetta 1 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): 4260 4260 Surface Surface 844 Unknown Casing Collapse Structural Conductor Unknown Surface Unknown Intermediate Production 3270 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None 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 6/15/2025 None 1800' Perforation Depth MD (ft): Slots 1678' - 1800' 1800' Slots 1678' - 1800' 1800'7" 12-3/4" 10" Unknown 650' MD Unknown Unknown Unknown 650' Unknown 650' Length Size Proposed Pools: N/A TVD Burst N/A 4360 psi Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 100-003 3900 C Street, Suite 701, Anchorage, AK 99503 50-009-10014-00-00 ASRC Energy Services Alaska, Inc PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Unknown 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: 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 quest: Abandon Plug PerforationsFracture Stimulate Reppair 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: r Casing ___________________ ame:4. Current Well Class:5. Permit to Drill Number: Exploratory Development Stratigraphic Service 6. API Number: g:8. Well Name and Number: ation or Conservation Order governs well spacing in this pool?N/A Rosetta 1 Yes No esignation (Lease Number): 10. Field: Exploratory N/A N/A D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): 4260 4260Surface Surface 844 Unknown g Collapse al or Unknown e Unknown ate on 3270 psi SSSV Type:Packers and SSSV MD (ft) and TVD (ft): N/A nts: Proposal Summary Wellbore schematic13. Well Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Service Date for 15. Well Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG esentative: GINJ Op Shutdown Abandoned Contact Name: Adrienne McVey Contact Email:amcvey@asrcenergy.com Contact Phone: 907-980-8623 le: VP of Drilling, Projoects and Engineering 6/15/2025 None 1800' epth MD (ft): 800' 1800' Slots 1678' - 1800' 1800'7" 12-3/4" 10" Unknown 650' MD Unknown Unknown Unknown 650' Unknown 650' Length Size Proposed Pools: N/A TVD Burst N/A 4360 psi Perforation Depth TVD (ft): 100-003 , Suite 701, Anchorage, AK 99503 50-009-10014-00-00 Services Alaska, Inc PRESENT WELL CONDITION SUMMARY Tubing Grade: Tubing MD (ft): Unknown quire a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: 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: 2025.05.22 17:26:18 -08'00' 325-323 By Grace Christianson at 8:14 am, May 23, 2025 BJM 6/3/25 XX 10-407 All conditions of approval in original sundry still apply. Provide 24 hr notice to AOGCC opportunity to witness tag of cement plug 2 @ 300' MD. SFD 6/3/2025 DSR-6/3/25 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.05 08:10:07 -08'00'06/05/25 RBDMS JSB 060525 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 8 May 19, 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 Rosetta 1 Well (PTD: 100-003 / API: 50-009-10014-00-00) Dear Commissioners, ASRC Energy Services Alaska, Inc (AES-AK) hereby requests sundry approval to change the approved program for permanently plugging and abandoning the Rosetta 1 well, located in the city of Houston. The original sundry number is 324-521. 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 8 1.0 Well Summary – Rosetta 1 The Rosetta 1 well 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. Coiled tubing operations on Rosetta 1 are scheduled to begin 2Q of 2025. General Well Information Status: Orphan Well – See attached ‘Current Wellbore Schematic’ (Figure 1.1-1) for details. A slip-on wellhead was installed on February 28, 2025. Prior to wellhead installation a small hole in the 7” casing was leaking approximately 10 bpd water/brine with small gas bubbles (no measurable LEL). Since wellhead installation, the observed shut-in wellhead pressure is 85 psi. Base of Fresh Water: Estimated at 440’ MD / 440’ TVD Reservoir Pressure: As based upon information within the AOGCC & DNR well files from the original drilling of Rosetta 1, the deepest reported indication of coal, gas, or oil is ~2115’ MD. The strata through this interval 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. Strata below this depth have very little likelihood of containing hydrocarbons as indicated from comments within the files and lithology and mud log data captured during drilling. 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. Based upon available well data, the final mud weights were 10.6 ppg at TD, however this was not believed required to manage abnormal pressure. MASP: The Maximum Anticipated Surface Pressure is calculated as ~844 psi and is based upon a gas gradient to surface from the deepest section reported to possibly contain hydrocarbons at 2115’ 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 12-¾” Casing x 11” 5M, 11” 5M x 7-1/16” 5M (see Figure 1.1-3 for details) BOP Configuration: Coiled Tubing – 4-1/16”, 10M BOP (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 8 Regulatory Variance / Waiver Requests As per the above ‘Reservoir Pressure’ section, the deepest reported indication of hydrocarbons in Rosetta 1 is ~2115’ MD. The effective 7” casing shoe is at 1678’ (casing is slotted from 1678’ down to actual shoe at 1800’). So, the potential hydrocarbon-bearing open hole interval is 1678’ – 2115’ (top of 7” casing slots down to deepest reported hydrocarbons). The P&A plan includes setting a cement retainer at 1600’, above the 7” casing slots, and downsqueezing 300’ of cement to a depth of 1900’. Based upon reviews of the geological and mud log information, it is believed the potential amount of hydrocarbons present below 1900’ is very limited and therefore the risk of migration to other strata lower in the wellbore is low and of very limited consequence. Based upon this information, the proposed P&A plan for Rosetta 1 does not involve operations to reenter the open hole section in an attempt to isolate this limited section from the strata below. It is believed the probability of successfully reentering the open hole with coiled tubing after the passing of significant time is low and adds risk to the overall operation. A waiver to the requirements of 20 AAC 25.112.(a) is being requested to leave this limited section from 1900’ to 2115’ MD in its current condition and open to the strata below to the well TD at 4260’ MD. An equivalent variance was approved in a previous sundry (324-521). That sundry and variance request was written assuming an open hole cement plug was placed from 1800’ –1915’ on 8/29/58, prior to running 7” casing, per well records. However,a slickline drift run conducted 4/22/25 reached 2100’ SLM, indicating the open hole plug is no longer present at 1800’. For this updated sundry, the proposed downsqueezed cement from 1600’ to 1900’ isolates the same open hole interval as the 8/29/58 cement plug described in well records. 1.1 P&A Procedure – Rosetta 1 Note: Pre-Coiled Tubing Work (wellhead and cellar installation) approved in previous sundry 324- 521 has been completed. Additionally, some workwithin the scope of sundry 324-521 was carried out with slickline on 4/22/25, specifically: a drift to 2100’ SLM with a 2.25” sample bailer, showing that the open hole plug at 1800’ noted in the well file is no longer present at that depth; and a memory CBL from 1600’ SLM to surface. The CBL showed good cement behind 7” casing up to ~350’. Coiled Tubing Based Operations 1. Move in and rig-up Coiled Tubing and equipment. Note: Notify AOGCC 24 hours prior to the BOP test for witnessing. 2. Nipple up BOPE and test to 250 psi low / 1000 psi high. 3. Record shut-in surface pressure. Since wellhead installation, the observed shut-in wellhead pressure is 85 psi. 4. Drift to 1600’ for cement retainer. Slotted 7” casing starts at 1678’; stay away from this depth. Note: while there are no indications of perforations in the 7”, take care when running in the hole. It is possible if not likely that the 7” was perforated for testing. While care is to be taken on the entire trip in and out of the hole, it is possible that the interval from 730’-820’ may have been an interval that was tested as the operator reported gas and water when drilling this hole section. Agree. SFD gp p; CBL showed good cement behind 7” casing up to ~350’ setting a cement retainer at 1600’, above the 7” casing slots, and downsqueezingpg 300’ of cement to a depth of 1900’ py casing is slotted from 1678’ down to actual shoe at 1800’ Recommend approving requested waiver. SFD 1678’ – 2115 Gas was reported in drilling mud from 1650' to 1690' MD. SFD 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 8 5. Make up and run in hole with 7” cement retainer. Set the retainer at 1600’. 6. Rig up cement unit. Mix and pump 70 bbls of 15.3 ppg cement: a. Plug #1: downsqueeze 300’ (18 bbl) below retainer from 1600’ – 1900’. b. Plug #2: unsting from retainer and lay in 1300’ (52 bbl) from top of retainer at 1600’ up to 300’. 7. Circulate out excess cement above 300’. 8. Tag top of cement plug #2 with 5,000 lb down. Note: Notify AOGCC 24 hours prior to tag for witnessing. 9. Mechanically perforate 7” casing at ~300’ (above top of cement plug #2) with Gator Tool. Note: memory CBL run 4/22/25 shows TOC behind 7” casing at ~350’. 10. Establish circulation through perforations. POH. 11. RDMO coiled tubing unit. Post-Coiled Tubing Work 1. RU cement unit to dry hole tree. 2. Mix and pump Plug #3: 24 bbl surface plug circulated into 7” x 10” annulus and 7” casing via perforations at 300’. 3. RDMO cement unit. 4. Remove wellhead and well cellar. Complete excavation as needed around the well to allow cutting the 12-¾”, 10” and 7” casing strings 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 for witnessing. Top-off 7” casing, 7” x 10” annulus, and 10” x 12-¾” annulus with cement as needed. Note: Photo-document the site clearance including the cut off wellhead before and after any top jobs are performed, marker plate installed and final site clearance. 5. 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 100-003 Rosetta 1 API 50-009-10014-00-00 6. Perform post-P&A methane monitoring and record results for reporting purposes. 7. 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. Provide AOGCC 10 days advance notice for final site clearance inspection. Agree. SFD Consider pumping a few extra bbls of cement to provide room for error in CT displacement timing. -bjm Mix some excess cement and pump until clean cement returns observed at surface. -bjm Cut off should be 3' below original ground level, before gravel was added to wellsite. -bjm Cement returns taken through upper hot tap, 7" x 10-3/4" annulus valve. See attached email. -bjm Pump enough cement to place base of cement at lowest hydrocarbon show at 2115' MD, requires extra 24 bbls cement assuming 50% OH excess. -bjm 42 bbls - bjm 2115' -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 8 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 6 of 8 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 7 of 8 Figure 1.1-3. Wellhead Photograph (wellhead installed February 28, 2025) 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 8 Figure 1.1-4. BOP Configuration 1 McLellan, Bryan J (OGC) From:McVey, Adrienne <amcvey@asrcenergy.com> Sent:Monday, June 2, 2025 11:34 AM To:McLellan, Bryan J (OGC) Subject:RE: Rosetta 1 (PTD 100-003) sundry Bryan, Yes, that is correct. The red 2” outlet in the picture below is connected to the 10” surface casing x 7” production casing annulus. We will take returns from that outlet when pumping the surface cement plug. The smaller outlet is connected to the 12-3/4” cemented conductor x 10” surface casing annulus. Thanks, Adrienne McVey ASRC Energy Services, LLC 907-980-8623 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, May 30, 2025 4:07 PM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 To: McVey, Adrienne <amcvey@asrcenergy.com> Subject: Rosetta 1 (PTD 100-003) sundry Adrienne, When pumping surface cement plug, where do you intend to take returns? Will it be out of one of the hot-tapped annuli through a choke? 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. 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 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, Rosetta 1 ASRC Energy Services Alaska. Inc. Permit to Drill Number: 100-003 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 are the well log files from the cement evaluation log run in the subject well on April 22, 2025. Please acknowledge receipt by e-mailing amcvey@asrcenergy.com. Sincerely, Adrienne McVey Drilling Engineer DATED this 20th day of May, 2025. 100-003 T40432 By Gavin Gluyas at 3:24 pm, May 20, 2025 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?N/A Rosetta 1 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): 4260 Unknown Casing Collapse Structural Conductor Surface Unknown Intermediate Production 3270 psi 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 8/28/2024 None Perforation Depth MD (ft): Slots 1678' - 1800' Slots 1678' - 1800' 12-3/4" 650' 1800' 1800'7" 1800' TVD Burst None 4360 psi MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 100-003 3900 C Street, Syute 701, Anchorage, AK 99503 50-009-10014-00-00 ASRC Energy Services Alaska, Inc Proposed Pools: AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): Exploratory Unknown PRESENT WELL CONDITION SUMMARY Length Size 4260 Surface Surface 650' 650' Subsequent Form Required: Suspension Expiration Date: N/A 844 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: Unknown Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP Test Location Clearance Abandoned 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: 2024.09.10 15:20:44 -08'00' 324-521 By Grace Christianson at 12:23 pm, Sep 11, 2024 Verify TOC inside 7" casing and obtain AOGCC approval before cutting off wellhead. DSR-9/13/24 X SFD 9/12/2024 10-407 Submit 7" CBL to AOGCC and obtain approval before setting cement plug. X CT BOP test to 1000 psi X BJM 9/20/24 Variances approved - see explanation in section 1.0 Provide 24 hrs notice for AOGCC witness of cut off wellhead, before and after any cement top off. Photo-document the cement at surface, marker plate installed, final site clearance. Provide 10 days notice for final site clearance inspection. ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.23 08:11:35 -08'00'09/23/24 RBDMS JSB 092324 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 August 29, 2024 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 Rosetta 1 Well (PTD: 100-003 / API: 50-009-10014-00-00) Dear Commissioners, ASRC Energy Services Alaska, Inc (AES-AK) hereby requests sundry approval to permanently plug and abandon the Rosetta 1 well, 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 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 9 1.0 Well Summary – Rosetta 1 The Rosetta 1 well 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 Rosetta 1 are scheduled to begin 3Q of 2024. General Well Information Status: Orphan Well – See attached ‘Current Wellbore Schematic’ (Figure 1.1-1) for details. An active water / brine leak with small gas bubbles (5% LEL) was witnessed coming from a small leak in the 7” casing during two separate site visits in June and August 2023. 12-¾” and 7” casings were confirmed at or near surface, however a 10-¾” casing string (surface casing on file) was not found. The 7” casing has a P&A plate welded on top, however a wellhead is not in place. Base of Fresh Water: Estimated at 440’ MD / 440’ TVD Reservoir Pressure: As based upon information within the AOGCC & DNR well files from the original drilling of Rosetta 1, the deepest reported indication of coal, gas, or oil is ~2115’ MD. The strata through this interval 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. Strata below this depth have very little likelihood of containing hydrocarbons as indicated from comments within the files and lithology and mud log data captured during drilling. 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. Based upon available well data, the final mud weights were 10.6 ppg at TD, however this was not believed required to manage abnormal pressure. MASP: The Maximum Anticipated Surface Pressure is calculated as ~844 psi and is based upon a gas gradient to surface from the deepest section reported to possibly contain hydrocarbons at 2115’ 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 12-¾” Casing x 11” 5M, 11” 5M x 7-1/16” 5M (see Figure 1.1-3 & 1.1-4 for details) BOP Configuration: Coiled Tubing – 4-1/16”, 10M BOP (see Figure 1.1-5 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 above ‘Reservoir Pressure’ section, the deepest reported indication of hydrocarbons in Rosetta 1 is ~2115’ MD. As part of the original well operations, a cement plug was placed in the open hole from ~1915’ up to 1800’ and 7” casing run and cemented back to surface immediately above the open hole plug. A limited section of ~100’ with the potential to contain hydrocarbons is open and uncemented in the well. Based upon reviews of the geological and mud log information, it is also believed the potential amount of hydrocarbons present in this section is very limited and therefore the risk of migration to other strata lower in the wellbore is low and of very limited consequence. Based upon this information, the proposed P&A plan for Rosetta 1 does not involve operations to reenter the open hole section in an attempt to isolate this limited section from the strata below. It is believed the probability of successfully reentering the open hole after the passing of significant time is low and adds risk to the overall operation. A waiver to the requirements of 20 AAC 25.112.(a) is being requested to leave this limited section from ~1915’ to 2115’ MD in its current condition and open to the strata below to the well TD at 4260’ MD. Additionally, a variance to the requirements of 20 AAC 25.112.(b) & (c).1 is being requested to forego further isolation across the shoe and to allow the cement plug isolating the 7” slotted casing (perfs) to begin immediately above the slotted casing, at current PBTD of approximately 1677’ per Figure 1.1-1. 1.1 P&A Procedure – Rosetta 1 Pre-Coiled Tubing Work 1. Excavate around the well only as needed to provide access to the existing casing for the required pre- P&A methane monitoring. Perform monitoring and record results for reporting purposes. 2. Prepare location for coiled tubing/rig operations and excavate around the well as required. Remove any debris / solid waste specified for clean-up. 3. Hot tap the 12-¾” and check for pressure, the presence of cement and 10-3/4” casing in the 12-3/4” x 7” annular space. Note: There is a plate welded to the 7” x 12-3/4” at surface so this annulus is not currently accessible. The operator commented that the 7” cement job was “…figured to fill to shoe of the surface casing at 650’…”. There are no comments about returns during the cement job so it is not known where the TOC is in the annulus. Also, in later filings the operator reported to have run 10-3/4” surface pipe in the well, however, 12-3/4” (12” line pipe) is what is observed at surface. It is possible that this pipe may be the surface string or that it is a conductor and there is 10-3/4”surface casing isolated in the annulus of the 12-3/4” x 7”. 4. Hot top 7” and analyze the nature of the flow from the 7”. 5. Based on information obtained from the hot tap work, install slip on weld bushing onto the 12-3/4” (see note), new starting head, remaining wellhead and 7-1/16” dry hole tree. Note: The 7” casing is offset ~7/16” to the centerline of the 12-3/4” casing. To correct this eccentricity, a bushing will be installed on the 12-3/4” and the starting head will be placed on the bushing, centered on the 7” centerline then the starting head will welded to the 12-3/4” bushing. 6. Install cellar as required. Recommend approving requested variance.SFD Recommend approving requested waiver.SFD Variance approved as the existing cement plug appears sufficient to contain hydrocarbons in their indigenous strata. -bjm Variance approved on the condition CBL indicates sufficient cement outside 7" casing to prevent fluid migration. 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 Coiled Tubing Based Operations 1. Move in and rig-up Coiled Tubing and equipment. Note: Notify AOGCC 24 hours prior to commencing P&A operations and for the upcoming BOP test. 2. Nipple up 4-1/16” BOPE with 7” riser/lubricator to dry hole tree and test to 250 psi low / 1000 psi high. 3. Bleed any gas at surface from the well and record shut-in surface pressure. 4. If not previously drilled out, make up mill and motor assembly and drill the 7” cap plate. Otherwise, proceed to step 5. 5. Make-up mill on mud motor. Run in hole while maintaining shut-in wellhead pressure. No record exists for a cement plug placed in the 7” casing at surface, however if cement is encountered proceed to drill out the plug while maintaining the shut-in wellhead pressure. Note: The base plan is to drill any shallow cement plug using water. Shut-in wellhead pressures are expected to be in the range of 50 – 125 psi, depending upon formation pressure and actual density of formation water/brine. For reference, a column of fresh water down to the open formation at 1800’ and formation pressures at a worst case of 9.6 ppg, would result in a surface pressure of ~110 psi. 6. Continue to run in hole to PBTD at the top of the 7” cement wiper plug, at +/-1677’. Note: While there are no indications of perforations in the 7”, care is to be be taken when running in the hole. It is possible if not likely that the 7” was perforated for testing. While care is to be taken on the entire trip in and out of the hole, it is possible that the interval from 730’-820’ may have been an interval that was tested as the operator reported gas and water when drilling this hole section. 7. Once at PBTD, displace the well over to a 9.6 ppg brine or water-based mud. Verify well is dead and pull out of the hole. Lay down BHA. 8. If available and if deemed of greater efficiency than running on e-line, run the CBL in memory mode on Coiled Tubing from PBTD to surface in the 7” casing. Otherwise, proceed to step 9. 9. Make up and run in hole with 7” bridge plug. Set bridge plug at 1650’ MD (depth may be adjusted based upon depth reached on prior cleanout run and CCL data obtained from CBL run). Tag plug to confirm competency. Note: Notify AOGCC 24 hours prior to tag of bridge plug to allow witnessing of the operations. 10. Rig down Coiled Tubing. 11. Rig-up E-line unit. 12. Run CBL from PBTD to surface in 7” casing. Submit results of CBL to AOGCC immediately. Any further E-line scope will be based upon a plan forward as based upon CBL results. Approval of the plan forward must be obtained from the AOGCC prior to proceeding with any cement operations. 13. If not set previously by Coiled Tubing, make up and run in hole with 7” bridge plug on E-line. Set bridge plug at 1650’ MD (depth may be adjusted based upon depth reached on prior cleanout run). 14. Rig down e-line. 15. Rig up Coiled Tubing and equipment. 16. Tag bridge plug to confirm competency (if set by e-line). Set max safe CT weight on bridge plug, minum 5klbs to confirm it is set. -bjm Set max safe CT weight on bridge plug, minum 5klbs to confirm it is set. -bjm 7" cap plate will be drilled with gate valve milling tool, not CT. See attached gate valve milling procedure and diagram. -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 Note: Notify AOGCC 24 hours prior to tag of bridge plug to allow witnessing of the operations. 17. If remedial cementing of the 7” x 12-¾” annulus is not required, make-up cementing stinger and run in hole to bridge plug at 1650’. Note: Notify AOGCC 24 hours prior to pumping all cement plugs to allow witnessing of the operations. 18. Rig up cement unit. Mix and pump 65 bbls of 15.8 ppg cement and lay in a plug from top of bridge plug up to surface. 19. Pull cementing stinger to base of wellhead near ground level and circulate any cement from the well above that point. 20. Nipple down BOPE. Rig-down and move out Coiled Tubing and associated equipment. Post-Coiled Tubing Work 1. Remove wellhead and well cellar. Complete excavation as needed around the well to allow cutting the 12-¾” and 7” casing strings 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 7” casing and 7” x 12-¾” annulus with cement as needed. Photograph casing and cement. Note: Photo-document the site clearance including the cut off wellhead before and after any top jobs are performed, marker plate installed and final site clearance. 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 100-003 Rosetta 1 API 50-009-10014-00-00 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. Note: Contact the AOGCC with 10 days in advanced for final site clearance inspection after rig down. Below, Figure 1.1-1 shows the current wellbore schematic and Figure 1.1-2 shows the proposed wellbore schematic after P&A. Verify TOC inside 7" casing before cutting off wellhead. -bjm Exactly 65 bbls of cement required to fill inside 7" casing. Mix and pump at least 5 extra bbls (70 bbls total) to provide room for error in CT displacement timing. -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 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 7" gate valve to be rigged up? 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 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 4 1.2 Gate Valve Drilling Procedure – Rosetta The Rosetta 1 well (pre wellhead installation) has 7” casing to surface. The casing has a 7”, 8 round pin looking up. There is a makeshift “well cap” that is screwed on that pin. The well cap consists of a ~.20 to .25” plate that is welded to a metal pin end thread protector (See Fig. 1.2-1). If this plate cannot be removed during wellhead installation, the plate will need to be milled out with a Gate Valve Drilling Unit once the wellhead is fully installed. Post wellhead installation, the plate, if still in place, will be internally confined within the 12-3/4” x 11” 5M Starting Head. There will be an 11” x 7-1/16” 5M spool stacked on top of the 11” head and a 7-1/16”, 5M valve (See Fig. 1.2-2). There are numerous uncertainties that will be resolved with tapping of the casing strings and wellhead installation. Those uncertainties could alter the final wellhead configuration. Gate Valve Drill Plate 1. Hold safety meeting and perform JSA. Note: Designate muster point, and egress routes. Discuss and document all pertinent safety issues associated with the task to be completed. 2. Clear work area. 3. Move in 3-1/16”, 15M Gate Valve Drilling Unit (GVDU) and equipment (See Fig 1.2-3). 4. Install 3-1/16” 15M x 7-1/16”5M crossover spool on bottom of the GVDU. 5. Install 7” lubricator as required. Lubricator will be long enough to house the mill once the swab valve is closed. 6. M/U plate drilling mill on polish rod, R/U GVDU. 7. Connect and function hydraulic powerpack. 8. R/U a test pump to the needle valve assembly on GVDU 9. Clear all unnecessary personnel from the area. 10. Pressure test GVDU to 1,000 psi. 11. Bleed off to slightly above or equal to well pressure (to be determined during or after wellhead installation) after completing sufficient test. 12. Ensure the master valve is open. Open the 7-1/16” swab valve, run in and tag the 7” cap/plate. 13. Drill out the 7” cap/plate monitoring for pressure change. Note: It is anticipated that the cap will be secured to the Entry Bushing which should arrest torsional and compressive forces on the plate. Nonetheless, care is to be taken when drilling to ensure that the mill does not bind the plate. 14. Once fully penetrated through the plate, work through the plate area to ensure that there are no burrs or obstructions. 15. After completing the drilling operation, retract the mill into the lubricator and shut the 7-1/16” swab valve. 16. Bleed the pressure off the GVDU 17. Rig down the GVDU and secure well. 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 4 Figure 1.2-1. Pre-Wellhead installation – Rosetta 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 3 of 4 Figure 1.2-2. Post-Wellhead installation – Rosetta 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 4 of 4 Figure 1.2-3. 3-1/16”, 15M Gate Valve Drilling Unit 1 McLellan, Bryan J (OGC) From:Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Sent:Friday, September 20, 2024 9:12 AM To:McLellan, Bryan J (OGC) Subject:RE: Rosetta 1 (PTD 100-003) P&A sundry Good morning Bryan, The 7” lubricator underneath the GVDU is there to allow for a full diameter mill to be installed on the polish/drive rod. Our current plan is to use a step mill so we will progressively open up the plate to essentially full drift diameter of the 7” ID. Tim From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, September 20, 2024 9:02 AM To: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: RE: Rosetta 1 (PTD 100-003) P&A sundry Thanks for the detailed procedure and diagram. If we end up milling the plate with 3-1/8” OD mill, what will be the next step? Will we use a 2.75” mill on CT to mill a pilot hole through any existing cement inside the casing? Can the CBL Ʊt through the small hole or do we need to get the cap fully removed before running the CBL? Thanks 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: Thursday, September 19, 2024 4:43 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Rosetta 1 (PTD 100-003) P&A sundry ❚❛❜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. 2 Bryan, Please see the attached procedure. Thank you, Tim From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, September 18, 2024 2:55 PM To: Brandenburg, Timothy <tbrandenburg@asrcenergy.com> Subject: Rosetta 1 (PTD 100-003) P&A sundry Tim, Can you send me a diagram of the gate-valve drilling assembly and brief procedure for milling out the abandonment plate to attach to the sundry? Thank you 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:Carlisle, Samantha J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Letters to Merge into Rosetta 1 and Rosetta 3 Orphan Wells Files Date:Wednesday, August 2, 2023 11:55:48 AM Attachments:LETTER_1000050_Rosetta-3_Pressure_Contained_with_72pcf_Mud_from_WHF_159-008_p71-72.pdf LETTER_Rosetta-1_Pressure_Contained_with_72pcf_Mud_from_WHF_159-008_p71-72.pdf From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, August 2, 2023 11:54 AM To: Junke, Kayla M (OGC) <kayla.junke@alaska.gov>; Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: Letters to Merge into Rosetta 1 and Rosetta 3 Orphan Wells Files Kayla, Sam: Could you please insert the attached letters into the Laserfiche files for Rosetta 1 (100-003) and Rosetta 3 (100-005)? These files contain a copy of the same letter that is important because it states the overpressure encountered in each well was contained using 72 pound per cubic foot (9.6 ppg) drilling mud. The original of this letter can be found in the Rosetta 4 Well History File (159-008) on pages 71 and 72. Cheers and Be Well, Steve CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. ROBIN WILLIS GEOLOGIST -PETROLEUM ENGINEER TSO SUBWAY TERMINAL BUILDING LOS ANGELES 10. CALIFORNIA MADIOON 8•215C August 10, 1959 f ` U / y 77 L RECEIVED Mr. Le Roy G. Snow AU G 11 1959 U. S. Geological Survey 1012 Bartlett Building 215 hTest Seventh Street IDS ANGEIEs Los Angeles 14, California Dear Mr. Snow: Enclosed is Mr. Tucker's application for the drill- ing of Anchorage Gas and Oil Development, Inc., Rosetta No. 4 near Houston, Alaska. In accord with our telephone conversation, I have changed the depth of the surface casing from 150 to 300 feet. It is still my opinion that 200 feet of surface casing is adequate provided it is properly cemented. I would like to call your attention to the following facts. I have already pointed out that we know from seismograph shot holes that the surface formation at this location in the Houston shale series is a tough, impervious, nearly horizontal shale which, in my opinion, would effectively hold any pressure if given a cement bond of as little as 50 feet. In our conversation I did not go into detail con- cerning the pressure encountered in Rosetta No. 1 and Rosetta No. 3. Both of these wells encountered salt water at depths between 700 and 2000 feet in the Houston series. In both cases this water was found to have a pressure slightly in excess of normal hydrostatic head, which was easily over- balanced and contained with 72 pound mud. In Rosetta No. 1 the porous horizon was encountered at 3100 feet in faulted basement rocks. There was no sign of entry into the well from this against a light drilling fluid. In Rosetta No. 3 an extensive faulted or fractured zone was encountered between 1900 and 2000 feet. No entry against ez�T, i`ror u DMOTED Uu j�u N�1I$9 0 h�U;=ti'►' A(Mrdc;tt Page Two normal mud weight was noted here. At about 3000 feet this well encountered a porous zone in steeply dipping Eocene or Cretaceous beds which flowed salt water after the well was swabbed down, but which did not come in against the light drilling fluid. These three formations are the only ones known to be present in this district. I think it is a virtual certainty that the information obtained from the other two wells may be considered a reliable indication of the hazards to be encountered in No. 4. After talking with you I called Mr. Tucker who confirms the fact that it will be very difficult to get even 100 feet more 10-3/411 casing in Anchorage this summer. If, considering the foregoing, you decide that it might be reasonable to allow the proposed well to be drilled with 200 feet of surface pipe, I would certainly appreciate your ad- vising me thereof. _ Yours, ery tryl , c -- - Robin Willis, Engi eer RW:K Enc. cc: Mr. George H. Tucker ROBIN WILLIS GEOLOGIST -PETROLEUM ENGINEER TSO SUBWAY TERMINAL BUILDING LOS ANGELES 10. CALIFORNIA MADIOON 8•215C August 10, 1959 f ` U / y 77 L RECEIVED Mr. Le Roy G. Snow AU G 11 1959 U. S. Geological Survey 1012 Bartlett Building 215 hTest Seventh Street IDS ANGEIEs Los Angeles 14, California Dear Mr. Snow: Enclosed is Mr. Tucker's application for the drill- ing of Anchorage Gas and Oil Development, Inc., Rosetta No. 4 near Houston, Alaska. In accord with our telephone conversation, I have changed the depth of the surface casing from 150 to 300 feet. It is still my opinion that 200 feet of surface casing is adequate provided it is properly cemented. I would like to call your attention to the following facts. I have already pointed out that we know from seismograph shot holes that the surface formation at this location in the Houston shale series is a tough, impervious, nearly horizontal shale which, in my opinion, would effectively hold any pressure if given a cement bond of as little as 50 feet. In our conversation I did not go into detail con- cerning the pressure encountered in Rosetta No. 1 and Rosetta No. 3. Both of these wells encountered salt water at depths between 700 and 2000 feet in the Houston series. In both cases this water was found to have a pressure slightly in excess of normal hydrostatic head, which was easily over- balanced and contained with 72 pound mud. In Rosetta No. 1 the porous horizon was encountered at 3100 feet in faulted basement rocks. There was no sign of entry into the well from this against a light drilling fluid. In Rosetta No. 3 an extensive faulted or fractured zone was encountered between 1900 and 2000 feet. No entry against ez�T, i`ror u DMOTED Uu j�u N�1I$9 0 h�U;=ti'►' A(Mrdc;tt Page Two normal mud weight was noted here. At about 3000 feet this well encountered a porous zone in steeply dipping Eocene or Cretaceous beds which flowed salt water after the well was swabbed down, but which did not come in against the light drilling fluid. These three formations are the only ones known to be present in this district. I think it is a virtual certainty that the information obtained from the other two wells may be considered a reliable indication of the hazards to be encountered in No. 4. After talking with you I called Mr. Tucker who confirms the fact that it will be very difficult to get even 100 feet more 10-3/411 casing in Anchorage this summer. If, considering the foregoing, you decide that it might be reasonable to allow the proposed well to be drilled with 200 feet of surface pipe, I would certainly appreciate your ad- vising me thereof. _ Yours, ery tryl , c -- - Robin Willis, Engi eer RW:K Enc. cc: Mr. George H. Tucker MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: AOGCC Well file DATE: May 2, 2022 FROM: Bryan McLellan AOGCC Sr. Petroleum Engineer SUBJECT: Rosetta 1 and Rosetta 2 Orphan Well Site Survey Well Names: Rosetta 1 (PTD 100-003) and Rosetta 2 (PTD 100-004) Operator: None (Orphan Wells). Previously Anchorage Gas and Oil Development Objective: Locate and map orphan wells and associated debris, reserve pits and other features relevant to future well plugging and site clearance operations. Attachments: • Some photos are included in this report. Additional photos are located in the AOGCC wellfile. • DNR survey map with GPS coordinates of wells and other features. Observations: I traveled to the wellsites of Rosetta 1-4 to locate and assess these Orphan Wells in preparation for plugging and abandonment. I was met by a survey crew from Alaska DNR (Joe Donohue and Randy Guidu) at Rosetta 1 & 2 to accurately map the location of the wells. This date was selected for the site visit to be snow-free, but before the new vegetation concealed the debris and wells. Rosetta 1 Four previous attempts during site inspections in 1994, 2000, 2001 and in 2015 were unsuccessful in locating Rosetta 1 or the associated Diamond Core Hole #2 well. Both wells had been observed leaking saltwater and gas in a 1971 report. Rosetta 1 was located on 5/2/2022 after extensive use of metal detectors and digging multiple holes. It was about 30’ due north of the Northernmost corner of a ~15x60’ pit, probably a mud or reserve pit, shown on the map created by the survey crew. There is a lot of buried metal debris in the area surrounding these wells and many false hits with the metal detectors, also indicated on the survey map. We found casing couplings, old pipes and other metal debris, including cables and what looked like structural beams, possibly from a rig. Rosetta 1 had been buried under about 6” of organic material and tree roots and approximately 1.5 feet of inorganic dirt and gravel, indicating that it had been intentionally buried and not just naturally filled in with dead vegetation. The cap on top of the well looked just as it did in the 1971 photos. Rosetta 1 Oct 1971 Rosetta 1, 5/2/22 The 1971 report indicated some gas leaking around the outside of the casing on Rosetta 1. We did not see any gas bubbling but did not expose any of the casing and there was no water in the pit. Research should be done to determine who buried the well and if any downhole plugging work was done. It seems doubtful that anything downhole was done since the cap on the well looks much the same as it had in 1971. There is an MEA right-of-way and powerline just to the south and this well is just out of the Parks highway right-of-way, so either MEA or DOT may have been responsible for burying the well. The possible reserve pit indicated on the map could be checked for old drilling mud or contamination. Additional debris, pipes, cables, etc… was found partially buried in the woods south of the MEA cut around an area that seemed to have been leveled at one point. The debris is also indicated on the map attached at the end of this document. Diamond Core Hole #2 The Oct 15, 1971 AOGCC inspection report found a 3” diameter well flowing slightly brackish water with considerable gas bubbling up through it. AOGCC staff were unable to find this well in their 1994, 2000, 2001 and 2015 visits. The Diamond Core Hole well was found on 5/2/22 buried approximately 2’ below ground level after an extensive search with metal detectors and digging multiple test pits. The well has a metal cap welded on top and is partially encased and covered in cement. It looks as though someone shoveled a sack of cement into the hole on top of the well and then buried it. No obvious signs of leakage were observed. Diamond Core Hole #2, 5/2/22 Edge of metal cap can be seen protruding from cement encasement, 5/2/22. This is assumed to be the Diamond Core Hole #2 mentioned in AOGCC’s Oct 15, 1971 inspection report. Obviously someone has capped this well and placed cement over it between the 1971 and 1994 AOGCC site visits. No record of this activity exists in the AOGCC database and there is no way to determine if it has been plugged downhole or simply had a cap welded on top. Rosetta #2 Rosetta 2 was easily identified at the top of the highway cut in the DOT right-of-way. A~10’ tall, ~12” marker pipe has been welded on top of the well some time between the 1971 and 1994 AOGCC reports. No record exists in AOGCC’s records of any downhole plugging or welding on this marker pipe. There was no obvious signs of current water or gas leakage from the casing as were reported in the previous AOGCC reports. Gas leakage might not have been audibly detectible since wind was blowing at 10-15 mph. There was some staining on the side of the highway cut about 20’ from the well where water had been seen emerging from the sand during the 1994, 2000 and 2001 site visits. There was some standing water in the ditch below the well next to the highway with a visible sheen. The sheen could have been from road runoff since this well only produced gas and saltwater. Below are photos from the 2000 & 2001 reports along with photos from this May 2, 2022 inspection. The next 3 photos are from the 2001 site inspection of Rosetta 2: Rosetta 2, looking north, 7/17/2001. Bubbling gas next to casing of Rosetta 2, 7/17/2001. Water seepage from the highway cut ~27’ from Rosetta 2, 7/17/2001. Water leaking from the highway cut about 27’ from Rosetta 2, estimated at 2 pints/min, 9/4/2000. The remaining photos in this report are from the site inspection 5/2/2022. Additional photos are available in the wellfile. View of Rosetta 2 looking north, 5/2/2022. Rust-colored soil stained from previously observed water seepage. Sheen observed in water along the highway below the well 5/2/2022. Rosetta 2 looking south from drone, 5/2/22. Rosetta 2 looking south from drone, 5/2/2022. This well was rumored to have once been flowing significant saltwater down to the highway cut, south along the highway to the end of the ridge, then west down to the railroad, killing much of the vegetation in its path. This would have been before the 1971 site visit. Orange flagging tape in the woods on right of photo indicates location of Rosetta 1 relative to Rosetta 2, which is seen on the left of the photo. Photo taken with highway on the left, 5/2/2022. Rosetta 1 is center left of photo, spray-painted in orange. Railroad can be seen at the bottom of the hill, top of the photo, 5/2/2022. Rosetta 1 is spray painted orange in lower right. Rosetta 2 is seen as a pipe sticking out of the top of the highway cut in upper left. The southbound lane of Parks highway is in lower left. 5/2/2022 Other notable debris and possible reserve pit photos, all marked on the surveyor’s map: Possible reserve pit, 5/2/2022. Rosetta 1 is ~30 from the small flagging tape that is indicating some ~1.5” diameter wire rope in the upper right quadrant of the photo. ~2-1/2” pipe sticking out of the ground south of the MEA powerline cut, 5/2/22. Indicated on the map. Heavy piping, possible rig standpipe, south of the MEA cut, 5/2/2022. Timbers with 1” diameter wire rope, south of the MEA cut, 5/2/2022. Rosetta1and2Ͳ1 OrphanWellSiteInspectionFormͲ SiteName:Rosetta1and2 API#:50Ͳ009Ͳ10014Ͳ00Ͳ00,50Ͳ009Ͳ10015Ͳ00Ͳ00 DateandTime:ThursdayJune16,2022Ͳ1:45pm. Inspectedby:LisaKrebsͲBarsis,AlenaVoigt,LoriAldrich Access:ThepropertyissouthwestoftheParksHighwayaccessiblebyvehicleaccessiblebytheroad rightͲofͲway.AlargeparkingareaiswestofthewellsoutsideofagatedaccesstotheAlaskaRailroad. Thisparkingareacouldbeusedasastagingarea,thoughaccessfromtherailroadmayneedtobe acquired.Thewellsareatopahillabout20feethigherthantheroad.AnATVtrailonthecrestofthe hillappearsdrivable.Rosetta1isinaheavilyvegetatedareaonthehillandclearingwouldbeneeded togetequipmentclosetoRosetta1. Drainage:Thewellsareatthetopofhillbetweentheroadandtherailroad.Waterfromthehillflows offthehillinvariousdirectionsbutgenerallytothesoutheast.Adrainageditchparalleltotheroadwas dry.Nosurfacewaterwaspresentduringthesitevisit. VisualObservations:Rosetta2isvisiblefromtheroad.Duringthesitevisitnogasorliquidwas observedtobecomingfromthewellcasingofRosetta2.Noevidenceofwaterflowwaspresentat Rosetta2.OntheATVtrailadjacentbetweenRosetta2andthesumpedarea,finesedimentwasvisible inpatchyunvegetatedareas.PatchyvegetationandpresenceoffinesedimentcouldberelatedtoATV use. PossibledrillingmudwasobservedimmediatelyaroundRosetta1andupto35feetawayinasumped areathatcouldhavebeenareservepit. Nosurfacereleasesorleakingcontainerswereobservedinthevicinityofthewells.Somemetaland woodendebriswasobservedinthewoods. PIDreadings:Aphotoionizationdetector(PID)wasusedtoscreenambientairandadjacenttothewells. Bothreadingswere0.0ppm.BeforeusethePIDwascalibratedusingisobutylenegasandafreshair calibrationwasalsodone. Recommendations:ConsidersamplingthewaterwellͲpetroleumhydrocarbons,volatileorganic compounds,metals,polynucleararomatichydrocarbons. Rosetta1and2Ͳ2 Rosetta1and2SiteFeatures Rosetta1and2Ͳ3 PhotographicLogͲRosetta1and2 Photograph1:Rosetta2facingsoutheast Photograph2:Rosetta1 Rosetta1and2Ͳ4 Photograph3:PossibledrillingmudadjacenttoRosetta1Ͳ Photograph4:Possibledrillingmud~35feetwestofRosetta1 Photograph5:Waterwell Rosetta1and2Ͳ5 Photograph6:SumpedareafacingnorthwesttowardRosetta1Ͳpossiblereservepit Rosetta1and2Ͳ6 Photograph7:facingnorthwestfromATVtrail Photograph8:facingsoutheastfromrailroadaccessparkingarea 5000510051015102511751185119512151225125512651395140PARKS HIGHWAY 10050015002SITE 1: MP 59.4 PARKS HWYNOTES1. THE INFORMATION SHOWN HEREON IS BASED ON FIELD LOCATES PERFORMED BY THE ALASKA DEPARTMENT OF NATURAL RESOURCES, DIVISION OFMINING, LAND AND WATER ON MAY 2, 2022. THE PURPOSE OF THIS SURVEY IS TO ACQUIRE LOCATION AND CONDITION INFORMATION OF ORPHANWELLS FOR AOGCC, FOR POSSIBLE FUTURE PLUGGING, REMEDIATION AND RESTORATION WORK.2. THE COORDINATE SYSTEM FOR THIS PROJECT IS ALASKA STATE PLANE ZONE 4, NAD83(2011) EPOCH (2010.0000) IN US SURVEY FEET. THE BASIS OFCOORDINATES IS POINT NO. 100 "CP ROSE 2" BASED ON A TRIMBLE RTX SOLUTION PERFORMED ON MAY 4, 2022. POINT NO. 100 LATITUDE: N 61° 38'26.54655" LONGITUDE: W 149° 51' 40.86629"3. THE VERTICAL DATUM FOR THIS SURVEY IS NAVD88 (DERIVED FROM GEOID 12B). THE BASIS OF VERTICAL CONTROL IS POINT NO. 100 "CP ROSE 2",HAVING AN ELLIPSOID HEIGHT OF 347.80' AND A GEOID HEIGHT OF 323.57', BASED ON A TRIMBLE RTX SOLUTION PERFORMED ON MAY 4, 2022.4. FIELD WORK AND DRAFTING WAS PERFORMED BY RANDY GUINTU AND JOSEPH DONOHUE. DRAWING WAS REVIEWED BY KEVIN BOW, PLS.GRAPHIC SCALE15 METERS6060 FEET150301 METER = 3.280833 U.S. SURVEY FEET1 U.S. ACRE = 0.4047 HECTAREENDING:SCALE:DRAWN BY:DATE:DATE OF SURVEY: SURVEYOR:BEGINNING:STATE OF ALASKAOIL AND GAS CONSERVATION COMMISSIONANCHORAGE, ALASKACHECKED BY:SHEET:OFDNR, DMLW, SURVEY SECTION550 W. 7TH AVE, SUITE 650ANCHORAGE, AK 99501-357631KB1"=30'05/05/2022JD5/2/20225/2/2022VICINITY MAPScale: 1" = 1 MileSource:Alaska Mapper - National Map TopoORPHAN WELL SURVEYS HOUSTON, AKSite 1: MP 59.4 Parks HwySite 2: MP 58.6 Parks HwySite 3: MP 58.6 Parks Hwy, down trail 14 mi.WWWLEGENDFOUND WELLSET 12" SPIKE - GEODETICCONTROLFOUND PROPERTY CORNERPOWERPOLEELECTRIC JUNCTION BOXGNSS OBSERVATION TAKENEDGE PAVEMENTEDGE TRAILTOP/TOE OF SLOPEEDGE OF PERCEIVED SUMPPOWERLINEPPW NOTE to FILE Rosetta Wells- Well visit on 28 Aug 2015 Rosetta #1, #2 , #3 , PT 00-040 100- 50 SCWNNEQ JUL 2 12016 -NSB SUN 2 7 2019 16) frmWeRFilterSub API WELL # PTD # Cont UICPermit# Oper Name Well Name Status Status Dt. Field 50-009-10014-00- 1000030 No ANCHORAGE GAS AND OIL ROSETTA 1 P&A 6/30/1959 *EXPLORATORY 00 DEV 50-009-10015-00- 1000040 No ANCHORAGE GAS AND OIL ROSETTA 2 P&A 521/1956 "EXPLORATORY 00 DEV 50-009-10016-00- 1000050 No ANCHORAGE GAS AND OIL ROSETTA 3 P&A 10/22/1971 *EXPLORATORY 00 DEV 50-009-10017-00- 1590080 No ANCHORAGE GAS AND OIL ROSETTA 4 P&A 10/7/1961 *EXPLORATORY 00DEV 50-009-10018-00- 1610270 No HACKATHORN DRILLING CO ROSETTA 4- P&A 924/1962 *EXPLORATORY 00 A Summer Intern Jasper Jackson and myself (Guy Schwartz) made trip up to the Rosetta wells in order to inspect and locate the wells. We easily found Rosetta #2 next to the highway. There is now a new powerline that crosses the highway and nearly overhead of the wellhead. Estimate it is approx 40 ft from the powerline to the wellhead surface position. No fluids were seen escaping the well head area and the open ports on the wellhead did not appear to be leaking any methane. Recommend getting an LEL meter and sniffing the outlets on the wellhead to verify absence of methane. Could not locate Rosetta #1... may have been disturbed by the recent work to add a powerline right of way. Quite a bit of dirt and trees have been cleared in the assumed area of the wellhead. Could not find Rosetta #3 either. Vegetation was very high ... we did find parts of the rig such as cable and drums and a 8' piece of casing that was likely part of the wellhead. Wellhead was likely covered with local junk or vegetation. Suggest having the "google map" marked with the exact location for future reference and take an accurate GPS coordinate next visit. Red circle on the current Google map is actually a meter post station and not the wellhead location. Rosetta #3 piping found near wellhead area. �.�JILL Rosetta #2 wellhead. t lc-apfm 10j an95 PLUGGING & LOCATION CLEARANCE REPORT State of Alaska ALASKA OIL & GAS CONSERVATION COMISSION PTD No. DO - 098 3 Lease Memorandum To File: API No. ppb /0p o0 Well Name N2 ose tea./ Operator Am c/7 -accia_o�_ r r� _ x, d al1�� J Location Sem i l8 r-3 W --PL 1%260 Abnd Date Spud: TTTD =1 a —' Completed 9130 L Note casing size, wt, depth, cmt vol, & procedure. Sfc Csg: Long Cag : 1 2 16,0 ($ OSS 0j 4Ef O O Sic, 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: Conclusions: Code y Signed Date 2 �27/9r s I J� 1:4 J, TO: David John Chairm THRU: Blair Wondzell,-teAm;,, P. 1. Supervisor 9/28 FROM: John Spauldin , ' Petroleum Insp. 11 AA '. State of Alaska Alaska Oil and Gas Conservation Commission DATE: FILE NO: SUBJECT: October 23,1994 ROSETTA.doc 00� 00 to odd Inspection of Rosetta Wells Vicinity of Houston Ak. ,, Friday October 23,1994. 1 traveled by POV from my residence to the area near Houston Ak. to inspect the 5 Rosetta well locations for leaks of oil, gas and ,� water. Due to the new growth of brush and quite tall grass I was able to locate 4 of the 5 wells, ( wells 2,3,4,&4A. Rosetta #2: The 101/2" casing extends about 12' above ground level and has a flange welded to the top with a steel plate bolted to the top. There are two side outlets, one near the flange ( 2" ) and one about 4' from the flange ( 1 1/2" ). The 2" side outlet appears to be plugged. The 1 1/2 n outlet is open and does not appear to have any hydrocarbons or water escaping from it. Water is bubbling up around the casing and is flowing down the highway cut toward the highway; due to the sandy nature of the soil,the water is flowing a distance of 10 to 15 feet before disappearing. I dropped a rock into the 1 1/2" side outlet and was able to detect fluid at or very near the surface. The water coming from around the casing does not appear to have any hydrocarbons in it, although a slight smell of gas can be detected. I recommend that the State of AK consider a proper abandonment of Rosetta well #2 in the near future Rosetta #3: There is a 61 /2" marker post welded to the casing head extending 51 /2" above ground level. The marker is properly marked with the well name, section, township, range and meridian. The well marker is located in the middle of the MEA rower line right of way constituting a personal hazard as these ROW s are quite often used by ATVs during the summer months & snowmachines in the winter months. `' o 21 There is a rusted area where the marker post is welded to the casing head; it does not show any leakage of any type. The location is cluttered with old rig junk and an abandoned camper. The location is growing over with alders and small birch covering up much of the existing rig junk. Rosetta #4: A properly marked 4" capped steel pipe is welded to the 6" casing head. As noted in a previous report dated 10/25/711the 1 1/2" valve located on the 6" casing was found to be operative. 1 found this valve to be in the open position and was unable to close it. There did not appear to be any hydrocarbons escaping from this valve or the several bullet holes in the 4" marker post. The area in and around the cellar box has some water seepage that appears to be somewhat salty. Rosetta #4A: Located approximately 75' from Rosetta #4, has a properly marked 4" capped steel pipe, with well name, section, township, range and meridian. No leaks were found in the area immediately adjacent to the casing head. the marker post has bullet holes in it with no apparent leakage. As noted in the 10/15/71 report at that time, parts of a rig were scattered around both Rosetta 4 and 4A, all junk has been removed and everything looks to be in excellent shape. Rosetta #1: 1 was unable to locate this well or the diamond core hole located next to Rosetta #1. The area has grown over with quite dense vegetation and the well has no known marker post. This well is of some concern, as the 10/15/71 report indicates there was some leakage arond the casing of the well and also from the 3" diamond core hole. I will return in the spring prior to the grass getting as tall and try locate and inspect the wells in question. Summary and Recommendations : I inspected Rosetta wells 2,3,4&4A and found all to be in fair condition with the exception of Rosetta 2 as noted above. recommend that Rosetta 2 be considered for surface abandonment, # 3 be cut off below ground level and minor work that should be done to the other two wells. Property ownership will need to be determined. do A° $ s .t e-? t -9- / "ll kms+ 4 ° ,,, , d: �> i _ Ae Fcj 11 C WELL COP,^:PLETiON OR RPCOMPLETION REPORT ANO WELL LOO DESIGNATE TYPE OF COMPLETION: Neta i�7 ��iorl:- 171 Plug Same N Well LJ Over Deepen ❑ Back ❑ ❑ Different El ❑ Reservoir Reservoir (_j Oil Gas ❑ Dry ❑X DESCRIPTION OF WELL AND LEASE Operator Address Anchorage Gas &_Oil Development, Inc. ( 134 East Second Ave., Anchorage, Alaska Lease Name I Well Number P'ield & Reservoir Anchorage Gas & Oil Development, Inc. i# 1 I Houston, Alaska Location'] j ()� S z J 5 Qi t~ ff o i� 1 H e NW c u i' nor t1 f 5 t'C Z () Sea—TWP-Range or Block &Survey NE Corner of hill Corner of Section. 20, Township 18 North, Range 3 West. –County I Permit number Date Issued Previous permit number Date Issued Third Division I None Date spudded I Date total depth reached Date completed, ready to eyation June, 1954 A profit I Elevation of casing 'gust, 1956 'Saspended J .RKB, RT or Grfeet I hd. flange 'e'/,'•<' 33 3 feet Total depth + P•B,T.D. Seigle, dual or triple completion? I If this is a dual or triple completion, 4, 049 Ft. I! furnish separate report for each com- pletion. Producing interval (s) for this completion – I Rotary tools used (interval) Cable tools used I (interval) None F1111 Time None Was this well directionally drilled? NVas directional survey made? Was copy of directional survey Date filed No I NSA riled? Type of electrical or other logs rum (check logs filed With the commission) I Date filed �'•P•v. and Microlo May 2 , 1960 __ _ CASING RECORD Casing (rel)ort allstrings set in well --conductor, surface, intermediate, producing, etc.)! Purpose Size hole drilled Size casing set Weight (Ib./ft.) Depth set Sacks cement Amt. pulled Surface (12-" _ 10 41, I Conductor 3 I qn 650 _150 ATone I 26 _ 1,800 400 None TUBING RECORD LINER RECORD Size I Depth set Packer set at Size. Top Bottom Sacks cement Screen (ft.) in. ft. I ft. in. ft. I ft. I ( PERFORATION RECORD ACID, SHOT, FRACTURE, CEMENT SQUEEZE RECORD Number per ft. I Size & type I Depth Interval Ain't. & kind of material used Depth Interval 1682'– 1605 t INITIAL PRObUCTION Y Date of first production Producing method (indicate if flowing, gas lift or pumping—If l None I NSA Date of test I-Irs. tested Ch kA i show size & type of pump:) I I o e s ze I Oil prod. during test Gas prod. during test I Water prod. during test I Oil gravity bbls. I MCF bbls. °API (Corr) Tubing pressure I Casing pressure I Cal'ted rate of Pro- Oil I Gas Water I Gas—oil ratio Pro- duction per 24 hrs. bbis. MCF bbis. Disposition of gas (state whether vented, used for fuel or sold): CERTIFICATE: I, the undersigned, state that I am the President of the AnchA7`Ue rigs R Oil Dev., Inc. (company), and that I am authorized by said company to make this report; and that this report wf's pre- pared under my supervision and direction and that the Bets ated therein are true, corre��nd cplete to the best of MY knowledge: � -�° =` ` signature. G orae H. Tucker, President :uu Alaska Oil and Gas Conservation Commission Well Completion or Recompletion Report and Well Log Form No. P-7 Authorized by Order No. 1 Effective October 1, 1958 .;TAIL OF FORMATIONS PENETRATED Formation Top Bottom Description* Permable Sand 180 390 Permable Sand 615 695 Sand 730 820 3 sand stringers 10 to 15 ft each 980 1,640 Hard, fine, green sand 3,065 3,155 a Gas & Sart water 46 to 93 Mii1ll darcaeS Porosity 32.8 and 29.4;9 Permability 182 and 197 mi1lr da.rcj es Show all important zones of porosity, detail of all cores, and all drill -stem tests, including depth interval tested, cushion used, time tool open, flowing and shut-in pressures, and recoveries. vSTRUCTIONS: attach drillers log or other acceptable log of well. his Well Completion or Recompletion report and well log shall be filed with the Alaska Oil and Gas Conservation Commission not later than sixty '0) days after project completion. C3 2 Legend O Diamond drill hole 0�400 800 (Foo 1000 Figure 2. - Plan, Houston coal -drilling project. chos exi: quer cour 481 this feet or t was down rela poin whic were the the hole Deta tion s ervl by 1, numb( under appal glac dicat cons! res ex and n locat and t diffi tion ples beds FdRMNO. O%? IB MEMORANDUM T0: r FROM: a ' State of Alaska DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS 0. K. Gilbreth, Jr. Chief Petroleum Engineer DATE October 15, 1971 Karl L. VonderAhe ,Q SUBJECT: Inspection of Rosella Wells Petroleum Engineer �k & Vicinity Near Houston. ra f' Left the office October 14 at 9:20 A. M. and drove, with Don Blasko, U.S.B.M. Engineer, in a Federal car, to Houston, arriving there at 10:45 A. M. We visited the location of all five Rosetta wells and checked them for leaks of gas, oil and water. Rosetta #1 has no marker. The casinghead is in the remains of a cellar with board sides. The top of the casing is about two feet below ground level and about one foot above the bottom of the cellar. It is 8-5/8" (est.) casing with a steel plate welded on top. There are no side connections aboveground, but there is a leak in the casing a few inches below the surface from which a very small amount of gas is bubbling. We took a liter sample of the gas by water displacement. There also appears to be a very slight seepage of water which is 'very salty. Also caught a sample of this water. Either the water seepage is very, very slight or it is seeping away into the surrounding formation, as so little is present it was difficult to get even a liter sample. Alongside, to the south toward the railroad, is a sump of about 15' R 60' which is standing nearly full of water. About 90 feet SE of Rosetta #1 a 3" pipe protrudes 7" aboveground and from this is flowing a stream of water with considerable gas bubbling up through it. The water flow was measured and found to be one gallon a minute, or 34 barrels per day. The water is slightly brackish. 'A liter sample of the gas was caughtby water displacement and a gallon sample of the water was taken._ Don Blasko is sending the gas for analysis and the water for salinity determination. At present we have no way of identifying this well, but it is known that Tucker and Peterson requested the Bureau of Mines to leave their diamond core hole #2 unplugged for their use. Because of the size of the pipe from which the water is flowing it would indicate a diamond core hole rather than a rotary -drilled hole for oil exploration. Tucker & Peterson may have wanted it left open for a water supply for their drilling rigs. While brackish, the water could be used for drilling mud and cooling water for engines. This possibility should be explored to identify the well and the responsible party. Considering it is only a 3" pipe and is flowing water, the latter seems more likely. There is no showing of oil in this water or adjoining the surface stream from it. There is a great deal of iron oxide below as the stream flows through a lot of discarded thread protectors, collars and barrels. The stream flows for about 60 feet away from the highway and toward the railroad; here it seeps into the ground so that beyond this point down to the base of the railroad fill there is no water visible on the surface. The water is not salty enough to show any effect upon the vegetation. J r� 0. K. Gilbreth, Jr. -2- f October 15, 1971 About 36 feet SE and 54 feet NE from this "water well" is a 10-1/2" casing protruding 3-1/2 feet above a concrete block. It has a flange welded on top aka and a steel plate bolted to the flange. There is a 1-1/2" pipe stub welded into the casing near its base. This pipe stub is open and a pebble thrown into it can be heard rattling down the casing showing that there is no fluid near the surface. The protruding casing is serving as a marker, as the well name "Rosetta #2" and the 1/4 - 1/4 section, township and range are bead welded on it. At this time there is no water seepage showing on the highway cut face or in the ditch; all water showing on the surface is flowing away from the highway and toward the railroad. As the highway cut is through a mixture of sand and gravel it is possible that with winter temperatures the water from the "water well" may freeze on the surface to the point where the water may be diverted in the other direction and seep through the gravels to the highway. It is also possible that a subsurface leak in either Rosetta #1 or #2 from which water may now be seeping toward the railroad could be the cause of water going the other way through the gravels when it gets cold enough to freeze and seal the seepage, which may now be moving southwestward, and reverse the direction of flow. However, we were unable to find evidence of any fluid reaching the surface away from either of :these wells. Any oil found in the vicinity of the railroad must have come from spills originated by the railroad. Blasko dug a s- and while wait Willow for lun Upon returning sustain a flaw 3 We then drove to head and extendi marked with the the top of the',.c has rusted throu leak at some tim is cluttered wit: equipment. This highway. iression next to the welihee the water to clear to get_a :o get some matches to test is on the top of a ridge and is cellar of Rosetta #1 f it we drove into or flammability. ell" and found it would r welded to the casing- rker is properly ship and range. At the collar or weld has been a small fluid ecently. The location and other pieces of ut 150' NE of the At the location of Rosetta #4 the properly marked 4" steel tubular marker is welded into the top of the 6" casinghead and extends about six feet above the ground surface. A valve on a 1-I/2 stub welded into the 6" casing is still operative.` When opened it showed no fluid nor any gas pressure. ,� Rosetta #4-A is about 75 feet SW of #4. It has the jackknife derrick and substructure still standing over it. The draw -works are still in place on the floor. There is a Wilson -Snyder pump setting on the ground at the rear of the rig. The traveling block is laid down on the floor, but the cable is 0. K. Gilbreth, Jr. -3- October 15, 1971 still in place through the sheaves of the block and crown. The stand pipe with rotary hose still connected is standing on the edge of the floor and tied at the top with only a piece of hemp rope. The kelly joint is on the ground by the side of the road. Much junk and pieces of equipment are scattered around the location. There is a 9-5/8" casing collar exposed at ground level with a 6" marker welded into it and extending 5-1/2 feet above the surface. No connections on either the marker or the 9-5/8" casing. There is no leak of any kind apparent from this well. We returned to the office at 3:45 P. M. R i I I DIR UNITED STATES i """ C. ENG DEPARTMENT OF THE INTERIORh -- i ..ENG BUREAU OF MINES i 2 ENG P. 0. Box 2259 3 ENG Anchorage, Alaska 99510 - 4EN 5 ENG i 1 GEOL October 8, 1971 2 GEOL 13 GEOL Mr. Karl VonderAhe Petroleum Engineer State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Karl, In reply to your request for information regarding the Rosetta wells near Houston, I am forwarding all the data I have on the wells from my individual well card file. Also enclosed is Bureau of Mines R.I. 5350 "Investigation of Subbituminous-Coal Beds Near Houston, Westward Extremity of Matanuska Coalfield, Alaska" by R.R. May and R.S. Warfield, 1957. On pages 9 and 12 of this particular report can be found references to the gas encountered while drilling. Page 10 contains a stratigraphic section chart and notes depths which gas was encountered. Pages 12 through 20 contain a drillers log of all the holes drilled. The holes are geographically identified and locations are given. I notice that Rosetta wells No.'s 1 and 2 were both drilled in the NW 1/4 of section 20. Whether they were drilled immediately adjacent to Bureau of Mines Core Hole No. 2 (see page 8 of R.I.) I can not say. If additional information becomes available, I'll forward it to you. Attachments cc: Asst. Dir.--MS,WO Dep, Asst. Dir.--MS,WO Chief--AFOC, Juneau R.S. Warfield, AFOC, Juneau file Sincerely, Donald P. Blasko Petroleum Engineer CTAS A±VCH0RAGs6 • • b T i . j 1 'S N v $ ° s ao Z Legend O Diamond drill hole 0WS40'i0 'F0�;00 O\ Figure 2. -Plan, Houston coal -drilling project, C e q c 4 t: f( of WE do r pc wh we th th ho De til s e: by nun unc apF g la dic con res and 10c• and dif. tior ples beds y N f 4 f Rosetta Spud,=.;, 6 : 54 Units �Oss'. #1 s, S2 • tb/30/59 ' E Wildcat t ...._.._..,� Rosetta Na 1 L009: . Cap. $taws: Lee, Nos: srat 4,260 ft.� P Anchorage Gas & Oil Development -` a' e , '—Loc' DsH.'.i. C4a�p. Rra� s Quarter Corner NW quarter Corner 20 sea • x T. 18 N T.R. R. 3 W . A • � �I!k. --Date � Meridian Seward Meridian • �,,�. � North L Palmer On Shore ACX o: and s131'11,9 0 shore Wa s i 11a Qiv: pfei�.�al Survey,= Aar' 100-003 S,uw%ev 3AJt 13 VD7 FECH. "TA -SErPrN i,'IAY 0 9 1,96, E. H. COBB IN REPLY REFER TO: UNITED STATES �Q DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Alaskan. Geology Branch Fairbanks, Alaska DAzamber 17,1959 11r, G.Donald F.berlein Acting Chief Alaskan Geology Branch U.S.Geologieal Survey 345 Middlefield Road Menlo Park,Calif ornia Dear Don: There will be send to You today via parcel post a package containing the fallowing washed lithology chips. From the wall Rosetta # 1 the samples between the depths of 4095 feet to 4245 feet and from the Rosetta # 4 well all the washed samples between 0 and 1624 feet.An occasional check for rmicrofossils brought no results.This are all the samples I have recieved from those two wells. ,n Si'i'cc'erely, /Henry Bender Phys.Sci.Techn. PECEIVEa NOV 19 41959 ALXcSMA,y "EU WENLO PARK DATA MR icy iPN Eric 4004 Colleges Alaska June 310 1958 Harlan R. Her ;quist Navy Oil unit II. S. Geological. Survey ashington 25., D. C. Dear flarlan: I believe that today Hank is sending you, some slides of material he has picked : rom the Brie? orale Oil and Gas Co.'s Rosetta No. 3 (cormon7.y called tl:us e `G1oton well"). The .fauna �s not vent' good but I ?mo-,- the Survey would be very :interested to find out if the rocks are Tertiary or Cretaceous. If aad when you have a chance to look at them Mould you please let George Gates know Tdth a co-py for this office. I believe this is the first opportuniity that "hank has had to work on • these samples. He is going right along v4-1th them but is expecting to Uo out in the field wa to Clyde I arshaftig for a week or ten days., so I told him I tho:ight it r,-oi)ld be a good idea if he were to send you slides he has picked to d*e,. Later hank v�i3 2 be gone a month with Patton in the Koyukuk basin* RYm � Irene tells rte that she sen from the 'a. 3 prole last fall bu concretions. It is too b^.d v e c Irene as I don't think same has h (I'uth Schmidt and I) folu?d that ry cros cope out very 1 i ti.'_► e other light --and she handed us a ;paint finger. ,ou some possible microfossi is that they turned out to be ralcin t t spend a little time with d any microzaleo training. Tie ,he has a very fine binocular equipment, not even a zdke brush ks thick as my little The Rosetta No. 1 hole, M i.c'_ is located several hundred feet soutim6st of N"da 3a penetrated about 2,500 feet (I donft rerw:rber the exact amou lit) of r'Tertia+N,fi glen want i,?Zrough a big f.-�ui.t (the presiL:. -Ly t1h e cne vl i ch shows on the Geological T au of 6LZaska as bordering the ncrth side of ;.ire i_at anus Aa valley) :Talo calcareous rocks of lar-deteridned. a -e. They completed the holey dt7 and abandoned at about 4.9000 feet. As far as I 1 -mow -vie did not get any =1 fro:: it. They had trouble 'with iliE second hole., located nearby., and it was abandoned at 300 feet* According to Irene Rymz the third: hole is still. drilling (below 4.1500 feet when we were there) in the sazae ruaterial they ►: ere in when they shut do= last fall for the winter. They have not penetrated the fault although the beds are steeply dipping* +kt L.9500 feat thefy .Fina. -3 dr -lllne., in alternating, siltstolze, sandstone, cai"bonac..w?:`; L.o and a ;jidall ount of coil�louwoate* The section a' this do -.1,)t:2 a?:? G_ii'S mos bly ikJll3''..arine as M -i -ane 411-3s found a fev Pwu_t iIh6 is saving the best of thane for a Uhi.rna _he roclt is gay-ar in color and see::w hai°der tan tao �`ertiary from Mm- .hransoa I'liver or ;Deep Creel: - acs dami on the Kenai Peninsula. We gander if it could possibly be sc)mu pha.;e of t1he 1:atanuslca foxuavirilp Math and l also v-.LA16ed the Stxidard I've;, Cwcea'hole. hey- 'were 'were s t il.l dr= llf--a :.i the Tertiary at 12.v750 .t. e3c" wlhd� ' we Frere-Wiere. T4- loo:ced .�.k the s< ue beds as tl.a product t , horizon at ��), ^n Gilberts the well geolragdst said t1liey had had no aj&Afiemit ;shows. They--il :re xwely try-Ing to ualte Iio"►e for utra' igra--TUC ;)-arposes and can probably gat do�i to 4s000 or a 1 tti.e �_��;Iosr@ �,Ii c:'a .s tha capacity of Ilia rim. 1 W< s dto ? `? rl-,jiv- iia t' ? 3 i,aat weeltend <' -,d Flore:lco¢ .Clts and?qty c 1"8 Gal l ; �."'J: :; � � r iiK-i waaa:LI er is very a:l ny and pleases�2u buzz ha � e -. to � o " -51 :-)rest firesybecsuse it is so dx7o Poor 1 en. l�u�kel v. -as OL -'V v l las" a t.-,DoI. f.l.�,iiiJ771g a.irfiJ near h3.9 n homeste..d (J ck Loves �' d 1,vmi � are there too} 1n ovldai;rc Yen A t.�"i i"Li tI-e;y ii2 '� wt :air tout the fire .isni t7-�o�,u,, out yet* �. 1=E�.''Z no -v iFL7:"•IiS for the 'Jrli-�crsit;r wol storax Joan L'4=Donald has tr r..sferred to 113?reau of PLA)l.:i.c P,•aads• The .istos lure in you ---- rluansev r_cm-, They have 11L,+,—the 'l tchens were aomb:ined. ie four hips on -Uie s.:?.t taw? s.':.de s: -Z L 1C c0i'-P U:ald. were C=ried a- ^..-y' J. mclfe room for Standard (All s mgxnsicn. Pete rid tree o'Lhers are out climbing 14 ILU- ma Vrds weelt, Sincerely* cc: Gates ✓ PAwh Uormoe U. Robinson Geologist RECEIVED JUN 13 1958 1tLAti?%A&v ULOL. sic. MENLO PARA G. Donald. Zberlein, F oi.f2 t, U.3.G. . Alas.kan Geoloa Branch, B= 2f:59, Juneau, A - merge 0. Gates, fief, Alaskan Geology Branch, U. . G. . , Menio. irk, California 9 y f c'1 t�':�3.24, 1,057 nclosed is a copy of a letter to Art ,r z concerning; my visit to the veils Iteing drilled. at Houston. Under separate cover I am sending you some of the rock belcw 1750 feet to RoaettA No. 1. ming from the cuttings and accordingto Irene, they re Axa this kind of rock all the way dawn to 4800 feet at the bottm of the hole. t would you call this rock and what was the original rock from which it was derivedt Regardless of the stings, it tertAiniy is not ra rock in which one viould expect oil to occur and as far as ail occurrences are concerned should be considered basement. When I crushed sme of this material and attempted to dissolve it in kydroahloric acid, I got a large amo, t of residaze of a milky white mineral, brittle to the point of qr knife. ?- i^'4A` George 0. Gates Chief Alaskan Geology Branch ietat..ed to Mi.ni.fon, Anchorage., 7/17/57 Typed end mailed o Park, 7/24/57 3, cc: Gates 0 • M "7 -*Vp* Al Geol:=, Z%irlb"" Auvember 2s 1956 Artl-. $ o -. Cilit.-ornia ll s les s F4 Cut Flint Grants File (Te chni eat ) Reading AG/3m UNITED STATES DEPARTMENT OF THE INTERIOR GEIOLOGCAL SURVEY 1`r. George 0. Gates Chief, Alas'_ -an Geology Branch U.S. Geological Survey l er�lo, Far T1, vial. Dear George: in reference to our letter of September 30, regarding the poss-ible obtaining of cores and c'.,ttings from Tucker &- Peterson, dAbj�a Anchorage Gas w-, Oil Development Co., I have not as yet -'peen able to obtain a satisfactory sample arrangement with the Cou.pany. �.s you already know, these people are thru for the year having reached a little over 2,000 feet and as they plan to resume operations in the spr-ng I gill again try to make a deal with t1lern on getting samples. T e feeling i get in talking with. these operators is that they would like to withhold any and all information possibly in the hope of getting some participation. -ith best regards, cc: Snoti. Very truly yours, L.. Saarela Regional liming Supervisor Nom OCT 2 6 1955 + ATF.S t OF Ty a✓ v IN REPLY REFER TO: -rUNITED STATES W -o '%t DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY , xichorage, Alaska 3oii .: 5 7 October 24, 195 1`r. George 0. Gates Chief, Alas'_ -an Geology Branch U.S. Geological Survey l er�lo, Far T1, vial. Dear George: in reference to our letter of September 30, regarding the poss-ible obtaining of cores and c'.,ttings from Tucker &- Peterson, dAbj�a Anchorage Gas w-, Oil Development Co., I have not as yet -'peen able to obtain a satisfactory sample arrangement with the Cou.pany. �.s you already know, these people are thru for the year having reached a little over 2,000 feet and as they plan to resume operations in the spr-ng I gill again try to make a deal with t1lern on getting samples. T e feeling i get in talking with. these operators is that they would like to withhold any and all information possibly in the hope of getting some participation. -ith best regards, cc: Snoti. Very truly yours, L.. Saarela Regional liming Supervisor Nom OCT 2 6 1955 + ATF.S Its, oil Orvoamno, INC. 529 Cordom St lackorages kjzvpi- Q2100' w1tv Mhn bit and reamer, iov ae r-,-eno A drill POO to 1915% spotts-J, ramin, Nog, 75 racks, in place Adjast 29th*' W fill to 18CO'. FU3. Pan in SW" bit aM Teavar, found top; 4nMl aU ISLO1, heid 30,00s yc�rds weight, at P,X. Movet cement up tu rnn In tole,J P.M. Ran 7", '2-round/opsing, 18071 an hook, landed at buttom 12j, perforated with four 1-j" Motu per foot, torchcut, approximewyly 100 mash,' balket at SSW, nVOMS bar for UK= plug at 15781. WPM& with 4g, pack6, fj,,V,e t, f,11 Q jhQ f alleMe casing at 6502, nzFT UUMrUction aerenc, Un - Mated, Olsplaued with 07 Lbla, mud, usfnZ top and "t"O Ml& MmOM in WFOO 1-30 A.M. September 1. Shut " "IM; Mzsure Ot M to 3UO p,s,j. cr OaVla, druppong to rerc by 7-3c a. M, CERTIFICATE: I, the undersigned, state that I am the President of the AnChOr1kp GAS & 171 i D®Ye, Inc. (company), and that I am authorized by said company to make this report; and that this report W,,as pre• pared under my supervision and direction and that the fVtf ated therein are true, comet nd c plete to flit; best of frit=kho*Te"dge 7, / / /'I n r r 11 r Signature orge A. Tucker, President ( , . of V w'_< n.0 _hl"CrnAs . Alaska Oil and Gas Conservation Commission Well .Completion or Recompletion Report and Wep Log Fordo, No. P-7 Authorized by, Order No. I 6-tive ®dtoba r ;1, 1958 WELL COMPL ION OR RECOMPLETION REPORT AN6 WELL LOG DESIGNATE TYPE OF COMPLETION: New © Work- ❑ Plug Same Different well Over Deepen ❑ Back ❑ Reservoir nt ❑ Reservoir ❑ Oil ❑ Gas ❑ Dry DESCRIPTION OF WELL AND LEASE — -- Operator Address Anchorage Gas & Oil Development, Inc. 3d East Second Ave., Iachorafge, __ Lease Name Alaska I Well Number Field & Reservoir Anchorage Gas & Oil Development, Inc. # I 1 Houston, Alaska Locstion'110 S T 2_10' tE fro►+, t C NW corner o Se20 .c Sec.—TWP-Range or Block &Survey NE Corner of hW Corner of Section 20, Township 18 North West. _ Permit number I Date Issued Previous Third Division I permit number Date Issued —County— —I None Date spudded Date total depth reeched Date completed, ready to I tion Elevation of casing Jae, 1954 RT or Gr.) Augast, 1956 I Drodu�_apended I hd. flange _�jKB, —__-I feet Tojtal depth I P. B. T. D. I Single, dual or triple completion? J If this Is a dual or triple comDleHon, 40 Fte I � ' I I furnish separate report for eaich Com- _ �— —11 _ _ _ pletion. Producing interval (s) for this completion j Rotary tools used (interval) Cable tools used None i � (interval) Full Time None this well directionally drilled? Was _ W'as directfonai survey made? Was copy of directional survey Date filed No filed? N/A I I Type of electrical or other logs run (check logs filed with the commisglon) Date filed ✓S.P.V. and Microlo I May Z 1 60 CASING RECORD -- Casing (report all strings set in well—conductor, surface, Intermediate, producing, etc.) Purpose Size hole drilled Size casing set Weight (lb./ft.) Depth set i Sacks cement I Amt, pulled _ Surface 1 � � I 10 3 4� On Conductor 7« _ 2 650 1,800 _iSQ Neva None j TUBING RECORD _at LINER RECORD Size Depth set I Packer set Size Top Bottom Sacks cement Screen (ft.) ia. ft. ft. In. ft. I ft. PERFORATION RECORD ACID, SHOT, FRACTURE, CEMENT SQUEEZE RECORD Number Der ft Size &type Depth Interval Am't. & kind of material used Depth Interval __�� - Ib82-1605 — P1 jigged at 1 800 f t , INITIAL. PROUJKAI Date of first production Producing method (indicate if flowing, gas lift or pumping—if Dumping, show size & t YDe of pump:) None I N/A own Date of feetI Hrs. tested i Choke size I Oil prod. during test Gas pro d testWater prod. during test Oil gravity '< bbls. MCF ( bbls. • API (Corr) Tubing pressure j Casing pressure I Cal'ted rate of Pro - I s: duction Water` Gas—oil r fio 24 hrs. as per . '' r i C bbls. Disposition of gas (state whether vented, used for fuel or sold): CERTIFICATE: I, the undersigned, state that I am the President of the AnChOr1kp GAS & 171 i D®Ye, Inc. (company), and that I am authorized by said company to make this report; and that this report W,,as pre• pared under my supervision and direction and that the fVtf ated therein are true, comet nd c plete to flit; best of frit=kho*Te"dge 7, / / /'I n r r 11 r Signature orge A. Tucker, President ( , . of V w'_< n.0 _hl"CrnAs . Alaska Oil and Gas Conservation Commission Well .Completion or Recompletion Report and Wep Log Fordo, No. P-7 Authorized by, Order No. I 6-tive ®dtoba r ;1, 1958 I'll \C 14'Ci.[ ACY E�cl-AS iii'. OIL 2l�J l .` Ali- - iz e Sid Wa," "£+re D-Scr±ptioto 8r �+ 6 , 2' . r sc. t ra � San 3,: fit. � acoi lWated, 1 ted. f .� a(�rl T ort odor, 70 ft u( r. o'r cut. } x. r ; b Li :rC ailCt as . ?N; T�1Iy Sw'135i1 od<�i: �4�. .7F 3i111r4 i`T i.lt�iu1_ r /lJ L � :1v c ``72i�--. JV Stu.i.�l <.i sf1J .�t, G�-bo-,; C, fl Sv"' .tel sh odor. k 795 ,tel � .� rec. 1, ut' sand, .I .. _a;7_ ill�:`..l"1X, TT�,wLa� -. -G' �•'` m y , 1156 i....i %i .q tt ir'i -eG T� �v.'�.:A\' ,.. '..12.��?:�`::. f xT'..r�l (.tC�,r.._y ?:.I:i I. :�Ti. l f3. n.i. "4' \. StEI :�..t.. �� {i _4. {�i ,�E'73'�' 121 64 ? --1/4' r,_._ . coal. brittle, s':lir, y fa aur: -s, cl nu, =t, blac-k, 1353 c z/ t" 1 c'7l'i ; ± )^: w 1L1"± sttla1+:'hblu5 $r'1!l;F,' SliTV matrix, light gray, �> �,. u � whit r � r ,1: , . :_- ,. i±ii ?t . ,S�'SI✓�iE'lci43 odor, f) C.'Y ^_. 1412 }_ f 1465 'i icf `uc3;:iCi, it "("..1, ii 3n, �%`Jt3 y �e!)•$:Ft? iil;?C , bi:�i%, Fti %it odor no Ut i ("I". 14116 rF : _-ray,, sand, soft, n.�-gid. ora n�,d, v -,ry pu-urly sorted, s ltv ;matrix, ligi1jr, nraV <YP_ ? i.I;ic S�' __tlsh odor. i ._ ry _i h tt: c d ,.1 1 li _ i%v!!ttC fluor, no cut. 1,526 /8 r C silt' 1' F l`_, � ;Y j; j' r:� �.7 � ` 4 i d �7 .. .. ``_= _ - j 7,-,_ i7:.. �.e ic17-!� �il , i�?li,.a;. �.74'', ��, cdc� ��' fluor i �lr r 1, as a - V' &. +r}1,_l,, L',!3 i S:' ', brownisli no :OutC}Y' ! ri gra,.- ..c ,. ,.:`. -li•.!_ r. t , Wit".. nii sb �1.attj. ,lx cla; lOft1CS 1(;l: s �1.., 5d,1 t,tJ Sr SJ Ci': Ci, ii7�%1il up to i1 _ 'y r r �h+t . , i'it} jC?'?" i l" i:iit, Sj7Lc :�.I£ Q _itllE Wl1?tc� 11110ra ?T?:+.1C"fal<! 1632 p,?,Uble, mostly poori,, Sui ;). Sa-id as above, coal co- , lignitic, dill black, i)` odc.)r. cif, s3- fluo 16915 1 rays&nd, Esof%. med. grained, l"�i , poorly' sort�'ed, .L -SW, 1('itii gieepis1a gr" oao t or 110r. 1734 i 1/ 3 _ r g -,,---ay saml', conglomerate as above, -faint bila Ci�'�3 ?�� Stii, <'.t?S't7 odor, .AQ cut" 17 59 T,( . 1/67 1 - -ra1` .sa'rid as la::st, ab v.+ , slights fine' cia:_A r{.lu.irl�i., t.ilri. ^�,:J '?i.!ate'b oE3ot-, ; � i;2 `�1i::.F ??:? a _r�l f our ::ax ,fie} , no cut or fluor. y? a 1707 ii' fractured gLre_e-cl sli pee. b.l iln :l-yev, sa , d`y matrt s no 0{�f3�;= tl ; rF,i-: . mit and flu -rssce:_tc- as ahov,.=_ -7, Anchorage Gas, & I., Si dewall Cores description Pag�-2 3071 3077 36-86 Broken cuttings in thin nviu. (cuttings of,greenish lim-estcTle.) I-1/4".rec . S,--,ndstone. gray, soft, pcissiU -1y congi.,irnerase, with sba..'e.fragnients, tight, ,301-newhat brokc-a, quartz and clay material, Very few g -tains of Clark -a-rine-rals, Some pebbles. No --lj-, or fluorescence. -eC. Cor jg'ermF .ate, 0, j1111 pc _(-rl ed Ay ,.;rted quartz sand, no odor or cw fairiv strong blue white DL!orescence, (Trinra-D 3097 1-1/8" rec. Gray sand, firm, medium greenish ti dark gray, fine v&,,y POO I Tly soIT.Ied with fine si-jr-v Triat-t-ix, rlc, cut or Duo:rescence. 3102 o fluorescence, Sa rid, 41 -in mecliuin dark greenish gray, fine ery) silty matrix. In fi C. 3112 L-ec Sand as above wi-h some coarse quar?-:z grains. No odor, cut or fluoresce ce ri 3120 rec, Ciong',omeratc, very fine green ro gray -matrix with pebbles of sand, C41cite nitine.ral fluote-scence in spots. Marrix non-flui-,rescent, no cut nor odor. 3129 V r --c. Sand, firm, dark gray to whitish, very fine, tight, greenish, noodbr, fluorescence I One streak wi-j:h abundant dark minerals. 3139 1" rec. Gray sand, fairly ftr- sorted, very tight, dark gray with whitil sh .m, very poorly so , sti eaks, limy inatrix, no -quoresce-nce, nor cut. Quicklydissipatingswelet gas odor. 3146 1" rec. Sand, fin -n, v�ryl fine, clayey matrix, Tinedium dark gray, -ven.7 tiglit. no 'fluorescen cc. odor or cut. *4O_ G44, Oil, hOUattA#,. page ## noodor or cut, fairly attune whits �» zo o'» Gra; aand,, firm, medium�-end o ray fine ,_v4ry 3ort4d within it x., m odor, out �poorly O any above, w.i ,,h o , gy roe. og e aviary tintr gretp to gray with ' t Dual rlu a ire i �» edor, rivarosoonot or out. t ;. ' t 4 a . rid i 314* ' _1'" 3an , firm, very rin4> clay; ti 's W#d= Oark gray'. Very i . # o fluor azoo . r odor off' .Cut DECEIVED N 1960 Oil & Gas Section Division of Manes and Misai�t� i i i i i Alas ] ?Qpt. of Ntura e ANCHORAGE GAS AND 011, DEVROPMENT, JvC. 529 Cordova St Anchorage, AlasIM, COMPLETION DETAIL ------- ROSIETA 12LB Aug. 29 Cleaned out to 21000 with 8-3/4" bit and reamer. Ran open-end 3-1 drill pipe to 19151, spotted cement plug, 75 sacks, In place 4 AM. August 29th, calculated to fill to 18000. Aug. 30 Pan in with " 8-3/4" bit and reamvir,, found top; of cotnent at V-31001., he.1d 30.oO(',,,',) pounds weight., at 5 P. M. ,Aug. 31. Dw,!, sump for water storage, moved cement to loontion, rigged up to run casing. Started casing in hole, 5 P.M. thread Ran 7". 23# J-55 LTC 8-round/casing, 18071. on hook, landed at 16051, bottom 1231 perforated with four I-0 slots per foot, torch out, approximately 100 mesh, basket at 16801, cross bar for bottom plug at 16781. Cemented with 00 sacks, figured to fill to shoe of surface casing at 650', neat construction cement., un- treated, displaced with 67 bbla, mud, using top and bottom plugs; cement in place 1-30 A.M. September 1. Mut in casing; pressure at end of cementing,, 300 P.B.I. on casing, dropping to zero by 7-30 a. m. DeviDlopment Cc Rosettes iia. 2 Permit Mane Loc 710 DFU'L i 2150# Wit,, Sec 20, T181, tt SS rs cmVsny rig Spud: { o Plugs: None -54 COM2td= DSI 6-30»59 TD Eo2' t3' CBS: 10 3/4'" @ 6501 W/150 sax a" @ 2800s ,/400 .. M. T80MpS®y Log, hole 1V Englewood a�� '4th "'aye ,, �lofadp, '®gj(0) 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. Elevation: Collar of hole - 303 feet. Depth From- To- Thickness Ft. in. Ft. in. Material Ft. in. Remarks 0 0 11 0 Clay overburden 11 0 Thin glacial cover previously stripped. 11 0 22 9 Interbedded fine sandstone and silty claystone 11 9 22 9 23 1 Ironstone 0 4 23 1 27 3 Interlaminated fine sandstone, siltstone and silty claystone 4 2 Roof, "Pit" bed. 27 3 27 4" Bone 0 12 27 42 30 0-3/4 COAL, dull with thin anthraxylon bands and lenses 2 8u Core loss, 4 in. 30 0-3/4 30 3 Bone 0 2u 30 3 30 9 Shale, dark gray, coaly streaks 0 6 30 9 31 6 Claystone, dark gray, coaly 0 9 Core loss, 7 in. 31 6 31 9 Shale, dark gray, carbonaceous 0 3 31 9 32 2. COAL, du:l, thin anthraxylon lenses 0 51 32 22 32 4 Shale, dark gray; carbonaceous 0 12 32 4 33 1 Claystone, coaly 0 9 33 1 35 02 COAL, dull with thin anthraxylon streaks and lenses 1 111—�� 35 02 35 3 Bone, broken 0 22 Core loss, 1 in. 35 3 35 8 Bone 0 5 35 8 38 0 Claystone, few coaly streaks 2 4 Floor, "Pit" bed. 38 0 39 4 Claystone, coaly 1 4 39 4 43 7 Claystone 4 3 43 7 46 8 Claystone, silty street s 3 1 46 8 47 0 Ironstone 0 4 47 0 49 2 Claystone 2 2 49 2 52 2 Claystone, silty streaks 3 0 52 2 52 5 Ironstone, concretionary 0 3 52 5 53 3 Claystone, silty 0 10 53 3 53 8 Bone 0 5 53 8 75 2 Claystone, silty 21 6 Bedding is almost 75 2 77 2 Sandstone, medium, grading into horizontal, with upper and lower strata 2 0 infrequent cross- 77 2 80 10 Claystone, silty 3 8 bedding. 80 10 81 8 Sandstone, silty 0 10 81 8 82 1 Claystone, silty 0 5 82 1 86 2 Sandstone, silty 4 1 86 2 86 5 Claystone, silty 0 3 86 5 87 9 Sandstone, silty 1 4 87 9 90 5 Claystone 2 8 90 5 92 1 Claystone, silty, with sandy streaks and coal fragments 1 8 Depth From- To - Ft. in. Ft. in. 92 1 99 6 99 6 log 6 109 6 242 0 242 o 243 9 243 9 258 9 258 9 296 9 296 9 300 5 300 5 302 6 302 6 312 8 312 8 322 11 323 7 332 2 333 10 334 5 334 9 335 2 336 0 341 2 341 9 342 3 345 2 351 5 353 0 353 6 372 0 376 9 3e2 U 393 7 332 2 333 10 334 5 334 9 335 2 336 o 341 2 3�+1 9 342 3 345 2 351 5 353 0 353 6 372 0 376 9 387 6 387 6 387 7 Log, hole 1 (Cont.) Thickness Material Ft. in. Remarks Claystone, silty, with occasional coaly fragments 7 Sandstone, clayey matrix 10 Sandstone, soft, medium to fine, containing multiple beds of hard pebbles (quartz, chert, rhyolite, felsite,'basalt) and occasional coal fragments 132 Claystone, bone streaks 1 Claystone, silty 15 Interbedded fine sandstone, siltstone and claystone with occasional coaly streaks 38 Claystone, coaly, with many bright coal bands 3 Claystone, coaly, with few bright coal bands up to 1 in. thick 2 Interbedded claystone and siltstone, with occasional coaly fragments 10 Siltstone, sandy streaks 10 Claystone, coaly 0 Interbedded siltstone and 5 0 Core loss 2 ft. 5 in. 6 Core loss 111 ft. 9 0 Core loss 2 ft. 0 in. 0 Core loss 1 ft. 0 in. 8 Core loss 2 in. fine sandstone 8 7 Interbedded siltstone and claystone 1 8 Siltstone 0 7 Shale, soft, dark 0 4 Claystone 0 5 Shale, soft, dark, occasional coal fragments 0 10 Interbedded siltstone and fine sandstone 5 2 Sandstone, soft 0 7 Interbedded siltstone and fine sandstone 0 6 Sandstone, soft 2 11 Interbedded siltstone and claystone 6 3 Claystone, soft, dark 1 7 Siltstone 0 6 Interbedded claystone, siltstone and fine sandstone 18 6 Sandstone, soft 4 9 Interbedded claystone and shale, silty streaks 10 9 COAL, hard, bright, with conchoidal fracture 0 1 Core loss 6 in. Log, hole 1 (Cont.) Depth From- To- Thickness Ft. in. Ft. in. Material Ft. in. Remarks 387 7 388 8 Claystone, coaly 1 1 388 8 393 8 Claystone, 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 Sandstone, medium -fine 1 3 403 4 435 10 Sandstone, medium fine, with soft layers and occasional coaly streaks 32 6 435 10 453 4 Sandstone, soft, with few pebble bands 17 6 Core loss 16 ft. 2 in. 453 4 456 4 Sandstone, soft, medium -fine 3 0 456 4 471 l Sandstone, porous, poorly cemented 14 9 Core loss 8 ft. 9 in. Gas flow accompanied by brackish water - static pressure in excess of 15 lbs. 471 1 481 7 Sandstone, alternating soft per sq. in. and dense, pebble bands - bottom of hole in hard, fine sandstone 10 6 Bedding remains al- most horizontal - little distortion evident. Log, hole 2 Location: 710 feet S. and 2,150 feet E. of NW. eorner Sec. 20, T. 16 N., R. 3 W., Seward Meridian, Houston, Alaska. Elevation: Collar of hole - 330 feet. Depth From-- To- Thickness Ft. in. Ft. in. Material Ft. n Remarks 0 0 19 0 Overburden, soil and gravel 19 0 19 0 21 6 Sandstone, medium -coarse, with iron stains 2 6 21 6 21 U Shale, carbonaceous 0 5 21 11 33 6 Interbedded silty claystone and siltstone 11 7 33 6 80 0 Sandstone, soft, occasional pebble bands and coaly streaks 46 6 Bedding where seen 80 0 105 2 Claystone, occasional iron- stone nodules, coal fragments 9 almost horizontal. 25 2 Depth From- To - Ft. in. Ft. in. 105 2 lo6 o lo6 o 115 9 115 9 116 3 116 3 126 2 126 2 129 0 129 0 173 3 1?5 1 176 7 181 9 182 3 183 7 184 9 186 4 186 11 2o4 5 205 2 241 2 244 2 26o 9 310 3 313 4 320 9 34o 6 342 11 372 7 173 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 26o 9 310 3 313 4 320 9 34o 6 342 11 372 7 376 to 376 10 383 7 Log, hole 2 (Cont.) Material Siltstone, dense Claystone Siltstone, dense Claystone Claystone, coaly, frequent coal bands Interbedded clwystone, 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, coal) COAL, dull with bony streaks Shale, dark, coal streaks Claystone Claystone, coal streaks Claystone. Filtstone bands and very fine sandstone bands Shale, dark, with coal streaks Interbedded claystone, siltstone and very Fine sandstone Sandstone, soft Claystone, silty vTith 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 0 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 0 7 17 6 0 9 36 o 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 Depth From- To - Ft. in. Ft. in. 383 7 399 0 399 0 412 4 412 4 432 22 432 22 435 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 435 4 435 9 COAL 435 9 435 102 Siltstone 435 102 436 0-3/4 Bone 436 0-3/4437 11 COAL 437 11 437 438 6� Bone 437 6i 02 COAL 438 o2 438 3 Bone 438 3 440 2 Bone with coal streaks 440 2 440 8 Bone 44o 8 441 o COAL 441 0 441 3 Bone 441 3 445 7 Claystone, coal streaks 445 7 461 3 Interbedded claystone, siltstone and very fine sandstone 461 3 461 9 Sandstone 461 9 461 11 Claystone 461 11 462 1 Sandstone, soft 462 1 462 11 Claystone 462 11 463 8 Claystone, coaly 463 8 477 0 Claystone, occasional sandy streaks 477 0 484 0 Sandstone, cross -bedded, fine to medium, few clay streaks 484 0 508 1 Claystone to silty claystone 5o8 1 509 10 Sandstone, soft 509 10 511 5 Claystone 511 5 511 8 Claystone, coaly 511 8 533 0 Claystone and fine sandstone, interbedded and cross -bedded 533 0 533 8 COAL, bony 533 8 543 0 Interbedded claystone and fine sandstone 543 0 545 3 Sandstone, claystone inclusions Thickness Ft. in. Remarks 15 5 13 4 Core loss 2 ft. 0 in. 19 102 3 12 Roof of bed corres- ponding to log, hole 1, 296 ft. 9 in. to 302 ft. 6 in. 0 5 0 1? 0 2-4 1 0-3/4 0 5 o 6 0 22 1 11 0 6 o 4 0 3 4 4 Floor 15 8 o 6 0 2 0 2 0 10 0 9 13 4 Bedding nearly flat. 7 0 24 1 1 9 1 7 0 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.8 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.11 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. Static 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, 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 (Cont.) Depth From- To - Ft. in. Ft. in. Material 832 9 837 0 Sandstone, soft, with claystone and coaly streaks 837 0 840 9 Claystone, sandy and coaly streaks 840 9 843 3 Claystone, coaly, with many bright coal bands 843 3 847 10 Sandstone, soft, with occasional claystone streaks 847 10 848 3 Claystone 848 3 850 8 Claystone, dark, with bright coal streaks 85o 8 876 o Interbedded claystone and siltstone 876 0 876 6 Sandstone, cross -bedded, with streaks of iron carbonate 876 6 88o 8 Claystone, dark, with occasional coal streaks 880 8 895 8 Interbedded claystone and silty claystone 895 8 897 10 Sandstone, fine, dense 897 10 903 8 Interbedded claystone and siltstone 903 8 906 1 Claystone, coaly 906 1 913 6 Interbedded claystone, siltstone and fine sandstone 913 6 917 8 Claystone, coaly, with bright coal streaks 917 8 937 7 Interbedded claystone and siltstone, with occasional ironstone concretions 937 7 943 7 Claystone, coaly, with many bright coal bands and streaks 943 7 979 0 Interbedded claystone, silt - stone and fine sandstone, with occasional ironstone concretions Thickness Ft. in. 4 3 3 9 2 6 4 7 0 5 2 5 25 4 o 6 4 2 15 0 2 2 5 to 2 5 7 5 4 2 19 11 6 o Remarks 35 5 Bedding of all above strata varies from 0 to 15 degrees 979 0 985 0 Sandstone 6 o 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 o 8 988 1 988 6 Claystone, coaly 0 5 Depth From- To - Ft. in. Ft. in. 988 6 1013 8 1013 8 1o44 6 1044 6 1072 0 1072 0 1097 1 1097 1 1105 10 llo5 10 11o6 2 llo6 2 1112 3 1112 3 1142 0 Log, hole 2 (Cont.) Material Interbedded claystone and siltstone, with 3 ft. zone of ironstone concretions at 994 ft. Sandstone, fine to medium, occasional claystone streaks Sandstone with frequent conglomerate lenses of indeterminate thickness Interbedded claystone and silty claystone Claystone, dark, with frequent bright coal streaks and scattered sandstone concretions Claystone Interbedded claystone, siltstone and fine sandstone Sandstone, occasional claystone streaks Log, hole 3 Thickness Ft. in. 25 2 30 10 Remarks 27 6 Core mangled, no loss. 25 1 8 9 o 4 6 1 29 9 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. Depth From- To- Thickness Ft. in. Ft. in. 0 0 43 6 43 6 48 6 48 6 50 5 51 11 53 2 53 5 53 7 55 0 58 7 6o 4 50 5 51 11 53 2 53 5 53 7 55 0 58 7 6o 4 87 6 Material Overburd-,�n, 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, with occasional coaly streaks COAL, bony Interbedded cla.TTstone, silty claystone and siltstone Ft. in. 43 6 Remarks 5 o Core loss 3 ft. 4 in. 1 11 Core loss 9 in. 1 6 Core loss 1 ft. 2 in. 1 3 0 3 0 2 1 5 3 7 1 9 27 2 Log, hole 3 (Cont.) Depth From- To - Ft. in. Ft. in. Material 87 6 87 9 Sandstone 87 9 90 10 Claystone 90 10 96 11 Sandstone, porous, fine to medium, frequent clay bands 96 11 97 6 Sandstone, dense, fine 97 6 103 0 Claystone, silty, grading down to siltstone 103 0 103 11 COAL, bony 103 11 122 4 Interbedded claystone and silty claystone, with occasional sandy streaks 122 4 123 0 Shale, carbonaceous 123 0 125 2 Claystone 125 2 126 0 Claystone, coaly 126 0 126 1 Claystone 126 1 126 6 Claystone, coaly 126 6 127 0 Claystone 127 0 127 11 Claystone, coa.ly 127 11 133 5 Claystone, dark, with frequent coaly streaks 133 5 142 10 Claystone to silty claystone, occasional coaly fragments 142 10 145 8 Interbedded coaly claystone and carbonaceous shale 145 8 177 3 Interbedded claystone, silty claystone and very fine sandstone 177 3 181 8 Interbedded claystone and soft porous sandstone 181 8 182 6 Claystone, coaly 182 6 196 1 Claystone, frequent silty and coaly streaks 196 1 199 4 Claystone, coaly 199 4 217 6 Claystone, occasional silty streaks 217 6 224 0 Sandstone, fine 224 0 233 4 Claystone 233 4 236 9 Claystone, coaly 236 9 243 0 Claystone, occasional thin coaly streaks 243 0 244 0 COAL, bony 244 0 244 3 Shale, carbonaceous 244 3 256 1 Claystone, occasional coaly fragments and ironstone nodules 256 1 258 8 Claystone, coaly 258 8 260 4 Shale, dark, with few thin coaly streaks Thickness Ft. in. 0 3 3 1 6 1 0 7 5 6 0 11 18 5 o 8 2 2 0 10 0 1 0 5 o 6 0 11 5 6 9 5 2 10 Remarks 31 7 4 5 Core loss 1 ft. 0 10 13 7 3 3 18 2 6 6 9 4 3 5 6 3 1 0 0 3 11 10 2 7 1 8 Depth From- To - Ft. in. Ft. in. 26o 4 333 1 333 1 337 0 337 0 386 o 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 0 to 15 degrees, with moderate cross - bedding. Regular bedding seldom exceeds 5 degrees. P204mul!;S A)CCWR&.;I ZAS AND OIL I)EVEL-01MENT CO'.1TANY 31AXX IK,,USTON, AMEA, &LASKN- io "'Iltroduc L iw 4 Anchcrago Gas and CALL Develo?m&nt Ccagany., t=-' holds a j3,ock G' oil and Z�ss j*&nuc,, arcuad iiotwtaz cLation on the Atask,% Rzj�, j:.omprjujn3 acra,; in 17 to 19 North, X.,nigeb 3 ar-d 4 �*'Wcrd lloridia-:J, AIMAirX. Th4r- 6"lit& ab'GUt znd Ln adlftlo" LO ChQ rAILWAY it fib by ar. roao from Pzalmee.0r, 4 Vail(lic tc the "Pi. Ab,mtt 16V5,-�(;Q aeree IYI Lh-2 .�C'Utharll J,Cgt Ci thT, 'Z-ZOCk "...orzatiLUCO PQrL of thn. 4:,OOC ccrr�4 of the B1,*"-tcm Unit Araa. .4+ 4 ,licatico has jcn "doa to-46' Lh* U--I*CiWti0n- of -thi6 arc,'% and a.kw OL-LILne Lwas bec-cs 'ej+-.0vo'i 0Y th. S. Survey, 16%ac Ie6al werk cm it 'Itas, nVt be-m -jwo tout V'311z' Lbe cck-gpary's �'Caez-tg No. I cmd Razetta A b1m, , to deptho of 44A9 aad 6\10167 MV too Alt�,C,%!c 1-110-7 hc;I-P0 DO� Y*t befit' c ', 1* t 05 obta.,Ined in thest wvllmr 'ng. The rots Aforth th's results by .'na geologicrd w1w Qvsilabla. And 04.1clroes prc-q,ozals fox fUrLhar exploratics anJ dav�Iopr-r-at- 1111lial GAW10gist - 1 - Now a i ur'� �' ano'nn't. lt'�e Wiling of the Knownta WON hw nMed ouct to the apparent valm* of 0he AwAstc'�'P Os jYj m oil nod gas Sold; Q 6 YC0'Km4&V1 mWy. it ip only ructly Low a doclogic temstayn is to timpis old well W&W, old OQ ?rMvpvCtVV M lecay, ML a Vele V NOW uWar the Watim CA the �iwy call drillea in a given arse Nem Heids are ww& jminj tedzy ko %'-'l dove lo�rinvm" has gam on for dea0m, uic. i�- �kz'.-A IA140 numbery & wSuccessful wells wavt Men OilleV it to mly Vzough Womoyht =17110 cc aby Kon Quo WaStd nbal- jiscoverign *rm Melly :ma"le. 'alvK-t the iownt's, -'Otirg" �iLar.�Gd POWKY way Move of w0har toe nshourface iarmy tland or imc Cab- 4ur?xa. atzmawn, and fe"my we yownim �)� ovk7-face wtrmcLtme 01 tht wZOa- NOW it WY hUS" *00all 1154V ISM E. nnVOLO" 510CA is in S jeologic province napahl, OV proimclqn mth gx% AO` oil, a0d tv M w a l e Wwwathan an moist to nort & Prolow, Q Una aritlim-, 'Pw mauntain zorum fault %me been dewlwiwed % Raps"m Pa. 3, CCU apparaully cut it w admu; 170 Set Mv MIL my p0"Vide ClQzure', armaruze In the Lvntly wrtmucat dipping beds at Cho Nouatom COO AcHns abovo a oepch of KOM 2230 fems eh Cxrzt"" i. e z: e C i osmr'�:' txta- Y le, s eknowd amcg OU the mumcm cob! "em OL ova wait Sud & Zoe strip 00M. - i - " In bolo we mt it, m " b*Uw 3M fame is so. 3 my be e1oI at their spear ands mWo r the mesm sity at the be" of the Dowtom o al series o or wader the Castle NowntaAW hilt%. Ie ovembed ware of SUM now fault is the Sl wl, awe bsibtle comabieee to srhotha r possible oil and gas sosaEwit. permeable oae &* is save ail difilromt me"$ Uwe u4wd to as moustan so" 2,000 i'set. Of tboaw$ seoAs in meem 0. 1 betwom 1 U70 l-T :A 9 aai tbose its So. 3 batrom 1*0 and 1970 feet and botwcj A L12S feet oar an dw oleawle Ift to bo eqpable of s i preIln of Wis. 'i'oo* ed by !wile- pwiaa"Aft dwWAO Imes in tl�sy 7141dad atlrroet so t &A the Tritatoo opieien this is probably *w to the small" ot6wt of the - -,' drillio0 surd abionh gtcrI agais>et Hods for am yeno beavesm the time Choy torte dw:=" tooted. Sw early sewsoeeaw toot ewe cSwift drilltft me Is me. 3 tsw lM to 11"S iset. it s In alp stao" flown of 0w mbl eb lasted Corr eear " 11In, e iwtLI the perforations in the tell pipe plus"+. it is tip that tbz throo somas L*wd obwo hem riot bom fly e�wlaahtvd. Sod ;bnt the pseelbUttles they wepr000et w 1A be aeoliici aeat to wwrent .-"' 'PI . a isl Yximemorm at better ; io0"I~. o � s �4 r.IW 04V t-A A xftAl 43Uk ;j- lcbt r; Oi f- kin. Nc;'t'Vkv J4 AV, itvi �A Ac 0 %XAVA a t. r1p iclwlu tO #"jh i End Vo a a 00 R WY 0 kv 1 0 GO dy 11 . o t. -no or Awro, jp it, Wa RV 3 W WL AM SMOdS 10001 W Qa i I - hbor , on A ChW',a ', WS 10 WK UY U Mnd W I V 1W040 It NOT WCOW Kink fividec SS W oil ana ShoWnin Lo A Mg, v,st man ajn- he axpeaLve no psevLde valwnbla 100W�Jcal vv!nLsv; to 71, by-"nurn wS thest beds An! the chxr,,ccwr And .'Unrain in,!:. A hucaLWU a short Macaws zu= or w, 7 ca i-dicnea by pro! of W Semew urface svoz�w wromra; of bedrnck in AV 9DWAM RTMN wy lio!LW W ",.-tilt` - scprk nr0ov An Wiay igh0, U!400 Ox1aOfka dniv� Cho PTMEWAS 6j Zhu no 04, BOUyLso c-rjj c.. 711y are all In the Yount= sow'-, ow lot UIV of agaut nevon rW LWHIMY TLC WA-MaHU.- tr'zu ki cop a, by Sureau ano Famr, an" tad arveral son and "rilled tv 11916 Ditch Sam at wad and dipmetar, Bgjcm thil--, UW "Tod logged by Mrs. Wose Ryan, 10lag "le 907 On Q 19§0 QA� -n� cleaned anc and logged sets" lot! Nor by Qo- '-'aLems. 71C to As 0- 0 not a emed to 1300 1 1679 and LOW Kno anyo &-03,w, ry a 'i�tvtmelmod Non shl- V 00 Min Kn 2 men a shali"n Hose to so. 760 Anal, to p.mAo �Lmmrwlc loggsag OV Cho 11-1 In No. 1 aesecta W 3 ms Imsted 3069 is,; Wet poryhyv�z cowspy it drund to im zewn to Am 195K ssnplak unr# aeved, a aft e" ocoun eqns hK drilling vu* 061arved zKoughout. Ry"- %blumb*r4er alactria Ing, Wralog, Kpontm, and SW-Vdli tmoptea mra all tak*n W thig WW Whmp Ic roanbre W59 Net, 04 W&I vam finsli7 neW to 295' 'Feet'- an-J wMeram Inttevalz 'Wmero pereorv'ed 'Ond The g6vinsical rmord if bueb WSW is exc*ptimally com VW'� drilidd in an isolatedwityam, anj *kusa* tc rcatiag any' &0XVIOVS, Even I% Q va Vnrpxb1* GhT,+t t64* '#*Lis pradunhOw eaze"o V^"rt either dtAltd OFF Wousume of M Km ImPat b0tween drilling and testing, pa n5jn� ,we ,t Quango pi Und,vats caring tod Lank 09 te-eit d-'Ar3ag -JhrUli'v". - I - Wvl� 610 V47* mezzow the tolloving inic'matlay b4j boo IDIOM, Onva W! - Hounen are., are: the anni WO _010the dixth, wan cat tho Birch Creek The Musten coal 4OZI40 wanatAtd of akerrn%cia' hA 16 and wanjszony with Oweratonal coal rexn_ it is ProbabLy upper KOCOVIa In age. W TZtenS flom the gv�;Tnn w 10b 011 in Wetre No. 1, and team WO suMaev to in RMSCM No. W Fram Ma fift"On yer,Rpt of this 4'tx.3Wly lu five to fifla-ve WC aWwlevs, bw& vL_I;h up to 16 feet Q thin kzmax, Analysis of aid* -Wall ZOETIVn,. POSCMins rangiRg Kna to and avara8lhg 25.2lo An& The sands an6 ponrI7 agreed mad COUL"In clay, WhOn Milho Caw. Ch.4 to Owe tAPdSvZd W cWtv to the wall Wyn by 1001 @xpG&vFe CO tht. "65 satyr 61MMY QW. Yack W ovyzelatisl yy;w,mirm Rowncza No 1 ann NC indwarva that "he nod coal hadA May Inavahst 1001PULax valetta OU 3 art US) AM, Wtv ji,yin; 'jZ_(.A�4, cvf and hend- EL.Me. TV 4-0-i:tovi of thin forma- I,!, are the wishbone fennnnion of tha Hishbonq YA C'nri't. core* to to very Aw in PowrAbAKY. ban anwhyAlv of 00, cavo Stakle y4swev 13Z Porosis; with 10% eM on! e VAra-Vinink light was Much loop!,* AVIV& many Vraywarn Mh gaid fluyrercaac<� WdVa0ve Ur WS, rsom than yaA. viecuric&I rp,ioti"ity of thIG V,,Iriny town ;0 100, OhMSM B pence Cho log caanow Mr, Nitypr*ted in oerns a ace 4 gao, Aaw 2450 aflrxz�t 6040 feet the sentAen &zjj1g6 by Ronown blank 02P, with gone gards%ons. VOIS AtMW curverm. W! with Lhe WA toe wisbKona 00000mewaw nn,& i4hV10 exe thauig,it 00 lower Eocene in IXM. werg from corea Ave tv~10-01,4 tv he the series oil comonly dianovered VQ 6Q Wow n SUUM just Lela" "An" 'M.j;"" �! tbr conglomerate chore art two - "I re"hu"010 qu M wicrolog, 23 feet chlonnass. thi"ney orringuz, at rthe" Ae log hard ca it A to t�!eroxl avexam coca Un tc 22i Qoe/M'. roe Wn 101""S a' " r"Pol" 'a"r, dylkl"S WOW" Obtyr"Sd up, �e3v V, Ind RUG No - AU Alm 6:50 1100 lie oil Penetwozed a cot core woo MaW� AG .4 Ant A S law a f t-o 1 06, HIS&KA" g" Aryd"GRatl 'IX441 Wokolsou AM, b"t 401144 1",- !U;-VVV- so 1855 Ant. RXMFIVS indleake that the wall - tn f , 0- 1- 7palso '7n -X-.l All Paiat to AR RUMPI depth at W59 WS, till vi- Myalog A= a PDXCUZ Interval Mm 3015 to 3133 AVC, �My tb'qry yieldad of 140 C41MI, co, the TAcrrKWt erica h 1,* f eAd w0tho t''__9 of W teht; MEMO K"q "Awntly in ITMI sit% �t 0110C in.ply eazan_ 0SP7 Q E40 T-200. kAUIL, AM K�L� M -GUIM UdgM 5� 50 Y knostan MAUMr&U-. 1z the Gantle WannK =-M, 45 MILMS to Ohl -An, MM USS k n V nNer low-anglo wlvxrnVon!%. le is thnyja Ont the two ROL, nc -n! in �'-_ 'c', '_� ',JM EA�1(,, "' "- 3 end 2000 few, where 0, UqM encountered, and caving A .10 Crum& a cavity and 'C" -0 7wrl21A tag job. The urike or AS fSAC from EOUSM to e& 11 Want Earth 720 ESM Th* Elrv".Staq, coa" Caki'l? tiv- Carthrestarly dip of nbauz 0�01; Oojn7�. W loge of Rosetta No. I aad To. 1 cannot bc nzn"A .0 14 §W "11C IC L W"A' bUt traCing of th"-� CUM -Cox in We mine and Ivbolas ladiecte that W; 4A7 probably Me camtHwarej krw� Ma. I Le 'i'-ob 39 The Czatle way duplicaLe 200 ZU 300 feet of the Mown bads w 1720 Not in No. 3. - 9 - - Ao - W.01 ImAzz ywcWbl,;� ;,i, " Marc say oc 0"FRAVO: yornmA7 AlOw"aw by Omm- a.a01jor hardw famat!"ne, sweLy, M wishumme conglawwrao, Sol AQW10on n06 Iwo the !'Wx-0VPTPwQV' to avcmmla�', o'.A zo'�- theywC W0000A No. A rewhad th" Onk 111"t thic level. sincr !no faalt yrob*07 dips to che north, tag, ` a, C ei,to tenew by carvivi gelcooton of M Wnxcic': a LA pray-oW wall to the JVUSton Psuryu MUMS aa4 Tents re""! in :01 Wd thl Wn"V* Ors Lh* Wt* made ot QCM. lo 0&auc ,e- parmaabw swu Tho ZOE InAcatee rasletivity above is x t way or f ash we L er is wterpretem as. ""je are "Or"Ove Of So ownenAm, clusum. whvre they crn Wiled, jormnacle Yaw. Top rLe4`.LY10 log -b"d of qNsurt.. (Wet La No. 1 109) Ms uejvLy all WON i ave mcc b%wLn, OF aaz in A& Walta Me. and "0. .. ThW MOCLMI -M indPatZS MaL Ina teL hall NOUN cocculn '&b W;-' the """ "If Cy"TWIC ank '"MV A AM scam tent of Ae :% - 11 -- A At Sow N RQAM.".A m). I ft l 30M* . but 100 v'-Jit 1�'wc"'.evr. Vli* 'Ose as welM* the u,s, pureau of A= coca but* sent Vot Am IGO feet away *nd wre flowing aw of jas00 tent Q ther*fare not SCONMARY0, nbw a �011 drillod Sw th."!a 4A'VA 501 "� "'_r or xtgbr :n�c tic COMA. Vrootare in Cho Arad A cocoa, of FM awrMS1 as show by AV MAN wit wacvx it chsoMars *on be Mvpomtd to bo about AD JxV MAW'. Vis WhIVA in Msztta N*- Pocono 100 surinsma ten to fWann Zola thick wbinh sbo-H goa old AwAysis of aide -tell samplea of Mh-am For AMOM ZOSSOMS Matra 30. 1 was pleg'n" no INQ foot, and a CoMhUntlen atring 0i ed 0,SQ, W3I rwV With VC&CCALA=W USX "Mente tvrnm4b ports mc 3675 Var mad was than Nnrleceo Ath watm-, ar""l the S&I Waz owablad dowu through at tha top A Aw "VnEuxaziono MV MAd ;,:)r i""a4 rs-ratured. ?_! filled w1uh 8AA oavoy cr-uva 441=001 A Mims core hole, W alic-Wift'. to 6tan? QT &NUUt wo weens. more Via YaO04 with nak wSLM, USNY AO iYYTQVLn*t1 7"'*'he well out altlb 44a abled Man vKhant wasulF' jj&a_w4jj sawyco at 4he three etxLnj*rs miss purneabilities fzC. 4, ro 91 .111JdArays. 'j%ey havc yMdVd samp- y0har SAO OK Vue aw drillm, nbrowgh M6 sone. 4.evN sajda"I qA,,U by -,_h* w-.WellinLf, cai' zlhr, cl.A yaark-Ly. � c��, mad'.* av�*, ,�a 'cNntum wft�b ho kK*st U"Atw," krom tkb4� driliinr probubly L"t tho�f cvu 4; as thot x4le, - W& of Lho Xlvastkm Merl,"& lbo t:tt-otwe r"0.3* ibit, H jl rr am ruot, paog l sael 'Pi-rolo, &Ild msoiel % "A AITP.W"", SAVA pvrcsa'A,Ica of Aare. c19.41"", ow."I *A rc i's a2l-i itn zge n -w_i E "u. ua A el, 14 Tb* Sid*- jg if" _;�,roet ir: �-4hat 1"-Oew ol age ;5 fa abo-ut 3.) EP-at k,-.f porVUS '"js not covowl. -it. & I I . , nxxanfv,�F, m elocnric .art:-4. wa��Qr Ir, � ,ij,�rf-.MULO,2', tl!* C63ID-1 Alociol.ft_ULA�lw rl�WMVd, 4An'll clAt �7" ho",., llln �hl 7" Win my -�VA ASK Sol lew c 0 lit A a v; W, zh�; Ic FR -RIZI 01 this, �01!% V�w in! amming, -n§ An rnwo n7: �n q wn U-T W 17 , 7" to stop the flmw. A. OPUM On Vi- Va-PAS Vy-, j;yo PT 07- 10010n% wwwo N Ibis Mw 0— masn�VA7 0WO. V ".,7. .,n water drillAwn & �n7 �-s Y- Ac Rm 7 n-0 VO-,,II. ON. 1010 7��O in V.1209 that Vs Oak-, cr-O 'A' � 10- 7000-1776 . wm ?hm LOW 1079 fact -C: 1220- AVS Opt intervals In wo. I V m7MIJ -' -, .;_ti "I to per- M1100- - luc , 79-wwzly d,-- KIM r 97 Q--" W 14. rnsg-w Onc a OCZ0 n no wc V7 640-720' -ind WASS WIP M may mak- no vaICAMOV : nuv7SAV wn� :n c-aw 0", 1030-1070'. This in, At? j�mm 13 2 im" to F no, *beat excallwat at 0, 00�uwnl= OD Y - A 4 - 1-11�14441*.tftlty xg "INN t'a* fowvw tvg*,-, L7*wi-w, 0. "ut: Lo's 33 -F 740k, 16 tc �V.gbmjs� onod w4uk4ift cho, �,ijtlll OA--Qk,#w -set, With low. It* and --fe ia jgG*, i*4 by �oo mwa A"Y-f ftxvc�gtv* Tr fthc� fr*xh..w Or r chat, a lfom-ka, I 'r W!"', this f;bn Y #twg_e, 1P ic* 0454 wwd, frov fn ",tio k� � t, c ,�u,wmy owf, obtar."d pack.,W, ?v ke with 'A ve- "xim All. �j cn, i�k*f took 0, em t a wftowh tivo Oaa& Am °k* Mom ?mff" be pht"O'd uatow *r* x4 VK in A _W ,k4 4s-,- �tf,! umki Su T'bw 0,7 -'I, *vec It, -��q AL g tot x 5 3 40141 AY. nt q� -,of fir. 7AL it for a long time thereafter. It is thought to be the crushed zone of the Castle Mountain fault. It was tested through knife perforations from 1770 to 1950 feet, but only heavy viscous drilling mud was recovered and the perforations soon plugged up. The test is considered inconclusive. 1965-2440'. This interval represents the very hard dense con- glomerate of the Wishbone formation. It was tested by knife -perforating the 7" casing from 2180 to 2280 feet. On swabbing there was no fluid entry of any kind. The interval was then "sand-fracked" with 55 barrels of crude oil and 500 pounds of sand, which was put away into the formation at pressures dropping from 1600 down to 1300 psi, at the rate of one barrel per minute, after breaking the formation down at 2200 psi. The pressure did not dissipate into the formation, and the next morning when the well was swabbed, only about 15 barrels of crude came back. It is concluded from the results of this test that the conglomerate is highly impermeable, and that it is also not strongly fractured, even though very close to the Castle Mountain fault. The interval yielded the core, however, which showed an analysis of 10% porosity with 20% oil satura- tion in spite of zero permeability. It seems very likely that if the fault zone fractures carried salt water at this structural level, the fracking would have opened channels into them. Hence, there is the possibility that this is the level of an oil accumulation, and if the porous sands found below Robin Willis W10 ate aw be -naouatapce -0 chi, 1, they MAy VUR tAAa In onto PNturval. when InQ hwlfg> wnv ire xvil wit M=d to bo MAI Ash Mcnd up to a WPM of 00%. KhAtoon pop orkoioDi warn put in, fact, was :Wn Gn its bal3n Sol! impselattly who rAtq of lAi. y�fjt per 6my, AMP ava"n" down "lad up It an plarma-v- rate or 115 knrrexx per Ay. shc wd a 1AV14 gu1j, ra, W1 than zho intle"A Wev, tc bt dtt'Crib-d' dip* Allad "eu P01, p.j,*Paur* In thl ma4m, 11"na"d at Aar" it 30 =41110 Apt thorn 1, th*k damarib*4 a %ha t00% rat *064 aCter ohs rraWn, Ust W the 2161"ho"W"t In"ry"' ham' 0 vat goesTIVIA resioual in Ann hold from you rrueyl"n 0.1 it, one !"vernal a"! 340! f" wa-V show"m of fo-A'Por WILL pa;, obg4rvo? :irl-y LAP 001109 Of " *V11- Ai—mite 103" at %KAY v" O*r& qrvyleo"Al' A" fault awnz 0100Q, ,-46 was �-R caniag w%c ni-n eluh perforations tVom 2715 to 2985 fe-,%., cot-.onte.d tsro-ao ports st 2712 fropt. TM4 Interval wavi tr-on. 1-wl-oti bd, 2vubbing *41W, �mll down: L.'xo,,A;;h drill p1pe Ming at th'�, to;,, of twba j>org'cratlunso 'zltki t Wl short 1-1,49 test yield*d :salt :,,4tcR- eA �Dzra ratz of oft 5D --*r tt.�q, it Vero 0mr-4ni;Q Qr both 5.1a WtC 01.1" On VaQh a samyl-D frug'ht �t tho ar;,ia1der mr)10 rrcthy nzga;c3jcn rhlg;h ;,,wm 8 ctromg oil Odcr, UA wMich 3!�Aw�e- %ho b?w�7n 109% C" Orm&;� 01.1' odor on thcr-i vw,.n allcvA dryo Tte = mm of ths� rwab burn & t,�b-foct f%Q= 9'Cy- f�v' toa Qiced u-I& t,.�a rlAld, No Ail'reQ *41 %,,ac =t thin ��A "o sliovlm zDoHod twir. pi rc raw frnu 1.1.c fcmat11L;Tt, and that tha Chlolzml".> =,A v1sh- U-DrW f01-2fStIOT12; %.-1Z 03pt-':ae Of pp',-4rvratltn- and comit'--41mvima oil tho Hc;vton t�—atrlct- 1wc3 7 t�nll in 1�5 it t.o -ot,.it down for a p&rS:Dd of zwo voaai, t--(rjjl'.j ware T-T:RAO t:o w1*1. to ulp., JUrrzc�); On bask hold rho ads conatsrntd at praj;reoo1',r-.; do tLaa the) tit 2200 to 2750 fc6t, %he ld "AlCA I 0.11-3"it that the, crew thought %-to iz-iAl ,-,ao e.-.Ang to talon, e-vq-itr ;axe -ap,06 to shut tho blaw-rout. pr.,vvk '-Ad O"As of t4a on jtjy-%,,00 4 r uho mid otrocca In &ho di%,'3.h. M? By n ROGIN W"A-'% 21 0 goal tax ' . a0 r lot m *Mies ISO& .. ate'! �-�°�, <... �. � �� 1. ♦ �� l� ;`,A.: Cam-- r-, �,? :'�► rtllaim�.l� ��'� �'� a+r!® ��tfl►!d With G, .l } ! at awl# 0bl �S11 t 2�l1l� nth ®0 or god v► to werit the g� fat try tr ate ! • !t n%" Goal x me" � ��o ja guts cam. r - arcfood P14 va", of .�t "1 th*ir At Its reyvaSiam make In atowtom WIL.Lis p,'."" j"Tyr,-'4.A V,404.✓ 14 of (1;!)1,3 'U�a VQV* In 04*4t NO act yc= *01smacr*ph x1gNo pr*V0 Usofyj In of A h1guly WWPAW ws*hbopo # n We A Un V U on and Char ou tor of W f0ults W �2 PMAMOM PM10009 SlataP or *pPing Would be AN Vot tino TnT scinxia work. Po r ov �Q so In tho fr*x ea4t of wuston An :Cos � 0 ap C,417" hC100 to ppownwhyuor- VeyIng. par a Sul it prVbWy %ruv, An Sari al waj=07-1-y survey In ohm Chappast ty, K nurvey Wat man be 01 In thla vr*a. It Awt -t 'oed approximp%lon of the 100*Uan of the castle mountain SUMP and MIGht alto rova of Volat In Sanamh0r,'; *.,A 40y"h tthe yetkWIPhiss gn! thQicnvis (?,` th& Houston o wq cc th, worti side of thm fault, partlavinrly ta the =vy o:v rooth nol of Muster. It Anrold not, anbawavar, W rKlodW m: w j%ntpuapo%,svj Otii, Aq Vrivain Q* Wrpts, of 44psFaCokMAY P;Iduca gymnAr pacwAlWa A= mWonlarol rqll*f, A SIAM$ i3nA�Tryvy onuld njoQ s* or vm1o* in tpaalr� in folKwip, jol subsurtmee poslols 0 ;Vx!; van yun AyRr in OW WZ0614t* V101A ty as tne., Kn:at ow W0110R yo stowed a anvil groAvy Agh which wan apnaronzly rVaM to tho presence of theme, U40 Undar Vkh'i NA! at hoxvtnQ No. 3' NOR % ", I so Thom are ttw ;`or tort!" kV .""Arter sloop 11 1 mr. T:n* ta:'.v� ralAtiv*,, cae *aoro too twl"v 4*0�) 30-.VkltL?v ottlqj C. t; u. U, 1, 1 - .0 '�A 'Y' xroq can bo p-r-.tapoo -#-I, with L4 .'LAov *A".A"1cw dapt.-A �Cciv.)xrad tc most *I' tn'!& za A LA00P -,,I n&- rtakou Irl Al a. Thi,4 A%r%t III%* In W_tz pas ze;,,,dz of Lh4 8.ousz.Q:4 "I'llts to the pro't'p"b"' V tirios3e it tdz P""2w"rir tn6 **,it uI A t%�ita ow; V.#v2 nc;rw-4idm of a 1ciaAl-lor, to tv"I'l; ii u un) v.v 1 �hY 0 r ffle'o IG's 4-.V. 'ftg 7, 9W C O �"6 !'I. Z4 lit a L4v w Wlfi r h- !:J -i 3 ton z u a Ce r i7 y g 0 vark vinjoh might better 6*ftmo the WO&A wa W-41*bb"W "'�I*Odtnx "-.On WS" rom"A 44001AMP"Ar ft*rwo &n4 the WOUStom u3dt we* *" rftemmadod &rA dovelopWAS for ttl� (r (:5uq,�r,-',�N-L",t'- %LQ 4; ► block Is largo® W#11S 4 n�vo raklnd SIOG"'Ient O'hows of FA'O and *&I* Tboy awy owes gas Sandy vhIGh war* not OU60*9c" zz":411 h"gv* b*fn rm-mc 4*01641*al kmmmledAp tmm e". bo vkpp" ralitabir Ib7 shallow AE Ct"Fe'r4a a bwslz for Woorp"tASIOD Of fttvp* vWk should bo DcLi!M6,%*A &4*quaiw drULlim tqvJpmm% 'li5O- Subv*y Tamin-al BuIldlnge Las Aar*La "00 O&WOOPOL&O OCW"r a UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Mr. Ws►. K. Cowan, Pres. Southwest Helicopters Inc. San Fernando Valley Airport 7614 Havenhurst Pan Buys, Gal. Dear Mr. Cowan: IN REPLY REFER TO: Anchorage, Alaska Hoar 259 Juno 22, 1955 Reference is made to your inquiry of. June 6 regarding oil companies doing exploratory work and drilling the Territory. There is at present a great deal of leasing activity and three companies are actually drilling or getting ready to drill, three are reportedly getting equipment to start drilling and a few others are doing surface reconnaisance work. Due to seasonality of the work, most Companies transfer personnel to the States during the winter and it is suggested that you contact the headquarters there. The following companies are now active in drilling: Phillips Petroleum Co. Alaska Rep. Mr. Phillip O'Rourke, Div. Geologist (Icy Bay Area) Getchell Building 4th g F. St. Anchorage, Alaska Iniskin Unit Operators (Iniskin Bay Area) Aledo Oil Co. Oureka Area) Mr. Russell Havenstrike Mt. McKinley Building 4th g Denali Anchorage, Alaska Alaska Gas & 011 Development Co. Hoar 2005 Anchorage, Alaska The following companies are reportedly planning to drills Houston Oil Co. (Mile 176 Alaska Railroad) Alaska Galf Oil & Gas Co. (Goose Bay area opposite Anchorage Mr. George Tucker, Pres. 5th & Harrow Anchorage, Alaska 326 4th Avome Anchorage, Alaska 4F Mr. Cowan- 2 The following companies are reportedly active in Alaska: General Petroleum C/ E.R. Orwig, Bos 2061, Fairbanks, Alaska Richfield Oil Co. Base camp Soldotvf4 Alaska Shell Oil Co. " " Ham. Alaska Standard Oil Co. No Alaska office contact Seattle office Superior Oil Co. Union Oil " " " contact Seattle office Due to the amount of leasing activity outside of actual development contracts filed at this office, it is suggested that you helve your local representatives contact this offtes and the Land Office, Bureau of Land Management, Federal Builfingo Anchorage. Information regarding oil activities in Alaska may also be obtained from the Alaska Scouting Service, C/ Mr. John Rodrick, Box 2278, Anchorage, Alaska. If we caa be of further assistance please advise. Very truly yours, L.H. Saarela Regional Mining Supervisor ccs L.G. Snow