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182-199
2025-1013_Location_SCU_42B-05_jh Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10/18/2025 P. I. Supervisor FROM: Josh Hunt SUBJECT: Location Clearance Inspection Petroleum Inspector Soldotna Creek Unit 42B-5 Hilcorp Alaska LLC PTD 1821990 10/11/2025: I traveled to Swanson River Field and met with Andrew Tuttle (Hilcorp Lead Operator). I went over the site map in the main office to verify the location. I followed Andrew to the well location which had already been capped and buried. I noticed there was no gravel pile on top of the well. I also noticed the concrete cellar box appeared to still be present and mostly covered up along with some electrical lines associated with this well. I received no additional paperwork for this well. I asked Andrew if there was permission from AOGCC to leave the cellar box in place, he said there was and would track it down. 10/13/2025: Today I received written permission from AOGCC’s Bryan McLellan (AOGCC Drilling Engineer) allowing Hilcorp to leave the cellar box in place for now due to its configuration with the well next to it and the associated piping that is currently active. However, this means the well will be classified as “P&A” and not “Location Cleared”; it will remain on Hilcorp’s active well count until the cellar box and electrical are removed. Attachments: Photos (3) 2025-1013_Location_SCU_42B-05_jh Page 2 of 3 Location Inspection - SCU 42B-05 (PTD 1821990) Photos by AOGCC Inspector J. Hunt except as noted 10/11/2025 SCU 42B-05 location looking North Electrical lines in a culvert covered with grating at the top edge of the SCU 42B-05 cellar box 2025-1013_Location_SCU_42B-05_jh Page 3 of 3 After placing gravel over P&A’d well SCU 42B-05; photo courtesy of Hilcorp Alaska LLC 1 Gluyas, Gavin R (OGC) From:Ryan Lemay <Ryan.Lemay@hilcorp.com> Sent:Monday, October 13, 2025 1:51 PM To:McLellan, Bryan J (OGC) Subject:FW: [EXTERNAL] Well P&A SCU 42B-05 / Request to Leave Cellar In Place From: Maercklein, William C <wmaercklein@blm.gov> Sent: Tuesday, April 15, 2025 2:43 PM To: Ryan Lemay <Ryan.Lemay@hilcorp.com> Cc: Taylor Malone <tmalone@hilcorp.com> Subject: RE: [EXTERNAL] Well P&A SCU 42B-05 / Request to Leave Cellar In Place Ryan, Just to follow up in writing. The BLM acknowledges the identified risk and will transfer the remaining liability to the SCU 42-05X well. In the meantime the cellar for the SCU 42B-05 shall be backfilled with appropriate weed free gravel. Will From: Ryan Lemay <Ryan.Lemay@hilcorp.com> Sent: Tuesday, April 1, 2025 8:57 AM To: Maercklein, William C <wmaercklein@blm.gov> Cc: Taylor Malone <tmalone@hilcorp.com> Subject: [EXTERNAL] Well P&A SCU 42B-05 / Request to Leave Cellar In Place This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or responding. Good Morning Will, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Hilcorp recently plug and abandoned well SCU 42B-05 and submitted subsequent report of P&A operations on 3/11/2025. The well cellar to this well is butted up against active storage well SCU 42-05X along with it’s accompanying flowline (pictured below). There is significant operational risk of excavating that closely to an active well and flowline if we were to attempt to remove the cellar and back fill the location of SCU 42B-05 at this time. Hilcorp is requesting that P&A Subsequent Report may be accepted for SCU 42B-05 with the cellar remaining in place. The cellar would be removed and site backfilled at a later date when SCU 42-05X is longer in service and P&A’d. Thank you and let me know if you need any additional pictures. 3 4 Ryan LeMay OperaƟons Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, October 13, 2025 4:49 PM To:Ryan Lemay Cc:Donna Ambruz; Hunt, Josh D (OGC); Regg, James B (OGC); Guhl, Meredith D (OGC) Subject:RE: Well P&A SCU 42B-05 / Request to Leave Cellar In Place Ryan, Hilcorp has approval to leave the cellar in place. The status of the well will be abandoned, but not site- cleared. The well will stay on Hilcorp’s active well count until the cellar has been removed and site clearance is satisfactory to the commission. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <ryan.lemay@hilcorp.com> Sent: Monday, October 13, 2025 4:18 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Hunt, Josh D (OGC) <josh.hunt@alaska.gov> Subject: Well P&A SCU 42B-05 / Request to Leave Cellar In Place Bryan, Thanks for taking my call earlier for SCU 42B-05. As discussed, Hilcorp is seeking approval to leave the cellar in place at this time and the cellar has been backfilled with certified weed free gravel. We had discussed this a few months ago when I was getting approval from BLM as well, but I must apologize for never closing the loop in obtaining a formal e-mail approval. Request for leaving cellar is due to the operational risk of excavating near active storage well and flowline SCU 42-05X. The SCU 42B-05 cellar would be removed and site backfilled at a future date when SCU 42- 05X is no longer in service and P&A’d. SCU 42B-05 cellar is butted up right against active well SCU 42- 05X (pictured below). 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 Picture of cellar prior to back fill showing close proximity to SCU 42-05X Requested picture of cellar post backfill. 3 Attachments: BLM’s approval to leave cellar in place. 10-407 that was submitted for this well P&A for reference. Thank you and let me know if you have any questions or need any further information. Ryan LeMay OperaƟons Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com To help protect your priv acy, Microsoft Office prevented automatic download of this picture from the Internet. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 4 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Lemay Cc:Donna Ambruz; Hunt, Josh D (OGC); Regg, James B (OGC); Guhl, Meredith D (OGC) Subject:RE: Well P&A SCU 42B-05 / Request to Leave Cellar In Place Date:Monday, October 13, 2025 4:48:43 PM Attachments:image004.png image005.png Ryan, Hilcorp has approval to leave the cellar in place. The status of the well will be abandoned, but not site-cleared. The well will stay on Hilcorp’s active well count until the cellar has been removed and site clearance is satisfactory to the commission. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <ryan.lemay@hilcorp.com> Sent: Monday, October 13, 2025 4:18 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Hunt, Josh D (OGC) <josh.hunt@alaska.gov> Subject: Well P&A SCU 42B-05 / Request to Leave Cellar In Place Bryan, Thanks for taking my call earlier for SCU 42B-05. As discussed, Hilcorp is seeking approval to leave the cellar in place at this time and the cellar has been backfilled with certified weed free gravel. We had discussed this a few months ago when I was getting approval from BLM as well, but I must apologize for never closing the loop in obtaining a formal e-mail approval. Request for leaving cellar is due to the operational risk of excavating near active storage well and flowline SCU 42-05X. The SCU 42B-05 cellar would be removed and site backfilled at a future date when SCU 42-05X is no longer in service and P&A’d. SCU 42B-05 cellar is butted up right against active well SCU 42-05X (pictured below). Picture of cellar prior to back fill showing close proximity to SCU 42-05X Requested picture of cellar post backfill. Attachments: BLM’s approval to leave cellar in place. 10-407 that was submitted for this well P&A for reference. Thank you and let me know if you have any questions or need any further information. Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender'sphone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affectits systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Ryan Lemay To:McLellan, Bryan J (OGC) Subject:FW: [EXTERNAL] Well P&A SCU 42B-05 / Request to Leave Cellar In Place Attachments:image001.png From: Maercklein, William C <wmaercklein@blm.gov> Sent: Tuesday, April 15, 2025 2:43 PM To: Ryan Lemay <Ryan.Lemay@hilcorp.com> Cc: Taylor Malone <tmalone@hilcorp.com> Subject: RE: [EXTERNAL] Well P&A SCU 42B-05 / Request to Leave Cellar In Place Ryan, Just to follow up in writing. The BLM acknowledges the identified risk and will transfer the remaining liability to the SCU 42-05X well. In the meantime the cellar for the SCU 42B-05 shall be backfilled with appropriate weed free gravel. Will From: Ryan Lemay <Ryan.Lemay@hilcorp.com> Sent: Tuesday, April 1, 2025 8:57 AM To: Maercklein, William C <wmaercklein@blm.gov> Cc: Taylor Malone <tmalone@hilcorp.com> Subject: [EXTERNAL] Well P&A SCU 42B-05 / Request to Leave Cellar In Place This email has been received from outside of DOI - Use caution before clicking on links, opening attachments, or responding. Good Morning Will, Hilcorp recently plug and abandoned well SCU 42B-05 and submitted subsequent report of P&A operations on 3/11/2025. The well cellar to this well is butted up against active storage well SCU 42-05X along with it’s accompanying flowline (pictured below). There is significant operational risk of excavating that closely to an active well and flowline if we were to attempt to remove the cellar and back fill the location of SCU 42B-05 at this time. Hilcorp is requesting that P&A Subsequent Report may be accepted for SCU 42B-05 with the cellar remaining in place. The cellar would be removed and site backfilled at a later date when SCU 42-05X is longer in service and P&A’d. Thank you and let me know if you need any additional pictures. Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 20" H-40 92 10-3/4" K-55 3394 7-5/8"SS95,S95 10393 5-1/2" L-80 8472 5-1/2" N-80 10897 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Swanson River / Beluga Gas N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 40.5# 10438 Surface Surface 94# Surface 3395 SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 20 Surface 10230 29 6-1/2" DrivenSurface 39,33.7 Surface 92Surface CASING WT. PER FT.GRADE 2/9/1983 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2458652.60 TOP HOLE SIZE AMOUNT PULLED N/A 341821.80 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM 50-133-20363-00-00 Soldotna Creek Unit (SCU) 42B-05 FEDA028996 1919' FSL, 509' FEL, Sec. 5, T7N, R9W, S.M. 2586' FNL, 498' FEL, Sec. 5, T7N, R9W, S.M. N/A 12/7/1982 10,945' MD / 10,900' TVD 0' MD / 0' TVD 168' 341802.60 2457878.00 N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG Gas 2/14/2025 182-199 / 324-293Hilcorp Alaska, LLC If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 2077 sx9-7/8" TUBING RECORD 10943 8511 1250 sx Surface 10186 14-3/4" 6-1/2" N/A 108 sx Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 8:35 am, Mar 11, 2025 Abandoned 2/14/2025 JSB RBDMS JSB 031925 GxDSR-4/7/25BJM 10/16/25 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: Well Operations Summary, Schematic, MIT-IA, Photo documenting casing cut-off/cement top/welded plate. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Ryan Lemay, Operations Engineer Digital Signature with Date:Contact Email:ryan.lemay@hilcorp.com Contact Phone: 661-487-0871 Authorized General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Formation Name at TD: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Noel Nocas, Operations Manager 907-564-5278 Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2025.03.10 16:03:00 -08'00' Page 1/1 Well Name: SRF SCU 042B-05 Report Printed: 2/21/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:5/23/2024 End Date: Report Number 1 Report Start Date 1/17/2025 Report End Date 1/18/2025 Last 24hr Summary PTW/PJSM. MIRU YJ E-line, PT lubricator 250 psi low / 2000 psi high - good test. M/U 7' of 1-11/16" WB, CCL and 2.25" gauge ring. 7' offset from CCL, RIH tag at 4632'. Work tool down to 4661' and stop making hole, pickup was sticky. POOH. Discussed results with OE. R/D E-line to support Rig 401 . Report Number 2 Report Start Date 1/19/2025 Report End Date 1/20/2025 Last 24hr Summary PTW/PJSM. R/U YJ E-line, PT lubricator 250 psi low / 2500psi high - good test. RIH and set a 2-7/8" CIBP at 4655' and tag plug. Dump bail 35' of 16ppg cement, isolating the Beluga Pool. RIH w/2.25” GR and verify cement tag at 4620’. RIH and set 2-7/8" CIBP at 4546' and tag plug. Dump bail 35' of 16 ppg cement, isolating the Sterling/ Upper Beluga Pool. RIH with jet cut toolstring and tag cement at 4511. Pull up hole and jet cut 2-7/8" Tbg at 3495' as per sundry. RDMO E-line Report Number 3 Report Start Date 1/20/2025 Report End Date 1/21/2025 Last 24hr Summary Load out trailers, and rig down to move over to SCU 42B-05. Lay out liner, spot in base beam and rig, spot in all equipment and rig up, fill mud tanks w/ 100 bbls of PW, circulate down tubing up IA w/ 2,500 stks, flow check (well static), MIT to 1,500 psi for 30 min (Good test), install BPV, w/ vault well tech, N/D tree, inspected hanger and M/U blanking sub. N/U BOPE, install rig floor and cellar tarps. Begin testing BOPE as per sundry. AOGCC rep Jim Regg waived witness. Report Number 4 Report Start Date 1/21/2025 Report End Date 1/22/2025 Last 24hr Summary Cotinue testing BOPE to Hilcorp's and AOGCC's expectations with 2-7/8" test joint, 250 psi low / 2500 psi high - good test. Witness waived by AOGCC's Jim Regg on 1/20/25. R/D test equipment. Pull BPV, M/U landing joint, BOLD. Unseat hanger 20k, pull to surface 19k p/u wt. L/D hanger, M/U landing joint on string and RIH to 3494'. BLM Rep came out to witness pumping cement plug and found a discrepancy in well procedure. Wait on approval to pump cement. Updated plan sent via email, reviewed, and verbally appproved to proceed by BLM. Lay balanced cement plug from 3495' - 3,151' (Estimated TOC) with 8 bbls of 15.3 ppg Class G cement, yield 1.23 ft3/sk, water 5.6 gal/skl, mud scale cmt weight 15.4ppg. Displace with 16 bbls of FW. POOH 2,976' and L/D 17 joints of 2-7/8" tubing tallying pipe. Reverse circulated clean. WOC. BLM and AOGCC reps to arrive at 08:00 hrs on 1/22/25 for cement tag witness. Report Number 5 Report Start Date 1/22/2025 Report End Date 1/23/2025 Last 24hr Summary RIH w/ 2-7/8" IBT f/2976' and tag TOC cement at 3267' stacking 10k weight down. Kam St John from AOGCC and Quinn Sawyer from BLM witnessed verifcation of cement tag. Circulate well over to 9 ppg brine w/ 1% Baracor 100, 75bbls brine circulated around. POOH laying down 2-7/8" IBT from 3260' to surface totaling 112 joints plus 15.24' cut joint. R/U YJ E-line. PT lubricator 250 psi low /2500 psi high - good test. E-line RIH w/ 5-1/2" CIBP and set CIBPat 160', confirm plug is set with tag, POOH. RIH with 2"x2' 6spf 60 degree gun, fire at 100'-102', POOH. Check for communication from the 5-1/2" to 10-3/4" annulus seeing 500psi on 7- 5/8" annulus but no returns up 10-3/4" annulus. Line up to take returns from 7-5/8" annulus, getting good returns to surface at 2 bpm, 150psi. RIH with 2"x6' gun, fire at 98'-104', POOH. Check for communication in 10-3/4" annulus, getting returns to surface, circulating at 1.5 bpm, 425psi. R/D E-line. Build 50 bbl batch of 9ppg brine. P/U 2-7/8" IBT and RIH to 150'. PJSM, R/U cement lines. Mix and pump @ 1 bbl/min, totaling 14 bbls of 15.3 ppg Class G cement, yield 1.23 ft3/sk, water rate 5.6 gal/sk. Pumped 9.5 bbls in 10 3/4" annulus (did not see cement circulated at surface in annulus), pump 2 bbls in 7 5/8" annulus (good cement returns to surface in annulus), pump 2.5 bbl in 5 1/2" (good cement returns to surface), L/D 5 jnts of 2 7/8" tubing, wash out and N/D BOPE, N/U dry hole tree, RDMO Report Number 6 Report Start Date 2/4/2025 Report End Date 2/5/2025 Last 24hr Summary Conduct final Well Plug & Abandon survey with McLane Consulting Inc. Report Number 7 Report Start Date 2/13/2025 Report End Date 2/14/2025 Last 24hr Summary Notifications for witness of wellhead cut off, cement at surface, and cap made 2/11/2025 to BLM and AOGCC. Witness waived by Jim Regg of AOGCC on 2/11/2025. PJSM. Rig up and cut wellhead. Observed TOC in 5-1/2" casing at ~5-6'. Top 5-1/2" casing with cement to surface. Cement at surface across all well annuli. BLM rep Quinn Sawyer witnessed wellhead cut operations 2/13/2025. Report Number 8 Report Start Date 2/14/2025 Report End Date 2/15/2025 Last 24hr Summary Prior to installation of cap, BLM rep Quinn Sawyer witnessed cement at surface across all well annuli following 5-1/2" cement top off day prior on 2/13/2025. Welded cap on conductor with the following data: Hilcorp Alaska LLC PTD: 182-199 Well Name: SCU 42B-05 API: 50-133-20363-00-00 Field: Swanson River Sundry #: 324-293 State: ALASKA Rig/Service:Permit to Drill (PTD) #:182-199Permit to Drill (PTD) #:182-199 Wellbore API/UWI:50-133-20363-00-00 Site Clearance was not completed. The wellhead is cut off 3' below grade and marker plate installed, but cement cellar is attached to the adjacent active well and removal would risk damaging it. The cellar will be removed when the adjacent well is P&A'd. See email correspondence from Ryan Lemay 10/13/25 in wellfile. -bjm Updated by DMA 02-20-25 SCHEMATIC Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00-00 PBTD = 5,070’ MD / 5,057’ TVD TD = 10,945’ MD / 10,899’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20”84 --92’ 10-3/4”40.5 K-55 -Surface 3,395’ 7-5/8”39 L-80 FL4S 6.625”Surface 1,542’ 7-5/8”33.7 L-80 FL4S 6.765”1,542’3,512’ 7-5/8”29.7 L-80 FL4S 6.875”3,512’4,611’ 7-5/8”33.7 SS-95 LT&C 6.765”4,611’7,508’ DV Collar 7 508’7,510’ 7-5/8”33.7 SS-95 LT&C 6.765”7,510’8,338’ 7-5/8”39 SS-95 LT&C 6.625”8,338’10,438’ Liner 5-1/2”17 N-80 Hyd 513 4.892”3,495’8,511’ 5-1/2”20 N-80 4.778”10,230’10,943’ Tubing 2-7/8 ”6.4 L-80 IBT 2.441”3,495’6,800’ 3-1/2 ”9.3 N-80 8RD EUE 2.992”9,500’ 10,290’ 2-3/8”1.995”10,290’10,308’ JEWELRY DETAIL NO.MD ID OD Item B 5,076’CIBP with 4’ Cement – TOC @ 5,070’ - 7/23/21 C 5,480’--CIBP with 35’ Cement Cap – TOC @ 5,445’ –4/6/21 D 6,763’2.441 -2-7/8” Cement Retainer –3/16/21 E 7,744'2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 F 7,758'2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s G 7,773'2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go H 7,775'2.441 3.70 Slotted Circ/Debris Sub w/ XO I 7,808'2.441 3.70 WLEG (Post gun Release) J 8,345'2.441 3.70 BHF-C Firing Head 8,348'3.50 SXAR Gun Drop Sub 8,352'3.50 Safety Spacer 8,379'3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394'3.50 Bull Nose 10,199’7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’ 2-3/8” Baker Shear Sub PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Date Comments UB 47-0 4,596'4,605'4,587’4,596’9'7/24/2021 2-1/8” Spiral UB 47-0 4,633'4,640'4,624’4,631’7'7/24/2021 2-1/8” Spiral UB 50-6 4,802'4,811'4,791’4,800’9'8/18/2021 2-1/8” Spiral UB 50-6 4,828'4,840'4,817’4,829’12'8/8/2021 2-1/8” Spiral LB51-1 5,055'5,060'5,043’5,048’5’4/14/2021 2” Razor - Isolated LB51-1 5,079'5,096'5,066’5,083’17’4/7/2021 2” Razor - Isolated LB51-1 5,303'5,308'5,289’5,294’5’4/7/2021 2” Razor - Isolated LB52-9 5,330'5,337'5,316’5,322’7’4/7/2021 2” Razor - Isolated LB52-9 5,413'5,423'5,398’5,408’10’4/7/2021 2” Razor - Isolated TY54-1 5,532'5,539'5,516’5,523’7’3/26/2021 2” Razor - Isolated TY55-4 5,647'5,656'5,630’5,639’9’3/26/2021 2” Razor - Isolated TY61-0 6,045'6,051'6,025’6,031’6’3/26/2021 2” Razor - Isolated TY61-0 6,073'6,082'6,053’6,062’9’3/26/2021 2” Razor - Isolated TY61-0 6,106'6,119'6,086’6,099’13’3/24/2021 2” Razor - Isolated TY62-3 6,347'6,366'6,325’6,344’19’3/24/2021 2” Razor - Isolated TY62-3 6,429'6,443'6,406’6,420’14’3/24/2021 2” Razor - Isolated T77-3 7,861’7,876’7,827’7,842’15’6/4/2006 Isolated H1 10,450’10,462’10,405’10,417’12’10/14/2005 Isolated H3 10,466’10,478’10,421’10,433’8’10/14/2005 Isolated H4 10,515’10,527’10,470’10,482’12’10/14/2005 Isolated H5 10,530’10,585’10,485’10,540’55’10/14/2005 Isolated H7 10,614’10,632’10,569’10,587’18’10/14/2005 Isolated 10,638’10,652’10,593’10,607’14’10/14/2005 Isolated 10,658’10,666’10,613’10,621’8’10/14/2005 Isolated 10,672’10,686’10,627’10,641’14’10/14/2005 Isolated 10,745’10,759’10,700’10,714’14’10/14/2005 Isolated 10,763’10,772’10,718’10,727’9’10/14/2005 Isolated 10,787’10,792’10,742’10,747’3’10/14/2005 Isolated 10,796’10,802’10,751’10,757’6’10/14/2005 Isolated RKB =18.0’ G Top of FC Plug @ 8395’ Retainer @8527’ TO C @ 7 7 0 8 ’ I J Tbg Cut 9500’ Ret LIH IIIIIIIIIIIII H, I Cmt Ret Tbg Cut Section Mill 50’ D C B E, F 7- 5/ 8 ” T O C @ 12 0 ’ (2 / 8 3 ) C B L 2- 7 / 8 ” T O C @ 35 4 0 ’ (3 / 2 3 ) C B L 9.0 ppg brine Cmt plug: 3,495’-3,267’ 1/22/25 Tubing cut @ 3,495’ 1/19/25 CIBP 4,546, TOC @ 4,511’ 1/19/25 CIBP 4,655’ TOC @ 4,620’ 1/19/25 tubing punch: 98’-104’ 1/22/25 circ cmt plug: 0-100’ 1/22/25 (tubing & annulus) CIBP @ 160’1/22/25 10-3/4” @ 3395’ Well Name: SCU 42B-05 PTD: 182-199 API: 50-133-20363-00-00 Plug & Abandonment Cut and Cap Photos TOC in 5-1/2” at ~5-6’ TOC in 5-1/2” at ~5-6’ P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Email ahamilton@mclanecg.com Well SCU 42B-05 Plug & Abandon Memo Date: 2/4/2025 To: Hilcorp Alaska LLC……………………………………Attn: Cody Dinger From: Andrew Hamilton, PLS Project: Swanson River – SCU 42B-05 Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp’s SCU well located on pad 43-05 in Section 5, Township 7 North, Range 9 West, Seward Meridian, Alaska. The survey was performed on January 24, 2025. The scope of work consisted of providing accurate field elevations so the well can be plugged and abandoned per State requirements. Existing survey control was recovered and positional accuracy was confirmed by comparing check shots on hard targets to existing data. To establish original ground elevation near the well casing, original ground survey measurements were observed at the perimeter of the pad in opposite positions from the well location. A prorated original ground elevation at the well was computed from the pad perimeter original ground shots. A top of pad elevation was also recorded on or adjacent to the well casing. Two (2) temporary benchmarks (TBM) were set onsite. One adjacent to the SCU 42B-5 well on the concrete cellar and one to the south of the SCU 42B-05 well on the corner of the flare stack containment. Both TBM’s have a lath denoting the TBM elevation. Enclosed is Exhibit A which includes well casing cutoff detail with pad, original ground, proposed casing cutoff elevations, and TBM locations and elevations. x Mean pad surface grade in vicinity of well casing: 153.6’ ± x Original ground elevation in vicinity of well casing: 151.9 ± x Cutoff depth requirement: 3.0’ below original ground elevation x Minimum casing cutoff elevation: 148.9’ x Casing cutoff elevation: 147.9’ The cutoff mark elevation of 147.9’, exceeds the required minimum cutoff elevation of 148.9’ Please feel free to contact or office if you have any questions or comments. Sincerely, Andrew Hamilton, PLS McLane Consulting, Inc. Page 2 of 2 P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Email ahamilton@mclanecg.com TBM-1 TBM-2 X ORIGINAL GROUND ELEV.=144.9' X ORIGINAL GROUND ELEV.=157.9' W SCU 42B-05 GROUND ELEVATION AT WELL HEAD ELEV = 153.6' X ORIGINAL GROUND ELEV.=157.2' X TBM - 2 SET PK NAIL ELEV=155.58' ACCESS ROAD SCU 43-05 PAD X TBM - 1 SET PK NAIL ELEV=153.50' SECTION 5 T7N R9W SM AK REVISION: DATE: DRAWN BY: SCALE: PROJECT NO. BOOK NO. SHEET ENGINEERING / MAPPING / SURVEYING / TESTING P.O. BOX 468 SOLDOTNA, AK. 99669 VOICE: (907) 283-4218 FAX: (907) 283-3265 EMAIL: SAMCLANE@MCLANECG.COM PROJECT LOCATION HILCORP ALASKA, LLC WELL SCU 42B-05 P&A PLUG AND ABANDON EXHIBIT-A 1 24-02 257004 1"=80' BGB 1/24/2025 - NOTE SECTION 5, TOWNSHIP 7 NORTH, RANGE 9 WEST, SEWARD MERIDIAN ALASKA BASIS OF COORDINATES; HORIZONTAL DATUM IS ALASKA STATE PLANE NAD83 ZONE 4 US FEET (EPOCH 2010). CP-11 N = 2465103.01 E = 1486152.27 ELEV = 169.28' (NAVD88) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 5 Township: 7N Range: 9W Meridian: Seward Drilling Rig: Hilcorp 401 Rig Elevation: 12 ft Total Depth: 10945 ft MD Lease No.: FEDA028996 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 92 Feet Csg Cut@ Feet Surface: 10-3/4" O.D. Shoe@ 3395 Feet Csg Cut@ Feet Intermediate: 7-5/8" O.D. Shoe@ 10438 Feet Csg Cut@ Feet Production: 5-1/2" O.D. Shoe@ 8511 Feet Csg Cut@ Feet Liner: 5-1/2" O.D. Shoe@ 10943 Feet Csg Cut@ Feet Tubing: 2-7/8" O.D. Tail@ 6800 Feet Tbg Cut@ 3495 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Other 4511 ft MD 3265 ft MD 8.6 ppg Drillpipe 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: Brad Whitten Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Target base of cement was to be 100 feet below surface casing shoe @ 3395 ft MD. Set 10K lbs down weight which was pipe string weight at 3267 ft MD verified with tally. No MIT required per approved Sundry 324-293. Tag also witnessed by BLM representative. January 22, 2025 Kam StJohn Well Bore Plug & Abandonment SCU 42B-05 Hilcorp Alaska LLC PTD 1821990; Sundry 324-293 none Test Data: Casing Removal: rev. 3-24-2022 2025-0122_Plug_Verification_SCU_42B-05_ksj 9 9 9 9 9 9 99 9 9 9 99 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.03 16:31:38 -09'00' From:McLellan, Bryan J (OGC) To:Scott Warner Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: SCU 42B-05 - PTD 182-199 - Sundry 324-293 - BOP Change Request Date:Thursday, January 16, 2025 10:47:00 AM Attachments:Yellowjacket 7-1 16 inch Type U BOP Stack Drawing.pdf Scott, Hilcorp has approval to use the 7-1/16” BOP stack as requested on the upcoming RWO under sundry 324-293. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Thursday, January 16, 2025 9:06 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: SCU 42B-05 - PTD 182-199 - Sundry 324-293 - BOP Change Request Bryan, Sorry about that. Here is the attachment. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, January 15, 2025 3:56 PM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: [EXTERNAL] RE: SCU 42B-05 - PTD 182-199 - Sundry 324-293 - BOP Change Request Scott, The 7-1/16” BOP stack was not attached. Please send it over. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Wednesday, January 15, 2025 3:13 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: SCU 42B-05 - PTD 182-199 - Sundry 324-293 - BOP Change Request Bryan, I would like to change the BOP stack from the 13-5/8” to the 7-1/16” due to the 13” not being needed and the 7” being easier to rig up and down with how it fits under the rig floor. I have attached the 7” schematic. We are currently on the SRU 14B-27 tubing swap and plan to move to this P&A when that tubing swap is complete. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. EQUIPMENT HEIGHT 99.09" ADDITION FOR RING GASKETS TOTAL STACK HEIGHT 2 each @ 0.50" 99.59" OPEN AND CLOSE DATA OPEN CLOSE 2-1/16" 5M HCR 0.61 0.52 HEIGHT DATA AND WEIGHT DATA 7-1/16" 5M ANNULAR 3.21 4.57 7-1/16" 10M RAMS (PER SET) 1.3 1.3 ϳͲϭͬϭϲΗϱDEEh>Z^,&& Z ^dz> , /',d͗ϯϬ͘ϵΗ t /',d͗ϯϬϰϮ>^ ϳͲϭͬϭϲΗϱDdzW hKW , /',d͗ϰϰ͘ϭϵΗ t /',d͗ϲϰϬϬ>^ ϳͲϭͬϭϲΗϱDdzW h^d< ϳͲϭͬϭϲΗϱDZ/>>/E' ^WKK> , /',d͗ϮϰΗ t /',d͗ϭϲϬϬ>^ </>>^/ ͗Ϯ ,ϮͲϭͬϭϲΗϱDD's ,K< ^/ ͗ϭ ,ϮͲϭͬϭϲΗϱDD's Eϭ ,ϮͲϭͬϭϲΗϱD,Z 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,945'N/A Casing Collapse Structural Conductor Surface 1,580psi Intermediate 4,790psi Production 6,280psi Liner 8,830psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker FH Pkrs; N/A 10,199'; 10,272' MD/10,155'; 10,228' TVD; N/A 10,900'5,070'5,057' Swanson River Beluga Gas 20" 10-3/4" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Soldotna Creek Unit (SCU) 42B-05CO 716A N/A 8,472'5-1/2" ~1650psi 8,511' 5076; 5480 Length May 28, 2024 10,943'713' 2-7/8" 10,897' 8,511' Perforation Depth MD (ft): 10,438' 5-1/2" See Attached Schematic 6,890psi 3,130psi 92' 10,393' 92' 3,395' Size 92' 7-5/8"10,438' 3,395' MD Hilcorp Alaska, LLC Proposed Pools: 6.4# / L-80 TVD Burst 6,800' 7,740psi 3,394' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028996 182-199 50-133-20363-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY 9,190psi Tubing Grade: jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:58 am, May 15, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.05.14 17:33:58 -08'00' 324-293 BOP test to 2500 psi. SFD 5/15/2024 DSR-5/15/24 X 10-407 X Provide 24 hrs notice for AOGCC to witness cement at surface after wellhead cutoff, before installing marker Provide 10 days notice for AOGCC to witness final site clearance. Base of surface cement plug must be 150' below ground level. BJM 6/10/24 X Base of cement plug must be 100' below surface casing shoe. Place base of plug at 3495' MD. Verify location of cement plug by setting 15k lbs weight on plug. Provide 24 hrs for AOGCC witness. *&:JLC 6/10/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.11 13:49:30 -05'00'06/11/24 RBDMS JSB 061324 Well Prognosis Well: SCU 42B-05 Well Name: Soldotna Creek Unit 42B-05 API Number: 50-133-20363-00 Current Status: Shut-In Gas Producer Permit to Drill Number: 182-199 First Call Engineer: Jake Flora (907) 777-8442 (907) 301-1736 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (720) 988-5375 (C) Revised portion of procedure in Red font based on comments from AOGCC approval and BLM in Sundry approvals Current Bottom Hole Pressure: ~ 2,109 psi @ 4,587’ TVD (Calc from 8/19/21 perf pressure) Maximum Expected BHP: ~ 2,109 psi @ 4,587’ TVD (Calc from 8/19/21 perf pressure) Max. Potential Surface Pressure: ~ 1,650 psi (Based on the Calc. BHP and a 0.10 psi/ft gas gradient to surface) Brief Well Summary: SCU 42B-05 was drilled and completed in 1983 as an oil well in Hemlock H-10. The well was plugged back in 2005 to recomplete in the Tyonek 77-3 sand for gas storage. A 5-1/2” liner was run inside the 7-5/8” production casing from 8,511’ to surface and cemented. The well was plugged to isolate the 77-3 in 2006 sand by cement squeeze through a 2-7/8” CICR set inside the tubing above the packer at 7,758’. The tubing was cut above the CICR. A window of the 5-1/2” casing was section milled above the fish top from 7,569 – 7,598’ and an additional cement squeeze was pumped to remediate the annular gas flow. The well was left in a suspended status with a 2-7/8” kill string set at 6,800’. In 2021 a retainer was set inside the 2-7/8” kill string, and a cement plug was pumped up the inner annulus to 3,540’. Perforations were added in the Tyonek with no success. A CIBP was set at 5,482’ and 1 sack of cement was dump bailed on top. Perfs were added in the Lower Beluga with no success. A CIBP was set at 5,076’ and 1 sack of cement was dump bailed on top. Perfs were added in the Upper Beluga with no success. These perfs were left open from 4,596 – 4,817’. The purpose of this Sundry is to permanently P&A the SCU 42B-05 wellbore. Wellbore Condition x Inclination: near vertical x Cement: o 10-3/4” 40.5# K-55 set @ 3,395’ and cemented to surface o 7-5/8” set at 10427’ Primary Cement Job: Pumped 162 bbls Class G: CBL TOC at 7708’ Stage Cement Job (DV tool at 7508’): Pumped 304 bbls Class G: CBL TOC at 120’ (job log on 2/4/1983 noted cement to surface). o 5-1/2” 17# N-80 from 8,511’ to surface. Procedure 1. Provide 24-hour notice to AOGCC and BLM that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112(h). 2. MIRU E-line, PT lubricator to 2000 psi 3. Set CIBP at ~4775’, dump bail 35’ cement on plug (This CIBP isolates the Beluga Pool) 4. Set CIBP at ~ 4546’, dump bail 35’ cement on plug (This CIBP isolates the Sterling/Upper Beluga Pool) 5. Cut tubing at 3450’ (planned cut is 90’ above TOC @ 3540’) Cut tubing at 3495', 100' below surface casing shoe. -bjm Well Prognosis Well: SCU 42B-05 6. RU pump truck to tubing, fluid pack & circulate wellbore through tubing cut 7. Perform Combo MIT of tubing & annulus to 1500 psi, bleed tubing and annulus to zero psi 8. MIRU 401 Workover Rig 9. ND tree 10. NU 13-5/8” BOP Stack a. Test per approved 10-403 11. Install landing joint, LD tubing hanger 12. Circulate 9.0 ppg NaCL Brine from tubing cut to surface 13. TOOH to place tubing tail at 3445’, close annular 14. RU cementers, mix & pump 8 bbls cement (8bbls = 300’ in 5-1/2” casing) 15. Displace with 18 bbls water (planned TOC is 200’ above SC shoe) 16. Open annular, slowly pull tubing from cement plug to ~3000’ 17. Close annular reverse tubing clean 18. Pull / LD tubing 19. ND annular, NU dry hole tree 20. Provide notice to agencies of upcoming tag 21. RU E-line, tag TOC 22. Set CIBP at 160’ 23. Punch casing at 100’ (1983 CBL shows TOC at 120’) 24. RU cementers, establish circulation down 5-1/2” casing with returns from 7-5/8” x 10-3/4” annulus 25. Mix & pump ~14 bbls cement to fill the casing and annulus to surface from 100’ x 7-5/8” casing = .0471 bbls/ft x 7-5/8” x 10-3/4” annulus = .0416 bbls/ft 26. RDMO 401 27. WOC 28. Excavate wellhead, cut & cap casing Post Rig Abandonment Procedures: 1. Excavate cellar, cut off casing 3’ below natural GL. 2. Notify AOGCC 48hrs in advance. 3. Create well abandonment marker per 20 AAC 25.120. The following must be bead-welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 182-199 c. Well Name: SCU 42B-05 d. API: 50-133-20363-00-00 Need to penetrate 2 casing strings. Casing punch won't likely penetrate both strings. Need more powerful guns. Be perpared to pump top job after cutting off wellhead. -bjm Base of cement must be 100' below surface casing shoe per 20 AAC 25.112(c)(3). Place tubing tail at 3495' MD when pumping cement. -bjm Cement plug must have 15k lbs weight set down to verify location. -bjm RIH with tubing to 150' MD. -bjm Fill casing with cement from 150' MD, fill annulus from 100' MD. -bjm This is 5-1/2" 17# casing = .0232 bpf. -bjm Well Prognosis Well: SCU 42B-05 4. Set marker plate per 20 AAC 25.120 and collect GPS coordinates. 5. Photo document casing cut-off and Welded Plate install. 6. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic Wellhead Diagran RWO Sundry Revision Change Form 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:Jacob Flora To:McLellan, Bryan J (OGC) Subject:SCU 42B-05 AOGCC 10-403 P&A PTD 182-199 Submitted 05-15-24 - Pool Tops, BOP Diagram, Revised Prog Date:Monday, June 10, 2024 11:22:03 AM Attachments:image001.png SCU 42B-05 P&A 2024-06-10 Rev1.pdf 13 DRAWING DOUBLE FLEX.pdf Hello Bryan, We are completing the first P&A today on 13-09, and will then do both tubing repairs (32C-15, 14B-27) before starting the second P&A, 42B-05. I have owed you a handful of items on the SCU 42B-05: A. Please see below the Pool Tops with current and proposed plugs a. The LB 50-6 is now correctly labeled, it was shown as Upper Beluga on the WBDs b. There is an added CIBP isolating the Lower Beluga B. Attached BOP diagram a. Test per approved 10-403 language is added in the revised procedure b. The 2-3/8 – 3-1/2 flexbore rams cover the 2-7/8 pipe we are pulling C. Revised procedure a. BOP use & testing added b. KWF 9.0 ppg NaCL brine added c. Notice to agencies to witness tag added Procedure Revision Notes; The main difference between the 13-09 approved revision and this one is not setting a CIBP below the casing shoe depth. This wellbore has a 5-1/2” liner cemented to surface inside the 7-5/8” casing. I have pumped many (~20) squeezes inside vertical wells with 5-1/2” and have seen on the subsequent drill outs that the cement will sag 5-10’ below the open perfs. It doesn’t swap out with water in a closed environment. In this case we are pumping an additional 100’ of cement above the casing shoe depth (300’ total) and will perform a witnessed tag with wireline the following day. Please call if you would like to have more conversation around pumping cement over water- as mentioned I have done a lot of it and have seen the results via the drillouts. Best Regards, Jake Pool Tops & Plug Depths The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well Prognosis Well: SCU 42B-05 Well Name: Soldotna Creek Unit 42B-05 API Number: 50-133-20363-00 Current Status: Shut-In Gas Producer Permit to Drill Number: 182-199 First Call Engineer: Jake Flora (907) 777-8442 (907) 301-1736 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (720) 988-5375 (C) Current Bottom Hole Pressure: ~ 2,109 psi @ 4,587’ TVD (Calc from 8/19/21 perf pressure) Maximum Expected BHP: ~ 2,109 psi @ 4,587’ TVD (Calc from 8/19/21 perf pressure) Max. Potential Surface Pressure: ~ 1,650 psi (Based on the Calc. BHP and a 0.10 psi/ft gas gradient to surface) Brief Well Summary: SCU 42B-05 was drilled and completed in 1983 as an oil well in Hemlock H-10. The well was plugged back in 2005 to recomplete in the Tyonek 77-3 sand for gas storage. A 5-1/2” liner was run inside the 7-5/8” production casing from 8,511’ to surface and cemented. The well was plugged to isolate the 77-3 in 2006 sand by cement squeeze through a 2-7/8” CICR set inside the tubing above the packer at 7,758’. The tubing was cut above the CICR. A window of the 5-1/2” casing was section milled above the fish top from 7,569 – 7,598’ and an additional cement squeeze was pumped to remediate the annular gas flow. The well was left in a suspended status with a 2-7/8” kill string set at 6,800’. In 2021 a retainer was set inside the 2-7/8” kill string, and a cement plug was pumped up the inner annulus to 3,540’. Perforations were added in the Tyonek with no success. A CIBP was set at 5,482’ and 1 sack of cement was dump bailed on top. Perfs were added in the Lower Beluga with no success. A CIBP was set at 5,076’ and 1 sack of cement was dump bailed on top. Perfs were added in the Upper Beluga with no success. These perfs were left open from 4,596 – 4,817’. The purpose of this Sundry is to permanently P&A the SCU 42B-05 wellbore. Wellbore Condition x Inclination: near vertical x Cement: o 10-3/4” 40.5# K-55 set @ 3,395’ and cemented to surface o 7-5/8” set at 10427’ Primary Cement Job: Pumped 162 bbls Class G: CBL TOC at 7708’ Stage Cement Job (DV tool at 7508’): Pumped 304 bbls Class G: CBL TOC at 120’ (job log on 2/4/1983 noted cement to surface). o 5-1/2” 17# N-80 from 8,511’ to surface. Procedure 1. Provide 24-hour notice to AOGCC and BLM that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112(h). 2. MIRU E-line, PT lubricator to 2000 psi 3. Set CIBP at ~ 4546’, dump bail 35’ cement on plug (CIBP is planned 50’ over top open perf) 4. Cut tubing at 3450’ (planned cut is 90’ above TOC @ 3540’) 5. RU pump truck to tubing, fluid pack & circulate wellbore through tubing cut 6. Perform Combo MIT of tubing & annulus to 1500 psi, bleed tubing and annulus to zero psi 7. MIRU 401 Workover Rig Superseded Well Prognosis Well: SCU 42B-05 8. ND tree 9. RU annular BOP (for the purpose of closing on tubing to circulate while cementing, well is now plugged with multiple barriers in place) 10. Install landing joint, LD tubing hanger, pull tubing to 3445’, close annular BOP 11. RU cementers, mix & pump 8 bbls cement (8bbls = 300’ in 5-1/2” casing) 12. Displace with 18 bbls water (planned TOC is 200’ above SC shoe) 13. Open annular, slowly pull tubing from cement plug to ~3000’ 14. Close annular reverse tubing clean with 9.0ppg brine or mud to surface 15. Pull / LD tubing 16. ND annular, NU dry hole tree, RDMO 401 17. RU E-line 18. Punch casing at 100’ 19. RU cementers, establish circulation down 5-1/2” casing with returns from 7-5/8” x 10-3/4” annulus 20. Mix & pump ~14 bbls cement to fill the casing and annulus to surface from 100’ x 7-5/8” casing = .0471 bbls/ft x 7-5/8” x 10-3/4” annulus = .0416 bbls/ft 21. WOC 22. Excavate wellhead, cut & cap casing Post Rig Abandonment Procedures: 1. Excavate cellar, cut off casing 3’ below natural GL. 2. Notify AOGCC 48hrs in advance. 3. Create well abandonment marker per 20 AAC 25.120. The following must be bead-welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 182-199 c. Well Name: SCU 42B-05 d. API: 50-133-20363-00-00 4. Set marker plate per 20 AAC 25.120 and collect GPS coordinates. 5. Photo document casing cut-off and Welded Plate install. 6. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic Wellhead Diagran RWO Sundry Revision Change Form Superseded Updated by JMF 04-03-2024 SCHEMATIC Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00-00 PBTD = 5,070’ MD / 5,057’ TVD TD = 10,945’ MD / 10,899’ TVD 7-5/8” TOC @ 120’ (2/83) CBL RKB =18.0’ G Top of FC Plug @ 8395’ Retainer @8527’ Retainer 10,230’TOC @ 7708’I J Tbg Cut 9500’ Fill Tag @ 10,614 on 10/01/05 Ret LIH H, I Cmt Ret Tbg Cut Section Mill 50’ D Upper BelugaLower Beluga TyonekC A B E, F HEMLOCK2-7/8” TOC @ 3540’(3/23) CBL CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20”84 --92’ 10-3/4”40.5 K-55 -Surface 3,395’ 7-5/8”39 L-80 FL4S 6.625”Surface 1,542’ 7-5/8”33.7 L-80 FL4S 6.765”1,542’3,512’ 7-5/8”29.7 L-80 FL4S 6.875”3,512’4,611’ 7-5/8”33.7 SS-95 LT&C 6.765”4,611’7508’ DV Collar 7508’ 7510’ 7-5/8”33.7 SS-95 LT&C 6.765”7510’8,338’ 7-5/8”39 SS-95 LT&C 6.625”8,338’10,438’ Liner 5-1/2”17 N-80 Hyd 513 4.892”Surf 8511’ 5-1/2”20 N-80 4.778”10,230’10,943’ Tubing 2-7/8 ”6.4 L-80 IBT 2.441”Surf 6,800’ 3-1/2 ”9.3 N-80 8RD EUE 2.992”9500’ 10,290’ 2-3/8”1.995”10,290’10,308’ JEWELRY DETAIL NO. TM Depth Length ID OD Item A 18’--Tubing Hanger B 5,076’CIBP with 4’ Cement –TOC @ 5,070’-7/23/21 C 5,480’32’--CIBP with 35’ Cement Cap –TOC @ 5,445’–4/6/21 D 6,763’1’2.441 -2-7/8” Cement Retainer –3/16/21 E 7,744' 4.00' 2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 F 7,758' 5.85' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s G 7,773' 1.08' 2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go H 7,775' 2.61' 2.441 3.70 Slotted Circ/Debris Sub w/ XO I 7,808' 1.00' 2.441 3.70 WLEG (Post gun Release) J 8,345' 3.31' 2.441 3.70 BHF-C Firing Head 8,348' 4.14' 3.50 SXAR Gun Drop Sub 8,352' 26.68' 3.50 Safety Spacer 8,379' 15.00' 3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394' 0.56' 3.50 Bull Nose 10,199’ 7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’ 2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’ 2-3/8” Baker Shear Sub PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Date Comments UB 47-0 4,596'4,605'4,587’4,596’9'7/24/2021 2-1/8” Spiral UB 47-0 4,633' 4,640' 4,624’ 4,631’ 7' 7/24/2021 2-1/8” Spiral UB 50-6 4,802'4,811'4,791’4,800’9'8/18/2021 2-1/8” Spiral UB 50-6 4,828'4,840'4,817’4,829’12'8/8/2021 2-1/8” Spiral LB51-1 5,055'5,060'5,043’5,048’5’4/14/2021 2” Razor -Isolated LB51-1 5,079' 5,096' 5,066’ 5,083’ 17’ 4/7/2021 2” Razor - Isolated LB51-1 5,303'5,308'5,289’5,294’5’4/7/2021 2” Razor -Isolated LB52-9 5,330'5,337'5,316’5,322’7’4/7/2021 2” Razor -Isolated LB52-9 5,413'5,423'5,398’5,408’10’4/7/2021 2” Razor -Isolated TY54-1 5,532' 5,539' 5,516’ 5,523’ 7’ 3/26/2021 2” Razor - Isolated TY55-4 5,647'5,656'5,630’5,639’9’3/26/2021 2” Razor -Isolated TY61-0 6,045'6,051'6,025’6,031’6’3/26/2021 2” Razor -Isolated TY61-0 6,073'6,082'6,053’6,062’9’3/26/2021 2” Razor -Isolated TY61-0 6,106'6,119'6,086’6,099’13’3/24/2021 2” Razor -Isolated TY62-3 6,347'6,366'6,325’6,344’19’3/24/2021 2” Razor -Isolated TY62-3 6,429'6,443'6,406’6,420’14’3/24/2021 2” Razor -Isolated T77-3 7,861’7,876’7,827’7,842’15’6/4/2006 Isolated H1 10,450’10,462’10,405’10,417’12’10/14/2005 Isolated H3 10,466’10,478’10,421’10,433’8’10/14/2005 Isolated H4 10,515’10,527’10,470’10,482’12’10/14/2005 Isolated H5 10,530’10,585’10,485’10,540’55’10/14/2005 Isolated H7 10,614’10,632’10,569’10,587’18’10/14/2005 Isolated 10,638’10,652’10,593’10,607’14’10/14/2005 Isolated 10,658’10,666’10,613’10,621’8’10/14/2005 Isolated 10,672’10,686’10,627’10,641’14’10/14/2005 Isolated 10,745’10,759’10,700’10,714’14’10/14/2005 Isolated 10,763’10,772’10,718’10,727’9’10/14/2005 Isolated 10,787’10,792’10,742’10,747’3’10/14/2005 Isolated 10,796’10,802’10,751’10,757’6’10/14/2005 Isolated Updated by JMF 06-10-2024 PROPOSED Rev1 Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00-00 PBTD = 5,070’ MD / 5,057’ TVD TD = 10,945’ MD / 10,899’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOPBTM. 20”84 --92’ 10-3/4”40.5 K-55 -Surface 3,395’ 7-5/8” 39 L-80 FL4S 6.625” Surface 1,542’ 7-5/8” 33.7 L-80 FL4S 6.765”1,542’3,512’ 7-5/8” 29.7 L-80 FL4S 6.875”3,512’4,611’ 7-5/8” 33.7 SS-95 LT&C 6.765”4,611’7508’ DV Collar 7508’ 7510’ 7-5/8” 33.7 SS-95 LT&C 6.765” 7510’8,338’ 7-5/8” 39 SS-95 LT&C 6.625” 8,338’10,438’ Liner 5-1/2” 17 N-80 Hyd 513 4.892” Surf 8511’ 5-1/2” 20 N-80 4.778” 10,230’10,943’ Tubing 2-7/8 ”6.4 L-80 IBT 2.441”Surf 6,800’ 3-1/2 ”9.3 N-80 8RD EUE 2.992”9500’ 10,290’ 2-3/8” 1.995” 10,290’10,308’ JEWELRY DETAIL NO.MD ID OD Item B 5,076’CIBP with 4’ Cement –TOC @ 5,070’ -7/23/21 C 5,480’--CIBP with 35’ Cement Cap –TOC @ 5,445’ –4/6/21 D 6,763’ 2.441 - 2-7/8” Cement Retainer – 3/16/21 E 7,744' 2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 F 7,758' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s G 7,773' 2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go H 7,775' 2.441 3.70 Slotted Circ/Debris Sub w/ XO I 7,808' 2.441 3.70 WLEG (Post gun Release) J 8,345' 2.441 3.70 BHF-C Firing Head 8,348' 3.50 SXAR Gun Drop Sub 8,352' 3.50 Safety Spacer 8,379' 3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394' 3.50 Bull Nose 10,199’ 7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’ 2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’2-3/8” Baker Shear Sub PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVDFt Date Comments UB 47-0 4,596'4,605'4,587’4,596’9' 7/24/2021 2-1/8” Spiral UB 47-0 4,633'4,640'4,624’4,631’7' 7/24/2021 2-1/8” Spiral UB 50-6 4,802'4,811'4,791’4,800’9'8/18/2021 2-1/8” Spiral UB 50-6 4,828'4,840'4,817’4,829’12' 8/8/2021 2-1/8” Spiral LB51-15,055'5,060'5,043’5,048’5’4/14/2021 2” Razor -Isolated LB51-15,079'5,096'5,066’5,083’17’4/7/2021 2” Razor -Isolated LB51-15,303'5,308'5,289’5,294’5’4/7/2021 2” Razor -Isolated LB52-9 5,330'5,337'5,316’5,322’7’4/7/2021 2” Razor -Isolated LB52-9 5,413'5,423'5,398’5,408’10’4/7/2021 2” Razor -Isolated TY54-15,532'5,539'5,516’5,523’7’3/26/2021 2” Razor -Isolated TY55-4 5,647'5,656'5,630’5,639’9’3/26/2021 2” Razor -Isolated TY61-0 6,045'6,051'6,025’6,031’6’3/26/2021 2” Razor -Isolated TY61-0 6,073'6,082'6,053’6,062’9’3/26/2021 2” Razor -Isolated TY61-0 6,106'6,119'6,086’6,099’13’3/24/2021 2” Razor -Isolated TY62-3 6,347' 6,366' 6,325’ 6,344’ 19’ 3/24/2021 2” Razor - Isolated TY62-3 6,429'6,443'6,406’6,420’14’3/24/2021 2” Razor -Isolated T77-3 7,861’7,876’7,827’7,842’15’6/4/2006 Isolated H1 10,450’10,462’10,405’10,417’12’10/14/2005 Isolated H3 10,466’ 10,478’ 10,421’ 10,433’ 8’ 10/14/2005 Isolated H4 10,515’10,527’10,470’10,482’12’10/14/2005 Isolated H5 10,530’10,585’10,485’10,540’55’10/14/2005 Isolated H7 10,614’10,632’10,569’10,587’18’10/14/2005 Isolated 10,638’ 10,652’ 10,593’ 10,607’ 14’ 10/14/2005 Isolated 10,658’10,666’10,613’10,621’8’10/14/2005 Isolated 10,672’10,686’10,627’10,641’14’10/14/2005 Isolated 10,745’10,759’10,700’10,714’14’10/14/2005 Isolated 10,763’10,772’10,718’10,727’9’10/14/2005 Isolated 10,787’10,792’10,742’10,747’3’10/14/2005 Isolated 10,796’10,802’10,751’10,757’6’10/14/2005 Isolated G Top of FC Plug @ 8395’ Retainer @8527’TOC @ 7708’I J Tbg Cut 9500’ Ret LIH H, I Cmt Ret Tbg Cut Section Mill 50’ D C B E, F7-5/8” TOC @ 120’(2/83) CBL 2-7/8” TOC @ 3540’ (3/23) CBL 9.0 ppg brine lay cmt plug: ~3145-3445’ cut tubing @ ~3450’ CIBP w 35’ cmt @ ~4546’ CIBP w 35’ cmt @ ~4775’ tubing punch: 100’ circ cmt plug: 0-100’ (tubing & annulus) CIBP @ 160’ 10-3/4” @ 3395’ 3195-3495' -bjm Cut tbg @ 3495' -bjm Place cement in 5-1/2" casg from 150' MD to surface. -bjm Updated by JMF 04-25-2024 PROPOSED Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00-00 PBTD = 5,070’ MD / 5,057’ TVD TD = 10,945’ MD / 10,899’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOPBTM. 20”84 --92’ 10-3/4”40.5 K-55 -Surface 3,395’ 7-5/8” 39 L-80 FL4S 6.625” Surface 1,542’ 7-5/8” 33.7 L-80 FL4S 6.765”1,542’3,512’ 7-5/8” 29.7 L-80 FL4S 6.875”3,512’4,611’ 7-5/8” 33.7 SS-95 LT&C 6.765”4,611’7508’ DV Collar 7508’ 7510’ 7-5/8” 33.7 SS-95 LT&C 6.765” 7510’8,338’ 7-5/8” 39 SS-95 LT&C 6.625” 8,338’10,438’ Liner 5-1/2” 17 N-80 Hyd 513 4.892” Surf 8511’ 5-1/2” 20 N-80 4.778” 10,230’10,943’ Tubing 2-7/8 ”6.4 L-80 IBT 2.441”Surf 6,800’ 3-1/2 ”9.3 N-80 8RD EUE 2.992”9500’ 10,290’ 2-3/8” 1.995” 10,290’10,308’ JEWELRY DETAIL NO.MD ID OD Item B 5,076’CIBP with 4’ Cement –TOC @ 5,070’ -7/23/21 C 5,480’--CIBP with 35’ Cement Cap –TOC @ 5,445’ –4/6/21 D 6,763’ 2.441 - 2-7/8” Cement Retainer – 3/16/21 E 7,744' 2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 F 7,758' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s G 7,773' 2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go H 7,775' 2.441 3.70 Slotted Circ/Debris Sub w/ XO I 7,808' 2.441 3.70 WLEG (Post gun Release) J 8,345' 2.441 3.70 BHF-C Firing Head 8,348' 3.50 SXAR Gun Drop Sub 8,352' 3.50 Safety Spacer 8,379' 3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394' 3.50 Bull Nose 10,199’ 7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’ 2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’2-3/8” Baker Shear Sub PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVDFt Date Comments UB 47-0 4,596'4,605'4,587’4,596’9' 7/24/2021 2-1/8” Spiral UB 47-0 4,633'4,640'4,624’4,631’7' 7/24/2021 2-1/8” Spiral UB 50-6 4,802'4,811'4,791’4,800’9'8/18/2021 2-1/8” Spiral UB 50-6 4,828'4,840'4,817’4,829’12' 8/8/2021 2-1/8” Spiral LB51-15,055'5,060'5,043’5,048’5’4/14/2021 2” Razor -Isolated LB51-15,079'5,096'5,066’5,083’17’4/7/2021 2” Razor -Isolated LB51-15,303'5,308'5,289’5,294’5’4/7/2021 2” Razor -Isolated LB52-9 5,330'5,337'5,316’5,322’7’4/7/2021 2” Razor -Isolated LB52-9 5,413'5,423'5,398’5,408’10’4/7/2021 2” Razor -Isolated TY54-15,532'5,539'5,516’5,523’7’3/26/2021 2” Razor -Isolated TY55-4 5,647'5,656'5,630’5,639’9’3/26/2021 2” Razor -Isolated TY61-0 6,045'6,051'6,025’6,031’6’3/26/2021 2” Razor -Isolated TY61-0 6,073'6,082'6,053’6,062’9’3/26/2021 2” Razor -Isolated TY61-0 6,106'6,119'6,086’6,099’13’3/24/2021 2” Razor -Isolated TY62-3 6,347' 6,366' 6,325’ 6,344’ 19’ 3/24/2021 2” Razor - Isolated TY62-3 6,429'6,443'6,406’6,420’14’3/24/2021 2” Razor -Isolated T77-3 7,861’7,876’7,827’7,842’15’6/4/2006 Isolated H1 10,450’10,462’10,405’10,417’12’10/14/2005 Isolated H3 10,466’ 10,478’ 10,421’ 10,433’ 8’ 10/14/2005 Isolated H4 10,515’10,527’10,470’10,482’12’10/14/2005 Isolated H5 10,530’10,585’10,485’10,540’55’10/14/2005 Isolated H7 10,614’10,632’10,569’10,587’18’10/14/2005 Isolated 10,638’ 10,652’ 10,593’ 10,607’ 14’ 10/14/2005 Isolated 10,658’10,666’10,613’10,621’8’10/14/2005 Isolated 10,672’10,686’10,627’10,641’14’10/14/2005 Isolated 10,745’10,759’10,700’10,714’14’10/14/2005 Isolated 10,763’10,772’10,718’10,727’9’10/14/2005 Isolated 10,787’10,792’10,742’10,747’3’10/14/2005 Isolated 10,796’10,802’10,751’10,757’6’10/14/2005 Isolated G Top of FC Plug @ 8395’ Retainer @8527’TOC @ 7708’I J Tbg Cut 9500’ Ret LIH H, I Cmt Ret Tbg Cut Section Mill 50’ D C B E,F7-5/8” TOC @ 120’(2/83) CBL 2-7/8” TOC @ 3540’ (3/23) CBL 9.0 ppg brine lay cmt plug: ~3195-3445’ cut tubing @ ~3450’ set CIBP w 35’ cmt @ ~4546’ tubing punch: 100’ circ cmt plug: 0-100’ (tubing & annulus) 10-3/4” @ 3395’ Superseded Swanson River SCU 42B-05 Current 04/29/2024 Swanson River SCU 42B-05 10 3/4 x 7 5/8 x 5 1/2 x 2 7/8 Tubing hanger, FTC-5 1/2EN-CL, 7 x 3 ½ EUE 8rd lift and susp, w/3'’ type H BPV profile, 1- 1/4 npt control line port 10 ¾’’ 7 5/8'’ Casing head, CIW-WF, 11 5M FE top x 10 3/4 SOW btm, w/ 2- 2'’LPO Tubing head, Vetco FTC, 11 5M x 7 1/16 5M, w/ 2- 2 1/16 5M SSO, BG bottom prep Casing spool, Vetco-FC22, 11 5M FE x 11 5M , w/ 2- 2 1/16 5M EFO, 9'’ BG bottom prep 5 ½’’ 2 7/8'’ 3 1/8 5M dry hole cap Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 42B-05 (PTD 182-199) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/27/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42B-05 (PTD 182-199) Perf 08/18/2021 Please include current contact information if different from above. 11/02/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Coil + N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 11. Present Well Condition Summary: Total Depth measured 10,945 feet 5076; 5480; feet true vertical 10,900 feet N/A feet Effective Depth measured 5,070 feet N/A feet true vertical 5,057 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / L-80 6,800' MD 6,774' TVD Packers and SSSV (type, measured and true vertical depth)Baker FH Pkrs; N/A 10,199'; 10,272' MD 10,155'; 10,228' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 9,190psi Burst 7,740psi 92' 3,394' 6,890psi 3,130psi Collapse 1,580psi 4,790psi 8,830psi 5,280psi Casing Structural 20" 10-3/4" 7-5/8" Length 3,395' 10,438' 8,511' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 713' 0 10,897' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-061 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 182-199 50-133-20363-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 0 Soldotna Creek Unit (SCU) 42B-05 N/A FEDA 028996 10,438' Plugs Junk 92' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Sterling/Upper Beluga, Beluga and Tyonek Gas PoolsN/A measured TVD Tubing Pressure 0 Oil-Bbl measured true vertical Packer 5-1/2" 5-1/2" 8,511' 10,393' 8,472' 10. Field/Pool(s): Swanson River Field - WINJ WAG 0 Water-Bbl MD 92' 3,395' 10,943' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 8:53 am, Sep 03, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.02 16:20:30 -08'00' Taylor Wellman (2143) BJM 10/26/21 DSR-9/3/21 SFD 9/7/2021 RBDMS HEW 9/3/2021 Gas Rig Start Date End Date 3/11/21 8/18/21 Daily Operations: 03/16/2021 - Tuesday E-line arrives at facility, sign in, permits, JSA, PJSM. RIH W/ 1-11/16'' MSST W/ 2-7/8'' ALPHA cement retainer to ~6,770' WLM see collar. Spot/Pull up 5 ' above collar set retainer at 6,763' WLM. POOH. OOH. Rig down E-line. Begin rigging up tank for cementing returns. E-liner crew leaves location. Cementers arrive at location, Permits, JSA, PJSM. Begin rigging up to pump down tubing and accept returns up I.A. PT 250low/4,500high. Prove circulation 2 BPM at 500 PSI. Establish good returns while pumping water. Mix cement, pump 49BBLS cement at 4 BPM at 1,650 PSI. Drop ball, Pump total of 39.1 BBLS of displacement. 4 BPM at 1,550 PSI. Shut down. Pressure stabilizes at 1,170 PSI. Shut well in. Clean cement pumps. Cruz vac trucks (2) haul fluid returns/clean up fluid to G&I. Freeze protect Well, turn well site over to production operator. Crew leaves location. Slickline crew arrives at location, Starts equipment, sign in, PTW, JSA. Slickline finishes rigging down from previous well. Well head Specialist arrives and pulls BPV. Bottom of BPV was damaged allowing flow-through. Rig up Slickline. PT 250 low/2,000 high. RIH W/ 2.25'' x 4' DD bailer to tubing tail (~6,800' KB). Did not set down, but allow ~10' of tool string out of tubing tail. Pull up W/ straight overpull. WT several times to pull free. Discuss plan forward. Decided Just drift tubing/don't need to tag. POOH. Rig down from well. Move equipment to next well. 03/11/2021 - Thursday Slickline crew arrives at facility, sign in, PTW, JSA. PJSM. Snow removal around well. Spot equipment. Rig up SL. PT 250 psi low/ 2,000 psi high. Run # 1- RIH W /2.25'' x 4' DD bailer Will not pass hanger. POOH. Run # 2 - RIH W/ 2'' x 4' DD bailer. No pass. Run # 3 - RIH W/ 2.2'' LIB, 3 taps down. NO definitive marks/No pass. Run # 4 - RIH W/ 1'' x 2' prong. No depth change. Run # 5 - RIH W/ 1.75 LIB, 5 taps down. POOH W/ impression of BPV. Discuss plan forward. Rig down from well to drift/tag another well while they gather tools to pull BPV. Plan forward - Pull BPV tomorrow. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 42B-05 50-133-20363-00-00 182-199 3/10/21 - Wednesday Communicated to AOGCC concerning Sundry 321-061 specifying a passing MIT-IA to 1500 psi prior to continuing work. Communicated that we performed a passing MIT-IA back in August for the BLM. AOGCC did not require an additional test. 03/12/2021- Friday r set retainer at 6,763' WLM. pump 49BBLS cement at 4 BPM a Pump total of 39.1 BBLS of displacement. Communicated that we performed a passing MIT-IA back in August for the BLM. AOGCC did not require an additional test. Rig Start Date End Date 3/11/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 42B-05 50-133-20363-00-00 182-199 03/23/2021 - Tuesday Start equipment. Prep wellsite for job. Permits, JSA. Crew arrives, PJSM, mobilize equipment to well. Spot equipment, begin rig up to well. PT lubricator 250 low/ 2,500 high. RIH W/ Radial Bond Tool to 6,000' pull one pass to 5,000' @ 30 FPM. RIH to 6,766' (PBTD) Pull pass to 3,000' @ 30 FPM. POOH. Standby for data acquisition. Send data to town. Data is good, begin to swab. RIH W/2-7/8'' swab cups. Begin swabbing down fluid. Change cups as needed. Began pulling good pulls ~250-300ft of returns each run. As depth increased the amount returns slowly decreased. Slickline is pulling near maximum weight for .125" wire W/~50' returns. Progress slows through the night, at depth ~5,900' - continue swabbing next day. Perform MIT-IA to 1500 psi. Pre pumping: 4 psi, pressure up: 1721 psi, 15 min: 1706 psi, 30 min: 1697 psi, bleed down: 5 psi - pumped ~35 gal to pressure up, got back ~35 gal. PASS. Performed MIT-T to 1500 psi. Pre pumping 5 psi to 1777 psi for test, 5 min: 1776 psi, 10 min: 1775 psi, 15 min: 1774 psi, Bleed down: 4 psi – pump ~32 gal to pressure up, got back ~32 gal. PASS. 03/21/2021 - Sunday 03/19/2021- Friday Start equipment, Mobilize to well. Heater that was on the tree for freeze protect shut down. Got heater running again. Prepare for MIT on tubing. Pressure up on tubing from 5 psi to 1,777 psi for test, 5 min: 1,776 psi, 10 min: 1,775 psi, 15 min: 1,774 psi, Bleed down pressure. Area around well is congested due to ongoing work on pad. Rig down test equipment, Slickline begins to rig up to drift tubing. RIH W/2.26'' gauge ring to 4,973'WLM. WT, seems "sticky" POOH W/~200 pound extra. OOH W/gauge ring W/ wiper ball from Cement job wedged in gauge ring. RIH W/2.26'' gauge ring to 6,767'WLM. POOH. Re-rig tool string for running CBL. RIH W/memory CBL tools to 6,767' lightly tag bottom. Pick up tools, 2 minute stop. POOH @~30 FPM. OOH. Begin downloading CBL data, once downloaded send to town and await a response prior to swabbing down well. MIT I.A. while data is being downloaded. Pre pumping: 4 psi, pressure up: 1,721 psi, 15 min: 1,706 psi, 30 min: 1,697 psi, bleed down: 5 psi. RIH W/ 2-7/8'' swab mandrel W/ 2 cups. Swab down well to ~300' to freeze protect. Lay down Slickline lubricator. Crew released from location. 03/22/2021 - Monday Yellowjacket crew arrives at Swanson River facility. Permits, JSA, PJSM. Discuss scope of job and possible safety concerns due to congested area around well. Mobilize E-line equipment to well. Stage pressure test equipment. Begin rig up to run CBL. Town called: Previous CBL (memory on Slickline) was revised and is now good. RDMO E-line. E-line signs out and leaves location. Plan forward is have Swanson crew work on flowline today and swab well down tomorrow W/ slickline. RIH W/memory CBL tools to 6,767' RIH W/ Radial Bond Tool to 6,000' pull one pass to 5,000' Performed MIT-T to 1500 psi. Perform MIT-IA to 1500 psi. MIT I.A. while data is being downloaded. Rig Start Date End Date 3/11/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 42B-05 50-133-20363-00-00 182-199 03/24/2021 - Wednesday 03/26/2021- Friday Crew arrives at facility, Sign in, permits, JSA. Mobilize to well. Rig up E-line. PT 250psi low/ 3,500psi high. Jump gas from 42x-5 to pressure up tubing to desired pressure. RIH W/1-11/16'' x 7' GG W/2''x9' HC, 6SPF/60 deg. Make correlation pass. Send to town, No correction needed. Spot and shoot 6,073'-6,082'. POOH. WHP: shots fired: 1,336psi, 5 min: 1,335psi, 10 min: 1,329psi, 15 min: 1324psi. Fluid level is ~5,650'WLM. RIH W/1-11/16'' x 7' GG W/2'' x 6' HC, 6SPF/60 deg. Make correlation pass. Send to town, shift +1' correction needed. Spot and shoot 6,045'-6,051'. POOH. WHP: shots fired: 1,301psi, 5 min: 1,307psi, 10 min: 1,309psi, 15 min: 1,297psi. Small amount of dehydrated mud/cement on gun. RIH W/1-11/16'' x 7' GG W/2''x9' HC, 6 SPF/60 deg. Make correlation pass. Send to town, shift +2 correction needed. Spot and shoot 5,647'-5,656'. POOH. OOH, change out Gammaray. WHP: shots fired: 1306psi, 5 min: 1,306psi, 10 min: 1,303psi, 15 min: 1,300psi. Fluid level is ~5,520'WLM. RIH W/1-11/16'' x 7' GG W/2'' x 7' HC, 6SPF/60 deg. Make correlation pass. Send to town, No correction needed. Spot and shoot 5,532'-5,539'. POOH. WHP: shots fired: 1,298psi, 5 min: 1,300psi, 10 min: 1,299psi, 15 min: 1,296psi. E-line rigged down Move out, secure well. Turn well over to production. Crew leaves field. 04/06/2021 - Tuesday Crew arrives at location. Permits, JSA, jobscope. Standby for PT equipment. PT Lubricator 250psi/3,500psi. RIH WITH 2-7' 1-11/16" WB, 1-11/16" GPT AND 1-11/16" MSST WITH 2.10" CIBP FOR 2-7/8" TUBING. RUN GPT TO FIND FLUID LEVEL, RAN DOWN TO 5,540' - FOUND NO FLUID. Make correlation pass/send to town. +1' correction. Spot and set plug (5,482'). POOH RIH WITH 1-11/16" CCL AND 30' OF 2" BAILOR. DUMP CEMENT ON TOP OF PLUG AT 5,482'. POOH RIH WITH 1-11/16" CCL AND 30' OF 2" BAILER. DUMP CEMENT ON TOP OF PLUG. DUMPED AT 5,447' POOH - 8.5 GALLONS CEMENT total dumped. Lay down lubricator for the night. Turn in permits. Sign out and leave facility. Continue swabbing fluid from well, swab down to 6,210'. Made 48 pulls to get to depth. Yellowjacket rigs up to begin perforating. RIH W/1-11/16'' ss W/2'' x 14' HC 6 SPF/60 degree. Make correlation pass, send to town. Add 2' spot and shoot 6,429'-6,443'. WHP perf: 2,015psi, 5 min: 2,020psi, 10 min: 2,010psi, 15 min: 1,997psi. POOH, all shots fired, small amount of fine sand/mud on barrel in a few spots near ports. Bleed pressure to ~1,500 psi. RIH W/1-11/16'' ss W/2'' x 19'' HC 6 SPF/60 degree. Make correlation pass. Send to town. Add 1' spot and shoot 6,347'-6,366'. WHP perf: 1,500psi, 5 min: 1,498psi, 10 min: 1,492psi, 15 min: 1,479psi, all shots fired, no sand/mud. RIH W/1-11/16'' ss W/2'' x 13' HC 6 SPF/60 degree. Make correlation pass. send to town. shift -1' spot and shoot 6,106'-6,119'. POOH all shots fired, no sand/mud on barrel. E-line rigs down equipment, mobilizes equipment. Turn well over to production. DUMP CEMENT ON TOP OF PLUG AT 5,482' set plug (5,482'). DUMPED AT 5,447' POOH - 8.5 GALLONS CEMENT total dumped. Spot and shoot 6,045'-6,051' DUMP CEMENT ON TOP OF PLUG. shoot 5,532'-5,539' Spot and shoot 6,073'-6,082' shoot 6,429'-6,443' shoot 6,347'-6,366' shoot 6,106'-6,119' shoot 5,647'-5,656'. Rig Start Date End Date 3/11/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 42B-05 50-133-20363-00-00 182-199 Crew arrives at location. Permits, JSA, TGSM. Rig up lubricator. PT 250 low/ 2,500 high. RIH Gun #1 (2-1/8" Spiral Strip x 7') (CCL-TS=15.3'), make correlation pass, send to town. No depth correction needed. Spot and shoot (4,633'-4,640'). Good break/weight loss. POOH. OOH gun was dry. WHP pre: 1,404, 5 min. 1,406, 10 min. 1,408, 15 min 1,410. RIH Gun #2 ( 2-1/8" x 9') (CCL-TS=15.3') (Opening- 1,420 psi). Make correlation pass, send to town. No depth correction needed. Spot and shoot 4,596'-4,605'. Weight loss/good break, POOH. WHP pre: 1,390, 5 min. 1,402, 10 min. 1,404, 15 min 1,401. Rig down, turn well over to production, sign out and leave facility. Crew arrives at location, Permits, JSA, jobscope. Rig up E-line. PT lubricator. RIH WITH 7' 1-11/16" WB, 1-11/16" GG, 1- 11/16" SS AND 10' OF 2" RAZOR 6/60 MAKER CORRELATION PASS. PROPOSED PERF DEPTH = 5,413' TO 5,423' NO DEPTH CORRECTION NEEDED. SPOT AND SHOOT. POOH. WHP: SHOTS: 1,303, 5 MIN: 1,305, 10 MIN: 1,306, 15 MIN: 1,298. GUN CAME BACK DRY. RIH WITH 7' 1-11/16" WB, 1-11/16" GG, 1-11/16" SS AND 7' OF 2" RAZOR 6/60 MAKER CORRELATION PASS. SEND TO TOWN. PROPOSED PERF DEPTH = 5,330'-5,327' +1' CORRECTION NEEDED. SPOT AND SHOOT. POOH. WHP: SHOTS: 1,316, 5 MIN: 1318, 10 MIN: 1,315, 15 MIN: 1,314. GUN CAME BACK DRY RIH WITH 7' 1-11/16" WB, 1- 11/16" GG, 1-11/16" SS AND 5' OF 2" RAZOR 6/60 MAKER CORRELATION PASS. SEND TO TOWN. PROPOSED PERF DEPTH = 5,303'-5,308' +1' CORRECTION NEEDED. SPOT AND SHOOT. POOH. WHP: SHOTS: 1,319, 5 MIN: 1,320, 10 MIN: 1,317, 15 MIN: 1,308. GUN CAME BACK DRY RIH WITH 7' 1-11/16" WB, 1-11/16" GG, 1-11/16" SS AND 17' OF 2" RAZOR 6/60 MAKE CORRELATION PASS. SEND TO TOWN. PROPOSED PERF DEPTH = 5,079'-5,096' NO CORRECTION NEEDED. SPOT AND SHOOT. ~400 POUND OVERPULL AFTER SHOTS FIRED POOH. WHP: SHOTS: 1,322, 5 MIN: 1,324, 10 MIN: 1,322, 15 MIN: 1,322 . OOH. GUN HAD SMALL AMOUNT OF SAND/ MUD ON BARREL. GUN CAME BACK DRY RIG DOWN E-LINE, SECURE WELL, TURN OVER TO PRODUCTION. CREW LEAVES FIELD. 04/14/2021 - Wednesday Crew arrives at facility. Sign in, jobscope, PJSM Rig up E-line. PT 250low/3,000high. RIH WITH 7' 1-11/16" WB, 1-11/16" GG AND 5' OF 2" RAZOR 6 SPF/60 DEG. MAKE CORRELATION PASS. SEND TO TOWN. NO CORRECTION NEEDED. SPOT AND SHOOT 5,055'-5,060'. POOH. WHP: PRE: 1,293, 5 MIN: 1,325, 10 MIN: 1,350, 15 MIN: 1,386. TURN WELL OVER TO PRODUCTION. STANDBY AND WAIT FOR INSTRUCTIONS FROM TOWN. RIH WITH 2-7' 1-11/16" WB, 1-11/16" GPT. SAT DOWN @ 5,376' - SUMP 5,230'. GPT1 PASS 1 FROM SURFACE TO 5,376', GPT1 PASS 2 FROM 4,800' TO 5,376' SEND LOG TO TOWN. RDMO E-LINE. CONTINUE TO FLOW WELL AT CONSISTENT RATE. CREW LEAVES FACILITY. 07/23/2021- Friday Crew arrives at Swanson River. Permits, TGSM, job scope. Spot equipment, Rig up to well. PT 250 low/ 2,500 high. RIH for Drift Run (7'WB, GPT, Spangs, 2.26" GR) to 5,200'. Made it down through perfs with no issues / Pull Fluid Level Pass. fluid 4,970'. RIH 2.10" CIBP. Make correlation pass. Send to town. No depth correction required. Spot and set plug at 5,076'. ~ 100 pound weight loss. POOH. OOH. Bleed tubing for negative test, mix cement and rig up for cement run. RIH W/2.5 gallons in 20' of 2" Bailer to 5,070'. Dump cement. Good break no weight loss. POOH. Lay down lubricator for night. Crew signs out and leaves facility. 07/24/2021 - Saturday 04/07/2021 - Wednesday PROPOSED PERF DEPTH = 5,330'-5,327' +1' CORRECTION NEEDED. SPOT AND SHOOT. PROPOSED PERF DEPTH = 5,303'-5,308' +1' CORRECTION NEEDED. SPOT AND SHOOT. shoot (4,633'-4,640' F DEPTH =5,413' TO 5,423' NO DEPTH CORRECTION NEEDED. SPOT AND SHOOT. shoot 4,596'-4,605' RIH W/2.5 gallons in 20' of 2" Bailer to 5,070'. Dump cement. SHOOT 5,055'-5,060' RIH 2.10" CIBP. set plug at 5,076'. ~ PROPOSED PERF DEPTH = 5,079'-5,096' NO CORRECTION NEEDED. SPOT AND SHOOT. Rig Start Date End Date 3/11/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 42B-05 50-133-20363-00-00 182-199 08/18/2021 - Wednesday Crew arrives at facility, JSA Permits. Rig up E-line. RIH WITH 2 1-11/16" 7' WB, 1-11/16" GG AND 12' OF 2-1/8" SPIRAL STRIP GUN, 7.5' FROM CCL TO TOP SHOT, PROPOSED PERF @ 4,931' TO 4,943'. TAG FILL @ 4,840'. MAKE CORRELATION PASS. SEND TO TOWN. DISCUSS OPTIONS. DECIDE TO SHOOT 4,827.5' - 4,839.5'. NO CORRECTION NEEDED. SPOT AND SHOOT 4,827.5' - 4,839.5'. GOOD BREAK, WEIGHT LOSS. POOH. PRE: 1,679psi, SHOTS -1,655 psi, 10-1,652 psi, 15-1,645 psi. RIH WITH 2 1-11/16" 7' WB, 1-11/16" GG AND 9' OF 2-1/8" SPIRAL STRIP GUN, 9.5' FROM CCL TO TOP SHOT, MAKE CORRELATION PASS. SEND TO TOWN, NO CORRECTION NEEDED. SPOT AND SHOOT 4,802' TO 4,811' POOH. OOH, RIGGED DOWN E-LINE SECURE WELL TURN OVER TO PRODUCTION. SHOOT 4,802' TO 4,811' SHOOT 4,827.5' - 4,839.5' Updated by DMA 08-27-21 SCHEMATIC Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00-00 PBTD = 5,070’ MD / 5,057’ TVD TD = 10,945’ MD / 10,899’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” 84 - - 92’ 10-3/4” 40.5 K-55 - Surface 3,395’ 7-5/8” 39 L-80 FL4S 6.625” Surface 1,542’ 7-5/8” 33.7 L-80 FL4S 6.765” 1,542’ 3,512’ 7-5/8” 29.7 L-80 FL4S 6.875” 3,512’ 4,611’ 7-5/8” 33.7 SS-95 LT&C 6.765” 4,611’ 7508’ DV Collar 7508’ 7510’ 7-5/8” 33.7 SS-95 LT&C 6.765” 7510’ 8,338’ 7-5/8” 39 SS-95 LT&C 6.625” 8,338’ 10,438’ Liner 5-1/2” 17 N-80 Hyd 513 4.892” Surf 8511’ 5-1/2” 20 N-80 4.778” 10,230’ 10,943’ Tubing 2-7/8 ” 6.4 L-80 IBT 2.441” Surf 6,800’ 3-1/2 ” 9.3 N-80 8RD EUE 2.992” 9500’ 10,290’ 2-3/8” 1.995” 10,290’ 10,308’ JEWELRY DETAIL NO. TM Depth Length ID OD Item A 18’ - - Tubing Hanger B 5,076’ CIBP with 4’ Cement – TOC @ 5,070’ - 7/23/21 C 5,480’ 32’ - - CIBP with 35’ Cement Cap – TOC @ 5,445’ – 4/6/21 D 6,763’ 1’ 2.441 - 2-7/8” Cement Retainer – 3/16/21 E 7,744' 4.00' 2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 F 7,758' 5.85' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s G 7,773' 1.08' 2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go H 7,775' 2.61' 2.441 3.70 Slotted Circ/Debris Sub w/ XO I 7,808' 1.00' 2.441 3.70 WLEG (Post gun Release) J 8,345' 3.31' 2.441 3.70 BHF-C Firing Head 8,348' 4.14' 3.50 SXAR Gun Drop Sub 8,352' 26.68' 3.50 Safety Spacer 8,379' 15.00' 3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394' 0.56' 3.50 Bull Nose 10,199’ 7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’ 2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’ 5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’ 2-3/8” Baker Shear Sub PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Ft Date Comments UB 47-0 4,596' 4,605' 4,587’ 4,596’ 9' 7/24/2021 2-1/8” Spiral UB 47-0 4,633' 4,640' 4,624’ 4,631’ 7' 7/24/2021 2-1/8” Spiral UB 50-6 4,802' 4,811' 4,791’ 4,800’ 9' 8/18/2021 2-1/8” Spiral UB 50-6 4,828' 4,840' 4,817’ 4,829’ 12' 8/8/2021 2-1/8” Spiral LB51-1 5,055' 5,060' 5,043’ 5,048’ 5’ 4/14/2021 2” Razor - Isolated LB51-1 5,079' 5,096' 5,066’ 5,083’ 17’ 4/7/2021 2” Razor - Isolated LB51-1 5,303' 5,308' 5,289’ 5,294’ 5’ 4/7/2021 2” Razor - Isolated LB52-9 5,330' 5,337' 5,316’ 5,322’ 7’ 4/7/2021 2” Razor - Isolated LB52-9 5,413' 5,423' 5,398’ 5,408’ 10’ 4/7/2021 2” Razor - Isolated TY54-1 5,532' 5,539' 5,516’ 5,523’ 7’ 3/26/2021 2” Razor - Isolated TY55-4 5,647' 5,656' 5,630’ 5,639’ 9’ 3/26/2021 2” Razor - Isolated TY61-0 6,045' 6,051' 6,025’ 6,031’ 6’ 3/26/2021 2” Razor - Isolated TY61-0 6,073' 6,082' 6,053’ 6,062’ 9’ 3/26/2021 2” Razor - Isolated TY61-0 6,106' 6,119' 6,086’ 6,099’ 13’ 3/24/2021 2” Razor - Isolated TY62-3 6,347' 6,366' 6,325’ 6,344’ 19’ 3/24/2021 2” Razor - Isolated TY62-3 6,429' 6,443' 6,406’ 6,420’ 14’ 3/24/2021 2” Razor - Isolated T77-3 7,861’ 7,876’ 7,827’ 7,842’ 15’ 6/4/2006 Isolated H1 10,450’ 10,462’ 10,405’ 10,417’ 12’ 10/14/2005 Isolated H3 10,466’ 10,478’ 10,421’ 10,433’ 8’ 10/14/2005 Isolated H4 10,515’ 10,527’ 10,470’ 10,482’ 12’ 10/14/2005 Isolated H5 10,530’ 10,585’ 10,485’ 10,540’ 55’ 10/14/2005 Isolated H7 10,614’ 10,632’ 10,569’ 10,587’ 18’ 10/14/2005 Isolated 10,638’ 10,652’ 10,593’ 10,607’ 14’ 10/14/2005 Isolated 10,658’ 10,666’ 10,613’ 10,621’ 8’ 10/14/2005 Isolated 10,672’ 10,686’ 10,627’ 10,641’ 14’ 10/14/2005 Isolated 10,745’ 10,759’ 10,700’ 10,714’ 14’ 10/14/2005 Isolated 10,763’ 10,772’ 10,718’ 10,727’ 9’ 10/14/2005 Isolated 10,787’ 10,792’ 10,742’ 10,747’ 3’ 10/14/2005 Isolated 10,796’ 10,802’ 10,751’ 10,757’ 6’ 10/14/2005 Isolated p p UB 47-0 4,596' 4,605' 4,587’4,596’9' 7/24/2021 2-1/8” Spiral UB 47-0 4,633' 4,640' 4,624’4,631’7' 7/24/2021 2-1/8” Spiral UB 50-6 4,802' 4,811' 4,791’4,800’9' 8/18/2021 2-1/8” Spiral UB 50-6 4,828' 4,840' 4,817’4,829’12' 8/8/2021 2-1/8” Spiral LB51-1 5,055' 5,060' 5,043’5,048’5’4/14/2021 2” Razor - Isolated LB51-1 5,079' 5,096' 5,066’5,083’17’4/7/2021 2” Razor - Isolated LB51-1 5,303' 5,308' 5,289’5,294’5’4/7/2021 2” Razor - Isolated LB52-9 5,330' 5,337' 5,316’5,322’7’4/7/2021 2” Razor - Isolated LB52-9 5,413' 5,423' 5,398’5,408’10’4/7/2021 2” Razor - Isolated TY54-1 5,532' 5,539' 5,516’5,523’7’3/26/2021 2” Razor - Isolated TY55-4 5,647' 5,656' 5,630’5,639’9’3/26/2021 2” Razor - Isolated TY61-0 6,045' 6,051' 6,025’6,031’6’3/26/2021 2” Razor - Isolated TY61-0 6,073' 6,082' 6,053’6,062’9’3/26/2021 2” Razor - Isolated TY61-0 6,106' 6,119' 6,086’6,099’13’3/24/2021 2” Razor - Isolated TY62-3 6,347' 6,366' 6,325’6,344’19’3/24/2021 2” Razor - Isolated TY62-3 6,429' 6,443' 6,406’6,420’14’3/24/2021 2” Razor - Isolated Sand Top MD Btm MD Top TVD Btm TVD Ft Date Comments ,,,, 1 Winston, Hugh E (CED) From:Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent:Tuesday, April 6, 2021 7:22 AM To:Davies, Stephen F (CED); McLellan, Bryan J (CED) Cc:Meredyth Richards; Jeff Nelson - (C); Roby, David S (CED) Subject:RE: [EXTERNAL] RE: SCU 42B-05 (PTD 182-199; Sundry 321-061) Beluga Pool Perforations Hi Steve, Acknowledged, thank you for the response and clarification. Todd From: Davies, Stephen F (CED) [mailto:steve.davies@alaska.gov] Sent: Monday, April 5, 2021 4:31 PM To: Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Meredyth Richards <Meredyth.Richards@hilcorp.com>; Jeff Nelson ‐ (C) <Jeff.Nelson@hilcorp.com>; Roby, David S (CED) <dave.roby@alaska.gov> Subject: [EXTERNAL] RE: SCU 42B‐05 (PTD 182‐199; Sundry 321‐061) Beluga Pool Perforations Todd, In addition to my email below, to ensure clarity: Since CO 716 as modified by CO 716.001 doesn’t address commingling between pools, Hilcorp can’t commingle production from the Beluga Gas Pool with production from the overlying Sterling/Upper Beluga Gas Pool without additional permission from AOGCC. Thanks again and stay safe, Steve Davies AOGCC 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. From: Davies, Stephen F (CED) Sent: Monday, April 5, 2021 4:03 PM To: Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Meredyth Richards <Meredyth.Richards@hilcorp.com>; Jeff Nelson ‐ (C) <Jeff.Nelson@hilcorp.com>; Roby, David S (CED) <dave.roby@alaska.gov> Subject: RE: SCU 42B‐05 (PTD 182‐199) Beluga Pool Perforations Todd, Thank you for your update and explanation. The approved form for Sundry Application No. 321‐061 correctly lists the Sterling/Upper Beluga, Beluga, and Tyonek Gas Pools as those pools that will be affected by Hilcorp’s operations. CO 716.001 recognizes that the shallowest defined gas pool (Sterling/Upper Beluga Gas Pool) encompasses reservoir sands assigned to both the uppermost Beluga and the overlying Sterling formations. 2 Thanks again and stay safe, Steve Davies AOGCC 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. From: Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com> Sent: Monday, April 5, 2021 2:40 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Cc: Meredyth Richards <Meredyth.Richards@hilcorp.com>; Jeff Nelson ‐ (C) <Jeff.Nelson@hilcorp.com> Subject: SCU 42B‐05 (PTD 182‐199) Beluga Pool Perforations Hello Stephen and Bryan, I was looking at the approved Sundry for SCU 42‐05B and noticed that the Upper Beluga/Sterling and Beluga perforation intervals were not associated with the correct pools as indicated by your mark‐up. I suspect that this is due to the naming convention that is in place for these zones, many of them are called “Upper Beluga XX‐X” but are actually in the Beluga pool. Below is a note from Jeff Nelson, our geologist. At Swanson River in well SCU 42B‐05, we are currently working on setting a plug with a cement cap to plus off and isolate the perforations that have been shot in the Tyonek Gas Pool. After the plug + cement, we will proceed with perforating sundried intervals in the Beluga Pool. The Beluga Pool corresponds to all intervals that correlate with the interval 4,609’ MD to 5,304’ MD in the Soldotna Creek Unit 41‐4 well (per AOGCC CO 716.001). In our naming convention, 4,609’ MD in SCU 41‐4 (top Beluga Pool) correlates to the UB 50‐6 well pick. In our naming convention, 5,304’ MD in SCU 41‐4 (base Beluga Pool) correlates to the Tyonek well pick. The next perforations planned in SCU 42B‐05 are in the Beluga Pool and begin in the LB 52‐9 interval. Sundried intervals continue in the Beluga Pool up through the UB 50‐8 and UB 50‐6. The final sundried interval, the UB 47‐0, fall within the Sterling / Upper Beluga Pool. Please let me know if you have any questions or concerns. Thanks, Todd Todd Sidoti | Kenai Ops Engineer | Hilcorp Alaska | 907‐632‐4113 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: SCU 42B-05 Perf & Plug (PTD 182-199) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 9:10 am, Aug 26, 2021 David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company SCU 42B-05 50133203630000 182199 3/16/2021 CCL - SET RETAINER Yellowjacket SCU 42B-05 50133203630000 182199 3/24/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 3/26/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 4/6/2021 SET PLUG / GPT Yellowjacket SCU 42B-05 50133203630000 182199 4/14/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. PTD: 1821990 E-Set: 35200 06/02/2021 David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company SCU 42B-05 50133203630000 182199 3/16/2021 CCL - SET RETAINER Yellowjacket SCU 42B-05 50133203630000 182199 3/24/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 3/26/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 4/6/2021 SET PLUG / GPT Yellowjacket SCU 42B-05 50133203630000 182199 4/14/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. PTD: 1821990 E-Set: 35199 06/02/2021 David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company SCU 42B-05 50133203630000 182199 3/16/2021 CCL - SET RETAINER Yellowjacket SCU 42B-05 50133203630000 182199 3/24/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 3/26/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 4/6/2021 SET PLUG / GPT Yellowjacket SCU 42B-05 50133203630000 182199 4/14/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. PTD: 1821990 E-Set: 35198 06/02/2021 David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company SCU 42B-05 50133203630000 182199 3/16/2021 CCL - SET RETAINER Yellowjacket SCU 42B-05 50133203630000 182199 3/24/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 3/26/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 4/6/2021 SET PLUG / GPT Yellowjacket SCU 42B-05 50133203630000 182199 4/14/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. PTD: 1821990 E-Set: 35197 06/02/2021 David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/27/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company SCU 42B-05 50133203630000 182199 3/16/2021 CCL - SET RETAINER Yellowjacket SCU 42B-05 50133203630000 182199 3/24/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 3/26/2021 PERF GAMMA RAY Yellowjacket SCU 42B-05 50133203630000 182199 4/6/2021 SET PLUG / GPT Yellowjacket SCU 42B-05 50133203630000 182199 4/14/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. PTD:1821990 E-Set: 35196 06/02/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42B-05 (PTD 182-199) MRCBL Memory Radial Cement Bond Log Run2 03/23/2021 Please include current contact information if different from above. PTD: 1821990 E-Set: 34842 Received by the AOGCC 03/30/2021 03/30/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 03/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 42B-05 (PTD 182-199) MRCBL Memory Radial Cement Bond Log 03/19/2021 Please include current contact information if different from above. PTD: 1821990 E-Set: 34841 Received by the AOGCC 03/30/2021 03/30/2021 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: Coil + N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,899'N/A Casing Collapse Structural Conductor Surface 1,580psi Intermediate 4,790psi Production 6,280psi Liner 8,830psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: February 20, 2021 10,943'713' 2-7/8" 10,897' 8,511' Perforation Depth MD (ft): 10,438' See Attached Schematic 8,511' 5-1/2" 8,472'5-1/2" 20" 10-3/4" 92' 7-5/8"10,438' 3,395'3,130psi 92' 3,394' 10,393' 92' 3,395' 6.4# / L-80 TVD Burst 6,800' 7,740psi MD 6,890psi Length Size CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028996 182-199 50-133-20363-00-00 Soldotna Creek Unit (SCU) 42B-05 Swanson River Field / Sterling/Upper Beluga, Beluga and Tyonek Gas Pools COMMISSION USE ONLY Authorized Name: 9,190psi Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 7,082'7,082'7,054'2,749 7,082' N/A; N/A N/A; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:52 pm, Jan 28, 2021 321-061 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.27 17:10:34 -09'00' Taylor Wellman SFD 1/28/2021 2,749 * CBL required before perforating well. Re-enter Susp Well GAS SFD 1/28/2021 10,900 Development *Tyonek , Upper Beluga and Lower Beluga may not be commingled 10-404 10,945 cement packer SFD 1/28/2021 CO 716 & Coil + N2 gls 2/9/21 Perforate DSR-2/9/21C on Required? Yes 2/10/21 dts 2/9/2021 JLC 2/9/2021 RBDMS HEW 2/11/2021 Well Prognosis Well: SCU 42B-05 Date: 1/14/2021 Well Name: SCU 42B-05 API Number: 50-133-20363-00-00 Current Status: Shut In Gas Producer Leg: N/A Estimated Start Date: 12/15/2020 Rig: Fullbore / Eline Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 182-199 First Call Engineer: Todd Sidoti (907) 777-8443 (907) 632-4113 (C) Second Call Engineer: Jake Flora (907) 777-8442 (720) 988-5375 (C) AFE Number: Max. Expected BHP: ~ 3,054 psi @ 7,053’ TVD (Based on normal gradient) Max. Potential Surface Pressure: ~ 2,749 psi (Based on expected BHP and gas gradient to surface (0.10psi/ft)) Brief Well Summary SCU 42B-05 was drilled in 1983 as an oil well targeting Hemlock H-10. After producing 1.4 MMBO over 20+ years, work was progressed in 2005 to convert the well Tyonek 77-3 gas storage, however, the conversion was cancelled when a micro-annulus developed between the liner and casing. The 77-3 sand was shortly thereafter isolated and a kill string was installed. The well remained in suspended status until 2019 when a version of this workover for Tyonek and Beluga gas was first proposed. Budget constraints ended up bumping the project. Given that the subsurface situation at SCU 43B-05 has not changed and an ambitious 2021 gas target for the Kenai team, it is now worthwhile to execute this work. Objective The purpose of this work/sundry is to cement the kill string in place and add Tyonek, Lower Beluga and Upper Beluga intervals and RTP. Notes Regarding Wellbore Condition x Vertical well. x 7-5/8” string cemented through DV tool with cement returns to surface and some losses. CBL shows cement in place up to surface casing shoe. x 5.5” scab liner shows good cement bond up to the top logged interval, 5440’. 140 bbls of cement were circulated into the 7-5/8” x 5.5” annulus which volumetrically places TOC at surface. x Kill string was in good condition when installed in 2006 per Tuboscope inspection report. E-line 1. RU E-line, PT lubricator to 250 psi low & 3500 psi high. 2. RIH with junk basket / gauge ring and drift to end of tubing for retainer. 3. RIH with 2-7/8” poppet style cement retainer and set 30’ above end of tubing (~6770’). Fullbore 1. MIRU cementers & pressure test surface lines to 250 psi low / 4500 psi high. 2. Establish circulation down the tubing and up the IA with lease water. a. Notify OE if circulation rate is less than 2 bpm @ 3000 psi. 3. Mix and pump 60 bbls of 15.3 ppg cement slurry down tubing. 4. Swap to water, drop wiper ball and chase to EOT with 40 bbls water. 5. At 40 bbls away stop displacing and check tubing pressure. Pressure should read zero if the check in the retainer is holding, if not there should be approximately 1350 psi on the tubing. 6800 - 3000 ft = 57 bbls (send chart to AOGCC) set retainer cement tubing MIT- casing to 1500 psi (5.5" scab) 30 min/Chart 2 7/8" x 5 1/2" = .0152 bbl/ft " TOC target is 3000 ft 200ft x .0232 = 4.6 bbls Well Prognosis Well: SCU 42B-05 Date: 1/14/2021 6. Shut in well with both master valves to trap pressure. 7. RDMO cementers. 8. WOC minimum of 3 days. 9. MIT-IA to 1500 psi for 30 minutes charted. Send results to OE. Slickline 1. MIRU slickline. 2. Log memory CBL from TD to surface. 3. Swab well down to 6500’. 4. RDMO slickline. Contingent steps if unable to swab well down: 1. MIRU CT unit. Pressure test BOPE to 250 psi low / 4000 psi high. a. Notify AOGCC/BLM 48 hours ahead of time to extend opportunity to witness. b. Send completed BOP test form to the AOGCC within 5 days. 2. MIRU N2 unit. a. Ensure that standard nitrogen procedure is reviewed during PJSM. 3. RIH with BHA including nozzle and blow well dry with N2. 4. RDMO CT & N2. E-line 1. RU E-line, PT lubricator to 250 psi low & 3500 psi high. 2. Perforate the below zones from the bottom up with 2-1/8” Shogun Spiral guns: a. Final perforation intervals will be provided prior to loading guns for exact depths. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Meredyth Richards), and Geologist (Jeff Nelson) for confirmation. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and 5, 10 & 15 minutes after each perforating run. d. Tyonek, Lower Beluga and Upper Beluga pools may not be co-mingled. 3. RD E-Line. Zone Sand Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Amt. # Potential Sands Upper Beluga 47-0 +4,525’ +4,645’ +4,516’ +4,635’ 120 2 Upper Beluga 50-6 +4,793’ +4,900’ +4,783’ +4,889’ 107 3 Upper Beluga 50-8 +4,924’ +4,950’ +4,912’ +4,938’ 26 1 Upper Beluga 50-8 +5,045’ +5,065’ +5,033’ +5,052’ 20 1 Upper Beluga 50-8 +5,070’ +5,100’ +5,057’ +5,087’ 30 1 Upper Beluga 50-8 +5,300’ +5,286’ +5,315’ +5,300’ 15 1 Lower Beluga 52-9 +5,328’ +5,340’ +5,323’ +5,325’ 12 1 Lower Beluga 52-9 +5,405’ +5,430’ +5,390’ +5,415’ 25 1 Tyonek 53-0 +5,530’ +5,541’ +5,514’ +5,525’ 11 1 Tyonek 55-4 +5,645’ +5,658’ +5,628’ +5,641’ 13 1 Tyonek 56-9 +5,824’ +5,900’ +5,805’ +5,881’ 76 3 Tyonek 61-0 +6,038’ +6,200’ +6,018’ +6,179’ 162 2 Tyonek 62-3 +6,345’ +6,444’ +6,323’ +6,420’ 99 2 (leave trapped pressure ?) UB Ty LB SFD 1/28/2021 5315 Notification not ( forward CBL to AOGCC for review before perforating.) ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------ Tyonek, Lower Beluga and Upper Beluga pools may not be co-mingled. NOTE: required if SLB CTU ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- MIT-T for 15 min / 1500 psi CBL 5286 Well Prognosis Well: SCU 42B-05 Date: 1/14/2021 4. Turn well over to production. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) Contingent steps if any zone produces water and requires isolation: 1. MIRU N2 unit. a. Ensure that standard nitrogen procedure is reviewed during PJSM. 2. RIH with GPT tool and depress fluid into perfs with N2. 3. RIH and set 3-1/2” CIBP above the zone and dump 35’ of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. CTU BOP Schematic 4. Standard Well Procedure – N2 Operations Updated by TCS 1-14-21 SCHEMATIC Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00 PBTD = 7,082’ MD / 7,054’ TVD TD = 10,945’ MD / 10,899’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” 84 - - 92’ 10-3/4” 40.5 K-55 - Surface 3,395’ 7-5/8” 39 L-80 FL4S 6.625” Surface 1,542’ 7-5/8” 33.7 L-80 FL4S 6.765” 1,542’ 3,512’ 7-5/8” 29.7 L-80 FL4S 6.875” 3,512’ 4,611’ 7-5/8” 33.7 SS-95 LT&C 6.765” 4,611’ 7508’ DV Collar 7508’ 7510’ 7-5/8” 33.7 SS-95 LT&C 6.765” 7510’ 8,338’ 7-5/8” 39 SS-95 LT&C 6.625” 8,338’ 10,438’ Liner 5-1/2” 17 N-80 Hyd 513 4.892” Surf 8511’ 5-1/2” 20 N-80 4.778” 10,230’ 10,943’ Tubing 2-7/8 ” 6.4 L-80 IBT 2.441” Surf 6,800’ 3-1/2 ” 9.3 N-80 8RD EUE 2.992” 9500’ 10,290’ 2-3/8” 1.995” 10,290’ 10,308’ JEWELRY DETAIL NO. TM Depth Length ID OD Item 18’ - - Tubing Hanger B. 6800’ 6800’ 2.441 Kill String – 2-7/8” tbg 7703’ Tbg Cut 7,707' 30.50' 2.441 (1) Joint of 2-7/8" tbg w/ TC II 7,738' 5.75' 2.441 6’ x 2-7/8" Pup Joint w/ TC II BxP C. 7,744' 4.00' 2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 7,748' 9.74' 2.441 10’ x 2-7/8" Pup Joint w/ TC II BxP D. 7,758' 5.85' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s 7,763' 3.76' 2.441 4’ x 2-7/8" Pup Joint w/ TC II BxP 7,767' 5.75' 2.441 6’ x 2-7/8" Pup Joint w/ TC II BxP E. 7,773' 1.08' 2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go 7,775' 2.61' 2.441 3.70 Slotted Circ/Debris Sub w/ XO 7,776' 32.00' 2.441 (1) Joint of 2-7/8" tbg w/ 8rd BxP F. 7,808' 1.00' 2.441 3.70 WLEG (Post gun Release) G. 8,345' 3.31' 2.441 3.70 BHF-C Firing Head 8,348' 4.14' 3.50 SXAR Gun Drop Sub 8,352' 26.68' 3.50 Safety Spacer 8,379' 15.00' 3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394' 0.56' 3.50 Bull Nose 10,199’ 7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’ 2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’ 5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’ 2-3/8” Baker Shear Sub PERFORATION DETAIL FROM TO Length Interval Date Description 7861 7876 15’ 77-3 06/04/06 Isolated 10450 10462 12’ H 10/14/05 Isolated 10466 10478 8’ H 10/14/05 Isolated 10515 10527 12’ H4 10/14/05 Isolated 10530 10585 55’ H5 10/14/05 Isolated 10614 10632 18’ H 10/14/05 Isolated 10638 10652 14’ H 10/14/05 Isolated 10658 10666 8’ H 10/14/05 Isolated 10672 10686 14’ H 10/14/05 Isolated 10745 10759 14’ H 10/14/05 Isolated 10763 10772 9’ H 10/14/05 Isolated 10787 10792 3’ H 10/14/05 Isolated 10796 10802 6’ H 10/14/05 Isolated 2 7/8" Kill string Updated by TCS 1-14-21 PROPOSED SCHEMATIC Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00 PBTD = 7,082’ MD / 7,054’ TVD TD = 10,945’ MD / 10,899’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” 84 - - 92’ 10-3/4” 40.5 K-55 - Surface 3,395’ 7-5/8” 39 L-80 FL4S 6.625” Surface 1,542’ 7-5/8” 33.7 L-80 FL4S 6.765” 1,542’ 3,512’ 7-5/8” 29.7 L-80 FL4S 6.875” 3,512’ 4,611’ 7-5/8” 33.7 SS-95 LT&C 6.765” 4,611’ 7508’ DV Collar 7508’ 7510’ 7-5/8” 33.7 SS-95 LT&C 6.765” 7510’ 8,338’ 7-5/8” 39 SS-95 LT&C 6.625” 8,338’ 10,438’ Liner 5-1/2” 17 N-80 Hyd 513 4.892” Surf 8511’ 5-1/2” 20 N-80 4.778” 10,230’ 10,943’ Tubing 2-7/8 ” 6.4 L-80 IBT 2.441” Surf 6,800’ 3-1/2 ” 9.3 N-80 8RD EUE 2.992” 9500’ 10,290’ 2-3/8” 1.995” 10,290’ 10,308’ JEWELRY DETAIL NO. TM Depth Length ID OD Item 18’ - - Tubing Hanger B 6770’ 1’ 2.441 - 2-7/8” Cement Retainer C 7,744' 4.00' 2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 D 7,758' 5.85' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s E 7,773' 1.08' 2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go 7,775' 2.61' 2.441 3.70 Slotted Circ/Debris Sub w/ XO F 7,808' 1.00' 2.441 3.70 WLEG (Post gun Release) G 8,345' 3.31' 2.441 3.70 BHF-C Firing Head 8,348' 4.14' 3.50 SXAR Gun Drop Sub 8,352' 26.68' 3.50 Safety Spacer 8,379' 15.00' 3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394' 0.56' 3.50 Bull Nose 10,199’ 7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’ 2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’ 5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’ 2-3/8” Baker Shear Sub PERFORATION DETAIL FROM TO Length Interval Date Description 4525 4645 120’ UB47-0 4793 4900 107’ UB50-6 4924 4950 26’ UB50-8 5045 5065 20’ UB50-8 5070 5100 30’ UB50-8 5300 5286 15’ UB50-8 5328 5340 12’ LB52-9 5405 5430 25’ LB52-9 5530 5541 11’ TY53-0 5645 5658 13’ TY55-4 5824 5900 76’ TY59-6 6038 6200 162’ TY61-0 6345 6444 99’ TY62-3 7861 7876 15’ TY77-3 06/04/06 Isolated 10450 10462 12’ H 10/14/05 Isolated 10466 10478 8’ H 10/14/05 Isolated 10515 10527 12’ H4 10/14/05 Isolated 10530 10585 55’ H5 10/14/05 Isolated 10614 10632 18’ H 10/14/05 Isolated 10638 10652 14’ H 10/14/05 Isolated 10658 10666 8’ H 10/14/05 Isolated 10672 10686 14’ H 10/14/05 Isolated 10745 10759 14’ H 10/14/05 Isolated 10763 10772 9’ H 10/14/05 Isolated 10787 10792 3’ H 10/14/05 Isolated 10796 10802 6’ H 10/14/05 Isolated 5328 5340 12’LB52-9 (poppet type) 5405 5430 25’LB52-9 test IA to 1500 psi Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Swanson River Field SCU 42B-05 1/26/2021 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1.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: Request for Suspended Well Renewal 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,945'8,345' Casing Collapse Structural Conductor Surface 1,580psi Intermediate 4,790psi Production 6,280psi Liner 8,830psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12.Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng tkramer@hilcorp.com 10,899'7,082'7,054'N/A 7,082' N/A; N/A N/A; N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: 9,190psi Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028966 182-199 50-133-20363-00-00 Soldotna Creek Unit (SCU) 42B-05 Swanson River Field / Hemlock Oil & 77-3 Tyonek Gas Storage Length Size N/A, All perfs are isolated Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 6.4# / L-80 TVD Burst 6,800' 7,740psi MD 6,890psi 3,130psi 92' 3,394' 10,393' 92' 3,395' 8,472'5-1/2" 20" 10-3/4" 92' 7-5/8"10,436' 3,395' 8,511' Perforation Depth MD (ft): 10,438' See Attached Schematic 8,511' 5-1/2" Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 30, 2020 10,943'713' 2-7/8" 10,897' m n P 66 t al Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:43 am, Sep 23, 2020 320-391 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.22 16:53:22 -08'00' Taylor Wellman SFD 9/23/2020 Request for Suspended Well Renewal al gls 10/5/20 SFD 9/23/2020 NO FORM REQUIRED. Comm. 10/8/2020 JLC 10/7/2020dts 10/07/2020 RBDMS HEW 10/29/2020 KEN June 2020 Suspended Well Inspection Data Well: Soldotna Creek Unit 42B-05 Surface Location: 1,823’ FSL, 572’ FEL, Sec. 5, T7, R9W, S.M. Permit to Drill: 182-199 API: 50-133-20363-00-00 AOGCC Inspection Date: 09/04/20 AOGCC Inspector: Lou Laubenstein Hilcorp Representative: Jake Paulk Size Pressure (psi) Tubing 2-7/8” 140 Casing 5-1/2” 140 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x This well was drilled and completed as an oil well in Hemlock H-10 in 1983 as SCU 42B- 05. The well was plugged back in 2005 to recomplete in the Tyonek 77-3 sand for the purposes of converting to gas storage in 2005. A 5-1/2” liner was ran from surface inside the 7” production casing and developed a micro-annulus. The well was plugged to isolate the 77-3 sand in this well and left in a suspended status since 2006. The Tyonek 77-3 has been used as a gas storage zone since 2006 by well SCU 42-05X and 2007 by well SCU 42-05Y. SCU 42B-05 has remained in a suspended status to evaluate the plugback and isolation of gas stored in the Tyonek 77-3. x Condition of Wellhead: Good x Condition of Surrounding Surface Location: Good x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore isolate the 77-3 sand in this well and left in a suspended status since 2006. T well was plugged to Updated by DMA 09-18-20 SCHEMATIC Soldotna Creek Unit Well: SCU 42B-05 Completion Ran: 6/20/06 PTD: 182-199 API: 50-133-20363-00 PBTD = 7,082’ MD / 7,054’ TVD TD = 10,945’ MD / 10,899’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20” 84 - - 92’ 10-3/4” 40.5 K-55 - Surface 3,395’ 7-5/8” 39 L-80 FL4S 6.625” Surface 1,542’ 7-5/8” 33.7 L-80 FL4S 6.765” 1,542’ 3,512’ 7-5/8” 29.7 L-80 FL4S 6.875” 3,512’ 4,611’ 7-5/8” 33.7 SS-95 LT&C 6.765” 4,611’ 7508’ DV Collar 7508’ 7510’ 7-5/8” 33.7 SS-95 LT&C 6.765” 7510’ 8,338’ 7-5/8” 39 SS-95 LT&C 6.625” 8,338’ 10,438’ Liner 5-1/2” 17 N-80 Hyd 513 4.892” Surf 8511’ 5-1/2” 20 N-80 4.778” 10,230’ 10,943’ Tubing 2-7/8 ” 6.4 L-80 IBT 2.441” Surf 6,800’ 3-1/2 ” 9.3 N-80 8RD EUE 2.992” 9500’ 10,290’ 2-3/8” 1.995” 10,290’ 10,308’ JEWELRY DETAIL NO. TM Depth Length ID OD Item 18’ - - Tubing Hanger B. 6800’ 6800’ 2.441 Kill String – 2-7/8” tbg 7703’ Tbg Cut 7,707' 30.50' 2.441 (1) Joint of 2-7/8" tbg w/ TC II 7,738' 5.75' 2.441 6’ x 2-7/8" Pup Joint w/ TC II BxP C. 7,744' 4.00' 2.313 3.920 Sliding Sleeve, 2-7/8”, 2.313 7,748' 9.74' 2.441 10’ x 2-7/8" Pup Joint w/ TC II BxP D. 7,758' 5.85' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO’s 7,763' 3.76' 2.441 4’ x 2-7/8" Pup Joint w/ TC II BxP 7,767' 5.75' 2.441 6’ x 2-7/8" Pup Joint w/ TC II BxP E. 7,773' 1.08' 2.250 3.25 Profile Nipple, “XN”, 2.313” w/ 2.25” No-Go 7,775' 2.61' 2.441 3.70 Slotted Circ/Debris Sub w/ XO 7,776' 32.00' 2.441 (1) Joint of 2-7/8" tbg w/ 8rd BxP F. 7,808' 1.00' 2.441 3.70 WLEG (Post gun Release) G. 8,345' 3.31' 2.441 3.70 BHF-C Firing Head 8,348' 4.14' 3.50 SXAR Gun Drop Sub 8,352' 26.68' 3.50 Safety Spacer 8,379' 15.00' 3.50 TCP Guns loaded 10' w/ PowerJet Omega Charges 8,394' 0.56' 3.50 Bull Nose 10,199’ 7-5/8x3-1/2” (39#) EUE 8RD Baker FH Packer 10,206’ 2.875 S nipple Otis 3-1/2” 8RD position 2 w/optional 2.875” ID 10,272’ 5-1/2” 20# Baker FH Packer 10,307’ 1.791 Otis “N” nipple (w/ 1.791” no go) 10,308’ 2-3/8” Baker Shear Sub PERFORATION DETAIL FROM TO Length Interval Date Description 7861 7876 15’ 77-3 06/04/06 Isolated 10450 10462 12’ H 10/14/05 Isolated 10466 10478 8’ H 10/14/05 Isolated 10515 10527 12’ H4 10/14/05 Isolated 10530 10585 55’ H5 10/14/05 Isolated 10614 10632 18’ H 10/14/05 Isolated 10638 10652 14’ H 10/14/05 Isolated 10658 10666 8’ H 10/14/05 Isolated 10672 10686 14’ H 10/14/05 Isolated 10745 10759 14’ H 10/14/05 Isolated 10763 10772 9’ H 10/14/05 Isolated 10787 10792 3’ H 10/14/05 Isolated 10796 10802 6’ H 10/14/05 Isolated 7861-7876 ft 77-3 sand Q Y B Q ' Y Q Y _ Q' Q Q Q Q QQ P Q !! !!! !! !!! ! ! !! ! !! ! ! !!! !! ! QQ QYB QQ 'YQY _ Q' Q QQ Q Q QQPQ' 0 YSCU 42B-05 S007N009W SWANSON RIVER FIELD SCU_42-05 SCU_42A-05 SCU_42-05PB SCU_24A-05 SCU_33-05 SCU_42B-05 SCU_42B-05PB SCU_42-05X SCU_42-05Y SCU_12-04 SCU_314-04 SCU_32-05 SCU_32A-05 SCU_34-05 SCU_43-05 SCU_43A-05 SCU_13-04 SCU_44-05 SCU_12A-04SCU_314-04 SCU _ 3 2 - 0 5 SCU_43-05 S C U _ 2 4 A - 0 5 SCU_42-05YSCU_13-04 SCU_322C-04SCU_33-05 SCU_42B-05SCU_42-05XSCU_34-05SCU_14A-05 SCU_14-05 SC U _ 3 2 A - 0 5 SCU_24-05 S C U _ 4 1 - 0 5 SCU_44-05SCU_42-05PBSCU_42-05SCU_42A-05SCU_21C-04SCU 12-04 Pad SCU 14-04 Pad SCU 32-05 Pad SCU 34-05 Pad SCU 43-05 Pad Sec. 4Sec. 5 0 260 520 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 6/22/2020 SWANSON RIVER SCU 42B-05 Suspended Well ! ! ! !! ! Location Map Overview Coo k I nl et Kenai Homer Tyonek SewardNinilchik Anchorage HAK Petra Well Symbol _Unknown'Oil B Dry 0 INJ Q P&A P SHUT-IN Y Suspended Suspended Well Inspection Review RoD8rf |nspectNo: suxL0L200908I03644 Date Inspected: 9/4/2020 ' Inspector: Lou Laubenstein Type ofInspection Well Name: SOLDOTNACKUNIT 4ZB-08 ' '- Permit Number: - 1821990 Suspension Approval: - Sundry' # 306-167 � Suspension Date: 6/21/2006 - Location Verified? � IfVerified, How? ' GPSOffshore? El Well Pressures (psi) 140 140 - 0 Wellhead Condition Wellhead bingood condition with nosigns cfleaks orvisab|eissues. Subsequent Date AOGCZNotified: 8/25/2020 Operator: Hi|corpA|aska, LLC Operator Rep: Daniel Pau|k � Wellbore Diagram 4vai|? Photos Taken? Fluid in Cellar? W 8PV|nstoUed? El VR Plug(s) Installed? LJ Condition ofCellar Cellar had some water in it, the water looked clean with no sign of contamination. Surrounding Surface Condition The surrounding area ofthe pad was clean ofall 6ebb`viable spillage orleaks Comments Supen/bor[ommenb Photos (3)attached � FhJaKOctober 9,2020 O THE STATE °fALASKA. GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Swanson River Field, Hemlock oil and Tyonek Gas Pools, SCU 42B-05 Permit to Drill Number: 182-199 Sundry Number: 319-485 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alciska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, WJeI. Chair DATED this I day of November, 2019. RBDMS L�� jNOV 141019 RECEIVED STATE OF ALASKA OCT 2 3 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC on onr oc oon 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑Q Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑Q Alter Casing ❑ Other: Run Upr. Comp. /Nitrogen Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service 182-199 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20363-00-00 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 716 & CO 716.001 Will planned perforations require a spacing exception? Yes❑ No Q Soldotna Creek Unit (ICU) 426-05 9. Property Designation (Lease Number): 10. Field/Pool(s): 2yv� 1d cloir0 FEDA-028996 0 Swanson River Field / -77-3 Ty ajiiek G it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 10,945' 10,899' 7,082' 7,052' 2,082 7,082' 8,345' Casing Length Size MD ND Burst Collapse Structural Conductor 92' 20" 92' 92' Surface 3,395' 10-3/4" 3,395' 3,394' 3,130 psi 1,580 psi Intermediate 10,438' 7-5/8" 10,438' 10,393' 6,890 psi 4,790 psi Production 8,511' 5-1/2" 8,511' 8,472' 7,740 psi 6,280 psi Liner 713' 5-1/2" 10,943' 10,897' 9,190 psi 8,830 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# L80 6,800' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; N/A 12. Attachments: Proposal Summary Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ / Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: f Commencing Operations: November 4, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval`. ""�� Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. / Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: CtWO 00d hllcor .COflt ,Z Contact Phone: 777-8443 1 Authorized Signatur - — Date: � � C COMMISSION USE ONLY Conditions of approval: Notify Commission so the a representative may witness Sundry Number: kT I � u 31 q' (tl?n Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance E]^'2 2� L. Other t.JC�d LJ S :. d' (rs 4- C� J 1-1 ,0S /Soo —r,�5 C C7-.6 Post Initial Injection MIT Req'd? Yes ❑ No ❑ �Aj Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0- 904 IBDMS NOV 14 2019 " APPROVED BY Approved by _ COMMISSIONER THE COMMISSION Date: Submit Form and r�o(m 10x03 R vise 4/zo17 Approved application is vali f r t o t of approval. /� Attachments in Duplicate 11 /"1� � �g lh)�--X le n Well Prognosis Well: SCU 426-05 Al.,ka. LU DateJDARM19 11114111 WEEngineer; SCU 42B-05 API Number: 50-133-20363-00-00 Cutus: Suspended Well Leg: N/A Estart Date: November 0, 2019 Rig: KT #1 Real Req'd. 10-403 Date Reg. Approval Rec'vd: ReContact: Donna Ambruz 777-8305 Permit to Drill Number: 182-199 Firgineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) SeEngineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Max. Expected BHP: 2,700 psi @ 6,179' TVD (Based on normal gradient) Max. Potential Surface Pressure: 2,082 psi (Based on max. expected BHP and gas gradient (0.1 psi/ft)) Brief Well Summary SCU 426-05 was drilled and completed in 1983 as an oil well in Hemlock H-10. The well was plugged back In 2005 to recomplete in the Tyonek 77-3 sand for the purposes of converting to gas storage in 2005. A 5-1/2" liner was run from surface inside the 7-5/8" production casing and developed a micro -annulus. The well was plugged to isolate the 77-3 sand in this well and left in a suspended status since 2006. The Tyonek 77-3 has been used as a gas storage zone since 2006 by well SCU 42-05X and 2007 by well SCU 42-05Y. SCU 4213-05 has remained in a suspended status to evaluate plugback and isolation of gas stored in the Tyonek 77-3. The purpose of this work/sundry is to pull the kill string, perforate the 61-0 and 56-9 sands in the Tyonek zone, the 52-9 sand in the Lower Beluga zone and the 50-8 (two intervals) and 47-0 sands in the Upper Beluga zone, and install a 2-7/8" upper completion with a packer. Notes Regarding Wellbore Condition • Cement tagged at 7,082' MD on 6/20/2006 • Casing tested to 3,000 psi on 6/20/2006 • 2-7/8" Kill String left in well to 6,800' MD • Annulus and tubing freeze protected with diesel Pre -Rig Operations 1. MIT the casing to 2,500 psi for 30 minutes. lend'4j Well Prognosis Well: SCU 42B-05 uae"rn:u".k,,, LL,Date:,ljl//32'/2019 E �� Rig Procedure (Pull Tubing) (,i%c r /�'l � '. �c I. MIRU KT #1 Work Platform and 60 ton Crane. r" J'Iz 2. Circulate well with kill weight brine. 3. Ensure no pressure is on the well. 4. Set Back Pressure Valve. ND wellhead, NU BOP and test to 250 psi Low / 3,000 psi High; Annular to 250 psi Low / 2,500 psi High. Record accumulator pre -charge pressures and chart tests. (Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness.) a. Perform test. b. Test VBR rams on 2-7/8" test joint. c. Submit completed 10-424 form to AOGCC within 5 days of BOPE test. Copy to BLM. S. POOH with tubing. U&' X_' (i+t' riG7�✓ :1 E -Line Procedure v'b' 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,000 psi High. 2. PU CBL tool. 3. RIH with CBL and log from PBTD to surface. 4. POOH and RD E -Line. L 6t( •+t ( Jpf q Coiled Tubing Procedure (Jet Dry) 1. MIRU Coiled Tubing Unit and BOP equipment. PT BOPE to 250 psi Low/4,000 psi High. 2. RU Nitrogen pumping unit. 3. MU jet nozzle BHA. 4. RIH with coiled tubing and BHA, tag PBTD and PU 5ft. 5. Drop ball and come online with Nitrogen and jet well dry. a. Estimated volume of displaced wellbore fluid is 164 bbls. 6. Once well is dry, verify desired surface pressure to leave on well with Operations Engineer. 7. POOH with coil. LD BHA. 8. RD Coiled Tubing. �. C � LI K Ilik.,, Ala+ka, LL E -Line Procedure (Perforate) Well Prognosis Well: SCU 426-05 Date:30/21/2019 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,000 psi High. Note that the well is pressurized with Nitrogen. a. If necessary, bleed pressure down as requested by the Operations Engineer to establish a drawdown on the formation. 2. If needed: a. RIH with GPT tool and find fluid level. If fluid level is over the depth to shoot the new perfs, discuss using Nitrogen or high-pressure gas with the Operations Engineer. b. RU Nitrogen truck and pressure upon well to push water back into formation. Use GPT Tool to confirm if fluid level is below interval to pert. 3. RU perf guns. 4. RIH and perforate the following intervals. Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt. Upper Beluga 47-0 ±4,525' +4,645' +4,516' +4,635' 120 Upper Beluga 50-8 +41924' +4,950' +4,912' +41938' 26 Upper Beluga 50-8 +5,070' +5,100' +5,057' +51087' 30 Lower Beluga 52-9 +5,405' +5,430' +5,390' +5,415' 25 Tyonek 56-9 +5,824' +5,900' +5,805' +5,881' 76 Tyonek 61-0 +6,038' +6,200' +6,018' +6,179' 162 p�t4 a. Sands will be perforated one at a time starting with the lowest interval. b. If an interval proves to be non-productive, Hilcorp will move up to the next interval. If the interval is water producing, the water will be pushed back into the perforations and a CIBP Set with 35' of Cement placed on top of the mechanical plug - if there is room to place the cement between intervals. If there is not room, a shorter footage of cement may be placed or no cement at all depending on the available footage between zones. c. Hilcorn recognizes that the Beluga Sands and the Tyonek sands are in different PAS,. If the Tyonek Sands prove to be non-productive, a CIBP and 35' of cemnt will be set over the Tyonek Sands to separate the two different PA's. Then the Beluga Sands will be perforated one at a time in the same manner. d. Should there be a need to produce the Beluga PA and the Tyonek PA simultaneously from this q„� \ wellbore, then a comingling agreement will be pursued at that time. e. Proposed perfs also shown on the proposed schematic in red font. I k f. Final perfs tie-in sheet will be provided in the field for exact pert intervals. g. Use Gamma/CCL to correlate. h. The perforations in the table above are governed by Conservation Order 716 & 716.001. �} i. Install Crystal Gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. j. Record 5, 10 and 15 minute pressures after firing guns. 5. RD E -Line. K ❑ik., p V.A.. LU Rig Procedure (Install Upper Completion)w (CJI kby th 1. PU 2-7/8" Tubing, Packer and WLEG.' 2. RIH with 2-7/8" Tubing, Packer and WLEG to +4,600' MD. 3. Circulate corrosion -inhibited brine behind tubing. 4-4a—Park DTI�a`. M 1 T' (.d tc>" 19s- 5. If needed, MIRU Slickline PT lubricator to 250 psi Low/ 3,000 psi High. 6. PU and RIH with retrieving tool and pull ball & rod from ball set to surface. 7. RD Slickline. Well Prognosis Well: SCU 4213-05 Date:10/21/2019 / 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,000 psi High. 3. RIH and set 5-1/2" CIBP (or tubing patch) and dump 35' of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. KT #1 Flow Diagram S. KT#1 Choke Manifold Diagram 6. Coil BOPE Schematic 7. Standard Well Procedure — Nitrogen Operations 8. RWO Sundry Revision Change Form Soldotna Creek Unit Well: SCU 4213-05 Completion Ran: 6/20/06 ACTUAL SCHEMATIC PTD: 182-199 Hib+nrn Alaska, LLC API: 50-133-20363-00 RKB =18.0' e.6(, TD-- 10,945' ETD= 8,345' CASING AND TURING DFTAD SIZE WT GRADE CONN ID TOP BTM. 20" 84 77-6 Tubing Hanger B. 92' 10-3/4" 40.5 K-55 - 10466 Surface 3,395' 7-5/8" 39 L-80 FL4S 6.625" Surface 1,542' 7-5/';;33 (1) Joint of 2-7/8" tbg w/ TC If L-80 FL4S 6.765" 1,542' 3,512' 7-5/8" 29.7 L-80 F1,4S 6.875" 3,512' 4,611' 7-5/8" 1 33.7 SS -95 LT&C 6.765" 4,611' 7508' DV Collar 5.85' 2.790 4.560 SABL3 Pkv w/ KBH-22 Anch"&X0's7,763' 7508' 7510' 7-5/8" 33.7 SS -95 LT&C 6.765" 7510' 8,338' 7-5/8" 39 SS -95 LT&C 6.625" 8,338' 10,438' Liner Profile Nipple, "XN", 2.313" 10787 7,775' 2.61' 2.441 3.70 5-1/2" 17 N-80 H d 513 4.892" Surf 8511' 5-1/2" 20 N-80 4.778" 10,230' 10,943' Tubin C. 81345' 2-7/8 " 6.4 L-80 IBT 2.441" Surf 6,800' 3-1/2 " 9.3 N-80 8RD EUE 2.992" 9500' 10,290' 2-3/8" Safety Spacer 8,379' 1.995" 10,290' 10,308' 1F.WF,i.RV T)F.TAII NO. TM De th Len th ID OD Item 7861 18' 15' 77-6 Tubing Hanger B. 6800' 6800' 2.441 Kill String -2-7/8"tb 10466 7703' 8' H5 Tbg Cut 10515 7,707' 30.50' 2.441 (1) Joint of 2-7/8" tbg w/ TC If 10530 7,738' 5.75' 2.441 6'x 2-7/8" Pup Joint w/ TC 11 BxP C. 7,744' 4.00' 2.313 3.920 Sliding Sleeve, 2-7/8", 2.313 10638 7,748' 9.74' 2.441 10' x 2-7/8" Pup Joint w/ TC H BxP D. 7,755' 5.85' 2.790 4.560 SABL3 Pkv w/ KBH-22 Anch"&X0's7,763' 10672 10686 3.76' 2.441 10/14/05 4' x 2-7/8" Pup Joint w/ TC 17,767' 10745 10759 5.75' 2.441 10/14/05 6' x 2-7/8" Pup Joint w/ TC IE. 10763 7,773' LOS' 2.250 3.25 Profile Nipple, "XN", 2.313" 10787 7,775' 2.61' 2.441 3.70 Slotted Circ/Debris Sub w/ X7,776' 10796 10802 32.00' 2.441 10/14/05 (1) Joint of 2-7/8" tbg w/ Std F. 7,808' 1.00'WLEG (Post gun Release C. 81345' 3.31' 2.441 3.70 BHF -C Firing Head 8,348' 4.14' 3.50 SXAR Gun Drop Sub S,352' 26.68' 3.50 Safety Spacer 8,379' 15.00' 3.50 TCP Guns loaded 10'w/ Powerful Omega Charges 9,394' 0.56' 3.50 Bull Nose �- 10,199' 7-5/80-1/2" (394) EUE 8RD Baker FH Packer 10,206' 2.875 S nipple Otis 3-1/2" 8RD position 2 w/optiona12. 875" ID 10,272' 5-1/2"20# Baker FH Packer 10,307' 1,791 Otis "N" _i_- (w/ 1.791"no o) 10,308' 2-3/8" Baker Shear Sub PERFORATION DFTAff FROM TO Len th 111- IntervA06/04/06 Descri tion 7861 7876 15' 77-6 Isolated 10450 10462 2' H05 Isolated 10466 10478 8' H5 Isolated 10515 10527 12' H45 Isolated 10530 10585 55' H55 Isolated 10614 10632 18' H5 Isolated 10638 10652 14' H5 Isolated 10658 10666 8' H 10/14/05 Isolated 10672 10686 14' H 10/14/05 Isolated 10745 10759 14' H 10/14/05 Isolated 10763 10772 9' H 10/14/05 Isolated 10787 10792 3' H 10/14/05 Isolated 10796 10802 6' H 10/14/05 Isolated SCU 42B-05 Schematic 03-04-14 Updated by STP 3/04/14 Soldotna Creek Unit Well: SCU 42B-05 PROPOSED SCHEMATIC Completion Ran: 6/20/06 PTD: 182-199 Hilcurir Aluska, LLC API: 50-133-20363-00 CASING AND TTTRTNr DPTA IT TD- 10,945' ET 8,345' 15 l\/s SIZE ` WT GRADE CONN ID v TOP BTM. 20 84 _ _ Hanger A. 92, 10-3/4" 40.5 K-55 14,924 B. Surface 339 7-5; 8" 39 L-80 FL4S 6.625" Surface 1,542' 7-5/8" 33.7 L-80 FIAS 6.765" 1 542' 3,5]2' 7-5/8" 29.7 L-80 FL4S 6.875" 3,512' 4,611' 7-5/8" 33.7 SS -95 LT&C 6.765" 4,611' 7508' DV Collar 9.74' 2.441 ±6,179 10'x 2-7/8" PIP Joint av! TC II BxP 7508' 7510' 7-5/8" 33.7 SS -95 LT&C 6.765" 7510' 8,338' 7-5/8" 39 SS -95 LT&C 6.625" 8,338' 10,438' Liner 6'x 2-7/8" Pup Joint w! TC II BxP E. 7,773' 1.08' 2.250 3.25 5-12" 17 N-80 H d 513 4.892" Surf 8511' 5-12" 20 N-80 2.441 4.778" 10,230' 10,943' Tobin ] 00' 2.441 3.70 WLEG (Post 9, Release) 10,614 2-7/8" 10,569 10 587 18' G. 8,345' 14,600' 2-7/8" 6.4 L-80 EBT 2.441" Surf 6,800' 3-12" 9.3 N-80 8RD EUE 2.992" 9500' 10,290' 2-3/8" H7 8,379' 15.00' 1.995" 10,290' 10,308' TPLVPT PV 11PTATT NO. TM Depth LengthItem To TVD Btm TVD Ft Date IS'Iltbin UB 47-0 14,615 14,645 Hanger A. f4,600'Packer Pro used TBD HB 50-8 14,924 B. 14,600'WLHG ±4 938 126 Pro used TBD UB 50-8 7703'Tbg 35,100 35,057 35,087 Cut Pro used 7,707' LB 52-9 15,405 15,430 (1) Joint of 2-7/8" tbg w/ TC D7738'6'27/8Pup 15 415 325 Pro used TBD 155-9 joint w/TC II BxP C. 7,744'Sliding ±5,881 176 Pro used Sleeve, 2-7/8", 2.313 T61-0 7,748' 9.74' 2.441 ±6,179 10'x 2-7/8" PIP Joint av! TC II BxP D. 7,758 5.85' 2.780 4.560 SABL3 Pkr w/ KBH-22 Anchor Seal Assy & XO's 7,842 7,763' 3.76' 2.441 HI 4' x 2-7/8"Pop Joint w/TC II BxP 10,462 7,767' 5.75' 2.441 10/142005 6'x 2-7/8" Pup Joint w! TC II BxP E. 7,773' 1.08' 2.250 3.25 Profile Nipple, "XN', 2.313" w/ 2.25"No-Go 10/142005 7,775' 2.61' 2.441 3.70 Slotted Cvc/Dehris Sub «' XO 10,482 7,776' 32.00' 2.441 H5 (1) 7omt o1`278 tbg w.' 8rd BxP F. 7,808' ] 00' 2.441 3.70 WLEG (Post 9, Release) 10,614 10,632 10,569 10 587 18' G. 8,345' 3.3 Y 2.441 3.70 BB -F -C Firing Head 10,607 8,348' 4.14' Isolated 3.50 SXAR Gun Drop Sub 10,666 8,352' 26.68' 8' 3.50 Safety Spacer H7 8,379' 15.00' 10627 3.50 TCP Cams loaded 10' w/ PowerJet Omega Charges 10/142005 8,394' 0.56' 10,745 3.50 Bull Nose 10,714 1 14' 10/14/2005 Isolated t0,763 10,772 10,199' 10,727 1 9' 1 10/142005 7-5/80-12" (399) EUE SRD Baker FH Pecker 10,206' 10,792 2.875 10,747 1 S nipple Otis 3-12" 8RD position 2 Woptional 2.875" ID 10.'14.'2005 10,272' 10,796 In 802 I 5-12" 20# Baker M Packer 10,757 10,307' 10.'14;2005 1.791 Otis "N' of Ie (w/ L791"no o) 10,308' 1 1 1 2-3/8" Baker Shear Sub PERFORATION DETAIL Sand To MD Btm MD To TVD Btm TVD Ft Date Comments UB 47-0 14,615 14,645 14,606 ±A 635 1120 Pro used TBD HB 50-8 14,924 (4,950 34,912 ±4 938 126 Pro used TBD UB 50-8 15 070 35,100 35,057 35,087 130 Pro used TBD LB 52-9 15,405 15,430 35,390 15 415 325 Pro used TBD 155-9 15,824 15,900 15 805 ±5,881 176 Pro used TBD T61-0 36,038 36,200 ±6,018 ±6,179 3162 Pro osed TBD T77-3 7,861 7,876 7,827 7,842 15' 6/42006 Isolated HI 10 450 10,462 10,405 10,417 12' 10/142005 Isolated H3 10,466 10478 10,421 10,433 8' 10/142005 Isolated H4 10,515 10,527 10,470 10,482 12' 10/142005 Isolated H5 10,530 10 585 10,485 10,540 55' 10/142005 Isolated 10,614 10,632 10,569 10 587 18' 10/142005 Isolated 10 638 10,652 10,593 10,607 14' 10/142005 Isolated 10,658 10,666 t0,613 10 621 8' 10/142005 Isolated H7 10,672 10,686 10627 10,641 14' 10/142005 Isolated 10,745 10,759 10,700 1 10,714 1 14' 10/14/2005 Isolated t0,763 10,772 10,718 1 10,727 1 9' 1 10/142005 Isolated 10,787 10,792 10,742 1 10,747 1 3' 1 10.'14.'2005 Isolated 10,796 In 802 I 10,751 10,757 6' 10.'14;2005 Isolated Updated by DMA 10-22-19 N 3 D Z C D r m m D mm FA 1 Choke Manifold KT# 1 rig 03/15/2018 To Gas Buster Blooey Line ® Unibolt Connection O 10' in length 9'in width 2 1/16 5M Gate Valves B Kill P WH P'. 2" 1502 x2 V Flangw V: (Manual 2-1/1610K 10K Flange (Manu Coil Tubing BOP Coiled Tubing HR580 Injector Head 8 Gooseneck Weight = 12,850 lbs 4-1176" 10K Conventional Stripper 5K CO62 Lubricator 5K 0O62 x 4-1116" 10K Flange 41116" 10K Combi BOP TW SBI aux//Shear SeamOSet. Rpe'SI'p 41/16" 10K FIoW Cross Manua12x2Valve1 2 >"x? -r 101KRarga Manual 2x2 Valve 2 "' K x 1, 1OK Range Manvel 2x2 VaNO3 2- +.,K x. , 16, 1OK Range Manua12.2 Velve4 2 1,02 x 2-1/18" 10K flange 41116" 1 OK x Wellhead Adapter Flange Wellhead STANDARD WELL PROCEDURE IihurpAlaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 O m z R a C U m a) d fO 2 v m m (D (D o a O CD O CD O 73 DCD O (D L7 Q O v n� v -a ma E3 CD o CD < m d O O (D 3 (D fD O J 3 0)N CD ((DD O m v .Q a ca m o z< sT n (D O c m � Q 3' a � m = 3 CD CD z O O Q 3 CD C (D O N CD Q CL O (D N c a m 8 Fn W. r r n W v v m m v m O n (D CL C N n m to m Z m j C Z( o CL to .v Co -0D y•<m � ym CL D T: W v 2 N C CL 0-0 D O NO < 3<0 210 „ C (D C f01 � O m m CL (D (D o a O CD O CD O 73 DCD O (D L7 Q O v n� v -a ma E3 CD o CD < m d O O (D 3 (D fD O J 3 0)N CD ((DD O m v .Q a ca m o z< sT n (D O c m � Q 3' a � m = 3 CD CD z O O Q 3 CD C (D O N CD Q CL O (D N c a m 8 Fn W. r r n MI&I Choke Skid■ SSV � SSV Pilot Flow Line ® Hardline r IA 4213-05 Schwartz, Guy L (CED) From: Bo York <byork@hilcorp.com> Sent: Wednesday, November 6, 2019 6:54 AM To: Roby, David S (CED) Cc: Schwartz, Guy L (CED); Boyer, David L (CED) Subject: RE: [EXTERNAL] Sundry application for SCU 426-05 (PTD 182-199 Dave - Thanks for the reminder, I appreciate it. I will pass on to our team and discuss it with them. Bo York Hilcorp Alaska LLC Kenai Operations Manager byork@Hilcoro.com 907.777.8345 907.727.9247 cell From: Roby, David S (CED) [mailto:dave.roby@alaska.gov] Sent: Tuesday, November 5, 2019 1:51 PM To: Bo York <byork@hilcorp.com> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: [EXTERNAL] Sundry application for SCU 42B-05 (PTD 182-199 In the referenced sundry application it stats in step 4.d. of the E -Line Procedure "Should there be a need to produce from the Beluga PA and the Tyonek PA simultaneously from the wellbore, then a commingling agreement will be pursued at that time." I want to point out that PA designations don't necessarily conform to our pool boundaries and that there's three defined gas pools in the SCU that may be encountered during your proposed operations. These are the Sterling/Upper Beluga, Beluga, and Tyonek gas pools (these pools are defined in CO 716). Downhole commingling for these pools has not been approved on a pool wide basis, nor in the subject well, commingling between any two or more of these pools in this well would require an order from the commission authorizing downhole commingling. So, this is just a reminder to keep pool boundaries and not just PA boundaries in mind when determining if downhole commingling authorization is necessary. Thanks, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 CONFIDEN77ALITYN07/CE: 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 Dave Roby at 907- 793-1232 or dave.robvCdalaska.zov. The Information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, November 12, 2019 10:19 AM To: Christina Twogood - (C) Cc: Ted Kramer; Donna Ambruz Subject: RE: [EXTERNAL] SCU 426-05 RWO to perforate (PTD 182-199) Christina, Thanks... good drawings and explanation. By flowing down IA valve you can keep KT 1 rigged up. I also assume SCU 42X-05 will be shut in at the Master valve to isolate it. I'll get sundry processed now. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 on 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 Guy Schwartz at (907-793-1226 ) or (Guv schwartz@alaska aov). From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Monday, November 11, 2019 4:44 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Ted Kramer <tkramer@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] SCU 42B-05 RWO to perforate (PTD 182-199) Guy, While flow testing the zone(s) from SCU 426-05, we plan to route the flow from SCU 426-05 through the SCU 42X-5 wellhead to the flowline. A photo and diagram of the surface flow path are attached. The SSV downstream of SCU 4213-05 will be installed with the hardline and choke skid (in the background in the photo) and function tested. The SSV at the SCU 42X-5 wellhead (seen in the photo) is not the primary so we will hold that one open. We plan to keep the KT -1 rigged up during testing as the flow test is expected to be only a short duration. We expect 30 days to be sufficient for the test. Thank you, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w)907-777-8443 (c) 907-378-7323 From: Christina Twogood - (C) Sent: Friday, November 8, 2019 3:55 PM To: Schwartz, Guy L (CED) <guy.schwartz6Dalaska.gov> Cc: Ted Kramer <tkramerCcilhilcorp.com>; Donna Ambruz <dambruzPhilcorp.com> Subject: Re: [EXTERNAL] SCU 42B-05 RWO to perforate (PTD 182-199) 'Guy, We'll route flow through the SCU 4213-05 well over through another to utilize the SSV. I'll have a drawing of the full flow path over to you early next week. I'll confirm the remaining items together as well. Just wanted to touch base since it's in progress still. Have a great weekend, Christina Twogood Operations Engineer 907-378-7323 Sent from my iPhone On Nov 5, 2019, at 12:55 PM, Schwartz, Guy L (CED) <suv.schwartz@alaska.aov> wrote: Christi Just realized I need a wellhead/tree sketch and how will it look while you are flow testing? Are you rigging down KT -1 while you flow test the well? . ( Assume you are ND BOPE and NU production tree and flowline )? Also, making sure SSV is operational. Is 30 days waiver for tubing/packer long enough to test your zones? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793- 1226 ) or (Guv schwartz@alaska ciov_). From: Christina Twogood - (C) <ctwogoodR)hilcorp.com> Sent: Monday, November 4, 2019 3:33 PM To: Schwartz, Guy L (CED) <guy.schwartz(@alaska.gov> Cc: Ted Kramer <tkramer(a hilcorp.com>; Donna Ambruz <dambruz(@hilcorp.com> Subject: RE: [EXTERNAL] SCU 426-05 RWO to perforate (PTD 182-199) Guy, As discussed, please see responses below. I have attached an updated procedure reflecting the below items. Thank you, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8443 (c) 907-378-7323 From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, October 29, 2019 10:25 AM To: Christina Twogood - (C) <ctwogood0hilcorp.com> Subject: [EXTERNAL] SCU 4213-05 RWO to perforate (PTD 182-199) Christina, I have a few questions and comments for the procedure: 1) Need to MIT the casing before starting operations (2500 psi / 30 min) Agreed. 2) What is the load rating for the crane you are using ?... the air weight of the tubing is 43000 lbs. 60 ton 3) A CBL should be run in the 5'/:" to verify cement coverage. Agreed. 4) Are you sure of your order of the major steps? Your plan is Jetting with CT and perforating before you run tubing??? Yes, we are requesting a short term variance to be able to flow the zones to ensure they are productive prior to installation of a tubing string with packer for longer term production so that if a zone comes in with fluid, we are able to run a standard CIBP as opposed to a more complex system through the ID of the tubing to set back out in the ID of the casing. 5) the fluid used behind packer (IA) must be inhibited. Also no pressure test of the IA is mentioned. Agreed. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793- 1226) or (Guy schwartz@alaska aov). The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, @ is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 07, 2011 2:04 PM To: McMains, Stephen E (DOA) Cc: Davies, Stephen F (DOA) Subject: 77 -3 Gas Storage at Swanson River -Pool Code 772805 Steve, Further to the work begun earlier regarding the appropriate pool classification of Tyonek gas associated with the 64 -5 and 77 -3 storage projects, the 64 -5 [772803] and 77 -3 [772805] are distinct Tyonek sand intervals so the volume accounting needs to be separate. The matter is a little further complicated since there also is an undefined Tyonek pool code at Swanson [772500]. So far as I am aware, the only wells remaining to be reconciled are 42A -05 (180 -106) and 42B -05 (182 -199). Both wells were originally Hemlock oil producers and the Hemlock was plugged with the wells being completed in the 77 -3 sand. —t. 42B -05 was converted to GSTOR 11/7/05. First storage injection is reported in 12/05. First gas production is reported 11/05. All gas volumes are reported to the 64 -5 pool, this should be changed to the 77 -3. 42A -05 is a little more complicated. There is no record of any gas having been injected for storage. The Hemlock was plugged and the well perforated in the 77 -3 in June 2004. It appears that all gas produced from then until the well was converted to GSTOR on 10/1/05 was credited to the undefined Tyonek Pool code [772500]. Fairly regular /continuous production is reported up through 11/05 (14 days). No production is reported in 12/05 and only 7 days in 01/06. Again, all Tyonek gas from this well should be against the 77 -3 pool code [772805]. Please let me know if further information is needed. It is probably appropriate to put a copy of this message in each well file. Tom Maunder, PE Sr. Petroleum Engineer Pt\ tb%\k \s r V.,. \ ^ c.• �� %cc 3/7/2011 2010 December's SRF Tyonek 77 -ind Storage Well Monitoring Report • Page 1 of 2 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, January 10, 2011 2:26 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: FW: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Almost correct Tom. ` X & Y are the active wells in the 77 -3 gas storage sand and 42A -05 & 42B -05 were completed in the same sand, but have since both been suspended. Both A & B are being used as monitoring wells in case the gas gets out of the 77 -3, but neither has open perfs in that sand today. It is true that there are a number of other wells we are using to monitor the storage reservoir that penetrate, but were never completed in the 77 -3 sand. I do believe the split of the gas storage pool code for the 64 -5 & 77 -3 sands will be forthcoming from production accounting. They truly are separate accumulations, but both Tyonek sands. Let me know if you need more info. Larry A. `t a 141) 4PC•• From: Maun r, omas E (DOA) [mailto:tom.maunder @a` a.gov] Sent: Monday, January 10, 2011 1:55 PM To: Greenstein, Larry P; Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Larry, et al, I have been working with McMains sorting out the Swanson River storage gas. The two Swanson storage projects employ Tyonek reservoirs (64 -5 and 77 -3), but they are separate accumulations. From a reporting sense, all the volumes had been being reported under one pool code. I think that has been changed or is in the process of being changed. The question I have regards 77 -3 storage. As I understand, 42 -05X and 42 -05Y are the active injection /production wells. 42 -B -05 and 42A -05 are completed in the 77 -3 sand, but are not being actively employed. There are a number of wells that penetrate the sand enroute to the Hemlock, but none are completed in the 77 -3 sand. Do I have that correct? Thanks in advance, Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Monday, January 10, 2011 9:29 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is December's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 3/11/2011 2010 December's SRF Tyonek 77 -find Storage Well Monitoring Report Page 2 of 2 Both X & Y are in heavy usage now that the winter is in full swing, but the warmth at the end of December did allow a little injection to occur. While performing the MIT on 5X last month the operators noted that leaving the annulus with 0 pressure readings didn't offer much to monitor. They put a few hundred psi on both the 5X & 5Y well 7" annulus to better monitor pressure changes. Both annuli are now showing some ups and downs related to temperature swings based on injection vs production at different rates. Neither annulus appears to be tracking or communicating with the tubing pressures, they are just much more responsive now that there is some pressure on them to observe. The pressure responses from both wells were within expectations with no indications of any loss of integrity. Bottom line, the pressures for all the monitored wells remain within their expected ranges. Larry «Master Well List TIO Report 2011 01 01.xis» 0.1 LN 4 QO 3/11/2011 Sc&k 4a &-o5 'Regg, James B (DOA) From: Larry Greenstein [Igreenstein©hilcorp.com] Sent: Monday, May 07, 2012 11:23 AM � ? v To: Regg, James B (DOA) �1 Cc: Christopher Walgenbach Subject: RE: SRF MIT's for SCU 42A -05 and SCU 42B -05 Hi Jim, Chris sent me your e-mail requesting some info on the MIT for these two wells. You and I talked about these wells on Friday, as special cases for MITs not related to any UIC issues. The BLM wanted these wells classified as 'Monitoring Wells' (MW) for the containment of the 77 -3 gas storage. The don't have a status called 'Suspended', as the state does, and wanted a status more befitting to their actual usage in the field. One of the requirements they put on this MW status is the need for a MIT every two years with the initial one this spring. This is the only reason we are performing MITs on these wells and we will continue to report them with the monthly 77 -3 gas storage monitoring plots we send to you. If BLM wants to send an inspector, they can. As per our routine, we notify both agencies about any MIT efforts at SRF. Larry From: Christopher Walgenbach Sent: Friday, May 04, 2012 4:14 PM To: Larry Greenstein Subject: FW: MIT's Here you go Larry. Hilcorp Alaska LLC Production Foreman AdViMEDJUN 0 5 2012 Swanson River Happy Valley Westside Baker Dillon Red Pad Office 907 -283 -2541 Cell 907 -690 -1727 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 04, 2012 3:38 PM To: Christopher Walgenbach Subject: RE: MIT's SCU 42A -05; PTD 1801060; suspended 8/9/2006 SCU 42B -05; PTD 1821990; suspended 6/21/2006 AOGCC records show both wells are suspended; last activity was producing; neither well has ever injected. What is purpose of MITs? • • 'Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Christopher Walgenbach mailto:cwal enbach @hilcor .com P 9 L 9 p l Sent: Friday, May 04, 2012 2:17 PM To: tzelenka @blm.gov; Regg, James B (DOA) Cc: Bruce Hershberger; Dale Ashe; Kevin Cassidy; Larry Greenstein Subject: MIT's Tom /Jim, We are ready to do the BLM required MIT's on both 42A -05 & 42B -05 wells at your convenience. Thanks, Hilcorp Alaska LLC Production Foreman Swanson River Happy Valley Westside Baker Dillon Red Pad Office 907- 283 -2541 Cell 907 -690 -1727 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/27/10 Inspector: Bob Noble Operator: Union Oil Well Name: SCU 42B-05 • Oper. Rep: Lee Elliott PTD No.: 182-199 • Oper. Phone: 907-398-9992 Location Verified? Yes Oper. Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 06/21/06 Date AOGCC Notified: 09/22/10 - Sundry No.: 306-165 Type of Inspection: Initial • Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 _ Photos Taken? Yes IA 0 - OA 0 SCANNED AUG 1 4 ZU15 Condition of Wellhead: The location was verified with the use of a plot plan and well sign.The wellhead was found to be in good condition with working gauges. The cellar was found to be dry.There was a guard rail around the well to protect it. Condition of Surrounding Surface The location was found to be clean and free of any oil. Location: Follow Up Actions None Needed: Attachments: Photos(3) ' REVIEWED BY: Insp.Supry �F Comm PLB 09/2010 2010-0927_Suspend_SCU_42B-05_bn.xlsx ; ;. ` a4" ' -- # r r, ' i 1:i! , .. , a I .} ' N b' rn G i CC •, OU)) m +" c dVCr) o. > F- a . ,, E ., U —.1V1 JWP " �pr 9CO � /) Wc) .4011,1,. agv cv G, t I ' p Ue U 2 f-... N w O —'O ,t O coN 0 pi)vQ p 0: F'' 4N a CN • .wt .• !�� ,,;, '�'„al`�~' y +r* --\ tf..tr f it?V .usik ,;$c :•Z .., ,.: loft 7y Y• �.'� rr 4 ,001 " ;7jylr ',0��♦ ♦♦ *� `• i ' ri tjit I �7 ,ft :� �' �%� ' �� * '-- . '...,•,‘ • •-. 4 I# (s**f . ,. .... . 41 /- '1./P,r, - -- . .:‘, . .-, b :,r \ > w .ifs \ 47,1 # + t. 11 .1', .rte 1 `�� �` \ a ,� d A ,. Tir , ,, .. . „,,;*# ‘•V Ni s:\ ...4„„ , / ,:„ i t • - 1; I , 1144‘ 44* ''' .!/.,/ . a. „ , ”/iii ; 4" a 1 f:f. . . , , , a ^J a .moi. • /• \ \�� \ \\t"!� f �� \ .\\ \` ',v`\ G \ 1,, ;.,..........4_,, ,-,...1,0- - ,,b:;.,.,,,,x ,, ,,,,,;..,i,A, \,\\.. \\\\\\ „\ \ \ - \ `\\ \ -\ vi J :p 1 4g4 w40. ' 4 f,'.• \ \ \ \\.. ` .;. p, \ N ag '^ � j \ \\ \\ \ , CI �' r `,\ \\•\\\ 1\ \\\\ l \1 `\ ` \`` \ \\ \ \ \ N 4 VA ` vv v 11 t7 I" pis �� r7 • -0.i' 1 e� �/r N / p N Or ' 2009 November's SRF Tyonek 7~ Sand Storage Well Monitoring Repo Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 04, 2009 12:02 PM To: 'Greenstein, Larry P' Subject: RE: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Thanks Larry. I checked our files and database. Both wells are listed as suspended. I am going to be working more with injection now so I wanted to get up to speed. Tom From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Thursday, December 03, 2009 4:45 PM To: Maunder, Thomas E (DOA) Subject: RE: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report You're right, Tom. The X & Y wells are the actual gas storage wells we use for both injection and production from the 77-3 sand. Of all the other reported wells, only 42 -5 and 42~-5 were com the 77-3 sand., the rest just penetrate the 77- 3 sand. ~~,. ~O ~ ~-- ~~~--1~ Both 42A-5 and 42B-5 have had the 77-3 sand perfs cemented off and are just basically,hczlesin-the ground now. Their classification probably should be suspended, if I understand how you use tliaf term for wells, We still monitor these holes in the ground in case some kind of pressure starts showing up. I've attached the schematics for both wells for you to look at. Hope this helps. ~~~.~~~~=-~ ,iA~ ~ 201 Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December 03, 2009 4:08 PM To: Greenstein, Larry P Subject: RE: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Hey Larry, Just thinking about this project; for the 77-3 reservoir storage project, I know 42-05Y and 42-05X are used for storage and deliverability (production from storage). Are any of the other wells completed in the interval? I think 42-65 was, but not now?? Thanks in advance. Tom From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Thursday, December 03, 2009 3:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Hi Jim & Tom, 12/4/2009 2009 November's SRF Tyonek ~ Sand Storage Well Monitoring Repo Page 2 of 2 Here is November's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77-3 Sand Storage reservoir. The first of this winter's storage production occurred in November and the pressures responded as anticipated. No anomalies noted. Since the 13 3/8" pressure had stabilized in 42B-5, the field did a 100# bleed off to see if the casing would repressure or not. A small response was seen and we will continue to watch this pressure. The wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for all the wells being monitored. Larry «Master Well List TIO Report 2009 12 01.x1s» 12/4/2009 2009 August's SRF Tyonek 77 -3 S storage Well Monitoring Report Page 1 of I Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Tuesday, September 15, 2009 7:19 AM To: Maunder, Thomas E (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Sounds good Tom, I'II find a way to get this done...hopefully with the correct axis label, but if not, some kind of side note. Thanks , o . _a "\"\ Larry ®e l `� From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] �` Sent: Monday, September 14, 2009 9:14 PM To: Greenstein, Larry P Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report If you can't, thats OK. The storage wells are the only ones where you all inject gas. You might just make a note in the "note field" where you give the specifics on the well. Tom From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Mon 9/14/2009 5:23 PM To: Winslow, Paul M; Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Thanks Paul. Tom, I'll look into the program that spits out these plots to see if we can tweak it to be more accurate on the labeling. Larry MAR I 0 `tUt Fro inslow, Paul M Sent: Mon • - September 14, 2009 4:15 PM To: Maunder, Tho E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, - s B (DOA) Subject: RE: 2009 August's S • - •nek 77 -3 Sand Storage Well Monitoring R- • Tom, Prior to April 2009, we had only injected int. -15X, and ha. • • • uced from both 42 -05X and 42 -05Y. After installing a coalescer this year, we s - - • injecting into both 42 -05Y a : 42-05X. From here on out, we will be injecting and producing fro .• •oth wells. Paul 3/7/2011 zuui iiugusls 3rcr 1yoie& / /-3 3a1K1 31Lorage w 1v1uu1W1111g icepori rage 1 01 G • • Maunder, Thomas E (DOA) From: Winslow, Paul M [PWinslow @chevron.com] Sent: Monday, September 14, 2009 4:15 PM To: Maunder, Thomas E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Tom, Prior to April 2009, we had only injected into 42 -05X, and had produced from both 42 -05X and 42 -05Y. After installing a coalescer this year, we started injecting into both 42 -05Y and 42 -05X. From here on out, we will be injecting and producing from both wells. Paul Paul Winslow Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907 - 263 -7629 Cell: 907 -382 -3813 Fax 907- 263 -7828 pwinslow @chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 14, 2009 3:59 PM To: Greenstein, Larry P Cc: Ayer, Phil M; Winslow, Paul M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Larry, et al, It will be interesting to see the pressure plot next month on 12A -04. On 5X and 5Y, there are a couple of items. One is listed as an injection well and the other a storage well_ Do both wells inject gas and then produce it back? In our data base they are both listed as "GSTOR". Also, the volume on the right axis says BBLS. Should that be MCF? Thanks in advance. Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Monday, September 14, 2009 2:44 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is August's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 9/14/2009 2009 August's SKr''1'yonek 77 -3 Sand Storage Well Momtonng Report Page 2 of 2 • • We are still injecting into the wells, but the volumes are slowing down as the reservoir fins up. Both the 5X & 5Y wells are getting gas injected and the tubing pressures show the increases expected. The 12A-04 well WO has been completed and production has started. It is having some problems, but we are still trying to clean up the lost fluids and get production rates up. The rest of the wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for all the wells being monitored. Larry «Master Well List TIO Report 2009 09 01.xis» 9/14/2009 • • Chevrons Paul Winslow Chevron North America Petroleum Engineer Advisor Exploration and Production MidContinent/Alaska SBU 3800 Centerpoint Dr., Ste 100 Anchorage, AK 99503 Tel (907) 263 -7629 Email pwinslow @chevron.com t � ,.i E, :t - February 23, 2009 FIB '; ?OU Mr. Dan Seamount, Chairman t t iu J.zr Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Annual Material Balance Calculations of Production and Injection Volumes Swanson River Gas Storage Facility #3 (Tyonek 77 -3 sand) Swanson River Field /e) S sz — 5 Dear Commissioner Seamount: V$ ? Attached for your review is the annual material balance calculation of production and injection volumes for the Swanson River Gas Storage Facility #3 (SRGSF #3), as required per AOGCC Storage Injection Order #6 (SIO #6). SRGSF #3 applies to the Tyonek 77 -3 reservoir, which has had four wells completed in itJAC11 42A -05. SC1) 42B -05. SCU 42 -05X. and SCU 42 -05Y). This material balance report covers the primary production period, as well as the gas storage operations that have taken place from October 1, 2005 to the present time. Attachment #1 is a table of gas production and injection volumes for the SCU 42A -05, SCU 42B -05, SCU 42 -05X, and SCU 42 -05Y wells, from the commencement of primary production (July 2004) up through February 22, 2008. Note that the January and February 2009 volumes are estimated from daily metered values. Historic reservoir pressure estimates have been obtained primarily through surface shut -in tubing pressure (SITP) readings which were then converted to bottomhole pressures. In addition to the SITP's, downhole pressure gauges have been run several times, to obtain static bottomhole pressures and /or to conduct pressure transient tests. These data points are tabulated in Attachment #2 and plotted versus the corresponding net cumulative production on the standard P/Z plot (Attachment #3). Viewing Attachment #3, it has previously been noted that the early injection cycle pressures deviate above the straight line path established from the primary depletion points. Previous Annual Performance Reports have also documented that the production volumes /pressures have deviated below the primary depletion path. The latest 2008 injection and 2008/2009 production cycles mimicked the previously established trends, indicating the continued reservoir confinement of the gas storage volumes. During the peak of the 2007/2008 winter production season (Nov. '07 — Feb. '08), a net total of 852 MMcf of gas was produced from the 77 -3 reservoir. From Mar. - Sep. '08, a net total of 889 MMcf of gas was injected back into storage, via the SCU 42 -05X wellbore. To date (2/23/09) a total of 1,322 MMcf of gas has been withdrawn from storage during the 2008/2009 winter season. Note that after the extended cold period which lasted until mid January, Chevron was MidContinent /Alaska SBU /Chevron North America Exploration and Production www.chevron.com • • Swanson River Gas Storage Facility #3 2008 Annual Performance Report Page 2 able to re- inject a small amount of gas for about a week in mid January (15 — 23 and again in mid February (13 — 20` This injection and offsetting production over the past two months, accounts for the final P/Z vs. cumulative production point seen on Attachment #3. If you have any questions regarding this annual performance report, please contact Paul Winslow at your earliest convenience. Sincerely, Paul M. Winslow Petroleum Engineer Advisor Cc: Dave Whitacre Attachments Union Oil Company of California / A Chevron Company http : / /www.chevron.com 1 • ATTACHMENT #1 SRGSF #3 - PRODUCTION AND INJECTION VOLUMES (TYONEK 77 -3 SAND) 42a -05 42b-05 • 42 -05X 42 -05Y • Tvonek 77 -3 Sand Totals Cum Depletion Inventory Monthly Monthly ' Monthly Monthly • Monthly Monthly , Monthly Monthly , (Prod -Inj) (Primary- Depl Vol) Gas Gas Gas Gas Gas Gas Gas Gas Cum for POZ Total Gas Date Inj Prod Inj Prod • Inj Prod Inj Prod Plotting Inventory MCF MCF MCF MCF MCF MCF MCF MCF MCF MCF Jun -04 0 0 2,377,000 D ,L cs Jul -04 0 55,040. 55,040 2,321,960 Aug -04 0 194,185 249,225 2,127,775 Sep -04 0 173,352 ' 422,577 1,954,423 Oct -04 0 151,770' 574,347 1,802,653 Nov -04 0 161,949 736,296 1,640,704 Dec -04 0 116,582 F 852,878 1,524,122 Jan -05 0 160,730 1,013,608 1,363,392 Feb -05 0 160,235 1,173,843 1,203,157 Mar -05 0 164,902 1,338,745 1,038,255 Apr -05 0 156,158 • 1,494,903 882,097 May -05 0 172 ,327' 1,667,230 709,770 Jun -05 0 162,359 , 1,829,589 547,411 Jul -05 0 157,953 1,987,542 389,458 Aug -05 0 114,531 2,102,073 274,927 Sep -05 0 71,034 2,173,107 203,893 Oct -05 0 113,342 0 2,286 449 90,551 Nov -05 0 53,196 0 20,267 , 2, 359,912 17, 088 t o v � i Dec -05 0 0 224,142 16,950 ' 2,152,720 224 280 ` Jan -06 0 31,872 22,827 433 2,162,198 214,802 Feb -06 0 17,334 172 0; 2,179,360 197,640 Mar -06 0 87,263 24,813 99,300; 2,341,110 35,890 Apr -06 0 30,355 0 106,863 ; • 2,478,328 - 101,328 May -06 0 0 311,189 8; 2,167,147 209,853 Jun -06 0 0 12,011 • 0` 2,155,136 221,864 Jul -06 0 863 • 0 0 0 35,263 2,191,262 185,738 Aug -06 0 131' 0 0 331,869 6,215; 1,865,739 511,261 Sep -06 0 0 0 0 422,802 0 P 1,442,937 934,063 Oct -06 110,657 0 1,332,280 1,044,720 Nov -06 83,366 66,196 1,315,110 1,061,890 Dec -06 200,905 12,889 1 2,88 1,127,094 1,249,906 Jan -07 I 156,326 70,8341 1,041,602 1,335,398 Feb -07 106,193 56,748 i 1 3 8 8 992,157 84, 3 4 Mar -07 54,252 88,933 1,026,838 1,350,162 Apr -07 247,449 0 779,389 1,597,611 May -07 74,062 0 705,327 1,671,673 Jun -07 82,060 0; 623,267 1,753,733 Jul -07 39,731 103 f 583,639 1,793,361 Aug -07 139 0, 0 18,9251' 6 02,425 1,774,575 Sep -07 134,187 0 j 0 35,500 f 503,738 1,873,262 Oct -07 41,803 64i 0 0" 461,999 1,915,001 Nov -07 0 29,621 ; 0 0! 491,620 1,885,380 Dec -07 19,505 171,2471 0 35,047' 678,409 1,698,591 Jan -08 3,691 227,468 0 228,082 !! 1,130,268 1,246,732 Feb -08 117,547 120,442 0 180,632 1,313,795 1,063,205 Mar -08 239,096 24,957 0 5,280 t 1,104,936 1,272,064 Apr -08 i 223,992 12,1681 0 5,2551 - 898,367 1,478,633 May -08 2 12 , 951 414 ' 0 0I 685,830 1,691,170 Jun -08 ' 117,095 0I 0 0 ! • 568,735 1,808,265 Jul -08 75,423 0' 0 0 493,312 1,883,688 Aug -08 44,900 0I 0 01! 448,412 1,928,588 Sep -08 24,393 448 I 0 0 424,467 1,952,533 Oct -08 9,943 47,208 0 80,068, 541,800 1,835,200 Nov -08 1,267 222,108 I' 0 94,718 II 857,359 1,519,641 Dec -08 I 716 223,913 1 0 312,349 ` 1,392,905 984,095 Jan -09 90,992 127,8871 0 182,125 1,611,925 765,075 Feb -09 69,655 76,719 . 0 127,244 1,746,233 630,767 January and February (thru 2/22) '09 volumes are estimated from daily metered figures 2/23/2009 0:\ NAU\ MCBU \Alaska1DeptslAssetDev\CIGas \Gas CFT\Openmind \Swanson \Soldotna Creek Unit NorthISCU42A -5 \Surveys \Pressure.AOGCC • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 - Gauge Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psia Z Factor Psia Cum Gas, bcf P /Z, Psia Primary Production 42A -5 06/27/04 Surf PBU 1 0 3994 0.9803 4774 0.0000 4870 42A -5 10/22/04 Surf PBU 1 0 3050 0.9110 3646 0.5354 4002 42A -5 12/21/04 BHP Static 1 7982 3194 0.8933 3194 0.8403 3576 42A -5 2/8/2005 BHP PBU 8 7982 2482(SITP) 0.8859 2926 1.0599 3303 42A -5 06/23/05 BHP PBU 8 7811 1985 0.8835 1985 1.7931 2247 42A -5 07/11/05 SITP 2 0 1565 0.8859 _ 1871 1.8881 2112 42A -5 08/25/05 SITP 3 0 1385 0.8923 1655 2.1024 1855 42A -5 09/13/05 SITP 3 0 1490 0.8883 1781 2.1051 2005 42A -5 10/25/05 BHP PBU 8 7811 1556 0.8959 _ 1556 2.2666 1737 2005 Injection Cycle (42A &B -5 1 1/4/2006 IBHP Static 142 17811 11857 1 0.8803 1 2232 1 2.1423 1 2536 2006 Production Cycle 42A &B -5 3/10/2006 SITP 4 0 1895 0.8802 2236 2.1633 2540 42A &B -5 3/18/2006 BHP Static 1 7811 2026 0.8827 2026 2.2260 2295 42B -5 4/12/2006 BHP Static 42a- 120 0 1412 0.8911 1689 2.4038 1895 428-5 5/4/2006 SITP 96 0 1280 0.8969 1530 2.4783 1706 2006 -2007 Injection Cycle 42A &B -5 5/17/2006 SITP 48 0 1528 0.8871 1826 2.3799 2058 42A5 6/9/2006 Psuedo SITP 192 0 2010 0.8797 2403 2.1551 2732 42 -05X 8/3/2006 SITP/ BHP PBU 15 0 1875 0.8801 2256 2.1976 2563 42 -05X 8/24/2006 SITP /BHP PFO 12 0 2400 0.8851 2886 1.9949 3261 42 -05X 9/7/2006 SITP 24 0 2826 0.9004 3396 1.7610 3772 42 -05X 9/26/2006 SITP 24 0 3347 0.9290 4000 1.4678 4306 42 -05X 10/3/2006 SITP 53 0 3312 0.9267 3958 1.4422 4271 42 -05X 10/6/2006 SITP 11 0 3309 0.9265 3955 1.4390 4269 42 -05X 10/17/2006 SITP 107.5 0 3245 0.9234 3896 1.4127 4219 42 -05X 10/20/2006 BHP PFO 8 7794 3241 0.9216 3862 1.4015 4191 42 -05X 11/8/2006 SITP 31.5 0 3445 0.9358 4118 1.2840 4401 42 -05X 11/16/2006 SITP 44.5 0 3403 0.9328 4067 1.2497 4360 42 -05X 1/7/2007 SITP 89 0 3469 0.9374 4146 1.1109 4423 42 -05X 4/20/2007 SITP 20 0 3794 0.9626 4534 0.8318 4710 42 -05X 5/22/2007 SITP 8 0 3755 0.9583 4473 0.7523 4668 42 -05X 8/28/2007 SITP 12 0 3715 0.9561 4440 0.5834 4644 42 -05X 11/26/2007 SITP 840 0 3815 0.9644 4560 0.4622 4728 2/23/2009 0:\ NAU\ MCBU1Alaska1Depts\AssetDev \CIGas \USERS \PMW\Gas Storage \Swanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data • • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 - - Gauge Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psia Z Factor Psia Cum Gas, bcf P /Z, Psia 2008 Production Cycle 42 -05X 12/14/2007 SITP 89.5 0 3647 0.9507 4359 0.5166 4585 42 -05X 1/4/2008 SITP 31 0 3258 0.9231 3890 0.6896 4214 42 -05X 1/23/2008 SITP 7 0 _2676 0.8934 3199 0.9690 3581 42 -05X 2/8/2008 SITP 10 0 1990 0.8797 2379 1.2923 2704 42 -05Y 2/13/2008 SITP 27.3 0 1909 0.8800 2282 1.3859 2593 2008 Injection Cycle 42 -05Y 5/16/2008 SITP 24 0 3668 0.9476 4311 0.783 4549 42 -05Y 6/6/2008 SITP 216 0 3771 0.9552 4427 0.686 4635 42 -05Y 7/6/2008 SITP 96 0 3915 0.9663 4587 0.567 4747 42 -05Y 9/22/2008 SITP 96 0 3796 0.9571 4455 0.431 4655 42 -05Y 10/7/2008 SITP 96 0 3857 0.9618 4523 0.427 4703 2008 / 2009 Production Cycle 42 -05X & Y 11/13/2008 SITP 72 0 3214 0.9182 3796 0.660 4134 42 -05X & Y 11/30/2008 SITP 24 0 2847 0.8995 3372 0.853 3749 42 -05Y 12/8/2008 SITP 96 0 2719 0.8942 3222 0.941 3603 42 -05Y 1/14/2009 SITP 24 0 1518 0.8880 1792 1.654 2018 42 -05X & Y 2/21/2009 SITP 48 0 1777 0.8816 2104 1.748 2386 2/23/2009 0:\ NAU\ MCBU1AIaska\ Depts 1AssetDev \CIGas \USERS\PMW\Gas StoragelSwanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data ATTACHMENT #3 SRGSF #3 - POZ vs Cum Gas Production Plot (Tyonek 77 - 3 Sand) 6000 • A Primary •05 - Inj Cycle 5000 - A'06 Prod Cycle At •'06 -'07 lnj Cycle \\\\ • 40 ♦'07 '08 Prod Cycle 4000 •'08 lnj Cycle _ _ _ ® '08 -'09 Prod Cycle • CL 3000 • , N `�, a r • 2000 'A, A` 1000 - ' 0 0 0 1 2 3 4 Cum Gas Produced, bcf 2 / 23 / 20090 \NAU\MCBU \Alaska \Depts\AssetDev \CIGas \USERS \PMVV\Gas Storage \Swanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls AOGCC (090223) lPú '{'/Þ/Ob I STATE OF ALASKA _ ALASKA AND GAS CONSERVATION COMMIS~ RECEIVED AUG 3 0 2006 WELL COMPLETION OR RECOMPLETION REPO~ I or.:" . 1a. Well Status: OilD GasD Plugged D AbandonedD Suspended0 WAGD 1b. Well Class: A h nc O~fb 20AAC 25.105 20AAC 25.110 Development 0 ratory D GINJD WINJD WDSPL D No. of Completions Other Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of California Aband.: 6/21/06 82-199 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 December 7, 1982 50-133-20363 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1823'N & 572' W from S.E. Cor, See 5,T7N,R9W February 9, 1983 SCU 42B-05 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 766.2'N & 4.4' E of the Surface Location 177' RKB to MSL Swanson River Field Total Depth: 9. Plug Back Depth(MD+ TVD): 77-3 Tyonek Sand 774.71 'N & 9.32' E of the surface location 7082' I 7054' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 341,796 y- 2,457,871 Zone- 10,945'/10,900' TVD Swanson River Field TPI: x- y- Zone- 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 341,815 y- 2,458,645 Zone- NIA A-028996 18. Directional Survey: Yes o No D 19. Water Depth, if Offshore: 20. Thickness of Permafrost: NIA feet MSL 0 21. Logs Run: NIA 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 92' Surface 92' -- Driven 10-3/4" 40.5 K-55 " 3395' " 3394' 14-3/4" 1250 SX. 7-518 " 39 SS-95 " 10,438' " 10,393' 9-7/8" 2077 SX. 33.7 S-95 " 29 L-80 " 5-1/2" 20 N-80 10,230' 10,943' 10,185' 10,897' 6-1/2" 108SX. 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) "None" 2-7/8" Kill String 6800' None 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5CÁNNED r~UG 3 1 2005 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGaS-OiI Ratio: Test Period ... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ... 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Currently monitoring pressures. RBDMS BFL SEP 0 1 2006 ~ J., on Fo"" 111-407 Re,;",' 12/20'r{lR, 'M3 NÃ[ AFE A6000 CONTINUED ON REVERSE ~ NAME GEOLOGIC MARKER MD TVD 29. ORMATION TESTS Include and briefly su ze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state IINone". 28. NIA "None" 30. List of Attachments: Job Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Signature: Title: Drilling Manager Phone: 907-276-7600 Date: -g-è:.:S~ Sundry Number or NIA if C.O. Exempt: 306-165 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 AFE A6000 Daily Operations 6/1/2006 05:00 - 6/2/2006 00:00 Operations Summary SIMOPS PJSM RU slickline Pressure test to 3200. Test BOPs RIH with Pressure and temp gauges with well flowing to 7868'. SI injection. Start 12 hr Static Bottom Hole Survey. 6/2/2006 00:00 - 6/3/2006 00:00 Operations Summary Continue pressureltemp survey. SIMOPs and PJSM. RD slickline. 6/3/200600:00 - 6/4/2006 00:00 Operations Summary SIMOPs and PJSM. RU slickline. Rig up hardline, prime pumps and hydro test to 300 psi low, and 3500 psi high. Pump 8.5# prod water at 4 BPM down tbg. Press 2500 psig @4BPM at 55 bbls away. Cut rate to 2.8 BPM. Pressure still climbing. Continue to cut pressures until down to 1.3 BPM before pressure stop climbing. Shut pumps down with 95 bbls away. RIH with BO $hiftiflgtool and open sleeve at 7744'. POOH. Circ 3.8 BPM through sleeve the long way with good returns off the annulus. Reverse Circ. wI good returns. RD slickline and RU eline. Pressure test and PJSM. Arm setting tool and 2-7/8" EZ-SV Retainer. RIH wI same and tie in. Set BP at 7753' Pick up and tag BP at set depth. POOH. RD Eline. Pump and establish squeeze rate through retainer of 1 BPM with pressure of 2600 psi. SD. 6/4/2006 00:00 - 6/5/2006 00:00 Operations Summary SIMOPs and PJSM. Mix 15.8 # cmt. Pump 20 bbls of same at 3.8 BPM taking returns up annulus. Close annulus with 989 psi. Launch ball and displace with 24 bbls of lease water while taking returns off annulus. Close annulus and start squeeze. At 27 bbls (calc to be at top perfs) annulus at 2614 psi. Squeeze additional 4.9 bbls. Wait, open annulus and cir to bump ball. Bump ball at 43.6 bbls total displacement. Calculated cement below retainer is 7 bbls. Reverse circ to clean annulus of cement. Secure location. 6/5/2006 00:00 - 6/6/2006 00:00 perations Summary Simops and PJSM. WOC. Pressure test to 300 low and 2500 high (good test) AOGCC withness. Hold PJSM on arming Jet Cutter. RIH with 2.25" jet cutter and tie in. Tag cement top at 7747'. PU to 7703' and fire jet cutter. Good indication of tbg parting. RD eline and wireline. Secure location. 6/6/2006 00:00 - 6/7/2006 00:00 Operations Summary Prepping Pad for Rig Mobe. 6/7/2006 00:00 - 6/8/2006 00:00 Operations Summary Pre-Spud Meeting. Continue to prep location. 6/8/2006 00:00 - 6/9/2006 00:00 Operations Summary Kuukpik Rig #5 Mobe onto location. 6/9/200600:00 - 6/10/2006 00:00 Operations Summary Continue to mobe Kuukpik Rig. 6/10/200600:00 - 6/11/2006 00:00 Operations Summary Cont to Mobe Kuukpik rig. 6/11/200600:00 - 6/12/2006 00:00 Operations Summary Accepted Kuukpik rig at 16:00 hrs. Shell test BOPE. Building mud volumes. 6/12/2006 00:00 - 6/13/2006 00:00 Operations Summary State witnessed BOPE test. Spotted 5 bbls 15.5 ppg pill. POOH wI 2-7/8" TCII tbg. LD same. 6/13/200600:00 - 6/14/200600:00 Operations Summary POOH with 2 7/8" tubing, PU BHA and RIH with section mill 6/14/200600:00 - 6/15/200600:00 Operations Summary Section mill 5 1/2" casing 6/15/200600:00 - 6/16/2006 00:00 Operations Summary OOH wI BOT Lockomatic Section Mill. Found cutters worn and missing btm of mill. LlH in rat hole. PU new mill. RIH. Set down @ 5473'. Worked pipe. Stuck @ 5473'. Unable to circulate. RI wI string shot. Back-off at #12 DC. Reverse Circulate (3) BU @ 4.7 bpm. POOH. Fish Left in Hole = (1) 3 1/8" D.C., Bit Sub, Tristate Lock -0- Matic Section Mill (Total Ftg = 37.49, EST Top of Fish = 5,435 rkb) Daily Operations 6/16/200600:00 - 6/17/2006 00:00 Operations Summary PU jars and bumper sub w/BHA. Attach to fish and attempt to circ (still packed off). Jar and beat repeatedly while pumping. Pipe freed up and POOH with fish. MU wear bushing tool. Latched and pulled Wear Bushing. Cleaned out same. Found metal shavings. MU Clean out assembly, RIH to 5500'. 6/17/200600:00 - 6/18/2006 00:00 Operations Summary Pump high visc sweep. Continue to RIH from 5495' to 6500' Pump walnut hull ~weep, followed with high visc sweep. continue to 7555', circ BU. Pump walnut I visc sweep. Tagged bottom of section milled at 7569'. Mix and pump dry job. POOH to top of BHA. lay down bumper sub, XO, wavey bottom hollow mill. PU Under reamer., RIH with drill collars. Mill from 7569 to 7572'. 6/18/200600:00 - 6/19/2006 00:00 Operations Summary Milling 5 1/2" casing from 7572 - 7598', Trip for cement stinger 6/19/200600:00 - 6/20/2006 00:00 Operations Summary Perform braiden head squeeze 6/20/200600:00 - 6/21/2006 00:00 Operations Summary POOH LD DP and BHA. Recieve BOP waiver from State. PU and RIH to 7082' and Tag Cement. Circulate. Test casing to 3000psi for 30 min. POOH to 6800' and hang tbg (kill string). Pump diesel in annulus for freeze protect. ND BOP. 6/21/2006 00:00 - 6/22/2006 00:00 Operations Summary ND BOP, NU tree, Release rig. RKB =18.0' TD= 10,945' ETD= 8,345' Drawn by: SLT/CRW CASING AND TUBING DETAIL SIZE WT GRADE CONN m TOP DTM, 20" 84 - - 92' 10-314" 40,5 K-55 - Surface 3,395' 7-5/8" 39 L-80 FL4S 6.625" Surface 1,542' 7-5/8" 33.7 L-80 HAS 6.765" !,542' 3,512' 7-5/8" 29.7 L-80 FL4S 6.875" 3,512' 4,611' 7-5/8" 33,7 SS-95 LT&C 6.765" 4,611' 7508' J)V Collar 7508' 7510' 7-5/8" 33.7 SS-95 LT&C 6.765" 7510' 8,338' 7-5/8" 39 SS-95 LT&C 6.625" 8,338' 10,438' Liner 5-lI2" 17 N-80 Hvd 513 4.892" Surf 8511' 5-lI2" 20 N-80 4.778" 10,230' 10,943' Tubilll! 3-1/2 " 9.3 N-80 8RD EUE. 2.992 " 9500' 10,290' 2-3/8" 1.995" 10,290' 10,308' JEWELRY DETAIL 1.791 .."....-w·_"""-..,,,.,;.·"'"". n 'i1'ROl\'I TO LCiÌiÚi] Interval Date 7861 7876 15' 77-3 06/04/06 Isolated 10450 10462 12' H 10/14/05 so ¡ate! 10466 10478 8' H 10/14/05 so [ate! 10515 10527 12' H4 10/14/05 so ate! 10530 10585 55' H5 10/14/05 so late! 10614 10632 18' H 10/14/05 soa 'a! 10638 10652 14' H 10/14/05 [so :O! 10658 10666 8' H 10/14/05 [so :el 10672 10686 14' H 10/14/05 [sola :e, 10745 10759 14' H 10/14/05 [so :e, 10763 10772 9' H 10/14/05 so e, 10787 10792 3' H 10/14/05 [so 'e! 10796 10802 6' H 10/14/05 so e, 08/2006 e MEMORANDUM e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ? 4.- &{ c¡ loc> P. I. Supervisor Ì" 11 DATE: June 5, 2006 FROM: Jeff Jones Petroleum Inspector SUBJECT: P&A SCU 428-05 Chevron PTO 182-199 June 5, 2006: I traveled to Chevron's SCU 428-05 well location in the Swanson River Field to witness the pressure test and wire line tag of an intermediate perforation isolation abandonment plug in this well. Ken Lucas was the Chevron representative at the site today. A cement retainer plug had been set in the tubing at 7753' MO prior to my arrival and the well bore below the retainer had been cemented. On my arrival the tubing was pressured up to 2500 PSI and held for 30 minutes with no pressure loss observed. The tubing is in communication with the inner annulus through an open sliding sleeve and the pressures were equal throughout the test. A 600 # wire line tool assembly was then run in the tubing and the top of the cement plug was tagged solidly at 7747' MD. Summary: I witnessed the pressure test and wire line tag of an intermediate perforation abandonment plug in Chevron's SCU 428-05 well in the Swanson River Field. Attachments: none X Unclassified Classified ªCd\NNEn .jUN 1 9 2006 Unclassified with Document Removed SCU 428-05 Sundry #306-165 e l f,.~ L'ì'ì . e Subject: SCU 428-05 Sundry #306-165 From: "Tyler, Steve L" <tylersl@chevron.com> Date: Tue, 23 May 200615:09:43 -0800 To: "Au be ton wI CC: "Wals, nt <eharness evro Winton As we discussed, the Posi-Set plug that was originally to be set at 8000' will not be run. We will increase our volume of cmt, to be injected through the retainer @ 7753', to 20 bbls (100 sx) Please call if you have any questions or concerns. Thank You Steve Tyler y ~" 'iI.j~..í ff'"Y' ~V!~ I)~\!C"., .;'" (,)i ~f,;.) Union Oil Company of California *Office: (907) 263-7649 *Cell: (907) 350-6295 *Home: (907) 696-1837 *Fax: (907) 263-7389 *Email: tylersl@chevron.com F;nma¡':d~~IC~~t~-~t- T;;~-:-==~p~ ¡catio~/~-=tn~~ 1 of 2 5/23/2006 3:22 PM e e (m~.: Ii II.! ,Jdj FRANK H. MURKOWSKJ, GOVERNOR ALASIiA OIL A1Q) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 \Q;;): Iqq Re: Swanson River Field, Tyonek 77-3 Gas Pool, SCU 42B-05 Sundry Number: 306-165 ·r~Àl1\î'~.·r····.· . .. ~'\In~tJ ~t....,- .10 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this /~day of May, 2006 Encl. 1. Type of Request: Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 177' RKB to MSL D ~ 8. Property Designation: Swanson River Unit 11. Total Depth MD (ft): 10,945' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 7,861 to 10,802' Packers and SSSV Type: 9. Well Name and Number: SCU 42B-05 / 10. Field/Pools(s): Swanson River Field/77-3, Tyonek PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 8,345' 8,307' < ~, ¡ . Suspend .j Repair well D Pull Tubing D Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D Total Depth TVD (ft): 10,900' Length Size MD 92' 20" 3,395' 10-3/4" 1 0,438' 7-5/8" 8,511' 5-1/2" 713' 5-1/2" Perforation Depth TVD (ft): 7,826 to 10,756' 2, Baker FH Packers; SABL 3 ~~A- . ~/',;12.00t, R"'; Waiyer Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ¡úiik Exploratory D Service / [] / I ~ Z - I CC9 6. API Number: 50-133-20363-00 / Plugs (measured): Junk (measured): 8,345' Collapse 8,395' TVD Burst 92' 92' 3,395' 3,394' 3,130 psi 1,580 psi 10,438' 10,393' 6,890 psi 4,790 psi 8,511' 8,472' 9,190 psi 8,830 psi 10,943' 10,897' 9,190 psi 8,830 psi Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8"/3-1/2"/2-3/8" L-80/N-80/N-80 7,811'/10,290'/10,308' Packers and SSSV MD (ft): 10,199' and 10,272'; 7,758' 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: 6/1/2006 Oil D Gas D Plugged [] WAG D GINJ D WINJ D .j Date: Conditions of approval: Notify Commission so that a representative may witness 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date COMMISSION USE ONLY Plug Integrity r6 BOP Test B" Mechanical Integrity Test D Other: T e~ t- 1S 0 P ff-o ~O 00 Subsequent Form Required: Approved by: Form 10-403 Revised 11/2004 Service [] ../ Abandoned D D WDSPL Steve Tyler 263-7649 .s - - é:X- Sundry Number: 5 Location Clearance D RBDMS BFl MAY 1 7 2006 APPROVED BY THE COMMISSION Date: ~/b -06 Submit in Duplicate e e Swanson River Field seu 42B-05 Operation Summary to suspend well Objective: The well SCD 42B-05 is located on the same pad as the planned new well, 42-05X, for completion into the gas storage sand, 77-3. SCD 42B-05 demonstrated a microanulus leak shortly after completion (see attachment A). The intent of the below described summary is to isolate the 77-3 sand from the microanulus leak to / surface. The requested suspension of the well is to enable Chevron, as operator, to confirm the complete isolation of the sand through the full injection and production cycle associated with the gas storage sand. to()O ' ¡J () *' /" y MIRU Eline. RlH wi Posi-Set pIa. Set pkr @ ~ POOH. Dump bail 10' of cmt on PosiSet. POOH. RD y WOC for 5 to 7 days y MIRU Slickline. RlH tag TOC wi bailer. RIH wi shifting tool. Open Sliding Slve @ 7744'. RD slickline y MIRU Eline. RlH wi 3-112" HES Cmt Ret wi poppet valve. Set same @ 7753'. POOH. RD. ./ ~ RU Cmtrs. Cir.culated/fill.wellbore. Establish injection rate & pressures. Mixlpump ,@bIS of G cmt down tbg. Launch Wiper ball. Displace tbg. ' y RU slickline RlH close sldg slve. RD slickline. y Turnkey MI & RU Drilling Rig y NU BOPE & choke/killlines & test / y y y y y y y ~ y y RU Eline. PU Tbg Hngr. RIH and Cut tubing @ 7700'. POOH. RD Eline. / PU LD Hanger POOH LD Tubing PU/MU Section Milling Assy. RIH on DP to 7600'. / Section Mill 5-112" csg from 7600' to 7650'. POOH. BO LD Milling assy. RIH OE DP to 7650'. LaY-in{1bbIS of G neat cmt plug from 7650' to 7300'. POOH LD DP. ND BOPE and install abandonment tree. / Release rig. RKB ;18.0' TJþ 10,945' ETD; 8,345' Drawn by: SL T SIZE WI' GRADE CONN II) TOP BT¡VL 20" 84 - - 92' 10-3/4" 40.5 K-55 - Sutface 3,395' 7-5/8" 39 L-80 FLAS 6.625" Surface 1,542' 7-5/8" 33.7 1.-80 FLAS 6.765" 1,542' 3,512' 7-5/8" 29.7 1.-80 HAS 6.875" 3,512' 4,611' 7-5/8" 33.7 SS-95 LT&C 6.765" 4,611 ' 7508' DV Collar 7508' 7510' 7-5/8" 33.7 SS-95 LT&C 6.765" 7510' 8,338' 7-5/8" 39 SS-95 LT&C 6.625" 8,338' 10.438' Liner 5- 112" 17 N-80 Hvd 513 4.892" Surf 8511 ' 5-1/2" 20 N-80 4.778" 10,230' 10,943' Tubing 3- 112 " 9.3 N-80 8RD EVE. 2.992 " 9500' 10,290' 2-3/8" 1.995" 10,290' 10,308' 0) 7861 10450 10466 10515 10530 10614 10638 10658 10672 10745 10763 10787 10796 7876 10462 10478 10527 10585 10632 10652 10666 10686 10759 10772 10792 10802 H H H4 H5 H H H H H H H H 10/14/05 10/14/05 10/14/05 10/14/05 10/14105 10/14/05 10/14/05 10/14/05 10/14/05 10/14/05 10/14/05 10/14/05 11/1/2005 RKB =18.0' 20" 84 92' 10-314" 40.5 K-55 Surtàce 3,395' 7 - 5/8" 39 L-80 FlAS 6.625" Surface 1,542' 7 -5/8" 33.7 L-80 FL4S 6.765" 1,542' 3,5J2' 7-5/8" 29.7 L-80 FlAS 6.875" 3,512' 4,61J' 7-5/8" 33.7 SS-95 LT&C 6.765" 4,61J' 7508' DV Collar 7508 7510' 7-5/8" 33.7 SS-95 LT&C 6.765" 7510' 8,338' 7-5/8" 39 SS-95 LT&C 6.625" 8,338' 10438' 17 N-80 H d 513 4.892" 8511 ' 20 N-80 4.778" JO,943' 6.4 L-80 TC II 2.441" Surface 7,81 l' 9.3 N-80 8RD EVE. 2.992 " 9500' JO,290' 1. 995" 10,290' J 0,308' TD= 10,945' ETD= 8,345' Drawn by: SL T 10515 10530 10614 10638 10658 10672 10745 10763 10787 10796 1.791 10527 10585 10632 10652 10666 10686 10759 10772 10792 10802 11/1/2005 SOU 428-05 Pressure Monitoring (Attachment A) e e SCU 428-05 Pressure Monitoring Date & Time Tubing 51/2" x Tbg 7 5/8" x 5 1/2" SC Comments 1/21/06 13:00 1854 0 0 0 1/21/06 14:00 1854 0 35 11 1/21/06 15:00 1855 0 50 12 1/21/06 16:00 1855 0 65 12 1/21/06 17:00 1855 0 82 12 1/21/06 18:00 1855 0 95 13 1/21/06 19:00 1855 0 112 13 1/21/0620:00 1855 0 125 13 1/21/0621 :00 1855 0 138 13 1/21/0622:00 1854 0 150 14 1/22/063:00 1858 50 205 16 1/22/069:00 1855 55 260 11 1/22/06 15:00 1850 55 302 9 1/22/0622:00 1861 55 348 6 1/23/063:00 1863.5 55 366 4 1/23/069:00 1860.5 55 396 2 1/23/06 13:00 1851.1 55 411 4 . 1/23/0621 :00 1865 55 428 1 1/24/06 3:00 1865.5 55 428 1 1/24/069:00 1862 55 428 0 1/24/0615:00 1850 55 427 0 1/24/0621 :00 1865 55 430 0 1/25/06 3:00 1865 55 430 0 1/25/06 15:00 1850 45 438 0 lölea Tor.jU min. lOOK l:Jas samples. Started taking gas from 42A-05. 5 to 6 1/25/0615:30 1850 45 430 0 mmcfpd 1/25/0621 :00 1844 50 435 0 1/26/062:51 1838 50 420 0 1/26/06 20:48 1818 50 420 0 1/27/063:05 1813 50 420 0 1/27/0620:56 1803 50 445 0 1/28/063:09 1798 50 465 0 1/28/06 9:00 1799 50 485 0 1/28/06 15:00 1793 50 504 0 1/28/0621 :03 1786 50 515 0 1/29/06 3:07 1784 50 523 0 1/29/06 9:00 1781 50 539 0 1/29/0614:15 1779 50 566 0 1/29/0621 :07 1775 50 595 0 Keaucea wltnaraw Trom 4LA-U:> (0 l.ö to 1/30/06 3: 1 0 1771 50 615 0 2.4 mmcfpd 1/30/069:00 1770 50 631 0 1/30/0615:00 1762 50 660 0 1/30/0621 :25 1761 50 680 0 1/31/062:58 1763 50 695 0 1/31/069:15 1762 50 711 0 1/31/06 15:00 1758 50 727 0 2/1/06 9:00 1786 75 765 0 e Date & Time Tubing 51/2" x Tbg 7 5/8" x 5 1/2" SC Comments 2/1/06 15:00 1790 75 780 0 2/1/0621:17 1793.5 75 788 0 2/2/063:10 1795 75 799 0 2/2/069:00 1796 75 813 0 Started flowing 42a-5 at 5mcfd at 10:00, 2/2/06 15:00 1770 75 835 0 then cut it to 3mcfd at 15:45 well 42A-5 is flowing at a rate of 2/2/0621:10 1765 75 847 0 3.5mmcf from 2/2/2006 10:00 am to 22:15 when the rate was increased to 2/3/06 3: 00 1750 75 860 0 5.2mmcf 2/3/069:00 1752 75 872 0 Flowing 42a-5 at about 5mcfd 2/3/06 15: 00 1754 75 885 0 2/3/0620:50 1730 75 898 0 42A-5 was flowing at a rate of 4.8 2/4/063:08 1725 75 901 0 mmcfd 2/4/06 9:00 1733 75 910 0 Flowing 42a-5 at about 5mcfd. 2/4/06 15:00 1741 75 915 0 2/4/06 21 :05 1739 75 917 0 2/5/06 2:53 1734 75 922 0 flowing 42a-5 at about 5mcfd. Shut-in @2/05/06 12:30 PM 2/5/06 9:00 1730 75 930 4 2/5/06 15:00 1737 75 930 5 42A-05 Sut-in 2/6/0621 :03 1763 75 955 17 2/7/063:10 1764.5 75 960 20 2/7/06 10:05 1765 100 966 20 2/7/06 15:45 1760 100 980 22 2/7/06 21 : 1 0 1772 100 985 20 2/8/063:00 1769 100 990 13 2/8/06 9: 15 1773 100 995 6 2/8/06 14:58 1774 100 1010 8 2/8/06 21 : 00 1774 100 1030 9 2/9/062:30 1773 100 1035 10 2/9/06 8:56 1773 100 1040 12 2/9/06 14:49 1776 100 1045 15 2/9/06 21 : 00 1772 100 1060 16 2/10/06 2:35 1774 100 1070 18 2/10/068:49 1779 100 1070 20 2/10/0614:51 1778 100 1080 22 2/10/0621 :00 1774 100 1090 22 2/11/063:00 1774 100 1090 24 2/11/068:57 1774 125 1100 25 2/11/06 14:55 1773 125 1100 26 2/11/0621 :00 1777 125 1120 28 2/12/06 3:00 1777 125 1120 28 2/12/069:08 1776 125 1120 30 2/12/0614:56 1776 125 1130 32 2/12/0621 :00 1779 125 1130 29 2/13/06 3:00 1781 125 1135 29 2/13/06 9:08 1780 125 1140 32 2/13/06 15:12 1777 125 1150 32 2/13/0621 :00 1779 140 1156 32 2/14/063:00 1782 145 1160 32 Date & Time Tubing 5 1/2" x Tbg 7 5/8" x 5 1/2" SC Comments 2/14/069:06 1783 145 1160 31 2/14/06 15:14 1772 145 1170 32 2/14/0622:00 1776 145 1178 32 2/15/06 2:45 1783 145 1179 29 2/15/068:55 1783 145 1180 31 2/15/06 15:07 1777 145 1190 30 2/15/0621 :00 1784 145 1200 31 2/16/063:00 1783.5 145 1200 32 2/16/06 9:22 1784.5 147 1198 32 2/16/06 15:05 1780 147 1205 33 2/16/0621 :00 1784 150 1205 34 2/17/063:00 1784.5 150 1210 35 2/17/069:12 1786.5 150 1210 35 2/17/06 15:40 1784.5 152 1222 36 2/17/0621 :00 1786 152 1222 37 2/18/06 3:00 1786.5 152 1225 37 2/18/06 8:40 1788 152 1230 38 2/18/06 15:40 1775 152 1240 39 2/18/06 21 :00 1783 152 1240 40 Slickline work. Pressure survey. lose of tbg pressue due to slickline work. 2/19/06 3:00 1783 152 1240 41 2/19/06 8:45 1783 152 1240 39 2/19/06 15:05 1783 152 1242 40 2/19/0621 :00 1786 152 1235 42 2/20/06 3:00 1786.5 152 1235 41 2/20/06 9:05 1776 152 1235 42 2/20/06 14:50 1777.5 152 1235 43 2/20/06 21 :00 1789.5 152 1230 43 2/21/063:00 1789.5 152 1220 43 2/21/069:20 1788 152 1214 39 2/21/06 15:35 1787.5 152 1217 39 2/21/0621 :00 1781 152 1210 35 2/22/063:00 1781 152 1200 29 2/22/06 10: 1 0 1789 140 1200 25 2/22/06 15:00 1783 140 1200 26 2/22/06 20:48 1790 140 1190 27 2/23/06 3:07 1794 140 1190 19 2/23/068:45 1790 140 1190 15 2/23/06 15:18 1790 140 1190 16 2/23/06 20:53 1794 140 1180 18 2/24/06 2:56 1794 140 1180 9 2/24106 9:45 1780 140 1185 2 2/24/06 13:30 1785 145 1180 Itslewaown I ~/ö x ~-lIL' annulus from 5 1200psi to 1180 psi. Found no ice. 2/24/06 14:45 1800 100 1200 6 2 hr injection test @ 2mmcfd rate. 2/24/06 15:45 1809 100 1221 8 13:45 to 15:50. 2/24/0620:43 1790 100 1160 9 2/25/06 3: 11 1798 125 1160 6 2/25/06 6:30 1799 100 1160 9 2/25/069:35 1795 125 1170 4 - . ·Date & Time Tubing 51/2" x Tbg 7 5/8" x 5 1/2" SC Comments 2/25/06 15:18 1800 130 1180 6 2/25/0620:15 1800 130 1190 6 2/26/063:12 1800 130 1170 4 2/26/06 9:35 1800 130 1170 5 2/26/0615:18 1796 125 1180 6 2/26/0620:51 1799 130 1180 8 2/27/062:57 1799 130 1180 6 2/27/06 9:35 1785 130 1190 5 2/27/06 15:18 1798 130 1200 9 2/27/0620:55 1799 130 1190 8 2/28/063:12 1799 130 1180 4 2/28/069:35 1780 130 1190 2 2/28/06 15: 18 1796 130 1220 2 2/28/0620:46 1803 130 1200 6 3/1/062:48 1801 140 1200 4 3/1/069:00 1780 140 1200 0 3/1/0615:30 1805.5 140 1218 0 3/1/0621 :15 1804 140 1215 0 3/2/06 3: 05 1803 140 1212 0 3/2/069:00 1803 140 1218 3 3/2/06 15:00 1804 140 1220 3 3/2/0621:10 1805 140 1217 4 3/3/063:15 1805 140 1215 4 3/3/0621 :35 1807 145 1220 5 3/4/06 3: 10 1808 145 1219 3 3/4/06 8:52 1806 145 1218 6 3/4/06 15:30 1806 145 1220 9 3/4/0621 :20 1808 145 1210 13 3/5/06 3: 1 0 1806 145 1203 18 3/5/068:40 1810 110 1200 0 3/5/069:05 1816 100 1200 0 Start injection @ 1.5 mmcfpd 3/5/069:10 1814 90 1190 0 Increse injection to 2.3 mmcfpd 3/5/06 9: 15 1824 80 1190 2 3/5/06 9:20 1825 80 1200 2 3/5/06 9:25 1825 80 1200 2 Increse injection to 2.4 mmcfpd 3/5/06 9:30 1825 80 1205 2 3/5/069:45 1825 80 1220 2 3/5/06 10:00 1826 65 1225 2 3/5/0610:15 1825 55 1235 3 3/5/06 10:30 1825 40 1240 3 3/5/06 10:45 1825 30 1240 4 Injection @ 2.3 mmcfpd 3/5/06 11 :00 1824 30 1240 4 3/5/06 11 :30 1824 6 1240 6 3/5/06 12:00 1821 0 1240 6 3/5/06 12:30 1878 0 1240 6 Increase injection to 5.7 mmcpfd 3/5/06 13:00 1879 0 1238 7 Injection @ 5.6 mmcfpd 3/5/06 13:30 1879 0 1230 8 3/5/06 14:00 1880 0 1230 8 3/5/06 14:30 1879 0 1220 8 e ," " e e r , Date & Time Tubing 51/2" x Tbg 7 5/8" x 5 1/2" SC Comments 3/5/06 15:00 1882 0 1220 8 3/5/06 15:18 1930 0 1240 8 Increase injection to 7.5 mmcpfd 3/5/06 15:25 1960 0 1240 8 Injection @ 8.5 mmcfpd 3/5/06 15:30 1961 0 1218 8 Injection @ 8.7 mmcfpd 3/5/0615:35 1931 0 1210 8 Injection @ 7.6 mmcfpd 3/5/06 15:40 1940 0 1203 8 Injection @ 7.7 mmcfpd 3/5/06 15:45 1944 0 1200 8 Injection @ 7.9 mmcfpd 3/5/0615:50 1947 0 1200 8 3/5/06 15:55 1948 0 1200 8 3/5/06 16:00 1948 0 1200 8 3/5/0616:10 1940 0 1200 8 ----- ------,"" Ground/Pad Level e e , -82. - I q't ¿ 5\8 ()~ RevIsed 5í16í05 ·l----·----·-----------·"·----·--~----· Rig Floor I j I 21" I L__Bottom of Rota!Y.Table__ 12" I ~ottom <!l~'!~ªmª_ - -I r-=-=-}--- ________ i I I I' : I 1_____ 51" I 1 I !------.-J I I n__~__~_.n____ , , r-- , I I I 45" , .-_.:.-::;--O'--~--.-- ¡ ____----..___-------¡----L__ 14" I --'----Y--n_--- ----------- __n_. j , ~IOW Nipple L __I ! 13 5/8" Annular 1 l ___Ln- , ,---------" II ~ 121" j' I 10'1" 34114" L------ -..--.-. --I 13518" Double Gate ! I i ! L__. ! --T-:¡..---------rn-- 2~" [~ 1=1135/8" Mud Cross t ,-' -, -T- I - I "--'-1 17 314" j j 13 518" Single Gate _____L--'::=--=}_____----' '-T- ------=~::---- __I;:'~--=+----+=----n--- I 36" Sub Base Skid o O' ot- ~~ ,-'-": 36" ---Jl I I 13 518" spacer Spool I L, " r 7 11~~.x_!.3_518~~~0_~~A__ II I 71116" 5,000 Flange .I j I 66" I I I ¡ ¡ J 4314''- L, I 30114" _1__ , , , I I 2' Skid Base ___L 6" Rig Mat Pad Ground L¡Yel Ç~('':,..l''i''''~¡;:.:~~, ~;\iit{t\J) ~0 '¡if_i)" (~ ~ ~q~'~ I ! I I L--__..~_.__._____..____.____________________________ 10' 00 Cellar 8' Deep 13 518" BOP Stack Wth 2' Skid System SWanson River Abandonment well o o o o.ci It) N o o C!¡., CON ,.... N e e Attachment A Kuukpik Drilling Rig 5 Inventory 5/8/06 Rig 5 is a winterized 400,000 pound rated Telescopic Double t at is containerized except for the substructure and derrick package. Capacity: · 11,500' rated depth (Capable of standing back 9, 00' of 4 W' drill pipe with 6 %" tool joints plus HW and BH ) or (12,000' of 3 1/2'" or 4" with 5 X" tool joints plus B A.) Drawworks: · Tesco Hydraulic Single Drum Drawworks, Lebus 1 1/8" drill line. The Drawworks is equipped with brakes, two calipers for the working brake. The h system is used as the dynamic brake. Rig Power (hydraulic): · Two Series DDEC IV Detroit Diesel. Maximum co tinuous power 600 kw (800 HP); maximum power 634 kw 850 HP) each. · Each engine driving 6 Linde HPV130 hydraulic pu ps. · Total rig hydraulic power 1,200 kw (1,600 HP). · These units provide power for the Drawworks, top drive and one mud pump. Mast: · Tesco 102' double telescoping, freestanding. · 40Q,OOO-pound maximum static hook load, with 8 ines. · Certified and built to API 4H specs. Substructure: · Tesco Swing Up 17' high x 12' wide x 40' long (Ia · Rig floor to ground with skid system is 23' · Casing capacity 400,000 pounds simultaneous wi h 200,000 pounds setback. · Substructure is designed to skid forward and bac maximum of 14'. UOCC/Kuukpik Drilling LLC Drilling Order 06.01 16 e e Crown Block: · Tesco maximum static load 400,000 pounds with sheaves, split block. Traveling Block/Hook: . Tesco 400,000 pounds split block. Swivel: . Tesco integrated swivel with top drive. Top Drive: · Tesco Model 250 HMI Top Drive (250 ton). · Maximum Torque 20,600 ft-Ibs, Maximum Spe d 175 rpm. · Includes all standard Tesco pipe handling and afety features. . 3" x 55' rotary hose. Rotary Table: · TSM 17.5" opening. Pump #1 and Pump #2 · #1 Pump: One each Ellis Williams WH 1000 A Tr plex: 6" x 10" stroke. · Powered by a Hagglund Hydraulic motor produci g 746 kw (1000 HP). · Equipped with PD 45-5000 pulsation dampeners. · Operating Range - 0 spm to 140 spm. · Maximum Allowables: (90% of manufacturer's specifications ). · #2 Pump: One each TSM 1000 HP triplex pump · Powered by one each 1000 hp AC electric drive otor · Equipped with PD 45-5000 pulsation dampener. · Operating range - 0 spm to 120 spm. · Maximum Allowables: (90 % of manufacturer's specifications). Mud System: UOCC/Kuukpik Drilling LLC Drilling Order 06.01 17 e e · Three tanks, 8' wide x 6'9" high x 20' long: six compartments. · -Active capacity 520 bbls. · -Trip tank 30 bbls. · -Pill tank 30 bbls. · 5 each 7.5 HP agitators. · Mixing room with 3 Mission 5 x 6 centrifugal pump @ 3600 rpm powered by 2 x 22.5 kw (30HP) and 1 x 30 k (40HP) electric motors. · Harrisburg mixing hopper. · Two each Derrick Flowline Cleaner Shale Shaker . · One each Swaco 518 centrifuge. Well Control System: Accumulator: · Control Technology Accumulator · 170 gallon reservoir · 12 each 15 gallon bottles · Nitrogen backup system · Complete with pneumatic pump and electric tr plex pump Choke Manifold: · 5,OOO-psi choke manifold mounted in a separa e container located next to the substructure. · One Willis 2" manual choke, one Master Flow " Hydraulic Remote Choke. · Choke line valves consist of one manual and 0 e Hydraulic valve. · Kill line valves consist of two each manual valv s. · One each 5,000 psi upper Kelly valve. · Two each 5,000 psi lower Kelly I Stab in safety valves. · Mud Gas Separator: (Gas buster) located in a separate building beside the sub/shaker building. · 30" diameter x 16' high; 3" inlet; 8" outlet. And 0" vent line UOCC/Kuukpik Drilling LLC Drilling Order 06.01 18 e e Diverter System: · One each 16" diverter system complete wit a 135/8" annular and diverter spool with one each 16" fl nged outlet. · One each 16" hydraulic operated knife valv · 100' of 16" diverter line complete with flang s, bolts and gaskets Vacuum Degasser: · One each Derrick vacuum degasser. B.O.P.s: · One each 13 5/8" 5,000 psi Annular · One each13 5/8" 5,000 psi Double Gate · One each 13 5/8" 5,000 psi Single Gate · One each 13 5/8" 5,000 psi Mud Cross with 3" utlets · One 135/8" 5,000 psi spacer spool 3' long · One each Flow Nipple · Ram Blocks included: a. Two sets 4 %" b. One set Blinds c. One set 2 7/8" to 5 %" VBR's BOP Test Pump: · One each triplex test pump electrically driven, ra ed at 4.6 gpm at 5,000 psi · Complete with pressure gauges, hoses, an valving. Instrumentation: · Weight Indicator -PLC controlled. · Sierra Monitor (digital) fixed system gas detec or for H2S and Methane gas. 3 station. Sensors located a the rig floor, bell nipple and shakers. · Two each GasTech Genesis portable hand hel gas detectors. · Pason Pen less Electronic Drilling Recorder · Pason (Pit Bull Model) Pit Volume Totalizer Tankage: · 150 bbl water tank. UOCC/Kuukpik Drilling LLC Drilling Order 06.01 19 e e · 7,500 gallon fuel day tank Portable Vacuum System: · One each 85 gallon portable vacuum system Light Plant Generators: · Two each 14 L Detroit Diesel Series 60 (600 HP each) generators. · These provide AC for the rig and power the #2 Pump. Hydraulic jacking systemIWelding unit: · One each 75 KW generator to power the porta Ie hydraulic unit used to raisellower the sub and errick and also the hydraulic power for skidding the rig. T is generator also is designed to provide power to an electric welding machine mounted in the building. Boilers : · Two each 80 HP Volcano Boilers complete wit a hotwell tank and a blow down tank. · Approximately 12 steam heaters located aroun the rig. Rotary Equipment: · Spinner Hawk hydraulic pipe spinner. · Cavins Air Slips 2 3/8" to 5 %" · 2 Sets 4 %" Drill Pipe Elevators · 2 Sets hand slips for 4 %" Drill Pipe · 1 Set 6 W' Drill Collar Slips · 1 Drill Collar Clamp · 2 Sets of Rig tongs · 1 Set Elevator Bails Drill String: · 11,000' of 4 %" drill pipe, Grade TSS 95 · 16.60 #/ft with TCS-8000 or equal hardfacing · NC-46 (4 %" XH) tool joints 6 3/8" 00 x 3 X" I · 600' of 4 %" Heavy-Wate DP 41 #/ft with NC-4 connections · 63/8" OD x 27/8" ID · 12 each 6 1/4" OD x 27/16" ID Drill Collars wit Connections UOCC/Kuukpik Drilling LLC Drilling Order 06.01 20 e e . Crossovers to be provided: a. Saver subs, 2 each NC-46 Pin down for T p Drive b. HW x DC x-overs, 2 each NC-46 box x 4 %" H-90 Pin c. Bit subs, 2 each 4 %" H-90 Box x 4 %" reg ox bored for float d. 2 each upper IBOP (top drive) valves - N Connections e. 2 each lower IBOP (top drive) valves - NC 46 Connections f. 2 each Full Opening floor safety valves - C-46 Conn. g. 1 each Dart Valve with NC-46 Connections h. 6 each Lift Subs for 6 %" Drill Collars that fi 4 ~ Elevators Forklift: · One each Caterpillar IT 62G complete with bu ket, forks and material handling stinger. Camp: a. 2 ea 9' x20' office units for Toolpusher and Co pany Man incorporated on integral skid. b. 2 ea 9' x20' bedrooms for Toolpusher and Co pany Man incorporated on integral skid. c. 1 ea. 12' x 52' combination kitchen unit, washr om and 4 bunk beds. Has fresh water and sewage holdi g tanks built into units. UOCC/Kuukpik Drilling LLC Drilling Order 06.01 21 SCU 428-05 - Withdrawal of 403 e Subject: SCU 428-05 - Withdrawal of 403 From: "Walsh, Chantal -Petrotechnical" <WalshC@chevron.com> Date: Man, 01 May 2006 13:42:30 -0800 To: Winton Aubert <winton_aubert@admin.state.ak.us> Winton, e \tt;t:' ,q,q The 403 application for SCU 428-05 submitted to your agency last week is not correct. We would like to withdraw this application and resubmit a correct filing for the job. Thank you, Chantal Walsh Chevron Contract Engineer (907) 263-7627 ^' . ' . ", \tf","'tf'; .v' .~...\""tr:"' ' ,,- ';\'\"~"-' .....,,:....., '. 1 of 1 ~~ G,) .1 5/1/2006 1 :46 PM . . . ALAe all AND ~~;~g~S~~;~ON COM~idl )...7/ ex APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 r\..... ~ _ Operational shutdown U Perforate U Waiver Lr I II ~ I Itlther U Plug Perforations 0 / Stimulate D Time E~. ~n¡;jpn Do I":'.." " AlaSKa CW (j( gas !.A.!I'ISe ¡. Perforate New Pool D Re-enter Suspended Well D ib"¡'¡'H:'i"~ 4. Current Well Class: 5. Permit to Drill Number: R.....CEIV"'>= :1 t: . . t: . . 1. Type of Request: Abandon U Alter casing D Change approved program D Suspend U Repair well D Pull Tubing D 2. Operator Name: 11. Development D / Exploratory D Stratigraphic D Service /21 6. API Number: 50-133-20363-00 / 9. Well Name and Nu~er: SCU 42B-05 -' /. 1 O. Field/poo~: Swanson 'J'er Field/77-3, Ty nek PRESENT WELL CONDITI,9N SUMMA ~Y Effective Depth MD (ft): Eff?,ve Depth TV[ (ft): { 7,300' / 7,270' ~i7f ] } D / , TVD ",!-/ )/ \ ^' 92' ,\) 20" J/ 92' fi V 92' 3,395' \ I 1 \-3/4" a rv / 3,395' 3,394' 3,130 psi 1,5BO psi 10,43B' I \ 7-VB"~Y / 10,43 '~ ' 10,393' 6,B90 psi - 4,790 psi B,511' I' '5-1~ '-I ~ <MolY B,472' 9,190 psi B,B30psi 713' Vl ~1f:; / .... ~ 943' 10,B97' 9,190 psi B,B30 psi Perfora~Depth TV ,'~ ~~/ Tubin ·z~ Tubing Grade: Tubing MD (ft): 7,B26 to \0,1f.i' ~ '\ -~" -1/2"/2-31B" L-BO/N-BO/N-BO 7,B11'/10,290'/10,30B' 2, Baker FH ~c\eV\: ì4 '\ r~\ and sr MD (ft): 10,199' and 10,272'; 7,7;ß' \ to-I) 'A \ µ~ 12. Attachments: Description Summa~ Pro, ~ \ yr. Vi e 9s~ after proposed work: Detailed Operations Program D Bc¡Þ Sket D \.. \ / Explc ~ ~ tJ Development D 14. Estimated Date for / 7]) ~/' II tatus after proposed work: Commencing Operations: ( 5/1þ606,øfi \C ] Gas D Plugged 16. Verbal Approval: / Date: ""=:::. - WAG D GINJ D WINJ Commission Representative\ 17. I hereby certify that the fo~going isJrue and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy <\. Bra~enbUrg Title Drilling Manager Signature 7 ~ c I/Y ~ Phone 907-276-7600 Date o \//7 v¡,...-- ^ 1/2.-l'lQ ~61t- Union Oil Company of Califomia 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 177' RKB to MSL B. Property Designation: Swanson River Unit Total Depth MD (ft): 10,945' Total Depth TVD (ft): 10,900' Plugs (measured): Junk (measured): n/a n/a Casing Length Burst Collapse Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 7,B61 to 10,B02' Packers and SSSV Type: Service 0/ o D Abandoned D D WDSPL L/ - 2-( - 0 Ç::o COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,j 0&:'-1:::; .3 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RBDMS 8FL MAY (I :¡ 2006 Subsequent Form Required: Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: Form 10-403 Revised 11/2004 OR\G\NAL Submit in Duplicate e e # Date: April 27, 2006 To: File ~~~%~t: ~~~:d~~:sO? ~ÂJ / ! Chevron has requested approval to~lug Zone 77-3 perforations in Swanson River gas storage well 42B-05. The well has pressure communication between 2 strings of pipe. Plans are to plug these perforations and drill a new storage well in the same zone. PI A of 42B-05 should occur later after verification that the leak has been fully plugged. I recommend approval of this sundry request. e e Swanson River Field seD 42B-05 fl Operation Summary to Plug 1'];13 Sand ~ MIRU Eline. RIH wi Posi-Set pIa. Set pIa @ 7910'. POOH. Dump bail 1 0' of cmt on PosiSet. POOH. RD ~ WOC for 5 to 7 days ~ MIRU Slickline. RIH ta~.ag T wi bailer. RIH wi sbifting tool. Open Sliding Slve@7744'.RDslickline ~ MIRU Eline. RIH wi WHES Cmt Ret wi poppet valve. Set same @ 7753'. POOH. RD. ~ ~ RU Cmtrs. Circulated/fill wellbore. Establish injection rate & pressures. MiX/PU~S of G cmt down tbg. Launch wiper ball. Displace tbg. - ~ RU slickline RIH close sldg slve. RD slickline. ~ Turnkey MI & RU Drilling Rig ~ NU BOPE & chokelkilllines & test / ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ RU Eline. PU Tbg Hngr. RIH and Cut tubing @ 7700'. POOH. RD Eline. PU LD Hanger POOH LD Tubing PU/MU Section Milling Assy. RIH on DP to 7600'. Section Mill5-l/2" csg from 7600' to 7650'. /~ POOH. BO LD Milling assy.-\ RllI DE DP to 7650'. LaY-~lS ofG neat emt plug from 7650' to 7300'. POOH LD DP. ND BOPE and install abandonment tree. / / Release rig. RKB =18.0' TD= 10,945' ETD= 8,345' Drawn by: SL T SIZE WT GRAin: CONN m TOP !JTM, 20" 84 - 92' 10-3/4" 40.5 K-55 - ~I Surface i5' 7-5/8" 39 L-80 FL4S 6.625" e 12' 7-5/8" 33,7 L-80 FL4S 6,765" 2' 2' 7-5/8" 29.7 L-80 FL4S 6.875" 3,5]2' l' 7-5/8" 33,7 SS-95 LT&C 6,765" 4,61 ]' )8' DV Col1ar 7508' 7510' 7-5/8" 33,7 SS-95 LT&C 6.765" 7510' · 8,338' 7-5/8" 39 SS-95 LT&C 6.625" 8,338' 10,438' Liner 5-112" 17 N-80 Hyd 513 4.892" Surf 8511' 5-112" 20 N-80 4,778" 10,230' 10,943' Tubin!! 2-7/8" 6.4 L-80 TC II 2.441" nmr 7,811' 3-1/2 " 9.3 N-80 8RD EVE. 2.992 " 9500' 10,290' 2-3/8" 1.995" 10,290' 10,308' I"ROIVI IO IAtlllllb 11I.I\!1'Y1I1 P1I1", 7861 7876 15' 77-3 Perf'd w/3-1/2" PJ OmegaTCP Gun 10450 10462 12' H 10/14/05 Iso I¡le( 10466 10478 8' H 10/14/05 Iso la!'!! 10515 10527 12' H4 10/14/05 1so lae( 10530 10585 55' H5 10/14/05 Iso e( 10614 10632 18' H 10/14/05 Iso la€H 10638 10652 14' H 10/14/05 1so e( 10658 10666 8' H 10/14/05 1$0 e( 10672 10686 14' H 10/14/05 1$0 e( 10745 10759 14' H 10/14/05 Iso e( 10763 10772 9' H 10/14/05 Iso e< 10787 10792 3' H 10/14/05 Iso e( 10796 10802 6' H 10/14/05 Iso e< 11/1/2005 .. RKB ;18.0' 20" 10-3/4" K-55 Surface 7-5/8" L-80 HAS 6.625" Surface 7-5/8" L-80 HAS 6.765" 1,542' 7-5/8" L-80 FL4S 6.875" 3,512' 7-5/8" S8-95 LT&C 6.765" 4,611 ' 7508' DV Collar 7508' 7510' 7-5/8" 33.7 SS-95 LT&C 6.765" 7510' 8,338' 7-5/8" 39 SS-95 LT&C 6.625" 8,338' 10,438' Liner 5-1/2" 17 N-80 H d 513 4.892" 5-1/2" 20 N-80 4.778" Tubin 2-7/8" 6,4 L-80 TC II 2.441" 3-1/2 " 9.3 N-80 8RD EVE. 2,992 " 2-3/8" 1.995" TIÞ 10,945' ETIÞ 8,345' Drawn by: SLT 10,199' 10 ,206' 10,272' 10,307' 10,308' 2,875 1.791 7861 10450 10466 10515 10530 10614 10638 10658 10672 10745 10763 10787 10796 7876 10462 10478 10527 10585 10632 10652 10666 10686 10759 10772 10792 10802 12' 55' 18' 14' 8' 14' 14' 9' 3' 6' 11/1/2005 LPt,. L'l? Chevron === Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com January 17, 2006 REceIVED JAN 1 7 2006 Alaska Oil & Gas Cons. Commission -"'. Anchorage Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 Re: SCU 42B-05, Soldotna Creek Unit Dear Mr. Aubert, The recently converted gas storage well, SCU 42B-05 has shown pressure anomalies in the 5-1/2" by 7-5/8" annulus. The 77-3 sand has been injected with approximately .25 BCF. The current surface pressures are 1865psi on the tubing and 240psi on the 5-112" by 7-5/8" annulus. It is important to note the pressures are contained within the 7-5/8" casing which was tested to 2000psi surface pressure, over an 8.4ppg fluid column, during the workover and has an internal yield rating of 3000psi. At this time, all injection and production into and out of the 77-3 sand has been stopped. Unocal plans to run diagnostics to identify the full extent of the mechanical issue. During diagnostics the pressures will remain below the tested pressure of the casing. With these results we will identify the forward plan to either remediate the existing completion or abandon the well bore. Attached for your reference is a schematic showing the current configuration of the well. If you have any questions, please contact me at 263-7657. Sincerely, ~ ---:~ ~? . ~"f' " ,,< ~ .' /' Cd ç"'~/ Timothy G~enbUrg " ~ - " Drilling Manager "..~ .... '^ 1>\.,,& üÏ; ~Hill~L7~~[} f',. ,,¿ t TCB:sk Attachments cc: Dave Whitacre Phil Ayer Jeff Smetanka Larry Greenstein Evan Harness Steve Tyler Chris Myers Union Oil Company of California / A Chevron Company http://www.chevron.com RKB =18.0' SIZE \-\iT GRADE CONN II) TOP BTM. 20" 84 - - 92' 10-3/4" 40.5 K-55 - Surtàce 3,395' 7-5/8" 39 L-80 FL4S 6.625" Surface 1,542' 7-5/8" 33.7 L-80 FL4S 6.765" 1,542' 3,512' 7-5/8" 29.7 L-80 FL4S 6.875" 3,512' 4,611 ' 7-5/8" 33.7 SS-95 LT&C 6.765" 4,611' 7508' DV Collar 7508' 7510' 7-5/8" 33.7 SS-95 LT&C 6.765" 7510' 8,338' 7-5/8" 39 $$-95 LT&C 6.625" 8,338' 10,438' Liner 5-112" 17 N-80 Hvd 513 4.892" Surf 8511 ' 5-1/2" 20 N-80 4.778" 10,230' 10,943' Tubillfl. 2-7/8" 6.4 L-80 TC II 2.441" $ urtàce 7,811 ' 3-i/2 " 9.3 N-80 8RD EUE. 2.992 .- 9500' 10,290' 2-3/8" 1995" 10,290' 10,308' 7861 7876 15' 77-3 Perfd w/3-1/2" PJ Omega TCP Gun 10450 10462 12' H 10/14/05 10466 10478 8' H 10/14/05 10515 10527 12' H4 10/14/05 10530 10585 55' H5 10/14/05 10614 10632 18' H 10/14/05 10638 10652 14' H 10/14/05 10658 10666 8' H 10/14/05 10672 10686 14' H 10/14/05 10745 10759 14' H 10/14/05 10763 10772 9' H 10/14/05 10787 10792 3' H 10/14/05 10796 10802 6' H 10/14/05 TD= 10,945' ETD= 8,345' Drawn by: SLT 11/1/2005 ') Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com ') UNOCAL Debra Oudean Technologist Date: January 5, 2006 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 . e... Jìl!J1 \I\~: it)) ~ ¿nUb §fC~\NNE~) ,~I1":\\ ~ Î' (,.', .' ~~~~'JIu.Ð! - scu .:0~~:.~._,~~~~~_____:~~~..__..,_~___,.,_~~~~:~~..._.._._.~..~~.~~~_._~~;._...I.~;~~..:~:..~~~_~~~~.~,~__~¡~~:~.._. \199-054 501331012501 SCU 21A·09 COMPLETION RECORD 2.5 HSD 5 INCH 12/6/2005 10100-10460 1 pds I 'OMEGA POWERJET 6 SPF, 60 I, DEGREE PHASED ;160-0'¡6 1501 DIOl6800 ISCU 343-33' [COMPLETION RECORD 2" 15 !rICH IOlI9120ÚS IÛ3ìO'10592 II II 11 I PdS' OMEGA POWERJET HSD ¡160·0.¡6 15013310168(1) ISCU 3-1J.3j ICOMPLETlOrJ RECORD 1 11/1615 IrlCH 111¿O/2fJeJ') IÛS62-I0t3Úì II 11 1 llp,jS 'pdt I POWER PIVOT Gur~s !182~199_ 150133203630,)-rSCU~28.Õ5 ìT~P CORRELATIOI·J C-R CCL----I~INCH-I-IO/3012005!7:ïi6~78ii8--II--- - r-, --I -'I PdS-- ,_ I '182-199 1501332036300 SCU -128-05 [RESERVOIR SA TURA TIOr J 51r1CH ' 1012t)l2005 6190·8055 ,11 1 I[ Ilpd~., IJS I : TOOL SIGMA MODE I i182~99-" 50i332036300 SCU42B-"OS- ~~~E~M!~~D~~~~N~R~~~F5·INCii·· ·10129/2005 5450-8401---1--- ·--1··..1-1Pds~¡;d'l l~ã~1-~~:~- ~.i~~~~363~Õ-SCU·;¡~~~~--:~~~~-~~~ÑC~:~~~.~_~ES.7·-: 5:I~CH-·riõ~~~5-7~~Õ~~~4~···]~---:·:::~··~·-·~-1·~·~t~:~==] Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received 8~ib1i& ~h Date: DI / 'DI pi {)[P _ STATE OF ALASKA _ ALA. OIL AND GAS CONSERVATION COMM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 1 4 2005 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool D Perforate D 4. Current Well Class: Development EI Stratigraphic D A'aska Oil & Gas Cons. Commission Other oJ as WaiverD Time Extension D injection well. Re-enter Suspended Well D 5. Pern1it to prillt .umber: Exploratory Di,....' Service D . 6. API Number: 50-133-20363-00 1. Operations Abandon Repair Well Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator Union Oil Company of California Name: 7. KB Elevation (ft): 177' RKB to MSL. 8. Property Designation: Soldotna Creek Unit 11. Present Well Condition Summary: 9. Well Name and Number: SCU 42B-05 10. Field/Pool(s): Swanson River Field/77-3 Total Depth measured 10,945' true vertical 10,900' feet feet Plugs (measured) 8,395' Junk (measured) Effective Depth measured 8,395' true vertical 8,356' ~::: ~CANNELJ UI:C 1 6 2005 Casing Length Size Structural Conductor 92' 20" Surface 3,395' 10-3/4" Intermediate 10,438' 7-5/8" Liner 8,511' 5-1/2" Liner 713 5-1/2" MD TVD 92' 92' 3,395' " 3,394'- . 10,438' 10,393' 8,511' 8,472' 10,943' 10,897' Burst Collapse 3,130 psi 6,890 psi 9,190 psi 9,190 psi 1,580 psi 4,790 psi 8,830 psi 8,830 psi Perforation depth: Measured depth: 7,861 to 7,876' (see schematic for isolated) True Vertical depth: 7,826 to 7,841' Tubing: (size, grade, and measured depth) 2-7/8" 6.4#, L-80 @ 7,811" 3-1/2" 9.3# N-80 @ 9,500'-10,290'; 2-3/8" @ 10,290-10,308' Packers and SSSV (type and measured depth) 2 Baker FH packers @ 10,199' and 10,272'; Sabl3 Pkr@ 7,758' 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla RBDMS BFL NOV 1 f, 2005 Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 66 600 3,967 0 200 15. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: Oil D Gas D WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 14 o Tubing Pressure 150 1,080 Service EI x D GSTOR EI WINJ D WDSPL D Sundry Number or NIA if C.O. Exempt: 305-299 Contact Steve Tyler 263c7649 Printed Name Timothy C. Brandenburg Signature Title Drilling Manager Form 10-404 Revised 04/2004 Phone 907-276-7600 t 164620 Date II /0- 05 Submit Original Only ~ Run on RKB =18.0' TOP 20" 84 92' 10-314" 40.5 K-55 3,395' 7-5/8" 39 L-80 FlAS 6.625" 1,542' 7-5/8" 33.7 1.r80 FL4S 6.765" 3,512' 7-5/8" 29.7 L-80 FL4S 6.875" l' 7-5/8" 33.7 SS-95 LT&C 6.765" 7508' DV Collar 7510' 7-5/8" 33.7 SS-95 LT&C 8,338' 7-5/8" 39 88-95 LT&C 10,438' Liner 5-1/2" 17 513 5-1/2" 20 10,943' T 6.4 1.r80 TC 11 2.441" 3-112 " 9.3 N-80 8RD EUE. 2.992 " 2-3/8" 1.995" 10,290' TD= 10,945' ETD= 8,345' Drawn by: SLT 11/1/2005 e e Primary Job Type Abandon Zone Jobs prtmary Job Type Abandon Zone Daily Operations 10/3/200500:00 ·10/4/2005 00:00 Operations Summary PJSM. RU slickline. RIH with GR. Pumped xylene, Able to run in hole with 2.85" GR to 10,274'. POOH. RIH with 1.75" GR to 10,596'wlm. RD slickline and secure well. 10/4/200500:00 -10/5/200500:00 Operations Summary PJSM. RU slickline. RIH with wireline brush and brush from, 10,200' to 10,265'. POOH. RIH with 2.66" swedge. POOH. 10/5/200500:00 -10/6/2005 00:00 Operations Summary PJSM. Work on tree. 10/6/200505:30 -10m2005 00:00 Operations Summary SIMOPS. Working on tree. Address packoff seals. Test. Secure well. 10m2005 00:00 ·10/8/2005 00:00 Operations Summary SIMOPS with production and construction. Prep pad. 10/8/200500:00 -10/9/2005 00:00 Operations Summary 10/9/200500:00 ·10/10/2005 00:00 Operations Summary 10/10/200500:00 -10/11/2005 00:00 Operations Summary SIMOPS. Prepped pad. 10/11/200500:00 -10/12/2005 00:00 Operations Summary SIMOPS. PJSM. RU eline. RIH with 3-1/2" EX-SVB drillable packer. tbg press = 1020 psi, csg press = 500 psi. Set packer at 10230'. RIH wI 1-9/16" x 6' tbg punch. Perfed 3-1/2" tbg from 10172 to 10178, 23 holes, 0 degrees phasing. Pressure equalized after shooting guns POOH. RD eline. 10/12/200500:00 ·10/13/2005 00:00 Operations Summary SIMOPS with production and construction. PTSM. Removed tree. Spotted and RU coil tubing. Stabbed coil onto connector and pull tested. Contacted AOGCC for BOP test. Test waved by BLM. Ran tests on rams. 10/13/200500:00 ·10/14/2005 00:00 Operations Summary Blowdown tbg and tbg x csg annulus. SIMOPS with production and construction. PJSM. MU BHA. RIH with stringer for 3.5" EZ drill SV squeeze packer. Pump coil tubing volume 34 bbls while tripping in hole. Tag packer at 10196', PU and set down 4 times with 5000 - 7000 pounds weight.Pumped 20 bbls lease water down tbg to establish injection. Batch mixed 15.8 ppg cement. Pumped 3 bbls water lead. Issue with check valve in retainer. Pumped 40 bbls lease water. Achieved a 1.4 bpm rate. POOH with coil to remove check valves. RU N2 and blow down coil. Stand back injector head and secure well. 10/14/200500:00 ·10/15/2005 00:00 Operations Summary SIMOPS with production and construction. PJSM. RU and fill tbg and csg with lease water. MU BHA and fill coil with lease water. Shell test. RIH with stinger for retainer. Tag retainer. Establish circulation. Stab into retainer. Could not pump. Attempted to establish injection several times by picking up and setting down. Contacted AOGCC for approval to lay 10 bbls cement plug on top of retainer. Batch up cement. With coil 10' above retainer, pump 5 bbl spacer, 10 bbls 15.8 ppg cement, with 24 bbls water to put cement at end of coil. Layed balanced pulg in tbg and tbgx csg annulus (10188' - 9938' CT measured) POOH. Monitor Tbg and Csg. Blow down coil with N2 and RD. e e Unocal - Alaska SWW Daily Operations Summary Well Name SCU 42B-5 Primary Job Type Recompletion Jobs Primary Job Type Recompletion Field Name SWANSON API/UWI 501332036300 pnmary Well bore Affected Main Hole Lease/Sana! FEDA028996 -- Job Category Recomplete Objective Daily Operations 10/15/200500:00 -10/16/2005 00:00 Operations Summary SIMOPS. Prep surface location. t . II II II II II II Operations Summary SIMOPS with production. PJSM. Stage surface equipment. RU eline. RIH with 2.7 GR and tag at 9736'. POOH. RIH with 2.7" cutter. Positioned cutter at 9505'. Cut tbg. POOH. Pumb 3 bbls diesel down tbg and take returns from annulus. RD eline. RU and jug test tbg and csg to 2500 psi. 10/17/200500:00 -10/18/2005 00:00 Operations Summary SIMOPS with production. PJSM. Prep surface area for rig move. 10/20/200500:00 ·10/21/2005 00:00 Operations Summary MOBE rig. 10/21/200500:00 -10/22/2005 00:00 Operations Summary MOBE rig. 10/22/200500:00 -10/23/2005 00:00 Operations Summary MOBE rig. 10/23/200500:00 -10/24/2005 00:00 Operations Summary MOBE rig. 10/24/200500:00 ·10/25/2005 00:00 Operations Summary Check string pressures. All pressures zero. NO tree. NU BOPs. Test BOPs with AOGCC witness. 10/25/200500:00 -10/26/2005 00:00 Operations Summary Test floor valves. MU subs and test manual BOP. MU landing joint. Back out hanger lock down screws. PJSM. Pull hander and LD same. Circulate BU. POOH 3-1/2" tbg. LD same. PU BHA. RIH wI 6.4" string mill on 3-1/2" tbg. 10/26/200500:00 -10/27/2005 00:00 Operations Summary Finish RIH with bil and 6.4" string mill on 3-1/2" tbg. to 9013'. Pump 34 bbl40 visc pill. POOH UD 3-1/2 8rd tbg. LD BHA. RU Eline. Hold Safety meeting. RIH with Neutron Sigma RST Log. Log 8070' to 5113' WL. POOH. LD logging tools. PJSM PU 7-5/8" EZ SBV Bridge Plug. Attempt to RIH with plug. 10/27/200500:00 -10/28/2005 00:00 Operations Summary RIH with 7-5/8" EZ Drill Bridge plug. Had issues setting tool. Slips set at approximately 9522'RKB. Sheared JDC and POOH. PIU BOP's Dress 7-5/8" casing stub. NU 11" Csg Head. Test secondary 7-5/8" seals to 1000psi. (good). Issues testing the secondary seals to 3000 psi. Consulted with town. 10/28/200500:00 -10/29/2005 00:00 Operations Summary Pull csg head spool and dress seals for 7-5/8" csg stub. RU eline. PJSM. RIH and tie in to RST log from 10/26105. Set EX CIBP at 8543' W/L. PU two collars and RIH and set on Bridge Plug. POOH. RD eline. Shell test BOP's against Bridge Plug. 10/29/200500:00 -10/30/2005 00:00 Operations Summary RU cementers. PJSM. Pump 5 bbls water, 4 bbls CW100. Pressure test to 5000 psi. Pump 16 bbls chem wash. Drop bottom plug. Pump 20 bbls mud push. Pump 90 bbls, 14.5 ppf cement slurry.. Batch 15.8 cement slurry with gasblok. Pump 50 bbls tail slurry. Drop top plug. Pump 197 bbls 8.4 ppg lease water. Plug bumped at 3500 psig. Pressure up plug to 4500 psi. RD cement. PU BOP's Cut and dress 5.5" csg stub. Lower BOPs and drop 2' spacer spool. Add 2-7/8" tbg spool and 7-1/16"x11"DSA. Test void on 5.5" csg spool to 5000 psig (good). RU eline. RIH with SCMT Cement Bond Log. Tie in. Bond log pass from 8414' to 5440'. Repeat. POOH RD eline. RU wireline. set test plug Test pipe rams. 10/30/200500:00 -10/31/2005 00:00 Operations Summary PJSM. PU guns and bottom hole assembly, RIH. PU and RIH with 2-7/8"6.4# TCII tbg. , 172 jts. PU chem injection mandel. Test conections. Set in slips. Chem line pressure good. RU wireline. RIH and pull control line sleeve. RD wireline. RU eline. RIH with GR CCL and tie in. RA sub is tiede in and ompletion string is spaces out. Pick up pup joint and hanger for space out. Land hanger. Lock down hanger. e e Unocal - Alaska SWW Daily Operations Summary Well Name SCU 42B-5 Field Name SWANSON APIIUWI 501332036300 lease/Serial FEDA028996 Ori9 KB Elev (IIKB) Water Depth (It) 177.0 Daily Operations 10/31/200500:00 ·11/1/2005 00:00 Operations Summary RU wireline. PIH with N-test tool. Pressure up to 4500 psi on tbg and set packer. POOH. Pressure up annulus, tbg x 5.5"csg. MIT against packer. Pressured up to 4500 psi for 30 minutes (good test). RIH with BO shifting tool. Shift sleeve down. POOH RD wireline. RU wo circ packer fluid on test joint. String in 1 bbls of CRW - 132 packer fluid. BIO landing joint. PIU stack. N/U tree. Pressure test tree. Set BPV in hanger. 11/1/2005 00:00 - 11/212005 00:00 Operations Summary RD Nabors 129 rig. 11/2/2005 00:00 - 11/3/2005 00:00 Operations Summary Continue to RD Nabors 129 rig. 11/3/200500:00 ·11/4/2005 00:00 Operations Summary Surface cleanup of pad. 11/412005 00:00 - 11/5/2005 00:00 operations Summary No operations 11/5/200500:00 -11/6/2005 00:00 Operations Summary -Displace tubing with N2, Freeze protect shift sleeve closed. perforate bring on well and hand over to production 11/61200500:00 - 11/7/2005 00:00 Operations Summary Demobe and clean pad 11m2005 00:00 . 11/8/2005 00:00 Operations Summary Demobe and clean pad [Fwd: SCU 42B-05 Hemlock Abandonment] ) ! :Y2 - ¡c¡(( ~..~.bJ~.Þ~~··.IÞWq·:..·~.·~.~··.·412·~·~05.··.·H··~rT11.ock...AÞ~nøO.9·.rr·~·nt.~ ~.~9rn:·..Vf!J.int99 ·..~9R~~.··~V1{in.t?n"7é:1.~.b~.~.~ßdrn i.n ,·s~a.te.·¡Ç)·k; us> ~Å1EJ:rv1öOt 17 Øót20Q!\5.Q8:0():1~0800 . .. .~ ) -------- Original Message -------- Subject:SCU 428-05 Hemlock Abandonment Date:Fri, 14 Oct 2005 14:42:48 -0800 From:Tyler, Steve L <tvlersl@unocaLcom> To:Aubert, Winton wI AOGCC <winton aubert@admin.state.ak.us>, Porhola, Stan <stan porhola@ak.blm.ÇJov> CC:Walsh, Chantal-Petrotechnical <walshc@unocal.com> -'\~~ \~~ Winton and Stan We stab into the cement retainer at 10,230' wI CT but are unable to pump through the retainer. We would like to place the 10 bbls of cement above the retainer and production to achieve a TOC of 10,000'. As depicted in the proposed diagram. Thank you ~ÇANNED NOV 0 ~ 2.0D5 Drilling Foreman Chevron Alaska (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 Content-Type: application/msword 428-05 Proposed P&A.doc Content-Encoding: base64 1 of 1 10/17/2005 8:01 AM u o ;- Drawn by: SL T 10/17/05 (ñ) '.". .~ ") ® ~-;;::¡ 11 1~ II ~ """"""1 - .. ;1 j !~ ~1 'ì j '1-:1 ~ AI',ASIiA. OILAlVD GAS CONSERVATION COMMISSION Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 , ¡ j I I j ¡ I / ¡ ! / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~ "JOD''» ~ANNEL.: NO" 0 ('} t. \5 Re: Swanson River 42B-05 Sundry Number: 305-299 ~..~ "'."'i'~;;' ',:-~,,~r1 " , ,., '¥~ " " "" . Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the approval in the event it was erroneously issued. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Qincere¡y Daniel T. Seamount, Jr. Commissioner --r"- DATED this ) D day of October, 2005 Encl. e e Chevron === Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com September 30, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: SCU 42B-05, Soldotna Creek Unit Sundry for Conversion to Storage Service Dear Mr. Aubert, Attached is a Form 10-403 Application for Sundry Approval to work over the well SCU 428-05, and recomplete the well for gas storage service. The actual commencement of gas storage will not take place until a gas storage injection order is granted by your agency and a gas storage lease is granted by the BLM. The well will only be utilized as a gas storage well providing all requirements noted in the order have been met. Attached for your reference is a procedure, a schematic showing the current configuration of the well and a schematic showing the planned recompletion. If you have any questions, please contact me at 263-7657. Sincerely, ?--yc Timothy C. Brandenburg J?~c.s s. IV~ ~~, (p 3 0 'D O¡;t'G 2005 ~ ~$, Co .~ Y1J1lJ¡, TCB:sk Attachments cc: Dave Whitacre Phil Ayer Jeff Smetanka Larry Greenstein Union Oil Company of California / A Chevron Company http://www.chevron.com , C/lJ-/ð ·fJ.O )' \I-J G l\- I chlWJo~ -. STATE OF ALASKA . PTJ /C)//O Is . AL.A: OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: Abandon U Suspend 0 Operational shutdown U Perforate U Waiver U / Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Convert to gas Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 injection well 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory 0 182-199 /' 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-20363-00 ,/ 7. KB Elevation (ft): 9. Well Name and Number: 177' RKB to MSL SCU 42B-05 ,/ 8. Property Designation: 10. Field/Pools(s): Swanson River Unit Swanson River Field/Hemlock / 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10.945' 10,900' 10,945' 10,900' n/a n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 20" 92' 92' Surface 3,395' 10-3/4" 3,395' 3,394' 3,130 psi 1,580 psi Intermediate 1 0,438' 7-5/8" 1 0 ,438' 1 0.393' 6.890 psi 4,790 psi Production Liner 713' 5-1/2" 10,943' 10,897' 9,190 psi 8,830 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,450 to 10,802' 10,405 to 10,756' 3-1/2"/2-3/8" N-80/N-80 10,290'/10,308' . Packers and SSSV Type: 2, Baker FH Packers Packers and SSSV MD (ft): 10,199' and 10,272' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/1/2005 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ -B- ¡,J6Æ WINJ 0 WDSPL 0 Commission Representative: qSTo~ I~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Branden~urg Title Drilling Manager - Signature '7-~c /} ~!1one 907-276-7600 Date 9- '2'7-0S- c:7 Þ COMMISSION USE ONLY -- Sundry Number: ~. 2qq Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test g' Location Clearance 0 RECEIVED Mr:T N1~~d. Other: ì\vi 4,'cv.- o y d..e Y:' rvtl~~A ~ M{'~~5 ^,pptVlVtJ stor~v fh,O( Oil S"b,.q"."tFonnR~ RBDMS 8Ft. 0 CÎ 11 2U05 & Gas Cons. Commission Anchorage IDflo!5 Appm". by' ~ APPROVED BY COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 11/2004 Submit in Duplicate PBTD = 10,911, TD = 10,945 10-3/4" 40.5 K-55 Surface 3,395' 7-5/8" 39 L-80 FIAS 6.625" Surface 1,542' 7-5/8" 33.7 L-80 HAS 6.765" 1,542' 3,512' 7-5/8" 29.7 L-80 FUS 6.875" 3,512' 4,611' 7-5/8" 33.7 SS-95 LT&C 6.765" 4,611' 8,338' 7-5/8" 39 8S-95 LT&C 6.625" 8,338' 10,438' Liner 5-1/2" 20 N-80 4.778" 10,230' 10,943' Tubing 3-1/2 " 9.3 N-80 8RD EVE. 2.992 " Surface 10,290' 2-3/8" 1.995" 10,290' 10,308' 1 2 18' Tubing Hanger Gaslift Mandrels( #9-#1)3-1/2BUTIxEUE 8RD McMurry Hughes MHO GL at 1473',2747',3738',4507',5277', 5798',6088',6478', 10157' 7-5/8x3-1I2" (39#) EUE 8RD Baker FH Packer S nipple Otis 3-1/2" 8RD position 2 w/optionaI2.875" 1D 5-1/2" 20# Baker FH Packer Otis" le(w/1.791"nogo) 2-3/8" Bak Shear Sub 3 10,199' 10,206' 10,272' 10,307' 10,308' 1.791 2,875 4 10450 10462 H 10466 10478 8' H 10515 10527 12' H4 10530 10585 55' H5 10614 10632 18' H 10638 10652 14' H 10658 10666 8' H 10672 10686 14' H 10745 10759 14' H 10763 10772 9' H 10787 10792 3' H 10796 10802 6' H Drawn by: CRW 09/29/05 , . RKB =18.0' TD= 10,945' PBTD= 10,911' 20" 10-3/4" 7-5/8" 7-5/8" 7-5/8" 7-5/8" DV Collar 7-5/8" 7-5/8" Liner 4' 10,199' 10,206' 10,272' 10,307' 10,308' 2.875 1.791 10450 10462 12' 10466 10478 8' 10515 10527 12' 10530 10585 55' 10614 10632 18' 10638 10652 14' 10658 10666 8' 10672 10686 14' 10745 10759 14' 10763 10772 9' 10787 10792 3' 10796 10802 6' Drawn by: CRW 09/30/05 e e SCU 42B-05, Soldotna Creek Unit Recompletion Obiectives: 1. Isolate all hydrocarbon-bearing zones as per 20 AAC 25.1 12(c)(I)(D) 2. Test the cement plug to verify zonal isolation and 7%" casing integrity as per 20 AAC 25.112(g) 3. Recomplete wellbore to 77-3 gas sand. Procedure: Isolate Hemlock 1. MURU Slickline. Gauge tbg to EOT. Tag for fill. Retrieve GL V @ 10,157'. RD. 2. MIRU Eline. RIH set HES Retainer w/ Sldg Valve between 50' and 500' above perf interval (approximately @ 10,230'). POOH. RD. 3. Prepare pad & install liner, tankage & berms 4. Turnkey MI & RU CTU, BOPE and test same. G 5. Coil tbg unit Acceptance. Hold pre-spud & RES meetings. ..g}l I\- 6. RIH w/ HES stinger. Stab into retainer. Squeeze/lnject!Displace~ bbls of "G" neat below retainer. 7. PU CT above retainer. Lay-in 10 bbls of"G" Neat, while taking returns,out tbg x csg and CT x tbg annuli's to 10,000'. POOH. 8. Turnkeyed Demobe. RD CTU 9. Fill/Pressure test tbg to 2500 psi. Fill/Jug test Wellbore to 2500 psi. 10. MURU Slickline. Tag TOC. Have witnessed by agencies. RD. Recomplete to 77-3 Sand 11. Prepare pad & install liner, tankage & berms 12. Turnkey MI & RU Drilling Rig 13. Rig Acceptance. Hold pre-spud & HES meetings. 14. Finish RU basic components & mix mud. Circulate well clean 15. NU BOPE & chokelkilllines & test (incl. set catwalk) 16. RU Eline. PU Tbg Hngr. RIH and Cut tubing @ 9500'. POOH. RD Eline. 17. Circulate well. PU LD Hanger 18. POOH Standing Back TUbingj! 19. RU Eline. MU retainer. RIH t 87 '. et same 20. PUMU String ~ill & bit. RIH t " Pump viscous sweep. CBD. 21. POOH LD tubmg. Pressure Test' sg.£ 1 c" 1<U61\- 22. ND BOPE and install Casing Head. 23. NU BOPE. CO rams and test same. 24. RU casing crew. PU & Run 5-1/2" liner to 8700'. / 25. Cement liner to surface w/ 150 bbls (20bbls over) of cmt (750 sx). Drop slips. Hnglpack-offliner. Install new tubing spool. Land BOPE. CO rams. Test same. 26. PU Run completion. Space out, land completion. RU Slickline RIH set plug. Pressure to set pkr. Retrieve plug. RD Slickline. 27. ND BOPE and install tree. 28. Release rig. 29. MIRU Slickline, pump & N2. RIH open sldg slve. Pump 110 bbls of pkr fluid. 10 bbls diesel. Displace tbg w/ N2. Close sldg slve. RD equip. 30. MIRU Eline. RIH perforate 77-3 sand. POOH. RD. 31. Turn Well over to Production. &HANICAL INTEGRITY· REPORT. 5PUD DA!E: 12/7/ ¡q {i- t :.]:G RELEJ..S::::· ¿fig! !9~$ OPER & FIELD Uvt.C?t..t'.J - ~ L fA.. \-.:'"ELL NUMBER SCtA.. 4 2.. ~ - oç } f2-{q9 :~Di:;g: TD: IOQ4s J1D..lo~oO TVD: :?BTD: loQIl 1?/f'" Shoe: lDA~f HD I02.or~ TVD¡ .S·'hll Shoe: IOq4~ MD /o,g97TVD¡ I. 2 Þ ¡It II ~" h "Packer ID~c>e HI) MD /0 ~(p(¿, TVD ~~LL DATA .:....::..:1e~: DV: MD ·TVu :CP: 102 $'0 HD '":7I) Ca.sing: ::ole Si.ze q Þ ¡If' anå 6-'h,." Perfs 1~4S0 ' IOIQ9¡ J()l1'Z- I t6 loGO"l TVD¡ Set ê.t ~C?..Þ~-i!C;'.L INTEGRTTY - PART n Annulus Press Test: :P 15 m~n 30 min C ow:¡:¡¡en t s : M r:. r" .... ~1 v.A r'¿ J ---- ~CHÞ_l-iICÞ~ INTEGRITY - PART /2 Cement Volumes:', ,Amt. l..iner/O.g '-/4.; Csgt,017slL j DV Cwt -Jol to cover perfs 72 SI.t.. to 1AJ1J(J,y' ft4k f-,r;oo' @ '3oc!/" ~U~7. ' Theoretical Toe Q4S7' ~~ 'So!)~ ~œ~Ç.. Cement Bond Log (Yes or No) Lf In AOGCC File· ¡// . CBL E:valuation, ::one a.bove perfs A-M1~ Þ~V\'Î ¡~d;c""i:t~ to ./V 7 KQ4' ~ Ac'f:;L dM 'b/Sllqi~. Proàuction Log: Type Evaluation '. -'~ CONCLUSIONS: ? ar; /1: M r Trtú lA4'r--ld , ?ar:: :Z: Jr.1~CA/{ ~dÞI~ CAJl /t-fJfL ~(l~, )&u; MM, .wt-J ~ P f1~iJ vI. . '\d6~~ lohl7A70Ç, Ih;-JJ ~d 1 c.4. 'r-lu -td,> ,g" Gß l µ~ .. 3"x2" DSA 3"x2" DSA 3" #5000 HCR VALVE \ 2" CHOKE LINE I -- -P1P£-RAM5--- I i -- -B1..-INDfRAM&- -- , ... /3-118"#5000 GATE VALVE 2" KILL LINE -¥--------------- 1.. ------------- 3-1/8" #5000 GATE VALVE NABORS ALASKA RIG 129 11" BLOW"OUT PREVENTOR 2 RAM STACK CONFIGURATION 11" 5k PSI SCHAFFER ANNULAR BOP SCREWED HEAD FLANGED BOTTOM CONNECTION II" 5k PSI DOUBLE GATE PR[VENTOR STUDDED CONNECTION ... II" 5000# API FLANGED MUD CROSS =:a~=-F~~~'f&OF fþNa60n AIarIIr :'c -=:. ':',;' ANIIOII_c:..,., ~~ 995OJ-2t3SI NABORS ALASKA RIG /29 II' BLOW-OUT PRfVENTOR 2 RAJA STACK CONFlGURA11ON '" TmE DUE 'IY." ~ DDCIIIPI'DN e e SCU 428-05 API# 50-133-20363-00 Nabors Ria 129 Proposed Eauipment Confiauration Blow Out Preventors 11" x 5000 psi. nace trim · Annular 5000# Shaffer - 5000 psi. · Double gate LWS Shaffer - 5000 psi. · Spool 18" high with 2-3" outlets 5000 psi. · c/w 3-5000 psi. 3" gate valves · 1 each - 3" HCR valve rated 5,000 psi Accumulator/Air Compressors · Electronic control system model 6150 PLC · 6 station 170 Gal. · Max press 3000 psi. · Mounted in end #1 pump house · Master controls located at accumulator · Remote controls located in doghouse · 2 air compressors Quincy model 340 Mud System · 2 tank system - 8 compartments · Agitators in each compartment · Twin derrick model 2000 Linear Motion shakers · Total usable volume 1170 Bbl. Shaker Tank 50' x 6.5' x 11.5', 650 Bbl. · Trip tank 3' x 6.5' x 11.5' · Volume 40 Bbl. · Trip tank pump Brico 2" · Shaker compartment 18' x 6.5' x 11.5' · Volume 240 Bbl. · 2 each derrick model 2000 flowline cleaners · Gasbuster compartment 14.0' x 6.5' x 11.5' · Volume 185 Bbl. · Gasbuster 38" nace trim · Brook Hansen 7 % H.P. Agitator · Degasser compartment 14.5' x 6.5' x 11.5' · Drilco vacuum degasser · Volume compartment 190 Bbl. · Brook Hansen 7 % H.P. Agitator Suction Tank · 40.0' x 6.5' x 11.5' · Volume 520 Bbl. · CIW 12' x 11.5' mud house on end of tank contains hopper and Pump #1 · Gardner Denver model PZ9 · 1000 H.P. Triplex · Powered by Caterpillar 3412 750 H.P. · Right angle drive box Rigmaster · Model #RP800 e e Pump #2 · Gardner Denver model PZ9 · 1000 H.P. triplex · Powered by Caterpillar 3412750 H.P. · Rigmaster model RP800 right angle drive Kill Line · The Kill Line/Circulating Line will consist of 2",3000 psi Iron or 2",5000 psi hoses with threaded Fig 1502 Unions. Choke Line · The choke line will consist of 5,000 psi hoses with integral Fig 1502 Unions. Choke manifold building · Choke Manifold - 5000 psi. · Consists of 15 - 3" - 5000 psi valves · Instrumentation · Swaco superchoke (10000 psi) a.: e Unocal Alaska ReSOUrC_ Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL8 I\/E l~U G2 ,í '1('0""" M ,''':i: LU J (;¿ August 24, 2005 Ms. Cathy Forester Mr. John Norman Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 ,l'l¡'- lC(q . ì ~ -" ø$' tt~ APPLICATION FOR GAS STORAGE AREA INJECTION ORDER FOR TYONEK 77-3 SAND, SCU 42A-05, SWANSON RIVER FIELD ~?A'I9<) IfoJo(P ,pg-oç ,¡z.tqq Dear Commissioners: Attached for your review are two copies of an Application for Area Injection Order for gas storage for the Tyonek 77-3 Sand at the Swanson River Field and specifically for Well SCU 42a- 05. The application is submitted by Union Oil Company of California (dba Unocal), as Operator. Upon your approval of this application and pending approval of a gas storage agreement with the Bureau of Land Management, Unocal plans to commence injection of gas into this well for storage as early as this fall. Please contact either Phil Ayer at 263-7620 or Samuel Atta-Darkwah at 263-7864 if you have any questions regardinQ this application. 8M I}¡A-~ Philip M. Ayer Petroleum Engineer PMA:dma Attachments SCI\NNED NO\! û 3 20D5 cc: Phil Ayer, Unocal Jeff Smetanka, Unocal Kevin Tabler, Unocal Dave Whitacre, Unocal Robin West, USF&WS Claire Caldes, USF&WS SCU 42A-05 Well File Gas Storage File DUPL\CATE e e APPLICATION FOR AREA INJECTION ORDER TYONEK 77-3 SAND, SWANSON RIVER FIELD TABLE OF CONTENTS Section/Reoulatorv Citation Subiect Paoe A. 20 AAC 25.252(c)(1) Plat 3 B. 20 AAC 25.252(c)(2) Operators/Surface Owners 3 C. 20 AAC 25.252(c)(3) Affidavit 4 D. 20 AAC 25.252(c)(4) Description of Operation 5 E. 20 AAC 25.252(c)(4) Pool Information 5 F. 20 AAC 25.252(c)(4) Geologic & Prod. Information 6 G. 20 AAC 25.252(c)(5) Well Logs 7 H. 20 AAC 25.252(c)(6) Mechanical Integrity 7 I. 20 AAC 25.252(c)(6) Casing Information 8 J. 20 AAC 25.252(c)(7) Injection Fluid 11 K. 20 AAC 25.252(c)(8) Injection Pressure 11 L. 20 AAC 25.252(c)(9) Fracture Information 12 M. 20 AAC 25.252(c)(10) Formation Fluid 12 N. 20 AAC 25.252(c)(11) Aquifer Exemption 12 O. 20 AAC 25.252(c)(12) Wells Within Area 12 Number 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 e e APPLICATION FOR AREA INJECTION ORDER FOR GAS STORAGE TYONEK 77-3 SAND, SWANSON RIVER FIELD LIST OF ATTACHMENTS Description Cook Inlet Location Map SCU 42A-05 Location Map SCU 42A-05 Location Map (Expanded) Structure Map at Top Tyonek 77-3 Sand SCU 42A-05 Well Log Section at Tyonek 77-3 Sandstone SCU 42A-05 - Tyonek 77-3 - Production Data Material Balance Plot - P/Z vs Cumulative Gas for Tyonek 77-3 SCU 42A-05 Current Wellbore Schematic Sample Gas Analysis fTom Swanson River Field Leak Off Test for SRU 243B-4 Leak Off Test for SRU 223-28 Leak Off Test for SRU 213-10 Leak Off Test for KGSF # 7 Leak Off Test for SRU 241-16 SCU 42b-05 Schematic SCU 42-05 Schematic 2 e e SWANSON RIVER FIELD SWANSON RIVER GAS STORAGE FACILITY APPLICATION FOR AREA INJECTION ORDER TYONEK 77-3 SAND August 23, 2005 Introduction In 2001, Unocal commenced operation of a gas storage pilot project within the boundaries of the Swanson River oil field. Unocal refers to this gas storage operation as the Kenai Gas Storage Facility. In order to expand the capacity of the Kenai Gas Storage Facility, Union Oil Company of California (dba Unocal), as operator of the Swanson River Field (SRF), requests an area injection order for injection of gas for gas storage purposes into the Tyonek 77-3 sand, which is present in SCU 42A-05. Well SCU 42A-05 will be used to store gas in the Tyonek 77-3 sand. Additional wells may be converted, redrilled, or drilled into this sand to increase the future deliverability of the storage facility. In addition, Unocal requests that the commission include a provision in the injection order providing for administrative approval of future modifications to operational constraints. SCU 42a-05 will be converted from gas producer status to gas storage service as soon as practically possible. Up to this time Unocal has referred to gas storage operations in the field as being part of the Kenai Gas Storage Facility and gas storage wells had been renamed as KGSF #. In the future we will no longer refer to gas storage operations in the field as being part of the Kenai Gas Storage Facility but as part of the Swanson River Gas Storage Facility. In addition any future wells converted to gas storage will not have any name changes. Section A - Plat Attachment 1 is a regional map showing the location of the Swanson River Field relative to other fields in the Cook Inlet area. Attachments 2 and 3 are plats showing the location of the proposed injection well and the surrounding wells in sections 4 and 5. Section B - Operators/Surface Owners The surface owners and operators within a one-quarter mile radius are: . Unocal . U.S. Department of the Interior, U.S. Fish & Wildlife Service 3 e e . Section C - Affidavit Affidavit of Philip M. Ayer STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Philip M. Ayer, declare and affirm as follows: 1. I am over 19 years of age. I am employed by Unocal as a Reservoir Engineer. I have personal knowledge of the matters set forth in this affidavit. 2. On (L"A ...A"¡' a.^I ,2005, the surface owners/op~~t~d in section 8 were provided a copy of this permit application. ~ J.f~ day of ~+ Philip M. Ayer s~cribed and affiÿd before me at Anchorage, Alaska on ~~ ,2005. ~~. ~\\\\\\\II"II1IIIÛû ~ ... M. -1 ø...... ~~~;............~~:"~ ~oS"·' '. ~~ ~.. . $1CJ" ...~z. ~ [NOTARy\""1 æ : : æ ~. \?UBLIC./.§ ~~"" ..,~~ ~ ~." l"~"""""""'c:'~ ~ ~ (." OF ~\,;f' ~ W¡¡1111II1I1\\\\\\~ Notary Public in and for the State of Alaska I J / (7/.... My commission expires: ~7 4 e e Section D - Description of Operation Unocal proposes injecting gas into the Tyonek 77-3 sand for gas storage purposes. Initially, the SCU 42A-05 well will be used as the sole well for gas storage operations (both withdrawal and injection). Unocal may later decide to drill a new well, or red rill or recomplete another well to expand storage operations within this reservoir. The storage gas will normally be injected during the summer months and produced back in the winter months for sales. Section E - Pool Information The Tyonek 77-3 sand of the Tyonek Formation is the proposed zone of injection. This shallow gas reservoir is part of the Tyonek Participation Area (PA) [8910086520-C]. Gas from these reservoirs has typically been used on lease for fuel and for sales to Agrium/Enstar. The Tyonek PA (891 0086520-C) comprises the stratigraphic interval the top of which correlates to the measured depths defined in the following wells: Well SRU 212-10 SRU211-15 SRU 234-15 SRU 212-27 SCU 341-4 SCU 34-4 SCU 21-16 Measured Depth 5764 5640 5639 5322 5304 5123 5512 The base of the Tyone.k PAJs equivalent to the top of the Hemlock PA as defined in Unocal's October 2, 1995 letter to the AOGCC requesting expansion of the Hemlock Pool. The Hemlock Pool is defined in that letter in the following Soldotna Creek Unit wells: 41-4(10,085'-10880'MD), 43-4(10, 168'-10,920'MD), and 41A-8(10, 116'-10,880'MD), therefore the base of the Tyonek PA's stratigraphic interval correlates to'the measured depths in the following wells: 5 - e Well SCU 41-4 SCU 43-4 SCU 41A-8 Measured Depth 10085 10168 10116 Section F - Geoloaic & Production Information The Swanson River Field structure is a broad north-south trending anticline cut by a number of east-west trending normal faults. Oil and/or gas is produced from four formations at Swanson River Field. The shallowest gas production is from the Sterling Formation. The Sterling Formation extends to a depth of approximately 3000 TVD feet and is comprised of thick sandstones, mudstones and coals deposited in a high-energy meandering to braided stream environment. Gas is also produced from the thinly bedded sands of the Beluga Formation that underlies the Sterling Formation. These discontinuous sands were deposited in a lower energy stream system, and they are interlayered with abundant mudstones and coals. The Beluga Formation is approximately 2000 feet thick at Swanson River Field. The Tyonek Formation is comprised of meander belt and braided stream sandstones interlayered with mudstones and thick coals. The Tyonek Formation is approximately 5000 feet thick at Swanson River Field. Gas is produced from several sands in the upper and middle part of the formation, while oil production comes from the lowermost 100 feet of the Tyonek (the Tyonek G Zone). Underlying the Tyonek is the main oil producing interval at Swanson River Field, the Hemlock Formation. The Hemlock Formation is 600 feet thick at Swanson River Field and is comprised of thick conglomeratic sandstones interlayered with thin mudstones and minor coal. The Tyonek 77-3 sand is interpreted as a meandering channel belt that is present in portions of Swanson River Field. It can be mapped with existing wells and stratigraphically is surrounded by associated floodplain deposits. This relatively low energy fluvial system creates stratigraphic traps in which gas is found. This sand is gas bearing in portions of sections 4 and 5. The 77-3 sand gas column is penetrated by wells SCU 42A-05, SCU 42-05, SCU 42B-05, SCU 41-05, SCU 12-04, SCU 323-04 and SCU 332-04. The sand shales out up dip to the east at well SCU 43-04. The 77-3 sand is faulted out along the "0" fault on the south side of the accumulation in wells SCU 33-05 and SCU 43-05 6 e e (Attachment 3). Down dip in well SCU 32-05 the 77-3 sand is interpreted as water bearing; however it may also be interpreted as non-payor stratigraphically pinching out. The 77-3 sand accumulation at SCU 42A-05 can be seen on the structure map (Attachment 4). The maximum area case for the 77-3 sand at SCU 42A-05 is shown in green. The 77-3 gas storage sand is interpreted to be a combination structure/stratigraphic trap in which the 77-3 sand is bounded to the north and south by sealing faults, an aquifer down dip to the west and a pinch out/shale out up dip to the east. The attached log section for SCU 42A-05 (Attachment 5) shows the 77-3 sand at depths of 7972 to 8001 feet measured depth (MD). The 77-3 sand is overlain by 91 feet of impermeable, siltstone, clayey siltstone and shale. It is underlain by 100's of feet of siltstone, claystone, coal and silty sandstone. The 77-3 sand perforations were added to the SCU 42A-05 well in June, 2004. The well was perforated from 7972' to 7982' OH MD log depth. The peak gas rate occurred on 7/30/04 at 6.2 MMCFD. The well has produced no water and a cumulative gas volume of 1.830 bcf through June of 2005 (Attachment 6). Material balance analysis of historical production and pressure data indicates an original gas in place of 3.18 bcf (Attachment 7). Using this figure for the original gas-in-place, the current recovery of 1,83 bcf (as of 7/1/05) corresponds to 57.5% recovery. The SCU 42A-05 is still producing gas today from the 77-3 sand. Our current plans are to convert the well to gas storage service prior to complete depletion of the sand to avoid water and sand production problems which often occur in the late stages of depletion. Given the production history of the Tyonek 77-3 sand, it should be a good gas storage reservoir. Section G - Well Loas All open hole logs from wells in the Swanson River Unit are sent to the Commission as the logs are completed. Attachment 5 shows a log section for the proposed Tyonek 77-3 injection interval in well SCU 42A-05. Section H - Mechanicallntearitv The SCU 42A-05 well will be tested for mechanical integrity using the standard 30 minute annulus test as per 20 MC 25.412. To confirm continued mechanical integrity, Unocal will monitor daily the injection rates and pressures and notify the AOGCC the next working day if the rates and pressures indicate pressure communication or leakage in any casing, tubing, or packer. The rate and 7 e e pressure data will also be reported to the Commission on a monthly basis. It is planned to repair a small tubing leak prior to converting the well to gas storage service. Section I - Casina Information Attachment 8 is the current and proposed wellbore schematic for the SCU 42A- OS well. The casing in SCU 42A-OS was cemented in accordance with 20 ACC 2S.2S2(b) and tested in accordance with 20 AAC 2S.030(g) when completed. Summary: SCU 42A-OS is completed with 7" casing cemented down to a KOP depth of 10410' MD, a S" liner cemented from 10994' to 10191', and 3 %" tubing cemented in place. The TOC and bottom of cement in the 3 %" tbg X 7 "csg annulus is at 726S' and 100SS' respectively. The TOC in the tubing is at 9990' MD (top cement retainer). Note that the proposed Tyonek 77-3 sand gas storage interval lies above the S" liner. CBL and temperature survey data from SCU 42A-OS indicates the Tyonek 77-3 sand (7970' - 8000') has full zonal isolation. Production data from this zone is also supportive of a good cement bond and zonal isolation. The straight line P/Z curve on the Tyonek 77-3 sand is indicative of a volumetric acting reservoir with no behind the casing fluid migration. SCU 42A-OS (10410' MD KOP) is a 1981 redrill of SCU 42-,S. Well SCU 42-S, which was completed in 1972, is sometimes referred to within Unocal as SCU 42-S RD (as it is the cased sidetrack of the original SCU 42-S open hole that was plugged). Official State records only recognize the SCU 42-S name and do not differentiate between the original hole and the cased sidetrack. It is important to note that the casing information for SCU 42A-OS and SCU 42-S are one and the same above the 10410' KOP. In addition the Tyonek 77-3 sand of interest is penetrated above this KOP; therefore the casing information in both wells below this KOP is referenced but, is not of primary importance. The detailed casing histories for SCU 42-S and SCU 42A-OS are as follows: 8 e e Detaill SCU 42-5 Casina History SCU 42-5 was spud on 1/9/72. A wellbore schematic is included as attachment 16. The 10 %" casing was set at 3385' and cemented with 1875 sacks of class G cement with good circulation and returns. The shoe was tested to 2500 psi surface pressure with 72 pet mud without breaking down (equivalent to 1.24 psi/ft at 3385' MD, 3384' VD). A 9 7/8" hole was drilled to 10965' prior to losing circulation and sticking the drill pipe. The drill pipe was free pointed and recovered down to 5844'. The hole from 5674' to 10965' was abandoned by equalizing in a 350 cf 125 pcf class G cmt plug at 5818' (displaced by 20 cf wtr and 432 cf of 98 pcf mud). Cement was cleaned out from 5633'- 5674' and the well (referred to as SCU 42-5RD within Unocal, but State retains same SCU 42-5 name) was kicked off and successfully drilled to 10731'. The 7" casing was set at 10731' and cemented in two stages. The first stage was with 1200 sacks of 116 pcf class G neat cement around the shoe and had good circulation for 2/3rds of the displacement and lost circ with less then1 % displacement to go. The second stage was through a stage collar at 3613' with 440 sacks of class G cement and had good circulation throughout. Cement was drilled out from 10535' to 10721'. The casing and 7" shoe tested to 2500 psi surface pressure with 95 pcf mud without breaking down (equivalent to 0.925 psi/ft at 10535' MD, 10192' VD). A CBl was run in the 7" casing (with 2000 psig surface pressure) from 10718'- 7700' and 3700'- 1800' (TOC @ 8120' and 2100' respectively for each cement stage, good cement bond 10535'- 8120' and 3613' - 2100', uncemented pipe 8120' - 7700'). The uncemented portion of 7" casing was perforated at 8014' just below the Tyonek 77-3 sand (7970'-8000'), broke down with 1000 psig pump pressure while pumping 98 pet mud at 10 cflmin rate, and cemeI1Ls.que~:?:eg with4QQ. sacks of class G cement. The top of cement plug and casing held a final 4500 psi surface pressure with 98 pcf mud without breaking down (equivalent to 1.25 psilft at 8014' MD, 7845' VD). Firm cement was cleaned out from 7913'-8017'. A CBl was run from 10698'- 6550' wi 2500 psig surface pressure (good cement bond 10698'- 8104' and 7700'-7200', patchy cement bond 8104'- 7700'). Within the patchy cement bond section, there is very good to adequate bond in seven intervals (7992'- 8016', 7966'- 7978',7922'-7940',7892'- 7912', 7830'-7854', 7770'-7774', and 7744'-7754'). Cement was cleaned out from 10721'- 10731' (to 7" csg shoe) and a 6" hole was drilled to 11170'. The 5" liner was hung at 11168', top 10497', and cemented with 80 sacks of 120 pcf class G cement around the shoe with good circulation. Cleaned out firm cement 10346'-10497' (to liner top), cement stringers 10497'-11113', and hard cement 11113'-11123' (to cement wiper plug). A CBl was run 11095'-10494' 9 e e (good bond 11095'- 10696' which is 35' up in the 5" liner X 7" casing lap). The liner lap and 5" shoe was tested to 2500 psi surface pressure with 90 pcf mud without breaking down (equivalent to 0.857 psi/ft at 11123' MD, 10743' VD). Soon after perforating the Hemlock formation and running the tubing /packer completion, the tubing was pulled, and a tubing hole was found at 8012'. The 7" csg perforation hole at 8014' was isolated with a bridge plug and cement packer tool and cement squeezed with 300 sacks of class G cement. The cement plug and casing was tested to 5000 psi surface pressure with 98 pcf mud without breaking down (equivalent to 1.26 psi/ft at 8014' MD, 7845' VD). Firm cement was cleaned out from 7862'-8016' and the squeeze job perforation and casing tested to 5000 psi surface pressure with 98 pcf mud without breaking down (equivalent to 1.26 psi/ft at 8014' MD, 7845' VD). Prior to re-running the tubing packer completion, the 7" X 5" liner lap was isolated with DST tools and tested in an underbalance condition. There was no blow to surface during the test. An insignificant 15' rise in the original underbalance fluid cushion level and no significant pressure changes in pressure charts was noted; all indicative of liner lap integrity. WSO OK. The tubing and packer completion were rerun and the well completed in the Hemlock formation. SCU 42A-05 Casina Historv In 1981, seu 42-5 was re-drilled from a 10410' KOP as seu 42A-05 to gain a more favorable drainage point in the Hemlock formation. As mentioned earlier, SCU 42A-05 and seu 42-5's casing are one and the same above the 10410' KOP and the Tyonek 77-3 sand lies above this KOP. Although the seu 42A-05 casing information below this kick off point is not of primary importance, it is included as a requirement of the injection order application. In preparation to drill seu 42A-05, seu 42-05 was killed with 86 pcf mud and all tubing but 38' was pulled and recovered leaving the the top tubing fish at 10994'. The 7" csg and 5" liner was plugged back by equalizing in a cement plug at 11046' of 40 cf class G cement. Squeezed 12 et cement away. Tag TOe 10852'. Equalize in plug at 10852' w/56 cf G cement. Tag TOe 10490'. Test casing 3000 psi. Milled window in 7" from 10410'-10457'. Equalize in kick off plug at 10490' w/65 cf G cement. Tag TOe 10315'. Kicked off seu 42A-05 well at 10416' and drilled 6" hole to 11180'. The 5" liner was hung at 10994', top 10191' and cemented with 75 cfclass G cement around the shoe. The plug was bumped during displacement. Reversed out with no cmt returns. Tested liner lap to 3000 psi surface pressure with 76 pet mud without breakdown (equivalent to 0.83 psi/ft @ 10191' MD, 9871' VD). Clean out cement to shoe. Test liner to 3000 psi surface pressure with 76 pcf mud without breakdown (equivalent to 0.81 psi/ft @ 10994' MD, 10601' VD). Ran CBL from 10976'-10181' (TOe 10540', good bond 10976'-10540'). 10 e e The 5" liner was perforated at 10420', 10' below the 7" casing shoe, and squeezed with 20 sacks class G cmt. Pull out of retainer and reversed out. Clean out cement stringer to 10425'. Perforated well in Hemlock and ran 3 ~" tbg completion with tbg tail at 10828' and packer at 10133'. In June of 2004, SCU 42A-05 was successfully recompleted in to the Tyonek 77- 3 sand by effectively cementing the tubing in place and creating a cement packer in the tubing casing annulus. The 3 ~" tubing was cemented in place as follows: A tubing bridge plug was set at 10065',the tubing was perforated from 10055'- 10060' for circulation ports, a 3 ~" cmt retainer was set at 9990', circulation was established up the 3 ~"X 7" annulus via coil tubing stabbed in to the retainer, and 78.1 bbls of cement was pumped and displaced to the retainer by lease water. The CT was released from the retainer and 47 bbls lease water was circulated out. A temp log was run from 9984'-6200' (7265' TOC in the 7" csg X 3 1/2" tbg annulus) Section J - Iniection Fluid The type of fluid for proposed injection is gas. Produced natural gas from the Swanson River field and from other fields in the Cook Inlet will be injected and stored in the proposed storage interval during periods of high supply and redelivered during periods of high demand. The fluid composition for the proposed injection is dry natural gas with a specific gravity which ranges between 0.56 and 0.58. The properties of the Swanson River gas are shown in the gas sample included as Attachment 9. The estimated maximum amount of gas to be injected daily is 42 mmcfd. The injectiofl gª§ßhQ,l,¡Jçtþ~ fullYQ9J1lpatible with the Tyonek 77-3 formation, since this zone previously contained dry methane gas and was produced without any signs of formation damage. Section K - Iniection Pressure Existing compression will be used for gas injection and production operations. The estimated average injection pressure is 3500 psi. The maximum injection pressure will be 4400 psi. The compressor plant maximum output pressure limits the maximum injection pressure. Wellhead pressures will be maintained such that a gradient of 0.676 psi/ft at the target midperf reservoir depth of 7816' TVD is not exceeded. This corresponds to a wellhead pressure of 4400 psig at 0 mmcfd injection rate. Any injection rates atthe maximum 4400 psig wellhead injection pressure will result in a downhole gradient at the target midperf depth less then 0.676 psi/ft due to the frictional pressure drops in the tubing. 11 e e Section L - Fracture Information The proposed maximum injection pressures for the gas storage operation will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. A pressure control valve will be installed to protect the Tyonek 77-3 sand. The proposed maximum injection pressure for SCU 42A-05 in the 77-3 sand, as previously mentioned will not exceed a gradient of 0.676 psi/ft at the sandface. Leak off tests in wells SCU 2438-4, SRU 223-28, SRU 213-10, KGSF #7, SRU 241-16, all new wells drilled in the last eight years, show the fracture gradient at approximately 2000' to range from .75 to 1.1 psi/ft (see attachments 10, 11, 12, 13, and 14). Original reservoir pressure in the 77-3 sand in SCU 42A-05 is estimated at 4774 psi based on initial shut-in tubing pressure measurements of 3979 psi. Using the reservoir true vertical depth of 7816', this equates to an original pressure gradient of 0.61 psi/ft. Section M - Formation Fluid No samples exist of produced water from the proposed injection interval. Section N - Aquifer Exemption The proposed gas injection will be at a depth of approximately 7811'-7821' TVD. As per 40 CFR 147.102(b) the aquifers in the Swanson River Field are exempted in accordance with 40 CFR 144.7(b) and 40 CFR 146.4. Section 0 - Wells Within Area Well SCU 428-05 is the only well within a quarter mile of the proposed SCU 42A- 05 gas storage well that penetrates the 77-3 sand. C8L data from this well indicates the Tyonek 77-3 sand (7859' to 7897') has full zonal isolation. A wellbore schematic is included in attachment 15. Casing history is as follows: The 10 %" casing was set at 3395' and cemented with 1250 sacks of class G cement. The shoe was tested t01500 psi surface pressure with 9.3 #/gal mud without breaking down (equivalent to 1.56 psilft at 3395'). A 97/8" hole was drilled to 7874' with some well flow from 7604'- 7874 prior to sticking the drill pipe. The drill pipe was freepointed and recovered down to 3497'. The hole from 7897' to 3444' was abandoned by laying in 350 cu ft class G cmt plug at 3500', 12 e e pulling up to 3288' and braiden head squeezing the cement with 100 cf 11.9 ppg mud with a final surface pressure of 4500 psi (no apparent formation breakdown seen). Cement was cleaned out from 3397' to 3444' where the well was kicked off and successfully drilled to 10505'. The 7 5/8" casing was set at 10428' and cemented in two stages. The first stage was with 910 sacks of class G cement around the shoe and had good circulation throughout. The second stage was through a DV collar at 7508' with 1260 sacks sacks of class G cement and had good circulation with 50 sacks cmt returns (lost circ with only 5% displacement to go). Cement was drilled out from 10197' to 10415' and a CSL was run from 10075' to the surface (TOC 3374', good cement bond throughout however patchy intervals from 7576' to 7696' and 7852'- 7893'). Shoe was tested to 3000 psi surface pressure with 9.9 ppg mud without breaking down (equivalent to 0.803 psi/ft at 10415'). The well was then drilled to 10945'. The 5 %" liner was set from 1 0943' to 1 0229' and cemented with 125 cf of class G cement around the shoe. Pulled out of liner and reversed out cement contaminated mud and water. Ran CSL from 10911 '- 10000' (no cement in liner lap, excellent cement in 7 5/8" casing to top of CSL logged interval at 10000'. Liner lap and 5 %'shoe were tested to 5000 psi surface pressure with water without breaking down (equivalent to 0.891 psi/ft at1 0911 '). 13 Àll WELLs (1) e SCU_42A-05 e Oil Water Gas Cum Cum Cum Rate Rate Rate Oil Water Gas Month (CD) (CD) (CD) Prod Prod Prod bbl/d bbl/d Mcf/d Mbbl Mbbl MMcf -_._----- '_._----- ---------- ---------- --~._--- -.-.----- --------- 2004- 0 0 1775 0 0 55 2004-Aug 0 0 6264 0 0 249 2004-Sep 0 0 5778 0 0 423 2004-0ct 0 0 4896 0 0 574 2004-Nov 0 0 5398 0 0 736 2004-Dec 0 0 3761 0 0 853 2005-Jan 0 0 5185 0 0 1014 2005-Feb 0 0 5723 0 0 1174 2005-Mar 0 0 5319 0 0 1339 2005-Apr 0 0 5205 0 0 1495 2005-May 0 0 5559 0 0 1667 2005-Jun 0 0 5412 0 0 1830 Attachment 6 SCU 42A-05 -- POZ vs Cum Gas Production for Tyonek 77-3 Sand 5000 1000 . 4000 3000 CIS i ~ 2000 > i (') :r i :.1 ..... -..J . o o 1 2 Cum Gas, bef 3 4 8/23/2005 3:39 PM O:\Gas CmOpenmind\Swanson\Soldotna Creek Unit North\SCU42A-5\Surveys\Pressure\SCU 42A-05_POl vs Cum_081705.xls 42A-5_POZ_Chrt e Unocal Gas Analysis Report 23~Aug-05 locationNum: 1570 FaciO: SRU Anal Date: 7/18/2005 BtulCf: Gravitv: C02: N2: Methane: Ethane proøane: IButane: NButane: NeoPentane: IPentane: NPentane: C6+: 1011.588 0.5717022 0.188183 1. 111626 97.56321 0.6062282 0.1994195 0.1000801 0.1348223 o 0.0245657 2.622031E-02 4.564862E-02 100 e 1 Attach'ment 9 sRu ~ ;Z~5-ft e CUM AFE# ACTUAL TIME AFE TIME ACCEPT RIG $513,122 126626 3.33 DAY 4.00 DAY 8/4/97 16:00 8/7/97- DRILL FROM 2074' TO CASING POINT AT 2125'. POOH, TIGHT HOLE FROM 1331'-600'. RIH WITH CLEAN OUT ASSY, REAM THROUGH BRIDGE AT 642'-685', WASH DOWN FROM 685' TO 750'. REAM TIGHT SPOTS AT 1425'-1455', 1600'-1640' AND 1877'-1925'. TAG BOTTOM AT 2125' WITH NO FILL. PUMP HI VIS SWEEP WITH NO SIGNIFICANT CUTTINGS RETURN. POOH WITH NO PROBLEMS. BEGIN RUNNING 7" SURFACE CASING. SWANSON RIVER #223-28 DAY 5-7 8/8-8/10/97 D.C. $63689 CUM $712145 AFE# 126626 ACTUAL TIME 6.33 DAY AFE TIME 7.00 DAY ACCEPT RIG 8/4/97 16:00 8/8/97-RAN 7" CASING TO 2125'. CEMENT CASING WITH LEAD CEMENT OF 400 SX (140 BBLS) CLASS G WITH 4% BENTONITE, 2% /' CACL, AND .266% CELLOFLAKES AT 12.9 PPG, AND TAIL CEMENT OF 4 BBLS CLASS G WITH 2% CACL, .1GAUSK D-145, .75 GAUSK D- 300. PROBLEMS PUMPING TAIL SLURRY DUE TO LOSING PRIME. DISPLACE CEMENT AND BUMP PLUG. FULL CIRCULATION / THROUGHOUT JOB, CEMENT CONTAMINATED MUD TO SURFACE. ND DIVERTER AND RAN 1" TUBING TO 96', PUMPED TOP JOB WITH 74 SX CLASS G CEMENT. SET SLIPS, CUT CASING AND INSTALL TUBING SPOOL. NU BOPE. 8/9/97-PRESSURE TESTED BOPE TO 5000 PSI, WITNESSED BY LOU GRIMALDI-AOGCC. RIH WITH 6' BIT, TEST 7" CASING TO 3000 PSI. DRILL FLOAT EQUIPMENT. 8/10/97-DRILL 10' OF NEW FORMATION TO 2135'. PERFORM LEAK- OFF TEST WITH 9.0 PPG MUD AT 2058' TVD. BROKE FORMATION AT 1300 PSI = 21.1 PPG EMW. DRILL 6' HOLE TO 3923'. Attachment 11 , , , . , . '" .. ~,~co ~'~aska'-!."-c..'-,'*-¢°~° _...,, post O~ti~ ~iaska Anch°rage',,~-t o63 4304 Telephone Tom ~ellman Regional Engineer Cook Inlet Engineering Apri1 18, 1991 Mr. L. Sm. i%d Gas ConserVation CommissiOn aska 0¢ 'ne Drwe ~, ~orCUPz ,_. 99501 smith rt o{ operatOrS [or the pe~Orati~ o[ ~chOra~, . ~++achea P ~ - ~2 i~ter~%dW retr~?'2k%' to 10,47~ .)~'~ ¢~n, u~ ~l 1990. ~ ~o4 BOr~, ~,a t to perforam'b' bseqCeB MCVV~ ~' Attachment cc: Mr.~' C Delart R£¢EIVED APR 2 1991 Oil comPS,Oil'& Gas Cons. ~mmlss[Qn MarathOn corporatio AtlCO AlaSka, Inc. is a Subsidiary o! Atlant'tc ~[chfield company STATE OF ALASKA ALAbr, A OIL AND GAS CONSERVATION COMMISbION i'/' '~'i .'} ~i'~. ]~; REPORT OF SUNDRY WELL OPERATIONS ' I. Type of Request: Operation Shutdown ~ Stimulate Plugging Perforate )~ . Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing ~ Other 2. Name of Operator ARCO Alaska. IRS. 3. Address P.O. Box l O0360, Anchorage, AK 99510 4. Location of well at surface 1823' N & 572' W of SE corner, Sec. 5, T7N, R9W, SM At top of productive interval 766' N and 4'E of SL At effective depth 773'N and 8'E of SL At total depth 775' N and 9' E of SL 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 152' GL. 177' KB feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 421~-5 9. Permit number/approval number 32-199 10. APl number 50-133-20363 11. Field/Pool Swanson River-Hemlock 12. present well condition summary Total Depth: measured true vertical 10,946' feet Plugs (measured) 10,900' feet Effective depth: measured 10,91 O' feet Junk (measured) true vertical 10,865' feet Casing Length Size Cemented Structural Conductor 92' 20" Driven Surface 3395' i 0-3/4" 1250 sx Class G Intermediate Production 10438' 7-5/8" 2077 SX Class G Liner 713' 5-1/2" 108 SX Class G Measured depth True vertical depth 92' MD 92' MD 3395' MD 3395' MD 10438' MD 10393' TVD 10230'-10943'MD lO186'-10897'TVD Perforation depth: measured 10450'- 10462'; 10466'- 10478'; 1061 4'- 10632'; 10638'- 10652'; 10658'- 10666'; 10672'- 10686'; 10745'- 10759'; 1 Q763'- 10772'; 10787'- 10792'; 10796'- 10802' true vertical 10405'- 10417'; 10421'- 10433'; 10568'- 10586'; 10592'- 10606'; 10612'-10620'; 10626'-10640'; 10699'-10713'; 10717'-10726'; 10741'-10746'; 10750'-10756' Tubing (size, grade, and measured depth) 3-1/2", N-80 to 10,270'; 2-3/8", N-80 to 10,308' Packers and SSSV (type and measured depth) R E~ ~i.i~i~ 7-5/8" Baker FH packer @ 10,199'; 5-1/2" Baker FH packer @ 10,272' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A APR 1991 Alaska Oil & Gas Cons. CQm_rOIsSl~il lchorage 14. Prior to well operation Representative Dai].v Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 196 16,172 17 75 TubingPressure 2700 Subsequent to operation 194 16,510 29 75 2900 15. Attachments Copies of Logs and Surveys run~ Daily Report of Well Operations X 16. Status of well classification as: Oil .~X Gas Suspended ~ Service ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed T- ~/'~,.///9,~,~ ~/ V. ~'~ook Inlet Re§ional Engineer Form 10-404 Rev 06/15/88 Date 4'//~'/~/ SUBMIT IN DUPLICATE WELL ARCO Alaska, inc,' 8ul~ldlllrf of AtlanllG fltehfleld COmpan~ IP~DT IOPERATION AT REPORT 'rIME i WELL SERVICE REPORT _L_ WELL I D '~]NSON R I UER ARCO Alaska, Inc.' ~ll~ll~lly QI Atlllrltl~ RIc. llfleld Complny CONTRACTOR _L-~L ! ~..-~ ..... -- ., . - -- TEL ~VELL SERVICE REPORT FIELD* DISTRICT. STATE__ ' JD~YS I DATE IOPERATION AT REPORT TIME ...... CHECK THIS BLOCK IF SUMMARY GONTI~IUED ON I~A_cK - AUG-04-~90 ~38:54 ID:'~',I,~.SOIq RI:UER TEL N0:2651-~'~ ~1:=] PO4 ,, REMARKS OONTINUED: f_c,~. _.+ :3 DESCRIPTION DAiLY ACCUM. TOTAL cm6o .......... , :SCHLUMBERGER DRESSER.ATLAS IX)WELL HALUBURTON .... i, Il I I Il ARCTIC COIL TUBING FRAC-MASTER ............ B. J. HUGHES ........... Roustal:~outs Methanol Supervt~. Ion .... ,. A~E . ~-- ,,, ,, ii ii i ii TOTAL FIELD E$TII~A'rE ........ _ ARCO Alaska, Inc. Post Office Box lu0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering July 27, 1990 ORIGINAL Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 42B-5 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to perforate the HI and H2 intervals in Well SCU 42B-5. We propose to perforate 24' of the H2 and HI sands (10,466'- 10,478' MD and 10,450' - 10,462' MD, respectively) using a 1- 11 / 16" strip perforating gun at 4 spf. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact David Pursell at 263-4258. Sincerely, fi~T. Wellman TW:DAP:ch:0035 Attachment cc' S.W. Ohnimus /k I~ Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program m Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ .Stimulate__ Pull tubing __ Variance _ Perforate .~X Other 2. Name of Operator ARCO Alaska, In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service 1823' N & 572' W of SE corner, Sec. 5, T7N, R9W, SM At top of productive interval 766' N & 4' E of SL At effective depth 773' N & 8' E of S L At total depth 775'N&9'EofSL 12. Present well condition summary 6. Datum elevation (DF or KB) 168' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 42B-~ 9. Permit number 32-199 10. APl number 50-1 33-20363 11. Field/Pool Swanson River/Hemlock feet Total Depth: measured 1 0,94 6 feet true vertical 1 0,90 0 feet Effective depth: measured 1 0,91 0 feet true vertical I 0,865 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Plugs (measured) Junk (measured) Length Size Cemented 10,686'; 92' 20" 3,395' 1 0-3/4" 10,438' 7-5/8" 713' 5-1/2" measured 10,614 - 10,632'; Measured de~th ~q~'~rti~al depth 92' 92' 3,395' 3,395' 10,64O'; .... 10,438' 10,393' .... 10,943' 10,897' 10,638 - 10,652'; 10,658 - 10,666'; 10,672 - 10,745 - 10,759'; 10,763 - 10,772'; 10,787 - 10,792'; 10,796 - 10,802' true vertical 10,568 - 10,586'; 10,592 - 10,606'; 10,612 - 10,620'; 10,626 - 10,699 - 10,713'; 10,717 - 10,726'; 10,741 - 10,746'; 10,750 - 10,756' 13. Tubing (size, grade, and measured depth 3-1/2", N-80 to 10,270'; 2-3/8", N-80 to 10,308' Packers and SSSV (type and measured depth) 7-5/8" Baker FH packer @ 10,199'; 5-1/2" Baker FH packer @ 10,272' Attachments Description summary of proposal _X Detailed operation program _ BOP sketch X 14. Estimated date for commencing operation July/August. 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed//cC~~.~/-.~,('j~ ~J~Title Cook Inlet Regional Engineer / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity . BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form require 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Commissioner Form 10-403 Rev 5/03/89 Approved Copy Returned . 1- 0 IIAppr°val N~ ~/") _- ~:~) Date ~/B/~0 SUBMIT IN TRIPLICATE Perforation Procedure SCU 42B-5 le . 3, , . RU slicldine and pressure test lubricator. RIH with 1.7" gauge ring and tag fill. RD slickline. RU E-line unit and pressure test lubricator. Tie in and perforate the H2 sand from 10,466'-10,478' MD and the H1 sand from 10,450'-10,462' MD. RD E-line. Return well to production and test periodically. RECEIVED i. lt~rlllT l! Il II l~rlll III ll[ll? l~ll[S -- |~'lUrll/ll TO |lJr[u[ llOKIull! lillIS ~l.][Jl' i l~'l[l? [il llIUT'lllllll¢IgllT IUllll 14l il, lllOllL , : 4~07' -' 14 iTS II/1' tie It I-Il --" II/l' ITT I/It TI 114'11~ III KNIT II I[ -- lk1' NTT I/ll lO JVr rd Iii Kllllll Sill III IL lilfllL '--%' 5 '~g' -' 'l J1T IVl' Id lO ri.et -' ]V~"OITT l~lllellrlllllO ICltlll Ilgll(S 1114 1L IdilllL , -- I ifs llt' lUl Ill I-lC ~- 6/)~ .l. l~' loft l/ II TO l~l' fei Ill IClgllT NglilS Inl IL lllOllL . '-- 3~° I~TT W II Ti Ill' IUI Itl ICllJl llll/J Ill lt, ILllll], i . -- Ill JTS IYZ* Iii ltl I-N /0/6 7' -- ! S/I'- J! · SS.Il LTK I I & I~l' Ill! l/II fl II/I® III Iii l/I~l' Bill IICIdll 11($ Ill ¢1611l IL IAINIL i l -- I JT Il4® l~ III I-II -- Iii1' ill I ll~r Ill iii lllfl Itl I~Clll -- Ills *$* Illq~ ll~® IlO IISITlll I II ~"MgI~A4'O -- ~ ,1~$ 11/~'(1~ III ~1{ I.II _ /0~07 ' -- /e305' -- .1. 1llllli'll IQIIIOI' (,1011 -- lull I' II ~GI}Z I1' I ~ ltl --' IMI~ l~ ll illll l' i14#I -- IJIl.I/ .1%. i S.C.U. 42 SEC $,TTN,RgW, S .M. SWANSON RIVER I:'IELD i ii E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension REEEtVED Manual Rams Swab Valve Double Mastet Valves Wellhead ~_ : ~ STATE OF ALASKA ---" ~0.. ALASKA U..- AND GAS.CONSERVATION CC .... ~,IlSSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well : OIL [~ GAS [] SUSPENDED [] : :ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 82-199 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50-133-20363 4. Location of well at surface 9. Unit or Lease Name 1823'N & 572'W of SE Corner Sec 5, TTN, R9W, S.M. Soldotna Creek Unit At Top Producing Interval 10. Well Number 2583'N & 571'W of SE Corner Sec 5, TTN, R9W, S.M. SCU 42B-5 At Total Depth 11. Field and Pool 2598'N & 563'W of SE Corner Sec 5, T7N, Rgw, S.M. Swanson River - 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Hemlock GL = 152' K.B. = 177' A-028996 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No. of Completions !2-7-82 2-9-83 9-17-85 Nz~eet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10,945'; 10,900' 10,911'; 10,866' YES [] NO [~ NA feet MDI NA 22. Type Electric or Other Logs Run NA 23. CASING, LINER AND CEMENTING RECORD 10-3/4" 40.5# K-55 SETTING D3E~.MD 14-3/4" 1250 sks CASING SIZE WT. PER FT. GRADE TOP 29' BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7'5/8" 33,7#39.~ L-80 28' 3512' 9-7/8" 2077 sks 7-5/8" 29.7# L-80 3512' 4611' 9-7/8" 7-5/8" 33.7/t S8-95 4611' 8338' 9-7/8" 7-5/8" 39# SS-95 8338' 10,438' 9-7/8" 5½" 20# N-80 10,230' 10,943' 6½" 108 sks 24. Perforations open to Production (MD+TVD of Top and Bottom and . 25. TUBING REGORD interval, size and number) -.4 - .41" JSPF SIZE DEPTH SET (MD) PACKER SET (MD) 10,802'-10,796' 10,757'-10,750' 24~ 3½" 10,308' 10,199' 10,792'-10,787' 10,746'-10,741' 20/ 10,272' 10,772'-10,763' 10,726'-10,717' 36/ 26. NA ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10,759'-:10.,745' .. -- I 10)713!-10,?00' 54/ . DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10,686'-10,672' 10,640'-10,626' 56/ 10,666'-10,658' 10,620'-10,612' 32/ 10,652'-..10,638'. ' 10,606'-10,592, - .~56/ 10.632'-10.614' .10. 586'_- 10.568! . 72/ 27. ' PRODUCTION TEsT Date First P.r. oduction. · ] Method Qf Operation (Flpwing, gas lift, etc.) . I . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing :. Cas. ipgP~'essure CALCULATED I~ OIL-B.BL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. ~;. . . 24-HOUR RATE --~ ' : . 28. NA CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. : :. · RECEIVED · Alaska Oil & Gas Cons. Oornmissior! Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NA NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. NA FORMATION TESTS Include interval tested, pressure data, all fLu,ds recovered and gravity, GOIA, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ;. Item :28- If no cores taken, indicate "none" ' " STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WE LS DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator C~e~o~ U.S.A. ~c. 3. Address 8, APl Number 9. Unit or Lease Name 4. Location of Well At Surface:: ~8~3'N ~ 57~'~ of S~ Co~e~ Sec. 5, T?~, ~¢~, S.~. So]dotna C~eek At top producing interval: 760'N & I'E of surface location At total depth: 775'N & 9'E of surface location 5. Elevation in feet (indicate KB, DF, etc.) G.L. = 152' K.B. = 177' 12. Perforate Stimulate Repair Well Pull Tubing 10. Well Number SCU 42B-5 I6. Lease Designation and Serial No. A-028996 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Note: Report 13. Describe 11. Field and Pool Swanson River - Hemlock (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] [] Abandon [] Stimulation [] Abandonment [] [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began operations at 3:00 pm 8-31-85. Drilled out BPV in wellhead. Killed well with 9.5 PPG fluid. Pumped 5 sacks cement down tubing and displaced to 230'. WOC. Tested cement to 3500 PSI. Nippled down the tree and nippled up the BOPE. Tested the BOP's to 5000 PSI. Tested the annular to 2500 PSI. Released packer and pulled out of the hole with tubing hot topping every other joint checking for pressure. Found top of cement at 307'. Hot topped tubing below cement plug and killed well with 9.8 PPG fluid. Pulled out of the hole with the tubing. Picked up and tripped in the hole with a 4-1/8" mill, 2-7/8" drill pipe, and 3½" drill pipe. Clean out to PBTD of 10,911'. Tripped in the hole with an RBP and test packer. Set the RBP at 10,510', and tested the casing, liner top, and line to 3000 PSI. Tripped in the hole with a 4-1/8" mill a~nd a casing scraper to 10,600'. Picked up and tripped in the hole with 3-3/8" tubing conveyed perforating (TCP) guns below a test packer. Run gamma ray log and set the packer. Tested the test head and surface lines to 5000 PSI. Opened the bypass and pumped 70 bbls lease crude (1000 PSI under balance) down the tubing. Closed the bypass. Pressured the annulus to 2000 PSI and perforate the following intervals with 3-3/8" TCP guns 120° phasing 4- .41" JSPF: 10,802'-10,796', 10,792'-10,787', 10,772-10,763', 10,759'-10,745', 10,686'-10,672', 10,666'-10,658', 10,652'-10,638', 10,632'-10,614'. Flowed well to clean up. Pulled packer loose, and killed well. Pulled out of the hole with test packer and TCP guns. Ran completion string and packer. Spaced out and landed tubing. Nippled down the BOPE, and nippled up the tree. Displaced the well with lease crude. Set packer at 10,199' and 10,272' with EOT at 10,308'. Tested annulus and packer to 2000 PSI. Operations completed 9-17-85. 14. I hereby certify that the fo/e~e and correct to the best of my knowledge. Signed ./?~.~/_ ~._~_~.~_~__ Title Area Engineer The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO-~vfMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Chevron U.S.A Inc. 3. Address P. O. Box 107839, Anchorage, AK 99510 4. Location of We[[ At Surface: 182YN fa 572'W of SE Corner Sec. 5, TTN, Rgw, S.M. At Top Producing Interval: 759.71'N fa .7YE of Surface Location. At Total Depth; 774.71'N fa 9.32'E of Surface Location. 5. Elevation in feet (indicate KB, DF, etc.) GL= 152' KB: 177' 12. 6. Lease Designation and Serial No. A-028996 7. Permit No. 82-199 8. APl Number so- 133-20363 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 42B-5 11. Field and Pool Swanson River, Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate J;~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well J~[ Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Move in and rig up workover rig. 2. Kill well as required. 3. Nipple down tree and nipple up a Class III - 5000 PSI BOP. Test BOP's. 4. Release packers and pull out of the hole with tubing and producing equipment. 5. Clean out to PBTD of 10,911'. 6. Test casing and liner top above RBP set at 10,500' to 3,000 PSI. 7. Run tubing conveyed perforating guns below a test packer set at 10,300'. 8. Re-perforate the intervals 10,802'- 10,796', 10,792' - 10,787', 10,772'- 10,763', 10,759 - 10,745' 10,686'- 10,672', 10,666'- 10,658', 10,652 - 10,638', 10,632'- 10,614' with 4 JSPF. 9. Flow well until it cleans up. 10. Kill the~well. 11. Pull out of the hole with the test packet and guns. 12. Run the production tubing and packer. Nipple up the tree. 13. Displace the annulus with lease crude. Hydraulically set the packer, and test the packer to 2000 PSI. 14. Move the rig. Place the well on production. 2 E C E I~~ ~ [~ , Estimate that this work will start September 1 1985. 14. I hereby certify that the,foregoing is true and correct to the best of my knowledge. I Signed ~/~~--~ Title Area Engineer The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER ,*,pprovea Cc~7 goturr~d / _. By Order of the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TRANSMITT ~H&V i~i~1 U.~.~. IINi~. /~AND ACKNO~%EDGEMENT OF RECEIPT 'MATERIAL - (ALASKA) THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. 52 5--'ti w' RECEIVED BY --, REMARKS ON OTHER SIOE, THIS SHE'ET C~SrlION UeSJU INC. BOX 7-839 ANCHORAGE, ALASKA 99510 ' :.; I. nevlU. ~, .:. ~ TRANSMITTAL : · ~ . ~'-~ A://'/ ' DEPT.: PLAC~: _ THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. _ ,= CHE'VP, ON' U.$.A. Ir,lC. ) ACKNOWLEDGEblENT OF RECEIPT 0 'ATERIAL - (ALASKA) DATE FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. RECEIVED BY C~MPLI?'rlON REP~hT AREA: Soldotna Creek Unit LAND OFFICE: Anchorage PROPERTY: Swanson River Fi eld LEASE NO: A-028996 WELL NO: SCU 42B-5 APl NO: 50-113 - 20363 LOCATION AT SURFACE: 1823' N & 572' W from the S.E. Cor., Section 5, T7N, Rgw, S.M. LOCATION AT TOTAL DEPTH: 774.71I N & 9.32' E of the surface location ELEVATION: ~ DATE: 2/83 BY: AREA SUPERVISOR -- WORK PERFORMED BY: Brinkerhoff Signal Co., Rig #54 DATE COMMENCED WORK: 12/6/82" DATE COMPLETED WORK: 2/18/83 PLACED ON PRODUCTION: 2/16/83 SUMMARY TOTAL DEPTH: 10,945' EFFECTIVE DEPTH: 10,911' (cmt) CASING: 20" at 92' l0 3/4" at 3395' 7 5/8" at 10,438' 5 1/2" at 10,230' - 10,943' PERFORATIONS: 10,787 10,796 10,745 10,763 10,614 10,638 10,658 - 10,792 - 10,802 - 10,759 - 10,772 - 10,632 - 10,652 - 10,666 10,672 - 10,686 PLUGS' Original hole drilled to 7874'. Plugged with cement from 3500' - 3444!-' due to fish. · .... -...::,...... , . . 12/5 - 12/8/82 ~ ' - - 8.7 ppg Rigged up Brinkerhoff Rig #54. Accepted rig at 8:00 p.m., 12/~;/82. Drove 20", 94¥t, H-40 (88') conductor to 92'. Cut off 20" conductor. Nippled up 20" BOPE and tested. O.K. Spud at 10:30 p.m., 12/7/82. Drilled 14 3/4" te 391'. 12/9 - 12/10/82 9.4 ppg Drilled 14 3/4" hole to 3400'. Rigged up Schlumberger. Attempted to run DIL-SFL-SP log. Could not get below 1610'. POOH with logging tools. Ran in hole to 3400'. Circulated bottoms up. 12/I I/82 9.4 ppg Ran DIL-SFL-SP logs 3373' - 93'. Rig on standby 22Yz hours waiting for 10 3/4" casing. 12/I 2/82 9.4 ppg Waited for 10 3/4" casing 24 hours. 12/13/82 Waited for casing 12 hours. Circulated and conditioned mud for casing. Commenced running 10 3/4" casing. 12/I 4/82 9.3 ppg Ran 81 joints (3398') of 10 3/4", 40.5tt K-55 buttress casing with Baker float shoe at 3395' and Baker duplex stab-in float collar at 3302'. Halliburton cemented casing as follows: 20 bbl. caustic pre-flush, '10 bbl. spacer, 1250 SX Class "G" cement with 2.4% gel in mix water. Displaced with 35 bbls. mud. Floats held o.k. Nippled down 20" BOPE. Waited on cement. 12/I $/82 9.3 ppg Cut off 20" and 10 3/4" casing. Welded on 10 3/4" bradenhead with 10" 5MIt top flange. Tested lap weld to 1500 psi. Nippled up Class II! SM# BOPE and tested. Ool4. 12/I t;/82 95 ppg Drilled out cement stringers 2923'- 3304'. Tested 10 3/4" casing to 1500 psi. O.K. Drilled 3385' - 4002'. 12/17/82 9.6 ppg Drilled 9 7/8" hole 4002' - 4301'. Tight hole - raised mud viscosity and pumped'gel sweeps. Reamed 50' out of gouge hole. Drilled to 4331'. 12/I 8/82 - ! 2/22/82 9.7 ppg Drilled 9 7/8" hole 4331' - 6227" 12/23/82 ~ ' , - %6 ppg Drilled 9 7/8" hole 6647' - 6922' (reamed through coal sections). Drilled 6922 - 6928', Worked stuck pipe at 6288'. Had full circulation but unable to rotate pipe. Pulled pipe free with jars. Reamed 90' to bottom and drilled to 7002'. 12/2q/82 10.5 ppg Drilled 7002'- 7065'. Had flow after drilling break. Shut well in. Had no shut-in pressure. In..Q~_creased mud weight. Mud gas cut. Drilled 7065' 7068'. Reamed coal sections. Drilled 70-~;~i L-7093".--Mud not gas cut nor was well ~lowing. Reamed 90' to bottom and drilled to 7204'. 12/25/82 10.5 ppg Drilled 7204'- 7605' 12/2~;/82 II .7 ppg Drilled 7605'- 7874'. Well started flowing. SICP : 600, SIDP : 250 psi. Had a 20 bbl. gain. Circulated through choke and lost DPP and casing pressure after pumping 100 strokes. Opened well and attempted to work pipe. Pipe stuck. 12/27/82 11.8 ppg Worked pipe while waiting for Alaska Pipe Recovery. Pumped 150 bbl. mud with no returns. I hr.-SICP=200 psi DPP=0 psi. Rigged up to run free point. Pumped down drill pipe to kill pressure. Obtained circulation. Circulated through choke to kill well. Circulated out gas, fresh water, fine coal and sand (no heavy weight mud). Drill pipe pressure increased from 650 psi - 950 psi. Increased mud weight and pumped mud down drill pipe while controlling returns through choke (gas and water in returns). Unable to regulate drill pipe pressure with choke. Pumped hi2 bbls. Weighted mud down annulus until static. Ran free point. Pipe stuck at 3~t05'. 12/28/82 11.8 ppg Backed off at 3380'. Circulated and conditioned mud. Jarred on fish at 3380' without success. Ran free point. Pipe still stuck at 3405'. Backed off at 3380'. Washed over fish 3380'- 3445'. 12/29/82 11.8 ppg Washed over fish from 34tt5' - 3501'. Circ and 'cond. mud. POOH. RIH to 3380' with jarring assembly. Jarred on fish without success, Ran free point, Fish stuck at 3500'. Backed off at 3471'. POOH and recovered three joints drill pipe. RIH with washing assembly. Washed over fish 3471'- 3596'. 12/30/82 II .8 ppg Ran free point. Fish stuck at 3502'. Backed off at 3471'. Washed over fish from 3471'- 3596'. Ran free point. Fish stuck below 3605'. Free at 3596'. Ran string shot to 3596'- I it., 5" drill pipe twisted off. Recovered 27.22' of drill pipe (top of fish 3Lt99').. Fish: 9 7/8" bit, bit sub, lead collar, stab, monel, non mag stab, monel, stab, 3 - 6 3/4" D.C., stab, 4- 6 3/4" D.C., stab, X-O, jars, 30 its. of 5" HWDP, 101 its 5" D.P. 12/31/82 - I/I/83 Unsuccessfully attempted to get over fish at 3500' with overshot. POOH. Made up bent 5" D.P. single with overshot. RIH. Could not get below 3zt33'. POOH without tristate knuckle jt.,made up overshot and knuckle it. RIH. Could not get over fish. POOH. Make up wall hook guide on knuckle it. RIH. Worked over and latched onto fish. Ran wireline and retrieved restriction plug. RIH with string shot. Unable to get into top of fish. Took pull on fish to straighten out knuckle it. and pulled off fish. Retrieved restriction plug. RIH with wireline spud bars. Spud on obstruction. Could not get past 3b,99'. POOH with spud bars. Attempted blind back off. Backed off in drill collars. Screwed back into collars. RIH with string shot to 3z~98'. Backed off at 3z~99' with overshot and POOH. No recovery. Laid down fishing tools. Rigged down wireline. Tested BOPE to 5000 psi. I/2/83 I0 ppg Ran in hole with open ended drill pipe to 3500'. Set densified plug as follows: 10 bbls. caustic preflush ahead~ 350 C.F. Class "G" cmt. with !% friction reducer. Displaced out open ended drill pipe with 200 C.F. mud. Pulled drill pipe to 3288' and reversed out 16 C.F. excess cement. Bradenhead squeezed with 100 C.F. mud (max. pressure: hS0 psi. Did not break formation down). Shut-in for six hours. Tagged top of hard cement at 3397'. I/3/83 9.8 ppg Polished off cement plug to 3tt/~zt'. Kicked off with Dyna-Drill and drilled and surveyed 9 7/8" hole from 3ztz~z~' _ 3592'. I/~t/83 9.9 ppg Drilled and surveyed 9 7/8" hole 3592' - 15182 9.8 ppg Drilled and surveyed 9 7/8" hole 4467' - 5161'. 1/6182 9.8 ppg Drilled and surveyed 9 7/8" hole 5161'- 5861'. I/7/83 9.7 ppg Drilled ond surveyed 9 7/8" hole 5861' - 6388'. ~/8/83 Drilled end surveyed 9 7/8" hole 6388' - 6692'. 9.7 ppg I/9/83 10.5 ppg Drilled ond surveyed 9 7/8" hole 6692' - 7105'. !/10/82 Drilled 7105' - 7205'. Well started flowing. !1 ppg mud. Had I! ppg mud in returns. Circulated out !1.0 ppg gas kick with I/I 2/83 12.~ ppg Ran in hole with string shut and partially unplugged bit jets. Raised mud weight to 12.z~ ppg and killed well. Reamed 30' to bottom (17' fill). Circulated bottoms up. Well started flowing. Shut well in. Had 600 psi casing pressure and 0 psi drill pipe pressure. Circulated out gas. (Gas was close to surface.) Shut down. No flow. Circulated directly to mud pit while checking for flow. !/I 3/83 12.5 ppg Drilled 7205' - 729zt'. Attempted to unplug and unball bit. Broke circulation three times while tripping for new bit. Drilled 729zt' - 7332'. I/!/t/83 , 12.5 ppg Drilled and surveyed 9 7/8" hole 7332' - 7633'. !/15/83 12.5 ppg Drilled and surveyed 9 7/8" hole 7633' - 7943'. !/I~;/83 Drilled and surveyed 79zt3' - 7968'. 5000 psi. Drilled to 8186'. 1/17/83 12.5 ppg Drilled and surveyed 8186' - 83/t0'. I / 18/83 12.5 ppg Drilled and surveyed 83b,0' - 8507'. 1/19/83 12.5 ppg Drilled and surveyed 8507' - 8692'. i/20/83 12.5 ppg Drilled and surveyed 8692' - 8960'. 12.5 ppg Tested hydril to 2500 psi~ rams and kelly to Raised mud weight to !!.5 ppg and circulated out kick. Had 11.5 ppg mud in returns. Shut down. Had 200 psi casing pressure, 0 psi drill pipe pressure. Raised mud weight to !1.7 ppg with same results. Raised mud weight to 12.0 ppg and pumped 312 bbls. down annulus. Pressure decreased from II00 to 200 psi. Attempted to pump down drill pipe without success. I!/! 1/82 12 ppg I/2 !/83 ~ ' · ' 12.5 ppg Drilled 8%0' - 9133'. I/22/83 12.5 ppg Drilled 9133' - 9387'. I/23183 12.5 ppg Drilled 9383' - 9/t00'. Tested BOPE. Ran in hole. Broke circulation at 10 3//t" casing shoe. Washed and reamed/t0' to bottom. Drilled 9 7/8" hole 9/t00' - 957/4'. I/2q/83 12.~; ppg Drilled 9 7/8" hole 957/t' - 9777'. ! 125183 12.5 ppg Drilled 9769' - 9975'. ! I/2~;/83 12.5 ppg Drilled 9975' - 10, I/t2'. ! 1/27/83 Drilled 10~1~2' - 10,297'. 1128183 Drilled 10,297' - 10,352'. Pulled out of hole for bit change. 30' to bottom. Drilled to I 0,/t ! 5'. 1/29/82 Drilled 9 7/8" hole 10,/tlS'- 10,/t33'. and FDC-CNL from 10,/t33' - 3395'. after recording repeat section. 12.5 ppg Ran in hole. 12.5 ppg Reomed I/3 !/83 12.q ppg Continued stripping drill pipe in hole to 10,255'. Fish came free at 9815'. Pulled out of rope socket and retrieved wireline. Pumped pill and pulled out of hole. Laid down fish. Circulated and conditioned hole-bridge at 7000'. Circulated bottoms up. Washed and reamed ~;992' - 7022'. Circulated and washed to bottom. Drilled 9 7/8" hole 10,/t33'-10,505'. Attempted to free sonic tools while waiting for fishing tools. Stripped drill collars over wireline. Schlumberger spear hung in jars and parted wireline. Clamped off wireline - sonic tool remained on the wireline. Stripped drill pipe over wireline. I ~30/83 12.5 ppg 12.5 ppg Circulated and conditioned for logs. Ran DIL (W.L.T.D. 10,/t37') sonic tool stuck on bottom 2/I/83 .,, - , 12.4 ppg Circulated and conditioned hole. Pulled out of hole. Ran DIL 10,505' - 7500'~ BHC 10,505'- 3395'. Rigged up sidewall cample gun. Shot sidewall samples 10,500'- 10,495', 10,494'. Stuck gun at 10,494'. Unsuccessfully attempted to work SWS gun free. Freepoint indicated line tension from 4000'. Rigged up to strip over wireline. 2~2~83 12.5 ppg Stripped over wireline 'to 7983'. Fish came free. Pulled out of rope socket and pulled out of hole with wireline fish. Circulated and conditioned hole for casing. 2/3/83 12.5 ppg Rigged up and started running 7 5/8" casing. 2/4/83 12./¢t ppg Completed running 241 joints of 7 5/8" casing to 10,428' as follows: Csg. Detai I: Length Top 7 5/8" Float Shoe 1.83' 10,427' I Jt. 7 5/8", 39#, SS-95, LT&C 36.45' 10,390' 7 5/8" Float Collar 1.65' 10,388' 47 Jts. 7 5/8", 39#, SS-95, LT&C 2,050.15' 8,338' 19 Jts. 7 5/8", 33.7tt, SS-95, LT&C 826.76' 7,511' 7 5/8" Stage Collar 3.18' 7,508' 67 Jts. 7 5/8", 33.7tt, SS-95, LT&C 2,897.69' 4,61 I' 25 Jts. 7 5/8", 29.7tt, L-80, FL4S 1,098.68' 3,512' 46 Jts. 7 5/8", 33.7#, L-80, FL4S !,970.13' 1,542' 36 Jts. 7 5/8", 39#, L-80, FL4S 1,541.90' 0' On 2/7/83 tagged shoe 10' deeper at 10,~t38'. Rig up and test B. J. Hughes cement lines to 5000 psi. Pumped 56 CF water, 140 CF caustic (10#/bbl.), 56 CF water and 910 CF of Class G cement mixed with 3/4% friction reducer, .2% defoamer, and 0.15% retarder thru the shoe with good circulation throughout. Shut down pumps at 3% over theoretical displacement. (There was a 350 psi drop in surface pressure.) Floats held. Opened DV and began circulating at 150 SPM. Circulated mud for ~ hr. Returns wt. = 12.5 ppg. Test lines to 5000 psi. Pumped 112 CF of water followed by 1708 CF of Class "G" cement mixed with 2.1% pre-hydrated gel, 3#t% friction reducer, 0.15% retarder and .2% defoamer and 428 CF of Class "G" with 3/4% friction, 0.2% defoamer, and 0.15% oretadex. Bumped plug with 4;% excess. Held 3500 psi for 10 minutes. Bled back 22 CF. DV clo~ed. Had 50 CF of good cement returns before losing circulation with 5% of displacement to go (cement top should be 1000' to 2000' from the surface). All mixing and displacement rates were 4 to 6 BPM. installed casing slips in tubing spool. 2/5/83 11.7 ppg Completed installing tubing spool. psi, Class !!1 BOPE. Tested same. flowline. Tested to 5000 psi. Nippled up 13 3/8", 5000 Ran in hole to 3551'. Cleaned cement out of 2/6/83 9.9 ppg Drilled out D.V. collar at 7508'. Drilled out cement and float collar at 10,415'. Circulated and conditioned mud. Lowered mud weight to 9.9 ppg. Pulled out of hole. Rigged up Dresser Atlas and ran in hole with CBL-CCL-GR logging tool. Could not get below 10,075'. Ran CBL-CCL-GR from 10,075' to surface. 217183 9.4 ppg Ran in hole to 10,415'. Circulated and conditioned mud. Lowered mud weight to 9.4 ppg. Pressure tested casing to 3000 psi. O.K. Drilled out cement to shoe at 10,438'. (Found shoe and float collar 10' lower than expected.) Drilled 6'/2" hole 10,505' - 10,653'. 2/8/83 9.4 ppg Drilled ~?/2" hole 10,653 - I 0,930'. 2/9/83 %4 ppg Drilled 6~'~" hole 10,930 - 10,945'. Made a short trip to 7 5/8" shoe and conditioned hole for logs. Ran DIL-FDC-CNL and sonic from 10,945'- 10,438'. Shot 45 SWS at selected intervals from 10,928'- 10,448'. 19 misfired, 2 no recovery, 24 recovered. 2/! 0/83 9.4 ppg Conditioned hole for liner. Ran 22 joints of 5'1:,", 20tt, N-80, 8rd, LT&C liner from 10,943'- 10,230' with F.C. at. 10,910' and pumped 5 bbb. water, 20 bbls. caustic (! O#/bbl.), 5 bbl. water and 125 C.F. of Class "G" cement mixed with 3/4% CFR-2, 0.2% HR7 and 2% KCI by weight of mixing water. Bumped plug with 85 C.F. (4% over theoretical). Bled back ! C.F. Floats held. Reversed out contaminated mud and water. No Cement. Pulled out of hole while waiting on cement. 2/I ~/83 Waited on cement 13 hours. Pulled out of hole. Ran in hole with 4'/z" bit and located float collar at 10,910'. Tested liner lap to 3000 psi for 30 minutes. Pulled out of hole. Ran in hole with the 5'/~" and 7 5/8" casing scrapers. Circulated bottoms up and pulled out of hole. (No cement was found over top of liner.) 2/! 2/83 9.4 ppg Ran a CBL-GR and multi-spaced neutron 10,911'- 10,000'. Rigged up and ran Howco RTTS tester with no cushion in order to test the liner lap. Light blow from DP with RTTS at 9227' while running in hole. Howco hydro spring tester may hove small leak. Set packer above liner lap. Filled annulus with 34 bbls. Opened tool all the way. Flow decreased from medium blow in bubble bucket to dead in I hr. 45 min. Opened circulating sub. Reverse circulate 12 bbls. to get fluid to the surface (14 bbls. influx). Circulate bottoms up. No reservoir fluid sample observed. 2/13/83 ',, " ~ - 9.5 ppg POOH with Howco RTTS tester. Rigged up and ran Howco hydrospring tester. Landed packer at 10126'. Opened tool-had weak blow. Blow increased to heavy blow in I hr. Flowed well to bubble bucket for .5 hrso with heavy gas flow. Shut hydrospring and dropped bar to open circulating valve. Reverse circulated 7 bbls. of heavily gas and oil cut mud. Circulated hole volume. Spotted heavy pill. Pulled out ot hole. 2/I/~/83 9.,5 ppg RIH with Baker "Retrievamatic" 7 5/8", 39" retrievable packer to 10210'. Spotted a balanced 15 bbl. water plug on bottom. POOH to 10030'. Circulated DP volume of water and set packer. Pressured annulus to 1000 psi and hold. Pressured up on liner lap to 3000 psi. at I/[t BPMo Maintained + 3000 psi for 15 min. Shut down. Pressured liner lap to 5000 psi. Pressure bled from 5000 psi to 4800 psi in 5 min. Circulated water out. POOH. RIH to 10850'. Circulated 100 bbls. of water. Circulated lease crude. 2/15/83 Circulated 475 bbls. of lease crude. Pulled out of hole laying down drill pipe. Rigged up Weatherford and began running production tubing. 2/16/83 - 2/17/83 Finished running tubing. Landed tubing with tubing tail at 10313'. Set 5'/2" pkr. at 10278' with 1100 psi. Tested annulus. Set 7 5/8" pkr. at 1020zt'. Tested annulus. Install BPV. Dropped ball. with 1680 psi Nippled down BOPE stack. Nippled up tree. Pressure tested tree to 5000 psi. Removed BPV. Schlumberger recorded a temp. log from 100' - 1091 I' POOH. Pressure tested lubricator and packed off to 2`500 psi. Perforate 10787' - 10792' and 10796' - 10802' (DIL) using I !1/16" "Enerjet" with zt JHPF on O° phasing. Put rig on standby 9-.00 a.m.~ 2/1~;/83. 2/'!8/83 Perforated 10,745' - 10,759' and 10,763' - 10,772' DIL using 4 HPF on 0° phasing with Schlumberger's I 11/16" Enerjet guns. Released rig. 5/10183 - 5/I 1/83 Schlumberger rigged up. Pressure tested lubricator to 4000 psi. Perforated H-8 sand intervals 10,614' - 10,632', 10,638' - 10,652', 10,658' - 10,666' and 10,672' - 10~686' using I !1/16" Enerjet guns at 4JHPF and 0o phasing. Returned well to production. TUBING DETAIL Shoe @ 10313' Top; From KB 2 3/8" EUE, 8rd, Shear Sub I Jt., 2 3/8", EUE, 8rd 5Y2, 20~! x 2 3/8", 8rd FH packer X O: 2 3/8", 8rd, 3'/2", Armco Seal-Lok, XO: 3'/2", Armco SeaI-Lok, 3Y2", 8rd, 2 Jts., 3Y2", EUE, 8rd tbg, N-80 Otis "S" nipple, 3'/2", 8rd, with optional 2.875" ID. 3'/2", 8rd, EUE collar 7 5/8", 39t! x 3'/2", EUE, 8rd FH Packer I Jt, 3Y2", EUE, 8rd, N-80 ~+Md~urry Hughes, MHO, coated, G/L mandrel; 3'/2", Butt with XO's to 3'/2" 8rd, EUE with lY2" IRKED II ~; Jts., 3Y2" EUE, 8rd, N-80 ~+MHO G/L mandrel with dummy 12 Jts, 3'/2", EUE, 8rd, N-80 *MHO G/L mandrel with dummy 9 Jts, 31/2'', EUE, 8rd, N-80 ~+MHO G/L mandrel with dummy I~; J.t.s, 3'/2", EUE, 8rd, N-80 ~+MHO G/L mandrel with dummy 24 Jts, 31/2'', EUE, 8rd, N-80 ~+MHO G/L mandrel with dummy 24 Jts, 31/2'', EUE, 8rd, N-80 ~+MHO G/L mandrel with dummy 31 Jts, 3Y2", EUE, 8rd, N-80 ~MHO G/L mandrel with dummy 40 Jts, 3Y2", EUE, 8rd, N-80 *'MHO, G/L, mandrel with dummy 47 Jts, 3~/2'', EUE, 8rd, N-80 10312' 10278' 10204' 10163' 6486' 6095' 5800' 5283' 4514' 3745' 2755' 1480' ~AII mandrels are 3Y2", butt with XO's to 3'/2", EUE, 8rd. OoOo (Inches) 3.06:,25 4.500 4.250 4.500 ~.453 JoOo (Ir~ches) 2.000 1.995 2.000 2.937 3.000 ~ .... STATE OF ALASKA ~'-'" ALASKA ~,,- AND GAS CONSERVATION C(.,,,~-MISSION SUNDRY NOTICES AND .REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 107839, Anchoraqe, Alaska 4. Location of Well 99510 1823' N & 572' W from S.E. Cor Sec 5 T7N R9W S. B&M 5. Elevation in feet (indicate KB, DF, etc.) 168' KB 6. Lease Designation and Serial No. A-028996 7. Permit No. 82-199 8. APl Number 50- 133-20363 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 42B-5 11. Field and Pool Swanson River Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] '- Perforations [] Altering Casing [] Stimulate [] Abandon [] ' Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Shut in well and obtain pressure buildup_. 2. Perforate the H8 intervals 10614 - 10632, 10638 - 10652, 10658 - 10666, and 10672 -.10686 with 4 JHPF' and 0© phasing. 3. Return well t© prodUction from all zones. This work will be done during the week of April 25, 1983. 14. I hereby certify that the foregoin~is true and correct to the best of my knowledge. Signed . Title Aroa ~.nqineer The space below for Commission use Date Conditions of Approval, if any: Approved by ORIGIHAI. SIGNED BY [,.,:,~E C. SMITH Approved Co~-,.- Return~.d By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~. STATE OF ALASKA ALA OILAND GAS CONSERVATION OMMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well f-~ Workover operation [] 2. Name of operator 7. Permit No. .. Chevron USA Inc. - 82-199 3. Address 8. APl Number P.O. Box 7-839, Anchmrage, AK 99510 50-133-20363 4. Location of Well at surface Approx. '1800' N & 650'W from the SE Cor., Sec. 5, T7N, RgW, S.M. l , Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 168 '_~B_ A-028996 9. Unit or Lease Name Soldotna Creek 10. Well No. SCU 42B-5 11. Field and Pool Swanson River- Hemlock For the Month of December [.j)Depth,lndof mqnth_footage dri~[c.~d, fishin~ jobs. dire,ctio~al, c[riJ~i,n,g pro~em~.sDudCa[e, re~r~.. ~ zu c~cnor no ~z . bp~~ IZ///~Z. ~lle~ 14 3/~" ~ole to 3400'. ~ed. 1 " ' C1 "G" ~ 0 3/4 , ~.5#, K-55 Butt. ~g. to 3395 ~d c~nted ~th 1250 sx. . Tested ~PE to 2500 psi - csg to 1500 psi ~illed 9 7/8" hole to 7874'. Stuck pipe. freeport ~d fo~d pipe stu~ at ~5~ sack~d b~ at ~3~0'. W~hed over D.P. ~d recovered to 3497'. ~ep. to ab~~ hole for si~tra~. 13. Casing or liner run and quantities of cement, results of pressure tests see above 14. Coring resume and brief description none 15. Logs run and depth where run DII-SFL-SP 3373' -93' 16. DST data, perforating data, shows of H2S, miscellaneous data ~None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SlGN[O l~ll:. ~.J, ~;) ?~[0~,g~ T,TLE Area Operations Supt. DATE ~1 [b !~" . ¼ . NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission b.~ the, i 5th of the succeeding month, unless otherwise directed. FOrm 10404I/ I WI=LL COMPLETION OR RECOMPLETION REPORT AND LO Classification of Service Well '//'~'-" 1. Status of Well OIL [] GAS [] SUSPENDED-i I ABANDONED [] .SERVICE [] 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 82-199 3. Address 8. APl Number P. 0. Box 7839, AnChorage, Alaska 99510 50-133-20363 9. Unit or Lease Name 4. Location of well at surface 1823' N & 572' W from the S.E. Cor., Sec. 5, T7N, R9W, S.M. Soldotna Creek At Top Producing lnterval 766.2'N & 4.4' E of the surface location. 10. WelINumber SCU 42B-5 At TotaI Depth 774.71' N & 9.32' E of the surface location, ll. Field and Pool [~,-,'~, .,-'~1 fi- ~-~,~ ~' ~f ~ (',:,- . ,¢:~ ~) Swanson River Hemlock 5. ElevatIon ~n feet (.nd~cate KB, DF, etc.) 6. Lease Designation a/nd Serial No. 168' K.B.I A-028996 . 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 12/7/82 2/9/83 2/18/83I __ feet MSLI 1 -17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10,945'-10,900' 10,911 '-10,866' YES~] NO[]I __ feet MD -- 22. Type Electric or Other Logs Run CBL-GR-MULT I SPACED NEUTRON, D I L-SFL-SP, CBL-CCL-GR, FDC-CNL, BHC Sonic 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 SUrface 92' -- Driven 10 3/4" 40.5 K-55 Surface 3~95 14 '~/4 12~;0 SX. 7 5/8" 39.33-.7 SS-95.$-c.,5 " 10438' 9-7/8 2077 SX- 29 L-80' 5½" 20 N-80 10,230' 10943' 6~ .108 SX. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD _,. i~terval, size and number): SIZE DEPTH SET (MD) PACKER SET (MD) H-10 4 HPF .33" 2 3/8" 10,313' 10,278' 10,787.- 10,792MD - 10,741 - 10,746~VD 3½ 10,204' 10,796- 10,802MD- 10,750- 10,757TVD 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 10,745- 10,759MD- 10,700- 10,713TVD , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1~0,763- 10,772MD - 10,717- 10,726TVD . 27. PRoDuCTION TEsT Date First Production " ~- I Method of Operation (Elowing, gas lift, etc.} 2/16/8~3 'I Flowing . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MC~ WATER-BBL CHOKE SIZE GAS-OILRATIO 2/.16/83 2 ; TEST PERIOD JJ~ 26 700 32 Open 2274 . FI :o~ Tubing.. Casing Pressure CALCULATED OIL-BBL GASoMCI~ WATER-BBL OIL GRAVITY-APl (corr) . ~, . 8392 391 -- Press. ]600 24-HOUR RATE ~ 307 CORE DATA 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Sidewall sample data attached. :: RECE!!]ED · , _. -: · ', . . ..~. .:~. : : - MAR ---8 ~ Alaska Oil & ~as 6o;~s. 6om~nission - Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME H-1 H-8 H-lO GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 1O4O7 - 10565 1O687 30. 10452 - 10610 10732 FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. None 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed "~- ~' ~ Tit,e Area Engi neet Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS CORE ANALYSIS REPORT FOR CHEVRON UoS SCU-42B-5 SWANSON RIVER KENAI PENINSULA. ALASKA These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. ~HEVRON U.S.A. INC. ~CU-42B-5 ~WANSON RIVER (ENAI PENINSULA, ALASKA CORE LABORATORIES. INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE ; FORMATION. ' DRLG. FLUID; LOCATION ; 22-FEB-83 CORE ANALYSIS RESULTS DEAN-STARK ANALYSIS PAGE lA FILE NO ; BP-3-829 ANALYSTS ~ WSP,TLS,RBB LABORATORY; ANCHORAGE ~AMF'LE DEPTH qUM~R FEET PERMEABILITY (MD) POR GRAIN FLUID BATS. MAXIMUM 90 DEG VERTICAL % DEN. OIL W'rR Ar'mml~sis Performed on sidewmll corem DESCRIPTION samples insuf, for Pe~'meabil:i.t~ 1 2 4 5 7 8 11 12 .'1.3 :1.4 :1.5 16 :1.7 18 20 21 9296,0 24,4 2°23 7.6 78°6 10458.0 20.~ 2+72 0~0 89.3 10472,0 32° 22+2 2.70 2,2 83,2 10485°0 21.4 2~70 0+0 88.9 104~4.0 2~7 2~5 14+7 3~o& 10505°0 26.2 2,63 12+6 41,2 10514,0 27,7 2o&5 2,8 74°7 10523~0 28,0 2,~8 0,0 92.9 10535.0 30~0 2,60 3~8 ~2.~ 10557,0 31ol 2~&2 2~4 74,5 10577°<> 27.~ 2+~3 7°0 54.3 10&08.0 2&.8 2+&~ 0.0 82o& 10&1800 4~. 24~8 2o&7 3~0 70o~ 10759,0 20+2 2°73 0,0 96.4 10771,0 26,~ 2,88 0~0 74ol 10785,0 27°6 2~55 2.8 3~+8 107~7~0 28,7 2°62 8°4 42,6 10827.0 15o6 2°72 0°0 85,7 10837°0 24~3 2.6t9 0°0 74+1 10847.0 23.1 2.70 0.0 96.7 eom]. ss~vf-f~cl~,mioa ss~vf-f~'~$1t~miom ss;vf-'f~$1t~,mica ss;vf~r,sh~micm ms~vf~shu~micm sh ss~vf-f~slt~mica ~me These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 2A :HEVRON UoS.Ao INC. DATE ; 22-FEB-83 ~CU-42B--5 FORMATION . CORE ANALYSIS RESULTS DEAN-STARK ANALYSIS FILE NO ; BF'-3-829 ANALYSTS ; WSP,TLS,RDB ~AMF'LE DEF'TH PERMEABILITY (MD) POR GRAIN FLUID SATS, qUMBER FEET MAXIMUM 90 DEG VERTICAL % DEN° OIL WTR 22 10869°0 24+9 2,67 0,0 75,0 i .3 10876,0 23.7 2.64 3,2 79,2 25 10899,0 30, 21o8 2°85 1,9 78,8 28 10927,0 22,8 2,85 4,7 88,5 DESCRIPTION ss; vf-$~ r, $1 t.~, micm ss; vf-f.~r ~ ml%.~, micro, omrb ino].$ mm;vf-m~r,mlt~,miom These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS CORE ANALYSIS REPORT FOR CHEVRON U.S.A. INC, SCU._4o' ,=' ~..]E{ .... ,..,i SWANSON RIVER · KENAI F'ENINSUL. A, AI_ASKA These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, lnc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitablene,~ of an), oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CHEVRON U.S.A. INC. SCU-42B-5 SWANSON RIVER KENAI PENINSULA, ALASKA CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS BATE : FORMATION : DRLG. FLUID; LOCATION : 22-FEB-83 CORE ANALYSIS RESUI..TS DEAN-STARK ANALYSIS PAGE lA ,, · FILE NO : BF"-3-829 ANALYSTS : WSP~TLS,RDB LABORATORY: ANCHORAGE SAMPLE I:~EPTH NUMBER FEET PERMEABILITY (MB) POR GRAIN Ft. UII),:~C'A'°¥.:~. MAXIMUM 90 DEG VERTICAL % BEN. OIL WTR Ar.m].s~sis eerformed or, sidewmll cores DESCRIPTION Most s~,Ples if',s,..~f. 'for Permembili't:.~ 1 4 5 6 7 8 9 10 11 :l 2 .1.3 14 15 16 17 18 19 20 21 9296.0 24.4 2.23 7.6 78.6 10458.0 20.3 2.72 0.0 89.3 10472.0 32. 22.2 2.70 2.2 83.2 10485.0 21.4 2.70 0°0 88.9 10494.0 26.'7 2.65 14.7 39.6 10505.0 26.2 2.63 12.6 4.1..2 10514.0 27.7 2.65 2.8 74.7 10523.0 28.0 2.68 0.0 92.9 10535.0 30.0 2.60 3.8 62.2 10557.0 31.1 2.62 2.4 74.5 10568.0 i 23.6 2.61 10.5 71.6 10577.0 27.6 2.63 7.0 54.3' 10608.0 26.8 2.69 0.0 82.6 10618.0 43. 24.8 2.67 S.O 70.6 10759.0 20.2 2.73 0.0 96.4 10771.0 26.9 2.88 0.0 74.1 10785.0 27.6 2.55 2.8 39.8 10797.0 28.7 2.62 8.4 42.6 10827.0 15.6 2.72 0.0 85.7 10837.0 24.3 2.68 0.0 74.1 10847.0 2~.1 2.70 0.0 96.7 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitablene~ of any oil, gas or other mineral well or sand in connection with which such report is used or relied, u~on. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 2A CHEVRON U 0 S,A, INC, DATE ~~-..~2-..-FEB--.83 SC:U-..42B.--5 FORMATION ~ CORE ANALYSIS RESUI_TS DEAN-STARK ANALYSIS FILE NO ,~ BF .... 3..-829 ANALYSTS ,~ WSF',TLS,RDB SAMPLE DEF'TH PERMEABILITY (HD) POR GRAIN FI...UID SA'TS, NUMBER FEET MAXIMUM 90 BEG VERTICAl.. % DEN, OIL WTR 2 10869,0 24,9 2,67 0,0 75 0 . ( 23 10876,0 23,7 2,64 3,2 79,2 24 10885,0 39, 24,6 2,65 10,6 65,0 25 10899.0 30. 21.8 2.65 1.9 78.6 26 109~7,0.. ~,°'~ 8 2,65. 4,7 I. EoCR.[F'TION :i. r, c .1. s These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or ~nd in connection with which such report is used or relied upon. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY CHEVRON U S A COMPANY 42B-5 -.WELL HAME .. SWANSON RIVER, KENAI, ALASKA SINGLE SHOT 2-]0-83 JOB NUMBER TYPE SURVEY DANE CLARK ENGINEER NAME TI-~LE 473 DEPTH INTERNAL FROM ~6T~ S~fiNATURE 10946 12-!0-82 2-8.,83 DATES SURVEY TAKEN FROM TO Tills IS A RECOR[I OF A SUB-SURFACE SURVEY OF Y-..q!Jt~ WELL We have retained a copy of your survey report in our fides for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made from the original by any :~hJeprint company. RECEIVED Anch0¢ag~, GREATLAND D T REF:-f '1' ANAL DR Z LL I NG F:OMPLE-[ I ON REF'ORT .::F~M,F'U-I'ED l-,',,I 2-8-::::3 Li'.::;'~iNG RADIU'.::; AF r2:URVA'I-URE ]'EC:I-tN'iC.!UE FRF'.~Fi '.:_.;URVEY DAYA TAKEN ?-',:::-',::::':', !:'ZNAI_ CLOE;tJRE 0 fREC'i'iON N 2. O0 W ::;INGLE '.3HOT '.31JRVF-Y RECOR'Fi OF F;URVEY (WELL As;SU¢IEO VERTICAL 'i'0 4'7:3.0 ) F:H EV RON Lt. S. A. C:HFVRf]N 42B-5 (',, C:A:B DR t F l' 'i'RLIV ER T :"-';t.I B E;E A. '.::;E f': T l FiN_ O~:F:'-f'H i]G MN DEF'TFI DEF'TH ]'iTF;'I' 0 0 0 O. (30 -17¥. 00 0. O0 REF:]'iON RELATIVE COORDINATES ANGLE FROM WELL-HEAD O. O0 O. 00 ('~. o0 C L F', S U R E D I '.::;-I' A N C: E Fi G M N '.:; DOG LEG cl e 9 / i 00 47' :':: fl ('-) 47 :'::, 00 '.::'9 L:,. 0 (:) O. (')0 0.00 O. 00 0. O0 0.00 0 0 0 0. 000 ~.' ,::, .j ':'°49 2, 4 ::: 2 ...I ..I ,~. "",d, 5 i ":.} 4 2.7 i. 489 (J _, ,,. t_) i 5-;.'-:; i ::', '.:, :-:': 2 .6 :}': 4 '7 d, 657 '70 a, 4 / ,,'_ ._l .% 762() 7927 ':' :i. i4 () ]. ~:' 1 :'::6'7 · 9::: i i '9C) '::~',:: ('i ]..5 l ',:::61.9:::: i/:,84, '.9 E: (1) 15 ".:. ' 356,. 9'7 217':). 9'7 (").:30 .."""'..-:, ..... ._, ._,' ':.),i,· . 5"'678 , '9/-. .. 0 () ._,':':::/1-8 · 96 :2: i 2' 1 · ':i),"-,. _ "::.' 45 :'::4::::~ 1.9 :l.:2::2:,:i)4. '?; i '~' 45 "" s=; .:: ...... i · 71 :3:374. '7 .l '7:30 :i:650 · o4 :E:~4 7:1',. (::)4 '7 4'.:'i i:'9 !=i/:,. 5: :L::37 '2"'ii>, :2: i 7 :'3C~ 4".'.:'d,,q. 5,'i,~ ,::) F: '7' , 56 7 0 45 70 · 05' 4:3'~.~:::. 0':) 7 ('-~ 48'7 ',::~. 7 F', 4'701 · '78 '7 o El _1. P, 7. ,:t.e, 501. O. 4L-, 7 ('-~ 5497. l :'4 5:2:20. l :':: '7 0 .._,':' ,:-,'] .... o 1.84 5624 , :i:.: 4 7 0 6o21.2o 5::::44.20 · -% ,/...:,..:,%. . /_-, 4 ........ .-.._ 00 6, i 48 00 '7 :':i:C) 66:32,60 /:,w._,._" '="";. 60 ; 0 '7 ('):2.: 6 ":'""; "'"'": ") - '- · ,_,._ .... · '7 ' "'" 7225:::::9 _. _ 1o , _. '7C)4/-, ::':.z 7 15} .... ; '"" '= .... :' 5':' ':' · _ / 4..: ..... 1 :::: '7 ..._ ,_, · 1 ,_, '7:70 "'"';"""' · , 7._,=,7 91 7410 9i 7 1._% 7892 · :2:7 '771 ._,~". :2:7 6/. "5 8077.97 '79() O. 97 · i.71 N 15.00 W ~. 13 N d, 7.C)C) W 2.88 S 5'7.50 E 2.~( N 77.00 E 4.76 N E',2.50 W 6.28 N O. 00 W 9. .37 N !/-,_,.~a')_. W 1~.:30 N 2:3.50 W 25.02 N 2i.00 W d,:3.84 N 20.50 W 10:3.2.5 N 18.00 W 140 5'7 N tc' %" . , ..... 0 W 176.5) 1 N 1E:.50 W ,.-~ ~1:3.~:,7 N 1:3.50 W 250.'P9 N 12.50 W 287.99 N :3.50 W :314.'75 N 8.50 W · ':'51 29 N 2 ~;0 W ,'"11"'11~. . -- . · :,,:,: . '71 N 2 9;('~ E 440.5'7 N 9.00 E 46:3.Pi-' . _. ._/ N 9. ff~(") E 489.67 N 14.00 E 508.6'7 N i4.00 E 546.25 N 1'7.00 E =iF .... . - =~ . . · _:,Z 4._ N 22 (/0 E 1.70 N O. 46 W 4. ()5 N ":'....%0_. N · ../'7 N :3. 1'7 W ...":' 41 N 1.0':.). W 4.72 N 1.21 W L-,. 2(1) N '2.50 W 9.26 N :'::.4:t. W 14· 1:2: N 5· 1.8 W 24.'70 N 9·5'l W d, :'3 · i,")4 i",t :24 · (-):'~: W :LO2.00 N :'::7.64 W 1:38. '~.~ 1 N 49. '~' ,_,i W 174. ,=,._,""'"" N 6i .84 W 21t.28 N 72.~,=,""' W 248. :32 N 80.8:":: W 2:35. 10 N 87.6:5 W 311.74 N 9. 1.~=,.> '-' W ~_':48.19 N 5).5. i4 W :q 86.62 N '- = Y.J. 14 W 4:37.70 iXl 90 · 0o W /I-60. ::::4 N ::::6 · 2:3 W i-i (' q. 87.15 N ,:,.)·76 W 506.:3:':: N 75.97 W · "2;44 ":'" ~' '"' .... 0 N ,,-,._,.44 W ,.[ ":65.77 N 57.84 W, · 1..'76 N 15 ("~ 0 W 4.75 N :5:1 40 7 W 4.21 N 48 51 :3 W 2.65 N 24 24 5i W 4.87 N 14 20 4 W 6.69 N 21 59 56 W 9. :::7 N 20 i:3 2:i: W 15.05 N 20 8 46 W 26.47 N 2i :3 14 W 6'7.4'7 N 20._'=;':'.. ':.). W 108.72 N 20 15 17 W 147.5'7 N. 19 4'3:36 W 185.47 N 19 28 34 W 22:3.:30 N l:':: 55::L2 W 261.15 N i:B i 52 W 29:::,27 N 1'7 5 21 W 324.5:'3 N 16 22 4::_.: W :360.95 N i 5 16 ._.~;,_':: W 398, 16 N 13 49 29 W 446.86 N il 37 8 W 468.84 N 10 35 54 W 493.80 N 9 24 45 W 512· OO N 8 32 1 W 548.22 N 6 51 22 W · Joo.72 N 5 50 14/ 0. 124 ()..- ?] o._ 1 0. O01 0. 000 0. 050 O. i 0 l 2. 068, 4.28'7 1.76:3 0. OE: 1 0. 082 O. 162 0. 000 0.02~ 0. 005 0.019 0. 000 ' O. 086 O. i25 O. 132 0. O. 0. 083 O. 2'70 RECORD OF SURVEY ~EA'.:_; liEP'I"H 'FIG MN 829'9 :3446 ~5("~4 '.3550 8864 ? 10 9365 9546 9 7:39 00 :=: (} 222 0:368 06:30 0910 0946 DR I FT TRUVERT SUBSEA SECT I CmN DEF'TH DEF'TH E, 45 ':"-'/ 69 '-'( "-' ,_, ..' =, 1 · ,:, J,=, 4.6 6 0 8407.78 :32:30. '78 7 0 8465.41 :3288.41 7 0 ':'.~] . . ,_,._ 1 i 07 8:7:'::4 07 6 0 8629. :30 ,_-,'-' 4 '-'._, .."-'. '-'._-, '-'._, 0 ,_,""' o--:,.-,,_, ..._,. 4("~ 864/-,_. 4fl 4:3() 8947.97 :E: 770.97 4 45 9058. L-, 1 8:3:E: 1.61 ~-.~ r', - .-- .~..--o · ._, 1 'Y.3 Y'..". 6 (] 91 ' = · 4._, 60 4 45 9502 · 91 '?:325.91 4 0 ':.)/-,':) .%.:,'-' ._,'" 95._ 1 '"",:, '-' ~" · - .* -- · . n :7 15 '":'""="-' 03 9/." '"';. s ,=,..., ..' · . =, 7 ._ 0 2 45 100:35. '?8 '~.)858. '?8 :3 ('~ 101 '77.60 1 ("~"~ 00.60 :3:30 I(X32:'::.:36 i0146. ,.. . .~] (- ~-,"', · _-: t._ ii._,,:,4 91 1(]4('~'Z 9i .- 45 10864. ='''' · _, ~ 10/_-,:37..~l 2 45 109(':~0.48 1('~723.48 5:37.15 N 24. oo E 601.60 N 27.50 E 6c)7.54 N 1:::.5(') E 612.94 N :3.00 E 626.21 N 8.(1) 0 E 644.70 N 4.50 E 6,54.95 N '7.50 E d, 63.79 N 7. (1) 0 E 6:-':6. :34 N i :3..St] E 7 o 1.5:3 N 12.5c] E '7i~.E,A N i7 .%o E 724.9'7 N 1'~).(')0 E '7:3:'::. 34 N :35.50 E '7:39. :':: 1 N 26.5o E . / 46. :;"'" N 26.5o E 76('). ()1 N .-"'""",:,, .~;('~_. E 772.4'7 N :2:1. oc:) E. '77:3.92 I',1 '.':: 1.00 E DIREC'F ION RELATIVE CC[ORDiNATES FROM WELL-HEAD -- =""'= 49. · _,,:,._,. '77' N :':-:4 W 600 49' N 42 '-"= W · . /_-,11.'~.~-/ N 38.41 W fire'''~ r-, · .'._, :2:1 N 36 t, · ._1. -_~t W L-.,4:3.89 N :::4.50 W /_-,54. 18 N ::::3.42 W 663.06 N :32.2'9 W ,"-,,=,..,. 7 :'3 N 28. 18 W 701. 15 N 24./_-,:'::W ')'itl :'::7 N 2c") ""'-' W '724.79 N 1'7.71 W '7:3:3. :2:2 N 1:3. :2:2 W 7:2:9.42 N 9.66 W 746.83 N 5.?6 W '76(i.5i N 1. 16 '7'7:2:..":'":'._, N :::: .4:3 E 7'74.'71 N 9.32 C L iD :~; LI R E D i 'F; T A N C E iIG M N S 5:E:7.86 N 4 48 54 W 60 i. 'F/7 N 4 1:30 W 607.82 N 3 44:3'~ W 613. 18 N 3 35 28 W 626.:'::8 N 3 20:37 W 644.81 N :B 4 i W d, 55.04 N 2 55 2'7 W 66::: ""=' _..:,--, N 2 47 16 W 686.:36 N 2 21 II W 701.5:B N 2 0 43 W 715.67 N 1 40 2 W ......./~._.'~; 01 N i 24 0 W 7:33.44 N 1 2 26 W 7:39.49 N 0 44 53 W 746.85 N 0 27 27 W 760.51 N 0 5 15 E '77:3.28 N 0:37 29 E 774.77 N 0 41 21 E DOG LE[J d e 9 / 1 (:)0 0. (') 15 O. 51i 1.7:3? 0. :3:39 0. :B 40 O. 51:3 0.4 O0 0. 225 0. 190 O. 276 O. :3:39 0. 478 0.27:3 0. 177 O. :342 0.095 0. 179 0. O0 O' '-~ ~ 2 - 8 -83 ~EVRON 4.. B-.J I]ATA INTERF'OLA'i'ED FOR EVEN 1OO FEET OF SUB'.--;EA f'~EF']'H "E A S. . ,i{F' TH ""..'.?' '7 :::7'7 478 5'78 67:3 '77 878 '.-P '7 107' :3 1 i '7 8 ! 2'7 F: :i. :':: 78 1478 , i,~i ,'- 1._ 7c, 16'78 i 778 1:378 ]. 9"? :3 207 21. '7' 8 227'8 24'7',::', ,,,.~ ~.~ --~ .~L._ ./,---, 26 '78 :2 '7 '7,_,':' 287::: 2:: 978 :'::: 07:3 :31 '78 :'::278 :':::::78 :3478 :3578 :'::679 TRU VERT SUB SEA MD-'FVD VER-I'ICAL D E F"t'H DEF'T H D i F F. CO RIR EC:-I- 277 100 :377 200 47 '7 :700 577 400 6'77 " .... · _, (.) ~2 777 600 877 70 c) 97'7 '8c) O 10'77 900 I 17 7 10 0 0 12 77 l 100 1:377 1200 1477 1:300 ..... / / 1400 l e,'7'7 1500 ]. 7'77 1600 187 7 t '700 197 '7 1800 20'7'7 1900 '2 i '7 '7 2000 227'7 21 O0 2:3 '77 2200 24'77 2:300 ,:._ 7 7 2400 2677 2500 2 7 7 7 '26 00 2 8 7 '7 2'7 0 0 297 7 2800 :3077 2900 3177 :3000 327 7 ':' · _, 100 .:,.:, 77 3200 :3477 .... '"" - (' · :,..~C) .) · :,._ 7 7 :~ 400 ~ ._, :, 77 :3500 ., 0 0 0 0 1 1 0 1 1 1 0 1 0 1 0 1 1 o i 0 i 0 1 0 1' 0 1 1 0 i 0 1 0 : i 0 1 0 i 0 1 0 i 0 1 0 i 0 1 0 1 0 1 0 1 0 1 O 1 0 1 0 1 0 RELATIVE COORDINATES FROM WELL-HF-'AD ;EVRON 4.- B-o DATA iNTERPOLA'FED FOR EVEN 100 FEET OF SI_IB'.:;EA DEF'TH ':EAS. TRU VERT SUB SEA MD-TVD VERTICAL EF'TH DEPTH DEPTH D I FF. CORREC'I" 3780 :::8:::0 :3981 4082 4183 42:34 4385 4486 4586 4/_-,87 4788 4889 498'.:.~ 50':.70 5.'1.91 5292 5:392 549:3 5594 5695 5'795 589.6 59'~;'7 6098 6198 6299 640o /-,501 6L-,01 6702 68(")3 6'.:/04 7005 7105 7~06 3777 3877 :3977 4077 4177 42'77 43'77 44'77 4577 46T7 4777 4:_::77 4977 5077 5177 52'7'7 5 :'3 '77 ._4/7 5577 5677 5'777 5:3'7'7 59 '7 '7 607-7 6 i'77 62'77 6377 6477 6577 6677 677'7 68'77 6977 707'7 '7177 :--:600 :B 1 :37(')0 ':' .-,,.-., -) · :,,:,t . 4 1 :3'P00 5 1 40A0 6 1 4100 '7 1 4200 8 i 4:300 9 1 4400 9 ("~ 4.500 10 1 460 (] 11 1 4'700. 1 ~":' 1 4800 ]. 2 0 4900 1:3 1 5 0 o o i 4 i 5100 i 5 1 5200 . 15 0 ~..,.,~ · _ .... :, 00 16 5400 17 1 5F;i ')C) 1 ':' 1 5600 18 0 5700 19 1 5 8 0 0 2 0 1 5'P 00 21 1 6000 21 0 61 o0.. '-"-'az 1 6200 2:3 1 6:300 24 1 6400 24 0 :,.-'(-)(.) ~--' 1 6600 26 1 6700 27 1 6800 28 ~-,_ 9. 00 ~'":' '-',:, 0 7000 29 1 RELATIVE COORDINATES FROM WELL-HEAD 40.43 N 15.51 W ""r-, o,~, N 20 26 W ._zm .. m.! = . z-= 68 N '-'= o2 W _ ._! · ..' ._! · 78·5:7 N 29·62 N ':>1 .... OA N '-"- . '.:.> 9:, ..:: W 10:3..% =' - "· .... . i',l :,ad t4 t,4 11.5·89 N 42. lA W 12'7.94 N 4/.:,. 16 W i:'i:9.72: N 50.08 W 1.51. :36 N .~i:'::. 98W 16:"::.00 N 57.87 W 174./-'=i_.._N 61.77 W 186.:7::4 N 65.50 W 19:E:, 14 N 6:5:.91 W 210.05: N 71.9::J W 221.97 N 74.:'::2 W ...:,..:,.-.., ?~ ::..: · -._ ..... N 77,59 W 245.91 i',1 :5:(~. :-.-:c) W ..% v- ..... ..' .J 7. ':.~:Z N 82, 8'7 W 269,9. :~. N ,:,'""._, '~' · i '7 W 2:i:2. (")9 N ::'::'7. 19W 294. ":":'..._, iN 8'P, Oi W :l:(") 6. :3'7 N 90,8:5: W ":'1:5:._, . -~](')_. N 92. ,5:AW :'"::30 '-'= o'-, 9:3 · .~,.~, N .'..-',. W · _,4 ...':' ' '-'. 49 N 94 . ,:,._,'"' ~= W '"" ~'" :.'/.-I ,, W ..:,._,4,4A N '"'=' :3'7 · '"', . · ._ ._ c, 66, 68 N 95 .=,5 W '-,'" ," , , .z, :.2 · :, 7 Y._,":"-:',.., N 95 '-"- W :2:92,44 N 94,85 W 4A5 .... 'l . . ...,:,:, N 95:94 W m'" """ m 418 03 N ';".." :.Y W 430.45 N 91. 10 W 442 65 N '-" ..... · ,:,~. :zl W ~-' · I"~l m""l m 4._,4 .-.,-. N :2:7 20 W · EVRON 42B-5 2-:3-8:3 DATA INTERF'OLATE]-I F'OR EVEN 100 FEET AF SUBSEA DEF'TH EAS, TRU VERT '.E;UB F:EA MD-TVD VERTICAL ~- P'i- H D E F' T H D E F' T H D i F F, C 0 R R E C T 7307 7277 7100 '740:3 7:377 720 (:) '7509 7477 7:30 0 '76 ! 0 7577 7400 7710 7 e,'77 7500 78 t ~ 7777 7600 '79 t 2 '787 '7 '7700 :30 i :3 '79 '7 '7 78 00 ',3114 ',B 077 '7900 ',E: 214 8 t 7'7 8000 8:315 827'7 ' 8100 8416 8:3'77 8200 :3516 84'77 :3:300 861 '7 8577 8400 :3'71 '7 8 ~, '77 8500 :38 i :3 877'7 :3600 89 i 8 :38 '7 '7 8'700 90 i 9 :3 977 8800 9 :!. 1 ? 90'77 :3900 :~ :,::: :!. 9 9 i 7 '7 900 (3 9:320 927' '7 9 i 00 94 i: 0 9:3 '77 9200 '? 5 2 0 94'77 '? :300 '5:' 62 i 95'7 '7 9400 9 7'21 96'7'7 9 500 98 2 ]. '? 777 9600 99:22 98'7'7 9700 0022 '? 977 '? 800 01 "':" ') .... ~ ~ t 00'77 99 (') 0 0222 10177 i 0000 0:322 ! 02'7'7 10100 04'22 i 03'77 i 0200 0522 104'77 10300 0623 10577 10400 072:3 10677 10500 ( :'-:,'II :31 :':-:2 'T~ "2, :3:3 :2:4 :'::6_, :37 :'::8 :':: 9 '39 40 40 4i 4 i 42. 42 42 4 ":' 4:3 4:2: 44 44 44 45 45 45 45 45 45 46 46 RELAT I VE COORD i NAt"ES FROM WELL-HEAD 467, 49 N 47'.:], '~.)5 N 492 · 34 504, '74 N 51'7,6:-:: · 5:30. 1 ::: N 542, 4:':: 554· :36 N ._,~.: ..... 6'7 57,'i,. 60 N · _,:,7 4:2: N =;':} 7. ....... / N L-., 1 '.:;. 67 N ~,:'::?. 75 N 648.46 656.47 N 6.64.5',3 N 6'7:3. ('~2 N 6:::1.'73 N 69,:"~. 57 1'4 '706.95 N '?'t4. 1:':: '72('~ =;':' N '72,'i:, · ]. 1 N 7:3o. 90 1'4 '734. Sh-3 N 7:39.39 N 744. '""~' · -,._, N 749.74 1'4 755· 02 N 760.12 N '764.9'7 N 81f.;, 05 W '"":' 47 W ~,_, .., ~ '7'}:'. 4/:, W '7 6, :72 W '7:3. (:)7 ~ 6'?" /-":' W ,'i,~:,. (':'2 W ~,2. i5 W · _ 7 ::'::8 W ff]'":' :'q5 W ,_ ....~ · 4:'::. ,'i. 1 W 4:2: ' '"' .7._, W '::9. i.-"'7 W :37 ":'":' W -'"~ · .: ..... 89 W 34. :B5 W · '~:4.09 W F:3. 1 "7,'W 30.8i W 2'9.10 W 27.04 W 25. l~'l W 23.24 W 21,'"'.."1 W i9. 15 W 17. ,"c.'""' W 14. '"' ~-'' ? u:.. W 12. 19 W 9.67 W 7. · .~.) W 4.._, J W 1.7'7 W (). 9""' :3, 62 E ff_VRON 42B-5 DATA INTERPOLATED FOR EVEN 10(] FEET OF SUBSEA DEF'TH '£A'.::;. TRIJ VERT '.E;UB SEA MD-TVD VERTiI]:AL £F'TH DEPTH DEPTH l"l IFF. CORRECT i 082:3 :i. ~])?'2:3 10777 i 06 ('-~ 0 46 0 1 t-):--: 77 107 ~])0 46 0 RELA'[ I VE F:F-~ORD i NATES FROM WELL-HEAD 7/_-9.5i N 6.22 E '77:3.7.5 N ,_,'='. '74 E ~EVRON 42B-5 DATA ZNTERF'FILATED FOR EVEN t¢)0¢~ FEET OF MEASURED DEPTH MEA'.-i;. TRU VERT SUB SEA BEF'T H 1"~ E F' T H f]EP TH . - i_1 ,- ._~ 20~'~c~ 2~-~("~0 182 :':: :3 ~'~ (:i 0 :':: 00 (':~ 282:3 500 (1) 4988 481 ]. /_-, 000 =' - '" ="-:'" · _, .-:.~ ,:, 7 00 ~-~ 6 '9 '7:2: 6 / 9/_-, ',3 (')00 "'"" / .-.* 9 0 (:~ 0 8 9 5, 9 8 7 8 2 100 tR E L A T I VEf': OFIR D I iN A ]' E S FROM WELL-HEAf'~ · ..'-" 64 N 0.81:: W 2.24 N ._,'--'. 04 W 5. ('17 N .-..-':: .... 'i W 68.09 N 25.91 W · /' =' 187 6:':: N z,._,. W :':', 0 6. ',:30 i'4 9 (-). 89 W 427.7.'74 N 91. i7 W "'"""" '?4 /2,2 64 W ._1 ._1 ." · N · ~"-'1r''' · . · /_- ..... , ¢~4 N :3:3:3('i W 729.9 5 ~".1 1 ._";. 45 W : '." HORIZONTAL CHEVRON U.S.A. . "'-. CHEVRON 42B-5 ' : RADIUS'QF; CURVATURE SINGLE, SHOT. SURVEY · i SCALE. ;1','= 200' .FEB. 9, 1983 VIEW -, 0,800 I 0,000' 9600 9200' 8800 8400 7200 6800 6400 6000 5600 5200 4800 4400 4000 3,600 i · Ii·. · i . .I, . i,.,..'* -~-i ..... i ''' '' ' ; ...... o; ......... , , , . , , . . · !"r:. . , . · , ~!,. ~ ; ~ " I , ' '.[ ' i '.i .. · ~ ....... :_.1 ...... 'i ..... : .. 'ii|iii ~1 .;-~ ..' 'i": i.~ i..! . :.-~ ..... · .i . , ' . i · . i · , . ..... , . ; ..... .i ,, , i . . ._ . . . .'.'-:..-i ~ .... '-~':' ' , ....... · i i.' .':~ _' ..... 1 '~ .. ~ .... ' } ...... : J-..'i . . .SCALE:-~S--~HoWN-J i-.i-' _ ! ' ! ....... ' .......... ' ...... ...... . .... !. i . · -~ DECEMBER - J - -' ; -' '' ~ I ~ .~ : .......... ...... L'.-__i_ ! ....... ' ...... ~._:: _'_ ::_BESSE.,L. EppS:i.~---POT-TS--.:- ...... :L_~ _._: ....... I ....... ' .... : ........ !-Li-~--!-: ...... "--:-~-- '", .... :'. .-;'-t:']-- I ',-':,-':'." ' ' "'"' '" LING .- ...... · : '--' ~ ' ' GREA!T-LAND-DIR-E~IONALDRIL .,. !_. ........... . , t : . ........ . . , . : i ...... - ' [ ..... ' .... ; :' '- ' ' J '~ t .. !- 'J .... :. . . . i :... 5oo.':i!, .,:o, i--: I ...... .... ~. . -_! ...... . i I : .... ! ...... .... ?_ '.:-;:. ;-: ....... ,~ ..... , ........... ........................... ...... 600 TARGET, . .- _ % SURFACE'., , , · _L ..... ~. - ~-- ....... I_. , .i''; ~.' : '" ........ .... ..... · '~% '. :.. !._, .. ~ - .., ' ' ' '' . · .T.7 N','R'9 W'.! ;-~ .SM .- . : t ; ,. _, j.. .. , '-'."_; -" .~-'i;.. . ~ .... . ~ . , . . .L.-'.!_ ~.i'. ..... 500 ................ - ...... .. . · . i ._! ...... ~.,.:-- ' -- ................................... 1 ........ ~-- ...... 0 ..... . .,. _.t_._... : .... ~p ..... ~\. - ........ .... ~ ' , ........ 5000' . - - 6000' _ . ;_ _. ............. 7000- _. . _ . . . ..... 8000 · + ~3 -~ ~ ...... · ..... ! .... , . ! . ,.~ ..... . . . ....................... ; .. ~.., ........... : ROP"TVD---61OO'iTMD=6100 - . ....... - . ' '" 3°._ - DEP: 0 ............ I ' -' ' ..... " ' ..... : ..... i : .- ' _- ... I 's° .... BUILD' iV2° PER IO0'i .... i " - .... · s~ .~ -~, O i ~ ~ ..... t2o ~ ......... ; .... : - .. . ._EOC.. .T-VD =.6960 TMD_= 696'7J DEP=_98 ...................... - ............ :_~ ....i ' :" ' I "- ";. .... _ . t.. ' '~ 9 ::'' .... , - ~,'"'~r': : '. -i , · ~, . .: ...... ..: ._~L' ._'i_:.7 8000 .......... ; , .... ...... ~'C:' " ................. ' ............ :-' : .......... : . .-:-',. ;_:.,- !V£D -. .:-: '\- · .'~_AVERAGE .ANGLE_'IS-?O0_,'~. i ,. .-~U~O.!~. i-. 'SCALE· "'-500'! - ' '" \' ' - .... : '" ':-~: ? .... ~s~Oi~ ~, ..... ~:'~'°~ "-i '." ~ ".~' . ~, ':' .. -": ::'::---' · ,\. ~ .' · . ! ..... .. ". ',.; . ._ .,,¢. ~as Con'J,~.. '~:,, __:':: ." ' '... ." ' ' . '.i - ~ .'"i ~ -"' ..... ' ~t~or,~ T~,,m~.~,. · : . . . ,. .... ¥9ooo- - : .... '',.- ~9~ :-,o.0 .! i_:: .' _' .....; ....... :-.-' .... ........ ;% ...... ..,r ......... ' ................................. F "T .............. , ~ +~-~--' - ........ : ....... ii':.- .':' ',... -i. ' ~.' .i'. _. t TVD=9267 TMD:9$$5'.~'DEP_=6$1 : .... '... : .--' ....... 40oo .. _. . . _ . .......... 9000 __ . . io,ooo DROP .I° PER I00' . ~ ' ; : ; .... i : ;,o H-8 :' ................. : ............ '' TARGET ('EOC) ;TVO'=lO~556i .TMD='IO, 655"DEP~-;.?.77 : "; ...... ' ' ' ........ ' ' · ' ~ ' I ' ~ ! "-~ ' i0~900 ...... TMD=.IO~9.Tg/DEP'='?7:7 ........ .... ';-- --- --i "-.' .TD TVD= ' ' }' ' ~ :/--.-'!-'T-'J[ ~ I' ' --'".... - T .... ''~, '; ...... : ..... "',-" !'i."iCli , ' L ........ I I ~000 I l -o' I0OO - - .... ' ' ..... ' ........... ;;, ', ; iJ ~ : ...... i--~'i.-!-~'-!'!'-:'i i- ' : ' ; ......... i .... ~ '~ ' , r : : ................ !.__ ;_: ._ -' .! i ' . ; I ., ' " ' ..... . . , , - . : ' 1 . ~ ....... i-: - . ., i : ~ : , , , ." BOC I0°. 4°. . .. ..... I000 i_.1 - J.-LI t ' ' '" · : ~. .!, J ~..J ....i L.~-~.L-I-~-I--~ ...... l--I .i_LL-J '' l iii] 11/I .il.lB i,', iVERT, ICA,'£- ' ' ' I ~_ ,. , . _~ ! ! i~ .' ' ; ~ '.~-i. , . I l ~,-L ii!'!;:', 4-400 I-I , I/i:;I I-, ONEVRON' 42B- $i i.' 'i ~ i'~ ~/- 'i , it! -t i--t- ,l~ i ' I I ,I./1~*.; ~ , I I i , ,i,, I..L.,4.i ~60o'', -~'. , ;i'l.'l , '; .... , I ; ; . i I ' ,- ~: i ~ .: ' ~ ;''~ ~~"11 ~ ~: :. i,., , .i,, ~ ~ ~ i' ~ll .i ,, i~ "· ~.~_~_~_l.~ _.~.., ...... i : .... ~-~-~ ,. :~ .... - - -'' ., I:' ' t I ~i :, D HOWN 5soo, ~ I , .. , i , ARET.VD 6000 ' -. -[ ~ : = _l. ',_ . I ' [ : ; ' I I : ~ I , ~ , . i 'i Su6gested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator', well Nan~ and Number '-.. Reports and Materials to be received by: ~--Z Date R.equired Date Received Remarks -- Cc~np letion Report .... ~_ ~- l .~:" ,, · Registered ~ey Plat .InclinationS~ey i / . Drill St~ Test Re~s ~s R~. Yes ... TFQ\NSHITTAL AND ACKNO~EDGEPUJNT OF ]IECEIPT OF }t~TERBkL - (ALASKA) , o.. COMPANY . .. . 'WELL .... RUNS .. · . . · J [r 'THE' FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. CHECK AND ADVISE I~fE. DIATELY. · - .. .- INDUCTION ELECTRICAL LOG DUAL INDUCTION LATEROLOG BOREIIOLE CO~fl?ENSATED SONIC BOREIlOLE COI'~. SONIC w/caliper BOREItOLE CO~. SONIC w/gamraa BOREHOLE TELEVIEW:ER CONTINUOUS DIPI.~TER- High Res. CD}I- POLI%qOG PLOT CE,X~NT BOND LOG ~-;rSiNG C~LLAR LO~ - Perf. Rec. ¢O~?ENSATED FOP&rATION DEN. CO~-2ENSATED NEUTRON FOPC. D%TION ANALYSIS LOG FOP~£~TION DENSITY LOG F F FOPd.[~TI ON TESTER FOP~XhkTION FACTOR F F G32-~[A RAY -' GA~[~ RAY - NEUTRON GA>PtA RAY COLLAR LOG MI CRO- LOG - MI CROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY MICROLOG RWA CO,~ARISON PLOT SANDSTONE ANALYSIS ' SARABAND SIDEWALL NEUTRON POROSITY SO!,'IC TE~iPERATU KE LOG 2." 5" i_ PLEASE SEPIA BLUELINE CO:'LPLETION I~EI'Ol('r DIKECTIO:;AL SURVEY - SA~IB,E;D TABULAR1 --LISTING / I00 200 TRANSMITTAL ;'~'~ ACKNO~fLEDGEMENT OF RECEIPT OF~",,~TERI,AL -' (AL;~KA) ~TO: .DEPT.: PLACE: DATE THE FOLLOWING IS A LIST.'OF MATERIAL ENCLOSED HEREIN. FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. RECEIVED ~J~tEMARKS ON 'oTHER Si~E, THIS SHE'ET. CHEVRON U. SA. INC. BOX 7-839 ANCHORAGE, ALASKA 99510 STATE OF ALASKA ALASKA L~,L AND GAS CONSERVATION CO,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL:~ 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 82-199 3. Address 8. APl Number P. O. Box 107839, Anchorage, AK 99510 50-133-20363 4. Location of Well 1823' N & 572' W from the S.E. Cur., Sec. 5, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 25' K.B. I 6. Lease Designation and Serial No. A-028996 12. 9, Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 42B-5 11. Field and Pool Swanson River - Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] - Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On May 10 - 11, 1983, the following procedure was performed on well SCU 42B-5: 1) Shut in well. Pressure tested lubricator to 4000 psi. Obtained a 20 hr. bottom hole pressure build-up. 2) Perforated the H-8 intervals 10,614' - 10,632', 10,638' - 10,652', 10,658' - 10,666' . and'10,672' - 10,686' with 4 JHPF and 0© phasing. 3) Returned well to production from all zones. 14. I hereby cerj~jfy that~the fore{~i7 is true and correct to the best of my knowledge. Signed~-~- ~- Title Area ~,,ngineer The space below for Commission use Date ! Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL STATE OF ALASKA AND GAS CONSERVATION COMMISSION 3001 Porcupine-' Drive Anchorage, Alaska 99501 (907) 279-1433 which was transmitted via is hereby acknowledged: QUANT I TY CcV- e DESCRI PT ION - MAR - 8 !983 DATED: ~aska 0il & Gas Cons. Commissior~ An%Ora~ Copy sent YES ~ to sender NO __ SCU 4.2A-§ EXIST. WELL EXIST. 'WELL ~...~_~..~o). SCU CENTER CASING 572'~ UTM COORDINATES: N 22, 092, :305.8 E 2, 019, 120.5 NOTES; THIS SURVEY IS 'BASED ON EXISTING 'WELLS SCU 42A-5 AND SCU 4:3-5 (1:3-4) AS DETERMINED BY PREVIOUS SURVEYS AND THE PROTRACTED COORDINATES FOR THE S.E. CORNER OF SECTION 5, T. 5N., R. gw.~ S.M., ALASKA. TOP OF GRAVEL PAD ELEVATION IS 152.0 FT. SCALE: I": I00' (PROTRACTED} S.E. C OR. "'"~..,~ SEC. 5 WELL SURFACE LOCATION SURVEY -WE.L L NO: SCU 42B-5 SURVEYED FOR: CHEVRON U.S.A. INC. OPERATOR SURVEYED BY: McLANE AND ASSOCIATES, INC. SURFACE LOCATION: 1823 FEET NORTH AND 572 FEET WEST FROM THE S.E. CORNER OF PROTRACTED SECTION 5, T. 7 N., R.gVt., S.M., ALASKA. DATE: NOV. 30, 1982 SCALE: I" = IOOFT. SOU 4ZA-5 EXIST. WELL EXIST. 'WELL-r--,,.~~' SCU _ e, ~ 42B-5 NEW WELL 20" CENTER CASING 572' "- UTM COORDINATES: N 22, 092, 305.8 E 2, 019, 120.5 NOTES: THIS SURVEY IS BASED ON EXISTING 'WELLS SCU 42A-5 AND SOU 43-5 (13-4) AS DETERMINED BY PREVIOUS SURVEYS AND THE PROTRACTED COORDINATES FOR THE S.E. CORNER OF SECTION 5, T. 5N., R. gw., S.M.~ ALASKA. TOP OF GRAVEL PAl::) ELEVATION IS 152.0 FT. SCALE: I"= I00' WELL SURFACE LOCATION SURVEY 'WELL NO: SCU 42. B-5 SURVEYED FOR: ' CHEVRON U.S.A. INC. OPERATOR SURVEYED BY.' McLANE AND ASSOCIATES~ INC. SURFACE LOCATION' 182:~ FEET NORTH AND 572 FEET WEST FROM THE S.E. CORNER OF PROTRACTED SECTION 5, T. TN., R.gW., S.M., ALASKA. DATE' NOV. 30, 1982 SCALE' ~"= (PROTRACTED} S,E. C OR. ~...,,~ SEC. 5 TRANSMITTAL AND ACKNO~EDGE~UZNT OF RECEIPT OF ~[ATERI~kL - (ALAS~\) · C0b[PANY · ~LI. INDUCTION ELECTRICAL LOG DUAL INDUCTION L-~-T-F~q~t~g~ ~f=l_ BoREHOLE CO}~ENSATED SONIC BOREHOLE CO~,~. SONIC w/caliper BOREIIOLE CO~. SONIC w/gamma BOREttOLE TELEVIEWER - CONTINUOUS DIPI'~TER- H{gh CD,H- POLYWOG PLOT CEMENT BONUO LOG / VDL./~/C~'t._- CASING COLLAR LOG - Perf. Rec. COHPENSATED FOP~i4TION DEN. CO}'~°ENSATED NEUTRON FOP~DtTION ANALYSIS LOG FOR}LiTION DENSITY LOG F F FOR2.LATION TESTER FOP~XbkTION FACTOR F F GA~.~LA RAY .- GAb~t4 RAY - NEUTRON GA~'-RCA RAY COLLAR LOG - MICRO-LOG "' MI CROLATEROLOG MUD LOG --- -- ' . RWA CO~ARISON PLOT S~NDSTONE ~ALYS IS SIDEWALL NEUTRON POROSITY TE~E~TUD~ LOG CO?~I.ETION DI~CTIOUAL SURVEY CORE DATA Received and. checked by: PLEASE 7. ! t / / / / / BLUELINE _l / '/, / / I · /_ Alaska 0i~ & Gas Cons. uommi~Jo'~, . .. Anchorage ., .... .-.- Chevron Chcvron USA. Inc. '--'"P.O. Box 7-839, Anchoro;9, AY-, TRANSMITTED T~IE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HER£IN. PLEASE CIIECK AND ADVISE I}2-~--'nIA'. .... . ~, RECEIYED AND BY ..... ,.,,.i 9 p-,o Rnno r'.,]mmig.~ir)n I · II I Date 19 ~ TI~ A Iq~ ~ . STATE OF ALASKA ALASKA . AND GAS CONSERVATION CL.,..,vllSSION -~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION.. 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 82-199 ~.~ -- 8. APl Numbe~- 99510 50- 133-20363 P.O. Box 7-839, Anchorage, Alaska 4. Location of Well at surface approx. 1800' N & 650' W from the S.E. Cor., Section 5, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 168' K.B.I A-028996 9. Unit or Lease Name Soldotna Creek 10. WellNo. SCU 42B-5 11. FieldandPool Swanson River-Hemlock For the Month of January ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Abandoned 9 7/8" hole as follows: laid a 350 C.F. Class "G" cement plug through open ended drill pipe at 3500'. Pulled D.P. to 3288' and Bradenhead squeezed with 100 C.F. mud. Polished off plug to 3444' and drilled to 10,433'. Ran DIL, FDC-CNL 10,433'-3395'. Drilled 9 7/8" hole to 10,505'. 13. Casing or liner run and q-uantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run FDC-CNL, DIL - 10,433'-3395' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED FEB ] Alaska 0il & Gas Cons. O0mmissi, Anch0rag0 SIGNED ",/, ~' '~"'--;~/~,/.~/lL~.':/:3~"~7-- TITLE Area Operations Supt. DATE ~'/'.~//~ NOTE--Re~-~rt on this form is r/~uired l~r each calendar month, regardless of the status of operations, and must be/ filed in duplicate with the Alaska Oil and Gas Conservation Comrr~sion by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate STATE OF ALASKA ALASKA ~.,- AND GAS CONSERVATION CO,.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ~;] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron USA Inc. 82-199 3. Address 8. APl Number P.O. Box 7-839, Anchorage, AK 99510 50- 133-20363 9. Unit or Lease Name Soldotna Creek 4. Location of Well Approx. 1800'N & 650'W from the SE Cor., Sec. 5,T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 168' KB 6. Lease Designation and Serial No. A-028996 10. Well Number SCU 42B-5 12. OTHER [] 11. Field and Pool Swanson River-Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any / proposed .work, for Abandonment see 20 AAC 25.105-170). Stuck drill pipe while drilling 9 7/8" hole at 7874'. Ran free point survey and~ found pipe stuck at 3405'. Backed off at 3380'. Washed over D.P. and recovered to 3497'. Abandoned 9 7/8" hole from 7874' to 34/~/~' per following: Laid a 350 c.f. ci "G" densified cemmnted plug through open ended drill pipe at 3500'. Pulled drill pipe to 3288' and bradenhead squeezed with 100 c.f. mud. Tagged hard cement at 3397'. pOlished off plug to 3/~4/~' and kicked off for sidetrack. Verbal approval Blair Wondzell 12/30/82. ,.!AN ]. o ]983 Alaska Oil & Gas Cu,-~,~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space Below for Commission use Conditions of Approval, if any: By Order of COMMISSIONER the Commission Date Approved by Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 ¢'. '-'-' STATE OF ALASKA ALASKf J,L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL ~i~g COMPLETED WELL [] OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 7-839, Anchorage, AK 99510 4. Location of Well Approx. 1800' N & 650' W from the S.E. Cor., Sec. 5, T7N, R9W, S.M. . 5. Elevation in feet (indicate KB, DF, etc.) 168' K.B. 6. Lease Designation and Serial No. A-028996 7. Permit No. 82-199 8. APl Number so- 133-20363 9, Unit or Lease Name Soldotna Creek 10. Well Number SCU 42B-5 11. Field and Pool Swanson River-Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing I-'J Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 With a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to change the bottom hole location of Well SCU 42B-5, Swanson River Field as follows- From: Approx. 2400' N & 650' W from the S.E. Cor., Sec. 5, T7N, R9W, S.M. To- Approx. 2600' N & 600' W from the S.E. Cor., Sec. 5, T7N, R9W, S.M. DEC 0 ? ' .,.uSZ Alaska Oil & Gas Oons. c;ommiss~ Anoh0rag~ 14. I hereby certify t~at the foregoing is true and correct to the best of my knowledge. Signed / "- '~- ~/~ Title A~ea ~ngineer The space below for Commission use Date 12/6/82 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 Approved Copy Retumed / By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate [h~vron .,HEVRON U.S.A. If,,.... T?~.'..:;S;-I!TTAL AND AC:<:;O;~LEDGE.'.:E.';T OF RECEIPT OF MATERIAL - (AL,YSKA) -: FD - Folded R - Rolled S ':' Sepia F - Film X'- Xerox B - Blueline FOLLOWING IS A LEST OF MATERIAL ENCLOSED H£R£IN. PLEASE CHECK A~D ADVISE I}D~_~IATELY. .. 4~ -¥2: .., RECEIVED BY BY_ SCU 42A-§ EXIST. WELL 5CU EXIST. WELL SCU 3', --~T- 42B-5 NEW WELL CENTER 20" CASING 572' UTM COORDINATES: N 22, 092, :305.8 E 2, 019, 120.5 NOTES: THIS SURVEY IS BASED ON EXISTING 'WELLS SCU 42A-5 AND SCU 43-5 (15-4) AS DETERMINED BY PREVIOUS SURVEYS AND THE PROTRACTED COORDINATES FOR THE S.E. CORNER OF SECTION 5, T. S N.~ R. 9W., S.M.~ ALASKA. TOP OF GRAVEL PAD ELEVATION IS 152.0 FT. SCALE: I"= I00' WELL SURFACE LOCATION SURVEY WELL NO: S C U 42 B- 5 SURVEYED FOR.' CHEVRON U.S. A. INC. OPERATOR SURVEYED BY: McLANE AND ASSOCIATES~ INC. SURFACE LOCATION: 1823 FEET NORTH AND 572 FEET WEST FROM THE S.E. CORNER OF PROTRACTED SECTION 5, T. TN., R.gW., S.M.~ ALASKA. DATE: NOV. 30, 1982 SCALE: I" = I00 FT. (PROTRACTED) S.E. COR. ----.~ SEC. 5 "~ ,.~= COR: ,SEC. Y3'5' /:5'D x .~0. ~c.4 ~_ W 1 ~./00 ' I Novem~r 30, 1982 Er. T. L. Perr~an Area Operations Superintendent Chevron U.S.A. Inc. P o. Box 7-~-~9 Anchorage, Alaska 99510 Soldotna Creek Unit SCU 42B-5 chevron U.S.A. Inc. Pe~it No. our Loc 1800'N, 650'N Er S cr Sec 5, U/7N, m-~ R9W, S~3 Btmbole Loc. 2400'N, 650'W fr SE cr Sec. 5, ~,~, . Dear Nr. Perryman: .....~.~:~.~_~.~A~ is the aDproved application for permit to dri~].~ the a boy, re ~ ~- . =~_ ence.~ well If corin~ is conducted., a one cubic inch chip from each foot of recovered core is req~aired. S~nples of well cuttings and a log are ~ ~ ' ~ ~o~ .~ec~_r~.~~. ~ . A continuous directional survey is re~ired as per 20 I~AC 25.050(b)(5). if available, a tape containing the digitized log information shall be submitted cn all lc<is for copying except experimental lc~js, velocit},~ surveys an~ .~ip~.~eter. ~urveys. Many rivers i.~ Alazka and their drainage systems have been classified as important for the spawning or migration of anadromous fish· Operations in ti~ese areas are subject to AS 16.05.870 and the regulations promulgated, thereunder '-~ ~~ive Code) Prior to commencin~ (~e~ 5, Alaska operations you may be contacted by the ffabitat Coordinator's Office, De?sr~ent of Pollution of any' waters oi the State is prohibited by AS 46, Chapter 3, Artici~ 7 - -~ ~ .. .. ~nu ~%e regulations ~romul~ated ~ ~'. (Title a"R.~, Alaska A<~J~inistrative C~e,. ~ Chapter. 70) and Federal ~ater Pollution Control Act, as amended. ;.~rior to co~m~encing operations you ~ay L~ contact,(] by a representative o~ eh~ pe~ar~n~ serva tion ...... ~ .....t of Environnenta! ~ ~0~1 ..... TO aid us x.~ sch~ulin~3 field work, please notify this office 24 hours przo~ to cc~n~encin~ installation of the blowout Mr. T. L. Perryma~ . Sold°tna Creek Unit SCU 42B-5 -2- November 30, 1982 preventiOn equipment so that a representativ~ of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required~, please also notify this office 24 hours prior to c~mencing ecfdipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wit_ness present. Very truiy~yours, / //? k ./ /.,- C. V. ~tertOn ' Chai~an of SV O~D~ O~ 7~4~ Alaska Oil ~d Gas Conservation "~ommission Enclosure cc: Depar~ent of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Kenai National Wildlife Refuge w/o encl. cvc' Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, Al< 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department November 29, 1982 PERMIT TO DRILL NEW WELL SCU b,2B-5 - SWANSON RIVER FIELD Mr. C. V. Chatterton Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Per the verbal request of Mr. Jim Trimble attached is a plat map showing the courses of proposed well SCU 42B-5 and nearby existing wells. The vertical depths are marked at the points where the course of SCU 42B-5 crosses SCU 33-5. Chevron U.S.A. Inc. acknowledges the close proximity of SCU b~2B-5 and SCU 33-5 above 8,b,00' vertical depth. In order to assure the safe drilling of SCU ~t2B-5 directional single shots wjl!_..~be taken as necessary for directional control but not exceeding 100' intervals'~elo~i-kick-off at + 7,000 feet. If necessary, the course of SCU ~2B-5 will be adjusted to assure safe ~illing past SCU 33-5. Very truly yours, T.L. Perryman :RLT:sj Attachment Gas Cans. commission Anchorage t., . - .~'-::.~: .-'~-::_-~'~ --- "-L. : '--- ..... ':- :' - -- - '. ", _---.~.?-.'* ; '~._-- . : ............. . ...- : . . _ - . -~,,- ';;. ." . '~:G~ -~' '-':'" '~of the~0~42B-5~}~l 1: in-the Swanson River'Field. .L.',~;.~':?w;.~_'.*--"~*'j') ---;'Lc_;;'?_, - .' .... ' _ :.; - - ~"-; C' - ';. .- :?' '-~:~'~" _'}'~?."~irea Operat ions Superintendent_' ::}-. ' . ..... -...~:'.::~:-,'-'"-[:--JAn application, dated November 23, 1982, requested approval to drill -the-SCSI 42~-5 well,'~ich ~ould be the third completion in the SE i 'Section 5, TTN, B9W, SM. It Jo'-stated that. the ~-dri'llinc'and completion of the well should result in an ... /.[_.7-'/.'-j'..--~.,'additional'~00,000.barrels of recoverable reserves to the ''~- ~.. : ~ ..' ' ~wanson River';Field,-..-... ~,.. .;_ j-.;.~;').?~:X-':.';.-The alaska Oil and ~a~ Conse~vation C~tssion hereby authorizes '**~";:.~?~' '.;~%-'d~tllin~ and c~plotion o~ ~he S~ 42B-~ .well pursuant ~o ~ul~ ~ Chevron Chevron U.SA. Inc. /'- P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department November 23, 1982 SCU/.I.2B-5 - SWANSON RIVER FIELD Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 i--- t' O.?. ;v'W'" ....... i-, ..~ R-':*7, ' ~"' --.: ~, FILF: __ Dear Mr. Chatterton: Chevron U.S.A. Inc. submitted an application for Permit To Drill new well No. SCU Z~2B-5 dated November 19, 1982. The well would be the third Hemlock completion in the southeast quarter of Federal Lease No. A-028996, Section 5, T7N/RgW, S.M.B.& M. Current Swanson River Field Rules allow up to two completion per quarter section. Chevron U.S.A. Inc., as operator of the Swanson River Field, hereby requests a waiver of regulation 20 AAC 25.055 to permit the drilling of the subject well. Ownership percentages of all leases in the Swanson River Field area are as follows: Chevron U.S.A. Inc. - z~8.z~86Lt % ARCO Alaska, Inc. - z~8./t86b, % Union Oil Company of Calif. - 1.5136 % Marathon Oil Company - 1.5135 % No other operators or owners would be affected with the exception of Cook Inlet Region, Inc., owners of the mineral rights to the northwest quarter corner of Section 5, T7N/RgW, S.M.B.& M. The subject well offsets the lease line by more than 500 feet and there is no hyrdocarbon production in that northwest corner, Section 5, T7N/RgW S.M.B.& M. (see attached plat). SCU Zt2B-5 has been proposed as an H8 completion. There are currently no H8 completions on the west flank of the C-D Fault Block. Approval of above waiver and Permit To Drill SCU 42B-5 should result in an additional 700,000 barrels of recoverable reserves to the Swanson River Field. :MKR:sj Attachment Very truly yours, ~ .. /,/ T.L. Perryman Area Operations Superintendent RECEIVED NOV 2 4 1982 Alaska 0il & Gas Cons. (;0mmissi0n Anchorage Alaska Oil & Gas Conservation Commission November 23, 1982 Page Two CC: Mr. K. V. Zerda Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Mr. Do Eo Andrews ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Mr. A. Mechler, Jr. Marathon Oil Company P. O. Box 2380 Anchorage, Alaska 99510 Cook Inlet Region, Inc. Land Department 2525 C Street Anchorage, Alaska 99503 RECEIVED NOV 2 Alaskr~ Oil & Gas Corm. Commission Anchorage L Ohio Oil CO. ~ Ohio Oil CO' (H.H. West): (H.H.West) A-O?_3907 ~, A-O28076 8~ .. Union DJ! Co. : (Doris L. Ervin)., ,A-O28132 j Arco 1/2 - Chevron ~-028399 .-- ........ /-~- A~'co'l/2 - Chevron 1/2~i ._ 1-028396 ~nq 0,1 Co E,7 5 % J ROCo-S.O Co 18 75°/° I I C. I. R. INC. · :__ Arco 1/2 Chevron (Fred W Aiford) 1-028996 - 4 .- -~S4 r- ............. ; e i Z4~ 43 Ohio Oil Co. (Russell R. Simonson) A-O28077 ; i I .... ........ · ! . ! · I r--~-28 e ---!--:,-//-:;:- ? ...... /t .... ]__: Arco 1/2 - Chevron 1/2 A-028405 " Arco 1/2 - Chevron' 1/2 A-028403 3,12 ?iZlZ .- : ..- [ 4 47,-.. i ! ..-- ... · Arc! ! , i i !lYF CI H'~IT I ! ! ! · ! Arco 1/2 - Chevron 1/2 : TIBN~R 9W // 1/2 - Chevron 1/2 i, 1-028406 Arco 1/2 - Chevron (Fred W. Axtord) A'028990 Arco 1/2 - Chevron 1/2 {Fred W A~ford) j I A-028982 II jArco 112 1 Chevron 1/2 A-028400 i I I ! ! aelco Pc* 25% ii , Ar~'o 112 - Chevron 112 'i - i ·~4 - {Fred W. Axford) j i ' A-O28997 ~ · . .. I. ~ ~ II I I I ezl , i i Arco 1/2 - Chevron 1/2 Arco 1/2 - Chevron 1/2 - ,z j (Fre~ W Axford) ' (fred W. Axford} ; co 1/2 - Chevron 1/~ (Fred W A~ford) ~ ..... ~ A-028993 i ~ ~ J 15 .34 ~ ~,, .FcEI!/~; i!,JOV 2 SWANSON r IVE ~nCj~ AREA LEASE MAP CHEVRON U.S. A. INC. STATE OF ALASKA ALASKA O,~. AND GAS CONSERVATION COk.~IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] D EVE LOPM ENT O I L)[]~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE MULTIPLE ZONE [] 2. Name of operato.r Chevron U.S.A. Inc. 3. Address P. 0. Box 7-839, Anchorage, Alaska 99510 4. Location of well at surface Approx. 1800' N & 650' W from the S~[ Cor., Sec. 5, T7N, R9W, S.M. At top of proposed producing interval Approx. 2400' N & 650' W f/SE Cor. of Sec. 5, T7N, R9W, S.M.B.&M. At total depth Approx. 2400' N & 650' W from the S.E. Cor., Sec. 5, TTN, Rgw, S.M. 5. Elevation in feet (indicate KB, DF etc.) ' 168' K.B. I 6 . Lease designation and serial n°. A-028996 9. Unit or lease name Soldotna Creek Unit 10. Well number · SCL 42B-5 11. Field and pool Swanson River- Hemlock 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number U80615521 Amount 500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 16.5 miles from Kenai miles 2200 feet well 30 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10,971 MD 10,900 TVD feet 1120 12-1-82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures __~ psig@ Surface KICK OFF POINT 7000 feet. MAXIMUM HOLE ANGLE 1 3 oI (see 20 AAC 25.035 (c) (2) ~,~at2 ( ~/[~),/' psig@l. 0,900ft. TD (TVD) 21 SIZE Hole Casing i S.ee~ ttache Weight Grade program. 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Coupling Length SETTING DEPTH MD TOP TVD MD BOTTOM TVD QUANTITY OF CEMENT (include stage data) We propose to drill well SCL 42B-5 per the attached program. RECEIVED NOV 2 2 ]§82 Alaska 0il & Gas Cons. Commission Anchorage 23. I hereby certify that the/f/~r'r'r~goincA~ t/r~e and correct to the best of my knowledge SIGNED · TITLE Area 0perations Supt. The spac'~'Belov~for bommission use /f CONDITIONS OF APPROVAL DATE /I-- Samples required []YES ~NO Permit number Form 10-401 Submit in triplicate Mud Icg required Directional Survey required I APl number J--JYES J~NO [~YES []NO J 50- /~- Approval date ~) ,COMMISSIONER DATE Nlcr~mrn lq~_ r by order of the Commission November 22, 1982 r~r. T. L. Perryman Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Dear Mr. Perryman: ~'e-have received your letter of November 18, 1982 requesting the waiver of the requirement for a surface hole diverter systen~ for the drilling of the~ well in the Swanson River Field. In this letter it was noted that there were no oil or gas shows from the SCU 43-5, SCU 42-5 and the SCU 33-5'wells while drilling the hole to set the surface easing at 3400 feet. This letter will advise you that the Commission has examined tho evidence available and hereby Waives the requirements of 20 A^C 25.035(b)(1) for the drilling of the SCU 42B-5 well in the S~vanson River Field per the authority granted in 20 AAC 25.035(b)(2); Yours very truly, Harry ~. Kugler Commissioner BY ORDE~ DF ~tIE CO~-~_ISSION WELL PROPOSAL SCU-42B-5 DISCUSSION P~oposal Drill a new well from the SCU 13-4, 33-5 and 42A-5 well pad. The objective will be an H-8 completion approximately 670 feet to the North of the surface location. Justification SCU 13-4 was drilled and completed in the Hemlock 8 and 10 Sands in August, 1975. The H10 Sand had an initial production of 1026/2166 B/D M/D O/W/G~. The H8 Sand was added in 1976 after production had dropped to 274/69/4130. The H8, HIO Sand commingled production was 1271/243/7120. A portion of this increase was due to a solvent job done just after opening the H8 Sand. Poor production in early 1978 led to several wireline and solvent jobs. The wire- line work resulted in several wireline tools left in the tubing. Repeated fishing jobs through July of 1980 were unable to recover fish and well was determined to be unproducible due to mechanical conditions. A neutron log was run in October, 1979 prior to closing the hole. It indicated a low GOR 8 Sand saturation. There are currently no 8 Sand producers on the:west flank of the C-D fault block. Incremental reserves are estimated at 702,000 bbls. oil with a 382 bbl./ac-ft, recovery factor. Estimated 8 Sand recovery is over 40% of original oil in place. SCU 42B-5 will be at the same structural elevation as SCU 13-4. Stratigraphy and structure are well documented in this area, approximately 80 feet of oil effective 8 Sand are anticipated. The estimated original oil water contact is 10,570 feet subsea. The anticipated top of the H8 Sand is 10,388 feet subsea. The risks for an economic well are premature gas breakthrough and differential water encroachment. RECEIVED NOV2 2 982 Alaska Oil & 6as Cons. Oommissio. Anchorage PROP-~$AL FOR WELL OPERATIONS PRO 316~-~-_ FIELD: Swanson River PROPERTY AND WELL: Soldotna Creek Unit 42B-5 SURFACE LOCATION: Approximately 1,800 feet North and 350 feet West from the Southeast corner of Section 5, T7N, R9W, S.B.&M. BOTTOM HOLE LOCATION: Approximately 2,400 feet North and 650 feet West from the Southeast corner of Section 5, T7N, R9W, S.B,B.&M. ELEVATION: Estimated K.B. elevation of Brinkerhoff 54 is 168 feet K.B. to G.L. is 25 feet. BLOWOUT PREVENTION CONSIDERATIONS: 1. Potential Problems A. Gas and water entries' Gas sands and high pressure water sands can be encountered at any depth below the surface cas.inz. SCU 33-5 encountered a high pressure water sand at 7,116 feet. 801~1~c~ mud was required to control it. SCU 42-5 took a gas kick in the H4 while drilling with/ pcf mud. SCU 13-4 took a water kick above the Hemlock at 10,250 fe~-~- while drilling with 92 pcf mud. B. Lost Circulation: Lost circulation is most likely in the Hemlock, 5!'J~ SCU 13-4 experienced lost circulation when drilling through the top of the Hemlock at 10,350 feet with 97 pcf mud. Co Stuck Pipe: SCU 42-5 and SCU 42A-5~ stuck pipe in the H8. The most reasonable cause was differential sticking. . D. Precautions: Ail kicks should be handled by normal procedures. Drilling crews should be made aware of these methods prior to spudding. Kick and BOP drills should be practiced at regular intervals and noted on the tour sheets. An adequate supply of weight materials should be at the well at all times. ~~)s' Maximum Anticipated Formation Pressure: _ i in high pressure water sands above 10,400 feet. Hemlock pressure is approximately 4700 psi. 3. Maximum Anticipated Surface Pressure: 3700 psi. 4. Blowout Prevention Equipment: Class III 5000 psi BOPE. 10-3/4" and 7-5/8" casing. ~F~CE ' DIRECTIONAL DRILLING CONSIDERATIONS: 1. A vertical hole is to be drilled from surface to 7000' MD. ~' "lvOv~ ~,~ ~- :,~ q. ~tl~,~ka Oil ~; C, as ¢o~s. , A. Drift shots are rio be taken at a minimum of 500 {ncrements. Anchorage C°~rflissior~ B. Gyro survey to be run if necessary. o Kick-off at + 7000' feet (MD). Build at 2 dgrees/100 feet to 13 degrees. Target is the top of the H8 at 2,400 feet North and 650 feet West from the Southeast corner of Section 5, T7N, Rgw. S.B.&M. , Begin dropping angle at 2 degrees/100 feet at + 9980 feet(b~). Hole should be vertical at H8 intercept. Estimated Depths and Correlations' Marker SubSea Depth Vertical Depth Drilled Depth H! (Hemlock Top) -10,220 H8 -10,388 H10 -10,510 TD -10,732 10,388 10,556 10,678 10,900 10,457 10,627 10,749' 10,971 £CE'IVp D NOV £ 2 ~n~,, AL-~ska Oil ~ Gas Cons. Anchoraga C°mmis~,/ot~ PROGRAM 1. Drive 20" conductor pipe to 80 feet or as deep as possible during rig-up. . Drill for 10-3/4" casing to + 3,400 feet. Maintain drilling fluid per attached drilling fluid program. . Condition hole for logging at 3,400 feet. Take a ½ gallon sample of mud returns prior to pulling out of the hole to log. Run Schlumberger's Dual Induction SFL with $P from effective depth to the shoe of the conductor. Record on the following scales: A. Linear scale for 2" - 100' 0-50 ohm-m , Logorithmic scale for 5" = 100'. 10 MV scale for SP Development geologist to witness. 4. Cement 10-3/4", 40.5#/ft. K-55 buttress casing at 3,400 feet. Ao Use float shoe and stab-in duplex collar two joints off bottom. Centralize bottom five joints. Cement through the shoe with sufficient Class "G" cement premixed with 2.4% gel by weight of water to obtain returns to the surface. NOTE: Class "G" cement with 2.4% gel by weight of water: P. Yield - 1.86 CF/SX cmt. Water requirement - 1.36 CF/SX cmt. Gel requirement - 1.5 lb/CF water Slurry weight - 98 pcf Have stage collar on location in case lost circulation occurs while drilling top hole. . Cut off 10~3/4'' casing below the top of the cellar to allow the top flange of the tubing head to be above ground level after completion. 6. Install 10"-5000 psi, 10-3/4" SOW casing head. Test lap weld to 1500 psi. . . Install Class III, 13-5/8" - 5000 psi BOPE as per attached BOPE design. Test BOPE, kill line, blow line and manifold to 5000 psi as per State regulations 20 AAC 25.035. Alaska Oil & Gas Conservation Commission and/or Minerals Management Service to witness. Drill out cement to + 10 feet from the shoe. Pressure test casing to 1500 psi. Drill a 9-7/8" hole to + 10.457 feet M.D. (10,388 feet TVD.) Estimated sands tops as follows: Sands MD. T.V.D. V.S.S. Hi 10,457' H8 10,627' H10 10,749' T.D. 10,971' 10,388' -10,220' 10,556' -10,388' 10,678' -10,510 ~0,~00' NOV 2 2 ].982 Alaska 0il & Gas Cons. {;ornmis:,ion Anchorage A, Follow muo ~pecifications per the attached program. 10. Condition hole for logs at effective depth. Take a ½ gallon mud sample from the returns prior to pulling out of the hole to log. Run the following Schlumberger logs from effective depth to 10-3/4" casing shoe. A. Dual Induction with S.P. and G.R. Use linear 2"/100', 0-50 ohm-m and logorithmic 5"/100' scales. Use 10 MV/division for the SP and a 0-100 GRU scale for the gamma ray. B. Borehole compensated sonic log with G.R. Log scale to be 50-150 MSEC. C. Have an FDC-CNL-GR and SWS gun on location. D. Development geologist to witness. Record all logs on tape. 11. Drill to the top of the Hemlock if log correlation indiciates it to be necessary. 12. Run 7-5/8" casing to top of Hemlock as follows: Bottom 995' 33.7#/ft. S95 LTC Next 3,610' 29.7#/ft. S95 LTC Next 2,150' 26.4#/ft. S95 LTC Next 3,622' 26.4#/ft. N80 BUTT Top 80' 33.7#/ft. S95 LTC 13. Add 33.7#/ft, S95, LTC casing to the bottom if additional casing is needed. Cement 7-5/8" casing as follows: A, B. C. D. Run a standard shoe and collar. Run a stage collar at approximately 7,500 feet. Centralize the bottom 500' and above and below the stage collar. Cement in two stages as follows: (i) First stage: Pump sufficient Class "G" cement mixed with 3/4% CFR-2 through the shoe to reach near 8,500 (2) Second stage: Pump through the stage collar, a suffficient amount of Class "G" cement premixed with 2.1% gel by weight of water to reach 1000' into the 10-3/4" by 7-5/8" annulus. NOTE' Class"G" cement with premised gel at 2.1% by weight of water: Yield - Water requirements - Gel requirements - Slurry weight - 1.68 CF/SX cmt. 1.18 CF/SX cmt. 1.3 lbs/CF water. 102 pcf 14. Remove BOPE and land 7-5/8" casing. Install a 10" - 5000 psi bottom flange x 8" - 5000 psi top flange tubing head. Test secondary pack-off to 5000 psi. Install 13-5/8" - 5000 psi Class III BOPE. Test BOPE: kill line, blow line, and manifold to 5000 psi per State regulation 20 AAC 25.035. Alaska Oil & Gas Conservation Commission and/or Minerals Management S~e~.M_.~.eg~P~[) witness test. Al~Sk~ Oil & Gas Cons, Oommis~ior,, - Anchorage 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. Drill out stage collar and cement to within + 10 feet of 7-5/8" casing shoe. Run Variable Density - CBL-GR log from effective depth to above top of cement from stage collar. Cement squeeze as required. Pressure test 7-5/8" casing to 3000 psi. Condition mud weight to 68-72 pcf. Drill 6-½" hole to 10,971 M.D. (10,900" TVD). Follow directional program as outlined in Directional ConSiderations. 6-5/8" hole may be drilled if bits are available. Condition hole for logs. Take a ½ gallon mud sample from the returns prior to pulling out of th~ hole. Run the following Schlumberger logs from TD to 7-5/8" casing shoe. A. Dual Inducation, SP and GR (same scales as used on intermediate string). B. Borehole Compensated Sonic with G.R. (same scales as used on inter- mediate string). C. FDC-CNL, GR. 0-60 porosity units, 0-100 GRU. D. SWS to be taken as directed by development geologist. E. Record all logs on tape. Development geologist to witness logging. Condition hole for 5½" liner. Cement 5½", 20#/ft., N-80, buttress casing from TD to lap inside 7-5/8" casing by 200~ (+714~). Use sufficient densified (122 pcf) Class "G" cement with 3/4% CFR-2 to obtain returns ~above liner top. A. Use a float shoe and a float collar one joint above'the shoe. B. Use P-il0 special clearance couplings 'in the 'lap. C. Hang liner with a 7-5/8" x 5~" liner hanger. Clean out to the top of the float collar. Run a Variable Density CBL-GR-CCL and multi-spaced Compensated Neutron from TD,to above-the liner _hanger. Pressure test 7-5/8" casing, 5½" x 7-5/8" lap and 5½" liner to 3000 psi. Obtain WSO below base of H10 sand, if required. Displace 7-5/8" casing and 5½" liner to PBTD with 100 bbls of water followed by lease crude. Circulate until clean crude returns are obtained. Run 3~" completion string as per attached. Remove BOPE and install xmas tree. Pressure test tree to 5000 psi. Release rig. Supplementary program will follow for the perforating. NOV 2 Alaska Oil & Gas Cons, Cornl¥1isgion Anchorage DRILLING FLUID PROGRAM - SCU 42B-5 SWANSON RIVER FIELD Basic Drilling Fluid System Medium treated lignosulfonate mud. Optimum Drilling Fluid Properties Mud Properties Mud type Weight - pcf Viscosity - seq/qt.API Fluid Loss cc API Plastic viscosity - -cps Yield Point lb/100 ft. To 10-3/4" Csg. Pt. Reclaimed mud or extended gel 68-75 45'200 (1) From 10-3/4" Csg. From 6,000' to From 7-5/8" Csg.Pt. to 6,000' 7-5/8" Csg.Pt. CSg.Pt. to TD. Extended Gel Lignosulfonate Lignosulfonate 70-75 75-100 (2) 68-72 35-45 43-47 43-47 7-10 4-7 18-24 18-24 18-24 8-12 6-8 6-8 pH - 8.5-10.5 9-10 9-10 Calcium - ppm - 50 max. 50 max. 50 max. Solids content - 7-13 13-25 6-10 % vol. Remarks · .. l, o o High viscosity as required for surface drilling. 100 pcf maximum anticipated required mud wight. Have high pressure - high temperature drilling fluid test equipment on hand after drilling out shoe of 7-5/8" casing. Make fluid loss tests at esti- mated bottom hole temperature of 170 degrees F. COMPANY · PROPOSE-~ DRILLING CURVE WELL NO. ~C~/ ~tZ/~-.ff ~000 400~ 500O TO00 8000 9000 ...... I0 ZO 30 50 PROPOSAL FOP, WELI~qPERATi0r~IS PR0-316-A (TO BF~ISED AS A G0-111) CASiI~,~G REQb,REMENTS At, ID PRODUCING EudiPMENT NELL/LOCATION NO. SCL) ~Z~-S =IELD '~JC~n ~0~ FOTAL DEPTH IiOoo METHOD OF PRODUCTION ?lo~ =_STIMATED O/W/G. /, /,. EQUIP. FOR STEAM :ASING Gross Footage APl Size Weight Grade -C°nductor ioo' 2o" c)H ~ ~-qO DATE II- ESTIMATED SPUD DATE 12- MAX. ESTIMATED SURF. PRESSURE 3700 INJ. PRODUCER Threads Coupling Computer Design For: ~ud~'eES ~(q¢~ T~C O1~ This Well Water String: Design based on mud density I0~o' ,, Cementing ,,~ccessones Surface lbs./cu, ft. and above max. surf. pressure 7%" ~.7~ ~75 LYe Xo~ S~ ~.b0~ K~pln " ?~.~, ~o ~. ZS- 95/~"~7~/~~ ce~tr~,~eo Liner ~.7 ~ s~s ~ ¢~ff ~1~, ~ ?l~ ~ 5&d. Hanger Perforated .. ASING } NITIZED ASING SPOOL UBING HEAD 7 %" 33.7 PSI UBING Standard Design For Field Well No. Max. Drift Angle 5Zo' 5~/z'' go~- /a-so r%tl,-~s~ ', to ~ ' Mesh, Rows, Slots, HEAD: 5Ooo PSI CWP. Bottom Conn. IO 3/q, * 50~ ~ Top Conn. ~O" x~ A~ ~ ~.~ " Fittings I ~r~ ~O~ ~i ~ V~¢ ,~J ~J~ ~ o~. ~ 5X3OO TopConn. '~"'X$O0o .,,4/:~ ~,.~' --~'1o~ Type Suspension "i'~oll uJee~til ~'/z ~ ~ PSI CWP. Bottom Conn. Feet APl Size Weight Grade Threads qoo 3vz" 9.~ ff' ~-~0 Ar,~o Bottom ~o 200 3'/z~ 9. 3 ~t 10-%0 ZUE Next 9-~qc~r~ H~ 3'5~ ~so- I.~ ~ck Eu~ ~,n~-&~ Total ~bing C~tcher cker 7~/~ "x 3 YL type. Csg. Size " '-2_~-J~ ~L ~- Wt. 5000 Arm MC Centers, ~ MUC Remarks (Cross-overs, etc.) xo's ~ ~ Type Sc~,( - " Wt. Install at Type with' ~c)~ ~'~. "stroke at Other Fittings , PSI CWP. Dwg. No. Type __" PSI CWP. Dwg. No. Type. Polished Rod Type at "X · of "Stroke and ,, . '~':' i.:.: i.ii: ~ '"~ ~: ~ .... of "- Type Max. Stroke "Se! at Motor HP Remarks outletx with dASTREF ~" )(' 3' Arm Tubing Beans " Header " Stuffing'Box " JMP: "x )DS: Grade__,~'of JMPING UNIT. APl Size Engine Type ' · ' Long SPM apared By Area Supervisor Approved by Drlg. Supt. Sr. Drlg. Engineer ! ! I ! ! ! ! ! ! ! ! I '! / OCA TIOII JOlt. ~At& I", ZOO' ////~Z J F/_C-. · ~' ' ~t~:* 42'F tt . il I t t / I I I , I I , I I ~ ~o~r 7~2Z' 0 ~ I ~ I ~,,,,' I ' t /$-4® ,oRO, oOS~'z~ 4~- 5' mm ., I u _ . O~E JOl~ 3~~ ~ B~ ~L~AS~, ~P7N ~ ~ 35 'ABOVE ~E~ OTIS ~" ~IPp~ , POSITION ~, ~JOPTIO~ /0 Z~?~' Zl,~lE~ TOP (-+ 200' ABOVE ?~" CA~ING ~0~ ) . 70P JO/NT 5~ ~" S~'Z ~C~PT/C~. 4.75" ~o~. . . ~U~/~ /~. 3~" ~CO ~-~0~' , .- I0~7 , ~ -~.~. , . ~ .~ -._ .. .. , ' I _~-,~.~. 'II ~ ~" .;:--:~... , , i ~, ~ ........... .,.,,\\ . , /'','...' 17 i 16 - I ,, II · //--¥' ' -'-' ~--~'* · " ~ . I ,'/ ;I ,,-., ,,DJ/,,.., ..... · '; I ' m j..$' · ~ .~ I~' . . ~ ' .?'--;-r'" -/.~. - ..... . Iii ' , %'! , ' ' -~; ................... l: ..... :" \\ · ~.LN~W. __~ ._ .t____~,~__.._~- .... + ..... -~--:--------~H.-~ ......... .;.~ - -- , ! 4' ' I \% ~ ' I , : '? I I ,;, ~ , ,7,.~ . . . . ,;- . , ; ,r ', - '~'% ~ I '- ; ,r -! ' . ,r i \\ %''' ~' ' "' ' · I .' ~' I Il · . ~ i ~,, ~ ~,,.,,/k""'"-. l; ,.,,.- .· ~i · : - ~ '. I ,/, ~ ~ ~..' , ~, .,,~--_~ ~ ,,: ~ ,.~:: .. II , m_........., .'. , , . ...... ~.~o - ......... ~. .... _~ .... ~'~'~ 4i __ ! I~,.~ .~ I i Ix 27 ..../'. I'mlm~l~ . 26 ;~ 'l ~ ..... . ! I - I SWAN SO i . ~ i ' -. ,,-. ~..I I. . I I ./" II I I .- -.~;~ "' RIVER UNIT I . 'l m m m m34m I m,i I . ~5 '~, -'. i ~REEK UNIT - I II I i' I . ,F .... ' ....1~ .................. " ' ..... z,-~ I ~ ~ I ~' ' ( I SSOR ~ANT i, .. , I ,~' I " ~ I mm,mi ',',' . I I '~ - I " ~,~ I I l lz, ,o " · ~... ' I ~:, , ..... ,,,..,,- ,:-~,.?~ ;" ~ ~ · .- .~.(~ - " I I- 'L I I I I STERLING HIGHWAY I I~ MILLS I I 29 m m mm mmml mm I · m ! ~m mm128 m ' WAREHOUSE m I ~ YARD m-~ I m I .,~ *l I i' i i i i · mm I 44'0 ~' ........ T":' ' I 3-9 l:.S. L mm · mm I 41'J ill'il i - i i . imm ,Z 'i /.~5;"' .' m . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. t?~ A G t!~ 1 52. 52. 52. 52. 52, 52° 52, 3'I * 40 * q, :1, 12 * · 1~ * ~ 11 * '1 * 'I , '31' 4'/ * .12. · 11 * ["~ rti1] iii ii" i[~ [;-]: 52. bE. b~. 52. 52. * .13. '7 ,~ * 9 * * 10 · .19' * 41 * .... ,,> ~ b ,,, i J... o * 27,1 I 1. t * 2'7. o t. 1,1 ~ 2b.~J ~ 1.,~ * i. 1.. u ~ 2b,b i i..,, ~ 25.5 l.t' . ¥ * 2b,4 1. L', ,.>· 25.2 ~"'r '~ U ~ , 793. '!b2, '/79, '151. '1 b t.. 713, 0 * 7o9. · 52. * 50 * 1. * 'lOg, * hZ, ~ 3b * 2. * '709, * hZ. * 3I * ~. ,* 700, * 52, * 2u 'I. · 705' * hz. * 24 * 10, * tO;Z. * hZ, ~ 22 * 2, :~; o99, * 52. * 31 0 * C~'gu, * 52. * 45 * i. * ogB. * 52. * 3'1 * 0 * ~,9'/. * 52, * 44 * ':0 * 6~:;'1. * 52. * 29 * ~',.) , ~9'1. * 52, * 4~ * (_) '* 6~'1. * 52, * qb * ~, * ~'/. * 52. * 29 * 4. * 609. * b2. * 22 * 1. * ouH, * ~2. * 2b 3. * ~)U't, * 52. * 19 * fSb. .* ~)u4. * hZ, * 1.0 * 52. * ,Sb'~. * 52. * 8 * 33. * 652, ~ b2, * ~ * I3. * :,43. * 52. * 13 * ,~. * 033. * hZ. · 22 4. * t>.~(..). * 5Z. * 2~ 3 34d, Z~J7 , 2t3. 2bb, 2lb, I ~.~, l~JS, lbg. I 'lq, 37, il, T 44. JZ. 3 0. 21. 23. 21, 11, 2, 1, 0*26* u · 2o * 0*33* U 0 * 2b U 0
