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Home My WebLink About160-017Oeth Nolan Hilcorp AlaskOVLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Hil++r.++up Alaxkv, TAX Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 10/30/18 To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 CBL CD1: Elog digital data 2 SRU 23-22 Final CBL AKE-line 6-2a-18.ias 0` SRU 23-22 Final CBL (6-28-18).pdf SCANNED NOV U b LU)6 10017 2993 1 6/2018 6:52 PM LAS File 1,039 KB 6/28/2018 6:99 PM Adobe Acrobat Doc... 2,693 KB Please include current contact information if different from above. Please acknowledge fceipt by signing and RECEIVED OCT 3 1 201 AOGCC ng one copy of this transmittal or FAX to 907 777.8337 Received By: W/) A "\ Date: /0/ �// X STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ia. Well Status: Oil ❑ Gas❑ SPLUG❑ Other ❑ Abandoned ❑� Suspended[—] 20MG 25.105 20MC 25A 10 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑� Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcerp Alaska, LLC 6. Date Comp., Susp., or Aband.: 9/8/2018 14. Permit to Drill Number / Sundry: 160-017 / 318-105 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 1/4/1960 15. API Number: 50-133-10150-01-00 4a. Location of Well (Governmental Section): Surface: 2120' FWL & 2010' FEL, Sec. 22, T8N, R9W, SM Top of Productive Interval: N/A Total Depth: 1330' FSL & 2120' FWL, Sec.22, T8N, R9W, SM 8. Date TD Reached: 3/9/1960 16. Well Name and Number: Swanson River Unit (SRU) 23-22 9. Ret Elevations: KB: 15' GL: BF: 17. Field / Pool(s): Swanson River / Tyonek Gas 10. Plug Back Depth MD/TVD: 0' MD / 0' TVD 18. Property Designation: FEDA028406 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 351096.5 y- 2474865.6 Zone- 4 TPI: x- N/A y- N/A Zone- 4 Total Depth: x- 350036.3 y- 247305.12 Zone- 4 11. Total Depth MD/TVD: 11,614' MD / 11,235' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes v (attached) No Q Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page 4 necessary N/A 23. 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 22" Surface 28' Surface 28' DRIVEN 13-5/8" 54.5 J-55 Surface 3,000' Surface 3,000' 18-5/8" 2000 7" 26-29 al10 NS Surface 11,594' Surface 11,228' 8-5/8" 1810 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ,t �— A4& ,`�t't-T 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD/TVD) 2-3/8" 5,160' 5,082' MD / 5,082' TVD 11,126' MD / 10,794' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Date of Test: N/A Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 /S CONTI /U 'D/ txO PAGE 2 2Ck!S , jj O OCT 2 5 208 Submit ORIGINAL r .i�'Z ,V y 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MDfT-VD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary, Schematic, MIT -IA, Photo document casing cut-off/cement top/welded plate. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Ted Kramer, Operations Engineer Authorized Title: Operations Manager Contact Email: tkrameranhilcoro.cem Authorized Contact Phone: 907-777-8420 Signature: Date: 1 oAzy I la INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: 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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Tap of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from morethan 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Hilcorp Alaska, LLc SCHEMATIC Swanson River Field Well # SRU 23-22 API # 50-133-10150-01-00 RKB to TBG Head = 20.00' CASING AND TUBING DETAIL Tree connection: TC -3 Uni-bolt c..?SIZE �.. WT GRADE CONN TOP BOTTOM c tvt IuBP 22" Surf 28' T m 13-3/8" 54.5 J-55 Surf 3,000' t 7" 29 P-110 8rd LT&C Surf 36' 7" 26 P-110 8rd LT&C 36' 1,812' Volti 7" 29 N-80 8rd LT&C 1812' 3,159' 'IV 7" 26 N-80 8rd LT&C 3159' 6,560' 7" 29 N-80 8rd LT&C 6560' 8,066' M7" 26 P-110 8rd LT&C 8066' 9,771' Top Fum T clay. 2a 7" 29 P-110 8rd LT&C 9771' 11,594' 3.33T 3018 Tubing: 3 2-3/8" 4.6 N-80 Buttress 15,090' 5,160' 5 4 1000 sx @ 6,195' pumped 6TOC JEWELRY DETAIL above NO. Deoth(ft) Item DV @ 7,197' 5/97 Perfs 1 160' CIBP w/ 160' cement TOC = Surface 07/03/18 No bond log 2 3,095' CIBP w/ 338' cement TOC above 2,900' 06/28/18 2a 3,235' CIBP w/ 35' cement TOC @ 3,200' 06/20/18 3 5,082' Baker FH Retr. pkr, 2-3/8" x 7" 26# 4 5,127' X nipple, min. ID = 1.875" 5 5,160' Tbg tail (shear out sub) Tbg cut @ 6 6,220' Vented Plug 8,500 s 7a 9,215' Baker cmt retainer in 2-7/8" tubing 10/21/96 Calc Highest 7b 9,520' Baker curt retainer in tubing TOC in 8 9,533' Cameo Mandrel #8 w/dummy Annulus @ 9 11,072' Cameo Mandrel #9 w/dummy 8970' 10 11,126' Brown packer, HS -16-1 C 7a 11 11,193' Cameo D nipple e TOC in 12 11,255' Bottom of tubing tail Tubing @ M 7b 9,158' WLM e 10/11/95 n t 8 9 10 11 PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 5,189 5,199 Tyonek 51-9 6 9/12/97-Reperf4/14/12 12 6,235 6,244 Tyonek 554 4 4/30/97 Isolated 4/9/12 6,267 6,272 Tyonek 61-8 4 5/3/97 Isolated 4/9/12 6,277 6,284 Tyonek 61-8 4 4/28-30/97 Isolated 4/9/12 9,507 9,510 Tbg holes 4 10/95 For Hemlock P&A Isolated 4/9/12 11,208 11,216 Hemlock 4 Abdnd 10/95 PBTD = 9,215' TD =11,614' 11,226 11,254 Hemlock 4 Abdnd 10/95 MAX HOLE ANGLE = 240, KOP @ 3,000' Updated by DMA 09-13-18 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit NumberStart Date End Date SRU 23-22 50-133-10150-01 160-017 3/1/18 1 9/8/18 Daily Operations: 03/01/2018 - Thursday Arrive @Office . PJSM and review 1SA. Rig up. Crane turret frozen. R/U Slickline .125" TP - 100 psi, CP - 700 psi. P/T to 1500 psi, pass. RIH w/ 10' 1.75" DD bailer. S/D @ 2,480' KB. Drive bailer to 2,490' KB. bailer full fluid level at 1,850' KB. RIH w/ 10' 1.75" DD bailer. S/D @ 2,495' KB 2,503' KB. bailer full mud. RIH w/ 10' 1.75" DD bailer. S/D @ 2,500' KB. Drive bailer to 2,503' KB. bailer full. RIH w/ 10' 1.75"pump bailer S/D 2,499' KB. Driver bailer to 2,505' KB. bailer full of mud & coal. RIH w/ 1.75 cent 5' 11/4" poker.. S/D @ 2,505' KB. Drive poker to 2,507' KB Pulling binds. RIH w/ 10' 1.75" dd bailer. S/D @ 2,501' KB. Work tools 2,502' KB. full of mostly mud some coal. RIH w/ 10' 1.75" dd bailer.Open ended S/D @ 2,501' KB. Work tools to 2,503' KB. Pulling bind. RIH w/ 10' 1.75" pump bailer. S/D @ 2,500' KB. Work tools to 2,503' KB. POOH. RIH w/ 10' 1.75" pump bailer. S/D @ 2,503' KB. Work tools to 2,505' KB.. Fluid Level - 1,880'. Lay down unit. HLB is going back shop tonight and build some tools that should help bail better. Will be back at 0700 hrs tomorrow morning. 03/02/2018 - Friday Arrive @ office. PJSM and review JSA. Rig up .125" Slickline. Add additional 5' 1.5" stem.. P/T to 2,500 psi.TP - 20 psi, CP - 700 psi. RIH w/ 1.75 Cent 5' 1.25" stem and 2'5-barbed spear (1.65" max OD). Tag @ 2,503' KB. Work tools @ 2,507' fell through.. RIH to 2,523' KB and POOH. RIH w/ 10' 1.75 DD bailer S/D @ 2,527' KB. Work tools to 2,529' KB.. Bridge came up to 2,521' KB. Fluid level running in 1,880'. Fluid level pulling out 1,835'. Tubing @ 0 psi. Mud & Coal. RIH w/ 1.75" Cent 5' 1.25" stem and 2'5-barbed spear (1.65" max OD) S/D 2,542'. Work tools to 2,572' KB. POOH. RIH w/ 10' 1.75" DD bailer S/D @ 2,570' KB. Drive to 2,572' KB. bailer three cups coarse sand and mud. RIH w/ 10' 1.75" DD bailer. S/D @ 2,570' KB. Bail to 2,573' KB.. bailer full of sand. RIH w/ 10' 1.75" DD bailer. S/D @ 2,572' KB. Bail to 2,575' KB.. bailer full of sand. RIH w/ 10' 1.75" DD bailer. S/D @ 2,574' KB. Bail to 2,577' KB. bailer full of sand. RIH w/ 10' 1.75" DD bailer. S/D @ 2,575' KB. Bail to 2,577' KB. RIH w/ 1.75" Cent 5' 1.25 stem and 2'5- barbed spear, tag @ 2,577'. Work tools. Fell through. Work tools to 2 670' KB.2-QOH. RIH w/ 10' 1.75" DD bailer. S/D @ 2,614'. Work tool to 2,670' KB.. POOH. bailer full. Fluid level @ 1,880'. Lay down lubricator and rehead/stuffing box. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 50-133-10150-01 1 160-017 3/1/18 9/8/18 Daily Operations: 03/03/2018 -Saturday Arrive @ office. PJSM and review JSA. Rig up .12" slickline. P/T to 2,500psi. RIH w/ 10' 1.75" DD bailer. S/D @ 2,671' KB. Work tools to 2,676' KB. bailer full sand/mud. RIH w/ 10' 1.75" DD bailer. S/D @ 2,674' KB. Work tools to 2,750' KB. bailer full sand/mud. RIH w/ 10' 1.75" DD bailer. S/D @ 2,749' KB Work tools to and S/D @ 3,270' KB. Work tools to 3,283' KB. POOH. RIH w/ 1.75" Cent, 5' stem, 2' 5 barb 1.65" spear. S/D @ 3,277' KB. Work tools to 3,285'. Fall through to 3,317' KB. Work tools to 3,323' KB. Soft. POOH. RIH w/ 10'1.75" DD bailer. S/D @ 3,305' KB Work tools to 3,315' KB, bailer full sand. RIH w/ 10' 1.75" DD bailer. S/D @ 3,305' KB. Work tools to 3,314' KB. POOH. RIH w/ 1.75" Cent, 5' stem, 2' 5 barb 1.65" spear S/D @ 3,315' KB. Work tools to 3,321' KB. RIH w/ 10' 1.75" DD bailer. S/D 3,317' KB. Drive bailer to 3,318' KB. RIH w/ 10' 1.75" DD bailer. S/D 3,317' KB. Drive bailer to 3,319' KB. bailer full of moist sand instead of soupy sand. Add 5' weight bar. RIH w/ 10' 1.75" DD bailer. S/D @ 3,320' KB. Work tools to 3,321' KB. RIH w/ 1.75" Cent, 5' stem, 2'5 barb 1.65" spear. S/D @ 3,322' KB. Work tools to 3,323' KB. The way the spear is acting on this run is like we are close to breaking thru another bridge. Rig down lubricator and secure well. Be back in the morning. 03/04/2018 -Sunday Arrive @ office. PJSM and review JSA. TP - 0 psi, CP - 700 psi. Rig up .125" slickline. P/T to 2,500psi. RIH w/ 10' 1.75" pump bailer. S/D @ 3,276' KB. Work tools to 3,304' KB. bailer full sand/mud. RIH w/ 10' 1.75" pump bailer. S/D @ 3,306' KB. Work tools to 3,310' KB. bailer full sand/mud. RIH w/ 10' 1.75" DD bailer. 5/D @ 3,310'. Work tools to 3,312'. RIH w/ 1.75" Cent, 5' stem, 2' 5 barb 1.65" spear. S/D @ 3,310' KB. Work tools to 3,321' KB. RIH w/ 10' 1.75" pump bailer. S/D @ 3,320' KB. Work tools to 3,323' KB. bailer full sand/mud. RIH w/ 10' DD bailer.. S/D 3,320' KB. POOH. RIH w/ 1.75" Cent, 5' stem, 2'5 barb 1.65" spear. S/D @ 3,321' KB. Work tools to 3,322' KB. RIH w/ 10' 1.75" pump bailer. S/D @ 3,321' KB. Work tools to 3,324' KB. bailer full sand/mud. RIH w/ 1.75" Cent, 5' stem, 2'5 barb 1.65" spear. S/D @ 3,322' KB. Work tools to 3,324' KB. RIH w/ 10' 1.75" pump bailer. S/D @ 3,324' KB. Work tools to 3,327' KB. RIH w/ 10' 1.75" pump bailer. S/D @3,326' KB. Work tools to 3,327' KB. RIH w/ 10' 1.75" pump bailer. S/D @ 3,327' KB. Work tools to 33' KB. RIH w/ 1.75" Cent, 5' 1.25" Stem, 1" spear.S/D @ 3,326' KB. Drive to 3,328' KB. Rig down lub and secure well. Depart field. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 50-133-10150-01 1 160-017 3/1/18 1 9/8/18 Daily Operations: 03/05/2018 - Monday Sign in. Mobe to location. PTW and JSA. Rig lubricator back up. PT to 250 psi low and 1,500 psi high. TP - 0, CP - 700 psi. RIH w/ 10' 1.75" DD bailer. S/D @ 3,277' KB. Work tools to 3,311' KB. RIH w/ 10' 1.75" DD bailer. S/D @ 3,320' KB. Work tools to 3,326' KB. Work thru at 3,290' KB. RIH w/ 10' 1.75" DD bailer. S/D @ 3,290' KB. Fell through. S/D 3,326' KB to 3,327' KB. RIH w/ 1.75" Cent 5' stem 1.5" and 1.65" 5 Barbed prong. S/D @ 3,326' KB. Work to 3,328' KB. Add 6' weight bar to toolstring. RIH w/ 10' 1.75" pump bailer. S/D @ 3,328' KB. Work tools to 3,329' KB. bailer 1/2 full. RIH w/ 10' 1.75" DD bailer. S/D @ 3,328' KB. Work tools to 3,329' KB. bailer 1/2 full. RIH w/ 10' 1.75" DO bailer. S/D @ 3,329' KB. Drive bailer to 3,331' KB. Bail full. RIH w/ 10' 1.75" DD bailer. S/D @ 3,331' KB. Drive bailer to 3,334' KB. RIH w/ 10' 1.75' DD bailer. S/D @ 3,333' KB. Drive bailer to 3,334' KB. Rig down. Pollard will be here in the am. 03/06/2018 -Tuesday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up Pollard SL lubricator. PT to 250 psi low and 1,500 psi high. RIH w/ 1.75" x 8' DD bailer to 3,288' KB w/t 3,304' KB POOH - 1/4 full moist sand. RIH w/ 1.75" x 6' DD bailer to 3,304' KB w/t 3,316' KB POOH - 1/4 full moist sand. RIH w/ 1.75" x 6' DD bailer to 3,316' KB w/t 3,318' KB POOH - 1/4 full moist sand. RIH w/ 1.5" DD x 10' DD bailer 3,318' KB w/t 3,323' KB POOH - 1/4 full moist sand. RIH w/ same to 3,322' KB w/t 3,325' KB POOH - 1/4 full moist sand. RIH w/ 1.75" pump bailer to 3,323' KB w/t 3,327' KB POOH - 1/4 full. RIH w/ same to 3,326' KB w/t 3,331' KB POOH - 1/4 full fell through small 2' bridge. RIH w/ 1.5" DD bailer to 3,331' KB w/t 3,334' KB POOH - 1/4 full moist sand. RIH w/ 1.25" DD bailer to 3,331' KB w/t 3,334' KB - 1/2 full moist sand. RIH w/ 1.5" DD bailer to 3,332' KB w/t 3,336' KB - 1/2 full moist sand. RIH w/ 1.75" DD bailer to 3,333' KB w/t 3,337' KB 1/2 full moist sand. Rig down lubricator and secure well. Will be back in the AM. 03/07/2018- Wednesday Arrive at Swanson JSA, permit, TGSM. Pick up lub pressure test to 1,500# (test good). RIH w/ 1.65" spear w/ 3' prong to 3,290' KB w/t fall to 3,333' KB w/t POOH. RIH w/ 1.75" x 13' pump bailer to 3,333' KB w/t 3,337' KB POOH - empty - rod stuck shut. RIH w/ 1.75" DD bailer to 3,335' KB w/t 3,337' KB POOH - 1/4 full thick fluid no solid. RIH w/ 1.75" pump bailer 3,335' KB w/t 3,339' KB POOH - same. RIH w/ 1.5" DD bailer to 3,336' KB w/t 3,337' KB POOH -same RIH w/ 1.65" spear w/ 3' prong to 3,337' KB w/t 300-400# over pull w/ a 900# OP. POOH. C/O tool string to 1.5" w/ 15' of stem - RIH w/ 1.75" DD bailer to 3,337' KB w/t 3,339' KB. POOH - small amount of solids topped w/ thick mud. RIH w/ 1.65" spear w/ 3' prong to 3,340' KB w/t POOH. Rig down lubricator and equipment and move to another well for paraffin cutting. TP - 0 and CP - 700 psi. 06/18/2018 - Monday Mobilize Field triplex, diesel tank and blow down tank to 23-22. IA 500 psi. Filled to surface with diesel. Bleed down to tank. Hook up field triplex and crystal gauge. Pressure test 2-3/8" x 7" annulus to 1,500 psi for 30 minutes. Actual test time 17:10 @ 1,555 psi. End pressure and time 17:40 @ 1,547 psi. 8 psi drop in 30 minutes. Send test charts to town. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 50-133-10150-01 160-017 3/1/18 9/8/18 Daily Operations: 06/20/2018- Wednesday PESI arrive at office. FIII out JSA and PTW. RU PESI and make up 2.375" CIBP. E-line sub x over has bad threads. Wait for hot shot from pollard shop. 0 PSI WHP. Fluid level found around 1,900'. Finish making up BHA and 2.375" CIBP. RIH. Prog says to set at 3,300'+/-. Tagged with E-line at 3,238'. Run pass. Correlate to chemical injection manderal. RIH and tag same depth. Call town to discuss setting depth. BLM representative ok with setting at current depth of 3,235'. Set CIBP. Top of CIBP at 3,235'. POOH. Make up DD bailer loaded with 16.4 ppg cement. RIH and dump cement 3,235'. TOC @ 3,200'. Cement in place at 15:45 hrs. POOH. Rig back. Install night cap. Master swab closed. Well secure. Crews off location. Will return 0700 am for PT, tag and cut. „ r� 3�f� r✓tg Y 06/21/2018 - Thursday PTW with PESI. Hold safety meeting. MIRU Pollard E-line. Fill tubing with field triplex. Pressure test 2.375" tubing to 1,500 psi for 30 minutes and chart. Sent Chart to town. RIH with Jet cutter. Setting down with E-line at 3,160' Should be tagging cement at 3,200'. Possible cement stringer. Called town to discuss. Cut tubing at 3,144'. No pressure in tubin or IA. After cut noticed a increase in tubing pressure to 180 psi. Back side is u-tubing heavier fluids. POOH to surface. E-line at surface. Rig down and send them to GO pad. Order 2 pallets of Sodium Chloride for the AM. 06/22/2018 - Friday Dispatch Billy Hill Oilfield hotshots to Nikiski. Pick elevators, 2.375" air slips, IBOP, x overs from Weatherford. Pick up bails, 2x 12' pup joints of 2.375" IBT, pick up lift subs, x overs from HAK OSK dock. Pick up 2 pallets of Potassium Chloride from Baroid. Deliver to SRU 23-22 and unload. Place order to D/NOW for ring gaskets, 1502 subs, 5 gallons of pipe dope. Pick up Harvest 3 phase gen set from TajMahall at KGF. Pick up order from D/NOW. Stop at AN and purchase tools/supplies for rig. Move hot oil truck and return tank with containment from P&S yard to 23-22. Spot tank in containment. Rig up iron from production flow cross (2.375") to return tank. Rig up 2.375" x 7" IA to hot oil truck. Load and mix 68 bbls of 9.0 ppg brine into vac truck. Drop 3 phase gen set at electrician compound to wire up pig tail connection. Hot oil truck ready to circulate wellbore first thing in AM. .0 `�V (� 6. Hilcorp Alaska, LLC Well Operations Summary V 01> Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 50-133-10150-01 1 160-017 3/1/18 9/8/18 Daily Operations: 06/23/2018 -Saturday Fire up hot oil truck. Rig up Vac truck loaded with 68 bbls of 9.0 ppg brine. Rig crew arrived. Hold safety meeting. (3x Moncla hands). Crew start cleaning and assembling BOPE components. Flow cross, choke valves, HCR and Kill valve, 7" combi BOPE, 7" annular bag. Online down IA (2.375"x 7") taking returns up 2.375" tubing to return tank. Heat 9.0 ppg brine to 1607. 68 bbls pumped. Shut down. Empty return tank. Load water on vac truck. Mix up 2nd pallet of Brine at 9.0 ppg. Pump 69 bbls of 9.0 ppg brine down IA taking returns from 2.375" tubing. 136 bbls circulated. Empty return tank. Remove standing fluid from well cellar. Remove production flow line and fill 6'x 6' hole around flow line with gravel. Un fold and pull 100'x 100' pit liner. NOS wellhead tech install BPV. Break hanger flange. Remove production tree. Install 10' spacer spool to bring BOPE equipment above cellar. Install BOPE stack. Hammer up flanges. Remove BPV and install 2 way check. Spot in choke skid, kill manifold, and Koomey unit. Run through hot oil truck with manufacturer technician. Install pressure sensor and data acquisition software. Run and test upgrades. Walk location and pick up loose trash. Well secure. Location secure. SDFN. 06/24/2018 -Sunday Hold safety meeting. Pull Accumulator/BOPE hydraulic hoses out of baskets. Hydraulic fittings rusted. Work on breaking out hoses. Spot TK #1 platform over rig and adjust height. RU hoses to Koomey unit. Spot in power pack and tongs, generator. Start building berm. Missing 1 hydraulic hoses for BOPE stack. Called docks and found another set. Cat Loader injector line broke. Find compression fitting and temporarily fix. Head to CIFO lower property and get another set of accumulator hoses. 06/25/2018 - Monday Hold safety meeting. Continue to rig up KT#1. Work on trouble shooting Koomey unit. Pressure on mechanical system pressure gauge wont climb over 2,200 psi. Pressure on remote panel is reading 3,000 psi system pressure. 1 of 3 air pumps not working. Disassemble and clean corroded parts. Send rig pits to P@S yard. Pressure wash and clean out debris/fill from tank. Welder installing supports for gas buster. Fire pipe tong power pack. Apply pressure to HAK 1 pipe tongs. Hydraulic fluid leaking from lever body in multiple places. Shut down and attempt to tighten valve block. No luck. Finished working kinks out of Koomey unit. Function test all BOPE. Make up testjoint, with TIW valve and IBOP. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 50-133-10150-01 1 160-017 3/1/18 1 9/8/18 Daily Operations: 06/26/2018-Tuesday PTW. Hold safety meeting. Discuss job procedure and associated risks. Mobilize modified return tank to location. set in containment. RU and install Gas buster on top of new supports inside tank. install Gas vent tube. Install 3" ball valve on tank supply line. Install down pipe from gas buster to possum belly line. Spot crane into location. Pick test joint. Install test joint into hanger profile. Move in pipe racks and install cat walk/ Beaver slide. HAK #1 pipe tongs leaking fluids from previous dry run. Swap out with Moncla 401 pipe tongs. send HAK#1 pipe tongs to Moncla yard to be fixed. MIRU HAK hot oil truck. Fluid pack and fill gas buster. Crews cleaning up location. Amy Peloza providing training for Waste Manifesting. Pressure test all valves and BOPE components. Perform draw down test. (24 hr BOPE test witness notice sent at 6/26/18 @ 12:43 pm). PT went good. Shut down for night. 06/27/2018- Wednesday Hold safety meeting. Discuss BOPE test procedure. Wait to hear from AOGCC inspector. RU Beaver slide on cat walk. Spot in Moncla pipe tongs. Jim Regg waived witness. 24 hr BOPE test witness notification sent 6/26/18 @ 12:43PM. Waived 6/27/18 @ 0958 AM by Jim Regg. Start BOPE test. Test all rams and valves to 250/3,000 psi. Accumulator draw down test complete. 4 hr ROPE test. Make up 2x 12'2-7/8" IBT joints for pulling hanger. RU bails and 2 7/8" elevators to crane block. Stab assembly into hanger and tighten. Loosen hanger lock down screws and pins. Pull hanger and completion. Calculated hanging weight roughly 15k. PU weight on crane weight cell 14.5K. Pull hanger above slips. Remove control line and isolate. Lay down hanger pulling assembly along with 2-7/8" elevators. Install 2.375" MYT elevators. Rig up Moncla tongs with HAK 1 adjustment cylinder. Extend berm/ containment to the outside edges of pipe rack. Install correct hydraulic connections to adjustment cylinder and Moncla pipe tongs. test tongs. Break one joint and lay down. Metal dumpster on location for control line. Install TIW valve and 1502 king nipple . Location walk around complete. Well site secure. SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 1 50-133-10150-01 1 160-017 3/1/18 1 9/8/18 Daily Operations: 06/28/2018 - Thursday PTW. Hold safety meeting. Fire equipment. Start pulling 2.375" tubing. Remove stainless steel clamps and cut control line and discard in metal dumpster. Call out Pollard E-line to run CBL and set CIBP. Finished pulling 2.375" tubing and laying down. Online down casing to fill wellbore for CBL run. 6.35 bbls of produced water pumped. Pollard E-line on location. RU Pollard E-line open hole. RIH with CBL (cement bond log) while running in from surface no indication of cemented pipe. Tag @ 3,138' uncorrected depth. Log OOH to surface. Slight change in cement bond at shoe from 2,984'-3,015' (shoe 3,000'). Change in CBL still doesn't look like setup cement. Send initial log to town while logging strip from 3,138' to surface. At surface with final log run. Break down CBL tool string. RU 7" CIBP. RIH . 9' from CCL to top of CIBP. PU and park CCL at 3,091'. Puts top of CIBP at 3,100'. Set CIBP. Good weight bobble. PU 200' RIH and tag CIBP at 3,100'. POOH to surface. At surface. CIBP remains in hole. Rack back Pollard E-line. Rig back PESI. Secure well close blind rams. Shut down support equipment. Send final CBL log to town. Plan in the AM is to pressure test CIBP to 1,500 psi for 30 minutes. --7bt LY-3(P 06/29/2018 - Friday PTW, hold safety meeting with rig crew and PESI E-line. Rig up PESI. PT 7" casing to 1,500 psi for 30 minutes. Graph with chart recorder. Good test. Bleed down. PU casing punch. 2' charge length with 10 holes at .41" blast diameter. RIH. Tag top of CIBP at 3,095'. Log and get on depth. Tubing punch from 3,092'-3,094'. POOH. Bullhead down 7" casing with OA open to return tank looking for returns. Pressure 1,080 psi. shut down pump. Pressure holding flat line. Good cement above tubing punches from 3,092'-3,094'. (shoe depth 3,000'). Line up to pump down OA. 13-3/8" x 7". Online down OA. Pump 2 bbls/min at 460 psi. 20 bbls pumped. RIH with E-line with casing punch. Shoot 2,940'-2,042'. POOH to surface, online down 7" casing with 13-3/8"0" OA annulus open to return tank. Pump 1 bbl/min donw 7" casing 600 psi and flat line. No returns to surface in OA. Injecting into formation. Waiting on 10' tubing punch to arrive. Make up 10' casing punch. RIH punch tubing from 2,940'-2,950'. POOH with E-line. Pump down 7" casing looking for returns. No returns up OA. E-line off location shut down equipment. Well secure. Crews off location. 06/30/2018 - Saturday PTW. Hold safety meeting and discuss tripping pipe to 3,100'. Pick up tongs. TIH with 2.375" tubing to 3,100'. HES cementing on location to grab fresh water sample. Print off job procedure and discuss cementing operation and plan. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 50-133-10150-01 1 160-017 3/1/18 9/8/18 Daily Operations: 07/01/2018 -Sunday PTW. Hold safety meeting. MIRU HES cementing equipment. RU HAK hot oil truck. Circulate wellbore with 115 bbls of water to ensure proper density to keep tubing from u -tubing after cement job. Hold pre -cement safety meeting. Discuss job procedure. Pressure test lines to 250/3,500 psi. Good test, pump 10 bbls of fresh water ahead. Cement wet at 12:18. Online with 15.8 ppg cement. Pump 22.5 bbls, followed by 2 bbls of fresh water and 6.5 bbls of brine for displacement. 1 bbl 265' of cement head inside 2.375" tubing. Open well and let balance. Trip 22 joints ooh. Wash up cement truck. 22 joints or 700' of tubing removed. Tubing at 2,400'. Cement top at 2,517'. Line up and pump down 2.375" tubing to perform cement squeeze. Pressure broke over at 200 psi with 4 bbls pumped. Shut down hold pressure. Pressure bleed back to 68 psi. Hold for 30 minutes, pump min rate for 3.5 bbls pressure 233 psi. Shut down hold squeeze pressure for 1 hr. Pressure 200 psi, pull 4 more joints of tubing for 26 total. Reverse circulate 1.5x tubing volume to clean up 2.375" tubing. Secure well. SDFN. Allow cement to setup. HES rep advised not to tag until 0800 hrs. We will start tripping pipe at 0600 IH for a cement top tag. 7.5 bbls of cement injected into 13-3/8" casing shoe. 2 bbls returned to surface when bleeding off squeeze pressure. 5.5 bbls of cement should be behind. 07/02/2018 - Monday PTW ISA. Trip in hole with 2.375" tubing for TOC tag. Tag TOC at 2,827' tubing measured depth. Trip out of hole with tubing. Called out Pollard E -line. Pressure test 7" casing to 1,500 psi for 30 minutes. Chart with chart recorder. Good test. RU pollard E -line. RIH with junk basket to tag TOC. Found TOC 2,757'. POOH. Make up CIBP. RIH and log. Ensure no collar at required set depth. Set CIBP at 160'. RIH and punch tubing with 3' of tubing punches from 158.2' 18 shots. POOH with E/line. Online with hot oil truck to circulate the 7" x 13-3/8" casing. Took 47 bbls to fill back side. returns to surface. Good circulation. RU HES cementing crews. Ensure BOPE stack is full of water and close blind rams. Mix up cement. Pump 3 bbl spacer down 7" casing taking returns up 13-3/8". Online with cement 25.3 bbls cement at surface. Shut down. Close Tank Valve. Squeeze 3 more bbls. Pressure climb to 1,000 psi. Shut down. Clear lines. Rlg down cementers. Bleed off casing pressure. Shut in well. SDFN. Plan forward RDMO. 07/03/2018 -Tuesday Rig down down TK# 1 rig and move to SCU 41B-09. 08/27/2018 - Monday Excavate around cellar. Wellhead saw delivered by Billy Hill Oilfield hot shot from Weatherford. SDFN. Resume excavation in the AM. 08/28/2018 -Tuesday HAK HSE/Enviromental continue the reporting process. Monitor and take samples of certain areas of wellhead excavation. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 23-22 50-133-10150-01 1 160-017 3/1/18 1 9/8/18 Daily Operations: 08/29/2018- Wednesday Jacobs Engineering Environmental specialist on site taking samples and analyzing contaminated impact. Most samples show less than 50 PPMk, discuss options. Remove 2 scoops of material and place in contamination containment. Test excavation, all plots/site markers of excavation show 50 PPM or less of material. Call town to discuss plan forward. 08/30/2018 - Thursday Hold safety meeting and PTW. Jacobs Environmental taking samples. Have conference call with HAK environmental about options going forward. Permission granted to keep digging to get to P&A cut depth. All soil going forth needs to be in berms and covered. Build berms and prep for excavation. SDFN. well site secure. 08/31/2018 - Friday Continue with excavation. Send analytical samples to lab. All material being held in berms and covered. Removed cellar. Started breaking concrete and found more diesel spill under cellar apron. 09/03/2018 - Monday Took weekend off to await analytical results of material. Jack hammer and break cement away from conductor pipe to expose enough to get wellhead saw in hole. Segregate and hold cement in metal container. 09/05/2018- Wednesday Continue to sample with Jacobs Engineering. 09/06/2018 - Thursday Jacobs Environmentalist collecting samples. Lou Laubenstein with AOGCC on location. Inspect cut depth. Confirm cement is to surface. Inspect Marker plate: Hilcorp Alaska, LLC PTD: 160-017 SRU 23-22 API: 50-133-1015-01 State is ready to weld plate. Continue sampling, weld marker plate on conductor pipe. Remove buried flow lines and plug/seal weld the ends. Secure location and install cones and caution tape around excavation. 09/07/2018 - Friday Hold safety meeting with truck drivers. Give them ADEC permitted release and transport documentation. Load 3x side dumps. Estimated 150 yds of contaminated gravel. 54 yards hauled each day. Jacobs continues to take samples. Environmentalist loading samples to take them to Anchorage for lab analysis. Secure location and install excavation barriers. Location secure. SDFN. 09/08/2018-Saturday Load 3x side dumps and send to ASR Brad Quail in Anchorage. Jacobs taking samples to airport. Grabbing extra PID reader. SDFN. '. It SRU 23-22 Cement to Surface SRU 23-22 Marker Plate Welded On Data Collection Report Chassis Left Scale Right Scale Serial Number 476741 475325 Datatype Lower Units PSI G Lower PSI G 1800.0 1600.0 1400.0 23-22ia pt - 18 -Jun -18, 04:47:36, 5021 1200.0 1000.0 800.0 600.0 400.0 200.0 0.0 -200.0 00 Oo Oo 00 00 OOo �Oo X61 Elapsed Time hh:mm:ss -PSI G CPn Ubny Inc M�I�.NE Well S.R.U. 23-22 Plug & Abandon Memo Via email Date: 30 August 2018 To: Hilcorp Alaska LLC....................................................Attn: Cole Bartlewski From: M. Scott McLane, PLS Project: Swanson River Unit 23-22 Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp's Swanson River Unit 23-22 well located in section 22 T8N R9W Seward Meridian, Alaska. The survey was performed on August 23, 2018. The scope of work consisted of providing accurate field elevations so the well could be plugged and abandoned per State requirements. Existing survey control was recovered and positional accuracy was confirmed by comparing (2) check shots on hard targets to existing data. To establish original ground elevation near the well casing, (2) survey measurements were observed at the perimeter of the pad in opposite positions from the well location, parallel to the tidal flat gradient. These elevations were averaged and assumed to fairly represent original ground in the absence of historical data. A top of pad elevation was also recorded adjacent to the well casing then (2) reference grade stakes were set with measurements to the proposed cutoff elevation. Enclosed is Exhibit A which includes pad asbuilt data from 2018 and a well casing cutoff detail with pad, original ground and proposed casing cutoff elevations. • Mean pad surface grade in vicinity of well casing: 311.5'± (2018) • Original ground elevation in vicinity of well casing: 309.5'± (2018) • Cutoff depth requirement: 3.0' below original ground elevation • Minimum casing cutoff elevation: 306.5' • Casing cutoff elevation as staked in field: 305.5' The cutoff mark elevation of 305.5', as referenced in the field, exceeds the required minimum cutoff elevation of 306.5'. P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email msmclane@mclaneg.com Ca Utin Inc McLANE Please feel free to contact me if you have any questions or comments. Sincerely, M. Scott McLane, PLS McLane Consulting, Inc. �A:P�E OF A4 1#1 I,I 9 � 00 01 I`a-t .� 'A ',. M. scorn McLANE4928 S = Page 2 of 2 P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email msmclane@mclaneg.com / 83 83 z ww c� U) as N 11O_ N UU LIJJJ I CN WW N NORTH SCALE 0 200 400 FEET NOTES ORIGINAL GROUND SHOT ELEV = 310.3 (2018) LIMITS OF GRAVEL PAD aQII uJJ I W � d d =1.5 A0 0_ NE 4CO PAD SHOT (NEAR WELL)_ ELEV = 311.5 1111 OF A4gs�,� Zr*.11 IH 49 ...................00 00 /p2�� /zi�C _.i 00 00 c M. SCOTT McLANE. ,ff 4928-5 $/w/2o18 Ess I ON 1. BASIS OF HORIZONTAL; NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP -2. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2458384.578 E = 1483669.444 ELEV. = 212.690 (NAVD88) ORIGINAL GROUND SHOT ELEV = 308.8 (2018) WELL CASING CUT-OFF DETAIL 1 I WELL CASING TO BE REMOVED PAD ELEV = 311.5' f O.G. ELEV = 309.5' t I 1 � I REFERENCED WELL CASING CUTOFF AT ELEV = 305.5' PROJECT HILLCORP ALASKA, LLC REVISION:.. ConsuLiing Inc SWANSON RIVER FIELD DATE: SKIM018 WELL SRU 23-22 DRAWN BY: JAII PLUG AND ABANDON EXHIBIT -A SCALE: !'=2W PROJECTNO. 1SM31 ENGINEERING/MAPPING/SURVEYING/TESTING NAD 83, ASP ZONE 4 P O. BOX468 SOL DOTNA, M, ,669 BOOK NO. 17-p845 VOICE: R.71z814318 FAX: S07) 283d065 LOCATION SECTION 22 T8N R9W sNEEr EMAIL' SAMLV,NE@MCIANECC.CCM Hilcorp Alaska, LLC SEWARD MERIDIAN, ALASKA Sza Z3 -z2 0 PTh IW I70 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, October 4, 2018 1:54 PM To: 'Cole Bartlewski - (C)' Subject: RE: [EXTERNAL] FW: SRU 23-22 Surface P&A That will work. Thank you for the correction photo documentation. Jim Regg Supervisor, Inspections AOGCC �1E0 O ( 31 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Cole Bartlewski - (C) <cbartlewski@hilcorp.com> Sent: Thursday, October 4, 2018 12:56 PM To: Regg, James B (DOA) <jim.regg@alaska.gov> Subject: RE: (EXTERNAL] FW: SRU 23-22 Surface P&A Soon as we had got off the phone the other day Chad Helgeson called me and noticed the same discrepancy on the marker plate. Mr. Jim, will this picture be sufficient for the state files? The hole was and is still open due to the Environmental agencies. Respectfully, Cole Bartlewski 907-690-2854 From: Regg, James B (DOA) [mailto:jim.reag@alaska.gov] Sent: Tuesday, October 02, 2018 10:41 AM To: Cole Bartlewski - (C) Subject: [EXTERNAL] FW: SRU 23-22 Surface P&A Jim Regg Supervisor, Inspections AOGCC 333 W.71h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 1 'CONFIDENTIALITY NOTICE: This e-mail Osage, including any attachments, contains informa6rom 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Regg, James B (DOA) Sent: Thursday, September 27, 2018 3:20 PM To: 'cbartlewski@hilcorp.com'<cbartlewski@hilcorp.com> Subject: SRU 23-22 Surface P&A I reviewed the Inspector's report for the surface P&A on SRU 23-22 (PTD 1600170) and noticed from a photo that the API # on the marker plate is missing a zero. It should be 50-133-10150-01. See attached. Hilcorp must ensure the record is clear about this discrepancy; alternatively the marker plate should be replaced with the correct information. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or lim.regg@alaska.gov. (t'IrG4e,6t Wv k -e �Cd-e. 5r^c C( Z-3--Z-Z M ILOO,ZO (014 tie) • SZ -k z3-zz • P, 1/-70 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, September 27, 2018 3:20 PM 2 To: cbartlewski@hilcorp.com' (� q(0-7(16 Subject: SRU 23-22 Surface P&A Attachments: SRU 23-22 mkr plate.pdf I reviewed the Inspector's report for the surface P&A on SRU 23-22 (PTD 1600170) and noticed from a photo that the API # on the marker plate is missing a zero. It should be 50-133-10150-01. See attached. Hilcorp must ensure the record is clear about this discrepancy; alternatively the marker plate should be replaced with the correct information. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 SCptISOEV INUV � b ZU" 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.aov. I. loor I 7 ` iA tit. I s m a tb Www 0 MEMORANDUM `J State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggqjz-71, DATE: 9/7/2018 P. I. Supervisor FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector SRU 23-22 Hilcorp Alaska PTD 1600170; Sundry 318-105 9/6/2018: 1 traveled to the Swanson River Field for a wellhead cutoff and marker plate inspection of well SRU 23-22. 1 met up with Cole Bartlewski (Hilcorp) and proceeded out to the location for the inspection. The wellhead had been cut off 6 feet below natural grade, giving it a total of 9 feet from the top of the drilling pad. There was competent cement in well to surface. The marker plate was welded to the outermost casing string. Attachments: Photos (4) S(ANNfp NOV 2 b 2018 Inspection Supervisor's Note: The API # on the SRU 23-22 abandonment marker plate is missing a zero - As installed 50-133-1015-01 - Correct 50-133-10150-01 All other marker plate information is correct. 2018-0906—Surface—Abandon SRU 23-22 1l.docx Page 1 of 3 H ilcorp Alaska, LLC SW ANSON RNER UNIT 23-22 (SRU 23.22) Apt # 50-133-10150-01-00 pTp ## 160-017 028406 A LEASE # AK OATI6N N RgW, SNS r, Sl9RF ANE 4 SES L2' TS . r �S A' fir "may,, �„ ; . F � "�•-;rte.: "F�,,,�-:.,� � ;-=,.. ' } . w •, . 2018-0906 Surface—Abandon _SRU_23-22_11.docx Page 3 of 3 F • OF Tit • • `;w \ Iy/yis. THE STATE Alaska Oil and Gas "s M ofLASI�:.A Conservation Commission A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 letiMain: 907.279.1433 OBD Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Swanson River Field, Tyonek Gas Pool, SRU 23-22 Permit to Drill Number: 160-017 Sundry Number: 318-105 Dear Mr. Helgeson: 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. 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, earf - Hollis S. French Chair 1, DATED this7-46 day of March,2018. . RECEIVED • 0 STATE OF ALASKA MAR 1 3 2018 1� AND GAS CONSERVATION COMMISSION b�� Z O i 1 3 R'P ION FOR SUNDRY APPROVALS A 20 AAC 25.280 1.Type of Request: Abandon Q • Plug Perforations D Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q- 160-017 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-133-10150-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Swanson River Unit(SRU)23-22 ❑ Will planned perforations require a spacing exception? Yes 0 No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 ' Swanson River/Tyonek Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,614' ' 11,235' ' 9,042' 8,841' -1,731 psi 9,042'&11,614' N/A Casing Length th Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730psi 1,130psi Intermediate Production 11,594' 7" 11,594' 11,594' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/N-80 11,255' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Brown HS-16-1;N/A 11,126'MD/11,125'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory 0 Stratigraphic ❑ Development❑✓ ' Service 0 14.Estimated Date for 15.Well Status after proposed work: April 15,2018 Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑✓ . WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned Q . 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com Contact Phone: 777-8420 Authorized Signature: eti/& Date: 3is2/1� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 517- 105 Plug Integrity 27 BOP Test Mechanical Integrity Test ❑ Location Clearance 0 Other: it. 3tYL) ( a, / }In -re"; ` � � :vim 2 ' .44e �5= (1L.(`'1 Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes 0 No Subsequent Form Required: [0--1 3'7WO* oHR i i+li APPROVED BY I [� Approved by: COMMISSIONER THE COMMISSION Date: `, IG.iN 3 - _ , ,� � 3-t�¢r% (k�� Submit Form and '.J'' Form 10-403 Revised 4/2017 Appro a p'cation is vali or 12 months from the date of approval. Attachments in Duplicate 11)1 • • • • III Well Prognosis Well: SRU 23-22 iLiIcorp Alaska,LL' Date:3/12/18 Well Name: SRU 23-22 API Number: 50-133-10150-01-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: April 15, 2018 Rig: KT#1 Work Platform Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-017 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (M) AFE Number: Current Bottom Hole Pressure: —2,251 psi @ 5,199' TVD (Based on 0.433 psi/ft to TVD) Max. Potential Surface Pressure: — 1,731 psi (Based on 0.1 psi/ft gas gradient to surface) Brief Well Summary SRU 23-22 was drilled in 1960 as a Hemlock producer and remained active until 1984. It was placed as a top of structure well in the central fault block. It produced a total of 1.3MMBO &5.2BCF of gas. The Hemlock was abandoned and in 1997 Tyonek gas targets were perforated without success. The purpose of this sundry is to permanently plug and abandon the well. ✓ (-4 t.ti .•,. liik r(L--- P1 fu„. Kr Current Condition ]" y+-i`' e_1,04,.•.- 1-0 u-0 4-b x i e,,ti <s V[ 1� fl-Y- P ,co:�, "`"--- Slick line was placed on the well on December 13, 2017 to see if a plug could be set in the X nipple at 5,160'. Slick line set down on fill at 2,398'. Bailer was ran and fill bailed to 2,503' where progress stopped. Slickline was rigged down while waiting on a plan forward. —re d'fr i 6. On March 2, 2018 slickline was again rigged up on this well to bail fill. Fill was bailed from 2,480'to 3,337' 4-°� 7 where progress ceased. The fill is hard packed and unable for any gas pressure to move up through it. Slickline was rigged off the well on March 8, 2018. Hilcorp proposes that a CIBP be set inside of the tubing at+/- 3,300'with 35' of cement bailed on top (TOC= 3,265'). The tubing will then be cut off above the TOC and the surface casing plug set as determined by the cement bond log as described in the procedure below. 6 In support of this work, Hilcorp requests a waiver from 20 AAC 25.112 (c)(1)(E) and 43 CFR3162.3-42 (i) [BLM] n"I' which refer to setting the tubing isolation plug within a certain distance to the top perforation. The isolation kVplug/TOC in this well will be 1,889' and the packer 107' above the top perforation. The packer will be pressure tested to insure that it is competent (Step#2). „j/tA Pre- Rig Work 1. Provide 24-hr notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112.(h). 2. Pressure test the 2-3/8" X 7" annulus to 1,500 psi for 30 min. (on chart). "° 3. RU E-line. Pressure test lubricator to 1,500 psi. a. RIH W/2-3/8" CIBP and set at 3,300' (+/-). • Well Prognosis Well: SRU 23-22 IIilcora Alaska,LLi Date:3/12/18 b. PU RIH with bailer and dump bail 35' of cemnt on top of the CIBP. (TOC @ 3,265'). WOC. c. RIH and Tag TOC. Record depth. rf.mss_ "1?s SQL � /.cls d. PU Jet cutter, RIH and cut 2-3/8"tubing at 3,200' (+/-) in the middle of a joint. e. POOH. RD E-line. Rig Procedures 1. MIRU KT#1 Work Platform and rig equipment. K 2. Pump 9.0 PPG water down the annulus and circulate up tubing. Bleed all pressures to zero. 3. Set BPV. ND Tree. 4. NU BOPE, pull BPV and set TWC. .�e``' 5. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Lowsi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Notify AOGCC and BLM 24 hrs in advance of BOP test. c. Test VBR rams on 2-3/8" test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 6. L/D BOP test equipment, pull TWC. 7. Check pressures, if not balanced and dead, circulate well with 9.0 PPG water. Bleed all pressures to zero. a. Pull tubing string (2-3/8" 8RD) and lay down. 8. RU E-line. PU, RIH with CBL and log from 3,200' (+/-)to surface looking for Top of Cement. 9. PU RIH W/CIBP and Set @ 3,110 feet (+/-). Pressure test same to 1,500 psi. (on chart). 10. Proceed with P&A based on TOC (from CBL) by setting the following plugs: Option 1 If the CBL determines that there is cement behind the 7" to surface then cement plugs will be placed as follows: (t A) a. A cement plug will be placed on top of the CIBP @ 3,110' up to 2,900' using 15.8#/ gal. cement. b. A second CIBP will be placed @ 160'. 15.8#/gal. cement will be placed on the CIBP to surface. Option 2 If the CBL determines that there is cement present behind the 7" casing up past the 13-3/8" surface casing shoe ( 3,000'), but not up to 160' from surface,then cement and plugs will be placed as follows: a. A cement plug from the top of the CIBP at 3,110' up to 2,900'. b. A CIBP will be set at 160'. Holes will be punched in the 7" casing at 150' and cement circulated down the 7" X 13-3/8" annulus,through the holes punched in the 7" and up the 7" casing to surface. • Well Prognosis Well: SRU 23-22 Hilcorp Alaska,LL$ / Date:3/12/18 (! Option 3 If the CBL determines that there is not cement present behind the 7" casing, up past the 13-3/8" surface casing shoe (3,000'), then cement and plugs will be placed as follows: a. Holes will be punched in the 7" casing 100' below the Surface casing shoe (3,100' to 3,104'). The back side will be open and a pump in rate (PIR) established to see if there is circulation back to surface. b. If there is sufficient circulation to surface, then Hilcorp will circulate cement down the backside, through the casing punches, and up the 7" casing to surface. c. If there is no circulation to surface, then additional casing punches will be shot 75' above the surface casing shoe (2,925'—2,929'). A test packer will be ran and set on tubing at 3,100' and a PIR performed to see if circulation can be established from the holes below the surface casing shoe to the holes above the surface casing shoe. i. If circulation is established of a sufficient rate,then the test packer will be pulled and a cement retainer ran to 3,100 feet and set. A suicide squeeze will be performed to squeeze cement across the surface casing shoe. Go to step 10. (d). ii. If no circulation can be established, then the test packer will be pulled, a braden head squeeze will be utilized to squeeze cement behind the 7" casing and isolate the surface casing shoe. 1. Cement will be spotted on the CIBP @ 3,110' up to 2,700'. Pressure will then be applied to the 7" casing to squeeze the cement through the casing punches into the 7"X 13-3/8" annulus. WOC. iii. RIH and tag TOC to insure it is above 2,900' (if not, place a second plug of cement to bring the level up to this point. b k d. A CIBP will be set at 160'. Holes will be punched in the 7" casing at 150' and cement circulated down the 7" X 11-3/4" annulus,through the holes punched in c' the 7" and up the 7" casing to surface. 11. Clean and Clear Rig Floor. Flush all surfaces and lines and clean pits. 12. ND BOPE, NU Dry hole tree. 13. RD KT#1 Work Platform and move off location. Post—Rig Abandonment Procedures: 1 1. Excavate cellar, cut off casing 3' below natural GL. `� L 2. Notify AOGCC and BLM 48hrs in advance. K.5( 3. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10.The following must be bead-welded directly to the marker plate: .5.04 Lk a. Hilcorp Alaska, LLC b. PTD: 160-017 c. Well Name: SRU 23-22 d. API: 50-133-10150-01 4. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. • Well Prognosis Well: SRU 23-22 Hilcorp Alaska,LLQ Date: 3/12/18 a. Photo document casing cut-off and Welded Plate install with reference to original grade in photo. 5. Backfill excavation, close out location. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Diagram 5. Rig Workover Change Form S II SCHEMATIC Swanson •River Field Well# SRU 23-22 Hileorp Alaska,LTA: Actual Completion 11/2/96 RKB to TBG Head=20.00' CASING AND TUBING DETAIL Tree connection: TC-3 Uni-bolt SIZE WT GRADE CONN TOP BOTTOM c / 1 22" Surf 28' M T L m . 13-3/8"54.5 J-55 Surf 3000' 7" 29 P-110 8rd LT&C Surf 36' Top 7" 26 P-110 8rd LT&C 36' 1812' of Fill 3,3372 7" 29 N-80 8rd LT&C 1812' 3159' 3/6/187" 26 N-80 8rd LT&C 3159' 6560' 7" 29 N-80 8rd LT&C 6560' 8066' C , 7" 26 P-110 8rd LT&C 8066' 9771' M r 3�---- 7" 29 P-110 8rd LT&C 9771' 11594' F%``' l✓ �:: /fr-. 4 Tubing: .7"/./:. 6 2-3/8" 4.6 N-80 Buttress Surf 5,160' El with 3/8" SS methanol injection line Surf 2,487' 1000 sx pumped JEWELRY DETAIL above NO. Depth Item DV @ 7197' 5/97 Perfs 20.00 2-7/8"Tbg hgr w/Cameron"H"BPV profile No bond log _, N 1 20.60 2-7/8"x2-3/8"buttress xover L 2 2487 Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve 3 5032 Macco 2-3/8"D-SO glm w/1"dummy Tbg cut @ 4 5082 Baker FH Retr. pkr,2-3/8"x 7"26# 10/21/96 Calc Highest 5 5127 X nipple,min. ID= 1.875" TOC in 6 5160 Tbg tail(shear out sub) Annulus @ 8970' 7a 9215 Baker cmt retainer in 2-7/8"tubing C �:.... 7a TOC in 7b 9520 Baker cmt retainer in tubing e Tubing @ 8 9533 Camco Mandrel#8 w/dummy m ' 9158' LM 9 11,072 Camco Mandrel#9 w/dummy e � ' 7b W n ?iiii 10/11/95 10 11,126 Brown packer,HS-16-1 t 8 11 11,193 Camco D nipple iiii 12 11,255 Bottom of tubing tail 9 X 10 • mill1 PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 5189 5199 Tyonek 51-9 6 9/12/97 12 6235 6244 Tyonek 55-4 4 4/30/97 6267 6272 Tyonek 61-8 4 5/3/97 6277 6284 Tyonek 61-8 4 4/28-30/97 L 9507 9510 tbg holes 4 10/95 For Hemlock P&A PBTD=9,215' TD=11,614' 11208 11216 Hemlock 4 Abdnd 10/95 MAX HOLE ANGLE=24°,KOP @ 3000' 11226 11254 Hemlock 4 Abdnd 10/95 SRU 23-22 Schematic 03-07-18 REVISED:03-07-18 by DMA PROPOSED •Swanson River Field SCHEMATIC Well#SRU 23-22 Hi kart)Alaska,LLC Actual Completion 11/2/96 RKB to TBG Head=20.00' CASING AND TUBING DETAIL Tree connection: TC-3 Uni-bolt SIZE WT GRADE CONN TOP BOTTOM ciii c d( /✓ L 22" Surf 28' T Z M13-3/8"54.5 J-55 Surf 3,000' 7" 29 P-110 8rd LT&C Surf 36' 7" 26 P-110 8rd LT&C 36' 1,812' 7" 29 N-80 8rd LT&C 1812' 3,159' 7" 26 N-80 8rd LT&C 3159' 6,560' . 'C ,, ' '^ *4 Y• 7" 29 N-80 8rd LT&C 6560' 8,066' M = - =` 2 7" 26 P-110 8rd LT&C 8066' 9,771' Top Fill of T 2a 7" 29 P-110 8rd LT&C 9771' 11,594' 3,337 3/6/18 1, t _ X Tubing: 2-3/8" 4.6 N-80 Buttress ±5,090' 5,160' Cl 1000 sx 6TOC(n 6,195' pumpedJEWELRY DETAIL above El NO. Depth(ft) ItemLi \ DV @ 7,197' 5/97 Perfs 1 ±160' CIBP w/ 160' cement TOC=Surface ( 7 K IS '(t$`, No bond log - L , 2 ±3,180' CIBP w/400' cement TOC above 2,900' 2a ±3,300' CIBP w/35' cement TOC @±3,265' 3 5,082 Baker FH Retr.pkr,2-3/8"x 7"26# 4 5,127 X nipple,min. ID= 1.875" Tbg cut @ 5 5,160 Tbg tail(shear out sub) 8,500', 10/21/96 Calc Highest 6 6,220 Vented Plug TOC in 7a 9,215 Baker cmt retainer in 2-7/8"tubing Annulus @ 7b 9,520 Baker cmt retainer in tubing C 7a 8970' 8 9,533 Camco Mandrel#8 w/dummy :1TOC in 9 11,072 Camco Mandrel#9 w/dummy e Tubing @ 10 11,126 Brown packer,HS-16-1 e 7b 9,158'WLM 11 11,193 Camco D nipple n I ` 10/11/95 12 11,255 Bottom of tubing tail t 8 Iliiii 9 1!: : 10 11 PERFORATION DATA li[11, DII! X ii 1 TOP BTM ZONE SPF DATE COMMENTS 5,189 5,199 Tyonek 51-9 6 9/12/97-Reperf4/14/12 12 6,235 6,244 Tyonek 55-4 4 4/30/97 Isolated 4/9/12 6,267 6,272 Tyonek 61-8 4 5/3/97 Isolated 4/9/12 ' s ' '- 6,277 6,284 Tyonek 61-8 4 4/28-30/97 Isolated 4/9/12 9,507 9,510 Tbg holes 4 10/95 For Hemlock P&A Isolated 4/9/12 n .W J'-'44k4, 11,208 11,216 Hemlock 4 Abdnd 10/95 PBTD=9,215' TD=11,614' 11,226 11,254 Hemlock 4 Abdnd 10/95 MAX HOLE ANGLE=24°,KOP @ 3,000' Updated by DMA 03-08-18 • • HILCORP ALASKA 7-1/16" 5M BOPE ( 7-1/16" 5M HYDRIL GK ANNULAR 32"TALL, FLANGE TO FLANGE f • ( / \ 7-1/16" 5M LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM f / 26-3/4"TALL, FLANGE TO FLANGE 7-1/16" 5M DRILLING SPOOL ® W/2-1/16" 5M OUTLETS Rft"m 18"TALL, FLANGE TO FLANGE —77"TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: -3.30 gallon open chamber volume -3.86 gallon close chamber volume GATE STYLE BOP SPECS: - 1.45 gallons to close per gate - 1.18 gallons to open per gate -5.45:1 closing ratio - 1.93:1 opening ratio • • • 111 Swanson River SRU 23-22 IIiir.rp A,,,,t:.,MA: 05/18/2017 Swanson River Tubing hanger,Shaffer T55- SRU 23-22 A10,7 X 2 7/8 BTC lift and 133/8X7 X23/8 susp,w/2 SiTypeH BPV profile,3/8 control line,PN: 421810 BHTA,8-15-A, 2 9/16 5M FE ( 1H- MANI IF n . Valve swab,WKM-L, te#3:11 2 9/16 5M FE,HWO,AA .. Cross,stdd,2 9/16 5M X ' 2 1/16 5M 1 Valve upper master,WKM-L, ?ilk)` 2 9/16 5M FE,HWO,AA ��, Valve lower masterk., WKM-L,2 9/16 SM FE,HWO, •fl Adapter,Shaffer-AJO, AA Iib. 7 1/16 SM stdd X 2 9/16 SM, opt control line port .—Tubing head,Shaffer _ 7 1r ...__T55-Ll,13 5/8 3M X �' , I "r7 1/16 5M w/2-2 1/16 5M III - Valve,WKM-M,21/165M SSO,7"Type 1 secondary , 11111! FE,HWO,AA trim seal in head �4 - 1r, ° 4 Qty 2 0.11411111111•• ®U • o I tit II Casing head,Shaffer KD, III i i t I I Valve,plug,Rockwell,2" 13 5/8 3M X 13 3/8 SOW, lv LPO, w/2-2"LPO,7"KD slips MI ) , iinall 1 1. IM and packoff assy in head . ] . • et aCI / > W = 2 & Q 7,3 e 2E % o § / k °/ 2a§ / « E § t ) ƒ § i �� 'c fE O. « Ts 0 mo 2 co / � co >.' > = .._< a. � .§ Q_ / E C a) n ■ 2 e 2 2 .1.), a G c 2 � Cl c o c0 Ce 0 B § / C a / § O (.11 \ ai N CI M. N � 9 u) Q . k0 a) 2 / / JL. (pc < .c L- E § % a n ® ) 0 ' k o a. / / a) . L.a) % E c I�k 2 § f / co m _ c w0 c w > 2 / Ii &d 0. «CL / / 0 ■ k 0 a) o 0 » a) ct & 9 m c ® d o c q c � a) 0 x % k a .. ® _ .. o - » ¢ 4' / 0 & / k 1 c >,O Cu E 0 2 2 \ 9a. ► D4 DI o 0 z Z_ N D4►1 a J n L<1, M ka .1 Y 2 2 o v U 3 < I .i W 1131'4-) ce>0_, .< r ii' V 111 i� = 1 � � • Y 411 VA 11 a° A •.- .- ' VA. 4„ ire , Z Q H a) C J N li LL 0 A 0 '^ -- 0 VJ OJ Z 2 Li_ 0 D It W CK U' 0 W a. Q z0 1,7 < LIJ CC2 a. Dz Qom V O . IulI� 2 101 Z • • x o0 Thousand Cubic Feet of Gas ("MCF") per Month c; o 0 0 or Gas-Oil Ratio 0 O O O coo m O O O 0 0 O OO 0 O 1 O O O 0 O 0 0 N .-1 .i .4 N .-1 ei .i ,4 m I 1 1 ) oo N I. t I Pr o I N t-y o 0 r a tDl lll Se co cn -- sr O - o v 1 Pr 1 O E 3 Tu- _ 11 (7 F o v1 CO Na -_-_ - °6" c3 0 C1 P c 0 N 1 ID N ( ° J ��; . S8 w Z O j --- - 4PP I Y � I °I f' _ !ti Q C r - LL CO41 . .r _ a J ° oc °` Q 9 ' LJJ O • 4 08et- v Z M II - Y.. • p � � I I 1 - `Pr ° O r Z LJJ 0. O 44:a� 9 a il. z 9� II-9" `Q N.,....., .:4,8I11 t a S Z o o• . s 4PVq PO 1a �° ° 0° 7 p a 4 •o Z rV Q I QJ 4, ® • o o N o <et 0 't• il„, it, Y ".; 'co E �� ; 1— J M III;Mr_ 0 .43° s. 2 So _ ,. __. _ o + _ O ° t V O ° m ° i 4td ° 4 0 0 0 a j H 96t, v _ 4P ' I � o 3 0 V I a 1111 • - sS o o 0 o 0. O- 1. 1 6r 4Pt O O 0 0 e-t O O O .i O 0 .-1 O --1 .-1 i uo j .lad JaleM to siaiae8 ,io gluoiAl Jad no to suing . . Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, March 21, 2018 10:54 AM To: Schwartz, Guy L(DOA) Subject: RE: Sundry for SRU 23-22 P&A - PTD 160 -017, Sundry#317-568 Attachments: KT1 Engineered Drawings.docx; KT#1 Flow diagram v13-21-18.pdf; KT#1 Choke manifold drawing.docx Follow Up Flag: Follow up Flag Status: Flagged Guy, Attached are three files. The first file is the engineered drawings from when Chevron built the work platform. The second file is the fluid flow diagram which is not much different than the Moncla 401 flow diagram. Really,the components do not change much other than the rig is not there. The third file is the drawing of the choke manifold we plan to use. We are in the process of performing a mockup,assembling the work platform in Swanson River field next to the welding shop so that we can take measurements and insure that this will work as intended. As far as pulling tubing with the crane the answer is yes when the weight of the tubing is light enough that it can be easily handled by the crane. We are examining the possibility of using our casing jacks to unseat hangers and for pulling heavier hook loads until the weight decreases to within working limits of the crane. The casing jacks in this scenario will sit on top of the BOP stack and the weight will be transferred down through the BOP to the well head. I hope this helps, please let me know any other questions you might have. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Wednesday, March 21, 2018 9:23 AM To:Ted Kramer<tkramer@hilcorp.com> Subject: RE:Sundry for SRU 23-22 P&A-PTD 160-017,Sundry#317-568 1 • • Ted, I see this is the Work platform now... do you have any drawings of how this is set up...fluid handling etc? Will be using crane to pull tubing? 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.gov). From:Schwartz,Guy L(DOA) Sent:Wednesday, March 21, 2018 9:02 AM To: 'Ted Kramer'<tkramer@hilcorp.com> Cc:samantha.carlisle@alaska.gov Subject: RE:Sundry for SRU 23-22 P&A-PTD 160-017,Sundry#317-568 Ted, Thanks for the email explanation. AOGCC will cancel sundry 317-568 as requested and process the new sundry for the work as requested below. 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.gov). From:Ted Kramer<tkramer@hilcorp.com> Sent:Wednesday, March 14, 2018 11:03 AM To:Schwartz,Guy L(DOA)<guv.schwartz@alaska.gov> Subject:Sundry for SRU 23-22 P&A- PTD 160-017,Sundry#317-568 Guy, Hilcorp sent over a Sundry application yesterday afternoon for the above well. The intent is to cancel the above Sundry 317-568 and replace it with this new Sundry application. The reason for the replacement is that there was some inaccurate information discovered that needed to be corrected, namely, I had mistakenly thought that we had placed a PX plug in the X-nipple at 5,127'during our TA program with BLM. That had not in fact happened, I had this well confused with a well with a similar well number. 2 • • w Hilcorp put slickline on this well to confirm that the plug was there, and found fill in the tubing that we were unable to bail out. Therefore, I am requesting a waiver to place a plug in the tubing on top of the fill and place 35'of cement on top of that. Sorry for the confusion, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 3 • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 21, 2018 9:02 AM To: Ted Kramer Cc: Carlisle, Samantha J (DOA) Subject: RE: Sundry for SRU 23-22 P&A - PTD 160 -017, Sundry#317-568 Ted, Thanks for the email explanation. AOGCC will cancel sundry 317-568 as requested and process the new sundry for the work as requested below. Guy Schwartz Sr. Petroleum Engineer AR 1 1 2018 AOGCC 907-301-4533 cell RBDMSt01 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.schwarfz@alaska.gov). From:Ted Kramer<tkramer@hilcorp.com> Sent:Wednesday, March 14, 2018 11:03 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject:Sundry for SRU 23-22 P&A- PTD 160-017,Sundry#317-568 Guy, Hilcorp sent over a Sundry application yesterday afternoon for the above well. The intent is to cancel the above Sundry 317-568 and replace it with this new Sundry application. The reason for the replacement is that there was some inaccurate information discovered that needed to be corrected, namely, I had mistakenly thought that we had placed a PX plug in the X-nipple at 5,127' during our TA program with BLM. That had not in fact happened, I had this well confused with a well with a similar well number. Hilcorp put slickline on this well to confirm that the plug was there, and found fill in the tubing that we were unable to bail out. Therefore, I am requesting a waiver to place a plug in the tubing on top of the fill and place 35'of cement on top of that. Sorry for the confusion, SOWED ; Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1 of Tb THE STATE • S Alaska Oil and Gas ®f Conservation Commission x �. 333 West Seventh Avenue , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ain: 907.279.1433 ALA6�� MFax: 907.276.7542 March 6, 2018 www.aogcc.alaska.gov Certified Return Receipt 7015 0640 0003 5185 5857 Mr. David Wilkins Senior Vice President Alaska Hilcorp Alaska, LLC 3800 Centerpoint Drive, Ste 1400 %AHMED Anchorage, AK 99503 Re: Docket No: OTH-18-014 Plugging and Abandonment of Cook Inlet State 17589-1A (PTD No. 162-028) Plugging and Abandonment of Swanson River Unit 23-22 PTD No. 160-017D- Dear Mr. Wilkins: By letter dated January 22,2018,Hilcorp Alaska,LLC (Hilcorp)requested that the Alaska Oil and Gas Conservation Commission(AOGCC) allow the plugging and abandonment operations of the Cook Inlet State 17589-1A (PTD No. 162-028) to be included with the OCS exploration drilling program planned in 2020 utilizing a jackup rig. As proposed, abandonment would be completed by December 31, 2020. Sundry application(Sundry No. 315-165)granted March 23,2015 approved continued suspension status of Cook Inlet State 17589-1A until December 31, 2018. The well is located on State of Alaska oil and gas lease ADL 17589 which Hilcorp, as current owner and operator, acquired on November 1, 2016. Hilcorp proposes to substitute the Swanson River Unit (SRU)23-22 well (PTD No. 160-017) for plugging and abandonment in lieu of Cook Inlet State 17589-1A. Operations for the plugging and abandonment of SRU 23-22 would be completed by December 31, 2018. AOGCC approves Hilcorp's request to delay plugging and abandonment of Cook Inlet State 17589-1A, with plugging and abandonment to be completed by November 1, 2020. An Application for Sundry Approvals for the procedure shall be submitted to the AOGCC no later than January 10, 2020. Docket No: 011-1-18-014 • • March 6,2018 Page 2 of 2 An Application for Sundry Approvals for the plugging and abandonment of SRU 23-22 shall be submitted to the AOGCC by July 1, 2018. Abandonment of SRU 23-22 shall be completed by December 31,2018. Sincerely, Hollis S. French Chair, Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which vase the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • Post Office Box 244027 Anchorage,AK 99524-4027 113800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Hilcorp Alaska, LLC Phone:907/777-8300 Fax::907/777-8301 January 22, 2018 RECEIVED Hollis French, Chair JAN 3 0 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue AOGCC Anchorage,Alaska 99501 Re: Substitute P&A Well for Cook Inlet State 17589 lA Dear Chair French: Pursuant to a Purchase and Sale Agreement between ConocoPhillips Company, ConocoPhillips Alaska, Inc. ("CPAI"), and Phillips Gas Supply Corporation, as Sellers, and Hilcorp Alaska, LLC, and Harvest Alaska, LLC, as Buyers, Hilcorp Alaska, LLC ("Hilcorp Alaska") became the operator of the North Cook Inlet Unit ("NCIU") and associated leases, including DNR Lease ADL 17589 on November 1, 2016. Part of the acquisition included the suspended subsea well Cook Inlet State 17589 1A,API 50883100130000 (the "Well"). The AOGCC had previously established a deadline of December 31,2018,for CPAI to plug and abandon the Well as communicated by AOGCC to CPAI in AOGCC Sundry 315-165 dated March 25, 2015 and signed by Commissioner and then-Chair Foerster. Hilcorp Alaska has been developing a plan to complete the P&A in the allotted time using a Jackup mobile offshore drilling unit ("Jackup MODU"). While we have not yet identified and procured the Jackup MODU,we have prepared an initial cost estimate and base procedure for the P&A of the Well. On October 1, 2017, the Bureau of Ocean Energy Management ("BOEM") awarded Hilcorp Alaska 14 leases("OCS Leases")located in the Outer Continental Shelf("OCS") Cook Inlet on June 21,2017. OCS Sale 244-Lower 1n Lower Cook Inlet, as the result of Following the award of the OCS Leases, Hilcorp Alaska began developing a full season program to more effectively utilize a Jackup MODU. The program will include drilling one or more wells in prospects identified on the OCS Leases. The identification of well bottom hole locations will follow gradiometry and seismic surveys. Long lead permits are a key component to determining the timing to begin the execution of this program. The gradiometry survey will be flown this spring. However, the permitting for the seismic survey will require much more additional time. For instance, it will take approximately nine months to obtain the Incidental Harassment Authorization (IHA)which protects endangered marine mammals such as the Cook Inlet Beluga whales. This is insufficient time to allow our planned seismic program to be performed in 2018 and thus it will be delayed until 2019. The data from the seismic program will be utilized Chair Hollis French • • January 22,2018 Page 2 of 2 to generate the drilling location(s) for the Jackup MODU during the drilling program which is now projected to be undertaken in 2020. Accordingly,Hilcorp Alaska requests approval from the AOGCC to allow the P&A of the Well to be included with the OCS exploration drilling program in 2020,with the deadline for P&A of the Well set at December 31,2020. Hilcorp Alaska understands the importance of AOGCC's focus on plugging and abandoning idle wells. With this understanding, Hilcorp Alaska proposes to substitute an idle well for plugging and abandonment in 2018. The proposed well is SRU 23-22, API 501331015001 /PTD 1600170 in the Swanson River Field("SRF"). This well is not on a list of wells that has been discussed with the AOGCC for P&A. We propose to develop a P&A procedure for SRU 23-22 and submit a sundry for that project to the AOGCC. Hilcorp Alaska is preparing a plan to P&A onshore Kenai Peninsula wells in 2018. We propose to add SRU 23-22 to this list with the P&A of the well to be completed by December 31, 2018. Please contact the Project Lead, Paul Mazzolini, at 777-8369 to discuss the project or answer questions the AOGCC may have. Sincerely, HILCORP ALASKA, LLC David ilkins Senior Vice President Alaska VF' Tit • „i)** 1/7, s� THE STATE Alaska Oil and Gas ti�:► ---�-�►a� SKA,. Conservation Commission 333 West Seventh Avenue ier STM, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 P. Main: ALA9* Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager ��E Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Tyonek Gas Pool, SRU 23-22 Permit to Drill Number: 160-017 • Sundry Number: 317-568 Dear Mr. Helgeson: 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. 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, E-(0) Hollis S. French Chair DATED this day of December, 2017. Er--r.py 1 Pr,..e> RECEIVED 0 0 rD EC 0 5 2a1/ STATE OF ALASKA _'S,r12 Th / ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC 7 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon Q • Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q • 160-017 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-133-10150-01-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Swanson River Unit(SRU)23-22 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River/Tyonek Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,614' • 11,235' ` 9,042' 8,841' -1,731 psi 9,042'&11,614' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730psi 1,130psi Intermediate Production 11,594' 7" 11,594' 11,594' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/N-80 11,255' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Brown HS-16-1;N/A 11,126'MD/11,125'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch / Exploratory ❑ Stratigraphic 0 Development ❑✓ Service 0 14. Estimated Date for 15.Well Status after proposed work: December 13,2017 Commencing Operations: OIL 0 WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ,7!, A WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: ; t Iy.i' GINJ 0 Op Shutdown ❑ Abandoned Q • 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkrameKcahilcorp.com ey Contact Phone: 777-8420 Authorized Signature: / Date: J 7451/7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \ 1 . 5140, g Plug Integrity 1 BOP Test l Mechanical Integrity Test 0 Location Clearance 0 Other: *. 3 eleo r 5 4.) 14 . 7:73 t--" A. yL. /L` '� 1 / / Ac.4.11'.sa� fi'/11�o�ir Y` G.e1 �`Z.. .4A .Z.4..7 . //t.( f) Post Initial Injection MIT Req'd? Yes 0 No 0 ��/ // Spacing Exception Required? Yes 0 No d Subsequent Form Required: / 0 —4i 6 Ra::::::-) [[" f & 2.317 6:22f ,. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (-2- I 1 14 Submit Form and 1 1 Form 10-403 Revised 4/2017 ApprO1 li�6114�l ont from the date of approval. A achmen in Duplicate N VVVVVV �� • • Well Prognosis Well: SRU 23-22 Hilcorp Alaska,LLQ Date:12/5/17 Well Name: SRU 23-22 API Number: 50-133-10150-01-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: December 13, 2017 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-017 First Call Engineer: Ted Kramer (907)777-8420(0) (985) 867-0665 (M) Ted Kramer (907) 777-8420 (0) (985)867-0665 (M) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,251 psi @ 5,199' TVD (Based on 0.433 psi/ft to TVD) Max. Potential Surface Pressure: — 1,731 psi (Based on 0.1 psi/ft gas gradient to surface) Brief Well Summary SRU 23-22 was drilled in 1960 as a Hemlock producer and remained active until 1984. It was ideally placed as a top of structure well in the central fault block. It produced a total of 1.3MMBO& 5.2BCF of gas. The Hemlock was abandoned and in 1997 Tyonek gas targets were perforated without success. V The purpose of this sundry is to permanently plug and abandon the well. Current Condition PX Plug set in X-nipple at 5,127'. Tubing and casing were pressure tested to 1,500 psi in August 2017. Hilcorp requests a waiver from 20 AAC 25.112 (c)(1)(E) and 43 CFR3162.3-42 (i) [BLM] which refer to setting the plug within a certain distance to the top perforation. The isolation plug/ packer(lowest) in this well will be 107' above the top perforation. Pre- Rig Work 1. Provide 24-hr notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112.(h). /'2-�r 1-6 d € k C 54a e,444 2. RU E-line. Pressure test lubricator to 1,500 psi. a. RIH with bailer and dump bail 50'of cement on top of plug at 5,127' (TOC @ 5,077'). "` `' b. PU Jet cutter, RIH and cut 2-3/8" tubing at 3,200' (+/-) in the middle of a joint. c. POOH. RD E-line. Rig Procedures 1. MIRU Moncla #401 WO Rig. 2. Pump PW(8.4 ppg) down the annulus and bleed the tubing to zero to kill the well. 3. Set BPV. ND Tree. 4. NU BOPE, pull BPV and set TWC. 5. Test BOPE to 250 psi Low/3,000 psi High,annular to 250 psi Low/2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. • • • Well Prognosis Well: SRU 23-22 Hilcorp Alaska,LU Date: 12/5/17 a. Perform Test. b. Notify AOGCC and BLM 24 hrs in advance of BOP test. c. Test VBR rams on 2-3/8"test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 6. L/D BOP test equipment, pull TWC. 7. Circulate well with produced water to ensure well is dead. a. Pull tubing string (2-3/8" 8RD) and rack back. 8. RU E-line. PU, RIH with CBL and log from 3,200' to surface looking for Top of Cement. 9. Proceed with P&A based on TOC (from CBL) by setting the following plugs: a. Set CIBP @ 3,200 feet (+/-). Pressure test plug and casing to 1500 psi. b. PU, RIH with 2-3/8"tubing. Place cement on top of CIBP up to 2,800' (+/-),across the surface casing shoe. Pooh W/Tubing. c. PU RIH W/CIBP and set at 160'. Pressure test same to 1,500 psi. d. RIH W/tbg and spot cement plug from CIBP to surface. Note: If CBL determines that TOC behind the 7" casing is not high enough to cover the 13-3/8" surface casing shoe with good cement,then some adjustments to the P&A plan will be made. AOGCC and BLM will be notified and a mutually agreeable plan will be arrived at. 10. Clean and Clear Rig Floor. Flush all surfaces and lines and clean pits. 11. ND BOPE, NU Dry hole tree. 12. RD Moncla#401 and Move off site. Post—Rig Abandonment Procedures: 1. Excavate cellar, cut off casing 3' below natural GL.• 2. Notify AOGCC and BLM 48hrs in advance. 3. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10.The k1V following must be bead-welded directly to the marker plate: \ ?Za. Hilcorp Alaska, LLC �� b. PTD: 160-017 c. Well Name: SRU 23-22 d. API: 50-133-10150-01 4. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. a. Photo document casing cut-off and Welded Plate install with reference to original grade in photo. 5. Backfill excavation, close out location. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Diagram 5. Rig Workover Change Form II III 111 Swanson River Field Well# SRU 23-22 Hilcorp Alaska,LU. Actual Completion 11/2/96 RKB to TBG Head=20.00' CASING AND TUBING DETAIL Tree connection: TC-3 Uni colt SIZE WT GRADE CONN TOP BOTTOM C mm I 22" Surf 28' T Lt \ 13-3/8"54.5 J-55 Surf 3,000' 7" 29 P-110 8rd LT&C Surf 36' 7" 26 P-110 8rd LT&C 36' 1,812' — 2 7" 29 N-80 8rd LT&C 1812' 3,159' 7" 26 N-80 8rd LT&C 3159' 6,560' G , 7" 29 N-80 8rd LT&C 6560' 8,066' 7" 26 P-110 8rd LT&C 8066' 9,771' 3 7" 29 P-110 8rd LT&C 9771' 11,594' ��.00- . 4 5 Tubing: 6a 2-3/8" 4.6 N-80 Buttress Surf 5,160' with 3/8" SS methanol injection lineSurf 2,487' 1 TOC @ 6,195' 1000 sx pumped jib JEWELRY DETAIL above I NO. Depth(ft) Item DV @ 7,197' 5/97 Perfs 20.00 2-7/8"Tbg hgr w/Cameron"H"BPV profile No bond log , , 1 20.60 2-7/8"x2-3/8"buttress xover 2 2,487 Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve 3 5,032 Macco 2-3/8"D-SO glm w/1"dummy Tbg cut @ 4 5,082 Baker FH Retr. ph, 2-3/8"x 7"26# 8,500', 10/21/96 Calc Highest 5 5,127nipple,X ni le min.ID= 1.875" TOC in 6a 5,160 Tbg tail(shear out sub) Annulus @ 6b 6,220 Vented Plug C • ;`°; 7a 8970' 7a 9,215 Baker cmt retainer in 2-7/8"tubing ITOC in 7b 9,520 Baker cmt retainer in tubing e Tubing @ 8 9,533 Cameo Mandrel#8 w/dummy e 0 .I 7b 9,158' WLM 9 11,072 Cameo Mandrel#9 w/dummy n ,I 10/11/95 10 11,126 Brown packer,HS-16-1 t 8 11 11,193 Cameo D nipple I I 12 11,255 Bottom of tubing tail 9 ►Z1 € i1110-=111 10 "•" 11 PERFORATION DATA '� TOP BTM ZONE SPF DATE COMMENTS �� 5,189 5,199 Tyonek 51-9 6 9/12/97-Reperf 4/14/12 12 6,235 6,244 Tyonek 55-4 4 4/30/97 Isolated 4/9/12 6,267 6,272 Tyonek 61-8 4 5/3/97 Isolated 4/9/12 6,277 6,284 Tyonek 61-8 4 4/28-30/97 Isolated 4/9/12 '' 9,507 9,510 Tbg holes 4 10/95 For Hemlock P&A ' Isolated 4/9/12 ' '"`' 11,208 11,216 Hemlock 4 Abdnd 10/95 PBTD=9,215' TD=11,614' 11,226 11,254 Hemlock 4 Abdnd 10/95 MAX HOLE ANGLE=24°,KOP @ 3,000' SRU 23-22 Schematic 05.02.2012 REVISED:05/2/2012 by TDF • • 11 PROPOSED Swanson River Field Well# SRU 23-22 Hileorp Alaska,LLC Actual Completion 11/2/96 RKB to TBG Head=20.00' CASING AND TUBING DETAIL Tree connection: TC-3 Uni bolt SIZE WT GRADE CONN TOP BOTTOM M .. __._ _._ L22" Surf 28' T G m 13-3/8"54.5 J-55 Surf 3,000' 7" 29 P-110 8rd LT&C Surf 36' 7" 26 P-110 8rd LT&C 36' 1,812' 7" 29 N-80 8rd LT&C 1812' 3,159' 7" 26 N-80 8rd LT&C 3159' 6,560' ,, 7" 29 N-80 8rd LT&C 6560' 8,066' M = 2 7" 26 P-110 8rd LT&C 8066' 9,771' T 7" 29 P-110 8rd LT&C 9771' 11,594' —w; ►= 3 4-4a . Tubing: 5 IRDS 2-3/8" 4.6 N-80 Buttress ±5,090' 5,160' x1 TOC @ 6,195' 1000 sx ri pumped _ 6 JEWELRY DETAIL above NO. Depth(ft) Item DV @ 7,197' 5/97 Perfs 1 ±160' CIBP w/ 160' cement TOC=Surface No bond log L 2 ±3,200' CIBP w/400' cement on top TOC±2,800' 3 5,082 Baker FH Retr. pkr, 2-3/8"x 7"26# 4 5,127 X nipple,min. ID= 1.875" Tbg cut @ 4a ±5,127' Plug w/50' cement TOC±5,077' 8, cut 5 5,160 Tbg tail(shear out sub) 10/21/96 Calc Highest 6 6,220 Vented Plug TOC in 7a 9,215 Baker cmt retainer in 2-7/8"tubing Annulus @ 7b 9,520 Baker cmt retainer in tubing 8970' 8 9,533 Camco Mandrel#8 w/dummy C 7a TOC in 9 11,072 Camco Mandrel#9 w/dummy e Tubing @ 10 11,126 Brown packer,HS-16-1 e 7b 9,158'WLM 11 11,193 Camco D nipple n 10/11/95 12 11,255 Bottom of tubing tail t t 8 9 x x 10 11 PERFORATION DATA X TOP BTM ZONE SPF DATE COMMENTS 1 2 5,189 5,199 Tyonek 51-9 6 9/12/97-Reperf 4/14/12 16,235 6,244 Tyonek 55-4 4 4/30/97 Isolated 4/9/12 6,267 6,272 Tyonek 61-8 4 5/3/97 Isolated 4/9/12 6,277 6,284 Tyonek 61-8 4 4/28-30/97 Isolated 4/9/12 9,507 9,510 Tbg holes 4 10/95 For Hemlock P&A Isolated 4/9/12 G , 11,208 11,216 Hemlock 4 Abdnd 10/95 PBTD=9,215' TD=11,614' 11,226 11,254 Hemlock 4 Abdnd 10/95 MAX HOLE ANGLE=24°,KOP @ 3,000' REVISED: 11/30/17 by JLL • r HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16" 5M HYDRIL GK ANNULAR 32"TALL, FLANGE TO FLANGE 7-1/16" 5M LWS DBL GATE BOP ottv DRESSED W/VARIABLE RAMS IN TOP ° r!'',1:-VM.../ DRESSED W/BLIND RAMS IN BOTTOM 26-3/4" TALL, FLANGE TO FLANGE 7-1/16" 5M DRILLING SPOOL W/2-1/16" 5M OUTLETS 18" TALL, FLANGE TO FLANGE -77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume -3.86 gallon close chamber volume GATE STYLE BOP SPECS: - 1.45 gallons to close per gate - 1.18 gallons to open per gate - 5.45:1 closing ratio - 1.93:1 opening ratio • Swanson River SRU 23-22 • 11 05/18/2017 Swanson River Tubing hanger,Shaffer T55- SRU 23-22 AJO,7 X 2 7/8 BTC lift and 133/8X7X23/8 susp,w/2'''/Type H BPV profile,3/8 control line,PN: 421810 BHTA,B-15-A, 29/165MFE w.- 1\I 1 ul ilIF Valve swab,WKM-L, 2 9/16 5M FE,HWO,AA -. 'Q , P., SFR Cross,stdd,2 9/16 5M X J 2 1/16 5M Ufil NJ Valve upper master,WKM-L, �1 fi 29/165M FE,HWO,AA ® �. [Valvelio;14 e lower master, WKM-L,2 9/16 5M FE,HWO, Adapter,Shaffer-AJO, AA %i*. 7 1/16 5M stdd X 2 9/16 5M,'A npt control line port M Eq= . Tubing head,Shaffer �{ O 0 } T55-LI,13 5/8 3M X 1 , �U1 Valve,WKM-M,21/16 5M 7 1/16 5M w/2-2 1/16 5M FE,HWO,AA trim SSO,7"Type 1 secondary seal in head - '- 11 ...` 9 Qty 2 1111Wal 1M■ 1V 'll h I R ill 1 [Ill Casing head,Shaffer KD, III i i i/i Valve,plug,Rockwell,2" 13 5/8 3M X 13 3/8 SOW, ? LPO, w/2-2"LPO,7"KD slips ) SIMI1; ..-i... and packoff asst'in headPI 7 • • C a) ,a; d >- cu a) i 0 o0 V R ,c O a N 0 a o.a = a) Q " E - E C -0 oo CN Q i- m w a) = Q C L —ID a) COet CD o> 2 . = ^i __ L _ 0. v Q. 7 0_ 0" co a? L ,D M -0a) a) ra o a) � Z 0 sas R co� 0} r c o Z w O L a) CD �T. C) CI o N 13 F- O. TIS-Q o V N 'a Q O > ca L N o C nm Cl) Z m RI (_) a) 0 a) O a) CD L 0 0 • � z V -D c)) a) L .Q o i a L a) v �' a) m a) c 73 F 2 o) N = r.m i C a m -o > o co 2 o cc co L o Q- L L• d .1 11 ars ° ¢ � > 0a) cti ,- Q.4 o W o X a) = o ca rA Cd Q m ° 3 F- ca Q c crn a) � 0 xX o a) N u R" 0 X ca �' 0 'imp' 0 U >, .. _ u �, o U d Q) x+ ,� Cu 10 E 0 ca o aas ) V n cn Q ° Q a C3 0 0 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 4 202 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well u Perforations Abck3 i� Gas Cons. Co Imis; icn Plug al Perforate 0 Dt er Performed: Alter Casing Pull Tubing ❑ 1 9 ❑ 9 ❑ Stimulate - Frac Waiver Time Extension Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 160.017 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service [] 6. API Number: AK 99503 50- 133 - 10150 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 (Swanson River Facility) Swanson River Unit (SRU) 23 -22 " 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Beluga Undef Gas 11. Present Well Condition Summary: 6,220; 9,215 - Total Depth measured 11,614 feet Plugs measured 11,614 feet true vertical 11,235 feet Junk measured N/A feet Effective Depth measured 6,195 feet Packer measured 11,126 feet true vertical 6,176 feet true vertical 10,794 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13 -3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 11,594' 7" 11,594' 11,228' 7,420 psi 5,410 psi Liner Perforation depth Measured depth 5,189'- 5,199' feet True Vertical depth 5,188' - 5,198' feet Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.6t1/ N -80 5,160' 5,159' Packers and SSSV (type, measured and true vertical depth) Brown HS -16 -1 2 -7/8" x 7" 11,126' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 750 20 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development Q — Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: OiI Ej .. Gas al WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG [] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Stan Golis Printed Name Stan Golis Title Operations Manager Signature 5k— c. , Ili Phone 907 - 777 -8300 Date S /Z /z,p 12— RBDMS MAY 07 i0 . S-7 -/ z-- , Form 10 -404 Revised 11/2011 Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 23 -22: Plug Back / Reperf 50- 133 - 10150 -01 160 -017 4/9/12 4/15/12 Daitj,Operations: 04/09/2012 - Wednesday RU a -line and lubricator. Pressure test lubricator to 250 psi low and 2,500 psi high. RIH with 1- 11/16" Neo basket plug and tied into GR /CCL from 04/28/97. Set plug at 6.220'. POOH. RIH, dumped 1' of ceramic beads at 6,220'. POOH. RIH 4x w/ #17 Neo cement, placed on top of beads. TOC 6,211'. RD lubricator and secured well. 04/11/2012 - Wednesday RU lubricator, pressure test to 250 psi low and 2,500 psi high. Tubing pressure is 0 psi. RIH with 1-3/4" LIB. Top of vent at 6,211'. POOH. Fluid level at 230'. Made 5 runs w/ 1- 11/16 "x50' bailer of Neo 17# cement and dumped on plug. TOC 6,197'. RD lubricator and secured well. 04/12/2012- Thursday Waiting on cement to cure. 04/13/2012 - Friday RU SL. Pressure test lubricator to 250 psi low and 2,500 psi high. Tubing pressure 0 psi, casing 780 psi. RIH with 1 -1/2" GR and tagged TOC at ^'6,195' RKB. POOH. RIH w/ 1.99" OD swab cup and swabbed 15 -3/4 bbls of water from 370' to 3,850'. Well flowed < 1 barrel of water. Made 33 swab runs. RD lubricator and secured well. Tubing pressure 0 psi and casing 780 psi. 04/14/2012 - Saturday Pressure test lubricator to 250 psi low and 2,500 psi high. RIH w/ 1.99 swab cup and swabbed from 3,880' to 5,090'. Tubing pressure 0 psi, casing 750 psi. RD and secured well. RU a -line lubricator and pressure well up to 1,616 psi with field gas for underbalance for perf. Presssure test lubricator to 250 psi low and 2,500 psi high. RIH w/ 1- 11/16 "x10' 6spf, 60 deg, spiral strip gun. Tied into GR /CCL log dated 28- April -97. Spotted perf gun from 5,189' to 5 199'. Fired gun with 1,616 psi on tubing. Tools released in hole. 20' tool left in hole. POOH. RD a -line and secured well. 04/15/2012 - Sunday RU SL and pressure test lubricator to 250 psi low and 2,500 psi high. RIH w/ 1.72" LIB to 6,092' KB. POOH good impression of rope socket. RIH w/ 2" SB to 6,092' KB. Latch pull E -line toolstring. RIH w/ 1.75" DD bailer to 6,102' KB work to 6,125' KB. POOH. FL @ 3,000' KB. RDMO. n • Swanson River Field Well # SRU 23 -22 Hi7corp Alaska, IAA: Actual Completion 11/2/96 RKB to TBG Head = 20.00' CASING AND TUBING DETAIL Tree connection: TC -3 Uni -bolt SIZE WT GRADE CONN TOP BOTTOM C j \ / M ° 1 L 22" Surf 28' T m 13 -3/8" 54.5 J -55 Surf 3,000' 7" 29 P -110 8rd LT &C Surf 36' 7" 26 P -110 8rd LT &C 36' 1,812' .- 2 7" 29 N -80 8rd LT &C 1812' 3,159' 7" 26 N -80 8rd LT &C 3159' 6,560' L C , 7" 29 N -80 8rd LT &C 6560' 8,066' M 7" 26 P -110 8rd LT &C 8066' 9,771' T 3 7" 29 P -110 8rd LT &C 9771' 11,594' g immuf ›S 4 Tubing: 6a s MI 2 -3/8" 4.6 N -80 Buttress Surf 5,160' in 5� 8� with 3/8" SS methanol injection IineSurf 2,487' I TOC (a, 6,195' 1' 1000 S G — 6b pumped JEWELRY DETAIL above NO. Depth(ft) Item DV @ 7,197' 5/97 Perfs 20.00 2 -7/8" Tbg hgr w /Cameron "H" BPV profile No bond log _ 1 20.60 2- 7/8 "x2 -3/8" buttress xover L 2 2,487 Macco 2 -3/8" SMO -1C1 Chem Inj Mdrl w /1000 psi chem inj valve • 3 5,032 Macco 2 -3/8" D -SO glm w /1" dummy Tbg cut @ 4 5,082 Baker FH Retr. pkr, 2 -3/8" x 7" 26# 10/21 //96 Cale Highest 5 5,127 X nipple, min. ID = 1.875" TOC in 6a 5,160 Tbg tail (shear out sub) Annulus @ 6b 6,220 Vented Plug 8970' 7a 9,215 Baker cmt retainer in 2 -7/8" tubing C I 7a I TOC in 7b 9,520 Baker cmt retainer in tubing e Tubing @ 8 9,533 Camco Mandrel #8 w /dummy e I ` ``'' 1 7b 9,158' WLM 9 11,072 Camco Mandrel #9 w /dummy n 10/11/95 10 11,126 Brown packer, HS -16 -1 t 8 I l 11,193 Camco D nipple 12 11,255 Bottom of tubing tail 9 11 PERFORATION DATA LI TOP BTM ZONE SPF DATE COMMENTS X 5,189 5,199 Tyonek 51-9 6 9 /12 /97- Reperf4 /14/12,/ 12 6,235 6,244 Tyonek 55 -4 4 4/30/97 Isolated 4/9/12 6,267 6,272 Tyonek 61 -8 4 5/3/97 Isolated 4/9/12 6,277 6,284 Tyonek 61 -8 4 4/28 -30/97 Isolated 4/9/12 9,507 9,510 Tbg holes 4 10/95 For Hemlock P &A Isolated 4/9/12 L t. 11,208 11,216 Hemlock 4 Abdnd 10/95 PBTD = 9,215' TD = 11,614' 11,226 11,254 Hemlock 4 Abdnd 10/95 MAX HOLE ANGLE = 24 °, KOP @ 3,000' SRU 23 -22 Schematic 05.02.2012 REVISED: 05/2/2012 by TDF . .... e e Chevron === Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com Steve McMains AOGCC 333 W. ih Avenue, Ste. 100 Anchorage, Alaska 99501 I ~6 -' Ö \ 7 RECEIVED MAR 1 6 2006 Alaska Oil & Gas Cons C '. . omm,ss,on Anchorage March 16, 2006 Re: SRU 23-22 Outstanding Sundry Dear Mr. McMains, This letter is intended to update the Alaska Oil and Gas Conservation Commission on work that was done on the Swanson River well SRU 23-22 and not correctly filed with the agency. In October, 1996, Unocal filed a 403 pre-job filing (#396-206), addressing the planned isolation of the Hemlock and the recompletion of SRU 23-22 in the 61-8 Tyonek sand. A post filing, 407, was submitted addressing the isolation portion of the work. Attached is an additional 407, referencing the same 403 (#396-206), addressing the perforations in the 61-8 sand. At that time, additional perfs were added to the Tyonek 55-4 and 51-9 sands. These sands were not addressed in the initial filing sent to your office, but are addressed in this updated post filing. This also identities the current completion of the well bore. If you have any questions or concerns, please contact me at 907-263-7657. Sincerely, 2-9c Timothy C. Brandenburg Drilling Manager (""~-!..;; if~\;¡'.:,!ji;'ir: v\ô;¡,l~"",,,..\..i.;···' Attachment Cc: SRU 23-22 Well file ,," .. TB:sk Union Oil Company of California / A Chevron Company http://www.chevron.com ....:, . . STATE OF ALASKA _ ALA~OILAND GAS CONSERVATION COMM_ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil0 GasD Plugged 0 Abandoned 0 Suspended 0 WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJD WINJD WDSPL 0 No. of Completions Other Recomplete Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Uniion Oil Company of California Aband.: May 3, 1997 160-017 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 January 4, 1960 50-133-10150-01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2,120' FNL, 2,010' FEL, Sec. 22, T8N, R9W, SBM January 26, 1963 SRU 23-22 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 2,099' FEL, 2,267 FNL, Sec. 22, T8N, R9W, SBM 20' RKB to tbg head Total Depth: 9. Plug Back Depth(MD+ TVD): Swanson RiverlTyonek 1,330' FSL, 2,220' FWL, Sec. 22, T8N, R9W, SBM 9,215'/9,011 ' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 351,092' y- 2,474,863' 11,614'/11,235' Swanson River Production Facility TPI: x- 350,967' y- 2,474,693' 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 350,044' y- 2,473,055' n/a A-028998 18. Directional Survey: Yes lJNo 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: n/a feet MSL n/a 21. Logs Run: n/a 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 22" 0 28 0 28' driven 13-3/8" 54.5 J-55 0 3,000' 0 2,999' See Schematic for 7" 26/29 P-11D/N-8D 0 11,594' 0 11,227' Cement Detail 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) See Schematic Attached. 2-3/8" 11,255.40 11,132.3' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): n/a no production Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: /GaS-Oil 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". none RIIDMS BFL MAR ¡ 7 1006 ~ Form 10-407 Revised 12/2003 AFE 124693 CONTINUED ON REVERSE 28,. GEOLOGIC MARKERS NAME TVD 29. FORMATION TESTS Include and briefly s arize test results. List intervals tested, and attach detailed supporting da a as necessary. If no tests were conducted, state "None ". A11 B1 Beluga Tyonek HF E10 H2T H4T 2,999 3,110 3,717 5,929 6,257 8,958 11,207 11,276 2,998 3,109 3,716 5,918 6,236 8,769 10,868 10,932 none 30. List of Attachments: Directional survey, schematic, summary of operations. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Title: Drilling Manager Signature: Phone: 907-276-7600 Date: Sundry Number or N/A if C.O. Exempt: C:::> - <..:) c.... 396-206 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 124693 e e Report Name Position Log Well SRU 23-22 Date Created 11/11/2005 KB Surf X Surf V Well Name CURRENT STATUS API (ft) (ft) (ft) SRU 23-22 SUSPENDED 501331015001 329 351,092 2,474,863 MD TVD SSTVD X Off V Off X V Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 329 0 0 351,092 2,474,863 0 0 4,751 4,750 -4,421 -6 7 351,086 2,474,870 0.3 319 4,763 4,762 -4,433 -6 7 351,086 2,474,870 1.8 175 4,804 4,803 -4,474 -6 6 351,086 2,474,869 2.8 176 4,860 4,859 -4,530 -6 3 351,086 2,474,866 2.8 180 4,940 4,939 -4,610 -6 0 351,086 2,474,863 2.5 184 5,031 5,030 -4,701 -7 -4 351,085 2,474,859 3.3 199 5,129 5,128 -4,799 -9 -10 351,083 2,474,853 4.3 198 5,287 5,285 -4,956 -16 -22 351,076 2,474,841 5.8 218 5,376 5,374 -5,045 -22 -30 351,070 2,474,833 7.3 210 5,445 5,442 -5,113 -26 -38 351,066 2,474,825 8 205 5,645 5,640 -5,311 -41 -66 351,051 2,474,797 10 212 5,720 5,713 -5,384 -49 -77 351,043 2,474,786 11 212 5,920 5,909 -5,580 -72 -111 351,020 2,474,752 12.5 216 6,120 6,104 -5,775 -102 -147 350,990 2,474,716 14.5 222 6,320 6,296 -5,967 -141 -187 350,951 2,474,676 18.3 224 6,401 6,372 -6,043 -159 -206 350,933 2,474,657 19.3 224 6,494 6,460 -6,131 -181 -228 350,911 2,474,635 19.8 224 6,680 6,636 -6,307 -224 -271 350,868 2,474,592 18.8 225 6,772 6,723 -6,394 -246 -292 350,846 2,474,571 18.8 225 6,803 6,752 -6,423 -252 -299 350,840 2,474,564 16.5 217 6,896 6,841 -6,512 -268 -320 350,824 2,474,543 17 215 7,079 7,016 -6,687 -300 -366 350,792 2,474,497 18.5 213 7,226 7,154 -6,825 -327 -408 350,765 2,474,455 21 212 7,343 7,263 -6,934 -350 -443 350,742 2,474,420 21.3 213 7,484 7,394 -7,065 -378 -485 350,714 2,474,378 21.3 213 7,680 7,576 -7,247 -420 -547 350,672 2,474,316 23.5 214 7,880 7,760 -7,431 -465 -611 350,627 2,474,252 22.5 214 7,918 7,795 -7,466 -473 -623 350,619 2,474,240 22.5 214 7,966 7,840 -7,511 -482 -638 350,610 2,474,225 20.3 209 8,122 7,986 -7,657 -508 -686 350,584 2,474,177 20.5 207 8,243 8,099 -7,770 -529 -723 350,563 2,474,140 20.5 208 8,487 8,328 -7,999 -570 -797 350,522 2,474,066 20.5 209 8,687 8,515 -8,186 -606 -858 350,486 2,474,005 20.5 211 8,873 8,689 -8,360 -640 -913 350,452 2,473,950 20.5 211 8,981 8,791 -8,462 -660 -945 350,432 2,473,918 19.5 211 9,181 8,979 -8,650 -696 -1,002 350,396 2,473,861 20.3 212 9,340 9,128 -8,799 -726 -1,048 350,366 2,473,815 20.3 213 9,483 9,262 -8,933 -754 -1,089 350,338 2,473,774 20.3 215 9,530 9,307 -8,978 -762 -1 ,102 350,330 2,473,761 18.3 203 9,730 9,495 -9,166 -786 -1,163 350,306 2,473,700 20 199 9,908 9,663 -9,334 -807 -1,220 350,285 2,473,643 20.3 200 10,043 9,789 -9,460 -823 -1,265 350,269 2,473,598 21 198 10,190 9,925 -9,596 -840 -1,317 350,252 2,473,546 22.5 197 10,273 10,003 -9,674 -852 -1,346 350,240 2,473,517 21.3 205 10,437 10,153 -9,824 -880 -1,403 350,212 2,473,460 24.8 205 10,637 10,338 -10,009 -909 -1,475 350,183 2,473,388 20.8 198 10,872 10,557 -10,228 -940 -1 ,553 350,152 2,473,310 21.3 204 11,071 10,742 -10,413 -970 -1,620 350,122 2,473,243 22 202 11,614 11,246 -10,917 -1,048 -1,808 350,044 2,473,055 22 202 11,664 11,292 -10,963 -1,055 -1,825 350,037 2,473,038 22 202 "" > . , 4/28/97 e e RIH with GR/CCL. Tie in to Schlumberger TDT dated 8/15/96 and run GR/CCL pass from 6,400' to 5,000'. RIH with 7" pivot gun and tied in with GR/CCL dated 4/28/97. Perforated 6,277' yo 6,284',4 SPF, 180 deg. phasing. POOH. All shots fired. RIH with 1-3/4" ball seat bailer. Ran across perfs from 6,277' to 6,284' to get fluid sample and POOH. Sample was clear water. 4/30/97 MI/RU Schlumberger. RIH with 5' gun. Tie in with TDT dated 8/15/96 and shoot 6,277' to 6,282',4 SPF, 180 deg. phasing. All shots fired. POOH. RIH with 9' gun. Tie in with TDT dated 8/15/96 and shoot 6,235' to 6,244', 4 SPF, 180 deg. phasing. All shots fired. POOH. Open well to tank. No flow. 5/3/97 MIIRU Schlumberger. RIH with 5' pivot gun. Tie into TDT dated 8/15/96 and shoot 6,267' to 6,272',4 SPF, 180 deg. phasing. All shots fired. POOH. RD/MO. 9/12/97 MIIRU. PJSM. Pressure test lubricator to 500 and 3,000 psi. Pumped 40 gal water into well prior to RIH. RIH with 1-11/16" x 10' retrievable Enerjet. Tie in with Schlumberger GR/CCL dated 4/28/97. Shot 5,189' to 5,199'. POOH. Tool string stuck in hole at 598'. RU and methanol to check for ice plug. Could not pressure up. Pulled line to 1,300# (75% of weak point.) no change. Pulled, slacked off and held line incrementally up to 1,900# where it pulled out of the rope socket. Recovered all wire. Will arrange for Pollard to fish in the a.m. 9/13/97 MIIRU Pollard. Tubing pressure at 100 psi. RIH and latch fish. Jarred up several times, fish came free. Everything recovered. RDMO. SRU 23-22 124693, morning report summary, CONFIDENTIAL: last revised 11/11/2005, Page 1. &$ììl . . RKB to TBG Head Tree connection: TC-3 Urn-bolt 1 PBTD = 9,215' TD MAX HOLE ANGLE = 24'~\KOP @3000' 23-22schmll-2-96 13-3/8" 54.5 Surf 7" 29 P-110 SrdLT&C Surf T' 26 P-110 Srd L T&C 36' 7" 29 N-SO Srd LT&C 1812' 7" 26 N-SO Srd LT&C 3159' 7" 29 N-SO Srd L T&C 6560' 7" 26 P-110 Srd LT&C 8066' 7" 29 P-110 Srd LT&C 9771' Tubing: 2-3/8" 4.6 N-80 Buttress Surf with 3/8" SS methanol injeetionlineSurf 1 2 xover Maeeo 2-3/8" SMO-ICl w/1000 psi chern inj Maeeo 2-3/8" D.SO BakerFH Retr. pkr, X nipple, min. ID;= 1.875" Tbg tail(shear out sub) 3 4 5 6 5032 50S2 5127 5160 9215 9520 9533 11,072 11,126 11 ,193 11,255 Baker cmt retainerin 2·7/8" Bakeremt retainer in tubing Cameo M<:t:i1drel #8w/dummy Cameo Mandrel #9 w/dummy Brown packer, HS-16-1 CameoD nipple Bottom of tubing tail 5189 5199 Tyonek 51-9 6 9/12/97 6235 6244 Tyonek 55·4 4 4/30/97 6267 6272 Tyonek 61·8 4 5/3/97 6277 6284 Tyonek 61-8 4 4/28-30/97 9507 9510 tbgholes 4 10/95 11208 11216 Hemlock 4 11226 11254 Hemlock 4 e JOB STATUS REPORT e TIME NAME FAX It TEL It SER.1t 04/05/2005 13:44 AOGCC 9072757542 BR02J2502370 DATE, TIME FAX NO./NAME DURATION PAGE(S) RESULT MODE 04/05 13:42 2537302 00:01:53 05 OK STANDARD ECM . about:blank . Steve, A followup to our conversation about SRU Wells today. We have some well pool errors and production allocation isn't correct in our production database or UNOCAL's. We have found some paperwork submitted to us with the wrong pools on the forms and the wrong data was assigned to the wells. We will creat a pool code if the operator indicates production to a new pool. The wells in question are SRU 12-15, SRU 23-22 and SRU 241-16. For each well Bob Crandall would like a discription of the gas pools in the Tyonek, Sterling and Beluga formations. A date or time when these wells produced in specific pool. Illustration of the well with cross sections. We will insert this response into each well file to reduce confusion in the future about these wells and hopefully better explanations will acompany well recompletions and new permits in the future. Steve ~~ to ~ 1l ~ Unðli1L c,G j]O h ~d cJL 1 of 1 11/30/2004 9:35 AM UNOCAL( P. O. Box 196247 Anchorage, Ak 99519-6247 October 7, 1996 907-276-7600 907-263-7884 fax Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Swanson River Unit Well #23-22 AP/#50-133-10150.00 Form 10-403, Proposal to Recomp/ete Well to Tyonek Dear Commissioner Johnston: Unocal proposes to recomplete the Swanson River Unit Well # 23-22 as a Tyonek gas producer. This well's Hemlock Perforations were abandoned in October 1995 (Approval #95-163). This Work will require pulling the existing 2-7/8" tubing and running a single 2-3/8" completion. The Tyonek gas zone will be Perforated with through-tubing guns. Attached in triplicate are the 10-403 form with BOP schematic, detailed operations Program and wellbore schematics of before and after the proposed work. Estimated start date is October 25, 1996 so your timely consideration of this Proposal would be apPreciated. Please direct any questions to Tim Billingsley at 263-7659. Sincerely, ./ ~ /...,~, Tim Billingsley RECEIVED OCT 1 0 A]ask~ Oil & G~s Cons. Commission Anchcrago u AOC~cov. DOC 10/6/96 -", STATE OF ALASKA ALASKA Oh-AND GAS CONSERVATION CuMMISSlON APPLICATION FOR SUNDRY APPROVALS 1. :l'ype of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: x Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: x Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 20 feet ,,= 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Swanson River Unit ,. Anchorage, AK 99519-6247 Service: , 4. Location of well at surface 8. Well number 2120' FNL & 2010' FEL of Sec. 22, TSN, R9W, SBM SRU 23-22 At top of productive interval Same 9' Permit numbe~)o --{~ /7 At effective depth 10. APl number 2160' FSL & 2570' FWL of Sec. 22, TSN, R9W, SBM 50- 133-10150-0~ At total depth 11. Field/Pool 1330' FSL & 2220' FWL of Sec. 22, TSN, R9W, SBM Swanson R~y~/T~m,ne~ 12. Present well condition summaryU [-.~ ~,~ [ [~ ~ L Total depth: measured 11614 feet Plugs (measured) 9042'-11614' true vertical 11235 feet Effective depth: measured 9042' feet Junk (measured) .. true vertical 8841' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" 28' 28' Surface 3000' 13-3/8" 2000 sx 3000' 3000' Intermediate Production 11594' 7" 1810 sx 11594' 11594' Liner Perforation depth: measured 11208'-11216' Plugged RECEIVED 11226'-11254' Plugged true vertical 10859'-10867' 10876'-1090ZOCT 1 0 199 ; Tubing (size, grade, and measured depth) 2-7/8", 6.5~, N-80 8rd at 11255' Alaska, Oil & 6~s Cons. Commlssion Packers and SSSV (type and measured depth) Brown HS-16-1 2-7/8" x 7" {~ 11126' 13. Attachments Description summary of proposal: Detailed operations program: x BOP sketch: x ,, ,,, 14. Estimated date for commencing operation 15. Status of well classification as: 10/25196 16. If proposal well verbally approved: Oil: Gas: Suspended: x ,,,, Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,f~.l~[ ~ Dale Haines Title: Drilling Manager Date: FOR COMMISSION USE ONlY Conditions of approval: Notify Commission so representative may witness IApproval Plug intogrity.~ BOP Test f Location clearance Mechanical Integrity Test Subsequent form required 10- ~C:) 'T Original Signed By David W. Johnston Approved by order of the Commissioner Commissioner Date /~////?~O Form 10-403 Rev 06/15/88 Approved Copy SUBMIT IN TRIPLIC~ATE Returnee UNOCAL ) Objective: Recomplete Tyonek Gas Producer. Swanson River Field SRU 23-22 Workover Program 10/4/96 SRU 23-22 from an abandoned Hemlock Producer to a Status: Abandoned Hemlock producer. Proposed Work: Recomplete the well as a Tyonek gas producer. General Procedure: I. Pre-rig prep work: 1. RU E-line unit. 2 Tag TOC in tubing with 2.25" GR. POOH. Note: After abandonment of Hemlock perfs, the top of cement in tubing was tagged at 9158' WLM on 10/11/95. Highest possible calculated TOC in tubing x casing annulus was 8970'. 3 RIH with 2.25" full jet cutter and cut 2-7/8" tubing at 8500'. POOH and RD E-line. 4 Circ hole to lease water. He me Rig Mobilization and Prepare Well for New Completion Note: Notify BLM and AOGCC 24 hours in advance of BOP tests. I MIRU Alaska Well Service RIG 5. 2 ND tree. NU BOPE choke line. kill line and choke manifold. 3 Pressure test BOPE. 4 Pull 2-7/8" tubing. 5 RIH with bit and scraper to 6500'. 6 Circ hole to 6% KCL lease water with corrosion inhibitor. Pressure test casing to 1500 psi. 7 POOH and LD bit and scraper. Run 2-3/8" Completion: I RIH with new 2-3/8" completion including: 1) X nipple (minimum ID = 1.875") in tubing tail 2) 2-3/8" x 7" 26# Retrievable packer set at 5100'. 3) 2-3/8" gas lift mandrel with dummy. 4) Chemical injection gas lift mandrel w/1000 psi chem inj valve at 2500' approximately. 5) 2-3/8" buttress tubing to surface with 3/8" ss control line strapped to tubing. U AOGCCPR. DOC I 10/4/96 UNOCAL Swanson River Field SRU 23-22 Workover Program 10/4/96 2 Land tubing hanger. 3 Circ diesel down tubing for underbalance perforating. 4 Drop packer setting ball and set packer x~ith 3000 psi tubing pressure. Shear out ball. 5 Pressure test annulus to 1500 psi. 6 ND BOPE. NU and test tree. 7 RD rig and move to next workover. Perforate Tyonek I RU E-line umt. T!,.e-in Loc: Schlumberger's TDT date 8/15/96. 2 RIH with 1-11/16" GR/CCL for correlation log. Log from 6300' to packer jewelry at 5100'. 3 RIH with gun run # 1 and tie in to GR/CCL correlation log. Perforate 6277'-6288' (11 feet) with Schlumberger 1-11/16" pivot guns at 4 spf. 4 POOH with guns. 5 RIH with gun run #2. 6 Perforate 6268' - 6273' (5 feet) 7 POOH and RD E-line unit. 8 Turn well over to Production. POOH. RECEIVED OCT i0'!996 Alasks Oil 8, 13as Cons. C~mm~ssion u AOCK2CPILDOC 2 10/4/96 FILL-UP, D> ~'-' KILL LINE 5000 psi ~OP I O' S'O00 psi PI~ RAgS !0' 5000 BLIND RA]~ !0' ) 5000 10" 5000 ! FLOW CHOKE LINE ~ 8000 psi T BOP STACK 10~ EO0'O psi RECEIVED OCT 1 0 t99G Alaska Oil & C-a.s Cons. C,~mm:ss;oD UNOCAL ) Calc Highest TOC in Annulus 8970' TOC in Tubing ~ 9042' WLM, 10/11/95 6 7 7a 7b 8 9 10 ,11 SIZE WT Swanson River Field Well # SRU 23-22 Actual Completion 1/63 II CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 22" Surf 13-3/8" 54.5 J-55 Surf 7" 29 P-110 8rd LT&C Surf 7" 26 P-Il0 8rd LT&C 36' 7" 29 N-80 8rd LT&C 1812' 7" 26 N-80 8rd LT&C 3159' 7" 29 N-80 8rd LT&C 6560' 7" 26 P-II0 8rd LT&C 8066' 7" 29 P-110 8rd LT&C 9771' Tubing: 2-7/8" 6.5 N-80 8rd Surf 28' 3000' 36' 1812' 3159' 6560' 8066' 9771' 11594' 11,255' JEWELRY DETAIL NO. Depth Item 20.00 I 1722 2 3181 3 4487 4 5532 5 6464 6 7277 7 7974 7a 9215 7b 9520 8 9533 9 11,072 10 11,126 11 11,193 12 11,255 TOP BTM 9507 9510 11208 11216 11226 11254 Tubing Camco Camco Camco Cameo Camco Camco hanger Mandrel # 1 w/dummv Mandrel #2 w/dummy Mandrel #3 w/dummy Mandrel #4 w/dummy Mandrel #5 w/dummy Mandrel #6 w/dummy Camco Mandrel #7 w/dummy Baker cmt retainer m tubing Baker cmt retainer in tubing Cameo Mandrel #8 w/dummy Camco Mandrel #9 w/dummy Brown packer, HS- 16-1 Camco D nipple Bottom of tubing tail PERFORATION DATA ZONE SPF DATE COMMENTS tbg holes 4 10/95 For Hemlock P&A Hemlock 4 Abdnd 10/95 Hemlock 4 Abdnd 10/95 12 PBTD = 9042' TD = 11614' MAX HOLE ANGLE -- 24°, KOP ~ 3000' SC23BLMA.DOC RECEIVED OCT 1 0 Al~sk~ Oil & fi.~s Cor~s. ¢omm~s,~ion REVISED: 10/6/96 DRAWN BY: TAB UNOCAL ) ; · iii Tbg cut 8500' SIZE WT Swanson River Field Well # SRU 23-22 Proposed Recompletion 10/96 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 22" Surf 28' 13-3/8" 54.5 J-55 Surf 3000' 7" 29 P-II0 8rd LT&C Surf 36' 7" 26 P-II0 8rd LT&C 36' 1812' 7" 29 N-80 8rd LT&C 1812' 3159' 7" 26 N-80 8rd LT&C 3159' 6560' 7" 29 N-80 8rd LT&C 6560' 8066' 7" 26 P-110 8rd LT&C 8066' 9771' 7" 29 P-110 8rd LT&C 9771' 11594' Tubing: 2-3/8" 4.6 N-80 Buttress Surf xvith 3/8" SS methanol injection line Surf 5,160' 2,500' NO. ? Prop Perfs ::::::::5 .:.:.:.:.: 1 2 3 4 5 Calc Highest TOC in 7a Annulus (~ 7b 8970' 8 7a TOC in 9 Tubing (~ 10 JEWELRY DETAIL Depth Item 20.00 2500 5070 5100 5130 5160 9215 9520 9533 11,072 11,126 7b 9158' WLM 11 10/11/95 12 8 11,193 11,255 TOP BTM Tbg hgr with Cameron "H" BPV profile Chem Inj Mdrl w/1000 psi chem inj valve GLM w/dummy Baker FH Rem pkr, 2-3/8" x 7" 26# X nipple, min. ID = 1.875" Tbg tail (shear out sub) Baker cmt retainer in tubing Baker cmt retainer in tubing Camco Mandrel #8 w/dummy Camco Mandrel #9 w/dmmny Brown packer, HS- 16-1 Camco D nipple Bottom of tubing tail PERFORATION DATA ZONE SPF DATE COMMENTS 10 11 6268 6273 6277 6288 Tyonek 61-8 4 Proposed Tyonek 61-8 4 Proposed 12 9507 9510 11208 11216 11226 11254 tbg holes 4 Hemlock 4 Hemlock 4 10/95 For Hemlock P&A Abdnd 10/95 Abdnd 10/95 PBTD = 9042' TD ~- 11614' MAX HOLE ANGLE = 24°, KOP ~ 3000' SC23BLMP.DOC REVISED: 10/6/96 DRAWN BY' TAB Form ~160-5 (JUNE 1990) i UNITED ~,,~TES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reenb'y to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas [~ Well [~ Well O Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lea~e Design~on and Serial No. 6. If Indian, Nlottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Solclotna Creek Units 8. Well Name and No. 9. APl Weil No. 10. Reid and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECK APPROPRIATE BOX(s)TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent Subsequent Report Final Abandonment ['-] Abandonment 0 Change of Plans I--] Recompletion ~ New Construction O Plugging Back 0 Non-Routine Fracturing O Casing Repair O Water Shut-Off ~ Altering Casing 0 Conversion to Injec~on ~ Other Temporarily Abandon r'-] Dispose water (Note: Report results of multiple co~mpletion on Well Completion or Reoomptedon Refxxt and Log fon'n.) 13. Describe Proposed or Completed Operations (Clearly slate all pe~nent details, and give pertinent dates, including estimated date of stardng any IXOposed work. If well is directionally drilled, give subsudace locations and measured and true verdcai dep~s for all markers and zone pertinent to Ibis work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31,1997: Soldotna Creek Unit ~. j¢J SCU 21-8 ~ SCU 34-9 ~-) ~SRU 212-10 (O1"~SCU34-8 ~'--~SCU41B-9 ~.OO'~RU12-15 ~- I SCU 243-81 ~U 14-34 OO-J ~SRU 14-15 S i-~'SCU 13-9 L~ SRU41A-15 * High GOR well that may be produced intermittently Swanson River Unit SRU 212-27 SRU 23-27 SRU 331-27 0:3_" {_~ SRU 34-2a G~-7_ SRU 43-28 SBU 21-33WD ~ ~.-,~ APR 0 1 SRU 24-33 -/ 14. I hereby certify th~ the foregoing is true and correct. Dennis L. Groboske Petroleum Engineer Da. 3/29/96 Ap~oved by Co~cr~dons of aPlXoval, if any: 'l-lUe Date T'~e 18 U.S.C. Se=lion 1001, makes ira crime for any person knowingly and willfully to make to any deflartnmnt or agency of the United S1ato~ any tame, fictitious frau~_,._l,mt_ _~t,,~enmnls or r _epre,~,~___ ~ as to any nme~e-, within its jufis~rec'6,"~'l. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Shut-in Wells during Field Blowdown Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A SCU 34-8 SCU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 7 Wells 2 Wells 5 Wells ~>,~ * ~.~h GOR well that may be produced intermittently Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 Recompleted in Tyonek G1 and G2 zones · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. tkE..Gr_..Iv D ~PR 01 1~6 rtl F~ Oz© ~z i-z Spud: 1 460 Redri led: 1/26/65, Lost Workover: t0/10/9~ SRU 2,5-22 Swanson River Fied APl No.: b0-1~5-10150-00 ~of Hemlock: Ft. MD Ang.,., ~ Hem ock: 21 Degs. Hanger: ShaTTer 0,0 - 2&O' 22" OD CSG 0.0-5000.0' 1.3 5/8" OD 54.50t/fl J-55 SURF CS6 55.5- 1811,6' 7" OD 26.00t/fi P-110 PROD CSC 1811,6- 5159,5' 7" OD 29,00t/fl N-80 PROD,CSG 5159.5- 6560.1' 7" OD 26.00t/fi N-80 PROD CSG 6560.1 - 8065.8! 7" OD 29.00t/ft N-80 PROD CSG 8065,8-9770,9' 7" OD 26.00t/ft P-110 PROD CSG 9770.9- 11594,0' 7" OD 29.00~,/ft P-110 PROD CSG 9215.0 - 9510.0' CEMEN1- PLUG 10/95 9520.0 - 11126,3' CEMENT PLUG 10/95 11132.3 - t1332.0' CEMEN[ PLUG 10/95 11205.0 - 11206.0' SQUEEZE PERFS WSO, 5HPF, 1' 11332.0 - 11614.0' CEMENT PLUG 1/63 KB ELEV: 15' PBTB: 9215' ID: 11614' - 0.0-9200,0' 2,875" OD 6,50~/ft N-80 tBG 9~00,0-~55.4' 2.~75" OD 6,50t/~t,-80'mo 9042.0 - 9215.01 CEMENT PLUG Tbg. 10/95 9215.0 - 9215.5' RETAINER fbg, Baker 10/'95 9215.5- 9510.0' CEMENT PLUG fbg, 10/95 9507.0- 9510.0' SQUEEZE PERFS 10/95 fbg. 9520.0- 9520.5' RETAINER Tbg. 10/95 9520.5- 11126,0' CEMEM PLUG l'bg, 10/95 NOV 0 8 1995 Alaska Oil & Gas Cons. Commission , ~mchorage 11126,0- 11255.4' CEMENT PLUG Tb9. 10/95 11126,5 - 11152.5' REq'RV, PACKER Brown HS-16-t Pkr 11208.0 - 11216.0' ABANDONED PERFS H-2, Ab'd 10/95 11226,0 - 11254.0' ABANDONED PERF5 H-4, Ab'd 10/95 Oil We l Pugged Back 10/10/95 Spud: 1 460 Redril ed: 1/26/65, Lost Workover: 10/10/95 SRU 25-22 Swanson River Field APl No.: 50-155-10150-00 ~of Hemlock: Ft. MI) Ang,~ ~ Hem ock: 21 Deqs, Hanger: Shaffer 9215.0- 9510.0' CEMENI PLUG 10/95 8065.8- 9770.9' 7" OD 26,00t/fi P-110 PROD egg 9520.0 - 11126.3' CEMENI PLUG 10/95 11152.5 - 11532.0' CEMENT PLUg 10/95 11205.0 - 11206.0' SQUEEZE PERFS WSO, 5HPF, 1' 11552.0 - 11614.0' CEMENT PLUG 1/65 9770.9- 11594.0' 7" OD 29,00t/fl P-IlO PROD CS(; KB EEV: PBTD: 9215' 'rD: 11614' 9042.0 9215.0 9215.5 9220.0 95205 9507,0 9520,0 9552.7 9547.0 - 921,5.0' CEMEN-i PLUG Tb9. 10/95 - 9215,5' REAtNER fb9. Baker 10/95 - 9510,0' CEMENI PLUG Tb9, 10/95 - 9221,0' RES'I'R ID 10/95, Obstruction -11126,0' CEMEN'I' PLUg lb9, 10/95 - 9510.0' S(~UEEZE PERFS 10/951-b9. - 9520,5' RETAINER lb9.10/95 - 9545,8' OASLIFI- VALVE t8, Coreco MM GLM -9548,0' RES'IR ID 10/7/95 NOV 0,8 1995 Nasga.Oil & Gas Cons. Commission , ~chorage 11071.7 - t10194.EI' GASLIFI' VALVE t9, Camco MM GLM W/CEV 11075,0- 11076,0' RESIR ID 8/7/95 11115,2 - 11116.2' JOINT Brown CC Solely dr, 11126,0 - 11255.4' CEMENT PLUG lbg, 10/95 11126,3 - 111.~2.5' RE}RV, PACKER Brown NS-16-t Pkr 11193.2 - 11194.1' LANDING NIPPLE C~mco D 1i208.0 - 11216,0' ABANDONED PFRFS H-2, Ab'd 10/95 11226.0 - 11254.0' ABaDONEI)PFRFS tt-4, Ab'd 10/95 11254,8- 11255,4' REENTRY JOINT Venturi Shoe Oil Well Plugged Bock 10/10/95 SWANSON RIVER UNIT WELL 23-22 Day 1 (10/3/95) RU POLLARD SLU ON 23-33. RIH AND SET DUMMIES IN GLM'S. HAD PROBLEMS WITH SETTING DUMMY IN GLM @ 7,277'. RIH WITH lB AND WORKED BY GLM @ 7,277'. TAG BTM @ 11,048'. SET DUMMY IN GLM @ 7277'. SHUT DWN FOR THE NIGHT. Day 2-3 (10/7-10/8/95) RU HOWCO, BAKER TANK, AND CHOKE MANIFOLD. FILL UP TBG WITH 53 BBLS LEASE WATER CSG PRESSURE @ 1800 PSI. TBG PRESSURE BUILDING -- COMMUNClATION. PUMP 110 BBLS LEASE WATER DOWN TBG @ 2 BPM. WITH 79 BBLS AWAY TBG = 0 PSI; @ 110 BBLS TBG ON VACUUM. BLEED GAS FROM ANNULUS. CSG = 0 PSI. RU SCHLUMBERGER AND TEST LUB TO 3500 PSI. SlTP = 0 PSI. SlCP = 300 PSI. RIH WITH BAKER MODEL H 2.220" CMT RETAINER. SET DOWN @ 9547' TM. CAN NOT WORK THRU. TOP OF MANDREL @ 9533' TM CONFIRMED WITH CCL. SET RETAINER @ 9,520'. POOH. RD SCHLUMBERGER WLU. RU ARTIC RECOIL AND HOWCO. TEST BOPE TO 250~5000 PSI. SECURE WELL FOR THE NIGHT. Day 4 (10~9~95) RU CTU. PULL TEST CTC TO 24K. INSTALL RISER AND INJECTOR HEAD. SHELL TEST BOP, RISER, AND STRIPPER TO 250~5000 PSI. 3" HYDROLEX CONNECTION AT TOP OF PREVENTERS LEAKED @ LOW PRESSURE. LEAK FIXED. RIH W/STINGER CIRC. STAB INTO RETAINER @ 9215' (9,212' CTM). RETURNS OIL AND GAS CUT. PUMPED 25 BBLS LEASE WATER AFTER STAB IN. SHUT IN AND PRESSURE TEST CSG AND LAST SQUEEZE JOB TO 2000 PSI (2300 SICP) FOR 3 MIN. OK. PUMP 5 BBLS FRESH WATER, 19 BBLS 15.8 PPG CMT WITH ADDITIVES, 5 BBLS FRESH WATER, AND DISPLACE WITH 19 BBLS LEASE WATER. UNSTING AND POOH TO 9,000'. LEAVE I BBL CMT ON TOP OF RETAINER. CIP @ 13:00 HRS. CBU-- TRACE CMT. POOH CIRC. FLUSH EACH GLM ON THE WAY OUT. RD ARCTIC RECOIL AND HOWCO. NOV 0 8 1995 Alas~ Oil & Gas Cons. Commiss]o~ ~chorage Day 5 (10/10/95) CSG PRESS - 300 PSI. TBG PRESS = 0 PSI. BLEED CSG TO 50 PSI. GAS OUT AND OIL. ClRC CSG 60 BBLS. PRESSURE TEST ABANDONMNET PLUGS AND CASING TO 2500 PSI. NO STATE OR BLM WITNESS. STATE WlAVED AND BLM NEVER RETURNED CALL. TEST ON CHART. CONT TO ClRC TBG AND CSG THRU POINT OF COMMUNICATION. RETURNS CLEANED UP. WELL STATIC. RD HOWCO AND LINES. SUCK OUT BAKER TANK. Day 6 (10/11/95) RU SLICKLINE. RIH AND TAG CMT. FREEZE PROTECT WELL. LAST REPORT. t,10V 0 [~ 199~ Gas Cons, Commission Anchorage Unocal Corporatio. P.O. Box 100247 Anchorage, AK 99519 (9o7) 263-7805 UNOEAL Marie McConnell Drilling Engineer PED Friday, September 08, 1995 Mr. Russ Douglas AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Douglas: Unocal proposes to permenantly abandon the Hemlock formation, while maintaining the wellbore for future uphole potential in Swanson River Field Well SRU 23-22. The Hemlock is currently watered out and is no longer economically viable. Unocal plans to perform this work during the end of September, 1995, and appreciates your help in obtaining approval of this application. Please direct questions and comments to Marie L. McConnell at 263-7805. Sincerely, _ _ / Marie L. McConnell MLM RE SEP 1 ;~ 1995 Gas Cons, ~mmlssl~n 1. Type of request: STATE OF ALASKA ALA .~ OIL AND GAS CONSERVATION COMk ,ON APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 AbandOn X_ Suspend __ Operations shutdown __ Re-enter suspended well__ Alter casing__ Repair well _ _ Plugging X_ Time extension w Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate__ Other__ 6. Datum elevation (DF or KB) At effective depth At total depth , 5. Type of Well: Development X_ Exploratory __ Strafigraphio ~ ~ervice Location of well at surface 2120' S & 2010 W f/NW Corner of Section 22, T8N, R9W, SBM At top of productive interval ORIGINAL 15' 7. Unit or Property name Swanson River Unit 8. Well number SRU 23-22 9. Permit number__ 10. AP1 number 50-133-10150-00 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,614 feet Plugs (measured) 11,614 feet 11,332'- 11,594' Effective depth: measured true vertical feet Junk (measured) feet Casing Length Size Structural Cellar Conductor 28' Surface 3000' Intermediate Production 11,594' 7" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 22" 13-3/8" Cemented 2000 sx 1810 sx 11,208'-11,216'; 11,226'- 11,254' Propose to abandon w/cmt f/10,573' to 11,332' 2-7/8", 6.5#, N-80, 11,255' Measured depth True vertical depth SEP 1 1995 Gas Cons. ~l~r~l~ ,~ ....... Packers and SSSV (type and measured depth) Brown 2-7/8" x7" HS 16-1 Pkr @ 11,126' 13. Attachments Description summary of proposal _ _ Detailed operations program_ x BOP sketch x _ 14. Estimated date for commenCing operation Sept. 95 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil x Gas Suspended __ Service 17.1 hereby certify that the for~/~ng i~(lr~e~n~o the best of my knowledge. Signed G. Russell Schmidt }~.~x..,,,../~,,----- Title Drilling Manager FOR COMMISSION USE ONLY Date 09/08/95 Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by the order of the Commission Original 8igneo By David W. Johnston Form 10-403 Rev 06/15/88 ~oz Approved Copy Returr~ed c~h~mi~s-i°ner ....Date sUBMIT IN-TRIi~LiC-ATE SRU 23-22 Hemlock Abandonment General Procedure September 6, 1995 Field Prep Work 1. R/UWL. . 2. Tag fill with full gauge ring. 3. Verify all GLVs are dummies. 4. R/D WL. 5. Surface pressure test esg to 2500 psi. 6. Perform Hemlock injeefivity test through obstructed tbg @ 11,060' WLM. Set 1 st Cmt Ret 7. If able to pump in step 6, go to step 11, but omit step 13. 8. If unable to pump in step 6, R/U 1.5" CTU. 9. Cleanout tbg to 11,180'. 10.R/D CTU. 11.R/U E-line. 12.Tie-in w/CCL, 13.Perf tbg F/11150 - 153', 4 SPF (below pkr). (omit if able to pump, step 6) 14.Set 2-7/8" cmt retainer ~ 11,000' (above btm GLM). 15.R/D E-line. Sqz Hemlock 16.R/U 1.5" CTU. 17.Stab coil into ret ~ 11,000'. 18.Check CT x tbg annulus for flow. / 19.Establish injection rate w/lease water. 20.Sqz approx. 15 bbls cmt below ret. 21.Pull out of ret, circ out excess cmt. 22.R/D CTU. Set 2nd Cmt Ret SEP 1 3 1995 Gas Cons. Commission ~chomge ' 23.R/U E-line. ~ 24.Perftbg F/10,987 - 990', 4 SPF (above 1st ret, below GLM) 25.Set 2-7/8" cmt ret @ 10,700'. 26.R/D E-line. Circ Cmt above Pkr 27.R/U 1.5" CTU. 28.Stab coil into cmt ret ~ 10,700'. 29.Check CT x tbg annulus for flow. 30.Taking returns up 2-7/8 x 7" annulus, pump 18 bbls cmt below ret. 31 .Pull out of ret, equalize 1 bbl on top of ret, circ out excess cmt. 32.R/D CTU. Post Abandonment Field Work 33.WOC to harden. 34. Surface test plug to 2500 psi. 35.R/U 36.Tag TOC (approx ~ 10,573'). 37.Pull GLV ~ 9533'. 38.If unable to pull GLV in step 33, cut tbg ~ 10,073' (500' above TOC). 39.Circ corrosion inhibited brine around GLM or tbg cut. 40.Secure well, clean and clear location. SRU 23-22 - SWANSON RIVER FIELD - UNOCAL PRESENT CSG DETAIL 28' 22" 3,000' 11-3/4", 47//, J-55 11,594' 7", 29 & 26//, N-80 & P-110 .TBG DETAIL 2-7/8", 6.5#, N-80 TBG to 11,255' 1,722' Camco MM GLM, #1 3,181' Camco MM GLM,//2 4,487' Camco MM GLM,//3 5,532' Camco MM GLM,//4 6,464' Camco MM GLM,//5 7,277' Camco MM GLM,//6 7,974' Camco MM GLM,//7 9,533' Camco MM GLM,//8 11,072' Camco MM GLM,//9 11,115' Brown CC Safety Jt. 11,126' Brown 2-7/8" x 7" H$-16-1 PKR 11,193' Camco 'D' Landing Nipple 11,255' Venturi Shoe PERFORATIONS 11,208- 11,216' H2 11,226 - 11,254' H4 OBSTRUCTION tagged ~ 11,075' on 8/07/95 PBTI) = 11,332' TI} = 11,614' MLM 9/07/95 SRU 23-22 - SWANSON RIVER FIELD - UNOCAL PROPOSED CSG DETAIL 28' 22" 3,000' 11-3/4" , 47//, J-55 11,594' 7", 29 & 26//, N-80 & P-110 ~/f~7 T'oC TBG DETAIL 2-7/8", 6.5#, N-80 TBG to 11,255' 1,722' 3,181' 4,487' 5,532' 6,464' 7,277' 7,974' 9,533' 10,700' 11,000' 11,072' 11,115' 11,126' 11,193' 11,255' Camco MM GLM, # 1 Camco MM GLM, #2 Camco MM GLM, #3 Camco MM GLM, g4 Camco MM GLM, #5 Camco MM GLM, ~ Camco MM GLM, #7 Camco MM GLM, #8 2-7/8'' CMT RET 2-7/8'' CMT RET Camco MM GLM, #9 Brown CC Safety Jt. Brown 2-7/8" x 7" HS-16-1 PKR Camco 'D' Landing Nipple Venturi Shoe PERFORATIONS 10,987 - 10,990' 11,208- 11,216' H2 11,226 - 11,254' H4 TBG SQZ'D SQZ'D, ABANDONED SQZ'D, ABANDONED TOC approximately (~ 10,573' OBSTRUCTION tagged ~ 11,075' on 8/07/95 PBTD = 11,332' TD = 11,614' MLM 9/07/95 Union Oil Company of California Cook Inlet OnshorefrBU Well Summary DRLG MGR: DRLG SUPT: DRLG ENG: Project: Hemlock Abandonment Field: Swanson aivor Well Number: SRU 23-22 Hole Condition: Brief Well History: 1/4/60 1/26/63 9/13/74 8/1/83 2/29/84 10/25/84 3/8/86 3/7/87 8/7/95 Original Spud date. Recompletion - pulled old tbg, cleaned to 11,290', ran new tbg. Press survey, set down in CE¥ @ 11,072'. Tag ~ 11,080'. Set down in mandrel @ 11,072' - GLV work, 1-5 dummied, RDO in 6 & 9, 7 & 8 empty, Uii~ble-to Set down in GLM # 7 & 8 to set dummies. Unable to go below 11,071'. Tagged w/1.5" GR @ 11,080'. Press survey. Tag @ 11,071' KB w/1.9" GR - GR had wireline looking marks. Press survey. Tag ~ 11,071' w/1.9" GR. RIH w/2" GR T/11,057' WLM. 2" pump bailer T/11,057' rec'd some s~ale, 1-3/4" IB no marks (sand). RIH w/2.25" GR to 9525' WLM had metal marks & btm flared out. 11,614 TVD: 11,237 PBTD: 11,332 DRLS Datum: 15 KB CSG Record: Size WT Grade Depth Connection Cement 22 28 13-3/8 54.5 J-55 3,000 2000 sx 7 26, 29 N80, PI 10 11,594 LT&C 1810 sx Tubing Detail: Size Grade Depth Connections 2-7/8 NS0 11,255 EUE 8rd Drift Min. Restriction: Perforations: Jewelry Depth ID Camco q)' Nipple 11,193 2.250 Venturi Shoe 11,255 2.100 Top Bottom SPF Hole Size Phasing Date' Gun Depth Depth ('m) 11,208 11,216 4 1/2 3/7/60 Jet Perf 11 ~226 11,254 4 1/2 3/7/60 Jet Perf SQZ Pcrfs: 11205', 1', 5 HPF, 3/2/60. Plug Detail: Cmt F/I 1,332 - 11,594'. Fill Data: Fish: Deviation: Swab Valve: Objective: Sand and scale @ 11,057' None 20 degrees thru perfs R27 2-1/2" 4000 psi (estimated from adjacent wells - last survey 3/7/87) Abandon Hemlock while allowing future access to gas sands above 7,010' SUMMARY.XLS 9/7/95 · 16 ~ 8N-9W ---1 '7N-OW 17 ! I I I I · .. 4-~a ' ' - -777"1 . '. I. · ' ' 31-6 · ....... .~___~.~ - . ,6 15 · . 4..' 'i ~/'.' . ~-t~, -' '.>"~/" 1, · · 1 .' ' 4~4-1'5 · ,...!,.,,,..~.. !~,.. · 11 ~Ebb: bO l:JLt IU £OUU 22-22 :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ ........................ ; ....... : ....... ~ ........ 2 ....... ; ....... ; ........ 1 ::::::::::::::::::::::::: ~.j uJ ~l DLG Sun Sep 10 11:05:27 1995 COILED TUBING BOP SCHEMATIC ARCTIC RECOIL STRIPPER BLIND SHEAR SLIPS/RAMS Unocal North Ame~'~' Oil & Gas Division Unocal Corporation 909 West 9th Ave., P,O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region March 31, 1994 Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, Al( 99513-7599 Re: 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are'requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same-format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 Atask~ 0il & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma 7~,;Dennis L.' ~~,r~ske Petroleum Engineer Attachment CC: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC , Form 3160- 5 (JUNE 1990) . , UNIT, ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPUCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas [] Well [] Well r"] other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit --- 19 wells Soidotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Expiree: March 31t 1993 5. Lease Deeignation and Sedal No. 6. If Indian, AJIottee or Tdbe Name · .. 7. If Unit or CA, Agreement De~ignation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Reid and Pool, or Exl~or~o~ Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION ~ Notice~of Intent Subsequent Repo~ [--] Final Abandonment r-] Abandonment r'] Change of Plans I-I Recompletion r-] NewConstructlon !-] Plugging Back r"] Non-Routine Fracturing O Casing Repair [-'] Water Shut-Off O Altering Casing E] conversion to Injection [] Other Temporarily Abandon [-] Dispose Water 13. Desca'be Proposed or Completed OpefaUons (Clearly state ail pertinent delails, and give ~ dab~. induding esttm~Ki ~ o~ a~arllng any peoposed wodc ff well is clirectlonally ddlled, give subeur'ace Iocatiorm and meuumd and true ~ depltm fo~ all ~ and a~te p~tlne~ to As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit I' * scu 23e-3 scu 243-a ~ ISCU 13-4 SCU 341-8 : <J I * SCU 21A-4 SCU 13-9 :~1SCU 34-4 * SCU 34-9 5' I * SCU 43A-4 SCU 14-34 / -O//_.-* SCU 21-8 *High GOR wells that may be produoed Intermittently. Swanson River Unit ~'; SRU 212-10 ./~SRU 14-22 $ / SRU 43-28 ~usf, SRU 14-15//-~/~oRU 12-15 C I SRU 14A-33 5/SRU 23-15 ~J SRU 23-225'u3pSRU 24-33 *SusI~SRU 34-15 ~l SRU 23-27. '/SRU 32-33WD %1 SRU 41A-151r~l~SRU 212-27 SRU 21-33WD 5~S~ SRU 43A-15G~ SRU 331-27 ~ U~ SRU 432-15 ~ ! SRU 34-28 Conditions of apprmmi, if any: RECEIVED APl:{ - 1 1994 T'~o 18 U,S.C. Set, on 1001, makes it a crime for any pemon knowing~/and willfully to make to any departnmnt or ageflcy of the United sa~§~,~ns. C0mmissi0r haudulent statements or repraserdations as to any matte~ wilhin ils ~Jrbdiction. *See Instruction on Reverse Side ~oh0rag8 Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for ,, Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A "/5-t5 SCU 13-4 ~o--I~ SRU 212-10 ~-~SCU 34-4 (~[-o5 SRU 23-15 ~-'z~..SCU 341-8 (~.-~o SRU 41A-15 (~;~-'l SRU 34-28 ez~5~{ SRU 14-22 (~-~ SRU 43-28 (m-t'~ SRU 23-22 ~0--t~r> SRU 32-33WD/zI-~SSRU 212-27 (~--b~ SCU 243-8 ~o-~q~ SRU 331-27 (~--Z SRU 21-33WD/,0~zZ, SRU 12-15 Ioo-~&SCU 14-34 ~o-qc/SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown ,, Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8' ~)-I~ SRU 14-15 SCU 13-9 (~0-~ SRU 34-15 SCU 34-9' SRU 43A-15 SCU 23B-3' %~-b[~ SRU 432-15 SCU 43A-4' -~_-o'~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells · *High GOR wells that may be produced intermittently RECEIVED APR - 1 1994 Alaska Oil & Gas Cons. Commissiot~ Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. SCU 21-33WD: Shut-in due to wireline fish in tubing, Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3' · SRU 33-5: Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover. tO RECEIVED aPR - 1 1994 U~l & Gas Cons. Commission Anchorage Alaska Region Unocal ,orth AmerioK.-~ ~::l~ '"/7 Oil & Gas Division Unocal Corporation P.O, Box 190247 C-OMa- ' Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 COMM COMa_ RES S_~ ~__._L~ UNOCAL ) ~ ~NG ~N~SGT J ~p~{~.~ ~ ~. ,~TAT TECHI March 24, 1993 ~ ~/¢ ~AT TE~'H~ FILE Mr. Joseph A. Dygas Bureau. of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in S_,,wanson:,~,~RiverFiel~t Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. -As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field biowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SOU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. REEEIVED MAR 2 5 199;5 Alaska Oil & Gas Cons. C0rnrnission Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company REEEIVED Alaska 0il & Gas Cons. Commission Anchorage Form 3160-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31,1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE i. Type of Well [] Oil Gas Well 1'~ O Other Well 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone No. P. O. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) (907) 276-7600 Swanson River Unit Soldotna Creek Unit .......... 17 wells 14well~ 12. TYPE OF SUBMISSION TYPE OF ACTION 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field ! I. County or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA [~ Notice of Intent F~ Subsequent Report F-'] Final Abandonment Notice '==1 Abandonment O Recompletion 1~1 Plugging Back DCa.sing Repair [] O~r Temporari 1 y Abandon F-] Change of Plans -']New Construction ~"] Non-Routine Fracturing D Water Shut-Off r--]Conversion to Injection C Dispnse Water {Note: Repofl results of mulliple complelion on Well Completion or Recomplelion Report and Log form.) ! 3. Describe Proposed or Completed Operations (Clearly suite ali pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, UnoCal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994: Swanson River Unit / SCU 21-3 / SCU 21-8*/°~ SRU 212-10 SCU 23B-3! SCU 243-8~ SRU 14-15' SCU 13-4 ~ SCU 341-8~ SRU 23-15~ SCU 21A-4 SCU 13-9× SRU 34-15 SCU 34-4~. SCU 24A-9~ SRU 41A-15~ SCU 43A-4 SCU 34-9'~ SRU 43A-15 SCU 33-5~ SCU 14-34c-' SRU 432-15 SRU 14-22~ Swanson River Unit SRU 212-27~ SRU 331-27 SRU 34-28~ SRU 43-28 v SRU 14A-33~ SRU 24-33~ SRU 32-33WD RECEIVED '" MAR 2 5 Alaska 0il & Gas Cons. C0m~'~ss't°r Anchorage * High GOR wells that may be produced intermittently. 14. ! hereby certify that foregoing ' t c correct sis-- ~~>~ '~~~ Petroleum Engi neer (This spac~ for Federal or Sta~o~ ) Date · · Approved by Title Conditions of ai~roval, if any: Tide 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States ~ny false, f~'titious or fraudulent statements *Soo Instruction on Novomo Sido Attachment No. 1 . · . Swanson River Field ProPosed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Shut-in Wells until the Field Blowdown Shallow Gas Potential Hemlock Future Shallow Gas Producer Rate Potential P & A~1 and 'Hemlock Only' P & A Producers with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SOU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8' SCU 13-9 SCU 24A-9 SCU 34-9' SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33{2) 5 Wells {~ Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 (2~ Scheduled 'Hemlock Only' P & A in March-April, 1993. · High GOR wells that may be produced intermittently. RECEIVED Alaska 0jJ.& Gas Cons. Commission 7tnch0rage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: Shallow gas producer (Tyonek). Shut-in mechanical problems. Workover candidate. · SCU 21-3: due to Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: · SRU 12A-4: · SRU 211-15 RetUrned to production after flowline repair. Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR ~ 5 199;~ Alaska 0il & Gas Cons. fjomm'~ss~o~' Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 cOMM do~M SR S~ Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: , rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC 3, 1 1991 Alaska Oil & Gas Cons. C0mmi~ion Anchorage Mr. I-A. Dygas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: . Hemlock producers, and wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last year's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerely, J[ C. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment C~ L. C. Smith, Chairman AC)GCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation R[C£1VED Alaska 0i} & 6as cons. ComiU'tss'tot~ ORIGINAL Form 3160-$ (November 1083) (Formerty 9.-331) UNITED STATES ,,,..tT m T,,.~.ICA~I* (Other laatrueUoae os D~ARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT 'SUNDRY NOTICES AND REPORTS ON WELLS ids not U~ thin form for propo~lo to drill or to deepea or plug back to a ~lff~reat reservoir. UM "APPLJCATION FOR PERMIT~" for audi DrolmmdL) N&tda O1' OPal&TaB ARCO AlaSka; Inc. P.O.Box 100360 Anchorage, AK 99510 coci?lo~ or ~'gLL (Report Io~lttou clearly and lo &¢<~rdanc~, with any SCt~ requirements.· See also olmee l? below.) Form approved. i~d~et Bureau No. 1004-0135 Expires Au~tst 31. 1985 fi. L,I&II OlIIOX&TIOl 41D 111¼L I0. I. ri' IlOIil, AL~4~ll OI TIIBI 7. UII~ AOIIIMIN! Soldotna Creek/Swanson Rv 8. f&lll OB LB&lB IaMB 0. WILL fO. 10. IIILO AND ~f-, OB WILD~A~ Swanson River unit 19wells Soldotna Creek Unit ...... 13 wells PIIMi~ ~O. I IS..~&~oNo (S~w w~efJ~r off, I Swanson River Field lie** f** L, If** OB ILL ~1~ IUIVB! OR &BI& KenaiI Alaska 16. Check3 Appropr, ate Box To IndicaJe Nature of Notice, Report, or ~ Data NO'~ICB Off INTBN~FION ~O: . . 1Oltl~UIIf Illq)lJ 01~: w&~al ISlOT-Off ~ IBI~AIIFIOWILL (Other) , U Mm W I J (N~: Re. ri relulW ~ m~ ~e ~ oB ~omple.on or R~ompleflon bpfl end ~ fo~) (othe,) Temporary Abandon IT. Dh;SCRIBE I'IOPOaED oR co.~tPLEXEo oP~aA?lO.X8 (Clearly state all I~rtlnp,tt de~ttl~, and =lye ~rttnenC dmt& Inelud~ ~ml~ ~M ~ l~ uy p~ worL If ~1 b di~o~ dfiil~ five ~~ ~uno and meas. r~ and true vertl~ dep~ for~ ms.em ud Mm ~- ~nt M ~ ~L) · As d~ in ~e attached memo, ARCO Alaska, ~c. requests that the £oUowing we]~ have a tem~~y abandoned status: Soldotna Creek Unit SCI./ 235-3 SCU 21-8 SCU 12A-4 SCU 341-8 SCU 13-4 SCU 13-9 SCU 21A-4 SCU 24A-9 SCU 34-4 SCU 34-9 SCU 43A-4 SCU I4-34 SCU 33-5 Swanson River Unit SRU 212-10 SRU 14-15 SRU 23-15 SRU 34-I5 SRU 211-15 SRU 41A-I5 SRU 43A-i5 SRU 432-I5 SRU 14-22 SRU 21-22 SRU 23-22 SRU 23-27 SRU 212-27 SRU 331-27 SRU 34-28 SRU 43-28 SRU 14A-33 SRU 24-33 SRU 32-33WD * -High GOR wells that may be produced intermittently. 18. I hereby ce~Ltr3~t:l~t-the fo. refoinf ti trae and correct ~ RECEIVED , DEC 3 1 1991 Alaska 0il & Gas Cons. Commia ..... , ~ TXTLE Actinq Reqional EnqineerDA~ (This sp~ce for Federal or 8mt~ of~ce m) APPROVED BY CONDITIONS OIP APPROVAL, L~ ANT: TITLE DATB *See Instructions on Reran Side Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'HemloCk Only' P & A :i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:!:i:i:i:!:i:i:i:i:~:!:!:!:!:i:!:i:!:i:i:i:i:i:!:~:i:i:i:i:i:i:i:i:~:i:~:i:i:~:i:i:i:i:i:i:i:!:~:i:i:i:~:i:i:i:~:~:~:i:i:i:i:~:~:i:i:~:i:~:i:~:~:~:~:i:i:i:i:~:~:i:i:i:i:i:~:i:~:i:~:i:~:i:i:i..i:~:~:!:i:i:~:i:i:i:!:i:i:i.~:i:i:i:i:i:~:i:~..~:i~..i:~..i:i.!:i:~:i:i:i:~.i:i.i:i:i.i:~:i:i:i:i:i:i SCU 12A-4 SCU 13-4 SCU 21A-4 SRU 212-10 SCU 14-34 SRU 211-15 SRU 23-27 SRU 23-15 SRU 14A-33 SRU 41A-15 SCU 34-4 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 43-28 SRU 32-33WD SRU 24-33 11 Wells 9 Wel~' 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned i:i:!:i:i:i:i~:!:i:i:~:!:i:i:i:!:!:i:i:!:i:i:i:!:i:i:~:i:i:~:~:i:!~:i:i:i:~:i:i:i:i:i:i:~:~:i:i:i:i:i:i:i:!:i:i:i:i:!:.~!:!:i:i:~i:i:i:~:i:~:~:i:i:i:i~:~:i:i:i:~:i:~:~:~:i:i:i:i:~:i:~:i:i:i:~:i:~:i:i:i:i~:i:~:i:~:i:i:~:~:!:~:!:i:~:~:i:i:!:!:i:i:i:::i:i:i:~:i:~:i:i:i:i:i:i:!:i:i:i:i SCU 21-8 * SCU 13-9 SCu 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For:. Temporarily Abandonment Sundry 12/27/91. Attachm~.nt 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) RECEIVED DEC ct 1 1991 Alaska Oil & Gas Cons. Commiss~ Anchorage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, maY be produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is also 'being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU. 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SKF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21-15 & · SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED Alaska Oil & (Jas Cons. ~ummissio~, Anchoraoe t. ARCO Alaska, Inc!~-~ POst 0'*,,, c=. r=~x 400360, Anchorage. ~i~.s~a 995 !.0-0360 Te~ecnc?e ¢07 2-5 En§~,r~eer:nq December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a Period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1. Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have been attached for your information. Brief explanations are given for each well that has been added or deleted from the temporarily abandoned status (Reft your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of currently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call Stacy Strickland at.263-4914. Sincerely, Tom Wellman ' TW:SLS:jt:0016 Attachment · cc:-~C. V. Chatterton, Chairman AOGCC A. R. Kukla, Marathon Oil Company · S.W. Ohnimus, UNOCAL Corporation RECEIVED DSc2 1989 Alaska Oil & Gas Cons, Commissi . Anchorage . ~TED STATES Form 3160--S ~No,.-~., ~ D~ARTMENT OF THE INTERIOR (Fo~erty 9--331) ~UREAU OF ~ANO ~ANAGE~ENT SUNDRY NOTIC~ AND REPOR~ ON ~L~ (~ ~oe ~ ~ ~o~ for p~lm to d~l or ~o d~ or pl~ ~c~ m & ~m~ ~ol~. Um -~~ON ~R ~M~*' for ~ iii Form approval. Budcet flumeu No. 10~'~= 0135 l~xl)iml Au&Gat 31. 1985 ?. UI~T &OUaMauf,~ R&&ig 1. N&JilIl 01' OPIIA~Ol 3. &DDIII~ Off OFIIA~)I oldotnaCreekZwanson ~v~r units 10. ~.~A &HO ~GL, OB WILOCA~ Post offfce Box 100360 Anchroage, AK 99510 LOC&TIOI~ OF wILL (Report location clearly iud In accordance with any Sm~e reqai~e~8,· See also spate tT I~low.) &t surface Soldotna Creek Unit - 11 wells Swanson River Unit - 20 wells 14. l'llUlT NO. I16. ,mVAT~ONA (Sbo~ whir Off. IT, Oa. eM,) ,~wmncnn ~;~/nr I=imld 11. Sl~., ~q I.q if** OI ~L]r. ,UrD · UIVBT OB All& Kenai Alaska 16. Check Apomoflate Box To Indicate Nature et Notice, Reoort, o, Otbtr DaM IIO~ICBOffINTIN~ION ~: REP&II WILL I ] CH&~GB PL&~8 IOther) TemDorar i ly abandon , IUBOB~BI~ U~qla~ ~: i, IAc,rg# l'lJifllllPI . LLI~IIIJa I~AIIIRO IIOIR*IIO OB AClDttilll &lillMIIdlJT° (Other) No~u: Relmrt_r~aim. ~ mul_Ugde eomMeUeu om .Wall ompletloA or seeom~auon ~e~fl -nd ~ teaL; lT. DI~,.~rRII3£ [*RO['OSgD Oil COMPLgTED OPgAAI*ION~ (Clearly state all ~rtiaenC detail., iud =lye ~rtlneot ~t~ llelud~ I~IM data nefl~ ~ ~ ~rL) · As deScribed in thc attached memo, ARCO Alaska, Inc. requests that thc following wells have a temporarily abandoned status' $oldotna Creek Unit Swanson River Unit SCU 13-3 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 24-5 SCU 33-5 SCU 33-8 SCU 341-8 SCU 34-9 SCU 31A-16 SCU 14-34 SRU 34-10 SRU 23-22 SRU 14-15 SRU 312-22 SRU 21-15 SRU 23-27 SRU 211-15 SRU 314-27 SRU 331-27 SRU 31-15 SRU 34-28 SRU 34-15 SRU 43-28 SRU 41A-15 SRU 14A-33 SRU 43A-15 SRU 24-33 SRU 32-33WD SRU 432-15 SRU 12-34 RECEIVEC 2 91989 Alaska 0il & Gas Cons. C0mn '. Anchorage 18. [ bere0y certify tlmt the fore~oLu~ ts r~de &nd eorFe~ TZTLE ~ook Inlet Enginerring Managm~z~ (Thio opec~ for F~ or SliCe ob mi APPROVED BT CONDITIONS OF APPROVA/~ IJ' ~: TITLg DA~ /z o z ?-8,c? '~ Indmctiom on R~ SkJ~ Title 18 [J.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or a~enc7 of the United States any false, fictitious or fraudulent statements or represefltl~ons as to any matter wtthm tis )urtsdicclo~ TEMPORARILY ABANDONED WELLS IN SRF Wells under Evaluation Rate Poten[ial Wells being evaluated for P&A/Future Utility Wells SI for Inefficient producti..,o, n Wells S! until Blowdown 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-27 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 21A-4 33-5 34-10 43-28 24-33 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Tem_oorarily Abandoned Status: SCU 21A-4: Well is temporarily abandoned due to inefficient production (high GOR). SRU, 32-33 W D' Well is temporarily abandoned due to annulus communication problems. Removed from Temporarily Abandoned Status: $cu,, 243-8' productiOn. This shallow sands gas well has been returned SCU 13-9' A workover is planned for this well which will enable this well to be returned to an active status. SRU 212.10' This shallow sands gas well has been returned to production. SRU 23-15: This gas-lifted well has been returned to production. $RU 21-34: A sidetrack is planned which will enable this well to be returned to an active status. RECEIVED D c2 1989 Alaska Oil & Gas Cons. Commtssio[~ Anchorage For: Temporary Abandonment Sundry of 12/29/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* SCU 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed on~ temporarily abandoned O~c 2 91989 Oil ~ ~as Cons. Anchorage Commi~ioo For: Temporary Abandonment Sundry of 12/29/89 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United'States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph' Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 idays. ~ The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories' 1. Evaluate for rate potential 2. Evaluate for plug and abandon/fUture utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB' JWR: ch' 0006 Attachment cc' C. V. Chatterton, Chairman ' Alaska Oil & Gas Conservation Commission Form 3160--5 (November 1983) (Formerly 9--331) u,~ITED STATES s,,~,,T m (Other Jal~et~onl on DEPARTMENT OF THE INTERIOR ,er. rid,) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not aje this form for proposals to drill or to deepon or plug back to a different r~ervolr. UN ,'APPLICATION FOR PERMIT--" for such prop~dML) wELL WELL OTllaB NAME Or OPESATOI ARCO Alaska, Inc. 3. ADDlflI Of OPBBATOB P. O. Box 100360 Anchorage- AK 4. LOCATION or WSLL (Report location clearly and I~ a~cordanc~ with any State ~equir~--:--entLe Se~ also space 17 b~low.) At sqrface Soldotn~ Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 14. paBMIT NO. J15. SLaVAT~0NS (Show whether Dr, al', OR, etc.) Form approved. Budget Bureau No. 1004--0t35 Expires August 31, 1985 5. LIAII DIIIONA?ION AND IB~IAb 00. INDIAN, ALIBI 0N TRIalS NAMI~ ?. UNII* AOIrlIMINT I~AMI CreekYSwanson River Unit Film OB LlAaf NAMll Wild4 MO. 10, fIELD AND POOL; 0a WILDCAT Swanson River Field 11. IB~., ~.~ L, Ifq OB BLS. AMD IUBVN! OB ~mmA Kenai J Alaska Check Appropriate Box To Indicate Nature °f Notice, Repod, or Oiler Data NO'tiCS Of INTBNTIO~q TO: TEST WATER SHUT*Off '~ BBIsAIIIWO WELL ~ · AL~BRIMQ CAIIN~ P~LL OR ALTER CASINO ] I WATBB 8BUT-Off FRACTURE TREAT MULTIPLI COMPI.ETE J.~~J FItACT~BB TRIATMINT SHOOT OB ACIDIZI ABANDONe SHOOTINO OR ACIDlalNo ABANDq)NMBMTe REPAIR WELL CHANGE PLAN8 (Other) (NOTE: Report results or multiple completion on Well (Other) Temporarily abandon ~-. Completion or Reeompletton Report and Log form.) Dk;SCRIU£ i'ROI~OSED OR COMPLETED OPERATIONS (Clent*ly state all pertlnP,t details, and stye pertinent date8, Includlnw estimated date of starting any proposed work. If well is directiontlly drilled, five subsurface loc~tions nnd mean, red and true vertical depths For all markers and ~ones perU- neat to this work.) · As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON'RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SRU 23-22 SCU12A-4 SCU 13-9 ~ SRU 34-10 SRU 22-23WD SCU 13-4 SCU12A-IO SRU 14-15 SRU212-27 SCU323-4 SCU343-33 SRU 21-15 SRU314-27 SCU43A-4 SCU 14-34 SRU 31-15 SRU 23-27 SCU 24-5 SCU 14-3 SRU 432-15 SRU331-27 SCU 33-5 SCU23B-3 SRU 34-15 SRU 34-28 SCU341-8 SCU 34-4 SRU41A-15 SRU14A-33 SCU21A-4 SRU43A-15 SRU 24-33 SRU312-22 SRU 12-34 SRU 21-22 SRU 21-34 18. [ hereby cert~J~at the for, t~otng l~/~r'de and correct SI ~. . -..~ TITLE (Thin space for Federal or 8tale o~ee u~e) APPROVED BY CONDITIONS OF APPROVAL, /]' ANY: TITLE DAT~ *See Inductions on Revme Side Title 18 U.S.C. Section t001, makes it a crime for any person knowingly and willfully to make to any department or agency of the .................... ::_.;,~ ...... (r ....,4,,I,~.~+ e+n*~,m,~nte ~e ~d~nr~qentnti~rte aS to anY matter within its jurisdiction. TABLE Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Uti 1 i tS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSHITTAL TO: COMPANY' DATE: FROM: J-J, COMPANY: J/3, J~_e~ , WELL NAME: .~' ,"'L~4.. Transmitted herewith are the following' PLEASE NOTE- BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy RFCEIV APR n ~, Oil & Gas Cons~ Receipt Acknowledgment- Date: Return ReceiPt to: ARCO Alaska, inc. AT. TN: Judy Boegler AT0.-579 Po§~ Office Box 100360 Anchorage, AK 99510 1Precision Wireline P.O. Box 3905 ,_. ~-,~/Soidotna, AK 99669 - TIME DEPTH PRESSURE TEMP, -- , ,,, : ....Company j~'~_((~ r~,~~ ~ ~'wo-~J~o o ~0.~ ~0,0~ Field I.D. ~~~~ ~'~'/~'10 ~0 ~ ,q~ ~.~', ,, Tubing PSi , Casing PSI e Depth of Instrument ,[[ ~OMO I~;z~ -~:3~ 9~ ~¢~,~& J~ , ~' Date No. 1 ~_q_ ~) /~O~-~t/y I1_ o 17 Date No. 2 Inst NO. 1 ~~W Inst ~o. 2 At Depth (Date~ime) R E ( ?. 1Y [ D Off Depth (Date/Time) Shut in (Date~ime) ~f~chor3ge Remarks: ) ACKNOWI.,I.';I)CI,ihU..'HT OF REC[.:Ji'T OI ,:'~;iEi.t[AI, - (AI,A[;I':A) DEPT.: Fl)- l':o].d(:d 1[ - Ro!.Led S - Scl)La F -Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF bhXTERIAL ENCLOSED HEREIN. PLEASE CtlECK AND A.DV/SE.,Ii,fMEDIATELY. COMP. ANY WELL " HISTORY LOG 2'" 5" ! I . 100 200 ti II l! ti 'U ti ti II tt rtl ti , 11 RECEIVED BY Box 937 Roc~ Springs, C,- A 'White tNire~Line Well-ServiCe Area Code 307 TeJ. 362-6488 BOx 157~.~-: Casper;Wyoming 82601 SUBSURI:i6,CE~-PRESSURE SURVEY Producing Formation Elevation (CHF, DF, KB, etc.) 329-~ ( ) ( ) Datum }1,23.'7' subsea, or :- . Tubing set at ]_ ~255 Casing set at 1159/4, Production Packer at Perforations _.~]: 208-1! 25LI' Subsurface Controls (Nipples, etc.) Instrument Data ' Company Running Survey C · A. Whi~ce ~ Element - Range & No. Clock - Range & No. ' Calibration Date Static Pressure Data Pressure at Datum @ ) 11237 4! 94 psig ............ Shuit-in"Time ................ ) ........................................... hrs. Pi at Datum- Shut-in Tubing Pressure :Shut-in Casing Pressure Top of Oil ' Top of Water Temperature at ~2~? feet Date of Last Test Pressure @ Datum, Last Test Shut-in Time, Last Test Flow Test Data K2-9280 6000psi 3 Hr. , April 1,1975 1205 psig psig °F psig Choke Size Period of Stabilized Flow Stabilized Production Oil in hrs bbls/day MCF/day bbls/day Gas Water Flowing Tubing Pressure Flowing Casing Pressure psig psig Remarks: Operator_. N..-.-f~= Hopper Box 962 Soldotna, Alaska 99669 Area Code 913 Tel. 262-4496 Company- ' S~Dc] ard iD 5 '1 Company Lease.- · gl~'U Well Field.-~w~'m-g. on ~v~w ' State A~ ~ska . , rest Date. Apri q 14, ~ 975 Zero Point KB ' . ..... GRD Dept? D 20£ 60¢ 80C .ooc .02C .04C .o6c .08C .08~ .08~ Time Press., A P, psig 1210 1278 1395 2120 3003 3880 3958 4042 4125 4188 4191' 4194 Static Test Press. At rubin Press _ Casing Press. nar COMPLETION REPORT - PACKER A~D GAS LIFT INSTALLATION STANDARD OIL COMPANY OF CALIFORNIA -WESTIN OPERATIONS INC. - Operator AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No. : A-028406 PROPERTY: Swanson River Unit WELL NO.: SRU 23-22 Section 22 T 8 N., R. 9 W., Seward B & M LOCATION: Surface: 2120' South and 2010' West from Northeast corner of Section 22. Bottom Hole: 1834' South and 1046' West from surface location. ELEVATION: 329 ' K.B. K.B. is 15 ' above ground. DATE-June 29, 1963 BY: C.?.-CHATTERTON, District superintgndent ~1 , 1, i i , - ' ' ~'' ' , , i , , il i 11 , , il . i ii ' i . iJ '"!' ,ill i i i , . i~ I, ll, CONTRACTOR: Santa Fe Drilling Company, Rig #35 · DATE COMMENCED REMEDIAL WORK: January 26, 1963 _ i 11 il Il 11 , Il I ' I 11 I DATE COMPLETED REMEDIAL WORK: January 29, 1963 / ~lli - ~ Ilia ! I Il I I ' S~ TOTAL DRILLED DEPTH: 11,614' PLUGS: 11, 332 ' - 11,594' TOTAL VERTICAL DEPTH: 11,237' CASING: 22" cemented at 28' 13 3/8" cemented at 3000' 7" cemented at 11,594' COMPLETION REPCRT - PACKER AND GAS LIFT INSZALLATION SWANSON RIVER UNIT 23-22 Section 22 T. 8 N,, R, 9. W,.:. Seward B & M STA'I~JkRD OIL' COMPANY C~ CALIFORNIA, ~STER'N "OP~TIONS';' IN~'. - 'Operator 26, 1963: Commenced rigging up at 7:00 AM. Conditioned Black Magic Mud. ~ .a~..u. ary 27,. 1963: Killed well, removed x-mas tree and installed BOPE. Pulled tubing loose, ran to 11,244' and circulated before pulling out of hole. Ran casing scraper and cleaned out to 11,290'. J.anuary 28,_ 1963: Circulated and conditioned mud at 11,290'. Pulled. Reran a total of 357 Joints 2 7/8", 6.5#, N-80 EUE 8R Rg.2 tubing equipped with packer and mandrels. TUBING DETAIL K.B. to landing head Donut 54 joints 2 7/8", tubing Camco Mandrel w/plugged 46 joints 2 7/8" tubing Camco Mandrel w/plugged 41 joints 2 7/8" tubing Camco Mandrel w/plugged 33 joints 2 7/8" tubing Camco Mandrel w/plugged 30 joints 2 7/8" tubing Camco Mandrel w/plugged 26 Joints 2 7/8" tubing Camco Mandrel w/plugged 22 joints 2 7/8" tubing Camco Mandrel ~w/plugged 50 joints 2 7/8" tubing Ca~co Mandrel w/plugged 50 Joints 2 7/8" tubing Camco Mandrel w/CEV 1 joint 2 7/8" tubing Brown CC Safety joint R 20 valve (#1) R 20 valve (#2) R 20 valve (#3) R 20 valve (#4) R 20 valve (#5) R 2o (#6) R 2O v ve (#7) 2O valve (#8) (#9) One 2 7/8"i pup joint Brown 2 7/8" X 7", HS-16-1 packer 2 joints 2 7/8" tubing Camco "D" Nipple 2 joints 2 7/8" tubing Venturi Shoe Tubing landed at Removed BOPE and reinstalled x-mas tree~ K.B. Depth 20.00 ' .85' 20.85' 1700.67' 1721.52' 13.07' 1734.59' 1446.18' 3180.77' 13.10' 3193.87' 1293.14' 4487.01' 13.O5 ' 4500.06' 1032.19' 5532.25' 13.07' 5545.32 ' 918.60' 6463.92' 13.10 ' 6477.02 ' 800~39 ' 7277.41' 13.06 ' 7290.47' 683.64' 7974.11' 13.00 ' 7987.11 ' 1545.62 ' 9532.73 ' 13.09' 9545.82 ' 1525 o 89 ' 11, 071.71 ' 13.10 ' 10, 084.81 ' 30.35 ' 11,115.16 ' 1.07' 11,116.23] 10.05' 11,126.28' 6.00' 11,132.28' 60.92' 11,193.20' .91 ' 11,194.11 ' 60.66 ' 11, 254.77 ' .65' 11,255.42' 11, 255.42 ' January 29, 1963: Displaced mud with oil, set packer at 11,126' and returned well to production. Rig released at 10:00 AM. sat S.R. Hanson WELL RECORD INVENTORY Fi e l d: ' Swanson River Unit Location _ T8N.RgW. Sec.. 2.2. S,?,M..,,,. Operator & Wel I Name: ....... Standard Oil Co. Unit #23-22 l. Drilling Pemit: No. Pages 2. Survey Plat: 3. Monthly Reports (P-3): 4,. Completion Report (P-7):' 5. Well History: '. . . 6. Other: Core Analysis I{eport -Plan of .8.u.,b.-Surfa,ce Survey. 7. Mi s cel 1 aneous: ~ Total Pages: 8. Deviation Survey(s): 9. Well Logs: _(1) sL (2) M L _(3). cnM .(.4) . om,].... (5) mm (6) T_.BL m ' (7) (8). _(_9)_ (.~o), ,, UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS The fo~lou,in~ is a oorreet report of operatiot~,s a:~d prods, etlon ('includi~ drillin~ a~d producin~ ~ ~work ~o~need :!-26-63. ~~ a 7/8 $N 9W ~ dial~ . e~u~e~th ~ek4r an~ GL m~[s. ~n~ed tubing at yster (2) all fe - $. B. Hair, a: erry Owardi petreleUm · of N: No, im.--There were ........................................ runs or sales of oil; .................................. M cu. ft. of gas sold; ............................................ run~ or sales of gasoline during the month. (Write, "no" where applicable.) No~tteport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplieate with the supervisor by the 6th of the succeediag month, unless otherwise directed by the supervisor. OIL AND GAS CONSERVATION COMMITTEE i. · i i i i ill WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ,,. TYPE or w~,'~,L: o,,~,,.~:L,, []~ -"*~',~ELL ~' D~ [] O~h~ b. TYPE OF COMPLE~ON: WELl. OVER EN BACK RESVR. Other , ,,i 2. N&ME OF OPERATOR SUBMIT IN DUi ,ATE* STATE OF ALASKA (Se. other In- st ructions on reverie side 3. ADDRESS OF OPERATOR ; ' 4. LOCATION 0F wELL-(-Report location clearly and in accordance with any State requirements)* At surface AP1 NUM.ER/CAL CODE LEASE DmlGNX~O~ ~D SER~L NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NA/VI.E 8. UNIT,FA.r{~ OR LF~kSE NAME 9. WIKLL NO. 10. FIELD AND POOL, OR WILDCA.T 11. SEC,, T., R., M., (BOTTOM HOLE OEMEC~IVE) At top prod. interval reported below At total depth I-~OW 1V/A.NY* ROTARY TOOLS PRODUCING !N~ERVAL(S). OF THIS C(~MPI-~TIO~N'--TOP, BOTTOM, NAME (1VID AND TV'D)* 12. PERS~[IT N'O. i RT, GR, ~rC)* 117. ELEV. CASINGtIEAD INTERVALS DRILLED BY CABI,E TO01,S 23. WAS DIRECTIONAL SURVEY MADE 24. T~'PE ELECTRIC AND OTHER LOC;S RUN CA. SLNG SIZE Xz 26. LINER P~COL-~E) ' " ' .~ ~ TOP (?,!p) 13OTTOfI (liD) SACKS CEMENT* ~8, PERFORATIONS OP~ TO pRO~U~ON" (interval size and nurnbe[) ' CASING RECORD (Report all strings set in well) · ~,4 _ ~-~,/~ CEIILNTING RECOILD AR¢[OUNT PULLED i iiii iii i DEPTH SE/' (MD) PACK. ER SET (?,iD) $Ci~EEN (~{D) SIZE 29. ACID, SHOT, IF;IAC'~ O'RE, C~',IENT SQULEZ2, ETc. i i i ii i i 30. PRODUCTION DP, PT'Ii 1NTERV.~L (MD) A.:M. OUNI? AND I'2!ND OF MA1E?.'AL USE/) DATE FIRST PI%ODUCTION I IFI~oDUCTION ME'IHOD (Ftowh~g, i::aJ lif~, pumping--size and type of pump) ' [V/ELL STATUS (Producing or _ . ~ ~' , .... ~6%v, ~BING ]CA~'G PRESSURE [CAL~T~' ~I~BBL. GA~-~. I~SS. ] . i'4-HOUR RA* t W*~BBL. OIL GRAVITY-~I (COaR.) ITEST' WITNESSED BY 32. LI~T OF ATTACHMENTS ....... 33. I hereby certify that the foregoing and attached information is complete and correct as determined f~om all-avatlabl~ records SIGNED ~ ~t & B~ ~ I~ H TITLE DATE I'~--q'-~Y i i i i i i i iii *(See Instructions and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting e complete and correct well completion report end' log on all types of lends and leases in Alaske. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth meesure- ments given in cther spaces on this form end in any attechrnents. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv0l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additionel interval to be seperetely produced, show- ing the additional data pertinent to such interval. Item26: "Secks Cement": Atteched supplemental records for this well should show the details of any mul- tiple stege cementing and the location of the cementing" tool. Item 28: Submit a separete completion report on this form for eech interval to be separately produced. (See instruction for items 20 end' 22' above). 34. SUMMARY OF I~O~LMATION 'T'F~f~ INCLUDINC; 'iNT'E~VAL TF, STED. PJ~E?'~SUR£ DATA,'AN'D:'RF~OVERIES' OF OIL. GAS,- WATm AND MUD' ... ..... ~ ~ ~ s ~ ~ . A'N~ t~l).~lg~ SiiO'W.S OF' OIL, - . . _ 'CCMP~TION REPORT - NEW WELL STANDARD OIL G~PANY CF 0ALIFORNIA - OPEP~TOR ~ il , ! i l-I]_~ ! I, I i I I I I I I 0~! & G~s Section · .' n o£ Mitres ~cl Alaska' ue~" - "- 1AND OFFICE: Anchorage Lease No. 028406 AREA: Kenai peninsula - C~ok Inlet Area PROPERTY: -SWanson River ~it WELL NO.' 2.3-2.2.. .... ~o 22.(projected) T. 8N , LOCATION: Surfaces 2120~South and-2010' West from Northeast Corner Seotion 22. l~ttom Itole: Approx. ~30' South and 1050' West from surface location of well. . E~VATiON': 329:' ~': KB is 15' above ground. . . ':' DATE, lPriI 21~ 1960 i: BY ....... - : "', :- ' ~ " ' '" J.T. Crooker ~ -.District Superintenden~ " DRITJ.~,D BY." ceastal Dril~ng Company DATE COMMENCED DRILLING:' ~January 4, 1960 DATE cmpLETED :DRILLINg= ~arch 9, 1960 DATE_ OF INITIAL PRODUCTI~: PRODIJ¢ T [0~: ~ty Average_ ~'-¥ ~/.~ i12 days Water i]'2 B/D Flowing Gravity 33° 12OO .s.i. Tubing Pressure tO/64~ Bean SUMMARY TOTAL DEPTH: :11,240' T~ PLUGS: 11,594' - 11,132' 11,614' TD~ _ Well SRU ~32-22 aband°nedi~and redrilled from a depth of 4751' ~S_..~.all..SR~..~2~.22 'REC[IV[I) _ MAY 12 1960 Oi} a Gas Section Division of Mines and Minerals Alaska Dept. of Natuxal Resomv~s COMPIETION REPORT SWANSON RIVER UNIT 23-22 ..S. ecti.0n..22~. T......8 ,~.~.?~ R~. 9 ~., Seward B~M STANDARD OIL CO'~ GM CALiF~NIA, 'OPERATOR Page 2 .~ARY,_ CONT'D; CASING: 22" cern 28' 13-3/8" cern 3000' .~using 1000 sacks eement around shoe and 1000 sacks through c~llar at 987'. 7" cern ..11,594' using 810 sacks cement around shoe and 1000 sacks cement ~h~ough collar at 7197'e PERFORATIONS: WSO at 11,197' 5 - ~" ho:~s at 11,197' 4 _X~" ho~es per foot 11,246'-11',218' · 11,208'-11,200' COMPLETION REPORT SWANSON RIVER UNIT 23-22 Section 22~ T. 8 N.~ Ro 9 W~, Seward B&M ~T~[NDARD OIL CO.' (~F CALi~'OI~..IA" OPERATO~ Page 3 - WORK DONE NOTE:' SRU 23-22 is a direCtionally drilled hole utilizing the upper portion of abandoned driller: SRU 32-22. · Januar~ 4, 1760 CO cern plug 4677-4707~, set WS #1 $ 470%'. Unsuccessful in attempt to side- track old hole. 87-89 pcf January 5, 1969 Set WS #2 @ 4728'. Unsuccessful in attempt to sidetrack old holeo Januar~ 6~ 1960 Set WS #3 at 4751'o Direc~ionally drilled 7-5/8" holeo 4751' - 4763' 12~ drilled 87 pcf ~,anuar~ ?-8, 1960 Opened 7-5/8" hole to 10-5/8" 475i~ - 4763' 12'. opened Directionally drilled 10-5/8" hole. 4763' - 4860' 97' drilled Cored 8-1/2" hole. 4860! - 4891' 31~ cored 88-89 pcf Core #1 4860'-4881' 21~ cored O' recovered Core #2 4881'-4891' 10' cored 4' recovered 1-1/2' sandy siltstone. Massive, sandy, medimu grey finely micaceous siltstoneo No dip. 2v Grey sand° Fine grained massive friable to crumbly, micaceous, sub-angular, well sorted ~rey sand. Faint dull fluoresence~ uneven tan staining with thin coal laminae° ; Carbonaceous s[ltstoneo Brownish grey, lignitic, siltstoneo Twisted in coring, may have plugged barrel° 6t No recovery~ COMPLETION REPORT SWANS ON RIVER UNIT 23-22 Section 22, To 8 N., R. 91 STANDARD" OIL OO"o'"OF 6ALIFOi [o,, Sew, srd 'B&M ~tIA, OPFi~AT~ Page 4 ,J,,,a,nuar~ 8, ,!96q DST ~l (_HFT)486~-4891'- ~ HOWCO tester on 4½" DP W/lO00' WOo Set pkr @ 4869'. Tester makeup Consists of outside PRD, outside BT, inside PRD, 8' perfs, 8½"' pkr, safety joint, jars, inside BT, hydrospring tool, iO0(~WC (3 stds DC's, 8 stds DP), 2 singles air cushion, TC valve, 1 single (dry), bar drop reversing sub. Opened tester for 32 m. in ISI" 5:55 PM. Opened TC valve to ~" for flow test @ 6:27 PM. Faint steady blow for i rain, th~n dead° At 6:29 PM blow started again as fluid dropped in annulus° Filled annulus as fluid continued to drop° Pulled packex* loose @ approxo 6~45 PM. C~arts indicate partial plugging in perfs thruout shut in period. Test inconclusive° Approx. Pressures IH ISI IF FSI FH Outside BT 31OO 2000 2000 2000 3125 Inside BT 32~ 1300 1300 1300 3200 Drilled 8~" hole 89 pcf 4891' - 4896' 5' drilled January 9, !96~O DST ~2 attempted ~ Inte~l 4874 - ~896'. Pkr would not hold. Opened 8~"' hole to 10-5/8":o 4896 ' 36' opened° Directionally drilled 10-5/8" hole 4896' - 5109' 213' drilled 89 - pcf January 10, 1960 Directionally drilled 10-5/8" hole 90 pcf 5109' - 5180' 71' drilled Cored 8½" hole 5180' - 5208' 28' cored Core #3 5180-5208' 28' cored 28' recovered 9' Carbonaceous c~stone. Poorly bedded very finely micaceous, hard, brownishgrey claystone with common carbonized plant remainso Some slickensides in one coal streak° Dip 8° ~ o -. I1, good° COMPLETION REPORT ~ANSON RIVER U~iT 23-22 Section 22~ To 8 N.~ R. 9 ~o, Seward B&M STANDA~D 0IL'-CO. ~F' C'A~I~O~IA',' oPERAT0~ Page 5 Core #~, cont.'d, 11' Grey sand. Medium to fine grained, massive finely micaceous, friable grey s~nd with varied dolored grains o N(kcC but a very dull fluor~sence. Faint tan color to core. Local rounded pebbles and carbonized material. 8' Claystone. Medium grey, very finely micaceous, ba~, locally carbonaceous claystoneo Some slickensides and fractures° Directionally drilled 8½" hole sg½ pcf 5208' - 5212' 4' drilled Jauuar~....!l, 1960 Ran Schlumberger Micro caliper log to check packer seat° Recorded interval · 4763 ~-5213 '. ~ DST #3 (EFT) 5193-5212' Ran HOWCO tester on 4~-" DP w/2028' WCo Set pkr @ 5193'o Tester makeup consists of outside PRD, outside BT, inside PRD, 5' perfs, 8½" pkr, safety Joint Jars, inside BT, hyirospring tool, 2028' WC (3 stds DC's plus 19 stds DP), 2 singles AC, TC valve. Opened tester for 30 rain ISI" 11:38 AM° Opened TC valve to }" for I hr 17 rain flow test" 12:O8 AM° Medium steady blow to strong steady blow in 15 mino Cushion to surface @ 12:~5 PMo Gas to surfac~ @ 12:30 PM. Shut in for FSI @ 1:25 PM. Pulled pkr loose @ 1:55 PM° Outside BT clock stopped @fret 15 mino Rec 700' water in DP, bottom 1OO' of which was muddy. Chlorinity 88 G/Go Chlorinity ~f cushion water 14-20 G/Go Considerable atomized water in gas %hruout test. Gas stream would not burn uo~ttnuously w/o torch being held adjacent to it. PRD charts indicate partiml plugging in perfs after approxo 15 rain of fl~ test. Outside PRD chart indicates ~OO-350 psi drawdown during flow test° Stabilized flow rate approx. 1o5 MMCM/D at 200 psi surface pressure° Baroid test of sample indicated all methane° Pressures: IH ISI ~ FF FSI FH Inside BT 3202 2172 1916 946 1925 3128 Outside PRD 3250 2170 1980 1840 1920 32}~0 (approx.) January 12-14, 19~60 Opened 8½" hole to 10-5/8" 5180' - 5212' 32 ' opened COMPLETION REPORT SWANSCN RIVER UNIT 23-22 Section 22~ To 8 No; Ro 9 W.. Seward B&M $¥ANDARD OIL CO'° OF CALIFO~iA, OP~'RAT(~R Page 6 January 12-_.14,. 1960, cont'~o Directionally drilled 10-5/8" hole 89-90 pcf 5212' - 6020' 808' drilled January 15~. 1960 Direc{ionally drilled 10-5/8" hOle 89 pcf 6020' - 6401' 381~ drilled DP stud( @ 6373' while wali~ting for directional survey @ 9:30 PM. Worked pipe w/slight los t~ ~circula~ion o _ January 16..1960 Mixed and circulated I~Mo Circ. w/no loss of mud. Spotted 50 bbl SRU crude w/1 bbl NIO added°. Spotted crude around DC'so Added 2 bbls bit lube %o drilling fluid° In place @ ltl5 PMo Moved 1 bbl oil every 15 rain while working pipeo DP free @ 7ilO PM. Circ &:cond mudo Januar~17~. 1960 . Directionally drilled 10-5/8" hole 85½ pcf 6401" - 6772' 371' drilled Janu,,ary 18. 1960 Set WS #4 '@ 6772'. DO WS w/7-5/8" bit 6772'-6786'° Opened hole to 10-5/8"'~ Directionally drilled 10-5/8" hole 88 pcf 6786' - 6803 ' Ja.n.,uary 19-22..1960 17 ' drilled Directionally drilled 10-5/8" hole 88-92 pcf 6803' - 7680' 877' drilled January 23 ~ 1960 Directionally drilled 10-5/8" hole 88,-89 pcf 7680' - 7684' : 4 ~ drilled CCMPLETION REPORT SWANSON RIVER 23-22 Sectiqn_.22, T. 8 No, Ro 9 W~, Seward_B&M STANDARD OIL CO-. CF -CALIFORNIA, OPERATOR Page 7 January .? 3 c0.nt'd Lost circ, pulled up to straight, hole, 4450'o Mixed DCM, regained circo Staged back to bottom, cir~CUlated OKo Directionally drilled 10-5/8" hole 90 pcf · 7684~ - 7930' 246' drilled Set WS #5 @ 7918', DO WS w/?-5/8" to 7930'° Opened hole to 10-5/8"o January 25-26, 1.9.60 DirectionaLly drilled 10-5/8" hole 92-93~ pcf 79~0' - 8303' 373' drilled January 2 7~ 1960 Directionally drilled 10-5/8" hole 8303~ - 8375' drilled' 94 pcf 15 hrs installing overrid~ clutch on dynamic brakeo Ran in to 6000', failed to obtain circulation° PUlled back to 3600'° Mixed 2-50 bbl LCM pills° Re- gained circ. Staged back ~to bottom OK. January 28, 1960 Directionally drilled 10-5/8" hole 91~--94 pcf 8375' - 9484' 1109 ' dri lied Februar~ 3, 1960 Set WS #6 @ 9484'. DO WS w/7-5/8" hole to 9498'. Opened hole to 10-5/8"o Februar~ 4-6,. 1960 Directionally drilled 10-5/8" hole 9498' - 9748' 250' drilled COMPLETION REPORT ~.WANSON RIVER UNIT 23-22 Section 9_2~ T..~ N.. Ro 9i~W.~ Seward CO° Page 8 Febru~ry ~-6, cont. 'd~ · Lo~t circulation at 6292'~while attempting to break circulation while staging in after R.T. at 97~8'o~ Pulled to 4000' and regained circulation ~rith lost circulation material, then circulated at 4626', 6000' and every l0 stands t~ bottom° F~bruar~ 7-9, 1967 ~ Directionally drilled 10-5/8" hole 9748' - 10190' 442' drilled 91-93 pcf Mud wt. dropped from 92~ pcf to 89 pcfo Built mud Wto back to 93 pcf, 8 hrs. February 10, 1960 Broke circ @ 4500' w/hole.'to 10190'~ then lost mud at rate of 1 b~m while attempting to circo @ 7000'. Pulled to 4599' and conditioned mud w/lost citgo m~.erial. Pulled to 4500' and regained circulation with lost circo material. Circulated back in to bottcm in 1000' stages, 21-3/4 hrso February !!.. &.,12~., ,19.60 Directionally drilled 10-5/8" hole iOIPO' - 10305' 11%' drilled Continued to lose mud at 3-4 BPHo Stuck DP @ 10271' while w~king pipe 4:15 AM, (2/12/60)o Spotted 50 bbls SRU crude with 20 bbls aro. und DC's° Moved 2 bbls every ½ hour° Pipe came loose at 11:30 PMo FebruaxT~ 13.,,~ 1,~69 Conditioned mud. to 90 pcf~ reamed hole and wor~ed through tight spot at 10271'. Pipe stuck again at 10271' at 2:10 AM. Worked pipe loose at ~:15 AM° (2 hrs.)° Conditioned mud and reduced lost circulation material to 15%. February 14,17~ 1960 Directionally drilled 10-5/8" hole 90-93 pcf 10305' - 10872' 567' drilled Bit pulled tight 8051'-7983', 7~16'-7856' and at 7756' while making RT $ 10747'. Encountered tight hole at ~8071'-78~6~ and 7670' while making RT $ 10872~o Reduc ed hole size to 9-7/8" at 10,872' o C CMPLETION REPORT ~ANSON RIVER UNIT 23-22 Section 22, T. 8 N., .Ro 9.~om. Seward ~ S'T~NDARD 0IL CO. CF CALIFORNIA, OPERA~OR Page 9 February 18, 1960 Directionally drilled 9-7/8" hole 10872' - 10,945' 73 ' drilled° Lost circulation while drilling at 10945'° Pulled and ran open-end drill pipe to 4OOO~. Obtained full ~eturns at 4000~o Ran in to bottom and obtained full returns° Added lost circulation material to bring concentration up to 20%~ Broke circulation in 2000'~ stages while running drilling assembly and conditioned mud. F_ebruary 19 .&_ 2.0, 196~90 Directionally drilled 9-7/8" hole 10945' - 11161' 216' drilled. 91~ pcf Lost circulation while drilling at 11,161'o Ran in with open-end drill pipe, mixed and spotted lost cirCulation material and regained circulation at 4400~ Circulated back to bottom ~in 2000' stages° Februar~ ~2!; 1960 Circulated and conditioned hole for electric logso Ran Schlumberger I-ES and recorded interval 11, I53'-4751~o . Fe~rua ,rT' ,,,22-24, 19.,6..0 Directionally drilled 8-5/8" hole 91 pcf 11,161' - 11,614' 453' drilled February 25, 1960 .Ran Schlumberger I-ES log i~to 11,605' ~ recorde4 interval 11,599'-11,153 ' o Ran Microlog, re corded 11,600 f~2OO' ~ February 26, 1960 Opened 8-5/8" hole to 9-7/8". ]1,161' - 11,614' 453 ' opened ~ OMPI~TION REPORT SWANSON RIVER UNIT 23-22 Section 22, T. 8 N.~ Ro. 9 W., Seward '~TA~ARD O~L CO. CF CA~L~FORNIA, OPERATOk Page 10 Fe,,bruary 27, 1960 Ran Schlumberger Sonic logi, recorded interval 11, 604 ' -4 751' o Ran continuous dipmeter, recorded 7315'-~51'o Conditioned hole for 7" casing° Februar~ 28-.29~ 1960 Cemented 7" casing at 11,594' in two stages using Halliburton cementing equipment. First Stage: ~Circulated mud for 46 mino Pumped 40 bbls of water ahead and mixed 810 iSx of const, cern in 36 rain w/Oo~% HR-4o Argo wt of cern slurry 114-116 Pcf. Displaced cern w/2850 pump strokes using rig pump° Did not bump battom rubber plug. 250 psi to 500 psi working press° and 750 psi final pre,so Casing stuck @ 11,594'o Could not recip- rocate pipe° Full circulation throughout Job° Cern in place $ 11:00 PM° Used Halliburton power equipment to break circulation @ 3500 psi, at start of job° Second Stage: D~opped Halliburton DV opening bomb° Opened DV collar w/lO00 psi 40 rain L~ter. Pumped 20 bbls of water ahead. Mixed 1000 sx of consto cern w/O~!~% HR-4 in 48 mino Avg. slurry 114-116 pcf. Bumped top rubber plug in 30 rain using ri g pump. Full circ~lation through- out Job° 250 psi to 600 ~si working press, and closed DV collar w/2200 psi° Plug hit w/1765 pum~ strokes. Cern in place @ 1:25 AM. Collar (Halliburton DV) placed @7197'~ Shoe Joint equipped w/Baker flexiflow fillup shoe and Baker fle~flow collar on top of shoe Joint. Baker centralizers on all CSgo Collars from 11,593' to 11,100' and above and below DV collar°. ReciproCating type scratchers placed on 5' intervals 11,150'-11,280' and 11,34G'-11,360'. 9½ hours running casing. Casing Detail Top 41o52 1 Jt 1776.O8 ~2 its 1347o73 ~3 Jts 34OOo81 82 Jts 1505o63 316 Jts 1705.11 ~2 Jts Bottom 1816066 45 Jts 29 lb P-110, R-~, 8R, LT&C 26 lb P-Il0, R-~, 8R, LT&C 29 lb N-80, R-3, 8R, EThiC 26 lb N-80, R-3, 8R, LT&C 29 lb N-80, R-~, 8R, LT&C 26 lb P-110, R~, 8R, LT&C 29 lb P-110, R-~, 8R, LT&C DV collar, float collar and shoe Above KB 6 o OO 281 jts (includes pup Joint) Landed n593 °54 February 29-March !, 1,960, Landed 7" casing at 11,59~' Installed and tested BOPE w/15OO psi BO minso Held OK. DO DV collar at '7~97'o DO oem 11,245-11, B00'o COMPLETION REPORT SWANSON RIVER UNIT 23-22 S~ction.. 22, T. 8. No, R. 9 W., Se.ward B&34 STANDARD OIL COo OF CALIFORNIA, OPERATOR Page 11 M.arch 2-3 t 19.60 Conditioned mud to remove lost circulation material. Ran ~chlumberger Gamma Ray-Neutron log and recorded 11,312'-100'o Jet perforated 5 - ½" holes at 11,197' using Schlumberger equipment° WSO at 11,1979 Ran Halliburton tester on 2-7/8" drill pipe with 3016' wafer cushion and 90' air Cushion. Set p~cker at 1],150'. Obtained 30 rain initial shut in pressure. Opened tool for one hour flow test° Very light to light steady blow~!during flow period° Obtained 30 minute final shut in pressure. Recovered 540' net rise; top 270' oil, bottom 2709 drilling fluid° Oil cut ~% water at top of rise and 22% water at bottom of rise. Chlorinity of wa%er teste~d 87 G/G. Pre s sure s: IH IS I IF FF FSI FH Inside BT . 6742 Outside BT 6787 Outside BT 6730 Outside PND 6800 arch 4, 960 5368 (?) 1360 (?) 1512 5506 1392 (?) 1553 5415 1333 (?) 1514 545O 1350 1475 5312 67~2 5357 6770 5286 6730 5300 6800 Ran Halliburton squeeme cementing equipment° Packer would not set° March 5, 1960 Ran Halliburton squeeze cmmenting equipment° Set packer at 11,136'o Failed to break holes at 11,197' down with 5500 psi~ DO retainer and CO to 11,3OO' o March 6-7, 1960 Jet perforated 4 - ½" holes per foot 11,242-11,246' (per electrical log) using Schlumberger equipment° .H~CT.~I .11~242'-11,246' Ran Halliburton casing tester consisting of one inside PRD, one inside BT, 2 outside BT recorders, 7" packer, safety on 2-7/8 drill pipe. Used 3016' water cushion joint, Jars, TC' valve, " and 90' air c,zshion. Set packer at 11,144'. Obtained 33 rain initial shut in pressure° Opened ~" bean for 1 hour 34 minutes. Strong steady blow. Gas surfaced in 8 minso Cushion surfaced 51 minso Oil surfaced 1 hr 34 mine. Surface bean plugged when oil surfaced° Opened 3/8" bean for thr 45 minso Avgo fl~w rate 725 B/D oil, 96 MCF gas at 25Opsi surface pressure. Avg. gravity 32.6°, avg. cut 1o1~o Closed tool for 50 min final shut in pressure. COMPI~ION REPORT ~T~!SON RIVER UNIT 23-22 Section 22, T. 8 N., R. 9 W., Seward ST ANDARD '" OIL cO.' "~F CALIF0~N~A,' '-OPERATOR Page 12 Pre ssures: IH ISI IF FF FSI FH Inside BT 6439 Outside BT 6399 Outside BT 6334 Inside PRD 6500 56 ~9 3086 4306 5596 --plugged 4180 5505 3343 4256 5500 2650 4200 5506 time expired time expired 5457 6217 5500 6500 March 7, 1,9.6,0, CO and DO cern 11,130'-11, I37~o Jet perforated 4 - holes per foot !1,200'-11,205.', 11,718 '-11,242' using Schlumberger equipment. ~March 8~ 1960 L~nded 2-7/8" EUE tubing at 11,247'. ?q. bing Detail All 361 Joints 11,277' 2-7/8" EUE, 6°5#, N-80, R-2, new, domestic, 8R, T&Co 2o1" ID venturi shoe on bottom. Distance hung below K.B ... 20' Hung at ] 1247 March 9., !960_ Installed christmas bree and tested to 4000 psi° H~ld OK. Displaced hole fluid with crude oil ~preceded by BO bbl~ water using Halliburton equipment° Oil to surfac~ 5:15 PM. Rig relessed 11:59 PMo TDj .-pr DEVIATION DATA , , (Drift Shot) Feet 179' 656 ' 2180' 3390' 3660 ' 4363' 4550' Deviation Degrees Minutes o 45 o 45 0 3O 0 45 1 0 o 15 o 3o Total Drilled Depth Total Vertical Depth* Sperry-~un Magnetic MultiShot Survey from 3000'-11,071'. t 11,614' 11,240' *Bottom hole coordinates - 1050' west and 1830' south of surface location° *Estimated, based on lastmultishot reading at 11, O71' DD (10,734' VD)° PRODUCTION .....,REC OltD Dar? Oil Water Ga..~s ~ Tubing Pressure Bean Ho,,urs of.f 4/3/60 91 o lo 33 199o lO/64 18 4/9 476 2 40 33 12o0 lO/64 4 4/10 537 2 45 33 12oo lO/64 o 4/11 321 1 25 33 1775 lO/64 8 Note: First 192 bbls of this was recovered oilo Well shut in at 9:.00 PM. 4/11/60 for duration of breakup period. REPORT and RECEIVED I~IEI~ 6 1960 ~.~PLAN Oil & Gas Section Division of Mines and Minerals Alaska Dept. of Natural Resourcea of SUB.SURFACE SINGLE- SHOT SURVEY STANDARD OIL OF CALIF. SWANSON RIVER UNIT 25-2'2 KENAI, ALASKA Jo. NO. DA1-_ JANrFEB. 1960 _ $_ B ~ L DIRE~IONAL CO. D1RE~ONAL CONTROL 805 F. 8 M. Bldg. · 320 Pine Ave. · Long Beach 12, California Telephone: HEmlock 6-4417 B 0 L DIRECTIONAL CO. ao~ No. SURVEY DATA SHEET l SHEET NO. COMPANY ~TA~DJ~ 0IL OF C/~II~)i~I/~ ADDRESS WELL UNIT 23.-22 FIELD SWANS01~ R~VE~ COUNTY. i~AI STATE_ AL~i~ TRUE RECTANGULAR COORDINATES MEASURED DRIFT COURSE DRIFT VERTICAL REMARKS , DEPTH ANGLE DEPTH DEVIATION 'DIRECTION . ~,,~ NORTH SOUTH EAST WEST 3000! 00 I~ELL CON 5IDERi ',D VI~,RTICAL TO' Tills B ':PTH 3400 O0 O0° 30' 3400 O0 3 48 N 21° E 3 25 I25 3850 O0 00o 15' 3050 O0 1 98 N 34° W 4 89 14 4300 O0 O0° 45' 4299 96 5 90 N 36° W 9 66 3 33 4707 O0 O1° 15' 4706 88 8 87 N 04° W 18 51 3 95 4740 O0 Ol° 00' 4739 87 58 S 70° W 18 31 4 50 ~'~ '-.- 4751 O0 00o 15' 4750 07 05 N 41° W 18 35 4 53 4763 00 01° 45' 4762 86 37 S 05° g 17 98 4 50 480~ O0 020 45' 4803 81 1 97 S 04° g 16 O1 4 36 48601O0 02° 450 4859 74 2 I69 SOUTH 13 32 4 36 , . 4940 O0 02° 30' 4939 66 3 49 S 04° W 9 84 4 60 5031 O0 03° 15' 5030 51 5 16 S 19° W 4! 96 6 28 ( 5129 O0 040 15' 512825 7 26 S 18° W I94 8 52 5287 O0 05° 45' 5285 46 15 83 S 38° 18 14 41 ' 18 27 5376 O0 . 07° 15' 5373 75 11 23 $ 30° 18 24 14 ~ 23 89 .. · 5445 00 08° 00' 5442 08 9 60 S 25° W 32 84 · ~ 27 95 5645 O0 10o 00' 5639 04 34 72 S 32° ~ 62 '28 46 35 57201O0 11o 00' 5712 66 14 31 S 320 18 74~41 53 93 5920 O0 12° 30' 5907 92 43 128 S 36° W' ., 109 42 79 37 6120 O0 14° 30' 6101 54 50 08 S 42° 18 146 63 112 88 B ~ L DIRECTIONAL CO. SURVEY DATA SHEET COMPANY ST/LNDARD OIL OF CALIFOENIA ADDRESS WELL UNIT 2:%22 FIELD SWANSON RIVER COUNTY. KENAI STATE JOB NO. SHEET NO TRUE RECTANGULAR COORDINATES MEASURED DRIFT COURSE DRIFT VERTICAL REMARKS DEPTH ANGLE DEPTH DEVIATION DIRECTION NORTH SOUTH EAST WEST 6320 O0 18° 15' 6291 48 62 64 S 44° W 191 69 156 40 6401 O0 19° 15' 6367 95 26 71 $ 44° W 210 90 174 96 6494 O0 19° 45' 6455 48 31 42 S 44° W 233 50 196 79 660(] 00 18° 45' 6631 60 5g 78 S 45° W 275 77 239 06 6772 O0 18'-~ 45' 6718 71 29 57 S 45° W 296 68 259 97 68031 00 16° 30' 6748 43 8 80 $ 37° W. 303 71 265 27 68961 O0 17° 00' 6837~ 37 27 19 S 35° W 325 98 280 87 7079:00 18° 30' 7010 91 58 07 S 33° W 374 68 312 49 7226 O0 21° 00' 7148 15 52 68 S 320 W 419 35 340 41 7343 O0 21° 15' 7257 19 42 40 S 33~ W 454 91 363 50 7484 O0 21° 15' 7388 60 51 10 S 33° W 497 77 ~' .391 33 768(] 00 23° 30' 7568 35 78 15 S 34° iq 562 56 435 03 788(] O0 22° 30' 7753 13 76 54 S 34° W 626i Ol 477 83 7918 O0 22° 30' 7788 24 14 54 $ 34° W 638! 06 " 485 96 7966 O0 20° 15' 7833 27 16 61 S 29° W 652 59 ~ 494 O1 , 81221 O0 20° 30' 7979 40 54 63 S 27° W ~701 27 518 81 8243 O0 20° 30' 8092 74 42 37 S 28° iq 738 68 538 70 8487 00 20° 30' 8321 29 85 45 S 29° W 813 41' 580 13 8687 00 20° 30' 8508 62 70 04 S 31° W .~873 45 616 22 , 8873 00 20° 30' 8682 85 65 14 S 31° W 929 29 649 77 '~ COMPANY ...... B 0 L DIRECTIONAL CO. SURVEY DATA SHEET STAj~DARD OIL OF CALIFORNIA ADDRES~ JOB NO. SHEET NO, 3 WELL UNIT 2222 FIELD SW/~.~ RIVER COUNTY. I(ENAI STATE: MEASURED DRIFT TRUE COURSE DRIFT RECTANGULAR COORDINATES VERTICAL REMARKS DEPTH ANGLE DEPTH DEVIATION DIRECTION NORTH SOUTH EAST VVEST 8981 O0 19° 30' 8784 65 36 05 S 31° W 960 19 668 34 9181 O0 20° 15' 8972!29 69 22 S 32° W 1018 89 705 02 9340 O0 20° 15' 9121146 55 03 .5 33° tq 1065 04 734 99 9483 oO 20° 15' 9255~62 49 49 S 35° ~ 1105 58 763 38 9530 O0 18° 15' 9300!26 14 72 S 23° I~ 1119 13 769 13 9730 O0 20° 00' 9488 20 68 40 S 19° W 1183 80 791 40 9908 O0 20° 15' 9655 20 61 61 $ 20° W 1241 69 812 47 10)043 O0 21° 00' 9781 24 48 38 S 18° ~ 1287 70 827 42 10)190 O0 22° 30~ 9917 05 56 26 S 17° W 1341 50 843 87 10,273 O0 21° 15~ 9994!41 30 08 S 25° W 1360 76 t~L56 58 10,437 O0 24° 45* 10~143 34 68 67 S 25° ~ 1431 O0 885 60 10,637 O0 20° 45' 10~330 36 70 86 S 18° W 1498 39 907 riO 10,872, O0 21° 15' 10,549:]38 85 16 $ 24° I~ 1576 18., 942 13 11~071 O0 22° 00' 10,733 89 74 55 $ 22o i~ 1645 30 970 06 : ' CLOSURE 1910 07* S 30° 31' W ~ , ,,, .... . PRODUCING DEPARTM £NT TELEPHONE 47001 J. T. CROOK£R DISTRICT SUPERINTENDENT P. O. BOX 839 · ANCHORAGE March 23, 1960 ALASKA - RECEIVE[J Oil & Gas Section Division of Mines and Minerals Alaska Dept. o[ Natural ltesource~ Mr. Richard Murphy DiviSion of Nines & Minerals 329 Second Avenue Anchor~ge~ Alaska Dear Mr. Murphy: We are attaching hereto the Core Analysis Report and Baroid Mud Log on Swauson River Unit Well 23-22. Due to an oversight on our part we have neglected to send you recent log runs on our currently drilling wells. However, field prints of these logs are being prepared ~ud will be forwarded to you in a short time. Yours very truly, STANDARD 0IL COMPANY OF CALIFORNIA WESTERN OPERATIONS, INC. J..~CRO~KER ~tac~e~s ANALYSIS REF ORT . - . ~.PANY STkt~D~D-:OIL CO~_PAh~ OF CALIFOR~ffA C~UNTY KENAI '- ~ -WELL sw~so~ s~. ~z~ 2~-~ STATE ALASKA .. . FI~D- .SW~SON'~I~ T~.-~ GORE COh~TION~ D~METER ~l~Yl.l' ' _ ';"- ' . ''t ' .~ --:' · - ' md.'i~ ~~,. ~LK I~MARKS _." ..: ' ." .' ..:..: = ..~Uu'~ tr~[ ~.~.~:' ~ J '_,~,, ,'h_ ,,~'~ ' ' :: . . .' .: ' : '~ " . ' '." ' .... . .... ~ · , ... - --~: '~}'-:;..~-:. :_~ '. ~ ~' '7 "' - ' ........... : ......... . Divi~on Of Alines ~d - .. - .; -. ~ . -- . · <' ' : ~' ' -"~" ' ' 'O' " '4' " - i J ~ i .. -~, . . :.. ..1. ..... .. .. _ ~., , ', ~ ~ . ,.? , . ....... . ............ ~. . . -" "_Z-:'::'?-': <'"". ". ".-.'-'."'.-':--'.":':.:.- -'.-: ' - : ..i( .... - ' ' - - ' -:'. ~:~_ - :-_:~..~._' ..... - .'_ . :' ' ' .... :~..~. ~. :~ 0 ~ .,,~ ....... · .... ".., , ,, ".--<:'"TT ..... :: ~'- ...... ::--':_-- ::- .......... : " ' -.::. -.' '.. -: ~ :' "~l~'-~ -~ ~;~ . ~- ' : :"-::-.-' -: 7~ ~0 ~ ~ ' ' : :- ':'. ' .' '-' ': ~' '... 0 . ' ,.,' ,, = - . ... _ . . : -:- -~ : ::- . . -~. . . : ..... .. ' . . · - , r . ,~ , , i . ~1 I .~1 . - ' -' ~ ' '"'-."'< ' 9~. .... ~1~ .'.:~ ~'~o~ .~ : ,.~' ..7' , -. -~,,o -~ :, ..'.'~5 ~ ~ · . ..- ........... . .. j: - . ::.-. , ...... -_. ' ~: '~.~ G '~ . ,; ~. o~-' .- ?. ._. 0 28:0 ~ ~2 . -. . , ~ , ~: ~ ~ ,.r,,,, , , , . i , : , , , , ' . . ~ ' . - . . DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY UI~T ........................................... LESSEE'$ MONTHLY REPORT OF OPERATIONS Tl~e followin~ is a correct report of opera~ior~s arid prod~ctio~ J~e~t's address P, 0, ~x ~~ ................ }}~~--'Ol~"~';"~-~"~'~"~'h ........................................ ....................... Company ~iaatc~c;~9~9~,__X~m.: ........... ......................................... ~_~:~_A~_~_~ .................. ~~ ............. ~-~--~~!<~- ...... : .............. SEC. AND BARRELS OF OIL (}RAVITY GASOLINE WATKR (If (If drilling, depth; if shut down, ~ OF ~ ~. Ri~a! WE~ D~ OU. F~. or GAS GA~ONS O~ BAR~ Or ~EMARKS' NO. PaODUO~. (In thou~&) da~ ~d r~ult of t~t for RECOVERED ~on0~ S0 state) con.ut ~ ~) ~:~ PM. Vcz7 ~1: ~ ~:t~dy blo~ d~lrir4{ . hr flo~ teat. ~1~), ~t P~m~s : ~I~ ',~I iF ~ FSI FH 1~ 3., 5h~ 6795 C~at~[~de ~T 67 ~5 :k15 13k5 1505 r,-~ 6785 Jet ~ '~ ~ :' . ~eI fo,.,. ,~.,,~ ~n I 'I ~'? ~::~1 PM. C pene~t fo. flow or ~;- ~ttom hole . of f~lcv p~,~. Su ~ace be~n pl~ ~d ;~en ~,11 su~$.eea. ~emd to 3/8" ' ,. . ~a. ~kt (J~C't],y tO t;tl~ ~tl~'ll ~tll tt~t) 6/ 5 P~I. t~te B "D .. . ~" 7:35 m~. ~ mt~i~ ~2 T" 6t~ t ~tg~ a815 ~ 5k70 65~~ i Jet ~rf',t esg 'w~h~ & ~les/~ 1~-~ ~ ~1.8-242. ~ ~1 its ,~tt.,, +, , a Flo~ea to i~ appr;':~x. 5 l~ ~ cte.~ up wei.l.~ , ~&g z'elea!~ ,,1t,,2,9.. ," .. R. V. O' ° ' "' NoTm.--There were _.0_ ..... Z ........................... tuna or sales of oil; .................... 1~ .... .~ ......... il,.::'._` Ms o~.'ft, of gas pold; l' ................................. .~ ......... runs or salas of gasoline during No~.~epor~ on ~h~ form ~ required for each calendar month, ~gar~s of ~he s~a~us ~'5~efiktdns,' arid '~'be flied'in duplicate wi~h ~he superv~or by ~he 6~h of ~he suoe~ing month, u~ess ogherw~o diroe~ by ~he supervisor. Fo~ 9-329 (January 19~) ~7~ u.s. ~V~..Z.T P.iSrsse OrF~C~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356.5. Approval expires 12-31-60. Aneho~ ........... [':~_ .~p_ _n_ _ )~A'_~..r_ ..... LESSEE'S MONTHLY REPORT OF OPERATIONS followi~ is a correct report of operatior~s and prodt~otior~ (i~cludinll drillir~ a~ prod~cin~ ................ address .............. ~C~kQA~_~ _ _ ~~ .................. ~': ..... ~ " Company :~ ~._~. ~ ~~~.. J~c .............. ......................................... ~___P~___~__!cP~,~ ...................... ~ie~ed .................. ~:_:z_::::~_:~h[[.~ .................... SEC. AND DATS OU. F?. OF GAS GALLONS or BARRELS OF REMARKS ~ OF ~ TWP. RANGE WELL BARRELS OF OIL GRAVITY GASOLINE WATEE No. Pao.vo~o (In thousands) dat~ and result o! te~t for Sasolino RECOVERED none, SO st~t0) content c~ gu) , aa aN 9W Dr~d 10-3/8" hole k0~08'-1087~'1 9-7/8" X~72'-11.~1'. ~ ~-~ckl mmber~er I -E(;, ~c'd ~,153'-%751' 92~) ' .~ 11, 60"3 '. o~n~ 8-5/8" hole to P~z ~:~chl~'~rger ~F~nlc :[~g~ z~c'd ll, 6~h'-l,'fSl'; Dip~ter, ~c'd c~.nstn:c~ion cern t~atef w/O. "~%. cf s [~ry 114-2~6 p~f. 250-50,3 psi ~.~ p~ ~s~ 7~ psi fizZ. ~ll circ. '~vg~oUt. Cern in p~(,e ll PM. ,,b~ p ~i. ~d~ 1~ Ay. ~h.~r ~y !14-1!6 pcf. 250-~ p ~i w~. ~ss~ 22 30 psi fill. .~_ ~ cir n. th~u~(~ut. Cern in pla ~ 1. ~5 ~ ~. . o 0 NorE.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ................................... .Q_ ....... runs or sales of gasoline during the month. (Write "no" where applieable.) NoTr.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplii~ate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 1b--25766-~ U.S. ~OYZRH#~H? P#IN?I~ OFFICE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No, 42-E356.6. Approval ax~irm. 12~1~. An~o~ ~.~ om~ .... 02~ .................. LEASE NUMaE. F~~"~~"-- U~T ........................................... LESSEE'$ MONTHLY REPORT OF OPERATIONS Tl~e followin~ is a correct report of operations and prod~ction (incl~di~ dritlir~ and prod~einff for tk~ g~ltD_"~_~_.~ZZ__~--~l~,~- ........ 19_~_, ............ J~e~t' s address .............. ~--~--~--5~-~ .............................................................................. ............................. .................................. SEC. AND TWP. RANGE WELL ~ DAYS I CU. FT. OF GAS GALLONS OF BARRELS OF REMARKS 1~ OF ~ NO. rno~uc~v BARRE~ OF O~ ORAVITY (In thous~) OASOLINE WATER (Ii (If drilling, depth; ii shut down, ease; J RECOVERED none, so state) da~ ~d renult of t~t for gasol~e ..... eonteut of * .... Pi~ stu(:k ~- 10,~1 ~1~ ~r~ ipe to m~ ~~lon. ~ ~ ~ ~;0 bbls ~ e~d ~ - ~ bbl~ outsi~ ~ bbl,~ i~ide. Pt~ ~ loo~ e LI: ~0 '~ . D~led ~.0-~/8' ~1 e 10, ~'-10, ~0~ ~'. ~ur~: ~0,0~~ ~1° o18'~ 10,190' ~2~' ,~: 17W 10,273' ~1o15' S 25 W ~ t.:,.," ''' .... I ; ~'' '; :'~ ', ,;~' (~[~ :;. ~'.:,,-?: ,.-., CCI L, I, ~.~ ~.-.):,.~:::~ ,:. ., , " , , NoTE.--There were ....... -0 ............................ runs or sales of oil; ................... ._0. ....................... M cu. ft. of gas sold; .................................... ~_ ...... runs or sal~s of gasoline during the month. (Write "no" where applicable.) NOT~..--l~eport on this form is required for each calendar month, regardless of the status of operations, and must bo filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--25766-8 ti. $. ~OYERNMENT PRINTI~Ie OFFICE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R~56.5. Approval expires, 12-~1~0. ........... _::~S~._.~.~.~__r_ .... LESSEE'$ MONTHLY REPORT OF OPERATIONS Tt~e followin~ is a correct report of operations and prod~otion (ir~el~di~ drillin~ and prod~oi~ ................ ~e~ s address ............ _P,___~,_._~__~9 ........................ Company ~~~~~..~C, ............ ............................................................................................... ~iff~ ................................................................ ............................ ...................................... WELL DArtS ] CU. FT. OF (]AS GALLONS OF BARREL8 Or ' RE~ARK8 AND TWP. RANGE NO. Puo~oc~. ~ARRE~ OF O~ ~RAVITY OASOL~E WATER (I~ (I~ drlili~, depth; if shut down, OF ~ .... [ (~ thous~&) RECOVERED none, so state) ds~ ~d resultcont~tof oft~t~)f°r ~1~ 10-9/8" ~ ~ 9 ~' p~, ~o,~5, ~ 95~' .18°:~5' :~ ~3 ~ Dr(~''~ :' ... ,, ' ;' ])~'.'k? :; ' ' ~ "'.()~ J', (; ' '; - . ~. V. ~~ v/ 0 0 NoTn.--There were ...................................... runs or sales of oil; ............................................. M cu. f~. of gas sold; ................................... ._0_ ....... runs or sales of gasoline during the month. (Write "no" where applicable.) NoT~..--Report on thi~ form is required for each caJendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of bhe succeeding month, u~ otherw~e directed by the supervisor. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'$ MONTHLY REPORT OF OPERATIONS SEC. AND I 1~ OF 1~ TWP. RANGE' ~rEL~ DAleS CU. FT. OF (]AS GALLONS OF NO. ] Pao~oc~oBARRELS OF 0IL ~RAVITY (In thousands) ~ASOLINE I~ECOVERED s~ ~ ~ ~ ~[8', flaunt S 7o ~. 19~ld offf ~ hol~ ope~r, opened hole ~ 1C'-5/8" to ? f; ~[d 10-.5/8" hole ~930' .9051'. : . ~ , ~73' 20~ 3 ~ s 3~ w ~,~,~?~.~ ~~t i/3~ - 905i'. ,r , i i ?" ]Dh isi~ ....... ~gJ;X BA RREbS OF REMARKS ~VVATER (If (If drlllln$, depth; If Mint down, oause: so state) d.e, and result of t~t for ~on~nt of REC[ IVED' Oil & C;~s Sedion of N'lh cs and Minerals Dept. ot: Natm'al NoTE.--There were .......... ~[ ......................... runs or sales of oil; ................... ]0 ........................ M cu. ft. of gas sold; ...................................... 0 .... runs or sales of gasoline during the mont;h. (Wril, e "no" where applicable.) NowE.~Repor~ on Chis form is required for each calendar mon[h, regardless of the s[a~us of opera~ions, and mus~ be filed duplieaCe wi[h ~he supervisor by ~he Oth of ~he succeeding month, unless otherwise directed by ~he supervisor. Form 9-329 (January 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budg~ Bureau No, 42-RI~6,5, Approval expirea. 12-~1-60, NIT ........... ' ................ -' ............... LESSEE'$ MONTHLY REPORT OF OPERATIONS Tt~e followi~ is a correct report of operaHo~s a~d prodz~otio~ (ir~el~di~ drillir~ a~d prod~oi~ff ~ fo~ ~ ~g/g~_r~r~_~/a__~_~~_ .... , ~9__~, .......... ~:~~.~:~r_..~ ......................... ,... ~t~ar4 Oil Co. of Califo~[n ~e~' s address ................ _~,___~,___~__~n~3R .................... Company __Wea~.~ez~i~+_.~ ........... ........................................... ~_~9.~__~_~_~P_I~ ................ Si~ed ' ................................................................................... ~ . . , ~.~ ~ . Phoebe ~3R 76~01 dffe~t' s title .~!_.~:~_~.~ ................. AND TWP. RANGE WELL DA~e GU. FT. OF (]AS (]ALLONS OF BARREL8 Or REMARKS OF ~ NO.PRODUCED ~ARRE~ OF O~ GRAVITY (~ thousands) GASOLINE WATER (If (H dr~Hn$, depth; If shut down, oa~e; ~ECOVERED none, so s~te)~ ~d r~ult of ~t for g~ollne content of ~) ...... ~ 8N 9w ~ io-~/8" bit, co c~ ~1~ ~-47o7'. ::~ m~ il:. Um~ucce~l at~pt to sidet~ hole. [::~t WS '"~$~" ~'~51', f~d %'-..~ '~ 4"{63' in ~7-5/8~' h.le. ~d hole, drilled ,~, ,'~5 W. ~ld. off .~c ~.. ~0.,~/8~ ~ ~{'. Co~ ~0'-4~1' - r~ ~ ~n t[~I. Ope~d ~ ~ for t'low t~ot ~:'~' 6:27 I'M. ~nt bk~w 1 ~n ~n de~d. :. 6:29 blo%~ ~efl. ~n a~ fluid in amlulus dropped. Ftile. l ~.~ltm ~s fled oont'd t~ p~'. loc ce <.~ 6:45 ~. ~ee 7' $~:s ne~ ~e - all ~ld. in~i ..a~ pa~ial ptu~:~. Test ;l nconciustve. O~l;aide ~ .~ I~i~ 2~6 % ~0 ll~,~ 3015 Dr2.d 10'5/8" hole ~91' -51~'. A~.t~tmd ~omn. ~,~t l~~ ~n flow t~=et~=~~ K) ~n ~l. ~d. bl~w to st~t~ ~'~ ~n:~ Cons'. de~ble :..<. th:'~cut, ~;- ~bsu~T~ce ~. ~ fL)~ ~ .~-~F/D, 2~K) psi ' '~,~.,'~'-:'eu:Tac~ p~s~. Rea,. ' ~'" ~ ~ ~ lo-5/8" ~ole ~' .6Y~'. ~mt w~ ~4 ~ 6~?~', cc: L. ~ w .... ft. of gas sold; NowE.--There were ............ fA ....................... runs or sales of oil; ......................................... M cu. ................................ _Q. .......... runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th o[ the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--~5766-8 U.S. ~¥[RNMENT PnlST~S$ OFFICE h'lmit BI. 17 PRODUCING D£PARTMENT TEL~=PHONE 4700! J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX 839 ° ANCHORAGE ° ALASKA January lB, 1960 RECEIVED J~N 14 I9~ Oil & Gas Section Division 'o5 Mines and Minerttl~ Alaska Dept. otJ Natural Hesourcae, Mr. Richard Murphy Petroleum Engineer State Division of Mines and Minerals 329 Second Avenue Anchorage, Alaska ~ar Sir: We enclose herewith Alaska O&G Conservation Commission Form, P-l, Application For Permit To ~Plug Back, covering our Swanson P~ver Unit Well No. B2-22 (7). This well is to be directionally drilled under the designation SRU 23-22 (9) as a new well. Please return the yellOw copy indicating approval. Yours very truly, S~IANDARD OIL COMPANY OF CALIFORNIA WESTERN OPERATIONS, INC. J. T.~ROOKER attachment PRODUCING DEPARTMENT TELEPHONE 47001 J. T, CROOKER DISTRICT SUPERINTE.NDENT P. O. BOX 839 · ANCHORAGE · ALASKA January 13, 1960 Mr. Richard Murphy Petroleum En~neer State Division of Mines and Minerals 329 Second Avenue Anchorage, Alaska Dear Sir: We enclose herewith Alaska O&G Conservation Comm~ ssion Form, P-l, Application For. Permit To Dr--ill, covering our Swanson River Unit Well No. 23-22 (9) with check in the amount of $50.00 to cover permit fee. Please return the yellow copy indicating the permit number smd approval date. Yours very truly, atta~mts ST~ OIL COMPANY OF CALIFORNIA WESTERN OPERATIONS, INC. 'RECEIVED JAN 14 Oil & Gas Section Division of Mines and Minerals Alaska Dept. of Natural ltesoarces - APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK ~ ,~::.-;. - .... APPLIeAT:tON .TO-DR'ILL '~ .... DEEPEN El, PLUG BA, CK~ NAME OF COMPANY OR OPERATOR DATE Address -:? ";': -: : ..... ~ :: .......... -' ~-~ ~ ,, ~- ~-:~ '"-'C~ty ~"~: :- ~ ' Stat~ w~ OF AND LEASE le~. : .~ .... :_ ~ J ...... ~: .'. .... -'(:~. ': P . -: "'~" Well number , ii Elevation Name of (ground) , ' (¢) ., . 'm ..... Welt location (give footage fro~~~ Section~township--range or block & survey Distance, i_n miles, and direction from nearest town or post office Nearest distanco from proposed location to property' or lease line: Proposed depth: feet IRotary or cable tools Distance from proposed location to nearest drilling, completed or applied--for well on the same lease: Approx. date work will sram Number of acres in lease: Number of wells on lease, including this well. completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address i ~ · ~ ~ . Status of bond Remarks: (If this is an applicatiOn to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producin~ zone) (see CERTIFICATE: I. the undersigned, state that I am them/B~'~{~. of the ~ 0~..~3, of CaJJ2o~lfla (eompany), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. 17 Permit Number: ~ ~ov~a__ J]1~J 1 _4~lgSn Notice: ~fO~or ~'s~,a~Ut~'~&~l~ ~be s~~e2:s~i::, ence will ~hu~ b~vojde~. See ~str~ction on ~everse Side of-Form O~"ig;nai sign::d J..T. C~.OOKa, Signature Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958 Dr/ll/ug Program swaaso~ ~v~r o~t 2,.t-22 (~)) 1. After whlpstcckimg from orlgLmal hole, 32-22, at approximately ~750' eirectio~aLkv emil~ full hole for 7" casiaS to subsu~face location to encounter Hemlock Zome a~ approximatel~ the center of the NE~ of the S~ of projecte~ Section 22. a) Zpot core and evaluate possible Sas 'sands between 4850' amd 7000 '. 2. Penetrate Hemlock Zone to a drilled dmpth of mpproximatel~ 11,460' and run electric logs. 3- On basis of electric log amd mad logging shows ran 7" casing to below indicated productive intervals. ~. Cement 7" casing in two sta~es, seco~ stage through D~ collar at approximately 7000'. 5. Establish ~'s as necessary. 6. ~lectively Jet perforate amd test attractive sands. 7. mm ~" tut,~,~ ~