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Home My WebLink About184-010STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. WeII Status: oil ❑ Gas E] SPLUG ❑ Other ❑ Abandoned ❑� • Suspended[] 20AAC 25.105 20AAC 25110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class. Development Exploratory E] Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Dat mp., Susp., or Aband) 8/26/2019 14. Permit to Drill Number/ Sundry: - 184-010 / 319-136 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. a e Spudded: 1/18/1984 15. API Number: 50-133-10102-01-00 49. Location of Well (Governmental Section): Surface: 1983' FSL, 1082' FWL, Sec. 3, T7N, R9W, SM Top of Productive Interval: N/A Total Depth: 2639' FSL, 1350' FWL, Sec, 3, T7N, R9W, SM 8. Date TD Reached: 1/24/1984 16. Well Name and Number: Soldotna Creek Unit (SCU) 23B-3 - 9. Ref Elevations: KB:qq, GL: 128' . BF: f.2 17. Field / Pool(s): Swanson River f 2u Hemlock Oil 10. Plug Back Depth M/TVD: 0' MD; 0' TVD 18. Property Designation: FEDA028997 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 348733.0 y- 2457933.0 - Zone- 4 TPI: x- y- Zone- 4 Total Depth: x- 349010.0 y- 2458587.5 Zone- 4 11. Total Depth MD1TVD: •10,971' MD / 10,825' TVD • 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A I 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes (attached) No r Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 121. N/A (ft MSL) I 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 if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 22" Surface 37' Surface 37' 11-3/4" 47 J-55 Surface 2,040' Surface 2,040' 16" 1800 sx cmt 7" 29, 26, 23 N80PIlC Surface 10,013' Surface 9,952' 9-5/8" 2200 sx cmt 5:00 18 N-80 9824' 10,970' 9782' 10,824' 6" 225 sx Class C 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ^ �J VERIFIE 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDT VD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes LJ No LyJ Per 20 AAC 25.283 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 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 P Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Form 10-407 Revised 5/2017 ✓l CONTINUED ON PAGE 2 �YG 0 9 2019 SubmitORIGINAL only �1_�(SJtRBDsQ nOCT� 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑✓ . If Yes, list formations and intervals cored (MDTFVD, 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. 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: Bo York 907-777-8345 Contact Name: Ted Kramer, Operations Engineer Authorized Title: Operations Manager Contact Email: tkramer(rDhilcoro.com Authorized 7 r e1 " tE• Contact Phone: 907-777-8420 CI ViN,.('oma Signature: Yal k Date: 2 S / o 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 10407 well completion report and 10404 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 1 a: 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 ib: 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 (Top 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 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 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 farm: 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 WellOperations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 236-03 Rig 401 50-133-10102-01 1 184-010 1 6/10/19 1 8/26/19 Daily Operations: 06/10/2019 - Monday MI HAK 401 and associated equipment from SRU 21A-34. Laid containment andspotted equipment. SDFN. 06/15/2019 -Saturday ARIVE AT SWANSON, PERMIT, ISA. CHECK FLUIDS AND START CRANE TRUCK, MOVE TO 236-3. SPOT EQUIPMENT, RIG UP .125"S/L, GET HILCORP HOT OIL TRUCK AT PLANT. ASSIST W/ HOT OIL TRUCK TO M.I.T. 2313-3. PICKUP LUB, PRESSURE TEST TO 2,500 PSI, TEST GOOD. RIH W/ 4' PRONG W/ 1.80" CENTRALIZER TO 9,871'KB W/T NO CHANGE IN WELL POOH - MARKS ON PRONG. RIH W/ 1-5/8" JDC TO 9,871'KB W/T PULL UP TO 9,820'KB SIT DOWN POOH -JD PIN SHEARED. RIH W/ SAME TO 9,820'KB W/T POOH - W/ A -STOP. RIH W/ 2-3/8" GS TO 10,538'KB W/T MULTIBLE TIMES NOT LATCHING POOH - PIN NOT SHEARD. RIH W/ 1.75" LIB TO 10538'KB HIT DOWN TWICE POOH - CUTS ALL AROUND OUTSIDE OF LIB. W/ WHAT LOOKS LIKE SAND ON THE FACE OF THE LIB - CALL TOWN. LAY DOWN LUB, SECURE WELL, CLEAN UP AREA. 06/16/2019— Sunday ARRIVE AT SWANSON, PERMIT, JSA. REHEAD, P/U LUB, ADD ANOTHER STICK OF LUB, PRESSURE TEST 1,500 GOOD. RIH W/ 1.75" x 9' PUMP BAILER TO 10537'KB W/T POOH - SMALL AMOOUNT OF FRACK SAND, MEDAL MARKS ON BOTTOM. RIH W/ 1.50" PUMP BAILER TO 10538'KB W/T POOH -JUST WATER. RIH W/ 1.5" HYDROSTATIC BAILER TO 10,538'KB W/T POOH - FULL OIL. RIH W/ SAME PINNED W/ STEEL PIN TO 10,538'KB W/T POOH - FULL WATER. RIH W/ 1.75" LIB TO 10,538'KB HIT DOWN TWICE POOH - PICTURE OF G FISHING NECK W/ CUTS ALL AROUND THE SIDE OF LIB. RIH W/ PRONG W/ 1.80" CENTRALIZER TO 10,534'KB W/T 10,536'KB POOH - NO CHANGE IN WELL. CONDITION - MARKS ON BOTTOM OF PRONG - INDICATES KOBE MARKS. TALK W/ BILLY TO GET A GU ADAPTER FOR GS TO ALLOW GS TO SHEAR UP. LAY DOWN LUB, SECURE WELL. Pollard will be out in the AM with the right pulling tool to try and pull plug. 06/17/2019 - Monday ARRIVE SWANSON R. MEET W/ BILLY JSA PERMIT TGSM. CUT WIRE RE -HEAD CHECK TOOL STRING PT 2,500 PSI. RIH W/ 2- 3/8" GR TO 10,519'WLM 10,536'KB LATCH W/ TOOL POOH W/ D&D PACKOFF-NO ELEMENT. RIH W/ 2-3/8" GS TO 10,522'WLM 10,539'KB LATCH W/ TOOL POOH W/ G -SLIP STOP. RIH W/ 1.75" X 5' DD BAILER TO 10,694'WLM 10,711'KB TAG W/ TOOL POOH W/ OILY FINE SAND. RIG DOWN SLICKLINE. 06/18/2019 -Tuesday Held PJSM and had I WS crew go thru Orientation with Hilcorp Safety Rep John Coston. Cont RU the 401 and spotting associated equipment and sealed in rig footprint. Organized dog house. Raised Derrick and secured guide lines. Hooked up circulating lines to well and loaded pit with 60bbls of PW Opened well and reverse circulated 175 bbls of PW. Shut-in the IA and and pumped 3bbls down tbg and well pressured up to 3,500 psi held for 5mins with no leak -off. Bleed off tbg and SIW.SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 236-03 Rig 401 50-133-10102-01 1 184-010 6/10/19 1 8/26/19 Daily Operations: 06/19/2019 - Wednesday 4>' Held PJSM and discussed daily activities with IWS crew. SITP Opsi, SICP Opsi. Set BPV and 146the Production Tree. Inspected lift Treads and hanger. MU 3-1/2" Blanking sub and with left hand acme tread. NU 7-1/16" 5M BOP Stack as following: Mud Cross with 2-1/16" Outlets, Double Gate BOP dressed Top w/ 2-3/8"-3-1/2" VBR's and Blind Ram on Bottom, Hydril GK Annular. RU Rig Floor, Stairwell and Handrails. Connected Kill/Choke lines and Koomey Control lines to Stack. Function Test and found 4 -way leaking on the accumulator. Flood Stack and shut-in Blinds and preformed a good Shell Test. RU Total Safety Gas Detection and RigSense PVT System and function tested same. Continued Organizing and Inventorying tools and associated equipment for the HAK 401. Repaired 4 -way on the accumulator and function tested good. 06/20/2019 - Thursday Held PJSM and discussed daily activities. Check fluids and services rig. Organized and made a list of tools and equipment need for the 401. Started Building #9.6 Brine in rig pit. RU the 450 bbl Johnson Tank and contained. Cont servicing the Koomey Unit and preparing for the BODE Test. State Inspector Austin McLeod arrived on location at 11:00. Tested BOPE per Aogcc Sundry, Tested Gas Detection and pit level indicator -good test. Moved to our BOP stack and manifold. Could not get a low or high test on the pipe rams. Continued testing Valves with annular. Had two failures CMVS 8 and K-2 greased cycled and retested good. Troubleshot problem with pipe Rams, swabbed out 4 -way again, swapped out VBR"s to solid body Rams. Changed positions on the Accumulator and swapped hydraulic control lines and no success. Called Weatherford and they will be out first thing in the AM to troubleshot the Ram Body. 06/21/2019 - Friday Held PJSM and discussed daily ops to be preformed Weatherford BOP service hand on location to troubleshot issue the pipe ram. Opened Ram Doors and inspected no visible signs of wear or issues. After discussing decided to swap out 5M Double Gate BOP with one at there shop. Discounted Hydraulic Control Lines, ND Annular and DBL Gate BOP and waited for Truck to arrive with BOP from the Kenai Weatherford Shop. Continued Mix 9.6# Brine in rig pit and cleaning and service rig in the mean time. NU 7-1/16" 5M DBL Gate BOP and the Annular Preventer. Opened Doors and Dressed Top with 2-3/8"-3-1/2" VBR's and the Bottom with Blind Ram. Hooked up the Hydraulic Control Lines and functioned BOP'S PU 3-1/2" Test Jt and Shell Tested 250-2,500psi. Finished Testing BOPE Per AOGCC Sundry as following: Annular 250-2,500psi, Rams 250-2,500psi, Valves 250-2,500psi preformed Accumulator Drawdown Test and Gas Detection. 3 Fail/Pass were recorded on the K1, CMV 8 and pipe rams. Total Test time was 11hrs and witness by State Inspector Austin McLoen. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 236-03 Rig 401 50-133-10102-01 184-010 6/10/19 1 8/26/19 Daily Operations: 06/22/2019 -Saturday Held PJSM and discussed Daily activities. Checked Fluids and serviced rig. Pulled BPV, PU YT Elevators dressed for 3-1/2" tbg. MU 3-1/2 Landing Jt and BOLDS. PU on completion string and pulled PBR off seat @ 72k and pulled hanger to Rig Floor and BO/LD same. LD 3 its at closed pipe rams. MU Circulating Lines. NOTE: Injection Test was not successful. Plan to go to Appendix A P&A Option 2 on the Sundry Displaced well with 208bbls of 9.6# Brine taking produced water returns to the 400 bbl Johnson Tank. Circulating rate @ 3 bpm/750psi. With the 180 bbls pit had to shut down the pump in between loads to build the 9.6# Brine. The Chain for the lube pumps came apart on the Mud Pump. SD to repair. Continue circulating 9.6 Brine returning to the Johnson Tank, Displaced a total of 365 bbls. Spotted Catwalk and pipe racks. PU Handling Tools and Prep Rig to trip. TOOH L/D 32 its of 3-1/2" 9.2 N-80 IBT xo and 35 its of 3-1/2" 9.3# J-55 EUE 8rd and 1 GLV. With oil showing in pipe while tripping SD and reversed circulated 30 bbls and returns were clean. 06/23/2019 -Sunday Held PJSM and discussed daily ops. Check fluids and serviced rig. Continued TOH L/D 3-1/2" 9.3# J-55 EUE 8rd tbg having to stop and circulate every 10jts due to oil showing on pipe. Could not circulate hole clean because of the perforated joint @ 5,000'. LD its 151 that was tbg punched and reversed circulated 60 bbls and returns were clean. Continued TOH LD a total of 290 Jts of 3-1/2" 9.3# J-55 EUE 8rd tbg. SD Rig when driller noticed gear box smoking, called out mechanic and found the pinion gear had some slack in it. Cleaned, organized and serviced rig. Mechanics working on the right angle drive replacing a worn bearing and new seals in the pinion. 06/24/2019 - Monday Held PJSM and discussed daily ops. Check fluids and serviced rig. Cont TOH w/ 3-1/2" Completion String, LD a total of 67 jts of 3-1/2" 9.2# N-80 IBT Tbg, 237 Jts of 3-1/2" 9.3 J-55 EUE Tbg, 2 3-1/2" GLM and 13-1/2" X -nipple. Loaded 3-1/2" Completion string and hauled to Tubo for Inspection. PU and Handling tools for BHA, Strapped, Tallied and MU the Fishing BHA#1.4-3/4" Intensifier, 6 each 4-3/4" Drill Collars, 4-3/4" Oil Jar, 4-3/4" Bumper Sub, Stop Sub w/5-15/16" Ring, Spear Extension, Drain Sub and Itco Spear Min OD .75" amd Max OD 3.13". Total BHA length is 226.38'. Racked and tallied 2-7/8" PH6 7.9# P110 Work -string. TIH with Weatherford Fishing BHA #1 on 204 Jts of 2-7/8" PHIS 7.9# P110 Work -string f/ Surface t/6,623'md. (avg TIH rate at —880 per hr). Secured well SDFN. 06/25/2019 -Tuesday Held PJSM and discussed daily activities TIH with Weatherford Fishing BHA #1 on 2-7/8" PH6 7.9# P110 Work -string f/ 6,623'md t/9,661'md. (avg TIH rate at —880 per hr) Establish fishing parameters 68K up/62k dn. Speared into FHL Packer set do 10k and PU 10k over. MU TIW and lined up cgs to the gas buster. PU to 108k (40k over) sheared packer and observed weight drop to 78k 10k over string weight. L/D 1 Jt. Lined up well to circulate. Rolled pump over at 3bpm/1,000psi and reversed circulated a 50bbl bottoms up w/returns clean. Prep Rig to Stand back 2-7/8" Workstring. SOOH w/154 Stands of 2-7/8" PH6 and L/D a single. Racked 1 stand of 4-3/4" DC. PU BHA Handling tools and L/D Weatherford 4-3/4" Intensifier, 4 each 4-3/4" Drill Collars, 4-3/4" Oil Jar, 4-3/4" Bumper Sub, Stop Sub w/ 5-15/16" Ring, Spear Extension, Drain Sub, Itco Spear and Baker 7" FHL Packer. MU 2-3/8" Test Plug and landed with 2-3/8" Test Jt. RILDS. Secured Well and SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 2313-03 Rig 401 50-133-10102-01 1 184-010 6/10/19 1 8/26/19 Daily Operations: 06/26/2019- Wednesday Held PJSM and discussed daily activities. Checked fluids and serviced rig. Filled Stack and 2-3/8" Test Jt. Closed Bag and Pressure Tested 250-2,500psi good test. Bleed off pressure. Closed pipe ram and pressure tested 250-2,500psi good test. Charted and filed test. Witness was waived by Jim Regg 6-24-19 at 09:55. Pulled Test Hanger to Rig Floor. BO/LD same and the Tested Jt. TOH LD 28 jts of 2-3/8" 4.7# N-80 EUE 8rd and 1 Locator Seal Extension. PU 2-7/8" YT Elevators and Weatherford handling tools. MU Csg Scraper BHA consisting of 4-1/8" Junk Mill, 5" Csg Scraper, 24 Jts of 2-7/8" PH6, 7" Csg Scraper, 4-3/4" Oil Jars and 2-4-3/4" Drill Collar. TIH w/ BHA and 319 jts of 2-7/8" 7.9# PH6 P110 work-string. Worked BHA thru Liner Top with issues. Continued TIH. Worked scrapers at CIBP depths ((d 10.550' and (a 9.820'. Set Pipe In Slips, closed Pipe Rams and reversed circulated 2 bottoms up 100bbis @ 2.5bpm/1000psi. Returns were clean after 2nd bottoms up SD Pump. Secured Well and SDFN. 06/27/2019 - Thursday Held PJSM and discussed Daily Ops. Checked fluids and serviced rig. Prep Rig Floor and TOH L/D 271 Jts of 2-7/8" 7.9# PH6 P110 and Racking Back 36 stands. PU BHA handling tools and L/D Csg Scraper BHA consisting of 4-1/8" Junk Mill, 5" Csg Scraper, 24 Jts of 2-7/8" #7.9PH6, 7" Csg Scraper, 4-3/4" Oil Jars and 2-4-3/4" Drill Collar. Secure well and S/D for night. 06/28/2019 - Friday Morning safety meeting and daily plan forward MIRU HES E-line, P/U and RIH w/5" CIB (3.710" OD )and correlate to top of Liner Hanger @ 9,824'. RIH and tag top of Gravel Pack Packer @ 10,550'. P/U to 10,530' (clean pipe and above casing collar) and set CIB. P/U and re-tag plug to verify in place and POOH w/ a-line. R/U dump bailer and RIH on a-line. Tagged CIB on first bailer run at 10,530'. Then make 4 dump bailer runs placing 40' cement on top of CIB. POOH and lay down e- line. Perform BOP test as per sundry testing 250 low and 2,500psi for high test. Testing with 2-7/8" test mandrel. Remainder of job to run on 2-7/8" tubing only. All tests passed for good BOP test. Secure well and clean work areas. S/D for night and WOC. 06/29/2019-Saturday Morning Safety meeting and daily plan forward. Check fluids in equipment and fire up equipment P/U a-line and RIH with CCL- weight bar - drive down bailer. Tool length 9' from bottom of bailer to CCL detector. RIH and set down easy at 10,520'. Calculated top should have been @ 10,485' . POOH w/ a-line and checked bailer. Cement in bailer was semi-hard. Called engineer and plan forward is to dump bail 84 gallons (2 bbls cement ) on top of current top (10,520'). Make 10 dump bailer runs dumping total of 84 gallons (2 bbls) 16.Oppg cement from 10,520' up to 10,410' (110' of cement) Secure Well and S/D for night and WOC. Hilcorp Alaska, LLC 14 c.y Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 2313-03 Rig 401 50-133-10102-01 1 184-010 6/10/19 1 8/26/19 Daily Operations: 06/30/2019 -Sunday Morning safety meeting, plan forward, check fluids and start equipment. Prep a -line to RIH and then discuss plan with State Inspector Bob Noble. RIH with wireline and tae cement 0 10.350'. Indicating 190' good cement on top of bridge plug. Good solid set down and clean pick-up. POOH w/ wireline. Top off hole with 5bbls 9.6ppg brine and allow air to clear. Pressure up to 500 psi and hold for 5 mins and bleed off to purge air. Pressure test 7" casing along with 5" liner and cement/bridge plug. Pressure up to 2,700psi and hold for 30 mins. 15 minute test psi was 2,660psi and 30 minute test psi was 2,650 psi. Bleed off pressure and verify chart for good test with Inspector Bob Noble. R/U a -line in prep to RIH with CCL - Baker 20 setting tool and 7" Legacy bridge plug (5.610" OD). RIH w/ bridge -plug and tag liner top @ 9,824'. Correlate log to Top of Liner and set BP @ 9,810' (10' above collar). P/U and tag plug and POOH a -line. RDMO a -line. Start P/U and RIH w/ 2-7/8" 7.9# PH -6 tubing. RIH and tag bridge plug w/ 6' in on joint # 322 for DPM of 9,806' to tag plug. Lay down joint 322 and secure well. run (9,800' for 1,225 feet per hour) Secure well and S/D for night. 07/01/2019 - Monday Morning Safety meeting and daily plan forward. HES Cementers discussed safety and procedures for R/U and R/D and pumping cement plug. MIRU HES Cementers, tubing tail 5' above CIB @ 9,810' -PT lines to 3,500 psi, pump 5 bbls lead F/W down tubing, then 8 bbls 15.8ppg Class G cement -1bbl F/W tail and swap to 9.6 ppg brine. Displace cement plug w/ 45bbls 9.6 ppg brine, Pull 8 stands of 2-7/8" PH -6 tubing (pulling dry). Calculated TOC @ 9,595' Close annular and reverse out tubing with 100bbls 9.6 ppg brine with clean returns.RDMO HES cementers, Start POOH w/ 2-7/8" PH -6 tubing standing back 36 stands total, then come out laying down with 249 joints 2-7/8" PH -6 tubing. SIMOPS rebuild fluid end on service pump. (replaced seats and valve seals.) Clean work area, secure well and S/D for night. 07/02/2019 -Tuesday Morning Safety meeting, daily plan forward, fire up equipment. RIH w/ a -line and CCL, weight bar, and 2' drive down bailer and tag cement @ 9,528'. Allie Schoessler w/ BLM witnessed. POOH w/ a -line. Line up rig pump and pressure test CIB @ 9810' and cement from CIB to 9528' to 2500 psi as per sundry. Start pressure 2765, 15 min psi=2,750 30 min psi= 2,750. Test run for 30 minutes for good test. Bleed off and prep to RIH w/ a -line. P/U 7" Legacy CIBP on Baker 20 setting tool and RIH to 2,190' and set CIBP same depth. Allie S. w/ BLM witnessed. POOH and RIH 2 runs shooting casing punch holes from 2,189' to 2,184' and 1,939' to 1,934'. Monitoring 11" casing annulus. Pressure increased from 0 to 100psi on backside (11" annulus). Bleed off 11" annulus to Johnson tank w/ small amount of oil and then H2o returns. Indicating good u -tube from 7" annulus to 11" annulus. RDMO a -line and P/U and RIH w/ 2-7/8" tubing and tag CIBP @ 2,190'. Laydown 1 joint and secure well. Clean work area and straighten equipment, tool rooms, carry trash to incinerator, replace oil soak pads under equipment. S/I and secure well for night. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 2313-03 Rig 401 50-133-10102-01 1 184-010 6/10/19 1 8/26/19 Daily Operations: 07/03/2019- Wednesday Morning safety meeting, daily plan forward, fluid checks and fire up equipment. Prep fluids and well for cement job, space out 2-7/8" PH -6 tubing to have tubing tail 5' above CIBP @ 2,190' as per Sundry- stand by for Halliburton Cementers MIRU HES Cementers, PT lines for 250 low to 3,000psi high for good test. Pump 5 bbls lead F/W Then 17 bbls 15.8 ppg Class G cement. (Lower squeeze holes showed no communication to give a calculated 1,740' TOC after pumping) Follow with 1 bbl F/W and then 8 bbls 9.6ppg brine. R/D HES cementers, pull 12 stands at 2 minutes per stand shut annular and reverse out with 24 bbls 9.6 brine . Shut well At blinds and hold 500 psi for 30 mins -Lay down 48 joints 2-7/8" tubing, - break down 12 stands 2-7/8" PH -6 tubing. Clean work area move equipment and prep for rig move. Clean work area - secure well and S/D for night. 07/04/2019 - Thursday Morning Safety meeting, daily plan forward, check fluids and fire up equipment. MIRU a -line, zero a -line @ LDS and RIH with CCL, weight bar, and drive down bailer. RIH to 1,662' and tag cement. POOH w/ a -line. Bailer showed good cement core. P/U 7" Legacy bridge plug w/ Baker 20 setting tool and CCL. Zero and RIH and find collar @ 162'. Set CIBP @ 170'. POOH, P/U 5' casing punch and RIH and punch casing from 169' to 164'. POOH a -line. Shut blinds and pump down 7" casing @ lbpm @ 700psi with bbl for bbl returns up 11-3/4" Casing. S/D RDMO a -line. MIRU HES Cementers. Calculate job volume of 18.2 bbls 15.8ppg Class g cement w/ job plan to pump 22bbbls of same cement. Start pumping cement @ .7bpm down 11-3/4" casing taking returns up 7" casing at 684psi. PSI fall to 487 psi and see cement hit squeeze holes @ 12.5 bbls away. Psi increase to 687psi. Pump total of 20bbls with good cement returns to surface and Halliburton run out of cement @ 20bbls. Final pump psi @ 664 psi -S/D and wash up. RDMO Halliburton Start RDMO HAK-410 to 4313-15 Install old tree on well for dry hole tree. Cement visually at surface inside 7" casing. 08/26/2019 - Monday BLM/AOGCC Inspectors onsite, upon verification of cured cement to surface the wells abandonment plate was welded in accordance with BLM/State of Alaska requirements. K IHirorp Alaxka, LLC RKB: 145'/ GL: 128' AMSL KB -THF: 17.0' 22" 37' TOC @1662' i 11 3/4", 2,040' (131 l0( unknnan a CBL TOC unknown TOL 9,824' 7" 10,013' CBLTOC 10,308' 5 6 1 Surface Casing Punches @ 164'-169' & 1,934'- 1,939, 2,184'- 2,189 i 'i SCU 23B-03 Schematic Casino & T u b i n a Size I EWE LRY Type Wt Grade ID Top Btm I Hole Cot: Cmt To 22" Conductor Btm(MD) Top(ND) CIBP w/ 528' cement on top (TOC @ 1,662') 7/3/19 Surf 37' Phase unknown Surf. 11-'/." Surf Csg 47 1-55 11.250" Surf 2,040' 16" 1800sx Surf. 7" Prod Csg 29 2.875" 6.184" Surf 157' 9-'/e" 1,200 m Unknown 7" 23 6.366" 157' 4,630' 7" 26 N-80 6.276" 4,630' 6,473' 7" 29 6.184" 6,473' 6,805' 7" DV Collar 6,805' 6,807' 1,000 sx Unknown 7" 296.184" 6,807' 8,273' 7" 29 P-110 6.184" 8,273' 10,013' 5" Liner IS N-80 4.276" 9,824' 10,970' 6" 225 sx 10,308' 10,740 6 27 60 1-11/16- 5/8/89 H-5 10,880' 10,905' 10,740' Tubing 3 Y ", IMT -MOD 3 S" EUE 8RD-MOD 9.2 1 9.3 N-80 J-55 1 2.992" 2.992" 1 0' 982' 982' 1 9,673' C I OD 4.250- 4.500" 2'K ", EUE 8RD-MOD 1 4.7 N-80 1 1.995" 1 9,673' 1 10,553' 3.063- .063" JEWELRY DETAIL No. Depth ID OD Item 1 170' - CIBP w/ 170' cement to surface 7/4/19 2 2,190' Btm(MD) Top(ND) CIBP w/ 528' cement on top (TOC @ 1,662') 7/3/19 3 9,810' Phase Comments CIBP w/ 282' cement on top (TOC @ 9,528') 7/1/19 4 10,540' 4.000" 5.750" CIBP w/ 190' cement on top (TOC @ 10,350') 6/29/19 5 10,555' 2.686" 4.140" Baker SC -11- Gravelpack Packer 6 10,578' 1.995" 2.875" Johnson & Baker welded screen w/ centralizers (5 blank jts/6 welded screen jts) 7 10,925' - 3.937" 1 Model N-1 Bridge Plug TOC @ 9,528' 1 3 dPe �f�(D Leaking Liner Top YD'S Z S @ 10,350' 4 Tag Fill 1.50" Bailer 10,731' SLM 10/18/01 - H-2 H-3 H-3 H-4 H-5 H-5 5" 7 LZ 10,970' TD =10,971' MD / 10,825' TVD PBTD = O' MD / 0' TVD MAX HOLE ANGLE = 27° A 10,047' PTD: 184-010 API: 50-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Dh Threads: 3-1/2" IBT-MOD Updated by DMA 09-06-19 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) SPF Ft Phase Comments 2/20/98 H-2 10,750' 10,760' 10,619' 10,628' 6 10 60 1-11/16" 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' 10 10 60/90 3-3/8" 2/20/98 H-3 10,785' 10,820' 10,651' 10,684'- 6 35 60 1-11/16- 5/8/89 H-4 10,820' 10,840' 10,684' 10,703' 10 20 60/90 3-3/9- 2/20/98 H-5 10,853' 10,880' 10,715' 10,740 6 27 60 1-11/16- 5/8/89 H-5 10,880' 10,905' 10,740' 10,763' 14 25 60/90 3-3/8" Tag Fill 1.50" Bailer 10,731' SLM 10/18/01 - H-2 H-3 H-3 H-4 H-5 H-5 5" 7 LZ 10,970' TD =10,971' MD / 10,825' TVD PBTD = O' MD / 0' TVD MAX HOLE ANGLE = 27° A 10,047' PTD: 184-010 API: 50-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Dh Threads: 3-1/2" IBT-MOD Updated by DMA 09-06-19 SCU 23B-03 Wellhead Removed/Cemented to Surface 9Yi.1 � ♦ i� l f 'i�qn4 i��l � [�Ji : f YF�.I 19 :11:30 `t -61.00 ° N42W 5653mi1s TRUE -__ t w PRIEFS AAP SCU 2313-03 Marker Plate Installed 2 L t- NJ -` 1Y Consulting Inc McLANE Well S.C.U. 236-03 Plug & Abandon Memo Via email Date: 7/16/2019 To: Hilcorp Alaska LLC .................................................... Attn: Cole Bartlewski From: James A. Hall, PLS Project: Swanson Creek Unit —SCU 2313-03 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 Creek Unit SCU 23B-03 well located in Section 3, Township 7 North, Range 9 West, Seward Meridian, Alaska. The survey was performed on July 3, 2019. 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) original ground survey measurements were observed at the perimeter of the pad in opposite positions from the well location. A prorated original ground elevation at the well was computed from the (2) pad perimeter original ground shots. A top of pad elevation was also recorded on or adjacent to the well casing and a reference grade stake set with a measurement to the proposed cutoff elevation. Enclosed is Exhibit A which includes well casing cutoff detail with pad, original ground, and proposed casing cutoff elevations. • Mean pad surface grade in vicinity of well casing: 128.4 ± (2019) • Original ground elevation in vicinity of well casing: 128.1 ± (2019) • Cutoff depth requirement: 3.0' below original ground elevation • Minimum casing cutoff elevation: 125.1' • Casing cutoff elevation as staked in field: 124.1' The cutoff mark elevation of 124.1', as referenced in the field, exceeds the required minimum cutoff elevation of 125.1'. Please feel free to contact me if you have any questions or comments. (Sinkeer/ellyy, aJ mes A.PLS McLane Consulting, Inc. *:'49R JAMES A. HALL P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email jhall@mclanecg.com JAMES A. HALL • d 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 ZONE4 ARE: N = 2458384.578 / E = 1483669.4441 ELEV = 212.690 ORIGINAL GROUND SHOT X ELEV=127.0 (2019) C J PAD SHOT (NEAR WELL) SCU 238-03 P&A AELEV.=128.4' (2019) ASP NAD83 ZONE 4 O WA7 N: 2457673.5 E: 1488751.2 ELEV.=128.4' ✓ X �— ORIGINAL GROUND SHOT ELEV.=129.2' (2019) WELL GRAPHIC SCALE �so Ioo zoa 1 inch = 100 ft. WELL CASING CUT-OFF DETAIL WELL CASING 'TO BE REMOVED PAD ELEV = 128.4' f O.G. ELEV = 128.1' t --- ----------- 4. 0 ---------- 4.0 REFERENCED WELL CASING CUTOFF AT FI FV = 194 1' PRO u HILCORP ALASKA, LLC Consulting Inc SWANSON CREEK UNIT °" r "1flR01 � WELL SCU 23B-03 By ow NeLmPLUG AND ABANDON EXHIBIT -A ""; PROfiGTNO. 19)009 EA WEEMM r~MW IsuPV YIWI IMUING NAD 83, ASP ZONE 4 eoacrw ,9m �90n'! P.o.B&1J) 4E9 218 F U, N(K889 VgCE: ' 4i1G F0.1. (907)28l2265 l«AniSHEfT E, L SMWIdPEeMQANE6GCW Hilcorp Alaska, LLA. SECTION 3, TOWNSHIP 7 NORTH, RANGE 9 WEST, SEWARD MERIDIAN ALASKA Remark: AOGCC Coordinate Check 29 January 2020 INPUT Stale Plane, NAD83 5004 -Alaska 4, U.S. Feet OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. SCU 23B-3 1/1 NorthinglY: 2457 673.5 EastinglX: 1488751.2 Convergence: -0 44 20.24551 Scale Factor: 0.999926177 NorthingN., 2457912.361 Easting/X: 348728.330 Convergence: -0 44 13.29461 Scale Factor: 0.999926039 Grid Shift (U.S. ft.): X/Easting = -1140022.9, Y/Northing = 238.9 Datum Shift (m): Delta Lat. = 62.803, Delta Lon = -121.051 Corpscon v6.0.1, U.S. Army Corps of Engineers MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg� �� 117/1 1 DATE: August 28° 2019 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandon Petroleum Inspector SCU 2313-03 Hilcorp Alaska Inc. PTD 1840100; Sundry 319-136 8/26/2019: 1 arrived at Swanson River Field and met with Mike Erstrom (Hilcorp Construction Foreman). We went to the well location and I verified there was good hard cement to surface and all the correct information was on the marker plate. The cut off is over 4 feet below grade. I also took pictures of the hard cement, marker plate, marker plate after welded on and the depth of the cutoff. Attachments: Photos (4) 2019-0826—Surface—Abandon SCU 23B-03_bb.docx Page 1 of 3 Surface Abandonment — SCU 2313-03 (PTD 1840100) Photos by AOGCC Inspector B. Bixby 8/26/2019 2019-0826_Surface_Abandon_SCU_23B-03_bb.docx Page 2 of 3 PREFS -i.e — MAI MAP ,� IN► i ✓. ,'�� 2019-0826_Surface_Abandon_SCU_23 B-03_bb. docx Page 3 of 3 _ PREFS r• . x � 1 i Ir r rC X11 PREFS -i.e — MAI MAP ,� IN► i ✓. ,'�� 2019-0826_Surface_Abandon_SCU_23 B-03_bb. docx Page 3 of 3 MEMORANDUM TO: Jim Regg I5I ( o P.I. Supervisor � `yl 1 FROM: Bob Noble Petroleum Inspector Section: 3 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Phillip Shumake Casing/Tubing Data (depths are MD) Conductor: 22" O.D. Shoe@ Surface: 113/4" O.D. Shoe@ Intermediate: Feet O.D. Shoe@ Production: 7 O.D. Shoe@ Liner: 5' O.D. Shoe@ Tubing: 31/2x2318" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 30, 2019 SUBJECT: Well Bore Plug & Abandonment SCU 23B-03 ' Hilcorp Alaska LLC PTD 1840100; Sundry 319-136 7N Range: 9W Meridian: Seward NA Total Depth: 10971 ft MD - Lease No.: FedA028997 Suspend: P&A: X 37 Feet 2040 - Feet Cut@ Feet 10013 Feet 10970 Feet 10553 Feet Type Plug Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bridge plug 10530 ft MD 10343 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing IA 2700 2660 2650 P ✓ OA 20 20 1 20 Initial 15 min 30 min 45 min Result Remarks: I witnessed the Hemlock plug verifications - tag and pressure test - for the isolation plug set above the gravelpack packer inside the 5' production liner (Plug #1). Cast Iron bridge plug was set and cement dump bailed on top prior to my inspection. Attachments: none rev. 11-28-18 2019-0630_Plug_Verification_SCU_23B-03_bn THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 2313-03 Permit to Drill Number: 184-010 Sundry Number: 319-136 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www, a o g c c. a l a s ka. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, *4�� Daniel T. Seamount, Jr. Commissioner r DATED this,?— 3day of April, 2019. RBDMSLi� APR 2 3 2019 RECEIVED STATE OF ALASKA MAR 2 1 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS OGCC 1. Type of Request: Abandon ❑✓ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 184-010 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10102-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Soldotne Creek Unit (SCU) 23B-03 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028997 ' Swanson River/ Hemlock Oil 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): Fill @ 10,971' 10,825' 10,925' 10,782' -387 10,925' 10,731' MD Casing Length Size MD TVD Burst Collapse Structural Conductor 37' 22" 37' 37' Surface 2,040' 11-3/4" 2,040' 2,040' 3,070 psi 1,510 psi Intermediate Production 10,013' 7" 1 10,013' 9,952' 1 6,340 psi 3,830 psi Liner 1,146' 5" 10,970' 110,824' 1 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" x 2-3/8" 9.2# N-80 / 9.3# J-55 14.7# N-80 982 19,673'/ 10,553' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): FHL Packer / SC -1 L Packer; N/A 9,673' MD / 9,642' TVD; 10,555' MD / 10,439' TVD; N/A 12. Attachments: Proposal Summary Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development ❑� • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerlrDhilcoro.com Contact Phone: 777-8420 Authorized Signature. Date: -,) 1 R a -c(-, t e ) COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity OR"' BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4,R S0i7 �e 3�-�_-+— RBDMS1/X-/APR 2 3 2018 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑v • Subsequent Form Required: /©— 5/ Z� APPROVED BY A Approved by COMMISSIONER THE COMMISSION Date v-Zz-/9 4� �� /1• AA'' AA� submit Form and /}Form 10-4 Revises 4/2 Approved applic0 R4dfff 12F�f1t�fLm the date of approval. �� Attachments in Duplicate H Hilearp Aleeka, LL, Well Prognosis Well: SCU 236-03 Date: 03/20/2019 Well Name: SCU 2313-03 API Number: 50-133-10102-01 Current Status: Shut -In Oil Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: Rig 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 184-010 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) APE Number: Current Bottom Hole Pressure: — 5,080 psi @ 10,740' TVD (0.473 psi/ft pressure gradient) Maximum Expected BHP: — 5,080 psi @ 10,740' TVD (Based on normal gradient) Max. Potential Surface Pressure: — 2,072 psi @ Surface (Assumes a fluid (0.437 psi/ft) level at 5,000 It & 0.10 psi/ft gas to surface) Brief Well Summary Soldotna Creek Unit 238-03 was the second sidetrack drilled (February 1984) from the original SCU 23-03 parent well (originally drilled in 1963). The first sidetrack, SCU 23A-03, was drilled and logged through the Hemlock formation and then immediately sidetracked further up -hole in the parent wellbore, as SCU 2313-03. SCU 2313-03 targeted H5 oil reserves in the middle part of the Hemlock formation. In 1989, a rig workover was conducted to run a gravel pack across the Hemlock H2 through H5 intervals. The H2, H3, and H5 sands were re - perforated through tubing in 1998, with little to no added production. The well has been shut-in since April 1998. The purpose of this Sundry is to permanently P&A the well, I Hilcorp asks for a Variance from 20 AAC 112 (c) (1) (E) and 43 CFR 3160 G 2. Hilcorp proposes to set a cement retainer (as described in the procedure below) and squeeze the gravel pack across the Hemlock intervals using the down squeeze method. This request is to allow Hilcorp to set a plug (cement retainer) at 9,650' MD, which is 1,100' above the top perforations (10,750' MD). Hilcorp will set the cement retainer above the upper packer (FHL packer at 9,673') and squeeze down the 2-3/8" completion into the gravel pack. The volume of the 2-3/8" completion from the cement retainer at 9,650' to the top of the perfs at 10,750' is less than 5 bbls (^'4.25 bbls). The planned cement volume to be pumped will be twice this volume (10 bbls), in order to squeeze cement into the gravel pack. Pre - Rig Work: 1. Provide 24hr notice to the AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112 (h). Notify the BUM of P&A as per 43 CFR 3160 G 2. RU Pump Truck. RU on tubing and casing and perform a combination pressure test to 2,500 psi on chart for 30 minutes. Bleed down pressure. a. Note: Hole punch at 5,000' in the 3-1/2" tubing, thus the combination tubing / IA test. �3. MIRU Slickline. Pressure test lubricator to 3,000 psi. RIH and pull packoff plug @ 9,875'. RD Pl'�, Slickline. x Y JJ 4. RU Pump Truck on the tubing and perform a pump -in test. Establish PIR. Monitor pressure on I� p ky both the tubing and IA (due to hole in tubing at 5,000'). RDMO Pump Truck. 7 H Hil.p Alaska, LG Rig #401: Well Prognosis Well: SCU 23B-03 Date:03/20/2019 5. MIRU Rig 401. 6. Set Back Pressure valve. ND wellhead, NU BOP and test 250 low & 2.600 psi highannular to 250 G psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. Note: Notify pa {, AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness. DD r a. Perform Test. b. Test VBR rams on 3-1/2" test joint. �v6 c. Submit to AOGCC completed form 10-424 within 5 days of BOPE test. Copy to BLM. 7. PU on tubing and sting out of PBR @ 9.660'. Circulate well with 9.6 ppg brine. POOH w/ 3-1/2" tubing, laying down GLM's and standing back pipe. y 8. PU Cement retainer. RIH on 3-1/2" tubing to 9,650' and set same. 9. RU cementers. Mix and pump 12 bbls of 15.8 ppg class G cement. ` frova. Pump 10 bbls through the cement retainer into the gravel pack. i� b. Un -sting from the cement retainer and dump the remaining 2 bbls of cement on top of the retainer (^'54' in 7" 29# casing). 10. Wash up tubing and POOH. Note: CBL's indicate that cement was not brought up past the surface shoe so running a new CBL is not necessary. Work scope will proceed as if there is no cement across the surface casing shoe (behind the 7" casing). 11. RU E -line. PU. RIH w/ 7" CIBP to 2190' and set same. POOH. If / 12. PU casing punches and RIH to 2,189' (+/-) and punch casing from 2,189' to 2,184' (+/-). POOH qVn 13. PU Second set of casing punches and RIH to 1,939' (+/-). Punch casing from 1,939' to 1,934' (+/-) POOH. 14. RIH w/ 3-1/2" tubing (open ended) to plug at 2,190'. PU 5'. 15. RU Cementers and test lines. Spot a balanced plug of 15.8 ppg class G cement from 2,190' up to gJ 1,840'. 16. Pressure up on well to 500 psi for 30 mins. Bleed down and WOC. kV 17. RU E -line. Test Lubricator to 3,000 psi. RIH and tag cement. Make sure TOC is above 1,940', to to•'°•� ensure at least 100' of cement above the 11-3/4" surface casing shoe (@ 2,040'). POOH. RIH w/ 2"" 7" CIBP to 160' and set same. POOH. 19. PU tubing punches and RIH to 159'. Punch holes from 159' to 154'. POOH and RD E -line. 20. Rig up cementers to back side. Establish circulation down the IA through the tubing punches and k up the 7" casing. Circulate a 15.8 ppg cement plug from 159' to surface. RD Cementers, WOC. 21. Place dry hole tree on well. 22. RDMO Workover Rig. Well Prognosis Well: SCU 236-03 Hi1wra Alaska, LLQ Date: 03/20/2019 Post Rig Abandonment Procedures: 23. Excavate cellar, cut off casing 3' below natural GL. 24. AOGCC and BLM 48hrs in advance. 25. 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: Far Hilcorp Alaska, LLC b. PTD: 184-010 c. Well Name: SCU 236-3 API:50-133-10102-01 26. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 IILG 27. Photo document casing cut-off and Welded Plate install. 28. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form 10, collect GPS coordinates. ff nilmrn Alnskn, LU Well Prognosis Well: SCU 23B-03 Date: 03/20/2019 Well Name: SCU 238-03 API Number: 50-133-10102-01 Current Status: Shut -In Oil Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: Rig 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 184-010 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1952127 APPENDIX A P&A Option 2 — If Injection Test is Not Successful Pre - Rig Work: 1. Provide 24hr notice to the AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112 (h). Notify the BLM of P&A as per 43 CFR 3160 G 2. 2. RU Pump Truck. RU on tubing and casing and perform a combination pressure test to 2,500 psi on chart for 30 minutes. Bleed down pressure. a. Note: Hole punch at 5,000' in the 3-1/2" tubing, thus the combination tubing/ IA test. 3. MIRU Slickline. Pressure test lubricator to 3,000 psi. RIH and pull packoff plug @ 9,875'. RD Slickline. 4. RU Pump Truck on the tubing and perform a pump -in test. Establish PIR. Monitor pressure on both the tubing and IA (due to hole in tubing at 5,000'). RDMO Pump Truck. Rig #401: 5. MIRU Rig 401. 6. Set Back Pressure valve. ND wellhead, NU BOP and test 250 low & 2,600 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. Note: Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness. a. Perform Test. b. Test VBR rams on 3-1/2" test joint. c. Submit to AOGCC completed form 10-424 within 5 days of BOPE test. Copy to BLM. 7. PU on tubing and sting out of PBR @ 9,660'. Circulate well with 9.6 ppg brine. POOH w/ 3-1/2" tubing, laying down GLM's and standing back pipe. 8. If the pump -in test (Step 4) was successful, proceed to Step 10. 9. If the pump -in test (Step 4) was not successful, proceed to Step 14, 10. PU Cement retainer. RIH on 3-1/2" tubing to 9,650' and set same. 11. RU cementers. Mix and pump 12 bbls of 15.8 ppg class G cement. a. Pump 10 bbls through the cement retainer into the gravel pack. b. Un -sting from the cement retainer and dump the remaining 2 bbls of cement on top of the retainer (^'54' in 7" 29# casing). 12. Wash up tubing and POOH. 13. Proceed to Step 23. H IBleurp Alaska, LU Well Prognosis Well: SCU 23B-03 Date:03/20/2019 14. PU & RIH w/ Spear on 3-1/2" tubing and spear into PBR above Baker FHL packer 15. PU tubing to retrieve packer (75K shear) and 2-3/8" tubing below packer a. Tubing will pull out of seal bore assembly above the gravel -pack packer. 16. POOH w/ packer and tubing, laying down. 17. MIRU E -line. Pressure test lubricator to 3,000 psi. 18. PU & RIH w/ 5" CIBP to "'10,550'. Set same depth & POOH. 19, PU Dump Bailer and RIH to 10,550'. Dump bail 35' of cement on top of CIBP. POOH. a. TOC @ `10,515'. t �2 ,� �e y�l� N° IFY 20. PU & RIH w/ 7" CIBP to " (just above the 5" liner top). Set same depth and POOH. a. Note that the 5" liner top reportedly has a leak. 21. PU Dump Bailer and RIH to 9,820'. Dump bail 35' of cement on top of CIBP. POOH. a. TOC @ -9,785'. 22. Proceed to Step 23. Note: CBUs indicate that cement was not brought up past the surface shoe so running a new CBL is not necessary. Work scope will proceed as if there is no cement across the surface casing shoe (behind the 7" casing). 23. RU E -line. PU, RIH w/ 7" CIBP to 2190' and set same. POOH. 24. PU casing punches and RIH to 2,189' (+/-) and punch casing from 2,189' to 2,184' (+/-). POOH 25. PU Second set of casing punches and RIH to 1,939' (+/-). Punch casing from 1,939' to 1,934' (+/-). POOH. 26. RIH w/ 3-1/2" tubing (open ended) to plug at 2,190'. PU 5'. 27. RU Cementers and test lines. Spot a balanced plug of 15.8 ppg class G cement from 2,190' up to 1,840'. 28. Pressure up on well to 500 psi for 30 mins. Bleed down and WOC. 29. RU E -line. Test Lubricator to 3,000 psi. RIH and tag cement. Make sure TOC is above 1,940', to ensure at least 100' of cement above the 11-3/4" surface casing shoe (@ 2,040'). POOH. 30. PU, RIH w/ 2n'7" CIBP to 160' and set same. POOH. 31. PU tubing punches and RIH to 159'. Punch holes from 159' to 154'. POOH and RD E -line. 32. Rig up cementers to back side. Establish circulation down the IA through the tubing punches and up the 7" casing. Circulate a 15.8 ppg cement plug from 159' to surface. RD Cementers, WOC. 33. Place dry hole tree on well. 34. RDMO Workover Rig. Post Rig Abandonment Procedures: 35. Excavate cellar, cut off casing 3' below natural GL. 36. Notify AOGCC and BLM 48hrs in advance. 37. 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: (corp as , b . Well Name,: c. Well Name: SCU 23B-3 \ d. API:50-133-10102-01 38. 120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. H tile,,". Al.skn. LL 39. Photo document casing cut-off and Welded Plate install. 40. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form Well Prognosis Well: SCU 238.03 Date: 03/20/2019 xaH I coM Alaska, LLC RKB: 145'/GL: 128' AMSL KB — THF: 17.0' ," J. 11-3/4" ; 2,040' CBL IOC- fund unknown I- r 11i1i' 5,000 0111.'fOC'{ 10.308' � 8 u; I as SCU 23B-03 Schematic C an in o & T u In in n Size Type Wt 0 ED Top Btm 3 Cmt Cmt To 4 \N CBL TOC q ' unknown 37' 2.992' da Surf. � 6 �. 47 7-55 'i Surf 2,040' 16" 7 Surf. 7" TOLD 29 23 26 29 N 80 6.184" 6.366" 6.276" 6.184" 9,824' - 157' 4,630' 6,473' 6,805' 9-X" 1,200 sx Unknown 7" 1 7" 7" 7, 1,000 sx Unknown 7' 29 6.184" 6,807' 8,273' 7" 29 P-110 6.184" 8,273'10 013' 10,011' - Liner I N-80 0111.'fOC'{ 10.308' � 8 u; I as SCU 23B-03 Schematic C an in o & T u In in n Size Type Wt Grade ED Top Btm Hole Cmt Cmt To 22" Conductor 2.992" 5.250" I Surf 37' 2.992' unknown Surf. 113/," Surf Csg 47 7-55 11.250" Surf 2,040' 16" 1800 sx Surf. 7" Prod Csg 29 23 26 29 N 80 6.184" 6.366" 6.276" 6.184" Surf 157' 4,630' 6473' 157' 4,630' 6,473' 6,805' 9-X" 1,200 sx Unknown 7" 7" 7" 7" DV Collar 6805' 6,807' 1,000 sx Unknown 7" 29 6.184" 6,807' 8,273' 7" 29 P-110 6.184" 8,273'10 013' 5" Liner 18 N-80 4.276" 9,824' 10,970' 6" 1 225 sx 1 10,308' Tobio 3 % IBT-MOD 3% 3 % EUE 8RD-MOD 9.2 9.3 N-80 3-55 2.992" 2.992" 0' 982' 982' 9,673' - 3.937" C 1 OD 1750- .250" 4,500" 2 X ",EUE 8RD-MOD 4.7 N-80 1.995" 9,673' 10,553' 25 60/90 3.063" C��13 Leaking Liner Top 111TITMI k7a7:11I/_TII No. Depth ID OD Item 1 17' 2.992" - Shaffer Tubing Hanger, 3-1/2" IBT-Mod Lift Threads 2 1,993' 2.992" 5.250" 3-1/2"Camco KBUG Mandrel 8RD GLV #2 3 9,571' 2.992' 5.250" 3-1/2" Camco MMG-2 Mandrel 8RD GLV #1 4 9,627' 2.750" 3.500" XN-Nipple 5 9,660' 4.000" 5.750" PBR 6 9,673' 3.000" 5.968" Baker 7"x 3-1/2" FHL Packer (75k shear) 7 9,680' 2.992" 5.250" XO, 3-1/2" x 2-3/8" 7A 9,875' SUM 10,820 10,651' Tubing Packoff Plug 08/09/17 8 10,521' 1.875" 1 2.375" 1 X -Nipple 9 10,553' 1.995" 2.675" Baker Locator Seal Assembly, 20' of seals 10 10,555' 2.686" 4.140' Baker SC -11- Gravelpack Packer 11 10,578' 1.995" 2,875' Johnson & Baker welded screen w/ centralizers (5 blank jts/6 welded screen Its) 12 10,925' - 3.937" Model N-1 Bridge Plug Pat,v"o PIS 1.50" Bailer 10,731' SLM 10/18/01 H-2 • H-3 H-3 H-4 H-5 H-5 12; ti 10,970' TD = 10,971'MD / 10,825' TVD PBTD =10,925' MD / 10,782' TVD MAX HOLE ANGLE = 27° @ 10,047' WELL DATA PTD: 184-010 API: 50-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD Updated by PW 03-29-19 PERFORATION DETAIL r Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 2/20/98 H-2 10,750' 10,760' 10,619' 10,628' 6 10 60 1-11/16" 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' 30 10 60/90 3-3/8- 2/20/98 H-3 10,785' 10,820 10,651' 10,684' 6 35 60 1-11/16" 5/8/89 H-4 10,820 10,840 10,884' 10,703' 30 20 60/90 3-3/8" 2/20/98 H-5 10,853' 10,880' 10,715' 10,740' 6 27 60 1-11/16- 5/8/89 H-5 10,880' 10,905' 10,740' 10,763' 14 25 60/90 3-3/8" 1.50" Bailer 10,731' SLM 10/18/01 H-2 • H-3 H-3 H-4 H-5 H-5 12; ti 10,970' TD = 10,971'MD / 10,825' TVD PBTD =10,925' MD / 10,782' TVD MAX HOLE ANGLE = 27° @ 10,047' WELL DATA PTD: 184-010 API: 50-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD Updated by PW 03-29-19 22" 37' pat5.� 11-3/4" 2,040' RKB: 145' / GI.: 128' AMSL KB - THF: 17.0' 1 k TOC P otabove 1,,99.4{40' 2 CBL TO( unknmrn A CBL TOC unknown TOL 9,824' 7" 10,013' CBL TOC 10,308' 5 6 SCU 23B-03 Proposed Schematic (Option 2) r .. I. n A T .. k I w a+ TOC to Surface Using Punches Qe 1154'-1159' S 11,934' x1,939' 12,184'. 22,189' TOC @ 19,785' 3 Leaking Liner To Size Type I Wt I Grade I ID Too Btm I Hole Cmt Cmt To 22" Cenduclor I - I - I - Surf 37' - unknown Surf. 4 Surf Csa 1 47 1 1-55 1 11.250" 1 Surf 1 2040' 1 16" 1800M Surf. T' Prod Csg 29 2,875" 6.184" Surf 157' 93/." 1,200 sx Unknown T' 23 6.366" 15T A,630' 7" N 8D 26 6.276" 4,630' 6,473' 7" 29 6.184" 6,473- 6,805' 7" DV Collar 6,805' 6,807' 1,000 sx Unknoss+l 7" 29 6.184" 6,807' 8273' 7" 29 1 P-110 6.184" 1 8,273' 1 10,013' 5" Liner 18 N-80 1 4.276" 9,824' 10,970' 6" 225 ax 1 10.308' 10,740' 6 27 60 1 5/8/89 H-5 101880' 10,905' 10,740 Tuldne 14 25 60/90 3-3/8" i CRIB OD 3'b" IDT -MOD 9.2N-10 2.992" 0' 982• 3 4 •' EUE 8RD-h10D 9.3 J-55 2.991 982' _ 9 673' J.500" 2 % ", EUE 8RD-MOD 4.7 1 N -BO 1.995" 9,673' 10,553' p,p51" IMAM QV nCTAII No. Depth ID OD Item 1 2160' CIBP w/ 160' cement to surface 2 ±2,19(Y Btm(MD) Top(TVD) CIBP w "25(Y cement on top JTDC at or above 1,940') 3 29,820' Phase Comments CIBP w/ 35' cement on to (TOC 8a ±9,785') 4 210,550' 1 4.000" 1 5,750" CIBP w/ 35' cement on to TOC @ 210,515' 5 10,555' 2.686" 4,140" Baker SC -11. Gravelpack Packer 6 10,578' 1.995" 2,875" Johnson & Baker welded screen w/ centralizers (5 blank its/6 welded screen its) 7 10,925' 60/90 3.937" Model N-1 Bridge Plug n Q� cL ,� ✓ `y�� s , s t PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 2/20/98 H-2 10,750' 10,760 10,619' 10,628' 6 10 60 1-11/16" 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' SO 10 60/90 3-3/8" 2/20/98 H-3 10,785' 10,820 10,651' 10,684' 635 60 1-11/16" 5/8/89 H-4 10,820 10,840' 10,684' 10,703' 10 20 60/90 3-3/8" 2/20/98 H-5 10,853' 10,880 10,715' 10,740' 6 27 60 1-11/16" 5/8/89 H-5 101880' 10,905' 10,740 10,763' 14 25 60/90 3-3/8" 'rag Fill 1.50" Bailer 10,731' SLM 10/18/01 H-2 H-3 H-3 H-4 H-5 H-5 5„ 7 10,970' "nr TD = 10,971' MD / 10,825' TVD PBTD = 10,925' A'ID / 10,782" 1'VD MAX HOLE ANGLE = 270 Qn 10,047' PTD: 184-010 API: 50.133-10102,01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen UR Threads: 3-1/2" IST -MOD Updated by PW 03-20-19 Mourn Alaska. LLC RKB: 145'1 GL: 128' AMSL KB -THF: 17.0' 22" i 37' 11, TOC @ or above i�3 1,940' 11-3/4" 2,040' CBL TO( unknown 0 7�G�7 1 CBL TOC unknown 5 lµ TOL 4 9,824' 7" 10,013' :l CBL TOC R' 10,308' 7 S all 9 _ c 2 A TOC to Surface Casing Punches @ 1154'-±159' ±1,934'- ±1,939' ±2,184'- ±2,189' SCU 23B-03 "" a Proposed Schematic C as in a & T u b in g Size Type Wt Grade ID Top Btm Hole Cat Cart To 22" Conductor Surf 37' unknown Surf'. ii-%" Surf Csg 47 J-55 11,250" Surf 2,040' 16" 1800 sx Surf. 7" 29 6.184' Surf 157' 7" 23 6.366" 157' 4,630' 7" 26 N-80 6.276" 4,630' 6,473' 1,200 sx Unknown 7" Prod Csg 29 6.184" 6,473' 6,805' 9-''/v" 7" DV Collar 6,805' 6,807' 7" 29 6.184" 6,807' 8273' 1,000 sx Unknown 7" 29 P-110 6.184' 8,273' 10,013' 5" Liner 18 N-80 4.276' 9,824' 10,970' G" 225 sx g4.25W' Tubing 3'/:",IBT-MOD 9.2 N-80 2.992" 0' 982' 3'/, ", FUE 8RD-MOD 9.3 J-55 2.992" 982' 9673' 8RDMOD 47 N-80 1.995" 9,673' 10,553' TOC @ ±9,596' 3 Leaking Liner Top JEWELRY DETAIL N No. Depth ID OD Item 1 ±160' - CIBP w/ 160' cement to surface 2 ±2,190' CIBP w/-250' cement on top (TOC at or above 1,940') 3 ±9,650' Cement Retainer w/ 2 bbls of cmt on top (TOC±9,596') 4 9,660' 4.000" 5.750" PBR 5 9,673' 3.000" 5.968" Baker7"x3-1/2" FHL Packer (75k shear) 6 9,680' 2.992" 5.250" XO, 3-1/2" x 2-3/8" 7 10,521' 1.875" 2.375" X -Nipple 8 10,553' 1.995" 2.675" Baker Locator Seal Assembly, 20' of seals 9 10,555' 1 2.686" 1 4.140" Baker SC-1LGravelpack Packer SO 10,578' 1.995" 2.875' Johnson & Baker welded screen w/ centralizers (5 blank jts/6 welded screen jts) 12 10,925' 1 - 1 3.937" Model N-1 Bridge Plug PERFORATION DETAIL Date Zone Top(MD) Btm(MD) I Top(TVD) Btm(TVD) I SPF I Ft Phase Comments 2/20/98 H-2 30,754 10,760' 10,619' 10,628' 6 30 60 1-11/16- 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' 30 10 60/90 3-3/8" 2/20/98 H-3 10,785' 10,820' 10,651' 10,684' 6 35 60 1-11/16" 5/8/89 H-4 10,820' 10,840' 10,684' 10,703' 10 20 60/90 3-3/8" 2/20/98 H-5 10,853' 10,880' 10,715' 10,740' 6 27 60 1-11/16" 5/8/89 H-5 10,880' 10,905' 10,740' 10,763' 14 25 60/90 3-3/8" Tag Fill 1.50" Bailer 10,731' SLM 10/18101 - H-2 II -3 I1-3 H-4 H-5 H-5 10,970' TD = 10,971' MD / 10,825' TVD PBTD =10,925' MD / 10,782' TVD MAX HOLE ANGLE = 27° @ 10,047' API: 5D-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD Updated by PW 03-20-19 TOC @ ±9,596' 3 Leaking Liner Top JEWELRY DETAIL N No. Depth ID OD Item 1 ±160' - CIBP w/ 160' cement to surface 2 ±2,190' CIBP w/-250' cement on top (TOC at or above 1,940') 3 ±9,650' Cement Retainer w/ 2 bbls of cmt on top (TOC±9,596') 4 9,660' 4.000" 5.750" PBR 5 9,673' 3.000" 5.968" Baker7"x3-1/2" FHL Packer (75k shear) 6 9,680' 2.992" 5.250" XO, 3-1/2" x 2-3/8" 7 10,521' 1.875" 2.375" X -Nipple 8 10,553' 1.995" 2.675" Baker Locator Seal Assembly, 20' of seals 9 10,555' 1 2.686" 1 4.140" Baker SC-1LGravelpack Packer SO 10,578' 1.995" 2.875' Johnson & Baker welded screen w/ centralizers (5 blank jts/6 welded screen jts) 12 10,925' 1 - 1 3.937" Model N-1 Bridge Plug PERFORATION DETAIL Date Zone Top(MD) Btm(MD) I Top(TVD) Btm(TVD) I SPF I Ft Phase Comments 2/20/98 H-2 30,754 10,760' 10,619' 10,628' 6 30 60 1-11/16- 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' 30 10 60/90 3-3/8" 2/20/98 H-3 10,785' 10,820' 10,651' 10,684' 6 35 60 1-11/16" 5/8/89 H-4 10,820' 10,840' 10,684' 10,703' 10 20 60/90 3-3/8" 2/20/98 H-5 10,853' 10,880' 10,715' 10,740' 6 27 60 1-11/16" 5/8/89 H-5 10,880' 10,905' 10,740' 10,763' 14 25 60/90 3-3/8" Tag Fill 1.50" Bailer 10,731' SLM 10/18101 - H-2 II -3 I1-3 H-4 H-5 H-5 10,970' TD = 10,971' MD / 10,825' TVD PBTD =10,925' MD / 10,782' TVD MAX HOLE ANGLE = 27° @ 10,047' API: 5D-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD Updated by PW 03-20-19 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) I Top(TVD) Btm(TVD) I SPF I Ft Phase Comments 2/20/98 H-2 30,754 10,760' 10,619' 10,628' 6 30 60 1-11/16- 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' 30 10 60/90 3-3/8" 2/20/98 H-3 10,785' 10,820' 10,651' 10,684' 6 35 60 1-11/16" 5/8/89 H-4 10,820' 10,840' 10,684' 10,703' 10 20 60/90 3-3/8" 2/20/98 H-5 10,853' 10,880' 10,715' 10,740' 6 27 60 1-11/16" 5/8/89 H-5 10,880' 10,905' 10,740' 10,763' 14 25 60/90 3-3/8" Tag Fill 1.50" Bailer 10,731' SLM 10/18101 - H-2 II -3 I1-3 H-4 H-5 H-5 10,970' TD = 10,971' MD / 10,825' TVD PBTD =10,925' MD / 10,782' TVD MAX HOLE ANGLE = 27° @ 10,047' API: 5D-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD Updated by PW 03-20-19 Tag Fill 1.50" Bailer 10,731' SLM 10/18101 - H-2 II -3 I1-3 H-4 H-5 H-5 10,970' TD = 10,971' MD / 10,825' TVD PBTD =10,925' MD / 10,782' TVD MAX HOLE ANGLE = 27° @ 10,047' API: 5D-133-10102-01 Lease: FEDA-028997 Spud Date: 1/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD Updated by PW 03-20-19 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 DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM 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 HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 23B-03 (PTD 184-010) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset i earn Uperations Manager Date First Call Operations Engineer Date 10,000,000 1,000,000 L Y C O G 100,000 10 1 Jan -1980 HILCORP ALASKA LLC/ SOLDOTNA CK UNIT 2313-03 (184-010) SWANSON RIVER, HEMLOCK OIL Monthly Production Rates Cum. Prod Oil (bbls(: 186,127 Cum. Prod Water (bbls(: 32,500 Cum. Prod Gas (mcf(: 21,772,851 I I i i ro e_ II o ° a - o°oo _ ° 16 — - a e o 00 , Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 —.— Produced Gas (MCFM) o GOR ti Produced Water (BOPM) Produced Oil (BOPM) 10,000,000 W al 1,000,000 N O O 100,000 m O 7 T 10,000 C) 1,000 �— O d m 100 n 13 (D 3 0 3 10 s 1 Jan -2020 SPREADSHEET_Prod-I nject_Curves_W eil_V 119_1840100_SCU_23B-03_20190326.xlsx 3/26/2019 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, December 16,2014 1:42 PM To: 'Donna Ambruz' Cc: Stan Porhola Subject: RE: Sundry Cancellation - Sundry #314-433- SCU 2313-3 - PTD 184-010 Donna, Sundry 314-433 will be cancelled as requested. Guy Schwartz Senior 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.govov). From: Donna Ambruz [mailto:dambruz@hilcorp.com] Sent: Tuesday, December 16, 2014 12:16 PM To: Schwartz, Guy L (DOA) Cc: Stan Porhola Subject: Sundry Cancellation - Sundry #314-433- SCU 23B-3 - PTD 184-010 Guy, Please withdraw the above mentioned sundry (Plug for Redrill). Thank you. Donna (&nhAu z Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct 907.777.8310 - Fax dambruz@hilcorp.com 1 SCMWDEC 3 12014 • ��-O \ O THE STATE GOVERNOR SEAN PARNELL Stan Porhola SCANNED OCT 10 204, Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 23B-03 Sundry Number: 314-433 Dear Mr. Porhola: Alaska 01i and Gau 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907,279.1433 Fax: 907.276.7542 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, Cathy P oerster Chair DATED this ��day of July, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RIECEIV Et) JUL 2 2 2014 ors 7 1. Type of Request: Abandon ❑ Plug for Redril 0 . Perforate New Pod ❑ Repair Well El Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing[] Time Extension ❑ Operations Shutdowi ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 184-010 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number. Anchorage, Alaska 99503 50-133-10102-01 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 1238 Will planned perforations require a spacing exception? Yes ❑ No ❑� Soldotna Creek Unit (SCU) 2313-03 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028997 Swanson River / Hemlock Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,971 10,825 • 10,925 10,782 10,925 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 37' 22^ 37' 3T Surface 2,040' 11-3/4" 2,040' 2,040' 3,070 psi 1,050 psi Intermediate Production 10,013' T' 10,013' 9,952' 6,340 psi 3,830 psi Liner 1,146' 5" 110,970' 10,824' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" x 2-3/8" 9.2# N-80 / 9.3# J-55 / 4.7# N-80 982'/ 9,673'/ 10,553' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): FHL Packer/ SC -1 L Packer; N/A 9,673' MD / 9,642' TVD; 10,555' MD / 10,440' TVD; NIA 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory ❑ Stratigraphic❑ Development n Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 08/06/14 Oil ❑ Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑✓ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Cortact Stan Porhola Phone: 907-777-8412 Email s orhola hilcor.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: Te --s f PSP ve Spacing Exception Required? Yes ❑ No E/ Subsequent Form Required: r ' L/ �t 7 APPROVED BY by: COMMISSIONER THE COMMISSION Date:7— Z� Approved / z 7 1 s`I ^,� Submit Form and Form 10-403 (Revised 1� Af`�t a�p fppr 12 months from the date of approval. Attachments in Duplicate R$CMS JUL 3 0 2014 '>',7 �3 if` Hilcorp Alaska, LLC July 22, 2014 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 RECEIVED JUL 2 2 2014 !"`1OGCC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907/777-8412 Fax: 907/777-8301 Re: Swanson River Field SCU 2313-03 (PTD 184-010) Variance Request for Plug Setting Depth during Plugback Operations Dear Commissioner: i" This letter is to make a request for a variance to the requirements of 20 AAC 25.112(c)(1)(D) that requires a cement retainer to be set within 500' of perforations during abandonment. This request is to allow the setting of a plug (retainer at 9,650' MD) within 1,100' of the top of the perforations (top of perforation at 10,750' MD). We will set a cement retainer above the upper packer (FHL packer at 9,673') and squeeze down the 2-3/8" completion and the gravel pack. The volume of the 2-3/8" completion from the cement retainer at 9,650' to the top of the perfs at 10,750' is 5 bbl. The planned cement volume to be pumped will be twice this volume to be able to squeeze cement into the gravel pack. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LLC Stan Porhola Operations Engineer stp 10-403 Form Well Prognosis Actual Schematic Proposed Schematic BOPE Schematic 7-1/16" cc: Chad Helgeson Hileorp Alaska, LU Well Prognosis Well: SCU 236-03 Date:7/22/2014 Well Name: SCU 2313-03 API Number: 50-133-10102-01 Current Status: Shut -In Oil Well Leg: N/A Estimated Start Date: August 6th, 2014 Rig: Moncla #401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 184-010 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Current Bottom Hole Pressure Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary - 2,533 psi @ 10,573' TVD 2,533 psi @ 10,573' TVD 0 psi (0 psi gaslift, shut-in) (Static survey October 2001 above perfs 10,700' MD) (Static survey October 2001 above perfs 10,700' MD) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 3,994 ft. TVD. Soldotna Creek 236-03 was drilled as a sidetrack of SCU 23A-03 in 1984 (sidetrack of the original well SCU 23-03 drilled in 1963) to target H5 oil reserves in the middle part of the Hemlock formation. In 1989, a rig workover was conducted to run a gravel pack across the H3, H4, and H5. The H2, H3, and H5 were perforated through tubing in 1998. The well has been shut-in since 1998. The purpose of this work/sundry is to plugback the well to prepare it for a sidetrack using Saxon #169. The Saxon #169 will use the 7" bridge plug at +/- 7,100' to set the whipstock. 60*1C4//' rine L -e,4 rrg d/cd ;0Ql��v w4� Notes Regarding Wellbore Condition Wq# %a J/ pr0'ri✓�rQyv, rf fv�'r� q �D �t,e1r QvrJ ( 00 1��8 Pig 7*,.� IIJl Al, I -A,' ( • Last tag at 10,731' SLM on 10/18/01 w/ a 1.50" pumpbailer. a /�ow / ro vvp/ 1-e P,z WO Rig Procedure: Fro .11 Ile PC V. 1. MIRU Moncla #401 WO Rig. 2. Set BPV. ND Tree. 3. NU 7-1/16" BOPE. Set BPV. Test to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 1,500 psi High (hold each valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Notify BLM 48 hrs in advance of BOP test. 4. Bleed any pressure off tubing. Pull BPV. 5. Kill well w/ 8.4 ppg lease water. 6. Back out tbg hanger hold down pins. 7. MU 3-1/2" landing joint and pull tubing hanger free. 8. SOOH and rack back the 3-1/2" tubing. a. Send the 3-1/2" tubing hanger to CIFO for cleaning and redress. b. Tubing is 3-1/2" IBT-MOD (100% Tensile= 207k). Hileorp Alaska, I , Well Prognosis Well: SCU 2313-03 Date: 7/22/2014 c. Junk the pulled 3-1/2" IBT-MOD tubing (store at Swanson River). d. Note joint at 5,000' with punch hole. e. Junk the 3-1/2" GLM, XN profile, and seal assembly. 9. PU 7" 29.0# casing scraper and 6" bit. a. Drift diameter of casing is 6.184". 10. RIH w/ casing scraper w/ 3-1/2" IBT-MOD tubing to 9,660' to tag FHL packer PBR. 11. POOH. Lay down casing scraper, bit, and rack back the 3-1/2" tubing. 12. PU 7" Cement Retainer w/ mechanical setting tool. 13. RIH w/ 7" Cement Retainer and set at 9,650'. a. Correlate using pipe measurements (+/- 25'). 14. Tag w/ 10k DWT to confirm set. 15. Fill well w/ 8.4 ppg lease water. 16. Test casing to 2,500 psi for 30 min and chart. 17. Stab into retainer and establish circulation below the retainer. 18. Mix and pump 11 bbl of 15.8 ppg cement. a. Pump 10 bbl below the retainer. b. Leave 1 bbl on top of retainer. 19. Unsting out of retainer. 20. Circulate well clean w/ 8.4 ppg lease water. 21. POOH. Lay down the 3-1/2" tubing and lay down the stab -in adapter. 22. RU E -line. a. MU flange to 7-1/16" 5M BOPE. 23. PU 7" Bridge Plug w/ E -line setting tool. 24. RIH w/ 7" Bridge Plug and set at 7,100' (3'-5' above a collar). a. Correlate using CCL. 25. POOH. RD E -line. 26. Set BPV. ND 7-1/16" BOPE. NU dry hole tree. Pull BPV. 27. RD Moncla #401 WO Rig. 28. Turn well over to production. 29. Replace IA x OA pressure gauge if removed (7" x 11-3/4"). Drilline Rie Procedure: 30. MIRU Saxon #169 Drilling Rig. 31. Mix mud for 6" hole section. 32. Set test plug in wellhead. 33. NU 11" BOPE. Set BPV. Test to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Notify BLM 48 hrs in advance of BOP test. 34. PU window milling assembly on 4" DP. 35. RIH to CIBP at 7,100'. 36. Circulate well clean w/ 8.4 ppg lease water. 37. Test casing to 2,500 psi for 30 min and chart. 38. SOOH and rack back milling assembly. 39. PU mills and UBHO sub on a joint of HWDP. 40. PU whipstock and attach mills and milling assembly. • Well Prognosis Well: SCU 238-03 Hilcorp Alaska, LL Date: 7/22/2014 41. Orient whipstock above CIBP. 42. Tag up on CIBP. Set whipstock anchor. Shear off window mill from the whipstock. 43. PU 5-10' above the whipstock. 44. Circulate well over to 9.5 ppg 6% KCI/PHPA drilling mud. 45. ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic lHilcaILCorp Alas RKB: 145'/ GL: 128' AMSL KB - THF: 17.0' 22" ftd, 37' J 21 M L 11-3/4" Top Hole 2,040' Cmt To 22" Conductor CBI. TOC 5.250" Punch Surf unknown 2.992" Hole Sud. 11-%4" Sud Csg 5,000' ,l! 0 Sud 2,040' 16" �C Sud. 7" Prod Csg 29 23 26 29 N-80 6.184" 6.366" 6.276" 6.184" Sud 157' 4,630' 6 473' 157' 4,630' 6,473' 6,805' 4 1,200 sx Unknown CBL TOC S 7" 7" unknown 1,000 sx Unknown 7" 291 6.184" 6,807' 1 8,273' 7" 29 P-110 1 6.184" 8,273' 10,013' 5" Liner 18 N-80 1 4.276" 9,824' 10,970' 1 6" 225 sx SCU 2313-03 Actual Schematic C as in a & T u b in g Size Ty e Wt Grade ID Top Btm Hole Cmt Cmt To 22" Conductor - 5.250" - Surf 37' 2.992" unknown Sud. 11-%4" Sud Csg 47 J-55 11.250" Sud 2,040' 16" 1800 sx Sud. 7" Prod Csg 29 23 26 29 N-80 6.184" 6.366" 6.276" 6.184" Sud 157' 4,630' 6 473' 157' 4,630' 6,473' 6,805' 9-%" 1,200 sx Unknown 7" 7" 7" 7" DV Collar 1 6,805' 1 6,807' 1,000 sx Unknown 7" 291 6.184" 6,807' 1 8,273' 7" 29 P-110 1 6.184" 8,273' 10,013' 5" Liner 18 N-80 1 4.276" 9,824' 10,970' 1 6" 225 sx 10,308' Tubing 10,880' 3.937" Model N-1 Bridge Plug 6 27 60 1-11/16- CPlg OD 3 % IBT-MOD 9.2 N-80 2.992" 0' 982' 25 60/90 4.250" 3 %" EUE 8RD-MOD 9.3 J-55 2.992" 982' 9,673' 4.500" 2 % ", EUE 8RD MOD 4.7 N-80 1.995" 9,673' 10,553' 3.063" 7 In TOL 9,824' Leaking Liner Top i44 7" 10,013' CBL TOC 10,308' 8 E_ 9 10 11 I 11TITM IIWA11:111fe1II No. Depth ID CID Item 1 17' 2.992" - Shaffer Tubing Hanger, 3-1/2" IBT-Mod Lift Threads 2 1,993' 2.992" 5.250" 3-1/2" Carrico KBUG Mandrel 8RD GLV #2 3 9,571' 2.992" 5.250" 3-1/2" Camco MMG-2 Mandrel 8RD GLV #1 4 9,627' 2.750" 3.500" XN-Nipple 5 9,660' 4.000" 5.750" PBR 6 9,673' 3.000" 5.968" Baker 7"x 3-1/2" FHL Packer (75k shear) 7 9,680' 2.992" 5.250" XO, 3-1/2" x 2-3/8" 8 10,521' 1.875" 2.375" X -Nipple 9 10,553' 1.995" 2.675" Baker Locator Seal Assembly, 20' of seals 10 10,555' 2.686" 4.140" Baker SC -11- Gravelpack Packer 11 10,578' 1.995" 2.875" Johnson & Baker welded screen w/ centralizers (5 blankjts/6 welded screen jts) 12 10,925' 10,880' 3.937" Model N-1 Bridge Plug Tag Fill 1.50" Bailer 10,731' SLM 10/18/01 - H-2 - H-3 = H-3 - H-4 = H-5 - H-5 12 'T 5„ _ 10,970' TD = 10,971' PBTD =10,940' MAX HOLE ANGLE = 270 10 047' WELL DATA PTD: 184-010 API: 50-133-10102-03 Lease: FEDA-028997 Saud Date: 1/18/2984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD SCU 2313-03 Actual Schematic 10-18-01 Undated by STP 7/21/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 2/20/98 H-2 10,750' 10,760' 10,619' 10,628' 6 10 60 1-11/16" 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' 10 10 60/90 3-3/8- 2/20/98 H-3 10,785' 10,820' 10,651' 10,684' 6 35 60 1-11/16" 5/8/89 H-4 10,820' 10,840' 10,684' 10,703' 10 20 60/90 3-3/8" 2/20/98 H-5 10,853' 10,880' 10,715' 10,740' 6 27 60 1-11/16- 5/8/89 H-5 I 10,880 1 10,905' 10,740 10,763' 14 25 60/90 3-3/8" Tag Fill 1.50" Bailer 10,731' SLM 10/18/01 - H-2 - H-3 = H-3 - H-4 = H-5 - H-5 12 'T 5„ _ 10,970' TD = 10,971' PBTD =10,940' MAX HOLE ANGLE = 270 10 047' WELL DATA PTD: 184-010 API: 50-133-10102-03 Lease: FEDA-028997 Saud Date: 1/18/2984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD SCU 2313-03 Actual Schematic 10-18-01 Undated by STP 7/21/14 lRila corp Alaska, LLC RKB: 145'/ GL: 128' AMSL KB - THF: 17.0' 22" 1 37' r r ,r 4 11-3/4":-j 2,040' CBL TOC unknown 0 1 2 CBL TOC 3 unknown 4, X4 5 TOL 9,824' I 7" 10,013'' CBL TOC ' 10,308' 4 6 7 8 c ,7P 9 a* SCU 23B-03 Proposed Schematic C a s i n a & T u b i n a Size Ty e Wt Grade ID Top 7,100' Hole Cmt Cmt To 22" Conductor - - - Surf 9,660' 4.000" unknown Surf. 11-%4" Surf Cs 47 J-55 11.250" Surf M63 16" 1800 sx Surf. 7" Prod Csg 29 23 26 29 N-80 6.184" 6.366" 6.276" 6.184" Surf 157' 4,630' 6473' 6,805 9-%,1 1,200 sx Unknown 7" 7" 7" 7" DV Collar 6,805' 1 6,807' 1,000 sx Unknown 7" 29 6.184" 6,807' 8,273' 7" 29 P-110 6.184" 8,273' 10,013' 5" Liner 18 N-80 4.276" 9,824' 10,970' 6" 1 225 sx 10,308' Tubing 10,880' 10,715' 10,740' 6 27 60 1-11/16" 5/8/89 CplCplg OD 2 % ", EUE 8RD-MOD 4.7 N-80 1.995" 1 9,673' 10,553' 60/90 3 -3/8 - 3.063" d Leaking Liner Top JEWELRY DETAIL No. Depth ID OD Item 1 7,100' Bridge Plug (Set for Whipstock) 2 9,650' - - Cement Retainer 3 9,660' 4.000" 5.750" PBR 4 9,673' 3.000" 5.968" Baker 7"x 3-1/2" FHL Packer (75k Shear) 5 9,680' 2.992" 5.250" XO, 3-1/2" x 2-3/8" 6 10,521' 1.875" 2.375" X -Nipple 7 10,553' 1.995" 2.675" Baker Locator Seal Assembly, NY of seals 8 10,555' 2.686" 4.140" Baker SC -SL Gravelpack Packer 9 10,578' 1.995" 2,875" Johnson & Baker welded screen w/ centralizers (5 blank jts/6 welded screen jts) 10 10,925' 10,840' 3.937" Model N-1 Bridge Plug Tag Fill 1.50" Bailer 10,731' SLM 10/18/01 H-2 H-3 H-3 H-4 H-5 = H-5 l0i 5 _ 10,970' M TD = 10,971' PBTD = 10,940' MAX HOLE ANGLE = 270 @ 10 047' PTD: 184-010 API: 50-133-10102-01 Lease: FEDA-028997 Spud Date: 2/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD SCU 236-03 Proposed Schematic 7-21-14 Updated by STP 7/21/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 2/20/98 H-2 10,750' 10,760' 10,619' 10,628' 6 10 60 1-11/16" 5/8/89 H-3 10,760' 10,770' 10,628' 10,637' 10 10 60/90 3-3/8- 2/20/98 H-3 10,785' 10,820' 10,651' 10,684' 6 35 60 1-11/16" 5/8/89 H-4 10,820' 10,840' 10,684' 10,703' 10 20 60/90 3-3/8" 2/20/98 H-5 10,853' 10,880' 10,715' 10,740' 6 27 60 1-11/16" 5/8/89 H-5 10,880' 10,905' 10,740' 10,763' 14 25 60/90 3 -3/8 - Tag Fill 1.50" Bailer 10,731' SLM 10/18/01 H-2 H-3 H-3 H-4 H-5 = H-5 l0i 5 _ 10,970' M TD = 10,971' PBTD = 10,940' MAX HOLE ANGLE = 270 @ 10 047' PTD: 184-010 API: 50-133-10102-01 Lease: FEDA-028997 Spud Date: 2/18/1984 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" IBT-MOD SCU 236-03 Proposed Schematic 7-21-14 Updated by STP 7/21/14 2.57' 3.68' IOM Kill Valves al and HCR Shaffer 71/165000 CAMERON O 71/165000 Swanson River 2014 Moncla Rig 401 Knight Oil Tools BOP 2 3/8-3/2 variable H Blind 2 1/16 10M Choke Valves Manual and HCR Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re -drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for tenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change tenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. ALASKA ®IL AND GAS CONSERVAT, IGN COMUSSION June 22, 2009 \--6 -G\C) ' SARAH PALIN, GOVERNOR tf ! 333 W 7th AVENUE, SUITE 100 Ct ANCHORAGE, ALASKA 99501-3539 /r PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines %AtmE'Q UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertra)alaska. Dov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No.--- Well Name UNOCAL_ Union Oil Company of California_ !Union Oil Company of California 168-024 194-149 Granite Pt St 17587 5 Granite Pt St 18742 03RD _ j Union Oil Company of California 179-033 Granite Pt St 18742 14 i Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 1_8_ Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD - Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2_ I Union Oil Company of California 182-083 Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California _ -----,Union � Oil Company of California Union Oil Company of California 179-013 188-028 168-038 Trading Bay Unit D-06RD Trading Bay Unit G-34RD - Trading Bay Unit K-06RD --- - -- --- -- Union Oil Company of California — 169-066 Trading Bay Unit K-09 Union Oil Company of California _ 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 _ �Trading Bay Unit K-23 - Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California _ 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 _— Union Oil Company of California 167-049 MGS St 17595 13 _ Union Oil Company of California 176-075 MGS St 17595 18 _ Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD _ Union Oil Company of California 193-119 MGS St 17595 28 _ Union Oil Company of California 193-118 MGS St 17595 29 _ Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 _ i Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 _ Union Oil Company of California 167-058 S MGS Unit 04 _ Union Oil Company of California 175-044 S MGS Unit 13 _ _ Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 _S_MGS Union Oil Company of California 194-098 Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 _ Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 __ -----Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 _ Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 _ Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California Union Oil Company of California 161-043 100-269 Soldotna Ck Unit 34-08 Soldotna Ck Unit 41B-09 Union Oil Company of California_ 162-031 Soldotna Ck Unit 43-09______ Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 _ Union Oil Company of California Unil on Oil Company of California _ 160-041 j 167-076 Swanson Riv Unit 234-1_5_ Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN Union Oil Company of California 173-014 Trading Bay St A-30 Dale A. Haines Manager, Oil & Gas Operations August 3, 2009 SWIAEQ 0C -I 14 2014 Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, \ --r &-C, c, \ 0 0 Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com AIRA . Oil & Gas OQns, Nimrni>=ginr6 Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, �) oa,1� Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe wivr 7 PTP R QUITTAN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Se -97 No known damage. Low oil production Phase I Abandon abandon at end of platform hfe Br 14-42 1790330 Dec -00 No known damNe Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubin -to-c ing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Sep -0 I Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform ITfe G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13 4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 12011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov-0no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek as 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Mono od A-10 1670760 A r-8Coll sed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -81 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Mono od A-30 1730140 Oct -91 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of latform life Alaska Region •--�. Unocal North Ame'""' Oil & Gas Division �J Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCALO March 31, 1994 Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 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 1 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 Alaska Uil & 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. Yours very truly, Dennis L. r ske Petroleum Engineer DLG:dma Attachment cc: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC 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 Z5-15SCU 13-4 LPO -116 SRU 212-10 6o-3SSCU 14-34 ttt)-goSCU 34-4 SRU 23-15 6()-yc{ SRU 23-27 SCU 341-8 (�Z-3o SRU 41 A-15 SRU 14A-33 lad SRU 34-283` SRU 14-22 8 b SRU 43-28 - -i SRU 23-22 BO-( 5 SRU 32-33WD ul-33SRU 212-27 4;2,- to SCU 243-8 &J-145 SRU 331-27 (D2--2- SRU 21-33W Db0--u-SRU 12-15 8 Wells 8 Wells 3 Wells *High GOR wells that may be produced intermittently RECEIVED APR —1 1994 Alaska Oil & Gas Cons. Commission Anchorage Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned 102-19 SCU 21-8* 00-144 SRU 14-15 8\-96 SCU 13-9 coo-lkk SRU 34-15 0-44 SCU 34-9* SRU 43A-15 8`I -(D SCU 2313-3 * S-R--Dto SRU 432-15 SCU 43A-4*-j2_0-jSRU 24-33 SCU 21A-4* 6 Wells 5 Wells Attachment2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Tern orarily 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: Returned to full time production after workover. • SRU 21-3: Returned to full time production due to commencement of Blowdown in field. • SRU 33-5: Returned to full time production after workover. RECEIVED APR -1 1994 waska ul, & Gas Cons. Commission Anchorage s Form 3160-5 UNITi, RTES (JUNE 1990) 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'APPLICATION FOR PERMIT—' for such proposals SUBMIT IN TRIPLICATE 1. Tvi>e of Well Oil Gas © Well [ Well ❑ Other 2. Name of Operator Union Oil Comoanv of California (dba Unocal) 3. Address and Telephone P. 0. Box 196247, Anchorage, AK 99519 4. Location of Well(Footage, Sec., T., R., M., or Swanson River Unit --- 19 wells Soldotna Creek Unit --- 11 wells 276-7600 FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. API Well No. 10. Field and Pod, 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 I TYPE OF ACTION © Notice of Intent ❑ Abandonment ❑ Change of Pians ❑ Recompletion ❑ New Construction ❑ Subsequent Report\ ❑ Plugging Back ❑ Non—Routine Fracturing ❑ Casing Repair ❑ Water Shut—Off ❑ Final Abandonment ❑ Altering Casing ❑ Conversion to Injection © Other Temporarily Abandon ❑ Dispose Water (Note: Report results of multiple conmpletion on Wed completion or Powmpletim Report and Log form. 13. Describe Proposed or completed operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting arty proposed work if vel is directionaW drilled, give subsurfaoe locations and measured and true vertical depths for all markers and zone 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 1994 to March 31, 1995: Soldotna Creek Unit Swanson River Unit SCU 2313-3 SCU 243-8 Cs s -s-1 SRU 212-10'SRU 14-22 S 1 SRU 43-28 51 SCU 13-4 SCU 341-8 S S us SRU 14-15 1-CtRU 12-15 S I SRU 14A-33 751 * SCU 21A-4 SCU 13-9 1 ' 0 f �- S 1 SRU 23-15 s) SRU 23-22<7U,pSRU 24-33 51 SCU 34-4 * SCU 34-9 ) - G 1 L-. S us P SRU 34-15 ZS 1 SRU 23-27 - -.- SRU 32-33WD S r 151 * SCU 43A-4 SCU 14-34 S %1 SRU 41A-151 GPSRU 212-27 SRU 21-33WD Vo io I -O /L* SCU 21-8 SuSg SRU 43A -155A SRU 331-27 u,�f SRU 432-15 s I SRU 34-28 *High GOR wells that may be produced intermittently. signed nGG rrhis space for Federal and _ _-- A;Vroved by Trde Date R ECE I E Conditions of approval, if any: o� 3/3I/9Y APR —1 1994 Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and wilifulty to make to arry department or agency of the United Ste d i- fraudulent statements or r tions as to matter within its jurisdiction. H �t1S. COR1I111SS10( *See Instruction on Reverse Side ag— Alaska Region Re: 4� Unocal North Americp---, Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCALO�„�_ �Xlb March 24, 1993 Qee K ,JV;s . � rc u es�fed pa��4 Y e- rf{�gy 4-150 Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 1993 Sundry Notice Request for TA Wells in Swanson-: River Lflleld, Dear Mr. Dygas: FILE 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 blowdown. 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 SCU 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. RECEIVED MAR 2 5 1993 Alaska Oil & Gas Cons. Commission' Anchorage S 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, Dennis L.'G oske Petroleum Engineer DLG:sr Attachment cc: L. C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company i j REG Eav�L) MAR 2 5 11993 Alaska oil & Gas Cons. Gommissi(W Anchorage Form 3160-5 UNITED STATES (lune 1990) 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 "APPLICATION FOR PERMIT—" for such proposals FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian, Allonee or Tribe Name SUBMIT IN TRIPLICATE 7. If Unit or CA, Agreement Designation Swanson River/ Sol dotna Creek Units I. Type of Well EOil Gas Well Well ❑ Other 8. Well Name and No. 2. Name of Operator Union Oil Company of California (dba Unocal) 9. API Well No. 3. Address and Telephone No. P. 0. Box 196247, Anchorage, Alaska 99519 907 276-7600 10. Field and Pool, or Exploratory Area Swanson River Field 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit ---------- 17 wells Soldotna Creek Unit---------- 14 well 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 INNotice of Intent ❑ Abandonment ❑ Change of Plans ❑ Recompletion ❑ New Construction ❑ Subsequent Report ❑ Plugging Back ❑ Non -Routine Fracturing ❑ Casing Repair ❑ Water Shut -Off ❑ Final Abandonment Notice ❑ Altering Casing ❑ Conversion to Injection ® Other Temporarily Abandon ❑ Dispose Water (Note: Report results of multiple completion on well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all 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: t~ 6 t6l r-. CrP Swanson River Unit Swanson River Unit SCU f 21-3 SCU � 21-8*' x-11 yr239-3* SCU 243-8-' SCU 13-4 SCU 341-8" SCU 21A-4 SCU 13-9 SCU 34-4 J - SCU 24A-9-- SCU 43A-41 SCU 34-9*p' SCU 33-51' SCU 14-34 Lam° SRU 212-10 SRU 14-15, SRU 23-15t" SRU 34-15 SRU 41A -15V SRU 43A-15 SRU 432-15 SRU 14-221' * High GOR wells that may be produced intermittently. 14. I hereby certify that SRU 23-22` SRU 23-27" SRU 212-27f SRU 331-27 SRU 34-28Y SRU 43-28 SRU 14A -33r' SRU 24-33V RECEIVED SRU 32-33WD00, MAR 5 1993 Alaska 0i1 & Gas Anhorage Signed Tide Petroleum Engineer Date ZZ -3 (This space for Federal or S o use) Approved by Conditions of approval, if any: Tide Date Tide 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any depwmwnt or agency of the United States any false, fictitious or fraudulent statements or representatiorts as so any matter within its jurisdiction. 'See Instruction on Revere Side GENERAL INSTRUCTIONS This form is designed for submitting proposals to perform certain well oper- ations, and reports of such operations when completed, as indicated, on Federal and Indian lands pursuant to applicable Federal law and regula- tions, and, if approved or accepted by any State, on all lands in such State, pursuant to applicable State law and regulations. Any necessary special in- structions concerning the use of this form and the number of copies to be submitted, particularly with regard to local area, or regional procedures and practices, either are shown below or will be issued by, or may be ob- tained from, the local Federal and/or State office. SPECIFIC INSTRUCTIONS Item 4—If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State or Federal office for specific instructions. Item 13—Proposals to abandon a well and subsequent reports of abandon- ment should include such special information as is required by local Feder- al and/or State offices. In addition, such proposals and reports should include reasons for the abandonment; data on any former or present productive zones, or other zones with present significant fluid contents not sealed off by cement or otherwise; depths (top and bottom) and method of placement of cement plugs; mud or other material placed below, between and above plugs; amount, size, method of parting of any casing, liner or tubing pulled and the depth to top of any left in the hole; method of closing top of well; and date well site conditioned for final inspection looking to approval of the abandonment. NOTICE The Privacy Act of 1974 and the regulation in 43 CFR 2.48(d) provide that you be furnished the following information in connection with information required by this application. AUTHORITY: 30 U.S.C. 181 et. seq., 351 et. seq., 2S U.S.C. et. seq.; 43 CFR 3160. PRINCIPAL PURPOSE — The information is to be used to evaluate, when appropriate, approve applications, and report completion of secondary well operations, on a Federal or Indian lease. ROUTINE USES: (1) Evaluate the equipment and procedures used during the proposed or completed subsequent well operations. (2) Request and grant approval to perform those actions covered by 43 CFR 3162.3-2(2). (3) Analyze future applications to drill or modify operations in light of data obtained and methods used. (4)(5) Information from the record and/or the record will be transferred to appropriate Federal, State, local or foreign agencies, when relevant to civil, criminal or regulatory investigations or prosecutions. EFFECT OF NOT PROVIDING INFORMATION — Filing of this notice and report and disclosure of the information is mandatory once an oil or gas well is drilled. The Paperwork Reduction Act of 1980 (44 U.S.C. 3501, et. seq.) requires us to inform you that: This information is being collected in order to evaluate proposed and/or completed subsequent well operations on Federal or Indian oil and gas leases. This information will be used to report subsequent operations once work is completed and when requested, to obtain approval for subsequent operations not previously authorized. Response to this request is mandatory for the specific types of activities specified in 4:t CFR Part 3160. BURDEN HOURS STATEMENT Public reporting burden for this form is estimated to average 25 minutes per response, including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to U.S. Department of the Interior, Bureau of Land Management, (Alternate) Bureau Clearance Officer, (WO -771), 18 and C Strects,.N.W., Washington, D.C. 20240, and the Office of Management and Budget, Paperwork Reduction Project (1004-0135), Washington, D.C. 20503. *U.S. cPo, 1990-773-016/2601! 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 Shallow Gas Potential Rate Potential P & A(') and 'Hemlock Only' P & A SCU 13-4 SRU 212-10 SCU 14-34 SCU 21A-4 SRU 23-15 SRU 23-27 SCU 34-4 SRU 41A-15 SRU 14A-33 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SRU 341-8 SRU 212-27 SRU 34-28 SRU 331-27 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 11 Wells 7 Wells 3 Wells Shut-in Wells until the Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9" ASCU 235-'s"! 5 Wells "" Does not include SRU 211-15. Scheduled full P & A in March -April, 1993 EC (2jScheduled 'Hemlock Only' P & A in March -April, 1993. is High GOR wells that may be produced intermittently. SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33121 5 Wells MAR 2 5 1993 Alaska Uil & Gas Cons. Commission Anchorage 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 due to mechanical problems. Workover candidate. • SCU 21-3: Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status • SRU 21-22: Returned to production after flowline repair. • SRU 12A-4: Returned to full time production in 1992. • SRU 211-15 Scheduled for full P & A March -April, 1993. Waiting on personnel and rig. RECEIVED MAR 2 5 1993 Alaska Oil & Gas Cons. (;omrnissw'° Anchorage f f Form aPPrQV:t 1004-Q135 t �daet Buresu No. 1985 Expires-::AupNst 31. L so st1RYiT is �ooslC�'�"f' 0. Lsaastoxastox &so saaL► UNI STATES ?E�i�R (Otter 'tri V '[�E It! s a rrotAR• acro•trRa oa rs:sa >,A]1a Form 31605 DEp,ARTMENT OND MANAGEMENT LS �Novele,,, t9331� REAU OF L tForrnerlY 9 gU 'REPORTS O to a tt ,at fteer=otr. „.xa �,,,�,pT1tES AND deeVenor plot batt =• vat? a4ssa�calr? Swanson R` DRY r �, IC H R y6R1�1T for web Or°p°+�`' Creek SUN SoldOtna t too not uM this tore, fo�P�L�XTIO 8• paste os Lsasa Irara 1. casodes 9. watt. so. OIL WRLL ca wcut, Qa wtLDCA! 4f OTRR01 ama TOOL, s. Ira�s r Inc • - — io. rtsta aro r Field CO Alas' 99 0 give 'R o: orssATOs ral. e AK Wt sal 9tat� rMuirements-• Swan as sLR. 3. ADDa� 100360 An c-10end 1n sccordaace It. ssc��as os ass► P.O-- BOtiLL (Report toestton ctearl7 carton ori it below.} s also _ _ 19 wells is. a.n At surface 1� cpoM:: as :setas son River unit _-13 Wells Alaska swan Creek Unit Kenai w .rhetbsr fl=• n• as' ete.1 sold 16. Rtj,YAt'1O„S lSho OOW Dam 14• rss� ro• asr'osg o! To IndiCats Nature of Notice, sPo sossssps o wstL opncts Box „r,tsss Check AP tea id. xo'rtCt of tr?asstotr � • watts satrt4•t .tzrsstxa cAss YO �a?raw? -� atA„pOKytf*= • TCLL Qa aL'rtR CAST- r TRACTU 3190011340oa ACID[Zt1iO 60s as wa?as asn?-osr mutrrrLa CQ?APf.ITZ r'• rSST tOtber) results at '1209 rt sC0109-14 !or'ta•? �a� ►� .r asArp4K t Non : Retmrt oru4letion BeOo "ts o! sts ."1 rte- rRACraaa 'taa _ ws �omgletton or R� lneludlni en and Igossa 511001 OIL ACVD9” CHANGS T dept” low maw La• `+and ;treat °er °1 � aert�� Abandon Vtand measured and cru RsrA1s wsLL orary state alt v* T e - toxon T1y e' . ve subw� l°"t+ (Otber? O com= `� 1?. Ugsc lat I•Ror, k- Qa Inc. reqU,ests that the no ��` w°`ti� • ARCO Alaska, o spa: Asdecried ut the a �po�y abandoned follow g wells have w n n Riv r ni 22 1 � SCU 21-8 SCU 341-8 SCU 13-9 SCU 24AA SCU 34-9 SCU 14-34 SCU 238-3 SCU 12A-4 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 212-10 SRU 21- SRU 2.3 -22 SRU 14-15 SRU 23-27 SRU 23-15 SRU 212-27 SRU 315 SRU 331-27 SRU 211-15 SRU 34-28 SRU 41A-1.5 SRU 43-28 SRU 4311-15 SRU 14A-33 SRU 432-15 24-33 SRU 14-22 SRU 32-33WD SRU RECEIVE[ DEC 3 1 1991 Alaska Oil & Gas Cans. Commi: be produced in�ittently• GOR `X' 'that ma Y :L I t Tonal Engineer D1►'� is tree and correct Actin Re mat the foreta� TITLE gIGN�D sMe1 1011Ftdatsl of state °mM TITLE {Tbt� �Pa APPRO'OLrD 8Z,PPR091L. CONDITIONg Or � e 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 SCU 12A-4 SRU 212-10 SCU 13-4 SRU 211-15 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 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 24-33 SRU 43-28 SRU 32-33WD C4 _o � C7 C n = Ca C) n w o CM CO ca C) C �O 3 CO............. 11 Wells 9 Welf r' n Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned SCU 14-34 SCU 21-8 SRU 23-27 SCU 13-9 SRU 14A-33 SCU 24A-9 SCU 34-9 SCU 23B-3 SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 3 Wells 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field DEC 3 1 1991 Wells with Temporarily Abandoned Status Change Alaska oil & Gas Cons. Commiss (Based on 1991's TA Status; our letter 12/28/90) 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 212727: 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 SRF 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 DEC 3 1 1994 Alaska Oil & Gas Gnns. 60MMissiov Anchorage ARCO Alaska, Inc. Post Off Ice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 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 COMM I COMM I ` RES ENG SR ENG SR ENG ENG ASST I ENG ASST I tSFGEOL GEOL A f GEOL ASST STAT TECH I ST—AT TECH LFLE 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: 1. rate potential, 2. permanent abandonment (P & A), and 3. shallow gas sand potential and 'Hemlock Only' abandonment. RECEIVED DEC 3 1 1991 Alaska Oil & Gas Cons. Corn isscon Anchorage Mr. J. A. Dygas Page 2 December 27,1991 Shut-in wells until field blowdown, including: 4. Hemlock producers, and 5. 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 cc; L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation RECEIVED DEC 31 1991 . n Gomm►��o Alaska Oil & Gas Anchorage STATE OF ALASKA A ALASKA VIL AND GAS CONSERVATION COrviMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL GAS ❑ SUSPENDED ! 1 ABANDONED ❑ SERVICE ❑ Classification of Service Well 2. Name of Operator ARCO Alaska, Inc. 7. Permit Number 84-10 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 8. API Number 50- 133-101 -01 4. Location of well at surface 1983' FSL, 1082' FWL, Sec. 3, T7N, R9W, SM At Top Producing Interval 2549' FSL, 1322' FWL, Sec 3, WN, R9W, SM At Total Depth 2639' FSL, 1350' FWL, Sec. 3, T7N, R9W, SM 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 236-3 1 1 . Field and Pool ield- Swanson River Field- Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 128' GL 128' 6. Lease Designation and Serial No. -028997 12. Date Spudded 01/18/84 13. Date T.D. Reached 01/24/84 14, Date Comp., Susp. or Aband. 02/09/84 15. Water Depth, if offshore N/A feet MSL 16. No. of Completions 1 17. Total Depth (MD+TVD) 10971'MD/10825'TVD 18. Plug Back Depth (MD+TVD) 10940'MD/10796'TVD 19. Directional Survey YES 19 NO ❑ 20. Depth where SSSV set None feet MD 21. Thickness of Permafrost N/A 22. Type Electric or Other Logs Run FDC/CNL/GR/DIL/GR/BHC/GR/CBL/CNL/GR/CET/CCL/GR/G ro/Vertilo 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED " --- ---Surf 37' n ► 1611 711 29,26.23 N -80n 2700 Rx ('mt " 18# N-80 9824' 10840' 6" 225 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 10760'-10770'MD 65PF w/GP, 4SPF w/GP 90°PH 10820'-10840'MD 6SPF w/GP, 4SPF w/GP 90°PH 10880'-10905'MD 6SPF w/GP, 4SPF w/GP 90°PH 10628'-10637' TVD 106841-10702' TVD 10739'-10763' TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 26• ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED *Note 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY -API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ED �,U a 7 *Note: See well history for detailed description of acid job. Commission C1 /10 �►1'�Ska .Oil .& Gas Cons. . �►nchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GQ or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other -explain. Item 28: If no cores taken, indicate "none". Form 10-407 GEOLOGIC MARKERS FORMATION TESTS � NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT.-DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS None 32. i hereby certify that the foregoing is true and correct to the best of my knowledge Signedaz-VTitleArea Drilling Engr. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GQ or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other -explain. Item 28: If no cores taken, indicate "none". Form 10-407 4 ` ARCO Oil and Gas Company Ai Daily Well History—Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report' form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish Slate Field Lease or i fN13EVKHNft! *K Well no. Auth. or W.O. Title Operator A.R.Co. I number of wells (active or inactive) on this Producing Interval Oil or gas cost center prior to plugging and Production Oil on test abandonment of this well Spudded or gun Date Hour Prior status if a W.O. Date and dep Complete record for each day reported 04i2V89 i4 ' ee as of 8:00 a.m. 05/16/89 ( 2 ) RIG RELEASED MW: 8.7 NaCl TD:10971 R/D OTIS. PRESSURE TUBING TO SET PKR. PBR SHEARED AT 2900. PB:10940 CONT PRESS TO 3000 TO SET PKR. P/U ON TUBING AND ENSURE PBR SUPV:DL RELEASED. SPACE OUT AND LAND TUBING. RILDS. TEST ANNULUS TO Gravity corrected 2000 PSI. TEST TUBING TO 2500 PSI. R/U OTIS AND PULL 'XX' Effective date PLUG FROM 2-3/8" X-NIPPLEAT 10521'. L/D LANDING JT. SET BPV. LAY OVER SUB BASE. N/D BOP AND N/U TREE. TEST TREE TO 5,000 PSI. RELEASE RIG TO 42A-5 AT 1800 5/15/89. DAILY:$50,514 CUM:$643,786 ETD:$643,786 EFC:$640,000 Old TD New TO PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual. etc.) Producing method Official reservoir name(s) votenuai test (lata Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T -P. C.P. Water % GOR Gravity corrected Allowable Effective date For form prepitraon and distribution, see Procedure anual, Section 10, Drilling, Pages 86 and 87. • AR3B-459-3-C Title JUN 0 7 19A Jaska Oil & Gas Cons. Commission Number all daily well historyq�r�pq)Gpalp eiy I Page no. as they are prepared for eac Division of AllsntleRichfieldCompany ARCO Oil and Gas CompanyNor Daily Well History—Interim 4 Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. t) Submit "Interim" sheets when filled out but not less frequently than every 50 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State Field ARCO ALASKA INC. Lease or tQIdSOK INLET/KENAI AIC well no. Date and depttSWANSON RIIJ EWplete record for each day while drilling or workover in progress SCU 23B-3 as of 8:00 a.m. ROLL'N RIG 5 05/14/89 ( 9) POOH L/D 4-3/4" DC'S MW: 8.7 NaCl TD:10971 RIH WITH RBP AND SET AT 9688. TEST TO 1000 PSI. P/U STORM PB:10940 PKR AND SET BELOW TUBING HEAD. C/O TUBING HEAD AND TEST SAME SUPV:D L TO 3000 PSI. N/U BOP AND TEST. PULL STORM PKR. RIH AND RELEASE RBP. POOH L/D DP. RIH WITH 6 DC'S POOH AND L/D SAME DAILY:$64,146 CUM:$510,393 ETD:$510,393 EFC:$610,642 05/15/89 ( 0) RD OTIS MW: 8.7 NaCl TD:10971 LD DC'S. RIH W/ 2-7/8" & 3-1/2" COMP STRING. LOCATE INTO PB:10940 I BP PKR. SPACE OUT. PRESS ANN TO 2000 PSI. OK. RU OTIS. SUPV:DL RIH & SET XX PLUG IN "X" NIPPLE AT 10,521'. DAILY:$82,879 CUM:$593,272 ETD:$593,272 EFC:$640,000 VED JWI Uj ,laska Oil & Gas Cons. UmmissiO;I Anchorage The above is correct For form preparatio nd dinributic see Procedures M nu I Section 10, Drilling, Pages 86 and 87 Number all daily well history forms consecutively Page no_ as they are prepared for each well. 4 AR36-459-2-B ARCO Oil and Gas Company Daily Well History—Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description bf all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final' form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish date ARCO ALASKA INC. COOK INLET/KENAI AK Field ppm' a �� Lease or Unit Well no. SWANSON RIVER SCU 23B-3 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 4 AR36-459-2-B ROLL' N RIG 5 ELL r REBEftSE PHR, eBU, DAILY:$74,594 CUM:$288,880 ETD:$288,880 EFC:$928,880 05/10/89 ( 5) LD 3-1/8" COLLARS MW: 8.7 NaCl TD:10971 FINISH TIH W/ BIT AND SCRAPERS, TAG FILL AT 10925', WASHED PB:10940 FROM 10925 TO 10940, CIRC HEC PILL, PULL 19 STANDS, CUT DRL SUPV:EEV LINE, TIH AND TAG PBTD AT 10940, NO FILL, TOH DAILY:$29,358 CUM:$318,238 ETD:$318,238 EFC:$928,880 05/11/89 ( 6) RIG DOWN DRESSER MW: 8.7 NaCl TD:10971 LD 3-1/8"DC'S, RU DRESSER, TEST LUBRICATOR, TIH W/ 4.031 GR AND PB:10940 JUNK BASKET TO 10936, TOH, TIH W/ BAKER MODEL N-1 BRIDGE PLUG. SUPV:EEV UNABLE TO WORK BELOW 10892, TOH, TIH W/ GR AND JUNK BASKET TO 10934, NO OBSTRUCTIONS, TOH,RECOVER FORMATION AND SAND, RERUN JB AND GR TO 10934, TOH, RD DRESSER,TIH W/ N-1 BRIDGE PLUG ON 2-3/8" TBG AND 3-1/2" DP TO 10920, RU DRESSER, TIH W/ GR TO CORRELATE DEPTHS. DAILY:$16,390 CUM:$334,628 ETD:$334,628 EFC:$945,270 05/12/89 ( 7) WO BALL TO FALL MW: 8.7 NaCl TD:10971 SPACE OUT DP. DROP BALL. SET PKR AT 2000 PSI. POOH W/ PB:10940 SETTING TOOL. RIH W/ GP ASSY ON 2-7/8" TBG AND 3-1/2" DP. SUPV:EEV TAG BRIDGE PLUG. DROP BALL. PRESS DP. BALL SHEARED AT 1800 PSI. DROP 1-7/16" BALCALITE BACK UP BALL. DAILY:$40,479 CUM:$375,1079 ETD:$375,107 EFC:$640,000 05/13/89 ( 8) RIH WITH 7" RBP MW: 8.7 NaCl TD:10971 SET GP PKR WITH 2800 PSI USING 1-7/16" BACK-UP BALL. TEST PB:10940 ANNULUS TO 1000 PSI. RELEASE FROM PKR AND REV CIRC OUT BALL. SUPV:D L R/U DOWELL AND TEST LINES TO 5,000#. PICKLE WORK STRING WITH 10 BBL XYLENE, REV OUT SAME. REPEAT WITH 10% HCL. SPOT 1OBBL 7-1/2% HCL AT PERFS. SQUEEZE INTO FORMATION WITH 15 BBL. INITIAL PRESS 1/4BPM @ 2000 - 2500 PSI. FINAL PRESSURE OF 1800 PSI AT 1 BPM. EST CIRC PRESS AT 1 AND 3 B'PM IN LOWER AND UPPER CIRCULATE POSITION. PLUS UCP WITH 50% RETURNS. PUMP 5 BBL PAD, 25 BBL SLURRY (5.1PPG 12-20 RE -SIEVE SAND), AND 5 BBL PAD. DISPLACE WITH FILTEREDS BRINE. PRESSURE INCREASED TO 750 WITH SAND SCREENOUT AT THE LATE SCREEN. P/U TO UCP AND CONTINUE TO DISPL SLURRY WITH RETURNS CHOKED BACK TO 50%. SCREEN OUT WITH 1800 PSI WITH 12 BBL BELOW CROSSOVER PORT. RE -PRESS 3 TIMES AND DISPL ADDITIONAL 1/2BBL. FINAL SCREENOUT PRESS -1800 PSI. BLEED TO 1400 PSI IN 2 MIN. REVERSEOUT 12.5 BBL SLURRY. RE -TEST PACK TO 1800 PSI AFTER GEL BREAK PERIOD. BLED TO 200 PSI IN 45 MIN. POOH LOSING 1/2BPH. L/D GP SET TOOL AND 1" WASH PIPE. P/U 7" RBP AND RIH. DAILY:$71,140 CUM:$446,247 ETD:$446,247 EFC:$610,642 The ab ve is correct Sig atur Date Title pdiiing Supt. 2 For form prepa ion and distribution see Procedur anual Section 70, Drilling, Peg 8 and 87 ppm' a �� jrs,a Oil � Cas Cnns� 'UCC raISS10't11 4i LL�t� pnc�erage Number all daily well history forms consecutively Page no. as they are prepared for each well. 4 AR36-459-2-B ARCO Oil and Gas Company Daily Well History—Interim i Instructions: This form is used during orming or worrtuvcr Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish ARCO ALASKA INC. COOK INLET/KENAI AK Field Lease or Unit Well no. SWANSON RIVER S Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. ROLL' N RIG 5 05/03/89 ( 8) TD:10971 PB:10940 SUPV:DL 05/04/89 ( 9) TD:10971 PB:10940 SUPV:DL 05/05/89 ( 10) TD:10971 PB:10940 SUPV:DL 05/06/89 ( 11) TD:10971 PB:10940 SUPV:DL 05/07/89 ( 12) TD:10971 PB:10940 SUPV:EEV 05/08/89 ( 13) TD:10971 PB:10940 SUPV:EEV 05/09/89 ( 4) TD:10971 PB:10940 SUPV:EEV The above ! correct Signature For forfn preparatiocWdistnbuuon see Procedures Mau Section 10, Drilling, Pages 86 87 E AR3B-459-2-B R/U TO RIH WITH RTTS MW: 8.7 NaCl FIN CIRC. POOH WITH MILL. RIH WITH RBP. COULD NOT GET INSIDE OF LINER. POOH AND P/U 5" RTTS. DAILY:$15,790 CUM:$141,191 ETD:$141,191 EFC:$765,310 RIH WITH MILL AND SCRAPER MW: 8.7 NaCl R•IH WITH 5" RTTS. SET AT 9890 AND TEST CASING TO 2500 PSI -BLEED OFF 100PSI IN MINUTES. RIH AND SET AT 10625. TEST CASING TO 2500 PSI. LOST 50 PSI IN 30 MINUTES. CBU POOH. RIG REPAIR -DRUM CLUTCH. POOH L/D RTTS. P/U MILL AND SCRAPERS AND RIH FOR CLEAN OUT TRIP. DAILY:$18,365 CUM:$159,555 ETD:$159,555 EFC:$624,120 FILTERING BRINE MW: 8.7 NaCl RIH W/ BIT AND SCRAPERS TO PBTD. CIRC 30 BBL XC/SAND PILL. SHORT TRIP TO TOL. CIRC SECOND PILL. REVERSE CIRC. CLEAN PITS. FILTER BRINE. DAILY:$23,091 CUM:$182,646 ETD:$182,646 EFC:$640,000 R/U TO RUN VERTILOG MW: 8.7 NaCl CIRC AND FILTER BRINE. SHORT TRIP. REVERSE CIRC W/ FILTERED FLUID. POOH. R/U TO RUN VERTILOG. DAILY:$15,340 CUM:$197,986 ETD:$197,986 EFC:$624,120 POOH WITH D.P. MW: 8.7 NaCl RUN DRESSER VERTILOG IN 7" CASING. RIG REPAIR -STARTER ON DRAWWORKS ENGINE. R/D DRESSER. P/U MULE SHOE AND RIH WITH 3-1/2" DRILL PIPE TO TOP OF LINER. R/U DRESSER AND PERF WITH 2-1/8" THRU TUBING GUNS 1SPF AND 0 DEGREE PHASING FROM 10820-25 AND 10763-768. WELL STABLE. R/D DRESSER. CBU. POOH WITH DP. DAILY:$15,340 CUM:$213,326 ETD:$213,326 EFC:$624,120 RIH W/ TCP STRING MW: 8.7 NaCl FINISH POOH WITH DP. N/U AND TEST LUBRICATOR. PERF WITH DRESSER 3-3/8" BIG HOLE CHARGES AT 4 SPF 90 DEGREE PHASING FROM 10880-905; 10820-840; 10760-770. R/D DRESSER. P/U SCHLUMBERGER TCP ASSEMBLY WITH RA TAG. RIH ON 2-3/8" TUBING AND 3-1/2" DRILL PIPE. DAILY:$16,840 CUM:$230,166 ETD:$230,166 EFC:$624,120 TIH FOR CLEANUP MW: 8.7 NaCl FINISH TIH W/ SCHLUMBERGER TBG CONVEYED GRAVEL PACK GUNS, CORRELATE W/ DRESSER GR AND CCL, SPACE OUT AND SET PKR AT 10730, PRESSURE ANNULUS AND FIRE GUNS AT 1000 PSI Date/Title nriiiing Supt. Z� (mss Number all daily well history forms consecutively Page no. as they are prepared for each well. ARCO Oil and Gas Company „ Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report"_ on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field --mow Auth, or W.O. no. State A Operator —' ARCO W.I. Spudded or Wegun Date Hour Prior st .atus i a W.O. 04106169 14-00 Date and depth Complete record for each day reported as of 8:00 a.m. T1 ATTr1T DT/! C 04/26/89 TD:10971 PB:10940 SUPV:EEV 04/27/89 TD:10971 PB:10940 SUPV:EEV 04/28/89 ( ) TD:10971 PB:10940 SUPV:DL 04/29/89 TD:10971 PB:10940 SUPV:DL 04/30/89 TD:10971 PB:10940 SUPV:DL 05/01/89 TD:10971 PB:10940 SUPV:DL 05/02/89 TD:10971 PB:10940 SUPV:DL I) ) R/U MW: 0.0 DAILY:$0 CUM:$0 ETD:$0 EFC:$640,000 RUN HYDROSTATIC BAILER ON MW: 8.7 NaCl MOVE RIG FROM 42A-5 TO 23B-3. RIG UP. PDLL BPV. PULL DV @ 9725 CIRC 8.7 BRINE. PULLED PRONG FROM PS PLUG AT 9776. ATTEMPT TO PULL PLUG. RUN HYDROSTATIC BAILER. RIG ACCEPTED AT 1400 HR 4/26/89 DAILY:$23,940 CUM:$23,940 ETD:$23,940 EFC:$640,000 RAISE SUB BASE MW: 8.7 NaCl PULL PS PLU FROM 9776. SITP 500 PSI SICP 200 PSI. CIRC WELL THROUGH CHOKE. WELL ON SLIGHT VACUUM. FLUID LOSS 8-12 BPH. RU W/L. CUT TUBING AT 9790. POH W/ CUTTER. LEFT 3- 2"x3/4"SLIPS IN THE HOLE (ON BOTTOM). PUMP 50 BBL HEC PILL. RIG REPAIR (U -JOINT BETWEEN ENGINE AND TRANSMISSION). MONITOR WELL. SET BPV. N/D TREE. N/U BOP. SET DOGHOUSE. RAISE SUB BASE. DAILY:$24,810 CUM:$48,750 ETD:$48,750 EFC:$640,000 POH L/D 2-7/8" TBG MW: 8.7 NaCl RIG UP. TEST BOP. P/U ON TBG AND SHEAR PKR AT 45K ABV WT. POOH L/D TBG. DAILY:$19,600 CUM:$68,350 ETD:$68,440 EFC:$639,910 PREPARE TO ENGAGE FISH MW: 8.7 NaCl FINISH POOH WITH TUBING AND PKR. BOTTOM GLM WAS SPLIT. C/O RAMS TO 3.5 AND TEST BOP. M/U BHA AND RIH P/U DRILL PIPE. PREP TO ENGAGE FISH. DAILY:$15,940 CUM:$84,290 ETD:$84,380 EFC:$639,910 CIRC AT TOL MW: 8.7 NaCl ENGAGE FISH AT 97901. SHEAR PKR FREE AT 45K ABV WT. CIRC. POOH FULL RECOVERY. M/U BHA AND RIH. TAG TOL AT 9824. CIRC AT TOL. DAILY:$23,380 CUM:$107,670 ETD:$107,760 EFC:$639,910 CIRC AT 10,940' MW: 8.7 NaCl CIRC WELL CLEAN AT 9824 TOL. POOH. P/U 4-1/8" MILL AND RIH. C/O FILL F/10900 TO 109401. CIRC. DAILY:$17,640 CUM:$125,310 ETD:$125,400 EFC:$639,910 The abov is correct Signs t a Date / � � Title O�inp For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Number all daily well history forms all daily well history forms consecutively�Page no. as they are prepared for each well. AR3B-459-1-D STATE OF ALASKA 6L'/ ALA...101LANDGASCONSERVATIONCOMMIS �7`N 'l REPORT OF SUNDRY WELL OPERATIOA# 16 i N A U_�6 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Pull tubing _ Other W o r k o v e r 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development Exploratory _ Stratigraphic _ R K B 1 4 8 ' feet 3. Address 7 Unit or Property name P. 0. Box 1003605, Anchorage, AK 9951 -0360 Service_ Sol dotna Creek Unit 4. Location of well at surface 8. Well number SCU 236-3 1983' FSL, 1082' FWL, Sec.3, T7N, R9W, SM 9. Permit number/approval number At top of productive interval 2549' FSL, 1322' FWL, Sec.3, T7N, R9W, SM 84-10/8-803 10. API number At effective depth 2629' FSL, 1345' FWL, Sec. 3, T7N, R9W, SM 50— 133-1012-01 11. Field/Pool At total depth 2639' FSL, 1350' FWL, Sec.3, T7N, R9W, SM Swanson River - Hemlock 12. Present well condition summary Total depth: measured 10971 ' MD feet Plugs (measured) None true vertical 10825 T V deet Effective depth: measured 10940 ' MD feet Junk (measured) None true vertical 10796 T V Beet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37' 22" --- 37' MD 37' TVD Surface 2040' 11-3/4" 1800 sx cmt 2040'MD 20401TVD Intermediate Production 100131 7" 2200 sx cmt 10 0 1 3' MD 9952' TVD Liner 11461 5" 225 sx Class G 9824' -1 0970' MD 9781 ' -1 0824' TVD Perforation depth: measured 10760'-107703P 108201-108401, 108801-10905' true vertical 106281-106371, 106841-107021, 107391-10763' Tubing (size, grade, and measured depth) 3YI/2-7/8 tubing w/tail @ 10925' XECEIVED Packers and SSSV (type and measured depth) SSSV: None, Baker 'FHL' pkr @ 96731, Baker 'SC -1 L' pkr @ 10555' 13. Stimulation or cement squeeze summary JU; Se Well Histor for detailed description of Acid job.``' Inters trea ed (measured '1 5-{a 7- 7A ccA1�.0 7-0 TKO'? PAT � 0 .Oil.& Gas (� _ _$ Cons. Comrnission Treatment description including volumes used and final pressure Anc�1orago 14. N / A Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report Well Operations of Oil Gas _ Suspended _ Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. SignedP Title Area Drilling Engineer Date s-1Zeel'e v Form 10-404 Rev 06/15/88 * Workover Well History S W01 / 2 SUBMIT IN DUPLICATE in STATE OF ALASKA ~. ALv ..A OIL AND GAS CONSERVATION COMM I, JN s APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend_ Operation shutdown _ Re-enter suspended well _ Alter casing _ Repair well _U._ Plugging _. Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate \--i- Other _ 2. Name of Operator 5. Type of Well: Developments 6. Datum elevation (DF or KB) ARCO Alaska Inc. Exploratory Stratigraphic _ _ R K B 1481 feet 3. Address 7. Unit or Property name P. 0. Box 100360, Anchorage, AK 99510 0360 Service_ Sol dotna Creek Unit 4. Location of well at surface 8. Well number SCU 2313-3 1983' FSL, 1082' FWL, Sec.3, T7N, R9W, SM 9. Permit number At top of productive interval 2549' FSL, 1322' FWL, Sec.3, T7N, R9W, SM -1 10. API number At effective depth 2629' FSL, 1345' FWL, Sec. 3, T7N, R9W, SM 50— 133-1012-01 11. Field/Pool At total depth 2639' FSL, 1350' FWL, Sec.3, T7N, R9W, SM Swanson River - Hemlock 12. Present well condition summary Total depth: measured 10971 ' MD feet Plugs (measured) 109401 PBT D true vertical 1 0 8 2 5 'TVD feet Effective depth: measured 10940 1 M D feet Junk (measured) None true vertical 1 0 7 9 6 'TVD feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37 1 2211 --- 3 7 M D 37 1 T V D Surface 2040' 11-3/4" 1800 sx 2040'MD 20401TVD Intermediate Production 10013' 7" 2200 sx 10013'MD 99521TVD Liner 1146' 5" 225 sx 10970 'MD 108241TVD Perforation depth: measured 10 8 9 2 1 -1 0904' RECEIVED true vertical 107511-107621 OCT 2 it 1983 Tubing (size, grade, and measured depth) 2-7/8" N-80 (0' -9841 ' ) ; 2-3/4" N-80 ( 9841 ' - 1 0589') '`':-,ska.Ofl & Gas Cons. C0mrni,'5iUit Packers and SSSV (type and measured depth) �►,; as'.0;1ui0 Baker FH pkr @ 9841 ' , Baker FH pkr @ 9770' 13. Attachments Description summary of proposal Detailed operations program _ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: December 7 1988 Oil . Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved I Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Title DateSigned",k DrillingEngineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness B 6 Approval No. Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required approved COPY ORIGINAL SIGNED BY Returned ff 4/ LONNIE C. SMITH Approved by order of the Commissioner Commissioner Date / 0" Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NM ♦ A SCU 238-3 GENERAL PROCEDURE The well is already killed and loaded with 9.3 ppg brine in the annulus and 9.3 ppg brine/produced water in the tubing (the top ±6000' is produced water). 1. Pull PS plug in the'S' nipple at 9776. 2. Cut the tubing at 9790' (in between packers). 3. Chase the threads in the BPV profile and set BPV. 1. MIRU Roll'n 5. Ensure well is dead. ND tree. NU BOPS and test. 2. Release 7" FHL packer. Circ BU and POH LD tbg. 3. GIH with an overshot and catch 2-7/8" tbg fish. Pull 5" packer free. Circ BU. POH and LD fish. 4. Make a 6-1/8" bit and 7" scraper run to the TOL at 9824'. 5. Make a 4-1/8" bit and 5" scraper run, cleaning out to PBD. Short trip to TOL. Circ sand sweep to clean casing. Rev circ and filter fluid until clean. 6. GIH with 5" BP. Set same @ 9900. Test csg to 2500si. If posssible, get an injection rate into liner la p p (Chevron noted that the liner lap would only leak ar 100 psi/10 minutes so a squeeze will probably not be possible). 7. If can't get an injection rate or if csg tests, GIH and reset BP @ 10700' and test csg to 2500 psi. Rel from BP, PU a storm pkr and set same 1' below tbg spool. Change out tbg spool with rebuilt spool, NU and test BOPS. 8. Retrieve storm pkr and BP. Circ BU and ensure that completion fl is still clean. POH. fl - is C E I V E D 9. RU WL. Perf the H-3,4,5 with 3-1/2" big hole guns. OCT 2- 4 10. PU TCP guns and GIH. Run tie in log. Perf the H-3.4,5 s 5 sand :; .�� underbalanced and flow well 30 minutes. :_; p Oil & dons. 11. Kill well and POH.nc;�`(;jr1 o Pg�• Rev circ and clean out t • rt and 7" scrapers le and do a ith 4-118 bit, 5 screens in the ho 12. GIH w _ ack with the Iter #tuid• ppH and �i pre P Run G? asseMbly - r r lap with a 13. Ru raVel pa ed, isolate line circulating 9 lon If need 4. P41''1 LCIDp• 3-112" Compiet 1 Run a 2-315 % LM to a pV . 15. fir. Rei rig. ottom G 7 P ck evaluation tog out GV in b Run a gravel Pa crude • Change 16 lsplace Weil to • 17 ' � ver to p roductiOn . 18. Turn R ECEIVED OCC' 2It 1988 ; . k Oil & CR4 Cors. Com_mir tf aj Anch age _ 1 � w a� s �r - s�� s � • q�M • asw�� w •w a�wa I jw�� • �ws� � �w� ■ �M� IL �.�� r • wow r�JW ■ =Do n s w 48m� 440K_ • - • �a� �r ice■ & ! -olmmL a r r -S� 1111111L- fit- - s'� ams a �a t a i R J=A- o= �� ■ � mar —� �■ alKl9w do �A �.— m=Emig=m� ANEF"- �— Top o► PLUG 0940' SEC TION 3 T. T N, R. 9 W. -�• T.D. 10970 • CHEVRON U.S.A. INC. /i 1. / 13'�l " SURFACE CAST NO 2. 7" CASI NO HEAD 13% " - 3000 PSI FLANGE Z 13W - 3000 PSI X -7W- 5000 PSI TUBING HEAD 4.'7X(; - 5000 PSI X 1 1 " - 5000 PSI CROSS-OVER SPOOL. 5000 PSI BLIND RAMS 1 M : Snnn DSI P I PF RAMS 1. 2. 3. 4. 3. 4. S. 6. 7. 8. 9. 10. 11. 12. 13. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRE33URE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUS L UNIDTS RECORD THE TIME AND PRESSURE REMAINING AFTER ARE CLOSED WITH CHAROINO PUMP OFF. E LOWER LIMIT - IS ON THE IADC REPORT. THE ACCEPT 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT All HOLD-DOWN SCREWS ARELLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT N WELLHEAD. RUN IN LOCK -DOWN SCREWS IN HELD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD OR 00 M DOWNSTREAM CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. PRESSURE TO ZERO PSI TO TEST VALVES. TESTREMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND I`1 TO ZERO PSI. WITHITH ZERO PSI DOWNSTREAM. BLEED O�TENT AND PULL OUT OF HOLE OPEN PIPE RAMS. BACKOFF RUNN 000 PSI FOR 10 MINUTES. BLEED CLOSE BLIND RAMS AND TEST TO 5 TO ZERO PSI. MAKE SURE MANIFOLD OPEN BLIND RAMS AND RECOVER TEST PLUOY AND LINES ARE FULL OF BRINE AND ALL YAL ESARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI, 5000 PSI WITH K001`1EY P,�"� TEST KELLY COCKS AND INSIDE BOP 0 PREVENTER TEST FORM RECORD TEST INFORMATION ON BLOWOUT SIGN AND SEND TO DRILLING SUPERVISOR. Form nnnmved_ Form 3160-5SUBMIT IN T1L.r...,:ATZ0 UNITED STATES Budget Bureau No. 1004-0135 Expires August 31, 1985 (November 1983) (Other Instructions on re- (Formerly 9-331) DEPARTMENT OF THE INTERIOR verse side) 5. LRASE DEGIONATION AND SERLL NO. BUREAU OF LAND MANAGEMENT SCU243-8 SUNDRY NOTICES AND REPORTS ON WELLS d' IT INDIAN, ALLoTTan OR TRIES NAME (Do not use this form for proposals to drill or to deepen or plug back to a dlQerent reservoir. SCU12A-4 Use "APPLICATION FOR PERMIT—" for such proposals.) SRU 34-10 1. T. UNIT A01909MOUT NAME WELL GAS OTHER Soldotn Creek/Swanson River Uni 2. NAME Or OPERATOR 8. PARA OR LEASE NANR ARCO Alaska, Inc. SCU323-4 3. ADDRESS Or OPERATOR 8. WELL NO. P. 0. Box 100360 Anchorage, AK 99510-M60 4. LOCATION OF WELL (Report location cleltrly and 1D accordance with any State requirements.* 10. FIELD AND POOL, OR WILDCAT See also space 17 below.) SRU 23-27� At surface Swanson River Field SCU 14-3 11. W., T., a., Wo OR EL=. A" Soldotna Creek Unit --15 EURTST OR ATEA Swanson River Unit - 22 wells SCU23B-3 14. PERMIT NO. 16. ELEVATIONS (Show whether Dr, RT, at, eta) 12. COONT! OR PARISH 13. ETATE SCU 34-4 I Kenai I Alaska 18. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE Or INTENTION TO: EORSSqua" REPORT Or: TEST WATER SHUT -Orr PCLL OR ALTER CASING WATER SHOT-OFP RSTAIRINO WELL FRACTURE TREAT MULTIPLE CONPI.F.TE FRACTURE TUMATMZNT ALTERING CASINO SHOOT OR ACIDIZE ABANDON* SHOOTINO OR ACIDIEINa ABANDONMENT* REPAIR WELL CHANGE PLA*1S (Other) ( Other)( NOTE : Report results of multiple completion on Well Tpmnnraril v ahandnn Completion or Recompletion Report and Log form.) 1T. DESCRIDF, PROPOSED OR COMPLETED OPERATIONS (ClearlySand all pertinent detlls, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations measured and true vertical depths for all markers and sones pert! nent 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-10 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 R�r SCU341-8 SCU 34-4 SRU41A-15 SRU14A-33 SCU21A-4 SRU43A-15 SRU 24-336 r A� SRU 312-Z 2 SRU 12-34 g, GOm��ss10� SRU 21-22 SRU 21-34 &GaC�ota�e P�aS�' Ar 18. 1 hereby cert at the foregoingrue and correct SIGNEI}-�C��, L�fi�-- /---'' TITLE Reg -tonal Engineer DATE (This space for Federal or State office ase) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE 'See Instructions on Reveres Side DATE Title 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 t TABLE 1 Wells under Wells being Evaluation for Evaluated for Rate Potential P&A/Future Utility 41A-15 212-10 21-15 23-22 31-15 23-27 34-15 34-28 432-15 21-34 312-22 323-4 - 212-27 13-9 14A-33 341-8 12-34 24-5 22-23WD 13-3 243-8 13-4 14-34 23B-3 14-3 33-5 34-4 o y � Grim ro o C 0 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until Blowdown 43A-15 314-27 331-27 343-33 1, ARCO Alaska, Inc. Post Office Box 100360 Comm Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering August 19, 1987 -, G C, r Joseph A. Dygas , Branch Chief E N� ' S l A'r-I.EC United States Bureau of Land Management STA T�ECFI Post Office Box 230071 FILE-- I Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wel Is 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 days. The 39 wells listed i n 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 - ineffic-ient 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, G H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB:JWR:ch:0006 Attachment i� Y cc: C. V. Chatterton, Chairman Alaska Oil &Gas Conservation Commission2►�`p��& Pr�holags TRANSMITTAL AND AcnowLmmw OF RECEIPT OF MATERIALS EXP -140 Date I I n Ger. LE c `N Under separate cover, ve are forwarding the following material, via °a� a 19'f -P8 45 ,g� "N 10f o7a 7,! -o 0 ,e 0 a 7 7 6rPen If material is not received within five days, please advise immediately. By Received and checked by: Date: Remarks: RECEIVED r IOV 211994 Alaska Oil & Gas Cons. Commission Anchorage EXP -140 (22M -CD -8-61) Printed in U.S.A. 11Bill Sheffield, Governor Q_)) J 3001 PORCUPINE DRIVE ALASKA OIL ANCHORA►GE,ALASKA 995014.3192 TELEPHONE(907) 279-1433 ARID GAS CONSERVATION COMMISSION � DATE: OTO: tOdA C t'�n' r-;iE yg_D& .... A PIC'Sr'�`��k�lsfev�seh RE: Well9�n tnel ( /"ee,k&,zj � A2 A7.3 Loc. 3 T '�/� 9 7 hl Permit No. _� D ' /40 �f We wish to bring to your attention that the Commission has not - yet received the following required items on the subject well which our records indicated was completed /A — ti / 02 Ma�f►�� Ta -pe a,i�1 zl'(S-finy Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. erely C. V. Chatter on Chairman lc: C. 024 1f�11r�J1 ALASKA OIL AND GAS CONSERVATION COMMISSION DATE: To: rUF vRON Alba W tifils-a h RE: Loc. -S Permit No. SY --/z Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 995014.3192 TELEPHONE (907) 279,-1433 We wish to bring to your attention that the Commission has not" yet received the following required items on the subject well which our records indicated was completed M76tp e a h a� �. I'S tlfiJ Article 536(b) of Title 20 Chapter 25 Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled -well. Please submit the above missing material. -. erely C. V. Chatter on Chairman lc: C.024 i ----,CHEVRON- U.S.A. INC. TRANSMITT. ..41) ACKNOWLEDGEMENT OF RECEIP. MATERTAL - (ALASKA) ''TO: M R . Ad ALEA DATE A L! Cr 2-1, 1 q'6y DEPT.: A aG"cc . FD - Folded R - Rolled PLACE: S - Sepia F - Film X — Xerox' B - Blueline THE FOLLOWING IS A 'LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. sc)L.o o-rdA cRet-::Ky o r ._ InI �t�(s 12A-3 Z3 S -3 `I o u P- kEw nF Aug -.15 ,19 8q F�D R gEcsTe-Lm 5u iZ E t LAVs) nIasi-'a oil & Gas Cons. Commission BY KIIP. BLALK1 10TJ RECEIVED 8Ynrhnrgne CIMRON U.S.A. INC. BOX 7-839 ALASKA OIL AND GAS CONSERVATION COMMISSION DA i /1P VLQ h-, / L T► Hq- - . / i 1& A. . C/IPI i . C. "a #t - / •. i,(11,-CpkJ. Permit L • Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501=-3192 TELEPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our. records indicated was completed- 9 M(q�H��« �aP� a�� L ��fi/17 Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, 6 C. V. Chat Chairman ALASKA OIL AND GAS GONSERVATION GOMr11SS10N DATE: RE: / 1 til /. PO jeg< lk/ • / / Sec.j/ Permit No. i / Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501=3192 TELEPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject w 11 which our records indicated was completed Q� �'— g' keysferedfuy've/ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, 6 C. V. Chatt r on Chairman �- `� *Also Well .SCU 2-3 t vim-.- _ '- - - .i!, t�, _/ j �,_ - ; _ .r is S r-� t _= A 1�! :•.,a, -.,r ..i 'i -'• r R, i :r�}'..I s • a E ti�•• `j r r i - c t -.� .1. �p �f� Y 1}j t '` 5, i T � _ t . 1 � - s{ �t .i" .. ,'. j a - _ • aJ..i +. � .1 . .7 _ _ _';.'.: - �. _ r- i -{ s - , * WELL SURVEY. Pro -312 w i{ -t( r 11 1 rw.}. '_.a ,� � f` , -;3 i- ,�[ •'ti �• i ; � - i .: � � }�.t x^e;y.ti WELL NO. .SC�f Z-7"� `COUNTY ��.�.ti' - CITY OF OF -- .. =- SECTION NO. 3TONNSH I P - 7RANGE N v ,_ .; MS. B.O..& m. O M. 0. B. & M. TRACT N0. ' _ . _ LOT N0,, F1 ELD O PROPOSED 19 .� � /Y D • i /Q /e •.., ajey f' ,�«. �o h Li •, e- B'r,� . Se w -t� � !�M ' 3. :{� O PRELIMINARY LOCATION ��rhtV•. sic. iLe�ti .�T %�/,_ q t•M�/� O �L i - FINAL ,t r tet` � � ',,G .7 • � ; dT � �j��''" � ■pt 's' �i ..X 4 �!r--C- ]i �r i t, ` - r 1/��Qi•[��K�d'..^t �'{) t-•,' {�-�'�i� -�� r /.�L __tR.... �-I. N '7 � __ ) a r "� 5ri • t ._� I -. � 11 r' d Fi7',1.. t .f l a 4a p £° ELEVATlOA: GROUND- / Z 7. 9 CONCRETE MAT,_ `r DERRICK( FLOOR X_ . ..i...� ter.- i �. :} i .'� A L T E R N ATE 0R SU RVEYED L 0 C A T 1 0M f '.,� ..i' - � i:_I�,z •� �"- � rte. - LOCATION DE314NAT5ON LOCATION COORDINATES MOVE 11E11ARK3 a : Al 2Z O Ct9.47 E2 O c 060• 17 7 _ y�-.S:...�Y.. i �21;"_ 'a.,.�ri+-... .-.!__-:_.r •--�-•Ft'-'-ter..-. . �..s._. {�..,.r _..• .wT. 47 - - - li �- `� :SKETCH •OR REMARKS i :.ti •:' 1 t -�... i ,fi t vim-.- _ '- - - .i!, t�, _/ j �,_ - ; _ .r is S r-� t _= A 1�! :•.,a, -.,r ..i 'i -'• r R, i :r�}'..I s • a E ti�•• `j r r i - c t -.� .1. �p �f� Y 1}j t '` 5, i T � _ t . 1 � - s{ �t .i" .. ,'. j a - _ • aJ..i +. � .1 . .7 _ _ _';.'.: - �. _ r- i -{ s - , y( •_ _ 4j t Y Sy- } t t_ +1 •F ,,-. • Y .' -r^ f -- �..v•. - - _ _ u" {__ • _ w i{ -t( r 11 1 rw.}. '_.a ,� � f` , -;3 i- ,�[ •'ti �• i ; � - i .: � � }�.t x^e;y.ti l• -'4 1 J �1' �� ..:...) � T _.-.- � . " . '.l -� -r - A. - a -� i - �, t ,- 1 - ...j r � .•,�• -t-i -� *#-� +`>� -�I r'i� •i -+ 4-� ir` S1 •4 T Ji� .- - •�%._•ti_.. ." ;i_ _•_�` +.i'�/rl:.,�.ivx r_ . r Y`i ! -1-1 -"`i �T` /"i -i... � -ppm �.._+... /....�ya.+.wr.iti•�-...,r. = `� . -= � -( Uri.• + i} fl n . �• I -�� 1 - J '- _�I �' t � r Jj� if f •r r� - - ' J 'a4 -t� � !�M ' 3. �I -rte. f f f• n+t�� ,t r tet` � � ',,G .7 • � ; dT � �j��''" � ■pt 's' �i ..X 4 �!r--C- ]i �r i t, ` - r 1/��Qi•[��K�d'..^t �'{) t-•,' {�-�'�i� -�� r /.�L __tR.... �-I. N '7 � __ ) a r "� 5ri • t ._� I -. � 11 r' d Fi7',1.. t .f l a 4a p . ..i...� ter.- i �. :} i .'� � - .;i.- � .- f '.,� ..i' - � i:_I�,z •� �"- � rte. s�_�`y /►�. 300TH - - _ _ - 'i_'� a':: -s- - •_ ��Y _ •-.t i. yam._ }. - - r< ;r. .. '1 _ _ _'�'�i.:_ _ •-_ y ` ,.�` .I; !"„ _:"`';�� _'-{i.. i •CH MA _ �' _�- - �< _ 3 ' __ -', . - _ _ .- .._Z'.. ',it•• •` � .. t'Cr; '. i I S : %� D,L h!�4i s. 4.,C Gl./ r%�,/ls�_ • E-�r BEN _ - STATION -BEARING - :.I DISTANCE SIKE ' C031IIE NORTH SOIJTii EAST - WEST 7-- I Tom- ,�• i 7, :r; I aAx r -Y l -Y J "S -3146 J , • i r... t s !� -- 7' �� r> k ti �-. - • y - "+-' - �-'1 '.r - - , �: _ FJLE E�DR_ �i! �ce;Cf�+e MAINT:� fR�t. SURY e• f°± •F- r MAINT.,r3dJPT .:,� -. t� DATE• ICL.'� 3' , -'' =�-'DATE • ,- - ._ � � � ^_.._i_�_y ; J,. ��•'r.: •9 . • S i ' i i i • �i�i� ��ilr DATE } r- j •: c3 - _ _ _ 1 j- c > ''/ •-� ft- L --*"t 6i #� •a 1 �{ ts.a .s-.; - ...,..r y.... �.. •. �/y Y. 40 -t_..1'c'� IM.... .�- •`I r-r� t _ �� .Y.:IT tit_ Tr t _- ,•f •ia1 `t'�� + i ' " T. �.-i C`r-` .i• •* 4 PRO:312. 500- •�•E ._i.'. -- r»�$•i�.►i Ap r...+ 3�,�...p�... •w�►'S.y'..a.'`i+. .ji -' Rrs S+:--i...,L. Yj-_.-.s .?F,..� i. +"Y -+, `rN� * ?'f..s y{.1�,.i; -..j, -�ta'y..•C. �.•.�-7.�. !. hr,�2 TA/�bV;1'�.�� Y' i' - �!. s-�s -.•r<r ..+.i..a.ri+. 1..sz1r`_ _iL.Si�i•j.�w-.•I�a-afa +F� i:� _t��+,-'�:i, µ i�,a�W�L'[:'�'�i��'��,1� L' -. ` _ - W _ _� J,►�fiA_.>�_Zs i:.Y1F �~:!f7•�•w.�iw.•w. s'-� ,.�� .. ,. .. Chevron CFIE /4, ON U.S.A., IL" TRANSMITTAL .,,AD ACKNOWTEDGEMENT OF RECEIPT k.. MATERIAL - (ALASKA) TO: MI�. W M. V41 A L EIJ DATE_M/t� 9.I, JqZ4 DEPT.: A, D. C�r, c. C. PJACE: 3co 1 c)zwP 10 e- 'DR.. A IAC SHE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. Co. F - Film X - Xerox B - Bluelin - Folde R - Ro led - Se is PLEASE CHECK AND ADVISE IMMEDIATELY. RUNS F • FILM S*SEPIA ,� 1 2 3 4 5•6 T' WELL LOGS Lgavrzo ti, (J-5. A. WELD 9 -CU. 235-3= SEC 3 T -7N ,R. 9\N/ ��A.SEPIA I EA . 13 L -Q E LI t� OF I IA b I CAT7F D 1NEL L LCA CrS LOCATION PLAT PERMIT TO -DRILL 10-401 SUNDRY NOTICE 10-403 MONTHLY NOTICE P.4 CORE DATA " _SIDE WALL ---,SARABAND LISTING SOT. HOLE PRESS _APPUN DPN. or ASAND. SDRC. SUR. GYRO MULTt;e!. _DRC. SUR. GYRO 31"LE _CONDUCTOR INSTAULA _CLUSTER LISTING PROPOSED PROGR AM —..—. -COMPLETION REPORT ttAg Alaska OfficeI Fj)( E D , B Y ons. Anchorage commission REMARKS ON 2w !M UAL .IMoucrlon S FL UAL INDUCTION WITH LINEAR __OPAL 114OUCT1014 FOCUSED LOG _,)HAL INDLcTiOM LATEROLOG ...._,.•,,,,•�- --DUAL DETECTOR NEUTRON _ C.eT %�rC-Otis-CIC. (�}1.�' • _.BOREHOLE COMPENSATED SONIC • • -j.80REHOLE COM*. SONIC W/CALIPER ,,,•• •, _J�OOREHOLE COMP SONIC W GAMMA:,,• - •� 'CONTINUOUS DIPMETER HIGH RES.,,,,-•�- cM�j�j'. I'CEMENT BOND L00 '-CASING COLLAR PERFORATING RECORD- -- COLLAR LOG...... ... _ ..••-- �•LOLLAR OG FOR GYRO CORK. CCL TIE IN Foc GYRO _ •• I. OMPEIISATEO DENsI/NEUTRON/GR..-. -CQMPE N=ATED DEN:ILOG :COMPENSATED FORMATION DENSITY ... ...�� COMPENSATUD NEUTRON FORMATION DEM. �- -'COMPUTER PROCESSED Loa f•CY9EROIP I.' _ .'CotitPVT[R PROCEssED LOO ICYOERLOOK)I �. "dST"DT - .. IFLU Io Dt14SITY Loc _._ ____. ...... 'FLOMETER l FORMATION TESTER • • - 'FORMATION ANALYSIs Loa.. ,• • -•,.. • _- iGAMMA RAT ,rjAMMA RAY NEUTRON i7pAMMA RAY COLLAR LOO I"DUCTION ELECTRICAL LOG . .......�� !LATEROLOG iMICRO Lo• ..........................---, — MICROLATEROLOO i MuD Loa NUCLEAR •FLOLOO , • - •-, • •- •-_ NEUTRON p �ISi•T.�-.:�A RRTA..- i P"0Roa1T� Loc_ PROFILE CALIPER..:_ .... ........... ---. -- PRODUCTION LOG i PROXIMITY MICROLOG RWA CONPARISON PLOT- -- .. . . .. •��_•_ ISARASANO..-- ISONAN LOG .-... _.b ... _ _— I SOIIIC - - - ISANDSTOMc ANALYSIS ' P I_- •- •-• --,ice ISIOEWALL NEUTRON POROSITY SPINNER .._- . LISPECTRALOa�- 1 TEMPERATURE 'TVD o1L etas FOL CNFO wlc •. LS Loos i -. • _ . r r - _ _ • . • ;CAPD A(>Lrz, CASTD VOLE DIL 8HSfo cNFO ' C:F}s�� t4cL L- N caa2,o N Kunz i Z -- 13Y C U.S., OTHER SIDE, THIS SNEFT BOX 7-839 ANCHORAGE, ALASK, WZMECH Iwo MECI•1 1 210. 100 1 1 160.200 �. INC. )(73(o k 99510 _ Page / of DAILY PROGRESS OF WELL WORK For all W.L. work, perf. jobs, solvent jobs or other subsurface work other than drilling. Well no. SCV Z33-3 Field: SwANJSo-Q Rj*r�. Date: 114Y / , d6Z4 Object: 2EPC- ZF A-4 T E L(W&Z 415 /JV7�ZZ O: /J�59 Z - I090 All contractors present during work ZCNLvTVl3k 6'&c Work detail breakdown: SNIT /"NJ wE&L_ /,VE ; LJ :�"G UJ lu/-Fn/ rvu- Lv1&21(IF,01-� 7F _s7 C v3/Z; cam,, x `ice loon ?si G iA4-V SHUT 1n1 W&I-L 146)' J4ZC-0 I/ Z ( 13,500 /251 Qf- LIJ�CL /c Ic�V;V /N �IO(.� 3C�rJ l c.E'LL / 1 /CUO al n 4 �.i ;�,;;,u .,� N �� f� /J c4 O )*ILL /Jt- 10920 CZ01 car r'��> �c�/z-e 6, ,�� +�FT- 60t1.a2.f !_J /' y J (_ 0 �el_ll w,; N -e-11 TN1'i= u7 ��a /�4jl v� -e 01D ovGT pU % C,= jdOLC /�iyD LSI/D �G^�yni Gy,ys �� Gyi G �%9 C "✓�42(�f n/A,) 5467- -9 Z9 /2lGGE�% �o�:V SL:tiL ✓rl-�C'e�'t��z , 1944 a Or'l . ��C-fLFo2�,�►� Jc�',o: S��C-t r .07T/�e ;.� �`': ; `.', �.. •;. Contractor signature and Company (if detail prepared by Contractors) Results by Company Representative 12 C-2 �-�i A) 52/16C�Sr �t c L- Cod? 4t 62 Z59 ebi2l.) S /3&U 1-20 141. 9,9,7 cc: Production Foreman Area Engineer Well File - Original Company Repres6.0fitive Signature and Date �'i�TE OF ALK}SK/-{ LASKA Ol L � CCAs ^� CpNSER\j AnDti COMM tsslo� A-r-T'tJ *" MR. WM. VAO ALEO CCOMPANY WEII I ch"0"--4-Nevron U.S.A. Inc. j. Box 7-839, Anchorage, AK 99510 TRANSMITTED ;%qvX4 VA "10 mmomilmt 0"M a �M'd f ON W'k - - - - - - 1 F Owl OlLm- PLEASE SIGN AND RETURN: DATE: RECEIVED BY Date 19 —— TRANS. 8Y �R,o�v�-no � �lC� �� • 1 -- -- Bill Sheffield Governor ALASKA OIL AND GAS CONSERVATION COMMISSI06l D• lqgzz /jMICH ra ._ / / V/ / . 9JVe4- //L A RE: Well 07 _ Loc . �� `_ 7" / '/ Permit No. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-;-;3192 TELEPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed Lo Ma y h e fi �r- cJ TQ p� Survey plect- Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, C. V. Chat®ro Chairman We 11 Name: SCy 23t3�3 Page Z of Z Field: SuNospj lZ462 Date: kky Ij 4* PERFORATING DETAIL Odometer Zeroed On Cr- Ib.l Distance From Collar Locator To Top Shot `-I', 5 Correlations: Electric Log Depth Gamma Log Depth Correction Odometer Collars I011,90 Iv 1011b -� 10K39 AU ►c��gt� lob 1, 1 o�5y I a�SY bb69 3 1 10713 Perforating: Run # Gamma Log Depth Electric Log Collars Odometer Collars I011,90 Iv lo -536 10K39 AU 10717 bb69 10 210 Reset Odometer from ' to logyo ' and perforated IoS9Z ' to Ib=' wi th y zw P+ - W P,j Perforating: Run # E1Nllars tric Odometer Log, Collars Reset Odometer fro ' to ' and perforated ' to ' with Electric Log Depth Gamma Log Depth Correction IO L to I o LV a 102 � Reset Odometer fr m ' to ' and perforated ' to ' with Run # Ele tric Odometer Log C lars Collars Reset Odometer fr ' to ' and perforated ' to i with Run Elec is Odometer Lo Co ars Collars Reset Odometer ' to ' and perforated to ' with Run # E1 Log tric Odometer Cbkllars Collars Reset Odometer fr m ' to ' and perforated ' to ' with Run # E ectric Odometer Lo o l lays Collars Reset Odometer fm ' to ' 11 and perforated ' to ' with Note: Please use the reverse side of this form to record details of the perforating gun. Correlations Performed by Perforating Witnessed by PRO -352 (CD -6-74) Ur4nf-c+A in TT -.q -A- I �� n►C-� 1 F r -i T" ° F 00PN.� s! ki� ROPE SOCKET Z.7 FT. FROM ROPE SOCKET TO COLLAR LOCATOR COLLAR LOCATOR S FT. FROM COLLAR LOCATOR TO TOP SHOT TOP SHOT I FT. FROM TOP SHOT TO BOTTOM SHOT BOTTOM SHOT T , 7,:5 �b7TO M 61 � SjV✓��C f': � S %OTQL ?"a0L C6%.�x, 2� % STATE OF ALASKA -' O R I G ALASKA•_., AND GAS CONSERVATION CC MISSION uv WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ® GAS ❑ SUSPENDED ❑ ABANDONED ❑ SERVICE ❑ 2. Name of Operator Chevron U.S.A. Inc. 7. Permit Number 84-10 3. Address P. 0. Box 107839, Anchorage, Alaska 99510 8. API Number 50- 133-1012-01 4. Location of well at surface ,1983' N & 1082' E of the S.W. Cor., Sec. 3, T7N, R9W, S.M. At Top Producing Interval 566' N & 240' E of the surface location At Total Depth 656' N & 268' E of the surface location 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 23B-3 11. Field and Pool Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 128' G.L. 6. Lease Designation and Serial No. I A-028997 12. Date Spudded 1/18/84 (K.O.) 13. Date T.D. Reached 1/24/84 14. Date Comp., Susp. or Aband. 2/9/84 15. Water Depth, if offshore -- feet MSL 16. No. of Completions 1 17. Total Depth (MD+TVD) 10971'MD 10825' -TVP 18. Plug Back Depth (MD+TVD) 10940'MD 10796'TV 19. Directional Survey YES (k NO ❑ 20. Depth where SSSV set -- feet MD 21. Thickness of Permafrost '- 22. Type Electric or Other Logs Run FDC-CNL-GR, DIL-GR, BHC -GR, CBL-CNL-GR, CET -CCL -GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" -- -- Surface 37' -- -- 11 3/4" 47# J-55 " 2040' 16" 1800 SX. 7" 29 26 23 N-80 " 10013' 9 5/8" 2200 SX. 5" 18# N-80 9824' 10970' 6" 225 SX. 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) H-5 1058921 - 105904t M.D. 4-1--2" JHPF 1037-51';- 10,821'. TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2 3/8" 10590' ' ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production 2/10/84 Method of Operation (Flowing, gas lift, etc.) Flowin - Date of Test 2/13/84 Hours Tested 5 PRODUCTION FOR TEST PERIOD OIL -BBL 34 GAS -MCF 490 WATER -BBL 1 CHOKE SIZE GAS -OIL RATIO 14 512 Flow Tubing Press_ -650 Casing Pressure 0 CALCULATED 24-HOUR RATE ♦ OIL -BBL 162 GAS -MCF 2351. WATER -BBL 4 OIL GRAVITY -API (cord 40 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A o V Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 4 JAMI�IAO � 29. 30.- 0.GEOLOGIC GEOLOGICMARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A H-1 10714' 10585' H-2 i 10741' 10610' H-3 10752' 10621' H-4 10786' 10652' H-5 10853' 10714' 31. LIST OF ATTACHMENTS 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, K6, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other -explain. Item 28: If no cores taken, indicate "none" Form 10-407 COMPLETION REPORT AREA: Swanson River Field LAND OFFICE: Anchorage PROPERTY: Soldotna Creek Unit LEASE NO: A-028997 WELL NO: SCU 23B-3 API NO: 50-133-1012-01 LOCATION AT SURFACE: 15 983' N Sc 11082' E of the S.W. Cor., Sec. 3, VN, R9W, S.M. ELEVATION: 128' G.L. DATE: 2/84 it WORK PERFORMED BY: Brinkerhoff Signal Inc., Rig #38 DATE COMMENCED WORK: 1/18/84 DATE COMPLETED WORK: 2/9/84 SUMMARY TOTAL DEPTH: 10,971' PERFORATIONS: 10,892 - 10,904' EFFECTIVE DEPTH: 10 , 940' (cmt ) CASING: 22" at 37' 11 3/4" at 2,040' 7" at 10,013' 5" liner 10,970' - 9,824' tR- E C E I V E D AFAR r Z4 984 Alaska. Oil & Gas Cons. Commission Anchorage • A;. i SCU 2313-5 1/18/84 RIH to 5,635' - broke circulation. Kicked off with Dyna Drill from 10,023' and drilled to 10,072'. 1/19/84 Drilled from 10,0721- 1091191. 1/20/84 Drilled from 10,1191- 10,312' 1/21/84 -1/22/84 Tested choke manifold, kill line, blind and pipe rams to 5,000 psi - Hydril to 2,500' psi. Drilled 10,312' to 10,6001. 1/23/84 Mk Drilled from 10,6001- 10,8391. 1/24/84 Drilled from 10,839' - 10,9711. Circulated bottoms up. Schlumberger ran DIL/GR and BHC/GR logs from 10,9591- 10,0121. 1/25/84 Ran FDC-CNL-GR log from 10,9641- 10,0121. 1/26/84 Circulated and conditioned hole at 10,9711. Ran 1,1461, 27 joints 511 18# N-80 Butt. Casing from 10,9701- 9,8241. Item Length Top @ Bottom @ 511 Baker Float Shoe 1.60 109968.4 10,970 2 its. 51118# N80 Butt Csg. 83.87 10,884.5 109968.4 511 Baker Float Collar 1.65 109882.9 109884.5 25 it. 51118# N80 Butt Csg. 19065.81 91826 109882.9 Baker 511 1811 x 711 2911 liner hanger 3.22 99824 99827 Total Run = 191461 Top @ 9,8241 Bottom @.10,9701 Note: All csg. had sp. cl. cplgs. (O.D. = 5 5/1611), and was drifted with 4 1/811 O.D. drift. �a.. 'CLg ;s APR -, 4 t 1 J27/84 Mixed and pumped 225 SX Class "G" cement with 3/4% CFR -2, .1% HR -7 and .5% Halad 9, Slurry Wt. = 15.8 ppg., Slurry Volume = 259 C.F., Yield = 1.15 C.F./SX. Displace with 5 bbl. water and 76-1 bbls. mud. Bumped plug. Had full cement returns to surface. WOC 181 hours. Washed down from 9,300' to 9,786' - did not tag firm cement. WOC. 1/28/84 WOC 7 hours. Tagged firm cement at 10,8081. Drilled out float collar and cleaned out cement 10,8831. 1/29/84 Cleaned out cement to 10,9401. Ran 4 1/811 bit and 711 casing scraper to top of 511 liner. Schlumberger ran a CBL-CNL-GR from 10,944' - 9,8001. Schlumberger doubts validity of CBL and will rerun. Ran CET -CCL -GR from 10,9441- 9,8001. 1/30.84 Re -ran CBL-CNL-GR 10,944' - 9,8001. Both CET and CBL logs showed poor cement from 9,8241 - 10,06019 CET showed poor cement 10,0601 - 10,3001, good below 10,3081 - CBL showed good bond below 10,0601. Pres*e tested 511 and 711 casing to 3,000 psi for --_ I hr. - bled down to 2,600 psi. Retested casing to 3,000 psi for I hour - bled down to 2,450 psi. Set 711 Baker retrievamatic packer at 9,8211. Tested 711 casing to 3,000 psi for 2 hour - held o.k. POOH with 711 packer. 1/31/84 Set and reset Baker retrievamatic packer at 9,8471, 9,8451, 10,0691, 10,9381 - 511 liner would not pressure test. Bled off at +100 psi/10 min. Circulated bottoms up -continued to lee off at 100 psi/10 min. Reset packer at 9,8491 and pressured up the annulus to 1,500 psi and the drill pipe to 3,000 psi - PQId for 30 min. RIH to 10,9381 -circulated hole with lease crude and observed the well for two hours. POOH. 2/1/84 - 2/2/84 Ran 2 3/811 tubing to 10,5901 as follows: Tubing Detail Length Top @ Bottom @ Shear Sub 2 3/8119 EUE, 8rd 0.80 109589.90 24 Jts., 2 3/811 EUE, 8rd, Tbg: 47 N-80 747.83 511 18# x 2 3/811 EUE, Baker FH Pkr. 1.95 5.44 91841.22 XO: 2 3/811 EUE, 8rd P x 2 3/811 EUE 8rd 0.84 2 Jts., 2 3/811 EUE, 8rd, Tbg. 62.81 Otis S nipple, 2 3/8119 EUE 8rd, Pos. 1 1.51 9 776.11 711 29# x 2 3/811 EUE 8rd, Baker FH Pkr. 2.44 6.55 99969.56 1 Jt., 2 3/811, EUE, 6.4 N-80, 8rd Tbg. 31.54 Camco MM 5/611 Mandrel w/1''11 CEU 12.70 99825.32 98 As., 2 3/8f1, 8rd tbg. 39076.46 Camco MM, 5/611 Mandrel w/1111 dummy 12.81 69636.05 7 Jts., 2 3/811, 8rd, tbg. Cameo MM, 5/611 Mandrel w/1111 dummy 217.65 12.91 ; 6.405.4��'`" AP r � - L' -W dui-Af-IIISSlon Ma�:,�,� fi'� i • i� �; d Tubing Detail Length Top Bottom @ 12 its., 2 3/811, 8rd tbg. Camco MM 5/6" Mandrel w/ 11" dummy 371.91 13.06 69020.52 16 its., 2 3/811, 8rd tbg. Camco MM 5/6" Mandrel w/11" dummy 505.92 13.04 59501.56 28 its., 2 3/8" 8rd tbg. _ Camco MM 5/6" Mandrel w/11" dummy 879.44 13.07 49609.05 38 its., 2 3/8" 8rd tbg. 19187.61 Camco MM 5/6" Mandrel w/11" dummy 13.02 39408.42 47 its., 2 3/8" 8rd tbg. 19467.76 Camco MM 5/6" Mandrel w/11" dummy 12.96 19927.90 45 its., 2 3/811, 8rd, tbg. 19411.90 Otis "S" nipple, 2 3/8" 8rd, Position 4 1.56 514.24 16 its., 2 3/8" 8rd, tbg. 496.42 Tubing hanger 0.82 DF to tbg. spool 17.00 Nippled down BOPE. Nippled up tree. 2/3/84 Released Rig #58 at 1:30 p.m. 2/9/84 Dresser Atlas perforated lower H-5 from 109892' - 10,904' with a 1 11/16" link cone gun with 4--ff"" JHPF. All shots fired. Pressure increased on well head from 0 psi to 750 psi. 3 f h 11 6611111 Ills, fi .� il! t GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB -SURFACE DIRECTIONAL SURVEY CHEVRON U S A COMPANY SCU 23 B 3 WELL NAME Kenai, Alaska LOCATION A1 -184D1 S i NGLE SHOT 1-25-84 JOB NUMBER TYPE SURVEY, � � DATE DANE CLARK art �.� �1\ F_:iU C,iui s,E TTT+� i1 -L SIGNATURE 100 10971 DEPTH INTERNA, FROM TO 1-17-84 1-25-84 DATES SURVEv` TAKEN FROM TO THIS IS A RECORD OF A SUB -SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made from the original by any blueprint company. �/f GREATLAND DlRECTIONAL 1)HlLLIN8 COMPLETION REPURl COMPUTED ON 1-25-84 1-1SIN8 RADIUS OF CURVATURE TECHNlQUE CHEVRON FRUM SURVEY DATA TAKEN SCU 23B3 FlNAL CLOSURE DIRCTION N 22.20 E SlNGLE SHUT RVEY RECURD OF SURVEY (WELL *SSUMED VEK\lCoL TO 0.0) nEAS ... ..... ..... DHIF[ ..... ..... _..... .... _____ THUVERY .... ..... ... ..... ..... ... ... ..... SUBSEA ..... ..... ... ... ..... ..... ..... _ SECTlON _________ Dl8ECTIUN ..... ... ... ..... ..... _..... .... /i:.I�LAT1 _... _ ..... ..... _..... _..... ..... _ ..... ________________ � ..... ..... ..... .... UUG Lf 6 DEPTH DG MN UEPTH _... ..... ..... DEPTH DIST ANGLE FR0`| WEU --HEAD DIS[ANCE DG MN S __ 0 0 0 __ 0.00 ________ -z48.00 ____' 0.00 _ __-_ 0.00 _ __'-_-_ �.0o _ __-_ ..... 0.00 _ ______-_ �.00 - __ 0 _- 0 0 0.00v �) 0 0 0.00 -l48.00 0.00 0.00 o.�0 o'00 0.00 0 0 0 �).000 100 V 20 100.00 -48.00 0'29 N 17.00 � 0.28 N 0.09 E 0.29 N 17 0 0 � 0.333 2�� 0 0 200.00 52.00 0.5� N z7.0� E 0.�6 N 0.17 E 0.5J N l/ o 0 � 0.33u 300 0 30 300.00 152.0� 0.68 N 54.00 W �.�� |v J. w 0.83 N 12 4o 54 W V.50U 400 0 30 399.99 2�1.r� l,06 N 30.00 W 1.�6 m 0.76 � z.�'� w 27 �7 �9 W 0.002 5�0 0 30 499.99 351.99 i.47 N 50.00 W 2.�2 N 1.32 W 2.50 N 21 54 600 0 20 599.99 451.99 l.70 N 48.00 W 2.60 N l.87 W 3.20 N 35 43 47 W 0.l67 700 0 15 699.99 551.99 1.O'/ N 48.00 W �.Y4 N 2.25 W 3.70 N 37 24 19 W 0.083 800 0 30 799.98 651.98 l.94 N 76.�0 � 3.24 N �.82 � 4.30 N 41 0 10 W 0.25o 900 0 30 89Y.98 751.98 i.96 N 57.�0 W 3.59 N 3.62 � 5.10 N 45 12 3; W 0.0Q1 1000 1 l5 999.97 851.97 1'56 S 70.00 W 3./6 � 5.08 W 6.J� N 53 31 4 W 0.750 lz00 1 0 1099.95 951.95 0.33 S 77.00 W 3.20 N �.96 W 7.6� N 65 19 1 W 0.250 l200 l 0 1l99 93 1051 93 -0 60 S 83 00 W 2 90 N ' O 68 W 9 �5 N 7i 32 42 W 0 ^^2 l300 0 50 1299.92 1151.92 -1.57 � 6�.00 W 2.47 N 10.22 W 1o.51 N 76 24 15 1400 1 0 1399.9l 1251.9l -2.75 S 63.00 W i.78 N 1l.66 W I. A. N ul 10 Ju W 0.167 1500 0 50 149Y.89 1351.O9 -3.6� N 88.00 W 1.4� N 13.20 W z3.28 N 83 46 �� W 0.z67 1�00 0 45 159�.88 1451.88 -3.73 N 54.00 W l.88 N 14.49 � :L Li N 82 35 54 � 0.084 1/00 0 45 1699.88 1551.88 -3.55 N 66.00 W 2'54 N 15.62 � 15.83 N 80 46 50 W 0.002 l800 0 45 1799.87 1651.8/ -3.35 N 52.00 W 3.21 N l6.74 W l7.05 N 79 � 7 W 0.002 1Y00 0 45 1899.86 1751.86 -3.2Y N 78.0 W 0.004 200o 0 25 l999.85 1851.O5 4 W 2�V0 0 40 2099.85 195l W 4.7/ N 19.57 W ��00 0 45 2199.84 2o�l.U4 -2.46 N 39.00 W 5.67 N 20'41 W 21'19 N 74 2y 16 W 0.0e3 �100 0 50 2299.83 2151.83 -1'64 N 24.00 W 6.85 N 2l.13 W �'|00 0 40 2399.82 225l.82 '0'92 N 44.00 W 7.93 N 2l.86 W 2J'25 N /0 4 �3 W 0.l�/ 50 24Y9.81 2351.81 N 45.00 W 8.86 ' 1-25-�4 RECOKD UF SURVEY MEAS folk IFT TRUVERT SUBSEA SECTION DIRECTION _..... ..... /<KELA7IVE CUURDINAT1iS ... .... ..... ..... .... ..... ..... ..... ..... ___.... ..... ..... ... ____ CLUSURE ..... ..... ..... ..... ... ______ _______ DOG G DEPTH DG __ MN __ DEPTH ________ DEPTH DIST ANGLE FROM WELL -HEAD DIS[ANCE DG MN S des/100 2700 0 30 2699.80 __... ..... ... ..... ... ..... 2551.80 _______ 0.�1 _ N _____ 32.00 _ W _______ 1A.64 _ ________ N 24.48 _ W ..... _____... ..... 26.69 _ N __ 6u __ 30 __ J. _ W _______ 2800 0 30 2799.80 2651.80 1.07 N 40.00 W 5 N 2zi-.Y9 � 27.45 N 65 34 35 W 0.00l 2900 0 30 2899.79 2751.79 1.41 1-.4 50.00 W 11.97 N 25.b1 W 28.27 N 64 57 20 W 0.001 3000 0 15 2999.79 2851.79 1.73 N 26.00 w z2.48 N 26.01 W 28.8� N 64 22 14 W 0. 3100 0 15 3099.7� 2951.79 2.02 N 26.00 � 12.87 N 26.20 W 29.19 N 63 50 20 W 0.�J�/ 3200 0 l5 3199.79 3051.79 �.29 N 34.00 W z3.2� N 2�.42 W 29.�5 N 63 22 6 W 0.000 3300 0 l0 3299.79 3151.79 2.49 N 33.00 W :1. N 26.62 W 29.87 N 63 1 15 W 0.083 3400 0 15 3399.79 3251.79 2.54 ^i 88,00 W z3.72 N 26.92 W 30.22 N 62 59 30 W 0.083 3500 0 15 3499.7Y 3351.7Y �.34 S 80.00 W �3.�9 N 27.36 W 30.�9 N 6� 24 43 W 0.000 3600 0 l� 3599.78 3451.78 2.07 S 67.00 W 13.57 N 27.78 W 30.9z N 63 57 48 W 0.000 3/00 0 l5 369Y.7O 1.78 1.86 N 80.00 W 13.52 N 28.�0 W 3z.28 N 64 23 14 W 0.00z 3800 0 0 3799.78 365l.78 1.82 N 80 42 04 3l.49 N 64 29 39 W 0.250 3900 0 30 3899.78 3751.78 1.38 S 20.00 W 13.15 N 28.57 W 3�.45 N 65 l7 8 W 0.500 4000 0 30 3999.78 3851.70 0.54 S 3.00 � 12.29 N 28.70 W 31.22 M 66 48 48 W 0.002 4100 0 30 4099.77 3951.77 -0.31 S 3�.00 W 1�.46 N 28.90 W 31.09 N 68 22 40 W 0.003 4200 0 0 4199.77 4051.77 -0.74 S 3l,00 W 11.08 N �9.13 W 31.l6 � �9 z0 l0 W 0.500 4300 0 40 4299.77 4�51.77 -�.13 S 70.00 W �0.88 N 29.67 W 31.6� N 69 5l 32 W 0.66> 4400 8 45 4399.76 425l.76 -1.77 N 88.00 W 10.69 N 30.89 W 32.69 N 70 �4 28 W 0.083 4500 1 15 4499.75 435z.75 -2.47 S 85.00 W z0.65 N 32.63 W 34.32 N 71 55 54 W 0.500 4600 1 45 4599.71 445z.7l -3.56 S 90.00 W l0.53 N 35.25 W 3�.7y N 73 21 �0 W 0.^ 4700 1 45 *699.67 455i 4.86 S 64 10.37 N 38.29 4800 1 4799.62 4651.62 -6.58 S 72.00 W 9.74 N 41.28 W 42.4l N 76 43 31 W 0.01l 4900 z 35 4899.58 4751 80 N /8 25 15 W 5000 1 0 4999.55 4851.5� 6 S O2.00 W 8.68 N 46.32 W 47.13 w 79 23 2 W 0'58J 5z00 1 0 5099.54 4951.54 -z0.36 S 80.00 W 8.41 N 48.05 W 48.78 N 80 4 20 W 0.001 5200 0 50 5199.52 5051.52 -11'02 N O4'00 W 8.35 N 49.64 W 50.34 N 80 26 51 W 5300 1 0 529Y.51 &15l.51 -1l.27 N 70.00 W 8.71 N 51.19 W 51.93 N 80 20 29 W 0.167 5400 1 0 5399.50 5�5!.50 -11.14 N 57.00 W 9.49 N 52.75 W 53.60 N 79 48 8 W 0.004 5500 0 50 5499.�8 535z.�8 -10.64 N 4�.00 W 10.�3 N 53.97 W Z. W 0.167 5u00 1 0 5�99.47 5451.47 -v.8� N 38.00 W1l.75 N 54.99 W 56.24 1',,! 77 56 19 W 0.167 5/00 1 l0 5699.45 OR1'45-8.93 N 3o.00 W 13.26 N 56.13 W 57'68 N 76 42 28 W 0.16) 5800 1 25 5799.43 5651.43 -7.74 N 3(,.00 WN 57.46 W �9.40 N 17 23 W 0.2b0 5v00 1 30 5899.39 5 16 N 58.93 W 6z.�8 W 73 46 9 W �0001 45 �99Y.35 5851. 35 -4.88 N 37.00 W l9.45 N 60.60 W 63'65 N 72 l2 20 W 0-250 �l00 1 35 60Y9.3l 5951.31 6 N 53.00 W 2z.50 N 62.65 W 6u.24 N 71 3 32 W 0.1�/ 6200 1 15 6199.28 6051.28 -3.23 N �8.00 � 22.90 N 64.69 W 68.62 N 70 30 20 � 0.u�x3 1-25-84 RECORD OF SURVEY ..... ..... ... __ MEAS ..... ... ..... ..... ..... ..... DRIFT ... ..... ..... _..... ..... ..... TRUVERT ________ SUBSEA ____-___ SECT1ON _________ DlRECl'l .... ..... ... ..... _-____ LAllVE ... ..... ... -___.... ... COORDlNAl£S ... .... -... ..... ..... ... _-_______ CLOSURE ..... ..... ___... ..... ..... UOG ... _... _-_ LEG DEPTH DG MN UEPTH DEPTH DIST ANGLE FROM WELL -HEAD DlSTANCE DG __ MN __ S __ dee/100 _ ..... ..... .... ____ 6300 __ 1 __ 25 ________ 6299.25 ________ 6151.25 ________ -2.96 _ N _____ 64.00 _ W _______ 2 _ ________ N 6 _ ________ _ W 0.167 6400 1 30 6399.22 6251.22 -2.79 ^{ 64.00 W 25.14 N 69.01 W /3.4� N 69 58 51 W 0.083 �500 1 30 649Y.19 6351.19 -2.64 N 6�.00 W 26.27 N 71.37 W /b.05 N 69 47 33 W 0.001 6600 z 0 6599.16 6451.16 -2.65 N 71.00 W 27.09 N 73.39 W 7�.23 N 69 44 33 � 6700 1 0 6699.�5 6551.15 -2.68 N �7.00 W 27.71 N 75.02 W /9.98 � �9 43 35 W 0.�`{� 6800 1 0 6799.l3 6651.13 -2.82 N 78.00 W 28.24 N 76.68 W 8z'7� � 69 47 8 W 0.003 6900 J. 0 6899.12 6751.l2 -3.30 N o9.00 � 28.�3 N /8.42 � o3.4} N 70 4 9 W 0.0o3 7000 0 55 6999.10 6851.10 -4.03 S 8z.00 W 28.32 w 80.08 W 84.Y4 N 70 J1 35 W 0.0�3 7100 1 0 7099.09 6951.09 -4.94 S 78.00 W 28.01 N 81.73 W 86.39 N 7� 4 �0 W 0.083 7200 l 0 7199.07 7051.07 -5.88 S 81,00 W 27.69 N 83.44 W 8/.92 N 7z 38 21 W 0.00l /300 0 W 74 W 7500 � 15 7499.03 7351.03 -9.1� S 59.00 W 26.21 N 88.36 � 92.17 w 73 28 3/ W 0.250 7600 1 0 7599.0l 7451.0l -�0.5� S 68.00 W 2�.34 N 90.l2 � 9J.61 N 74 17 46 W o.250 7�00 1 0 769O.99 7550.99 -1 35 N 9z.54 W 94./2 N 75 6 22 W 0.008 7800 1 15 77 W 0.250 7900 1 � 7898.95 7750.95 -15.72 S '+6.�0 W 21.52 m 94.3� W 96./v w 77 9 14 W 0.167 8000 1 0 7998.94 7850.94 -17.40 S 44.00 � 20.23 N 9�.�5 W 97'77 N 78 3 21 W 0.083 8l00 1 5 8098.92 7950.92 -19.z1 S 40.00 W 18.88 N 96.u7 W 98./,Y N 78 58 � W 0.083 6200 1 5 8198.90 8050.90 -20.90 S 41.00 W 17.45 N 98.09 W 99.63 N 79 54 5/ W 0.»C. 8300 0 55 8298.89 8150.89 -22.55 S 43.00 W 16.15 N 99.26 W 100'57 N 80 45 35 W 0. /Y 8400 1 0 8398.87 8250.87 -24'11 S 42.00 W 14.92 N l00.39 W z0l.49 N 81 32 5u W 0.083 8500 1 0 8498.86 8350.86 -25.78 S 3�.00 W i+9 W 102.u9 N 82 23 24 W 0.002 8600 0 45 8598.85 8450.85 -26.44 N 49.00 W l3.41 N l02.64 W iO3.71 N 82 34 23 W 0.25l 8700 2 45 8698.80 8550.80 -24.47 N 4.00 W 16.07 N 104.17 W 105.40 N 81 13 50 W 2.0o3 8800 4 45 8798.58 8650'58 -l8.14 N 2�.00 E 22.43 w l02.99 W 105.40 N 77 42 46 W 2.010 8900 6 35 8898.08 8750.0O -8.28 N 2/-00 E 31.30 N 98.66 W lo�.51 N 72 23 44 W 1.834 900� 9 45 8997.06 8849.06 5.87 N 27.�0 � 43.96 N 92.21 W 102'15 N 64 30 40 W 3'1�/ 9019 z0 0 9015.77 8867./7 9.12 N 25.00 E o6.�9 N 9068 11 30 9063'9l 8915.9l 18.15 54.75 N 86.1� W l02.V8 N 5/ J3 46 W 3.189 9i32 12 0 912�.57 8978.57 30.88 N 33.00 E 65.49 N 78.77 W 102'4+ N 50 1� 32 W 0.807 9165 12 15 9158.84 90l0'84 37.68 N 34'00 E 71.27 N 74.94 W �03'*2 N 46 26 20 W 0'770 Y20� 13 15 9194.92 9046.92 45.72 N 30'00 E 78.19 N 70'62 W 105.3� N 42 5 7 W 2'/62 9217 1.!�-.i 0 9209.47 9061.47 49.31 N 37.00 E 81 W 40 10 J3 W 12.0/8 92�4 16 30 9254.70 9106.70 61.38 N 45.00 E 90.87 N 60.24 W i0Y.02 N 33 32 27 W 3.474 �30� 17 0 9293.96 9145.96 /2.27 N 45.00 E 99.22 N 5l.88 � i�l'Y7 N 2/ 36 l5 W 1.22,) ' CU 23B3 1-25-84 RECURD UF SURVEY hEAS DF�lFT TRUVERT SUBSEA SECTION DIRECTIUN RELATlVE COORDlNATES _.... ..... .... ..... ..... ..... ... ..... ..... ..... ..... ..... ... _ CLOSURE ..... .... ..... ... ... ..... ..... __..... ..... ..... ..... _ DOG LEG DNA H DG MN DEPTH DEPTH DIST ANGLE FRUM WELL-HEAU _ Dl6lANCE ________ _ DG __ MN __ S __ des/100 _____ 9363 _- l7 __ 0 ________ 9349.43 ________ 9201.43 ________ 87.84 _ N ... ..... ... ... ..... 46.00 - E ... ..... ... ..... ..... ... ..... 111.11 _ ________ N 39.79 W 118.01 N 19 42 7 W 0.147 9426 l8 0 9409.51 9261.51 104.97 N 49.00 E 123.90 N 25.82 W l26.56 N 11 46 17 W 9479 18 0 9459.92 9311.92 119.65 N 48.00 E z34.76 N 13.55 W 135.44 N 5 44 37 W 0.180 9493 19 30 9473.18 9325.18 z23.78 N 43.00 E 137.91 N 10.35 W 138.30 N 4 17 24 W ll.^ 9�36 19 45 9513.68 9365.68 137.19 N 16 W 96lO 20 V 9590.79 9442.79 l63.48 N 38.00 E 169.16 N J. E 170.13 N 6 7 23 E 1.044 9�37 20 30 9608.62 9460.62 l69.80 N 39.00 E 174.3l N 22.24 E 175.72 N 7 16 17 E 2.7i0 9675 21 0 9644'15 9496.15 182.72 N 38.00 E z84.85 N 30.62 E i87.36 N 9 24 22 � z.359 9}7o 22 15 9732.47 9584.47 216.40 N 38.00 E 212.+3 N 52.18 E 2lO.75 N 1.316 9923 26 30 9871.80 9723,80 277.15 N 38.00 E 262.l8 N 91.04 � 277.54 N 1'� 8 58 E 2.778 9995 26 30 9936.23 9788.23 308.06 N 38.00 t: - J. .4 14 316.60 N 38.70 E 294.47 N 116.34 E 316.62 N 21 33 29 E 1.081 10047 27 0 9982.74 9834.74 330.57 N 32.50 E 306.15 N 124.70 E 330.57 N 22 9 43 E 4.504 10l46 26 45 10071.05 9923.05 374.94 N 26.50 E 345.08 N z46.73 E 374.98 N 23 2 6 E z.254 10309 26 30 10216.76 10068.76 447.O6 N 24.50 E 411.01 N 178.17 E 447.96 N 23 26 12 E 0.288 l0�59 23 30 l0443.31 10295.31 553.48 N 21.50 E 508.24 N 219.44 E 553.59 W 23 2l 12 � 1.2l� 10747 23 0 10616.04 104�8.04 627.57 N 17.00 E 578.29 N 243.Y1 E 627.62 N 22 52 7 E 0.452 10900 20 30 l0�58.l4 10610.14 684.03 N l7.00 E 632.50 N 260.48 E 684.04 N 22 22 59 � 1.634 10971 20 30 10824.64 10�76.64 708.79 N J. E 656.28 N 267.75 E 708.79 N 22 1l 41 i:�:. 0.000 � / DATA lNTERPOLA}ED FUR LVEli 100 FEET OF SU8SEA DEPTH __ MEAS. ________ TRU VERT ________ SU _____ ________ EHTlCA COORDlNAT�S DEPTH __ DEPTH .... ..... ..... ... _..... ..... D�PTH UlFF. �OHR�CT FHUM WELL -HEAD l49 .... 148 ..... ... ..... ..... ... ..... ... ..... 0 _..... _.... ..... ..... 1 _... .... ___.... ..... 1 _________ 0.48 _ N ________ 0.15 _ E 249 248 100 1 0 o.65 N 0.14 E 349 348 200 1 0 z.09 N 0.4v W 449 448 300 1 0 z.80 N 1.00 w �49 548 400 1 0 2.37 N 1.�l W 6�9 648 500 74Y 748 600 849 848 700 1 0 3.38 N 3.22 � 949 948 800 z 0 3./9 N 4.z5 W z04� 1048 900 \ 0 3.44 N A..03 W 1149 1148 1000 1 0 3.03 m 7.78 W z24� 1248 1100 i 0 2./4 N 9.47 W 1349 1348 120D l 0 2.z6 W 10.88 W 1449 1448 z549 1548 1X:! - Go 9 849 1848 1700 1 0 3.54 N z7.28 W 1949 l948 1 W 2049 2048 1900 J. 0 4.4l N 19.16 W 2149 2l48 2000 l 0 5.l8 N l9.98 � 2249 2248 2100 1 0 6.20 N 20.79 W 234Y 2348 2200 1 0 7.43 N 2449 2448 2300 1 0 8.35 N 22.28 W 2549 2548 2400 1 0 9.34 N 23.27 W 2649 2648 2500 1 0 10.23 N 24.19 W 2749 2748 2600 l 0 10,99 N 24'71 W �849 2848 2700 1 0 11.66 N 25.28 W �949 948 2800 1 0 12.2J Nit 25.87 W J049 3048 2900 J. 0 12.67 N 26.10 W 3l49 3148 3000 1 0 13.06 N 26.u0 W 3249 3248 3100 1 0 13.41 N 26.53 W 3349 3346 3200 1 0 13.66 N 26.73 W 3449 3448 3300 z 0 13.72 N �7.13 W 3549 3548 3400 l 0 13.64 N 27.56 W �CU 23B3 1-25-84 UATA lNTERPOLATED FUR EVEN 100 T UF SU8SEA DEP7H ..... ... ... ..... ..... ... MEAS` ... ..... ..... ... ... __..... TRU VERT ________ SU8 SEA ..... ..... _.... ..... _ MD -TVD .... _..... .... ..... ..... ..... _ _..... _..... ..... ..... __... ..... ..... ..... ..... .... OORUINATES _..... ... ..... ... _____ DEP[H DEPTH DEPTH DIFF. CORRECT FRUM WELL -HEAD 3649 __ 3648 ..... ..... ..... _... ___ 3500 ______ z ________ i �:; __..... ..... ..... ..... ___ 13.5z N 27.98 W 3749 3748 3600 1 0 13.55 N 28.36 W 3849 3848 3700 I 0 13.5z N 28.51 W 3949 3948 3800 1 0 �2.74 N 28.67 W 40�9 4048 3900 1 0 11.87 N 28.73 W *l48 4000 1 0 lz./8 N 29.07 W 4249 4248 4100 1 0 11.00 m 2Y.23 W 4349 4348 4200 1 0 10.74 w 30.23 W 4449 4448 4300 1 0 �0.70 N 31.62 W 4549 4548 4400 1 � 10.57 N 33.78 W 464Y 4�48 4500 1 0 �0.49 m 36.72 W 4749 4748 4600 1 0 l0.l4 w 39.75 W 4845.) 4848 4700 1 0 9.34 N 42.6� W 4949 4948 4800 1 0 8.83 N 45.30 W 5049 5048 49 N 47.16 W 51.49 5148 5248 5000 5i00 1 0 0 8'32 N 48.85 � 5249 5349 5348 5200 1 l 0 8.47 Y.0� N N 50.37 W 51.97 W 5449 5 48 5300 1 0 9.97 N 53.40 W 5549 5548 5400 l 0 ll.08 N 54.45 W 5649 5648 5500 1 0 i2.45 N 55.53 W 5749 5748 5600 1 0 J. N 56.74 W 5849 5848 5700 1 0 16.07 N 58.17 W 5949 5948 5800 l 0 18.23 N 59.70 W 6049 6048 5900 1 0 20.55 N 61.55 W �149 6148 6000 l 0 22.25 N 63.69 W 6249 6248 W 6349 6348 6200 l 0 24.56 N �7.u2 W 6449 6448 630V 1 0 25.70 N 70.16 W 6549 6548 6400 l 0 26.74 N 72.45 W �641.) 6o48 500 1 0 27.38 N 74.20 W �749 6748 6�00 z 0 28.0l N 75.82 W �84Y 6848 �700 � 0 28.37 N 77.53 W 6949 6948 6800 l 0 28.4l N 7�'25 W /04v 7048 6900 1 0 28.18 N 80.87 W 1 25 84 DATA lNTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH _... ..... ..... nEAS. ________ TRU VERT ________ SUB SEA _..... .... ___ MD-TVU ________ ________________________ VER|IC�L RELA7IVE COORDlNAlES D�PTH DEPTH ..... ..... ..... ..... ... .... ..... ..... DEPTH ... ..... ______ DlFF. _____ CORRECT ________ _______ ��ROM �EL.... 'HEAu ________ _ ..... ..... ... ..... ..... ..... 7149 7l48 7000 1 V 27.8� n 82.56 � 7249 7248 7100 1 0 27.55 N 84.�5 W 734� 7348 7200 i 0 27.�7 N 85.73 W 7o49 7448 7300 1 0 26.68 |� 87.42 � 7549 7548 7400 | 0 2�.72 N 89.�5 W 76�9 7648 7500 /750 7748 7600 2 � 23.68 n 92.�5 W /850 7848 7700 2 0 2l.21 m Y�.�4 W 7950 7948 7800 2 0 20.88 w 9�.01 W 8050 8048 7900 2 0 �9.�Y N Y6.25 W ^ 8150 8148 80�0 2 2 0 0 i8.z7 16.7O N h 97.4/ ,8.69 W W 8250 8350 8248 8348 8100 8200 2 0 15.56 N 99.81 W 8450 8448 8300 2 o 14.2� w 100.95 W 8550 8548 8400 2 ,) l3.16 N �02.16 W 8650 8648 8500 2 V 14.24 N 103.49 W 8750 8748 8600 2 0 �8.85 � 1V4.01 W 8850 8848 8700 2 0 26.50 N 101.05 W u951 8948 8800 3 l 37.08 N 9�.72 W Y052 9048 8900 * 1 52.13 N 87.91 W 9154 9148 9000 6 2 u9.32 N 76.25 W 9258 92w8 9100 10 '� 89.46 N 61.6l W 9362 Y348 9200 �4 4 ll0.80 N 4o.l0 W Y467 9448 9300 l9 5 132.17 N 1�.44 W �573 9548 41. 25 6 157.27 N 8.l9 � v680 9648 9500 32 7 186.02 W 3l.5� E 9/88 9748 9600 40 8 217.�7 N ��.l9 E ;897 9848 9700 49 v 253.11 N 83.v6 E 1V009 9948 9800 61 12 292.09 N 114.44 E 1v121 i0048 9vo0 73 12 334.73 N 141.3v L 1o2J3 10l48 l0000 85 l2 379.O3 N �63.65 � lu344 10248 10100 v� ii 424.93 N �84.45 � lv4�4 10348 10200 106 i0 468.40 N 203.28 E 1v5�5 10448 10300 .1. 3. 11 �10.13 N �20.l9 � 1V673 10548 l0400 125 8 55k.63 N 234.Y9 � 1-25-84 DATA INTERPOLATED FUR EVEN 100 FEET OF SUBSEA DEPTH _..... ..... ..... ..... ..... ______.... ..... ..... .... ..... .... .... __... ... .... __..... ..... ..... ... __..... ..... ... ..... _... ..... ... .... _..... ..... ... ..... ..... _..... .... ..... ... ..... ..... ..... ..... ..... ..... ..... ... MEAS. TRU VERT SUB SEA MU -[VD VEHTlCAL RELATIVE COOHDlNATE� DEPTH DEPTH DEPTH DIFF. CORRECT FROM WELL -HEAD _..... ... ..... _ ___.... ... ..... ..... .... __..... ..... _... _______ _________ _ ________ _ 10782 10648 10500 134 9 5Y0.Y9 N 247.79 E 10890 10748 10600 142 8 628.83 N 259.36 � OAlA INTERPOLATEU FUR EVEN 10V0 FEET OF 01EASU11ED DEPTH ..... ..... ..... MEAS. _... ..... __..... ..... ... TRU VERT� ________ SUB SEA ..... .... ... _..... ..... ... ..... ..... ..... _____________ 8ELATlVE COORUlNATES DEPTH DEPTH DEPTH FROM WEL�-HEAD ... ..... _ 1000 1000 ________ 852 ________ _ ..... ..... ..... ... ..... ..... 2000 2000 1852 4.17 N l8.84 W 3000 3000 2852 12.48 N 26.01 W 4000 4000 3852 i2.29 N 28.70 � 5000 5000 4852 8.�8 N 46.32 W 6000 85l 19.45 N 60.�0 W 7000 6999 685� 2O.32 N 80.08 � 8000 7999 7851 20.23 N 95.6� W 9000 8997 8849 +3.9� N 92.21 W 10000 9941 9793 2�9.25 N 11�.20 � .~� - r--- -- - ' - , - -- -- ' .-- - --------'----- r- --'- - ---- ---' - - ---- -- -- --- '' ' -- - ''-------'------- - — -- ----- Ho�es' -7r;�TL - - -'------'--------'-- - ------ All volueG 1n O upthz sho� � SC23G3 ' [losure 7S6 ~ US CF RY6TURE 9ot��m �cle: ' TL QHOT SURVEY THO l�g7l ' ' inoh = 250 Feat ' H.S��ic . . / /n�� _"�� ^u � . . Y � -- ' -- ---'-'------- -' �o �uz. ' | -' or .ji / . . / \/ � ' Suggested form to be inserted in each "Active" well folder to d,.eck for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: IL Date C V - V - J 14 JA Required Date Received Remarks Completion Report Yes Well History Yes -Samples .. . . ...... .......... Mud Log Core Chips Core Description Registered Survey Inclination Survey Directional Survey Drill Stem Test Reports _ - / ProdActiOn Test Reports R:Ziin ogs un Logs Yes Digitized Data La C V - V - J 14 JA cnQyron ,C"EV R O N U.S.A. INC. TRANSMITTi D ACFi10iF1I.EDGEMENT OF RECEIPT Ar1TCRIAL - (ALASKA) r0 : DATE �-- �-7I-r-, v DEPT.: - - FD - Folded 8 -Rolled PLACE: �� (� S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. E) ewc 7-/ to /v /0 c7- :5-6 Z7/4 W (E (5 fo (sr— Sic W �/ - 55 �o Si-/ - n oo -- � 8Y RECEIVED 8Y ON U.S.A. INC. BOX 7-839 ee�.. wore nu nTuc a cinr THIS SNFTT ..vuncecF ei eers opsin January 13, 1984 Mr. R. L. Thos Area Engineer Chevron. U.S.A. Tnc . P. 0. Box 107839 Anchorage, Alaska 99510 Re: So.dotna Creek Unit SCU 23B-3 Chevron U.S.A. Inc. Permit No. 84-10 Sur. Loc. 1983 * ti, 1082-!E of S14 cr Sec. 3. T7N, 89111, SFS. tmho .e Loc. 600'N, -112-VE of the surface location. Dear Mr. Thomas Inclosed .s the approved application for perr�f.t to drill the above referenced well. T f coring is conducted, a one cubic inch chip from each foot of recovered core is re uired.ampler of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a. tape containing the di iti ed log 4,n.forMtion shall be submitted on all los for copying except experimental logs, velocl,ty surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been Classified as important for the spawning or migration of anadromous fish. Operations in these areas are sublQct to 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska dm ,nistrati've Code) . Pr6r to commencing operations VOU may be contacted by the Habitat Coordinator's Offlen , Department of Fish and Can -e. pollution of any waters of the Mato is prohibited, by AS 46, Chapter 3, Article 7 and the regulations prormigat ee thereunder (Title 181, Alaska Admint istratilre Code, Chapter 70) and by the Federal eater Pollution Control Act, a.s amended. Prior to conme-neing operations you may be contacted by a reprAsent-s-t-i- Te !a f thn Depzlrime t o�' Enron ent, 1 �,'t.`;nser?Tat;�,oln'l To aid us in scheduling field wore, please notify this office 4 .ours prior, to commencing -installation of the blowout pre- vention. equipment so that a representative of the Co lss?.on, VIM. R. L. `1nowars January 13, 1984 J #.dlotna Creek Vnit SCU 23L"3 way be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to co:�ncinq equipment installat on so ttat the Commission may witness testing before t5lrilling below the shoe of the con- ductor Pipe. in the event of auspeas o 'or abandonment, please give this off -ice adequate advance notification so that we may have a witness present; vel ._. trul furs , C. V. Chatterton. Chairman o Alaska Cil and. Gas Conservation ConwU' zsiQn be nclosure cc. Department of Fish and Game, habitat Section w/o encl. Department of Evirou ental Conservation wjo encl. STATE OF ALASKA ALASKA 01 _ ..Iq D GAS CONSERVATION COI`, - ..1SSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work. DRILL ❑ 1b. Type of well EXPLORATORY ❑ SERVICE ❑ STRATIGRAPHIC ❑ REDRILL X1 DEVELOPMENT OIL I SINGLE ZONE EJ DEEPEN ❑ DEVELOPMENT GAS ❑ MULTIPLE ZONE ❑ 2. Name of operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4. Location of well at surface 1983' N & 1082' E of the S.W. Cor., 9. Unit or lease name Sec. 3, T7N, R9W, S.M. Soldotna Creek Unit At top of proposed producing interval ±5001 N & 300' E of the surface 10. Well number location SCU 23B-3 At total depth ±6001 N & 325' E of the surface location I 11. Field and pool Swanson River -Hemlock 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 128' G.L. A-028997 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number U80615521 Amount 500 000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to_nearest dril in or comp) {ed 15 miles 1800 feet weltSSCU 23A 33� 5100' Abd. L 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date ±103-970' M. D. 1.0,818' TVDfeet 2560 1/14/84 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 3540 psig@ Surface KICK OFF POINT 10, 015feet. MAXIMUM HOLE ANGLE 26 ° (see 20 AAC 25.035 (c) (2) 4500 psig@10663ft. TD (TVD) 21 i Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 611 511 18# N-80 Butt ±1200' -9.0 - -901 1 1097011 10,818 59 SX- /00 Sk 98Is- ' 9 8 ' I I 22. Describe proposed program: i See attached program. i G:3� �iUll`..-iV�ia.jel; 23. 1 hereby cert if that the foregoin is true and correct to the best of my knowledge 1 I SIGNED TITLE Area En ineer DATE lnd'g 4 The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required API number ❑YES D4IO ❑YES KNO *ES ONO 50— %33 - A) I Permit number g`� J Approval date 01/13/84 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY//""7/(Ae,COMMISSIONER DATE January 13, 1984 by order of the Commission Form 10-401 Submit in triplicate 0. -7 1 4n SUPPLEMENTARY PROGRAM SCU 23A -3/23B-3 RBDRELL 1. Run in hole open ended with 2 3/8" tbg. on bottom to 10,800' or as deep as possible. Equalize 80 SX of Class "G" cement with 0.75% CFR -2 from 10,800' to +1091001. Pull out of cement and down squeeze- cement into the formation until cement top is at +10,250' or 2,500 psi of surface pressure is seen. WOC. 2. Run 6" bit and tag the top of the plug. Set 15,000 lbs. of string wt. on plug. AOGCC and BLM to witness hardness of plug. Alert these agencies 24 hours prior to hardness test. Pressure test the 7" casing to 3,000 psi for 15 minutes. Convert salt gel mud to treated lignosulfate mud with a 11.0 ppg. weight. 3. Run a 7" section mill and cut a minimum of 451 of window in the 7" 29# Pilo casing from +10,015 to ±10,060'. Casing collars at +9,896'; ±9,938'; +9,978'; 1090211; 10,063' and 10,1041: E - log depths. Under ream section window from 8 3/4" hole to 11" hole. 4. Spot a densified Class "G" cement plug across 7" window. Pull out of cement and down squeeze +10 ft3. Top of plug to be at or above 10,0001. WOC. 5. Cleanout cement plug to the top of the 7" window. 6. Redesignate well as SCU 23B-3. 7. Side track the original hole and the first side track to a TVD of 10,818' or +109970' MD using 6" bits. 8. Precise directional control is not required, but a minimum deflection of 50' from the original hole and the first side track should be kept. Attempt a low side and westerly kick off direction for a preferred net displacement to the west of 50' or more. Run single shot surveys as necessary to ensure adequate deviation. 9. Condition hole for logs. Obtain i gallon of drilling mud prior to pulling out of the hole. 10. Run the following Schlumberger logs from TD to the 7" window. A. Dual Induction with S.P. and G.R. Use linear 2"/1001, 0-50 ohm -m and logarithmic 5"/100' scales. Use 10 MV/division for the SP and a 0-100 G RU scale for the gamma ray. B. Borehole compensated sonic log with G.R. Log scale to be 50-150 MSEC. C. FDC-CNL, GR. 0-60 porosity units, 0-100 GRU. D. Record all logs on tape. E. Production Engineer to witness logs. 11. Make bit clean out and hole conditioning trip to run 5" liner. 12. Run and cement 511, 18# N-80 liner from TD to ±200' above window. Equip liner with float collar, float shoe, and centralizers. Cement liner with sufficient Class "G" cement with retarders and friction reducers as needed to obtain returns above the top of the liner. 13. Clean out cement to the float collar. Pressure test 5" liner, liner lap, and 7" casing to 3,000 psi for 15 minutes. 14. Run Schlumberger's CET -CCL -GR from PBTD to the top of the liner. 15. Supplementary completion program to follow. '' l ' J•r SII � 'i• -2 9 fi- C� %%p r R o A %host1Cc S CI� Gl,0ke- /1-1 Cl .-.1�D ICL td be sM &---4 fo S3 4L- 4 v � _ WELL HEAD HOOKUP f S.C. U. 236.3 SECTION 23 T. 7N.,R.9W. SM Chevron U.S.A. Inc. MEMORANDUM GO -144 TO: I /a _19 e4 FROM: SUBJECT: OUR YOUR FILE: \V\j 160 -ca ��s -vim CA bo OM -U 0 1`7'e� Z- Nw , jt?4" WHEN REPLY IS REQUIRED, FORWARD ORIGINAL AND ONE COPY 10-j-, t T7 s.. .,.y, ,.-,--, �.. �...., �„• --7 " 1• ') C �1t^: •L: , .CHECK LIST FOR NEW WELL PERMITSCompa. C � Lease & Well No. ITEM APPROVE DATE YES NO REMARKS (1)Fee (2) Loc �0 thru 8) �J'#-Ja-- INITIAL CLASS STATUS (8) UNIT NO. (3) Admin 1144,A_,, /-t-L-11 (5 thru 11) 7/0 0 J (10 and 11) (4) Cas (12 thru 20) (5) BOPE h,T1 (21 thru 24) (6) Add: Geology: Engi eerin : HWK K LCS BEW WVA JKT — HJHf- JAL _ rev: 12/08/83 1. Is the permit fee attached ............................. 4 ........... I L 2. Is well to be located in a defined pool ............................... 3. Is well located proper distance from property line .................. G� 4. Is well located proper distance from other wells .................... �.. 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... 9. Does operator have a bond in force ....................... 0.......... 10.. Is a conservation order needed ...................................... !� 11. Is administrative approval needed .... _ 12. Is conductor string provided ........................................ //1/ P41ge-6 13. Is enough cement used to circulate on conductor and surface ......... It 14. Will cement tie in surface and intermediate or production strings ... It�� 15. Will cement cover all known productive horizons ..................... CEMAN T- Y)I )-,L Cd V ie 12J-1- of Lh/jER. 16. Will surface casing protect fresh water zones ....................... A/RE�9DY J N PZ fie -E 17. Will al,l casing give adequate safety in collapse, tension and burstN .. / O4Y L./AACR 1s NEW , 18. Is this well to be kicked off from an existing wellbore ............. 19. Is old wellbore abandonment procedure included on 10-403 ............ 20. Is adequate well bore separation proposed ........................... 21. Is a diverter system required ....................................... .rrrRF�CE C�s�NG A�RE�oY �.N P�FrC 22. Are necessary diagrams of diverter and BOP equipment attached ....... �_ti. 23. Does BOPE have sufficient pressure rating - Test to Z P-Irb psig .. 1V 24. Does the choke manifold comply w/API RP -53 (Feb . 78) .................. .,110 T Su 133 i -'7-ED 25. Additional requirements ............................................. _)qTll Additional Remarks: COiPlt'�C D S' Del %/D.�i/S S �P 7,E�4z- Co111 w D/s'' n ce POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE 772 -loo r 'Fzo s'l SY o 0 J 0 xz �o t%j M H z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Oh _Schlumberger All p T 11P H PT ru« « Ix = i 3-1* -3 210 43 90 ATSAv, F: IT ,,.:` _ _ 0 i- , G -. _'�.e. � � �". -- . � �: _TFa rT �i 4'� � .� 9 0 _'-. ye11 p -31 ��r 19 3 [ .mss � •i �" � !� r � `3 "i � Ar �'+ -'.e �- ii 3. ♦ _ � w i + �- � ! � � '• 14 411 {�c �4. § 4'! 7 r 0 11". 1 21 9«-� 4137 z ,s r« yy 3 1 �- f s41oi o 5 _ zi --+k " '' may. S < ►` xr - . } as 4-2 b i d. •T k . T IT k -z f€ > _ F - - to f€ s . 7 • i 7 � +r °' EX111.0 4- 'e. fie+ -? .. ia5_�I � pyo �` 'yy qY .ryy 45Y 4 ✓�, -41 - � J yq.may - 15640 �� S's* �+fi �y 1w _ +� � 1 , 1- # A A S► ' .y { ` .: s ! !Z f' Iq 161 11 IVr J,6i # S r• € 001. a i i [ T A eS*�'�3�.-'��`'••��.�.£�'--s�i'`��-��-*<�- r=-t"y"'Sis`"fF^�"�4 �'.�..t�y;q+-��-'�'�Fr �f r�i 3�}7�: ''*',��'�r. +_`__�_✓��, `r�'C SA , -:_ v.s +� 3`j,`'r "3' r. +. ?h A i �; yy�� { y. P �q +� s �T -per { HC—FT `3 g��ssr #' E r �}�e- zz �R"-��"k�a'T+��-`_i'��-K��a��'Y�� •Ez'ry`Tf'��y"-�.4�i413'�-. (��^�i'�4 .��, �I"'�� j��y�` A Zy- )�.M��.a{i - r#. - 4 `moi 4C -�- A -:`- �� -� ;"# ��i ' � Yip- � � � '� � "' � _i• � t� ''�: w - _ - - 6 i'- iR--f' y s '; ytf l i �r '•' .1 '! if +.." A � (s � • � 8- �} _ of too S+ + -42 � a� -*. �l �. _ � '�'- { 'y`. y� iT tel. _ �i� tip �: 17. 14 It +it 1Y - -y "�Y is - - lj. A4 I -.3 ! Y 2 � 1 ='f $ � 5.:t -s .} '-��ssrg�g�-- � a 14.1 _ - ,w� }}. 1,0_6 4, aaeey� ; y y ♦s +�'}1' 5 try K. t[' - z- •-. rte-, - -f ^i %r -t. #i. i i J s ' :�,..i • K; fay. - „ 4i a= =' .►• r°=. , _ Jn f�<^.'-� y}�� :-.-. { ;a � � �y '�S.` � �` �_ �� fid- �sa:. �- �. - � � .s• - h � � # - �i -� - �t� �eae�' 6# '��a r- �"2 .�. � � � 4!.' Y• �. � 'i ..� * �� i 4' .� 4 ! 3- - -c dr. - #r ff. -.4d+ 4 u ft 4 47 tl _- -s __ 2 Z z 5:. - 21 10� 3°s .3 # 1011, x514 fx -'sX14,# ' a. 9* T Zr Z t 4• ri i i ', his �! ;+; #r= 4 f1 5 �f i �,R ;a yr i�01. =#'i�x3* ,8RK 17 -T xc y fbc � 3 11 ell 10 UV ii;-rte€ - 'S3'xz e'er 'v!._- -1 •. '�t4 ,. ' S= tel i 4 1 # '�Y+r 4K �R far, .�. � � �n �i �r 3 � '� 3 „°`z#,41 +3.+{mac i- 101 8- 'S-� $+- - - - -. 'E 9 z Schlumberger 1 1 az A y'- 14�:= as -� $ - N 11 `- .sem 3 •._: -- •:-_ z� '!=5`� x • _'i ± Frod *SAT tF #-WATER *TUTAL ppsl .R FERMv t.—aHL � ✓` A 1 7!f,' J w %�► ''- _ •. + :. rte;_ - : - it n7 V_'F; T -. _#J.9w _ -_t, �S1F ' ..- - ice.•(' �i1��Is +[ j,y }�• yr i�,•, t f F z }� i� r U. - T FT ml ' l r+r! 'tom �r Iq !$ «+�►'� i�L3[!�:! 14�i j ': Z44 41 Av 3 't 21 lot Z 24,p 117 4 I §-;-*- - -6 - a = ' - -. ter _ - # - 490 tt fc. :. i, 41 ic 6o 6 i[e 6 � � ` ! lw ! lil fir, 14 416.1� 44 ' .. x.92. � �• ` I li +141 i1- 0 -. 4 *1 fat =� 135, � 19� �, � k<- 1- --51 •,y SFA -.�iF'' -. v'4='" �' +i1 t+'E 4-a -• a-'�� E 2-4 4* IC.2.0 , kI'_ 4 1 -fl � it } � ) 91 A 20 187. 14 -� II �.T 14 <. # a I A� i': 'E ,fit ~• i _-`'- vt 432. 44404 x. *t -0 '- --a#` -fry ` _ - Pik' �5•- + 1P 3�M�i' M� h�4'sT J f Schlumberger f IR -WAT Ms T*TOTAL PRS ..:w ..r `. P �-w -.� r� -� ,� - -.. t�IZ ys v►-�►� �.. as tt �y . 1 -. F' '-- s".ra.- - _ _aa +sXifi.. .�r w► �- �r a.. Tj 9` 4. All *14 lis lit AM ,fie f *** START OF MSP PROGRAM SLMLIS FROM LIBRARY PSD.XLIB PROGRAM STATUS INDEX= 12084240 MSP TASK ID C8F3840307122826 *** THE FOLLOWING CARDS HAVE BEEN INPUT TO THIS PROGRAM (MSP STEP NUMBER 3) , PROJECT NAME f= WLSTST 1/ CONTENTS ' 1 2 3 4 5 6 7 8 .12345678901234567890123456789012345678901234567890123456789012345678901234567890 CARD 1 . &SLMLIX &END CARD 2 . &SLMLIS TAPE=2,&END DICTN,NREC FILE XSAMP,TOP OR BOT CARD 3 . &PARM SCAN=1,&END GEN=1066815,START=-1,PRINT=1, MINIT COMPLETED AFTER READING 3 CARD(S) ***** PROGRAM = SLMLIS NUMBER = A06 SETSSI = 12084240 *** MSP SYSTEM PRINT FLAG SET EQUAL TO -1 AT THIS POINT IN PROGRAM **** DDNAME=FT49F001 NUMTRK= 38 TRKSIZ=13030 DEVTYP= 4 UNIADR= 95A CURVAL=MS4629 ITYPE= 2 ,5 Ll" "- � D 23 *** START OF MSP PROGRAM MSPON FROM LIBRARY EPD.SYSTEM PROGRAM STATUS INDEX= 17183053 MSP 'TASK ID 0000000000000000 *** t THE FOLLOWING CARDS HAVE BEEN INPUT TO THIS PROGRAM (MSP STEP NUMBER 2) , PROJECT NAME = WLSTST 1 2 3 4 5 6 7 8 .12345678901234567890123456789012345678901234567890123456789012345678901234567890 CARD 1 . &MSPON &END MINIT COMPLETED AFTER READING 1 CARD(S) ***** PROGRAM = MSPON NUMBER = S33 SETSSI = 17183053 *** PINT INTERFACE PLOTTING HAS BEEN SELECTED FOR HOST PLOTTER = VERSATEC *** *** ACROSS = 23.0, ALONG =********, PAPER NUMBER = 500 *** *** PEN1 = 4BLK, PEN2 = 3RED, PEN3 = 2BLU, PEN4 = 1GRN, *** *** PINT/VAMP PARAMETERS ARE: WIDTH = 23.0 PROD =P CORD =Y *** *** DATA FILE ALLOCATION FOR THIS JOB (NREC) IS 3781 MSP RECORDS. *** ***** MSP JOB WLSTST STARTED HAVING EXTENDED TASK NAME H3/84.307/12:28:26 CURRENT NUMBER OF ACTIVE TASKS IS 1 *** PROGRAM MSPON COMPLETED WITH A CODE OF 0 **** *** JOB BESEAS M WITH CHRGE NO. S7,00666 STEP NO. 2 ON SYSTEM C033 AT 12:28:27 USING 224K/6776K BYTES MEMORY *** 22 THE TRACE DATA STRINGS WILL HAVE THEIR NAMES DERIVED FROM SCHLUMBERGER FIELD NAMES. GENERATION NUMBER =-2048 START SEQUENCE = 1 *** FT42F001 OPENED *** REEL HEADER LENGTH: 132 BYTES REEL NAME: REEL ID SERVICE NAME: VOLAN DATE: 84/01/26 REEL CONTINUATION NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: REEL COMMENTS TAPE HEADER LENGTH: 132 BYTES TAPE NAME: SERVICE NAME: VOLAN DATE: 84/01/26 TAPE CONTINUATION NUMBER: 01 PREVIOUS TAPE NAME: COMMENTS: TAPE COMMENTS * * * * * * * * * * * * * * * * * END OF FILE MARKER NO. 1 * * * * * * * * * * * * * * * * * FILE HEADER LENGTH: 64 BYTES FILE NAME: VOLAN .001 MAXIMUM PHYSICAL RECORD LENGTH: 1024 BYTES PREVIOUS FILE NAME: WELL SITE INFORMATION RECORD *** COMPANY: CHEVRON USA INC. WELL: SCU 23B-3 FIELD: SOLDATNA CREEK UNIT WELL SITE INFORMATION RECORD *** DATA FORMAT SPECIFICATION LENGTH: 1988 BYTES ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 1 8 4 73 60 9 4 65 .lIN Alas oii 4 Gay A��ho 1 24 DATUM SPECIFICATION BLOCKS: ENTRY IC TOOL SVORD# UNITS API API API API FILE# SIZE EXP PROC SAM REP DEPT SHIFT 1 DEPT FT 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 2 CALI PRE IN 00 1C 03 00 0000 0004 0000 00 01 44 00 00000000 3 DCAL PRE IN 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 4 DT PRE US/F 00 34 20 00 0000 0004 0000 00 01 44 00 00000000 5 GR PRE GAPI 00 1F 20 00 0000 0004 0000 00 01 44 00 00000000 6 PHIX PRE PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 7 PNS PRE PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 8 PDS PRE PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 9 RHGX PRE G/C3 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 10 RHOB PRE G/C3 00 23 01 00 0000 0004 0000 00 01 44 00 00000000 11 RT PRE OHMM 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 12 RMFA PRE OHMM 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 13 RWA PRE OHMM 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 14 RWSP PRE OHMM 00 00 00 00 0000 0004 0000 00 01 44 00 0000.0000 15 SP PRE MV 00 01 00 00 0000 0004 0000 00 01 44 00 00000000 16 AFLG 001 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 17 HVOL 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 18 HWT 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 19 PHIE 001 PU 00 00 00 00 0000 0004 0000 00 01 44 0000000000 20 PSXO 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 21 RO 001 OHMM 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 22 RHGA 001 G/C3 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 23 ROHY 001 G/C3 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 24 SBCW 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 25 SBEP 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 26 SBEX 003 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 27 SBGP 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 28 SBGR 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 29 SBND 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 30 SBSP 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 31 SW 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 32 SWB 002 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 33 SXO 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 34 VCL 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 35 VDCL 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 36 VDOL 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 37 VSH 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 38 VSND 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 39 KGAS 001 MD 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 40 KHYD 001 MD 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 41 KINT 001 MD 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 42 KOIL 001 MD 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 43 KWTR 001 MD 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 44 PHIT 002 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 45 PSW 002 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 46 RKG 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 47 RKO 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 48 RKW 001 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 49 PHIX 002 PU 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 WLS TRACE DATA STRINGS FROM FILE 1 DEPTH UNITS ARE: FT DATA STRING >CALI PRE < IN UNITS OF >IN < HAS A WLS, NAME OF >CALIPREI< DATA STRING >DCAL PRE < IN UNITS OF >IN < HAS A WLS NAME OF >DCALPREI< DATA STRING >DT PRE < IN UNITS OF >US/F< HAS A WLS NAME OF >DTPREI < DATA STRING >GR PRE < IN UNITS OF >GAPI< HAS A WLS NAME OF >GRPREI < DATA STRING >PHIX PRE < IN UNITS OF >PU < HAS A WLS NAME OF >PHIXPREI< 26 DATA STRING >PNS PRE < IN UNITS OF >PU < HAS A WLS NAME OF >PNSPREI < DATA STRING >PDS PRE < IN UNITS OF >PU < HAS A WLS NAME OF >PDSPREI < DATA STRING >RHGX PRE < IN UNITS OF >G/C3< HAS A WLS NAME OF >RHGXPREI< DATA STRING >RHOB PRE < IN UNITS OF >G/C3< HAS A WLS NAME OF >RHOBPREI< DATA STRING >RT PRE < IN UNITS OF >OHMM< HAS A WLS NAME OF >RTPREI < DATA STRING >RMFA PRE < IN UNITS OF >OHMM< HAS A WLS NAME OF >RMFAPREI< DATA STRING >RWA PRE < IN UNITS OF >OHMM< HAS A WLS NAME OF >RWAPREI < DATA STRING >RWSP PRE < IN UNITS OF >OHMM< HAS A WLS NAME OF >RWSPPREI< DATA STRING >SP PRE < IN UNITS OF >MV < HAS A WLS NAME OF >SPPREI < DATA STRING >AFLG 001 < IN UNITS OF > < HAS A WLS NAME OF >AFLG0011< DATA STRING >HVOL 001 < IN UNITS OF >PU < HAS A WLS NAME OF >HVOL0011< DATA STRING >HWT 001 < IN UNITS OF >PU < HAS A WLS NAME OF -11WT0011 < DATA STRING >PHIE 001 < IN UNITS OF >PU < HAS A WLS NAME OF >PHIE0011< DATA STRING >PSXO 001 < IN UNITS OF >PU < HAS A WLS NAME OF -PSX00011< DATA STRING >RO 001 < IN UNITS OF >OHMM< HAS A WLS NAME OF >R00011 < DATA STRING >RHGA 001 < IN UNITS OF >G/C3< HAS A WLS NAME OF >RHGA0011< DATA STRING >ROHY 001 < IN UNITS OF >G/C3< HAS A WLS NAME OF >ROHY0011< DATA STRING >SBCW 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SBCW001l< DATA STRING >SBEP 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SBEP0011< DATA STRING >SBEX 003 < IN UNITS OF >PU < HAS A WLS NAME OF `SBEX0031< DATA STRING >SBGP 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SBGP0011< DATA STRING >SBGR 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SBGR0011< DATA STRING >SBND 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SBND0011< DATA STRING >SBSP 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SBSP0011< DATA STRING >SW 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SW.0011 < DATA STRING >SWB 002 < IN UNITS OF >PU < HAS A WLS NAME OF >SWB0021 < DATA STRING >SXO 001 < IN UNITS OF >PU < HAS A WLS NAME OF >SX00011 < DATA STRING >VCL 001 < IN UNITS OF >PU < HAS A WLS NAME OF >VC1,0011 < DATA STRING >VDCL 001 < IN UNITS OF >PU < HAS A WLS NAME OF >VDCL0011< DATA STRING >VDOL 001 < IN UNITS OF >PU < HAS A WLS NAME OF >VDOL0011< DATA STRING >VSH 001 < IN UNITS OF >PU < HAS A WLS NAME OF >VSH0011 < DATA STRING >VSND 001 < IN UNITS OF >PU < HAS A WLS NAME OF >VSND0011< DATA STRING >KGAS 001 < IN UNITS OF >MD < HAS A WLS NAME OF >KGAS0011< DATA STRING >KHYD 001 < IN UNITS OF >MD < HAS A WLS NAME OF >KHYD0011< DATA STRING >KINT 001 <• IN UNITS OF >MD < HAS A WLS NAME OF' >KINT0011< DATA STRING >KOIL 001 < IN UNITS OF >MD < HAS A WLS NAME OF >KOIL0011< DATA STRING >KWTR 001 < IN UNITS OF >MD < HAS A WLS NAME OF >KWTR0011< DATA STRING >PHIT 002 < IN UNITS OF >PU < HAS A WLS NAME OF >PHIT0021< DATA STRING >PSW 002 < IN UNITS OF >PU < HAS A WLS NAME OF >PSWO021 < DATA STRING >RKG 001 < IN UNITS OF >PU < HAS A WLS NAME OF >RKG0011 < DATA STRING >RKO 001 < IN UNITS OF >PU < HAS A WLS NAME OF >RK00011 < DATA STRING >RKW 001 < IN UNITS OF >PU < HAS A WLS NAME OF >RKW0011 < DATA STRING >PHIX 002 < IN UNITS OF >PU < HAS A WLS NAME OF >PHIX002;1< 27 DEPTH 10960.000 10950.000 10900.000 MNEMONIC VALUE CALI 5.634 PHIX 13.599 RHOB 2.514 RWSP 0.107 HWT 0.0 RHGA 2.733 SBEX 53.618 SBSP 66.453 VCL 29.402 VSND -999.250 KOIL 0.001 RKG 0.0 CALI 5.276 PHIX 19.652 RHOB 2.350 RWSP 0.064 HWT 1.493 RHGA 2.680 SBEX 23.279 SBSP 0.845 VCL 4.069 VSND 69.870 KOIL 0.023 RKG 0.169 CALI 5.615 PHIX 15.421 RHOB 2.391 RWSP 0.070 HWT 3.885 RHGA 2.651 SBEX 1.409 SBSP 6.516 MNEMONIC VALUE DCAL -0.366 PNS 19.867 RT 7.359 SP -14.750 PHIE 5.136 ROHY -999.250 SBGP -999.250 SW 100.000 VDCL 21.896 KGAS 0.001 KWTR 0.001 RKO 0.0 DCAL -0.724 PNS 21.855 RT 3.949 SP -34.750 PHIS 17.631 ROHY -999.250 SBGP -999.250 SW 86.689 VDCL 3.098 KGAS 0.049 KWTR 12.028 RKO 0.079 DCAL -0.385 PNS 14.304 RT 23.016 SP -31.048 PHIS 14.700 ROHY 0.553 SBGP -999.250 SW 47.445 MNEMONIC VALUE DT 78.625 PDS 8.262 RMFA 0.186 AFLG 0.0 PSXO 5.136 SBCW -999.250 SBGR -999.250 SWB 59.372 VDOL -999.250 KHYD 0.001 PHIT 12.642 RKW 0.0 DT 78.625 PDS 18.205 RMFA 0.774 AFLG 2.000 PSXO 15.284 SBCW -999.250 SBGR -999.250 SWB 5.216 VDOL 0.0 KHYD 0.031 PHIT 18.601 RKW 41.213 DT 80.875 PDS 15.705 RMFA 0.684 AFLG 0.0 PSXO 6.974 SBCW -999.250 SBGR 0.0 SWB 0.704 MNEMONIC GR RHGX RWA HVOL RO SBEP SBND SXO VSH KINT PSW PHIX GR RHGX RWA HVOL RO SBSP SBND SXO VSH KINT PSW PHIX GR RHGX RWA HVOL RO SBEP SBND SXO VALUE -287.292 2.752 0.163 0.0 10.103 -999.250 73.984 100.000 68.268 0.001 5.136 12.642 -156.707 2.680 0.193 2.134 3.002 -999.250 7.115 87.899 8.153 29.185 15.284 19.583 42.814 2.637 0.667 7.023 5.528 -999.250 0.0 52.222 28 10850.000 10800.000 10750.000 VCL 0.354 VDCL 0.250 VDOL 0.0 VSH 0.953 VSND 100.000 KGAS 0.036 KHYD 3.645 KINT 10.593 KOIL 2.394 KWTR 0.003 PHIT 14.804 PSW 6.974 RKG 0.342 RKO 22.603 RKW 0.030 PHIX 15.176 CALI 6.138 DCAL 0.138 DT 78.813 GR 131.289 PRIX 18.980 PNS 30.855 PDS 8.163 RHGX 2.870 RHOB 2.515 RT 6.688 RMFA 0.291 RWA 0.303 RWSP 0.159 SP -1.857 AFLG 0.0 HVOL 0.0 HWT 0.0 PHIE 0.132 PSXO� 0.132 RO 8.521 • RHGA 2.820 ROHY -999.250 SBCW -999.250 SBEP -999.250 SBEX 99.383 SBGP -999.250 SBGR 100.000 SBND 100.000 SBSP 95.820 SW 100.000 SWB 99.213 SXO 100.000 VCL 59.408 VDCL 42.814 VDOL -999.250 VSH 99.550 VSND -999.250 KGAS 0.001 KHYD 0.001 KINT 0.001 KOIL 0.001 KWTR 0.001 PHIT 16.726 PSW 0.132 RKG 0.0 RKO 0.0 RKW 0.0 PHIX 16.726 CALI 5.656 DCAL -0.344 DT 72.375 GR 58.829 PHIX 12.754 PNS 18.728 PDS 7.592 RHGX 2.748 RHOB 2.525 RT 38.906 RMFA 1.270 RWA 0.749 RWSP 0.080 SP -26.190 AFLG 2.000 HVOL 5.263 HWT 3.742 PHIE 9.693 PSXO 3.904 RO 9.506 RHGA 2.729 ROHY -999.250 SBCW -999.250 SBEP -999.250 SBEX 37.012 SBGP -999.250 SBGR 10.227 SBND 36.061 SBSP 15.804 SW 40.277 SWB 19.926 SXO 45.706 VCL 12.632 VDCL 10.219 VDOL 0.0 VSH 28.109 VSND 22.736 KGAS 0.033 KHYD 0.291 KINT 0.488 .KOIL 0.034 KWTR 0.001 PHIT 12.105 PSW 3.904 RKG 6.771 RKO 6.989 RKW 0.0 PHIX 11.794 CALI 5.828 DCA•L -0.172 DT 82.750 GR 91.963 PHIX 27.295 PNS 39.044 PDS 15.508 RHGX 2.918 RHOB 2.394 RT 10.398 RMFA 1.326 RWA 1.028 RWSP 0.157 SP -2.315 AFLG 1.000 HVOL 0.0 HWT 0.0 PHIE 4.150 PSXO 4.150 RO 4.591 RHGA 2.806 ROHY -999.250 SBCW -999.250 SBEP -999.250 SBEX 87.457 SBGP -999.250 SBGR 74.233 SBND 100.000 29 10700.000 10650.000 FILE TRAILER SBSP 94.758 VCL 53.907 VSND -999.250 KOIL 0.001 RKG 0.0 CALI 6.891 PHIX 21.475 RHOB 2.396 RWSP 0.117 HWT 0.0 RHGA 2.755 SBEX -999.250 SBSP -999.250 VCL 44.347 VSND -999.250 KOIL 0.001 RKG 0.0 CALI 5.814 PHIX 23.240 RHOB 2.333 RWSP 0.103 HWT 1.392 RHGA 2.720 SBEX -999.250 SBSP -999.250 VCL 28.969 VSND 100.000 KOIL -999.250 RKG -999.250 SW 100.000 VDCL 37.475 KGAS 0.001 KWTR 0.001 RKO 0.0 DCAL 0.891 PNS 29.072 RT 6.321 SP -12.350 PHIE 0.864 ROHY -999.250 SBGP -999.250 SW 100.000 VDCL 25.634 KGAS 0.001 KWTR 0.001 RKO 0.0 DCAL -0.186 PNS 28.941 RT 7.098 SP -16.819 PHIE 8.703 ROHY -999.250 SBGP -999.250 SW 74.871 VDCL 16.745 KGAS -999.250 KWTR -999.250 RKO -999.250 LENGTH: 64 BYTES FILE NAME: Ej<t+l a MAXIMUM PHYSICAL RECORD LENGTH: La 08 BYTES NEXT FILE NAME: LLLLLLLlll SWB 79.837 VDOL -999.250 KHYD 0.001 PHIT 20.582 RKW 0.0 DT 80.813 PDS 15.404 RMFA 0.352 AFLG 0.0 PSXO 0.864 SBCW -999.250 SBGR -999.250 SWB 95.589 VDOL -999.250 KHYD 0.001 PHIT 19.577 RKW 0.0 DT 83.438 PDS 19.231 RMFA 0.412 AFLG 0.0 PSXO 6.516 SBCW -999.250 SBGR -999.250 SWB 58.411 VDOL 0.0 KHYD -999.250 PHIT -999.250 RKW -999.250 sxo 100.000 VSH 86.167 KINT 0.001 PSW 4.150 PHIX 24.389 GR 57.939 RHGX 2.778 RWA 0.373 HVOL 0.0 RO 5.919 SBEP -999.250 SBND 91.556 sxo 100.000 VSH 96.720 KINT 0.001 PSW 0.864 PRIX 20.562 GR 50.420 RHGX 2.736 RWA 0.497 HVOL 1.988 RO 3.775 SBEP -999.250 SBND 58.411 SXO 77.156 VSH 65.375 KINT -999.250 PSW -999.250 PHIX 22.895 30 END OF FILE MARKER NO. 2 TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: SERVICE NAME: VOLAN DATE: 84/01/26 TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAME: COMMENTS: TAPE COMMENTS REEL TRAILER LENGTH: 132 BYTES REEL NAME: REEL ID SERVICE NAME: VOLAN DATE: 84/01/26 REEL CONTINUATION NUMBER: 01 NEXT REEL NAME: COMMENTS: REEL COMMENTS * * * * * * * * * * * * * * * * * END OF FILE MARKER NO. 3 * * * * * * * * * * * * * * * * * END OF FILE MARKER NO. 4 * * * * * * * * * * * * * * * * * 31 *** FT42F00l CLOSED *** 32 *** MSP JOB WLSTST HAVING EXTENDED TASK NAME H3/84.307/12:28:26 HAS 0 DATA STRINGS LISTED BELOW ***** NO DATA STRINGS STORED FOR THIS MSP TASK ***** *** PROGRAM SLMLIX COMPLETED WITH A CODE OF 0 **** *** JOB BESEAS3@ WITH CHRGE NO. S7,00666 STEP NO. 3 ON SYSTEM C033 AT 12:29:51 USING 224K/6776K BYTES MEMORY *** 33 *** MSP JOB BESEAL M HAVING EXTENDED TASK NAME H3/84.306/10:17:40 HAS 48 DATA STRINGS LISTED BELOW 'CftACS:.;..:. ; ....;....:.... DATA STR T NGS , ;•: *.*;.: ** r*:* * .�k .** �** k#r* ..... > :; bA'I`A:'S'i`It:I.NG Lt7GGING tAG.: _,_FIELD*.: WELL * LOG *Ct]PVF,*': CURVE. INFORMATION * `NO.* 1� Otvf CREATION* . *;'.:`:.. SEN....:*. NAME ,:;� :.DATE *TYPE* 'TAPE->�* I]� *UNIT *UNIT * TOP * BOTTOM *SAMPLE* MINIMUM * MAXIMUM * OF * PROGRAM* DATE ' *(IWNAME) * * * NO. * * * * * INCR * *RECS* *********************************************************************************************************************************** 1 CALIPREI 10650.00 10960.00 1., DCALPREl 10650.00 10960.00 ::::.: :: •. _.. - i;DTP1. <:. :10650.0010960:00 LISEDT 10184306 10650:00 10960.00 . .....:::..... ...:::.: ::: :....:.:::. Et XPRRI.> 10 6 5 0 0.0.1 0 0 960.0 . 1 RE1 ....... ..... ,P T P _ _ .. 10550.00 10960:00 :..:. T POSVRM .. _ . 10650.00 10960.00 1 RHGXPREI 10650.00 10960.00 1 RHOBPREI 10650.00 10960.00 1 RTPREI 10650.00 10960.00 :.•..:..:... :..1:...RMFAP.RE1.... ..:, ....., ,., 10.650.00. 1.0960.00 :.....:.:. VA :10650:'A0 1096.0.00< IO10960 0' .. o'1 650 0 .'00 ;..:: •.::... ] 1 :SMO. 1d 50. 0 1 960;00 :..:::..•>::1>: Ii '1LG001 _ 0610960 50.0q .'00 .10960.00 1...HVOL0011 10660.00 2 1 HWT0011 10650.00 10960.00 1 PHIE0011 10650.00 10960.00 1 PSX00011 10650.00 10960.00 1 SBEX0031 1 SBGP0011 1 SBGR0011 1 SBND00ll 10650.00 10650.00 10650.00 10650.00 1 VDCL0011 10650.00 1 VDOL0011 10650.00 1 VSH0011 10650.00 1 PHIT0021 10650.00 1 PSWO021 10650.00 1 RKG0011 10650.00 0.50 5.17188 7.83131 2 LISEDT 10184306 0.50-.828125 1.83131 2 LISEDT 10184306 0.50 54.4375 125:125 2 LISEDT 1:0.184306 0.5 -289.. 0 713 _ 5. 13 940 `` 2 D ., LISE T 3.:a $. `0 1 4 3 0.50 5:69977 62.5991 .2: LISPDT_ 1:01843:06.. >: 0450 11.691367.4252. OO OUO 2 LISEDT! 1p164306 ... 0.50-1.91576 71.8206 2 LISEDT 10184306 0.50 1.89204 3.01993 2 LISEDT 10184306 0.50 1.46496 2.68161 2 LISEDT 10184306 0.50 2.72656 51.8750 2 LISEDT 10184306 0.500.808281E-01 878.170 2 LISEDT,..,...1.0184306.,......,.. 10960.00 050... 7, -0 . Q 61.73E 1 9 l 7: 47 ,. $ � .. '' ? _L:T SEDT: , 10 8 1.. 0.500 .6109Q8E-0.10.171280 . .. 2 L ISE13'I''; ...... :01843:06 0:50x36.1500:' 0.556250 2 W SEDT 1016 3;06 0 50-999.-250. • 2 00.00 0 . 2 tIEED '�. 1q 8 �. x.306 0.500.000000E+00 16.1555 2 LISEDT 10184306 0.500.000000E+00 11.3762 2 LISEDT 10184306 0.500.000000E+00 22.7198 2 LISEDT 10184306 0.50-100.000• 17.8379 2 LISEDT 10184306 0.50-9.99.25.0:>. ;.303E:76. 2 :.I;ISEDT;.> I.OJ 8:43QG...::;: o.50 445 25.0 :2.9.1433 ::;'. 2 to 'SEI'';, ......... 1:0184':305 959.250' 0:.72064$ .: ' 2 %:ISEDT`: J::01$?1.3:06 0:5:0-99.9.250 T999 2 LI'SEt�T: ....... ...... ...............:.: 1:g18:430�: 0.50499'9.250' u999:250 ' 2 LISEDT. 1:'0i$¢�.06 :. 10960.00 0.50-999.250 103.976 2 LISEDT 10184306 10960.00 0.50-999.250 -999.250 2 LISEDT 10184306 . 10960.00 0.50-999.250 100.000 2 LISEDT 10184306 10960.00 0.50-999.250 100.000 2 LISEDT 10184306 1096q '00 0.5:0--999'.2501" OO OUO : 2 IS T:::::: 1;0184 :06:::.... 109G0',00 0.54 15:.10.9:,; L00'OAOh:z:EATi: 10960:.00 .,. 6 5a0:0 '0000'0+00 100:000 .>::< 2 10960.00 0.50-999.250 58.3182 2 LISEDT 10184306 10960.00 0.50-999.250 11.9375 2 LISEDT 10184306 10960.00 0.500.000000E+00 100.000 2 LISEDT 10184306 10960.00 0 50 999.250 100.000 2 LLSEDT. 101843.06 L'9G0!p0 a.'S. 41.554 a,:063:a6 1;0960';a0 I'. 0 5q 999<; 250 > '.195 �89 : 2 LISEtIT'; 101843'06 . 1:0960.'00....' 0..q 09.0 '9��..769 LISEDT. 1:018':OG 1U96000 f.:: 0:50 999; 25Q:, 160*'305 2 .SEIa' 1:0184:3:06 :< 10960:00 0.50-899.250 32.0093 2 LISEDT 101$4306 10960.00 0.50-999.250 27.7691 2 LISEDT 10184306 10960.00 0.50-999.250 17.8379 2 LISEDT 10184306 10960.00 0.50-999.250 58.4358 2 LISEDT 10184306 1ko9,0:9.0 a:,5:0999:250::: ;:64;::.077.0 .:: .. ...::.2::.L..1SEDT::. 10960:,00 0 5'0 999. 25q ;10q 00q 2 LY!EE1T! 1fS1843,06 10950:00 0.5:b 3.2$13; 6$»0:89 ,: LT.SEDT::. 16184':06 TOTAL NUMBER OF HEADER AND DATA RECORDS IN THE DATA FILE = 96 , AVAILABLE RECORDS = 3685 *** PLOT NUMBER AT TERMINATION OF THIS JOB IS 0 *** 27 ***** MSP JOB BESEAL M HAVING TASK NAME C8F3840306101740 CURRENT NUMBER OF ACTIVE TASKS IS 0 *** PROGRAM MSPOFF COMPLETED WITH A CODE OF 0 **** *** TOP RFCWAT.IG WTTu ruAr. Air) C7 nne.ZG CTro Air) d e 28 *** START OF MSP PROGRAM SLMLIS• FROM LIBRARY PSD.XLIB PROGRAM STATUS INDEX= 12084240 MSP TASK ID C8F3840307143749 *** THE FOLLOWING CARDS HAVE BEEN INPUT TO THIS PROGRAM (MSP STEP NUMBER 3) , PROJECT NAME = WLSTST 1� /t CONTENTS 1 2 3 4 5 6 7 8 .12345678901234567890123456789012345678901234567890123456789012345678901234567890 CARD 1 &SLMLIX &END CARD 2 &SLMLIS TAPE=2,&END DICTN,NREC FILE XSAMP,TOP OR BOT CARD 3 &PARM SCAN=1,&END GEN=1066815,START=-1,PRINT=1, 1� MINIT COMPLETED AFTER READING 3 CARD(S) ***** PROGRAM = SLMLIS NUMBER = A06 SETSSI = 12084240 *** MSP SYSTEM PRINT FLAG SET EQUAL TO -1 AT THIS POINT IN PROGRAM **** DDNAME=FT49F001 NUMTRK= 38 TRKSIZ=13030 DEVTYP= 4 UNIADR= 967 CURVAL=MS4629 ITYPE= 2 f 23 *** START OF MSP PROGRAM MSPON FROM LIBRARY EPD.SYSTEM PROGRAM STATUS INDEX= 17183053 MSP TASK ID 0000000000000000 *** THE FOLLOWING CARDS HAVE BEEN INPUT TO THIS PROGRAM (MSP STEP NUMBER 2) , PROJECT NAME = WLSTST CONTENTS 1 2 3 4 5 6 7 8 .12345678901234567890123456789012345678901234567890123456789012345678901234567890 CARD 1 . &MSPON &END MINIT COMPLETED AFTER READING 1 CARD(S) ***** PROGRAM = MSPON NUMBER = S33 SETSSI = 17183053 *** PINT INTERFACE PLOTTING HAS-BEEN SELECTED FOR HOST PLOTTER = VERSATEC *** *** ACROSS = 23.0, ALONG =********, PAPER NUMBER = 500 *** PEN1 = 4BLK, PEN2 = 3RED, PEN3 = 2BLU, PEN4 = 1GRN, *** *** PINT/VAMP PARAMETERS ARE: WIDTH = 23.0 PROD =P CORD =Y *** *** DATA FILE ALLOCATION FOR THIS JOB (NREC) IS 3781 MSP RECORDS. *** ***** MSP JOB WLSTST STARTED HAVING EXTENDED TASK NAME H3/84.307/14:37:49 CURRENT NUMBER OF ACTIVE TASKS IS 1 *** PROGRAM MSPON COMPLETED WITH A CODE OF 0 **** *** JOB BESEAS4@ WITH CHRGE NO. 57,00666 STEP NO. 2 ON SYSTEM C033 AT 14:37:50 USING 224K/6776K BYTES MEMORY *** 22 THE TRACE DATA STRINGS WILL HAVE THEIR NAMES DERIVED FROM SCHLUMBERGER FIELD NAMES. GENERATION NUMBER =-2048 START SEQUENCE = 1 *** FT42F00l OPENED *** REEL HEADER LENGTH: 132 BYTES REEL NAME: 135882 SERVICE NAME: EDIT DATE: 84/01/25 REEL CONTINUATION NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: LIBRARY TAPE TAPE HEADER LENGTH: 132 BYTES TAPE NAME: 8948 SERVICE NAME: EDIT DATE: 84/01/25 TAPE CONTINUATION NUMBER: 01 PREVIOUS TAPE NAME: COMMENTS: LIBRARY TAPE END OF FILE MARKER NO. 1 * * * * * * * * * FILE HEADER LENGTH: 64 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: 1024 BYTES PREVIOUS FILE NAME: WELL SITE INFORMATION RECORD *** COMPANY: CHEVRON USA INC WELL: SCU 23B-3 FIELD: SOLDOTNA CREEK UNIT DATA FORMAT SPECIFICATION LENGTH: 748 BYTES ENTRY BLOCKS TYPE 4 8 9 * * * * * * * * * * * * * * * * SIZE REP CODE ENTRY 1 66 1 4 73 60 4 65 .1IN R E Alaska, oil & Gas Cons. Commission Anchorage 24 DATUM SPECIFICATION BLOCKS: ENTRY IC TOOL SVORD# UNITS API API API API FILE# SIZE EXP PROC SAM REP DEPT SHIFT 1 DEPT FT 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 2 SFLU DIL OHMM 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 3 ILM DIL OHMM 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 4 ILD DIL OHMM 00 OC 2E 00 0000 0004 0000 00 01 44 00 00000000 5 SP DIL MV 00 01 00 00 0000 0004 0000 00 01 44 00 00000000 6 GR DIL GAPI 00 1F 20 00 0000 0004 0000 00 01 44 00 00000000 7 DT BHC US/F 4C 34 20 00 0000 0004 0000 00 01 44 00 00000000 8 GR BHC GAPI 4C 1F 20 00 0000 0004 0000 00 01 44 00 00000000 9 SP BHC MV 4C O1 00 00 0000 0004 0000 00 01 44 00 00000000 10 NPHI FDN PU 5C 44 02 00 0000 0004 0000 00 01 44 00 00000000 11 DRHO FDN G/C3 5C 2C 00 00 0000 0004 0000 00 01 44 00 00000000 12 RHOB FDN G/C3 5C 23 01 00 0000 0004 0000 00 01 44 00 00000000 13 NCNL FDN CPS 5C 22 5C 00 0000 0004 0000 00 01 44 00 00000000 14 FCNL FDN CPS 5C 22 5D 00 0000 0004 0000 00 01 44 00 00000000 15 CALI FDN IN 5C 1C 03 00 0000 0004 0000 00 01 44 00 00000000 16 NRAT FDN 5C 2A O1 00 0000 0004 0000 00 01 44 00 00000000 17 RNRA FDN 5C 00 00 00 0000 0004 0000 00 01 44 00 00000000 18 GR FDN GAPI 5C 1F 20 00 0000 0004 0000 00 01 44 00 00000000 WLS TRACE DATA STRINGS FROM FILE 1 DEPTH UNITS ARE: FT DATA STRING >SFLU DIL < IN UNITS OF >OHMM< HAS A WLS NAME OF >SFLUDILI< DATA STRING >ILM DIL < IN UNITS OF >OHMM< HAS A WLS NAME OF >ILMDILI < DATA STRING >ILD DIL < IN UNITS OF >OHMM< HAS A WLS NAME OF >ILDDILI < DATA STRING >SP DIL < IN UNITS OF >MV < HAS A WLS NAME OF >SPDILI < DATA STRING >GR DIL < IN UNITS OF >GAPI< HAS A WLS NAME OF >GRDILI < DATA STRING >DT BHC < IN UNITS OF >US/F< HAS A WLS NAME OF >DTBHCI < DATA STRING >GR BHC < IN UNITS OF >GAPI< HAS A WLS NAME OF >GRBHCI < DATA STRING >SP BHC < IN UNITS OF >MV < HAS A WLS NAME OF >SPBHCI < DATA STRING >NPHI FDN < IN UNITS OF >PU < HAS A WLS NAME OF >NPHIFDNI< DATA STRING >DRHO FUN < IN UNITS OF >G/C3< HAS A WLS NAME OF >DRHOFDNI< DATA STRING >RHOB FDN < IN UNITS OF >G/C3< HAS A WLS NAME OF >RHOBFDNI< DATA STRING >NCNL FDN < IN UNITS OF >CPS < HAS A WLS NAME OF >NCNLFDNI< DATA STRING >FCNL FDN < IN UNITS OF >CPS < HAS A WLS NAME OF >FCNLFDNI< DATA STRING >CALI FDN < IN UNITS OF >IN < HAS A WLS NAME OF >CALIFDNI< DATA STRING >NRAT FDN < IN UNITS OF < HAS A WLS NAME OF >NRATFDNI< .DATA STRING >RNRA FDN < IN UNITS OF > < HAS A WLS NAME OF >RNRAFDNI< DATA STRING >GR FDN < IN UNITS OF >GAPI< HAS A WLS NAME OF >GRFDNI < 25 DEPTH MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE MNEMONIC VALUE 10982.000 SFLU 9.172 ILM 7.285 ILD 25.766 SP -51.188 GR -76.438 DT 78.625 GR -76.438 SP -51.188 NPHI -999.250 DRHO -999.250 RHOB -999.250 NCNL -999.250 FCNL -999.250 CALI -999.250 NRAT -999.250 RNRA -999.250 GR -999.250 10950.000 SFLU 17.313 ILM 4.500 ILD 3.949 SP -69.750 GR 79.500 DT 78.625 GR 79.500 SP -69.750 NPHI 22.363 DRHO -0.002 RHOB 2.348 NCNL 7024.000 FCNL 3372.000 CALI 5.273 NRAT 2.023 RNRA 2.082 GR -188.250 10900.000 SFLU 25.625 ILM 18.766 ILD 23.016 SP -69.125 GR 45.063 DT 80.875 GR 45.063 SP -69.125 NPHI 14.503 DRHO 0.004 RHOB 2.393 NCNL 5971.000 FCNL 3876.000 CALI 5.618 NRAT 1.518 RNRA 1.540 GR 46.883 10850.000 SFLU 6.895 ILM 6.160 ILD 6.691 SP -46.344 GR 129.500 DT 78.813 GR 129.500 SP -46.344 NPHI 29.218 DRHO 0.006 RHOB 2.512 NCNL 3005.719 FCNL 1182.281 CALI 6.136 NRAT 2.532 RNRA 2.542 GR 139.309 10800.000 SFLU 70.563 ILM 32.250 ILD 38.906 SP -64.750 GR 53.156 DT 72.375 GR 53.156 SP -64.750 NPHI 18.506 DRHO 0.085 RHOB 2.553 NCNL 6044.000 FCNL 3312.000 CALI 5.656 NRAT 1.788 RNRA 1.824 GR 62.531 10750.000 SFLU 14.648 ILM 10.281 ILD 10.398 SP -33.875 GR 89.938 DT 82.750 GR 89.938 SP -33.875 NPHI 36.230 DRHO 0.004 RHOB 2.404 NCNL 3733.750 FCNL 1292.000 CALI 5.862 NRAT 2.945 RNRA 2.930 GR 97.734 10700.000 SFLU 6.184 ILM 6.074 ILD 6.340 SP -41.625 GR 52.906 DT 80.813 GR 52.906 SP -41.625 NPHI 27.588 DRHO 0.060 RHOB 2.398 NCNL 3512.000 FCNL 1365.000 CALI 6.805 NRAT 2.461 RNRA 2.572 26 27 GR 58.750 10650.000 SFLU 6.336 ILM 6.574 ILD 7.098 SP -44.219 GR 55.031 DT 83.438 GR 55.031 SP -44.219 NPHI 28.223 DRHO -0.002 RHOB 2:330 NCNL 3754.000 FCNL 1508.000 CALI 5.801 NKAT 2.443 RNRA 2.488 GR 54.844 10600.000 SFLU 10.055 ILM 10.367 ILD 11.922 SP -34.000 GR 66.813 DT 89.188 GR 66.813 SP -34.000 NPHI 30.615 DRHO 0.011 RHOB 2.305 NCNL 3498.000 FCNL 1315.000 CALI 5.684 NRAT 2.596 RNRA 2.658 GR 75.375 10550.000 SFLU 7.277 ILM 7.691 ILD 7.910 SP -46.000 GR 44.281 DT 80.063 GR 44.281 SP -46.000 NPHI 28.419 DRHO 0.047 RHOB 2.385 NCNL 3416.500 FCNL 1312.125 CALI 7.142 NRAT 2.537 RNRA 2.603 GR 57.477 10500.000 SFLU 7.977 ILM 6.652 ILD 7.270 SP -41.000 GR 43.969 DT 79.688 GR 43.969 SP -41.000 NPHI 27.686 DRHO 0.033 RHOB 2.385 NCNL 3266.000 FCNL 1233.000 CALI 8.008 NKAT 2.545 RNRA 2.648 GR 45.469 10450.000 SFLU 6.805 ILM 6.082 ILD 6.246 SP -40.125 GR 45.688 DT 80.000 GR 45.688 SP -40.125 NPHI 27.080 DRHO 0.062 RHOB 2.429 NCNL 3777.875 FCNL 1492.125 CALI 7.136 NRAT 2.448 RNRA 2.531 GR 49.959 10400.000 SFLU 4.816 ILM 4.648 ILD 4.773 SP -50.750 GR 75.875 DT 81.250 GR 75.875 SP -50.750 NPHI 28.711 DRHO 0.058 RHOB 2.449 NCNL 3262.000 FCNL 1238.000 CALI 7.703 NKAT 2.590 RNRA 2.635 GR 78.625 10350.000 SFLU 13.492 ILM 8.477 ILD 9.297 SP -36.500 GR 76.875 DT 111.563 GR 76.875 SP -36.500 NPHI 36.230 DRHO 0.133 RHOB 2.350 NCNL 1764.000 FCNL 593.000 CALI 7.473 NRAT 3.043 RNRA 2.975 GR 78.875 10300.000 SFLU 2.617 ILM 2.131 ILD 2.076 SP -37.500 27 ' GR 54.469 DT 90.125 GR 54.469 SP -37.500 NPHI 32.615 DRHO 0.109 RHOB 2.351 NCNL 2760.312 FCNL 874.062 CALI 10.172 NKAT 3.052 RNRA 3.156 GR 58.008 10250.000 SFLU 3.863 ILM 3.803 ILD 3.787 SP -36.375 GR 64.125 DT 83.688 GR 64.125 SP -36.375 NPHI 25.163 DRHO 0.087 RHOB 2.422 NCNL 3253.875 FCNL 1309.875 CALI 9.180 NRAT 2.473 RNRA 2.487 GR 62.511 10200.000 SFLU 2.426 ILM 2.553 ILD 2.561 SP -38.125 GR 65.813 DT 92.750 GR 65.813 SP -38.125 NPHI 32.394 DRHO 0.044 RHOB 2.404 NCNL 2976.500 FCNL 948.094 CALI 10.126 NRAT 3.034 RNRA 3.139 GR 77.301 10150.000 SFLU 3.020 ILM 2.596 ILD 2.576 SP -37.875 GR 67.563 DT 89.063 GR 67.563 SP -37.875 NPHI 31.367 DRHO 0.063 RHOB 2.423 NCNL 3112.125 FCNL 1034.781 CALI 9.857 NRAT 2.942 RNRA 3.007 GR 68.973 10100.000 SFLU 3.934 ILM 3.836 ILD 4.016 SP -35.500 GR 76.125 DT 84.125 GR 76.125 SP -35.500 NPHI 29.113 DRHO 0.058 RHOB 2.479 NCNL 3106.937 FCNL 1030.375 CALI 10.867 NRAT 2.866 RNRA 3.015 GR 72.816 10050.000 SFLU 4.098 ILM 3.859 ILD 4.121 SP -30.750 GR 48.156 DT 87.938 GR 48.156 SP -30.750 NPHI 31.433 DRHO -0.008 RHOB 2.285 NCNL 3243.687 FCNL 1049.500 CALI 9.734 NRAT 2.938 RNRA 3.092 GR 44.109 10000.000 SFLU 2000.000 ILM 2000.000 ILD 16.891 SP 127.000 GR 35.969 DT 131.875 GR 35.969 SP 127.000 NPHI 49.388 DRHO -0.505 RHOB 1.981 NCNL 1486.375 FCNL 388.449 CALI 6.301 NRAT 3.691 RNRA 3.825 GR 39.223 9950.000 SFLU 2000.000 ILM 2000.000 ILD 16.734 SP 121.500 GR 24.359 DT 54.875 GR 24.359 SP 121.500 NPHI 47.870 DRHO -0.446 RHOB 2.134 NCNL 1569.922 28 FCNL 417.500 GR 33.125 9919.500 SFLU 2000.000 GR 22.297 NPHI -999.250 FCNL -999.250 GR -999.250 FILE TRAILER CALI 6.257 NRAT 3.605 RNRA 3.772 ILM 2000.000 ILD 17.109 SP 123.750 DT 88.125 GR 22.297 SP 123.750 DRHO -999.250 RHOB -999.250 NCNL -999.250 CALI -999.250 NRAT -999.250 RNRA -999.250 LENGTH: 64 BYTES FILE NAME: apo -ll a MAXIMUM PHYSICAL RECORD LENGTH: la pS BYTES NEXT FILE NAME: llllllllll END OF FILE MARKER NO. 2 TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: 8948 SERVICE NAME: EDIT DATE: 84/01/25 TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAME: COMMENTS: LIBRARY TAPE REEL TRAILER LENGTH: 132 BYTES REEL NAME: 135882 SERVICE NAME: EDIT DATE: 84/01/25 REEL CONTINUATION NUMBER: 01 NEXT REEL NAME: COMMENTS: LIBRARY TAPE END OF FILE MARKER NO. 3 * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * END OF FILE MARKER NO. 4 * * * * * * * * * * * * * * * * * 29 *** FT42F00l CLOSED *** 30 *** MSP JOB WLSTST HAVING EXTENDED TASK NAME H3/84.307/14:37:49 HAS 0 DATA STRINGS LISTED BELOW ***** NO DATA STRINGS STORED FOR THIS MSP TASK ***** *** PROGRAM SLMLIX COMPLETED WITH A CODE OF 0 *** JOB BESEAS O WITH CHRGE NO. S7,00666 STEP NO. 3 ON SYSTEM C033 AT 14:38:30 USING 224K/6776K BYTES MEMORY *** 31 t ** MSP JOB BESEAL2@ HAVING EXTENDED TASK NAME H3/84.306/10:06:15 HAS 17 DATA STRINGS LISTED BELOW ........ :::>:;::>:> :::::.:..:... _:. 'Ci2ACE_ DATA STRINGS r..... * * �k :. � *:*. *.......... 4�r * .. **. ** * * ** :.;...:;a.:'#'2.iidG...;..: :t.O GAN C fL,D -,,, WEf,L_ L4G .. CtIkVE: INF'oRMAT20N. N0. ,ftM *CREATION*: *::: (3EN * NAME -*TYPE*: 'TAPE' Ib » _ :UtV *UNIT: *UNIT * TOP * BOTTOM *SAMPLE* MINIMUM * ' MAXIMUM * OF * PROGRAM* DATE *' *(IWNAME) * * * NO. * * * * * INCR * *RECS* *********************************************************************************************************************************** 1 SFLUDILI 9919.50 10982.00 0.500.124023 2000.00 4 LISEDT 10084306 ILMDILI 9919.50 10982.00 0.50.1.8300,8 2000.00. 4.LISEDT •1 :::::•...........:<;1::: 1#11D1: 1 .::,.:: _ :: ... . .: 9919:50:J0982 00 0:500:783691 ::: 2000 '00 4 ....1.0084306.. 'LISEll'� ... 10.0$43Q6; :.::::.::::...:.:1&PDI,.. :: .. ...: 99 9:50:1Q98 2.044 0.50-7547500,...13 250 4>41 EDT 0 10 .$43 36.`. .• RIyII;�.......:.... .... ,:.. < 9915.50 10982:00; 0.50=-76.4375 139..000 4 IvISEDT 3 008430E ..:....:........:...... 9919 4 $0 10.982.00 A.50 51i8750 - 133:.625 4 LISEDT >L08843,Q6.. L...GEEHCI 9919.50 10982.00 0.50-76.4375 139.000 4 LISEDT 10084306 1 SPBHCI 9919.50 10982.00 0.50-75.7500 134.250 4 LISEDT 10084306 1 NPHIFDNI 9919.50 10982.00 0.50-999.250 66,7450 4 LISEDT 10084306 1 DRHOFDNI 9919.50 10982.00 0.50-32768.0 0.205078 4 LISEDT 10084306 RiiOBFDN] :..•.. ;:: 99.19...50::10982.0,0 ..0.50-3.2768,.0...,. , >,,2.,69159 .,...4, LISEDT.:,..: 1:0.0.84306..,:..:., :.:•::•:•:•:>•::.::.;.;..: ..:.:::::.:•.•:::::.:�; :. ...::..:.......� •..�: ..:•: ..� ;> 919 ... .: ,: 9 ,. •50 09$ 0 1 2.0 7C : 0 50 �2 $ 0 7.5 0 l 5.0 , 4.::L1S.... EpT `IOQB`4806:.;>.; '.: 919 50: 10982.0'tl 0.50=-.16896:.0 5048>00 4'' _ . LI:.D�' 1O.Q84306' .N.....:...:....:....:.........•:. :: - 99:9.:50:098.40 0:50.99.9.:250. x:3..5503 4 .LISEDT :': L'0Q$��Q6: : 1 <N ##A'I'itiN�...::.:•:•. •::.::: >: _. 9.919 50.1 as 9 00. 2. 0 : 999. 2 . 5 0 5 0 4'' 71 E .8 4 4; LTS. EDS' 1 O Q 6 4 3.0.6' : 1 ...... NRAFDNI 9919.50 10982.00 0.50-999.250 5.22266 4 LISEDT 10084306 1 GRFDNI 9919.50 10982.00 0.50-999.250 147.458 4 LISEDT 10084306 NUMBER OF TRACE DATA STRING HEADER AND DATA RECORDS IN THE DATA FILE = 68 V:1IYvASLE 1#MCONDS. 3713 ***** MSP JOB BESEAL2@ HAVING TASK NAME C8F3840306100615 HAS BEEN DELETED CURRENT NUMBER OF ACTIVE TASKS IS 0 *** PROGRAM MSPOFF COMPLETED WITH A CODE OF 0 **** I'.1.0.;.,.7.:11,,.,,,,.USI.NG 344K/56,56K,,.BYTES..,MEMORY 27 STEP PROCESS ELAPSED CPU SETSSI LIBRARY NUMBER NAME TIME(SEC) TIME(SEC) 1 Mt?JOB .8 0:06 13483264 EPD:VSM8p.'I'ESTLI8 2 MSPaN 3.6 0.11 10084150 EPD:VSMSP.TESTLIB 3 ;18FDX 44.9 4.90 11084237 PSD.XL113 4 MSPOFF 3.2 0.22 13184174 EPD.VSMSP.TESTLIB TOTALS 53.5 5.30 28