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Home My WebLink About160-0221a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Swanson River Field GL: 319' BF:N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 22" - 30' 13-3/8" J-55 1,349' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate N/A SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 17-1/2" Driven Surface 1650 sx Surface 1,349' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 348941 2480090 50-133-10138-00-00July 24, 1960 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 11/14/2022 160-022 / 322-567 N/A SRU 12-15September 15, 19602175' FNL, 1092' FWL, Sec 15, T8N, R9W, SM, AK 337' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORDSETTING DEPTH TVD 2480090 TOP HOLE SIZE N/A Sterling/Upper Beluga Gas Pool A028406 Date of Test: Oil-Bbl: N/A Gas-Oil Ratio: AMOUNT PULLED N/A 348941 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. PACKER SET (MD/TVD) Conductor N/A 1,349' MD / 1,349' TVD N/A 11,383' MD / 11,383' TVD 1,349' MD / 1,349' TVD N/A 2175' FNL, 1092' FWL, Sec 15, T8N, R9W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information - 54.5 30' Water-Bbl: PRODUCTION TEST N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 0 Flow Tubing WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 11:25 am, Feb 28, 2023 Abandoned 11/14/2022 JSB RBDMS 030823 JSB xGDSR-3/14/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval N/A N/A 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. INSTRUCTIONS Hemlock P&A Schematic, P&A Reports Authorized Title: Drilling Manager No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 2.28.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.02.28 11:13:02 -09'00' Monty M Myers P&A SCHEMATIC ( Updated by CJD2-28-23 SRF: TS 2-15 Well: SRU 12-15 PTD:160-022 API: 50-133-10138-00-00 SIZE WT GRADE CONN TOP BTM ID 22”Surf 30’ 13-3/8”54.5 J-55 8rd Surf 1,349’TOW 12.615” 7”23 N-80 Buttress 1649’4750’6.366” 7”26 N-80 Buttress 4750’6160’6.276” 7”29 N-80 Buttress 6160’7879’6.184” 7”26 P-110 8rd LT&C 7879’9627’6.276” 7”29 P-110 8rd LT&C 9627’11382’6.184” Tubing: 2-3/8”4.6 L-80 SC BT&C 1976’5,480’(cut)1.995” JEWELRY DETAIL NO.Depth Item 1 1508’DV collar 2 1640 13-3/8”bridge plug 10/5/22 3 1948’Cement Retainer 4 2498’Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/ 1,000 psi chem inj valve 5 3321’CIBP w/ 35’cement TOC @ 3286’10/25/21 RKB to TBG Head = 21.20’ 5 OPEN HOLE / CEMENT DETAIL 13-3/8”17-1/2” Hole: 97bbls of 15.3ppg cement pumped out shoe(ToC at 2500’ MDwith 30% washout). 170bbls of 15.3ppg cement via DV collar at 1508’MD. 7” 12-1/4” hole to 3395’ MD. 9-5/8” hole to TD: 12.9ppg mud in hole pre-cement. 114bbls 15.6ppg cement pumped out theshoe. 130bbls of 15.6ppg cement via DV collar at 8007’ MD. 11/17/96 CBL and USITshow free pipe above 5460’ MD (agrees with volumetric calculations) 2-3/8” 9/1/03: 121bbls of 15.8ppg Class G cement pumped through tubing punches at 5420’ MD. 9/2/03 SL temp log shows ToC at 2042’ MD. Suggested ToC from lift pressure = 2075’MDand volumetric calculation suggests 2500’ MD 12.9# Mud 12.9# Mud PERFORATION DATA DATE TOP BTM ZONE 9/25/22 2,604 2,610 Punch DID establish communication to OA 9/25/22 2,894 2,900 Punch No communication to OA 9/25/22 3,117 3,123 Punch No communication to OA 10/25/21 3,220 3,226 Sterling B5 10/12/21 3,372 3,380 Sterling B6U 1-11/16” Spiral- Isolated 10/25/21 10/22/20 3,393’ 3,399’ Sterling B6L 1-11/16” Spiral- Isolated 10/12/21 8/13/14 3,684’ 3,693’ Beluga (36-9A) 1-11/16” Shogun Spiral –Isolated Straight hole, Max angle = 1qq PBTD = 1,349’MD/TVD TD = 11,383’MD/ 11,382’TVD 1 2 3 7”cut at 1649’ MD ToC at 1700’ (volumetric) 4 TOW @ 1,349’MD Activity Date Ops Summary 8/3/2022 Upon arrival at SRU 12-15 All three strings were bleed to bleed tank. Tubing and IA were reading less than 25 psi. All bleed down fast. OA zero and confirmed no gas at bleed tank.,Pressure tested the 2.375” x 7” annulus to 2000 psi @ 12:43. 1950 PSI At 12:51. 13:10 1940 psi. MIT-IA PASS Did have a calibrated and recordable gauge. Found later that it did not record. No communication between the OA, IA, or tubing.,Hooked up to 7” x 13 3/8” annulus and pressure tested. No communication between strings. Slow bleed off, no sustained injectivity though 14:57 910 psi 15:02 900 psi 15:13 882 psi 15:28 866 psi,Bleed down to tank an tested OA again. Slow bleed off, no sustained injectivity again. 16:00 925 psi 16:05 922 psi 16:16 917 psi 16:58 905 psi.,Rigged onto 2.375” tubing. Pumped 60bbls (injected) at an estimated 1.5-1.75 bbls/min at 900-1000 psi. No response on OA 9/24/2022 AK Eline and pump operator on location. Open PTW and PJSM. Rig up AK Eline and pump truck, make up CBL tools. PT to 250/2500 per sundry.,Load tubing w/ 14 bbls produced water. RIH w/ 1.69" CBL tool. Tag plug @ 3280'. Pull CBL @ 40 fpm from 3280' to surface. Identify TOC @ 1998'.,Eline crew called to coil job at KBU 22-06Y. Lay down lubricator and tools and secure well. 9/25/2022 AK Eline & pump truck on location. Open PTW & PJSM. Rig up Eline. PT to 250/2500 psi.,RIH w/ 12' x 1.69" weight bar, CCL, & 6' x 1.59" Big Hole perf guns. 3' CCL to top shot. Come online w/ PW @ 1 bpm / 900 psi. Punch tubing to OA @ 3317' - 3123'. CCL stop depth 3114'. Pump 15 bbls and see no pressure increase on the OA. Swap to OA and pump 0.5 bbls and pressure up to 900 psi. No injectivity.,RIH w/ 12' x 1.69" weight bar, CCL, & 6' x 1.59" Big Hole perf guns. 3' CCL to top shot. Come online w/ PW @ 1 bpm / 900 psi. Punch tubing to OA @ 2894'-2900'. CCL stop depth 2891'. Pump 10 bbls bringing pressure up to 1900 psi. No response on the OA. Swap to OA and pump 0.5 bbls and pressure up to 900 psi. No injectivity.,RIH w/ 12' x 1.69" weight bar, CCL, & 6' x 1.59" Big Hole perf guns. 3' CCL to top shot. Come online w/ PW @ 1 bpm / 900 psi. Punch tubing to OA @ 2604''-2610'. CCL stop depth 2601'. (0 psi on OA, 100 psi on IA). Bring pump rate up to 2400 psi @ 2.2 bpm, see response on OA and open returns. Continue to circ out OA and rig down Eline.,Continue to circ out OA increasing pump rate to 2.7 bpm. Flowback 100 bbls fluid prior to 12.9# mud returns. Pump 353 bbls PW and take 307 bbls of returns to tank. 1:1 returns at end of pumping. (278 bbls OA volume from tubing punch @ 2604'). Final pump rate of 2.7 bbl/min @ 1400 psi. Note final IA pressure of 400 psi. 9/26/2022 Take on 350 bbls of produced water. Fluids management out of returns tank.,Pump truck operator on location. Open PTW & PJSM. Come online w/ PW pumping down the tubing taking returns out the OA pumping 3 bpm @ 1700 psi. Start seeing OA returns after 10 bbls pumped. (OA psi 0) Pumped total of 343 bbls of PW and took 327 bbls of returns.,Perform MIT-IA to 2000 psi. Lose 45 psi in 10 minutes. 1955 final IA pressure. (OA pressure 0) Rig down pump truck and secure well. Left return line on the OA until vac truck on location in the morning. 9/27/2022 Approve PTW and held PJSM,Prep location for 401. Cruz vac truck worked on hauling returns from rain for rent tanks to G&I.,Set containment and spotted beam and 401. Raised and scoped derrick, leveled rig and secured guy lines . Winch truck on location and set choke houses, pits, mud pump and koomey unit. Began sealing in containment. Organized and inventory parts trailer.,Spot generator, office trailer and communication tour. IT on location and hooked up comm's. Worked on part check list for BOP package. Secured location and SDFN. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: SRU 12-15 Swanson River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00107 SRU 224-10 PreDrill Spud Date: 9/28/2022 Held PJSM and obtained PTW Checked well Pressures Tbg/IA/OA = 0/0/0,Bled off flowline, Remover flowline and lock and tagout valves. Vac truck continued hauling mud returns from rain for rent tank. Finished sealing in containment,Set BPV and N/d Tree and riser. Clean and inspected lift threads all good. M/u Blanking sub,N/u 13-5/8" BOP package, R/u Kill and choke lines, Hooked up control lines and function tested Bop's,R/u work floor and drillers console, complete final torque up on stack. Built 2- 3/8" test joint. Filled pits with 8.6 PW Secured well SDFN 9/29/2022 Held PJSM, obtained PTW, warmed equipment Check well pressure IA/OA = 0/0,R/u testing eq. flooded stack and worked air out of the system. Shell test bop's 250-2500psi. Observed leak off at 1200psi.,Troubleshoot issue, found leak path at the hanger, L/d test jt. R/u lifting eq. to top of stack, broke bottom connection on stack, picked stack up with blocks, inspected hanger neck, added more teflon and retighten blanking sub and 1/4" plug in the control line port. Landed stack and torqued up connection.,M/u 2- 3/8" Test Jt, Flooded stack and shell tested Bop's 250-2500psi- good test.,Tested BOPE per sundry as following: Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi. Preformed Koomey Drawdown, tested gas detection and pit level indicator. 2 3/8" Test Joint was used. Tested fluid was 8.6 water. No failures during test. AOGCC Witness waived by Jim Regg via email 8/28/22 @ 5:49pm BLM Witness waived by Allie Schoessler via email 8/28/22 @ 3:07pm,R/d Testing eq. Pulled BPV tbg was static, M/u Landing Jt and handling tools, BOLDS and pulled hanger off seat 20k landed in slips with 1k in tension.,R/u EL, PT lubricator 250-2500psi, RIH w/Wt Bars , CCL and 1-11/16" jet cutter. CCL 5' from cutter. Come on w/pump held 100psi on tbg, CCL depth @ 1,971', Cut tbg @ 1,976'. Good communication with IA after cut. POOH L/d Cutter,R/u and pump down IA returns up Tbg, circulated 75bbls of 8.6 PW @ 3bpm/350psi. Returns 1 for 1. P/u 10" on Tbg and set in slips, P/u wt 6K,RIH w/Wt bar, CCL and 1-11/16" jet cutter #2. RIH and fired cutter @ 1976' to ensure 3/8" control is cut. POOH L/d tools and RDMO EL,Pulled hanger to rig floor, de-completed and L/d hanger and Landing Jt. secured control line. R/u power tongs and handling eq. Installed TIW and secured well. SDFN. 9/30/2022 Held PJSM, approved PTW. Warmed eq. Check well pressures, Tbg/IA/OA=0/0/0,POOH standing back 2-3/8" tbg, spooled control line. L/d cut piece. Visually inspected Tbg all good to use for as WS.,M/u 7" retainer and setting tool, RIH on stands, dropped ball. Pressured up and set retainer @ 1, 948'KB. P/u off retainer and PT t/1000psi, held for 10mins, good test on the retainer.,POOH standing back WS, L/d setting tool. M/u cement stinger, RIH stung in retainer spaced out stump on rig floor.,Held PJSM, R/u Hal cementers, PT 500/4000psi-good test, Pressured up and held 100psi on IA, Pumped dn Tbg returns up OA, catch full returns after 5bbls away. confirmed circ 2bpm/900psi. Mix and pumped 104.5bbls of 15.3 cement @ 3bpm, FCP 420psi, 103bbls returns up OA.,Closed OA and squeezed 10.5bbls 15.3 cement, worked rate .3 to .5bpm, 350-750psi. Pumped 7.5bbls displacement. SD pump. unsting from retainer, Pumped and Lay in 10bbls of cement on top retainer, SD pump, Est TOC @ 1700', R/D cementers,POOH slowly Standing back 8 stands to 1400'. Circulated TxIA STS. SD pump. Secured well SDFN 10/1/2022 Held PJSM and approved PTW,,POOH f/1400 t/surface. L/d cement stinger, M/u 2-7/8" RIH t/1443' and parked,R/u Test eq. CMIT IAxOA per sundry 1250psi, Max pressure on 13-3/8" is 1350psi Pre Test=0psi Initial = 1342psi 15mins = 1277psi 30mins= 1228psi,Consult OE, permission to increase max pressure to 1450psi. CMIT IAxOA. Results are inconclusive. Pre Test=0 Initial = 1432psi 15mins = 1345psi 30mins = 1290psi,R/d test eq. RIH and tagged TOC @ 1745'KB with 2k down. POOH standing back Tbg. L/d Mule shoe.,Secured well SDFN 10/2/2022 Held PJSM, approved PTW, warmed equipment SI well pressures IA/OA=0/0,R/u Mix tank and built 35bbls of 9ppg Brine. Vac truck on location and empty open top returns from cement job. Hooked up controls for 7" ram. Built 2-3/8" and 7" test joint .,Hooked up controls for 7" ram. Built 2-3/8" and 7" test joint . N/u 13-5/8" x 7-1/16" spool for EL to R/u,Released AAO crew at noon, waiting on approval from AOGCC to proceed with the RWO. 10/3/2022 Held PJSM, approve PTW Check well pressures IA/OA=0/0,Waiting on orders, verbal approval from state to proceed with cutting and pulling 7" csg. (Will verify testing Cement Plug before setting 13-3/8" CIBP),R/u Testing eq. to IA and OA. CMIT IAxOA per procedure to 1250psi. Initial=1449psi, 15mins=1383psi, 30mins=1343psi, 7.3% loss over 30mins.Bled off test pressure. Opened IA & OA and monitored for 30mins – verified no flow Shut-in IA & OA and monitored for 30mins- no pressure build.,MIRU EL, N/u 7-1-16" WL flange, Assembly 7" Jet cutter, P/u Wt bar, centralizer and 5.8" Jet cut for 7" csg, CCL to Cutter 6.1', RIH w/tools and set down @ 1,486', could not work tools down and no over pulls coming off of tag depth. POOH L/d cutter.,RIH w/1.69" Wt bar, 7" centralizer and CCL, worked thru 1480', fell free and tagged @ 1,645'. POOH, M/u Wt bar, CCL and 5.9" GB/GR, RIH worked tool f/1470' t/1530' cont RIH and Tag @ 1,647', worked tool to 1655'. Stop making hole, POOH L/d tool, GB full of green cement.,M/u Wt bar and 1-11/16" CCL, RIH tagged TOC @ 1,660'. POOH. M/u 5.8" Jet cut for 7" csg, CCL to Cutter 6.1', RIH tag TOC @ 1654', logged up to collar @ 1610', RIH parked CCL @ 1643', opened OA to pit, cut 7" csg @ 1649', observed fluid movement in OA . POOH, L/d tools. RDMO E/L,R/u circ eq. Lined up to pump down the IA with returns up OA, pumped 30bbls of 9ppg Brine balanced plug and displaced w/49bbls of 8.6ppg PW @ 3.5bpm/150psi. SD pump. Secured well and SDFN. 10/4/2022 Held PJSM, approved PTW Over night SI pressures, IA/OA=0psi Opened OA and IA, verified no flow,R/u testing eq. Shell tested BOP's 250-2500psi-good test. Tested BOP per Sundry as following: Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi, charted for 5mins, 1 F/P on K2, cycled and retest was good, preformed Koomey drawdown and closure times, N/T on gas detection (Tested 9-29-22). 2-3/8" and 7" test jt was used. AOGCC and BLM witness was waived.,R/d Test eq. and drained stack, R/d stairs, handrails and work floor. Vac out rain water from cellar.,Held PJSM discussed removing stack and prep wellhead to pull 7".,Removed BOP's and Tbg head from wellhead, pulled snap rings and seal plate, welded in slip segments to 7" csg.,M/u 13-3/8" x 13-5/8" DSA, Installed BOP stack and torqued connection. R/u work floor, handrails and stairs,R/u testing eq. Shell tested BOP stack 250/2500psi and charted 5mins.,P/u handling tools, M/u 7" spear with stop (4'swallow) and Landing Joint. Engaged spear and pulled 7" csg free @ 40k, landed in slips and installed TIW. Secured well SDFN. 10/5/2022 Held PJSM and approved PTW, warmed eq. Shit-in pressures IA/OA=0/0psi Opened well verified no flow.,Pulled 7" Csg to floor, BO/LD spear, R/u Parker's csg handling eq,,POOH L/d 43joints of 7" Csg and cut joint, filled hole with 8.6ppg PW for displacement,R/d Parker Csg eq. R/u 2-3/8" Handling tools,M/u setting tool and 13-3/8" Bridge Plug, RIH on 2-3/8" tbg and tagged casing stump @ 1,649', P/u to 1,640', dropped ball. R/u head pin and kelly hose, pressured up on Tbg to 2800psi and set the bridge plug @ 1,640'. L/d circ eq.,L/d circ eq. P/u and RIH tagged plug @ 1640', set down entire string weight (5k) down to verify set. POOH standing back 2-3/8" tbg, L/d setting tool. Secured well and SDFN. 10/6/2022 Held PJSM and approved PTW, warmed eq.,M/u 2-3/8" Mule Shoe, RIH on 2-3/8 wk string from derrick, Tagged 13-3/8" CIBP @ 1,640'. Set down 5k (entire string weight) and verified plug integrity. AOGCC inspector Kam StJohn witness tag.,P/u 4" and wait on cement crews to arrive, crew preformed rig maintenance and housekeeping,MIRU Hal cement, pumped 5bbls down tbg, returns up OA. PT 500/3000psi- good tested, Mix and pumped 39bbls of 15.3ppg cement @ 2bpm/25psi. Pumped 3.5bbl FW displacement, returns 1/1. Washed up cement eq. RDMO cementers Estimated TOC @ 1,400',POOH slowly w/2-3/8" wk string f/1635' t/1300', pipe was dry, circulated tbg clean. Vac truck emptied return tank and hauled to G&I,POOH L/d 2-3/8" tbg f/1300' t/surface.. and remining stands in derrick.,R/d handling eq. Cleaned and cleared rig floor, R/d stairs, handrails and work floor 10/7/2022 Held PJSM and approved PTW.,Blow down circulating lines and R/d same. N/d 13-5/8" BOP Stack and N/u the dry hole tree,Prep rig, Scoped and lay down derrick. R/d associated equipment and moved to SRU 32-33WD. Picked up containment and clean location . End of Predrilling workover ops. Activity Date Ops Summary 11/7/2022 Continue evacuating all fluids from mud pumps and removing equipment from rig floor. Button up Generator 3 and prep for move. Remove torque tube bushing for top drive extension, bring TD carrier to rig floor and remove top drive from blocks and set in carrier.;R/U and move Top Drive from rig floor to catwalk. Travel to Swanson to evaluate location. Prepare lower section of torque tube to travel down catwalk when scoping derrick down. Remove T-Bar from torque tube. Loader prepping location at SRU 224-10 for setting up rig footprint.;Remove Generator 3 and set on trailer along with fuel tank. Take down Centrifuge tent and remove windwalls from pits with crane. Connect bridle lines and scope derrick down to half-mast laying lower torque tube on catwalk. Prepare derrick for laying over, hang blocks, unspool drilling line and;cut 9 wraps, lay over mud gas separator, wrap and tie up kelly hose and service loop, break over exhaust pipe on HPU, remove brake linkage, unpin A legs and lay over mast on headache rack. Remove clamshell, centrifuge with crane. Lay over V-Door onto catwalk;Rig crew traveled to SRU 224-10 and laid felt, liner, and spotted rig mats.;Lower roof top on mud pits. Removed Handy berming around the rig. Prepped derrick to be removed from carrier. Secured misc. items through out the rig for travel. Circulating boiler water to cool down. Finish unplugging Pason cables, cameras, Gai tronics, and all electrical wires through out;the rig. Scoped in and lowered dog house in water tank. Removed all light from module roofs. Folded up walk ways, removed stairs, and cont. removing snow through out the rig.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 0 bbl Hauled: 0 bbl Fluid to KGF G&I Cumulative: 0 bbl Hauled: 0 bbls of cmt to KGF G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 11/8/2022 Circulated water in boilers to bring temperature down and evacuate water. CCI picking all three pit modules, mud pump #2 module, accumulator/ water tank/ doghouse module transporting to Swanson River. Set up crane and remove iron roughneck, choke house and lay over v-door windwall and lower derrick;windwalls. 48 hour notice given to AOGCC and BLM for diverter test.;When trucks arrive back remove mud pump #1 module, generator module, Rig HPU and boiler house module. Set cranes and remove mast from draworks module and set on trailer and secure, move drilling line spool to same trailer and secure.;Load and transport Draworks skid, and mud pump, gen skid, pony sub and mats to Swanson river, clear snow and ice from mats and liner;Set remaining mats on liner, set pony subs over well, install lights on buildings prep f/ rig movers to set rig, transport remaining equipment from beaver creek to Swanson river 11/9/2022 Evaluate loader incident and ensure loader operator is good. Make notifications as per policy for incident. Rigging ordered to retrieve loader from ditch. Cranes rig up on pad, bring subbase and set on pony subs with cranes. Receive notification that the draworks skid was dropped 3' last night when;moved to staging pad from beaver creek. Observe damage to draworks skid and arrange to ship to CCI shop for complete evaluation and repair.;Retrieve loader from ditch and set upright on road. Decision was made to stand down for the rest of the day and have meeting on events and communication of the plan forward and expectations before work continues.;Crews cleaning up Beaver creek pad, prep to move offices, work on draworks skid, wait on inspectors in morning, hold safety stand down with all crews. 11/10/2022 Continue with Safety standown. DSM, Tool Pusher and Hilcorp Safety attend meeting with CCI support crew to discuss recent events and plan forwards to avoid any more incidents. Meet at Swanson River operations office with Key personnel and agree to action items to be implemented.;Travel to rig site and restart spotting mud pit modules #1 and #2, Place jig in place and bring in mud pit module #3, Place Mud Pump #2 in place first due to tight location, Place mud pump #1, Set up cranes and install draworks skid on sub, set HPU, Hoist derrick and install on draworks skid.;Set choke house and raise wind wall, set IR in, Spot water tank/doghouse, spot in gen skid, hook up interconnects get gens fired up and get lights up, get air compressor, pump hydralic oil into rig HPU, function and bleed air out of system, raise pit rooves, raise doghouse into drilling position.;Prep and raise mast, hook up rig floor and pit systems, continue hooking up modules, install drive shaft and break linkage, install lights around rig, lay felt liner and mats for catwalk, haul in equipment for rig up and stage for crane, prep derrick to scope up 11/11/2022 Continue to rig mud tanks, pumps, Generator #3 and set windwalls for pits. Install tarps across rig. Crane set in centrifuge and rig up same. Set in boiler house and replace bad lines and connect air heater to warm up system. Spool up drilling line and slip on 9 wraps. R/D camps at BCU. Secure upper;torque tube to mast. 1-1/2 gallon antifreeze spill from bed truck at staging pad with failure to hose.;Continue rigging up boilers, spot mud gas separator with crane and rig up. Continue rigging up mud tanks, inspect derrick and prepare to scope up, Spot and rig up catwalk with assistance from crane. Spot camps and connect electrical lines and receive comms at 19:00 hours. Hook up Pason, Install;stairs on safety shack. Spot mechanical building and hook up electrical lines.;Raise gas buster and hook up , Scope up Derrick Pin torque tube and Prep t/ P/U top drive, P/U top drive and remove from cradle, spot in third party shacks, build mud docks, build steam pressure staging up, take on water to rig tank.;M/U torque bushing, R/U top drive service loop and kelly hose, function test top drive, install saver sub and clamp, install bales and elevators, change oil on top drive gear box, work on rig acceptance checklist. 11/12/2022 Continue bringing mud and equipment from staging pad and get location ready for operations, Change oil in Top Drive swivel, Gear box. Oil and filters on right angle drive and floor motor. Change out Hydraulic IBOP on Top Drive. Function test MP #1 and MP #2, Change agitator in pit #5.;Pressure test all surface lines and stand pipe, Blow down all lines. Continue offloading mud products from staging area and set on docks. Continue working on rig acceptance checklist. Remove wellhead with wellhead rep., install new wellhead, test plug and 2' spacer spool. Spacing too short for vent;line wellhead rep travel to shop for another spool. Building 6% KCL 9ppg mud.;N/U diverter assembly, N/U spacer spools, DSA and Diverter T assembly, set annular tighten bolts, install knife valve and joint of vent line, set line anchors, M/U koomey lines and set in riser, riser wouldn't fit needs 6'' cut off it, take out riser and send to weld shop.;Charge koomey unit, get test joints and DP to location from staging pad, set test joint M/U to test plug, Perform Function test of Diverter system. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: SRF SRU 224-10 Swanson River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00107 SRU 224-10 Drilling Spud Date: 11/13/2022 Perform Diverter test, Knife valve opens in 2 seconds, 21-1/4" Annular Preventer closes on 4-1/2" test joint in 40 seconds. Vent Line 156', Outlet F/ subbase 144', Closest ignition source 86'. Move crew safety meeting camps, electrician shop & mechanic shop away to clear regulation restrictions.;from end of vent line. Riser taken to CCI shop to get trimmed. Contact Swanson control room to get flair pilot distinguished. Pilot has been shut off. Complete 600 BBLs of 6% KCL 9.0ppg WBM. Rig accepted at 06:00.;Pull test plug and install 15-1/2" wear ring and RILDS (2). Rack and tally 4-1/2" CDS40 HWDP, install bell nipple returned from welding shop, install flow line and secure.;P/U and RIH with stack washer sub with HWDP T/ 548', POOH and stand back HWDP., break off stack washer.;RIH w/ stack washer P/U DP singles f/ surface t/ 1211' POOH standing back DP in derrick, clear floor.;Get scraper BHA to floor, get OD's and ID's and lengths on all equipment, load racks w/ DP.;M/U scraper BHA and 12.25'' Bit, Bit sub and crossover, RIH P/U DP Tag cement @ 1365' POOH Stand back DP, RIH P/U DP singles t/ 1250'. 11/14/2022 Displace well with 6% KCL 9.0ppg WBM at 1364', Stop and screen down F/ 140's T/ 120's for higher flow rate Circulate at 8BPM with 300psi. continue circulating until good mud returned.;Washed and reamed at 40 RPM and TQ 6K, clean out F/ 1365' T/ 1387' when torque increased stopped and let it mill off. P/U and CBU at 1384' until returns cleaned up GPM 380, SPP 390psi. Slack off and verify 15K down at 1387'. P/U 42K S/O 40K.;POOH with 13-3/8" scraper assembly standing back drill pipe and L/D scraper assembly.;P/U and M/U 6-1/2" spiral drill collars and stand back in derrick.;PJSM on picking up and assembling 13-3/8" whipstock assembly, load all components to rig floor, P/U Tri-Mill assembly and set in hole. P/U and M/U 6-5/8" Flex Joint, XO, UBHO, XO and lift sub. POOH and scribe mill assembly with BOLT hole lower in hole, Lower back in hole and confirm scribe.;B/O lift sub and Gyro hand orient UBHO sub with scribe. M/U lift sub and stand mill assembly back in derrick. P/U whipstock and unable to get the shipping pins drove out of the anchor assembly. Lay down and P/U backup whipstock.;P/U back up Whip stock Pull pins and, M/U to Mill assembly, install 35k shear bolt as per WIS rep, RIH w/ BHA f/ derrick t/ 1383' fill pipe blow down top drive.;R/U Yellow Jacket Eline Hoisting GyroData tools RIH, orient whip stock t/ 3.02 POOH R/D ELine.;M/U Stand, Slack off and set down 1388' set down 19k to shear trip anchor, verify set, set down 41k to shear bolt on whip stock TOW 1349' BOW 1371' , get pumps up to speed and establish parameters.;Mill window f/ 1349' t/1357' 550 gpm 560 psi 86 rpm 6.7k tq on bottom 6k WOB time drill 1 ft per hour 550 lbs of metal recovered.;Hauled: 0 bbl Solids to KGF G&I Cumulative: 0 bbl Hauled: 165 bbl Fluid to KGF G&I Cumulative: 165 bbl Hauled: 0 bbl Cement to KGF G&I Cumulative: 0 bbl Lost: 0 bbl Fluid Down Hole Cumulative: 0 bbl Daily Metal: 0 lbs Cumulative: 0 lbs David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122 Log Print Files and Log Data Files: Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-14B 50133205390200 222057 11/5/2022 Yellowjacket SCBL HVB-16A 50231200400100 222070 7/30/2022 Yellowjacket SCBL NCI B-03A 50883200950100 222048 9/22/2022 AK E-Line CBL PAXTON 6 50133207070000 222054 7/23/2022 AK E-Line CBL S MGS Unit 6 (DI-06) 50733200420000 167052 10/6/2022 AK E-Line CBL SRU 12-15 50133101380000 160022 09/25/2022 AK E-Line CBL Please include current contact information if different from above. By Meredith Guhl at 12:59 pm, Nov 22, 2022 T37288 T37289 T37290 T37291 T37292 T37293SRU 12-15 50133101380000 160022 09/25/2022 AK E-Line CBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.22 13:28:54 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 15 Township: 8N Range: 9W Meridian: Seward Drilling Rig: Hilcorp 401 Rig Elevation: 19 ft Total Depth: 11383 ft MD Lease No.: FEDA 028406 Operator Rep: Suspend: X P&A: Conductor: 22" O.D. Shoe@ 30 Feet Csg Cut@ Feet Surface: O.D. Shoe@ Feet Csg Cut@ Feet Intermediate: 13 3/8" O.D. Shoe@ 3167 Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 11382 Feet Csg Cut@ 1649 Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 2 3/8" O.D. Tail@ 5480 Feet Tbg Cut@ 1976 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 1639ft 8.6 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Wade Hudgens Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Bridge plug set at 1639 ft in 13-3/8" csg right above 7" csg cut. Set down string weight of 5000 lbs slacked off the blocks retainer stayed in place. Plan forward pump 37 bbls cement on retainer to approximate depth of +-1400' October 6, 2022 Kam StJohn Well Bore Plug & Abandonment SRU 12-15 Hilcorp Alaska PTD 1600220; Sundry 322-567 none Test Data: Casing Removal: rev. 11-28-18 2022-1006_Plug_Verification_SRU_12-15_ksj CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Donna Ambruz; Noel Nocas; Katherine O"Connor; Wade Hudgens - (C) Subject:RE: SRU 12-15 RWO Path forward (PTD#160-022) Date:Wednesday, October 5, 2022 1:53:00 PM Ryan, Hilcorp has approval to proceed with the plan below, with the following condition: Set at least 15,000 lbs, or full workstring weight, whichever is less, on the plug to verify its location. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, October 5, 2022 11:38 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com>; Noel Nocas <Noel.Nocas@hilcorp.com>; Katherine O'Connor <Katherine.Oconnor@hilcorp.com>; Wade Hudgens - (C) <Wade.Hudgens@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: SRU 12-15 RWO Path forward (PTD#160-022) Bryan- Given the failed MIT on SRU 12-15, Hilcorp proposes the below amended procedure. Attached is a modified schematic to reflect this change. Please let us know if this approach is acceptable. Thank you, Status thus far: 9/30/22: Cement in 7” and in 7” x 13-3/8” annulus pumped to 1700’ (volumetric ToC) 10/1/22: Failed witnessed MIT. Pipe tag ToC in 7” at 1745’ MD 10/3/22: EL found ToC at 1654’ MD in 7”. EL cut 7” at 1649’ MD 27. Spear 7” casing, and pull from prior cut. In progress 28. RU and set 13-3/8” bridge plug at 1560’ MD ±1640’ MD avoiding collars. (May use EL, or pipe to set plug. TBD) 29. Stack weight down on plug to verify integrity (offer witness opportunity 24hrs in advance) 30. Lay in cement to 1400’ MD a. Must be at least up to 1,458’ MD to cover DV collar by 50’ per BLM b. Additional height to act as base of whipstock c. Planned volume = 25bbls 37bbls 31. RDMO rig 401 Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. PROPOSED SCHEMATIC ( Updated by CRR 10-05-22 SRF: TS 2-15 Well: SRU 12-15 PTD: 160-022 API: 50-133-10138-00-00 SIZE WT GRADE CONN TOP BTM ID 22” Surf 30’ 13-3/8” 54.5 J-55 8rd Surf 3167’ 12.615” 7” 23 N-80 Buttress 1649’ 4750’ 6.366” 7” 26 N-80 Buttress 4750’ 6160’ 6.276” 7” 29 N-80 Buttress 6160’ 7879’ 6.184” 7” 26 P-110 8rd LT&C 7879’ 9627’ 6.276” 7” 29 P-110 8rd LT&C 9627’ 11382’ 6.184” Tubing: 2-3/8” 4.6 L-80 SC BT&C 1976’5,480’(cut) 1.995” JEWELRY DETAIL NO. Depth Item 1 1508’ DV collar 2 ±1640 13-3/8” bridge plug 3 1948’ Cement Retainer w/203’ cement ToC 1,745’ 9/30/22 4 2498’ Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/ 1,000 psi chem inj valve 5 3321’ CIBP w/ 35’ cement TOC @ 3286’ 10/25/21 -- Continued on pg 2 -- RKB to TBG Head = 21.20’ 5 OPEN HOLE / CEMENT DETAIL 13-3/8”17-1/2” Hole: 97bbls of 15.3ppg cement pumped out shoe (ToC at 2500’ MD with 30% washout). 170bbls of 15.3ppg cement via DV collar at 1508’ MD. 7” 12-1/4” hole to 3395’ MD. 9-5/8” hole to TD: 12.9ppg mud in hole pre-cement. 114bbls 15.6ppg cement pumped out the shoe. 130bbls of 15.6ppg cement via DV collar at 8007’ MD. 11/17/96 CBL and USIT show free pipe above 5460’ MD (agrees with volumetric calculations) 2-3/8” 9/1/03: 121bbls of 15.8ppg Class G cement pumped through tubing punches at 5420’ MD.9/2/03 SL temp log shows ToC at 2042’ MD. Suggested ToC from lift pressure = 2075’ MD and volumetric calculation suggests 2500’ MD 12.9# Mud 12.9# Mud PERFORATION DATA DATE TOP BTM ZONE 9/25/22 2,604 2,610 Punch DID establish communication to OA 9/25/22 2,894 2,900 Punch No communication to OA 9/25/22 3,117 3,123 Punch No communication to OA 10/25/21 3,220 3,226 Sterling B5 10/12/21 3,372 3,380 Sterling B6U 1-11/16” Spiral- Isolated 10/25/21 10/22/20 3,393’ 3,399’ Sterling B6L 1-11/16” Spiral- Isolated 10/12/21 8/13/14 3,684’ 3,693’ Beluga (36-9A) 1-11/16” Shogun Spiral – Isolated - Continued on pg 2 -- Straight hole, Max angle = 1q PBTD =±3,286’ MD/TVD TD = 11,383’ MD/ 11,382’ TVD 1 2 4 3 7” cut at 1649’ MD ToC at 1700’ (volumetric) PROPOSED SCHEMATIC ( Updated by CRR 10-05-22 SRF: TS 2-15 Well: SRU 12-15 PTD: 160-022 API: 50-133-10138-00-00 JEWELRY DETAIL (Abandoned) --- Continued from pg 1 -- NO. Depth Item 3390’ CIBP set 10/12/21 with 10’ cement cap 3528’ CIBP with 35’ cement cap 10/14/20 4309’ EL CIBP 4912’ SL Packoff Plug with ToC at 4860’ MD 5399’ Macco 2-3/8” D-SO GLM w/1” dummy 5447’ Baker FH Ret packer, 2-3/8” X 7” 26# PERFORATION DATA -- Continued from pg 1 -- DATE TOP BTM ZONE 8/13/14 4,565’ 4,575’ Beluga (44-1) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,750’ 4,760’ Beluga (47-6) 1-11/16” Shogun Spiral - Isolated 10/30/13 5,000’ 5,015’ Beluga (50-6) 1-11/16” Shogun Spiral - Isolated 09/16/03 5,015’ 5,019’ Beluga (50-6) 1-11/16” PJ Spiral – Isolated 09/01/03 5,418’ 5,424’ Tubing punch MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 15 Township: 8N Range: 9W Meridian: Seward Drilling Rig: Hilcorp 401 Rig Elevation: Total Depth: 11383 ft MD Lease No.: FEDA028406 Operator Rep: Suspend: XXX P&A: Conductor: 22" O.D. Shoe@ 30 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 3167 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 11382 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 2 3/8" O.D. Tail@ 5480 Feet Tbg Cut@ 2000 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Retainer 1948 ft 1745 ft 8.6 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing NA NA NA IA 1342 1277 1228 OA 1342 1277 1228 Initial 15 min 30 min 45 min Result Tubing NA NA NA NA IA 1432 1345 1290 1247 OA 1432 1345 1290 1247 Remarks: Attachments: Wade Hudgens I Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Witness TOC tag with 2000 lbs of tubing stacked on cment plug - found at 1745 ft MD. First CMIT IAxOA deemed failure for falling below required test pressure, and also failed to demonstrate stabilization. Second CMIT lost 87 psi in 15 min, additional 55 psi at 30 min - total loss of 142psi in 30 minutes (10% of required test pressure) but didn’t show stabilization. Second test was held an additional 15 min losing 43 psi, declining below the required test pressure and did not exhibit stabilization. I directed the Hilcorp Company Man (Wade Hudgens) to get approvel from town prior to moving on to the next step. October 1st 2022 Brian Bixby Well Bore Plug & Pressure Test SRU 12-15 Hilcorp Alaska LLC PTD 1600220; Sundry 322-567 none Test Data: F Casing Removal: rev. 11-28-18 2022-1001_Plug_Verification_SRU _12-15_bb 9 9 9 9 9 999 9 9 9 9 Ã 9 9 9 9 9 9 6XQGU\ UHTXLUHVSVL WHVWSUHVVXUHMEU 9 1228 1228 1247 1247 First CMIT IAxOA Second CMIT James B. Regg Digitally signed by James B. Regg Date: 2022.10.03 13:25:42 -08'00' 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Subm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:401 DATE: 9/29/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #1600220 Sundry #322-567 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:1887 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.NA Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13 5/8" 5M P Pit Level Indicators P P #1 Rams 1 4 1/2" x 7" VBR NT Flow Indicator NA NA #2 Rams 1 2 3/8" Ram P Meth Gas Detector P P #3 Rams 1 Blind Ram P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 4 1/16" 5M P Time/Pressure Test Result HCR Valves 1 4 1/16" 5M P System Pressure (psi)3000 P Kill Line Valves 3 4 1/16" & 2 1/16" 5M P Pressure After Closure (psi)1800 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 0 NA Full Pressure Attained (sec)115 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 x 2100 P No. Valves 8 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 0 NT Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:3.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9/27/2022 4:22 PM Waived By Test Start Date/Time:9/29/2022 11:30 (date) (time)Witness Test Finish Date/Time:9/29/2022 14:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp 2-3/8" Test Jt was used. NT on Ram #1, will test before removing Tbg head and pulling the 7" Csg. Bottle Precharge - 1000 psi. Chris Hannevold Hilcorp Wade Hudgens SRU 12-15 Test Pressure (psi): wade.hudgens@hilcorp.com wade.hudgens@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0922_BOP_Hilcorp401_SRU_12-15 NT on Ram #1, will test before removing Tbg head and pulling the 7" Csg. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp 401 Date:Friday, November 18, 2022 4:32:07 PM Attachments:2022-0929_BOP_Hilcorp401_SRU_12-15.pdf Swanson River Unit 12-15 (PTD 1600220) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert Subject:RE: SRU 12-15 (PTD#160-022) Pre rig work: sat 9/24 Date:Friday, September 23, 2022 3:41:00 PM Attachments:SRU 12-15 AOGCC 10-403 PTD 160-022 Submitted 09-23-22.pdf Ryan, Hilcorp has approval to proceed with the pre-rig steps, steps 1-11 in the sundry submitted to AOGCC 9/23/22. FYI, the sundry number is 322-567 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Friday, September 23, 2022 2:26 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: SRU 12-15 (PTD#160-022) Pre rig work: sat 9/24 Bryan- Per our conversation, Hilcorp is requesting verbal approval to execute pre-rig wellwork on SRU 12- 15(PTD#160-022). This encompasses steps #1-11 in the pre-RWO (p3) section of the attached submission. Please advise. Thanks, Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/12/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 12-15 (PTD 160-022) GPT-PLUG-PERF 10/21/2021 Please include current contact information if different from above. 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´KJUZ&DPHURQ³+´%39SURILOH ¶ ´;´%7 &FURVVRYHU ¶ 0DFFR´602&&KHP,QM0GUO ZSVLFKHPLQMYDOYH ¶ &,%3Z¶FHPHQW72&#¶ ¶ &,%3VHWZLWK¶FHPHQWFDS ¶ &,%3ZLWK¶FHPHQWFDS ¶ (/&,%3 ¶6/3DFNRII3OXJZLWK7R&DW¶0' ¶ 0DFFR´'62*/0Z´GXPP\ ¶ %DNHU)+5HWSDFNHU´;´ & 0 7 V[ SXPSHG DERYH '9#¶ & ( 0 ( 1 7 '9# ¶ ¶72& #¶ VDQG &PW7RS#¶ VDQG VDQG 5.%WR7%*+HDG ¶ 7UHHFRQQHFWLRQ7&8QLEROW´%RZHQ $VDQG &PW7RS #¶ &PW7RS #¶ %8 %/ ´72& #¶ E\&%/ &PW7RS #¶ &PW7RS #¶ &PW7RS #¶ 3(5)25$7,21'$7$ '$7( 723 %70 =21( 7LHLQORJ 6FKOXPEHUJHU7'7 6WHUOLQJ% ´6KRJXQ6SLUDO2SHQ 6WHUOLQJ%8 ´6SLUDO,VRODWHG ¶¶6WHUOLQJ%/ ´6SLUDO,VRODWHG ¶¶%HOXJD$ ´6KRJXQ6SLUDO,VRODWHG ¶¶%HOXJD ´6KRJXQ6SLUDO,VRODWHG ¶¶%HOXJD ´6KRJXQ6SLUDO,VRODWHG ¶¶%HOXJD ´6KRJXQ6SLUDO,VRODWHG ¶¶%HOXJD ´3-6SLUDO,VRODWHG 3%7' ¶7' ¶ 6WUDLJKWKROH0D[DQJOH qq % 6WHUOLQJ% ´6KRJXQ6SLUDO2SHQ 6WHUOLQJ%8 ´6SLUDO,VRODWHG 6 OL ´ 6K 6 L O 2 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/09/2021 To: Department of Natural Resources Resource Evaluation 550 W 7th Ave, Suite 1100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 12-15 (PTD 160-022) Plug/Perf 10/12/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/09/2021 By Abby Bell at 5:09 pm, Nov 09, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: W hat Regulation or Conservation Order governs well spacing in this pool? W ill planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD): 4912', Junk (MD): 11,383'N/A Casing Collapse Structural Conductor Surface 1,130psi Intermediate Production 3,830psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: October 6, 2021 2-3/8" 11,382' Perforation Depth MD (ft): See Attached Schematic 11,382'11,382'7" 22" 13-3/8" 30' 3,167'2,730psi 30' 3,167' 30' 3,167' 4.6# / L-80 TVD Burst 5,480' 6,340psi MDLengthSize CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028406 160-022 50-133-10138-00-00 Swanson River Unit (SRU) 12-15 Swanson River Field - Sterling/Upper Beluga Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 11,383'3,493'3,493'1,382 4,309', 3,648' & 3,390' FH Packer; N/A 5,447' MD & TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:10 pm, Sep 23, 2021 321-503 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.23 11:30:59 -08'00' Taylor Wellman (2143) MITIA to 1500 psi required within 10 days for return to production post-perf to check integrity of cement packer above proposed perf zone. DSR-9/23/21 X X BJM 9/28/21 Provide 24 hr notice to AOGCC to witness MITIA. DLB 09/23/2021 10-404 dts 9/28/2021 JLC 9/28/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.28 13:23:45 -08'00' RBDMS HEW 9/28/2021 Well Prognosis Well: SRU 12-15 Date: 9-23-2021 Well Name: SRU 12-15 API Number: 50-133-10138-00 Current Status: Shut in Gas well Leg: N/A Estimated Start Date: 10/9/2021 Rig: E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-022 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) AFE Number: Maximum Expected BHP: 1536 psi @ 3,398’ TVD (Based on normal gradient) Max. Potential Surface Pressure: 1382 psi @ 3,415’ TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary SRU 12-15 was drilled by in 1960. During a workover in 2003, Unocal cemented the 2-3/8” tubing inside the 7” casing, creating a monobore with a cement packer. Hilcorp perforated the Beluga 36-9A, 44-1 and 47-6 sands in 2013, and set a pack off plug above these perforations in 2017. The Beluga was plugged back in 2020 and the Sterling B6L was shot returning the well to production. The purpose of this work is Plugback Sterling B6L and perforate and test the Sterling B6U and B5. BLM Variance Request Due to the close proximity of perforation intervals, Hilcorp is requesting a variance to BLM Onshore Order #2 Section G, 2, iii. Hilcorp requests to set a CIBP at 3390’ for isolation. Notes Regarding Wellbore Condition x Well is plugged back at 3493’ with a CIBP and cement cap. x Max deviation of 1 degree. x Temperature log ran 9/3/2003 indicates a top of cement in the 2-3/8” by 7” annulus at 2042’ MD. 120.9 bbls of 15.8 ppg cement was pumped through tubing punches at 5418’ on 9/2/2003 to cement in the 2-3/8” tubing string. Slickline Procedure 1. MIRU Slickline unit. 2. RIH with gauge ring (1.75” min OD) to tag plug at 3493’ SLM. E-Line Procedure 1. Operations to depress fluid level into open perforations with GL gas. 2. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low & 2500 psi high. 3. RIH with GPT and determine fluid level. 4. RIH to 3390’ and set CIBP 5. PU and RIH with 1-11/16” Shogun Spiral guns, 6 SPF. Proposed Perforation Intervals: Sand TOP MD BOT MD Total TOP TVD BOT TVD Sterling B5 3216 3238 22 3215 3238 Sterling B6U 3371 3380 9 3370 3379 -00 DLB Well Prognosis Well: SRU 12-15 Date: 9-23-2021 a) Proposed perforations are also shown on the proposed schematic in red font. b) Final Perforation tie-in sheet will be provided in the field for exact perforation intervals. c) Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d) Use Gamma/CCL to correlate. e) Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals after firing gun. f) The listed Sands are governed by Conservation Order 716.001. g) Sand intervals may be grouped or shot one at a time and flow tested to the system. If a sand makes water, then a plug or an isolation patch may be set prior to moving up to the next sand interval. 6. POOH. RDMO e-line. 7. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic MITIA to 1500 psi required within 10 days for return to production post-perf. bjm Updated by TCS 07-21-21 SCHEMATIC Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00-00 1 C M T C E M E N T SIZE WT GRADE CONN TOP BTM LENGTH 22”Surf 30’ 13-3/8”54.5 J-55 8rd Surf 3167’ 7”29 N-80 Buttress Surf 303’ 303’ 7”26 N-80 Buttress 303’1197’ 894’ 7”23 N-80 Buttress 1197’4750’3553’ 7”26 N-80 Buttress 4750’6160’1410’ 7”29 N-80 Buttress 6160’7879’1719’ 7”26 P-110 8rd LT&C 7879’9627’1748’ 7”29 P-110 8rd LT&C 9627’11382’1755’ Tubing: 2-3/8”4.6 L-80 SC BT&C Surf 5,480’(cut) with 3/8” methanol inj line from surf to 2498’ JEWELRY DETAIL NO.Depth Item 21.20’2-7/8” hgrw/Cameron “H” BPV profile 22’2-7/8” X 2-38” BT&C crossover 1 2498’Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/ 1,000 psi chem inj valve 2 3528’CIBP with 35’ cement cap 10/14/20 3 4309’EL CIBP 4 4912’SL Packoff Plug (capped w/ 52’ of cement) 5 5399’Macco 2-3/8” D-SO GLM w/1” dummy 6 5447’Baker FH Ret packer, 2-3/8” X 7” 26# C M T 800 sx pumped above DV @ 8007’ C E M E N T DV @ 1508’ 5 6 2-3/8’ TOC @ 2042’ 50-6 sand Cmt Top @ 5395’ Tag Fill @ 4,934’ 8/03/14 4 47-6 sand 44-1 sand RKB to TBG Head = 21.20’ Tree connection: TC-3 Uni-bolt (2.5” Bowen) 36-9A sand Cmt Top @ 4,860’ Cmt Stringers @ 4,804’ 3 Tag Fill @ 4,706’ Cmt Top @ 4,174’ Tag Fill @ 4,271’ 2 B6 7” TOC @ 5480’ by CBL Cmt Top @ 3,493’ PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 10/22/20 3,393’ 3,399’ Sterling B6L 1-11/16” Shogun Spiral -Open 8/13/14 3,684’ 3,693’ Beluga (36 -9A) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,565’ 4,575’ Beluga (44-1) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,750’ 4,760’ Beluga (47-6) 1-11/16” Shogun Spiral - Isolated 10/30/13 5,000’ 5,015’ Beluga (50-6) 1-11/16” Shogun Spiral - Isolated 09/16/03 5,015’ 5,019’ Beluga (50-6) 1-11/16” PJ Spiral - Isolated PBTD = 3,493’-TD = 11,383’ Straight hole, Max angle = 1qq Updated by MKR 09-22-21 PROPOSED SCHEMATIC Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00-00 1 C M T C E M E N T SIZE WT GRADE CONN TOP BTM LENGTH 22”Surf 30’ 13-3/8”54.5 J-55 8rd Surf 3167’ 7”29 N-80 Buttress Surf 303’ 303’ 7”26 N-80 Buttress 303’1197’ 894’ 7”23 N-80 Buttress 1197’4750’3553’ 7”26 N-80 Buttress 4750’6160’1410’ 7”29 N-80 Buttress 6160’7879’1719’ 7”26 P-110 8rd LT&C 7879’9627’1748’ 7”29 P-110 8rd LT&C 9627’11382’1755’ Tubing: 2-3/8”4.6 L-80 SC BT&C Surf 5,480’(cut) with 3/8” methanol inj line from surf to 2498’ JEWELRY DETAIL NO.Depth Item 21.20’2-7/8” hgrw/Cameron “H” BPV profile 22’2-7/8” X 2-38” BT&C crossover 1 2498’Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/ 1,000 psi chem inj valve 1A 3390’CIBP 2 3528’CIBP with 35’ cement cap 10/14/20 3 4309’EL CIBP 4 4912’SL Packoff Plug (capped w/ 52’ of cement) 5 5399’Macco 2-3/8” D-SO GLM w/1” dummy 6 5447’Baker FH Ret packer, 2-3/8” X 7” 26# C M T 800 sx pumped above DV @ 8007’ C E M E N T DV @ 1508’ 5 6 2-3/8’ TOC @ 2042’ 50-6 sand Cmt Top @ 5395’ Tag Fill @ 4,934’ 8/03/14 4 47-6 sand 44-1 sand RKB to TBG Head = 21.20’ Tree connection: TC-3 Uni-bolt (2.5” Bowen) 36-9A sand Cmt Top @ 4,860’ Cmt Stringers @ 4,804’ 3 Tag Fill @ 4,706’ Cmt Top @ 4,174’ Tag Fill @ 4,271’ 2 B5 B6U B6L 7” TOC @ 5480’ by CBL Cmt Top @ 3,493’ 1A PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 PROP 3216 3238 Sterling B5 TBD PROP 3371 3380 Sterling B6U TBD 10/22/20 3,393’ 3,399’ Sterling B6L 1-11/16” Shogun Spiral -Open 8/13/14 3,684’ 3,693’ Beluga (36 -9A) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,565’ 4,575’ Beluga (44-1) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,750’ 4,760’ Beluga (47-6) 1-11/16” Shogun Spiral - Isolated 10/30/13 5,000’ 5,015’ Beluga (50-6) 1-11/16” Shogun Spiral - Isolated 09/16/03 5,015’ 5,019’ Beluga (50-6) 1-11/16” PJ Spiral - Isolated PBTD = 3,493’-TD = 11,383’ Straight hole, Max angle = 1qq David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type SRU 11-22 50133206120000 213055 11/3/2020 PERF GAMMA RAY SRU 12-15 50133101380000 183032 10/14/2020 SET PLUG SRU 12-15 50133101380000 10/21/2020 PERF GAMMA RAY SRU 213-15 50133206520000 215100 6/25/2020 PERF GAMMA RAY/GPT SRU 241-16 50133205400000 204088 10/13/2020 PERF GAMMA RAY SRU 241-16 50133205400000 204088 3/30/2021 PERF GAMMA RAY KGSF 1A 50133101600100 220063 11/13/2020 PERF GAMMA RAY Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:21 pm, Jun 28, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type SRU 11-22 50133206120000 213055 11/3/2020 PERF GAMMA RAY SRU 12-15 50133101380000 10/14/2020 SET PLUG SRU 12-15 50133101380000 183032 10/21/2020 PERF GAMMA RAY SRU 213-15 50133206520000 215100 6/25/2020 PERF GAMMA RAY/GPT SRU 241-16 50133205400000 204088 10/13/2020 PERF GAMMA RAY SRU 241-16 50133205400000 204088 3/30/2021 PERF GAMMA RAY KGSF 1A 50133101600100 220063 11/13/2020 PERF GAMMA RAY Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:21 pm, Jun 28, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,383 feet 3528, 4309, 4912 feet true vertical 11,383 feet N/A feet Effective Depth measured 3,493 feet 5,447 feet true vertical 3,493 feet 5,447 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)2-3/8" 4.6# / L-80 5,480' MD 5,480' TVD Packers and SSSV (type, measured and true vertical depth)FH Packer; N/A 5,477' MD 5,447' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 6,340psi 30' 3,173'2,730psi Collapse 1,130psi 3,830psi Casing Structural 22" 13-3/8" Length 30' 3,173' 11,382' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 750 Casing Pressure Liner 1,566 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-398 480 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 160-022 50-133-10138-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Swanson River Unit 12-15 N/A FEDA028406 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field - Sterling/Upper Beluga Gas Pool, Beluga Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7"11,382'11,382' WINJ WAG 0 Water-Bbl MD 30' 3,173' 1,150 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:03 am, Apr 28, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.04.27 14:56:34 -08'00' Taylor Wellman (2143) BJM 7/21/21 3,167 DSR-4/29/21 RBDMS HEW 4/30/2021 SFD 4/28/2021 SFD 4/28/2021 3,167 Rig Start Date End Date 10/14/20 4/11/21 04/11/21 - Sunday Sign in and mobe to location. Start rig up and hose on the outrigger started leaking. We had it under containment so no spill. Call to town to have another crane brought out. Finished all we could rig up until crane showed up. Spotted crane and rigged up lubricator. PT to 250 psi low and 3,500 psi high. TP was 2,580 psi. Put 2800 psi of field gas and they said it broke over and settled about 2,630 psi. RIH w/GPT, JB/1.85" GR and tie into yellowjacket perf log. Found Fluid Level at 410', went on down hole and tagged at 3368'. Top of open perf is 3,393'. We set down going about 160fpm. Pickup up and pulled 5 to 600 lb over line weight. Tried 3 more times and didn't do any good and still getting the overpull on line. Its acting like sticky mud. Could very well be a bridge there. Logged out of hole. Rig down lubricator, secure well and turn well over to field. Discussed with Reservoir Engineer and Geologist the length of time since this well was returned to production. Decision made to close out Sundry as well has been performing above expectations. We will submit a new Sundry for the perforations already approved when the time comes to add them. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 12-15 50-133-10138-00-00 160-022 10/21/2020 - Wednesday Sign in. Mobe to location. PTW and JSA. Rig up equipment and lubricator. PT lubricator to 250 psi low and 3,000 psi high. TP - 1,085 psi. RIH w/ 1-11/16" x 6' Strip gun and tie into GR/CCL log. Run a correlation log and send to town. Told to shift up 2'. Spotted gun from 3,393' to 3,399' (6')with 1,085 psi. Fired gun and within a min pressure went to 1,150 psi. Picked up 5' and tools hung up. picked up 1,200 lbs over string wt and came free, did the same thing again after 8'. Got free and POOH. After 5 min from firing gun - 1,186 psi, 10 and 15 min - 1,184 psi. All shots fired and strip gun was wet. Rig down equipment and lubricator. Turn well over to field. TP - 1,185 psi. 12/07/2020 - Monday 10/14/2020 - Wednesday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT Lub to 250 psi low and 3,000 psi high. Tp - 450 PSI. RIH w/1.71" CIBP and tag at 3,538' tied in to Chem Man at 2,498. Ran a CCL/GR from 3,538' to 1,600'. Send to town. Set plug at 3,528' w/450 psi on well. Lost 100 lb line tension when plug set. Waited 5 min and picked up 20' and went back down and tag plug. POOH and bleed tubing to 0 psi. Mix cement and fill bailer. RIH w/ 1-11/16" x 20' and tag plug at 3,528'. Pick up and dump bailed 2 gals of 17 ppg cement on plug. POOH. Good dump. Made 2 more 1-11/16' x 20' bailer runs filled with cement and dumped on top of cement. Dump bailed 6 gals (35') total. CIP at 1430 hrs. Est TOC at 3,493'. Rig down equipment and turn well over to field. Spotted gun from 3,393' to 3,399' 10/27/2020 - MITIA to 1600 psi passed. See attached chart. bjm Fired gun a went back down and tag plug. Pick up and dump bailed 2 gals of 17 ppg cement on plug. Set plug at 3,528' w Dump bailed 6 gals (35') total. CIP at 1430 hrs. Est TOC at 3,493'. Updated by DMA 04-22-21 SCHEMATIC Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00-00 1 C M T C E M E N T SIZE WT GRADE CONN TOP BTM LENGTH 22” Surf 30’ 13-3/8” 54.5 J-55 8rd Surf 3167’ 7” 29 N-80 Buttress Surf 303’ 303’ 7” 26 N-80 Buttress 303’ 1197’ 894’ 7” 23 N-80 Buttress 1197’ 4750’ 3553’ 7” 26 N-80 Buttress 4750’ 6160’ 1410’ 7” 29 N-80 Buttress 6160’ 7879’ 1719’ 7” 26 P-110 8rd LT&C 7879’ 9627’ 1748’ 7” 29 P-110 8rd LT&C 9627’ 11382’ 1755’ Tubing: 2-3/8” 4.6 L-80 SC BT&C Surf 5,480’(cut) with 3/8” methanol inj line from surf to 2498’ JEWELRY DETAIL NO. Depth Item 21.20’ 2-7/8” hgrw/Cameron “H” BPV profile 22’ 2-7/8” X 2-38” BT&C crossover 1 2498’ Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/ 1,000 psi chem inj valve 2 3528’ CIBP with 35’ cement cap 10/14/20 3 4309’ EL CIBP 4 4912’ SL Packoff Plug (capped w/ 52’ of cement) 5 5399’ Macco 2-3/8” D-SO GLM w/1” dummy 6 5447’ Baker FH Ret packer, 2-3/8” X 7” 26# C M T 800 sx pumped above DV @ 8007’ C E M E N T DV @ 1508’ 5 6 2-3/8’ TOC @ 2042’ 50-6 sand Cmt Top @ 5395’ Tag Fill @ 4,934’ 8/03/14 4 47-6 sand 44-1 sand RKB to TBG Head = 21.20’ Tree connection: TC-3 Uni-bolt (2.5” Bowen) 36-9A sand Cmt Top @ 4,860’ Cmt Stringers @ 4,804’ 3 Tag Fill @ 4,706’ Cmt Top @ 4,174’ Tag Fill @ 4,271’ Tag Fill @ 4,058’ SLM 2 B6 7” TOC @ 5480’ by CBL Cmt Top @ 3,493’ PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 10/22/20 3,393’ 3,399’ Sterling B6L 1-11/16” Shogun Spiral - Open 8/13/14 3,684’ 3,693’ Beluga (36 -9A) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,565’ 4,575’ Beluga (44-1) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,750’ 4,760’ Beluga (47-6) 1-11/16” Shogun Spiral - Isolated 10/30/13 5,000’ 5,015’ Beluga (50-6) 1-11/16” Shogun Spiral - Isolated 09/16/03 5,015’ 5,019’ Beluga (50-6) 1-11/16” PJ Spiral - Isolated PBTD = 3,493’ - TD = 11,383’ Straight hole, Max angle = 1qq Superseded Data Collection Report Chassis Left Scale Right Scale Serial Number 476741 475325 688896 Datatype Lower Upper Units PSI G PSI G Lower Upper 0 0 0 0 0 1 1 1 1 1 1 0.0 500.0 1000.0 1500.0 2000.0 PSI GPSI G Elapsed Time hh:mm:ss 12-15 MIT IA - 27-Oct-20, 10:04:08, 252 PSI G PSI G Updated by TCS 07-21-21 SCHEMATIC Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00-00 1 C M T C E M E N T SIZE WT GRADE CONN TOP BTM LENGTH 22” Surf 30’ 13-3/8” 54.5 J-55 8rd Surf 3167’ 7” 29 N-80 Buttress Surf 303’ 303’ 7” 26 N-80 Buttress 303’ 1197’ 894’ 7” 23 N-80 Buttress 1197’ 4750’ 3553’ 7” 26 N-80 Buttress 4750’ 6160’ 1410’ 7” 29 N-80 Buttress 6160’ 7879’ 1719’ 7” 26 P-110 8rd LT&C 7879’ 9627’ 1748’ 7” 29 P-110 8rd LT&C 9627’ 11382’ 1755’ Tubing: 2-3/8” 4.6 L-80 SC BT&C Surf 5,480’(cut) with 3/8” methanol inj line from surf to 2498’ JEWELRY DETAIL NO. Depth Item 21.20’ 2-7/8” hgrw/Cameron “H” BPV profile 22’ 2-7/8” X 2-38” BT&C crossover 1 2498’ Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/ 1,000 psi chem inj valve 2 3528’ CIBP with 35’ cement cap 10/14/20 2A 3648’ Packoff Plug 3 4309’ EL CIBP 4 4912’ SL Packoff Plug (capped w/ 52’ of cement) 5 5399’ Macco 2-3/8” D-SO GLM w/1” dummy 6 5447’ Baker FH Ret packer, 2-3/8” X 7” 26# C M T 800 sx pumped above DV @ 8007’ C E M E N T DV @ 1508’ 5 6 2-3/8’ TOC @ 2042’ 50-6 sand Cmt Top @ 5395’ Tag Fill @ 4,934’ 8/03/14 4 47-6 sand 44-1 sand RKB to TBG Head = 21.20’ Tree connection: TC-3 Uni-bolt (2.5” Bowen) 36-9A sand Cmt Top @ 4,860’ Cmt Stringers @ 4,804’ 3 Tag Fill @ 4,706’ Cmt Top @ 4,174’ Tag Fill @ 4,271’ Tag Fill @ 3,597’ SLM 2 B6 7” TOC @ 5480’ by CBL Cmt Top @ 3,493’ 2A PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 10/22/20 3,393’ 3,399’ Sterling B6L 1-11/16” Shogun Spiral - Open 8/13/14 3,684’ 3,693’ Beluga (36-9A) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,565’ 4,575’ Beluga (44-1) 1-11/16” Shogun Spiral - Isolated 8/13/14 4,750’ 4,760’ Beluga (47-6) 1-11/16” Shogun Spiral - Isolated 10/30/13 5,000’ 5,015’ Beluga (50-6) 1-11/16” Shogun Spiral - Isolated 09/16/03 5,015’ 5,019’ Beluga (50-6) 1-11/16” PJ Spiral - Isolated PBTD = 3,493’ - TD = 11,383’ Straight hole, Max angle = 1 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 12-15 (PTD 160-022) GPT-Gauge Ring 12/07/2020 Please include current contact information if different from above. Received by the AOGCC 01/14/2021 PTD: 1600220 E-Set: 34576 Abby Bell 01/14/2021 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Monday, November 16, 2020 12:01 PM To:Winston, Hugh E (CED) Subject:FW: SRU 12-15 AOGCC 10-403 319-427 PTD 160-022 - WITHDRAW P&A From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Monday, November 16, 2020 7:51 AM To: Donna Ambruz <dambruz@hilcorp.com>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Ted Kramer <tkramer@hilcorp.com>; Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com>; Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: RE: SRU 12‐15 AOGCC 10‐403 319‐427 PTD 160‐022 ‐ WITHDRAW P&A Donna, The AOGCC will cancel this sundry to Plug SRU 12‐15. (#319‐427) It was approved in Sept 2019 so has expired anyway. Guy Schwartz Sr. Petroleum Engineer AOGCC 907‐301‐4533 cell 907‐793‐1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Donna Ambruz <dambruz@hilcorp.com> Sent: Sunday, November 15, 2020 8:16 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Ted Kramer <tkramer@hilcorp.com>; Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com> Subject: SRU 12‐15 AOGCC 10‐403 319‐427 PTD 160‐022 ‐ WITHDRAW P&A Guy: Please withdraw/cancel the above‐referenced sundry. Thank you. Donna Ambruz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 2 907.777.8305 ‐ Direct 907.777.8510 ‐ Fax dambruz@hilcorp.com From: Ted Kramer Sent: Saturday, November 14, 2020 2:26 PM To: Yarawsky, Sharon <syarawsk@blm.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: Re: [EXTERNAL] SRU 12‐15 Sharon, Yes we do. Ted Kramer Sent from my iPhone On Nov 13, 2020, at 2:57 PM, Yarawsky, Sharon <syarawsk@blm.gov> wrote: Good afternoon Ted. Since well SRU 12‐15 has been brought back to production, do you want to rescind your plug and abandonment sundry notice for this well? Sharon L. Yarawsky Mineral Law Specialist/Surface Compliance BLM Alaska State Office, Branch of Energy and Minerals 222 W. 7th Avenue, #13 Anchorage, AK 99513‐7504 907‐271‐5683 (office) syarawsk@blm.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,383'N/A Casing Collapse Structural Conductor Surface 1,130psi Intermediate Production 3,830psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Mike Quick Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: October 9, 2020 2-3/8" 11,382' Perforation Depth MD (ft): See Attached Schematic 11,382' 11,382'7" 22" 13-3/8" 30' 3,167'2,730psi 30' 3,167' 30' 3,167' 4.6# / L-80 TVD Burst 5,480' 6,340psi MDLength Size CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028406 160-022 50-133-10138-00-00 Swanson River Unit (SRU) 12-15 Swanson River Field / Undef Beluga, Sterling Gas Pools COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic mquick@hilcorp.com 11,383'3,648'3,648'1038 psi 3,648' FH Packer; N/A 5,447' MD & TVD; N/A Perforation Depth TVD (ft): Tubing Size: Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:21 am, Sep 28, 2020 320-398 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.25 15:08:01 -08'00' Taylor Wellman SFD 9/28/2020 gls 10/5/20 GAS DSR-9/28/2020 Perforate New Pool SFD 9/28/2020 + MIT-IA to 1500 psi (pre and post perforations) 10-404 Sterling/Upper Beluga Gas Pool, Beluga Gas Pool Comm. 10/6/2020 dts 10/06/2020 JLC 10/6/2020 RBDMS HEW 11/2/2020 Well Prognosis Well: SRU 12-15 Date: 9-25-2020 Well Name: SRU 12-15 API Number: 50-133-10138-00 Current Status: Shut in Gas well Leg: N/A Estimated Start Date: 10/9/2020 Rig: E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-022 First Call Engineer: Michael Quick (907) 777-8442 (O) (907) 317-2969 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) AFE Number: Maximum Expected BHP: 1380 psi @ 3,415’ TVD (Based on offset well BHP data) Max. Potential Surface Pressure: 1038 psi @ 3,415’ TVD (Based on expected BHP and gas gradient to surface (0.10psi/ft) Brief Well Summary SRU 12-15 was drilled by in 1960. During a workover in 2003, Unocal cemented the 2-3/8” tubing inside the 7” casing, creating a monobore with a cement packer. Hilcorp perforated the Beluga 36-9A, 44-1 and 47-6 sands in 2013, and set a pack off plug above these perforations in 2017. Well has been shut in since 2014. The purpose of this sundry is to return this well to production by adding perforations in the Sterling sand intervals. Work scope includes dump bailing cement on the pack off plug previously set at 3648’, above the Beluga 36-9A perforations, and perforating the Sterling B6 and B5 sands. Notes Regarding Wellbore Condition x Current shut in tubing pressure = 480 psi. x 2-3/8” tubing (2” OD) Pack Off plug set at 3648’ on 7/10/17. o Plug was pressure tested to 1700 psi. x Max deviation of 1 degree. x Temperature log ran 9/3/2003 indicates a top of cement in the 2-3/8” by 7” annulus at 2042’ MD. 120.9 bbls of 15.8 ppg cement was pumped through tubing punches at 5418’ on 9/2/2003 to cement in the 2-3/8” tubing string. Pre-Sundry Work 1. Pressure test (MIT IA) 2-3/8” by 7” annulus to 1500 psi for 30 minutes. (TOC at 2042’ TVD x 0.25 psi/ft = 511psi pressure test, 1500 psi is minimum test pressure). Chart test. Slickline Procedure 1. MIRU Slickline unit. 2. RIH with gauge ring (1.75” min OD) to tag plug at 3648’ SLM. Contingency: If current pack off plug at 3648’ does not hold pressure, an additional 2-3/8” tubing plug will be set ~5’ above the current plug, prior to dump bailing cement. 3. RIH and dump bail 35’ of cement on top of plug. (35’ cement = 5.7 gallons in 2-3/8” tubing). 4. Swab off fluid, if a fluid level is found in wellbore, to below new perforation depth (3415’). E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 3,000 psi High. Contingency: If fluid level cannot be swabbed out of well: a) MIRU Coil tubing unit. Pressure test BOP to 4,000 psi high, 250 psi low. Pre- MIT-IA Look for fluid level? Work Scope The purpose of this sundry is to return this well to production by adding perforations in the Sterling sand intervals. Work scope includes dump bailing cement on the pack off plug previously set at 3648’, above the Beluga 36-9A perforations, and perforating the Sterling B6 and B5 sands. Well Prognosis Well: SRU 12-15 Date: 9-25-2020 b) RU Nitrogen. RIH W/ Coil and blow well dry with Nitrogen leaving 500 psi on well head. RDMO Nitrogen and CTU. 2. PU and RIH with 1-11/16” Perforating gun, 6 SPF. Proposed Perforation Intervals: Sand TOP MD BOT MD Total TOP TVD BOT TVD Reservoir Pressure Sterling B5 3215’ 3235’ 20’ 3215’ 3235’ 1110 psi Sterling B6U 3365’ 3385’ 20’ 3365’ 3385’ 1300 psi Sterling B6L 3390’ 3415’ 25’ 3390’ 3415’ 1380 psi a) Proposed perforations are also shown on the proposed schematic in red font. b) Final Perforation tie-in sheet will be provided in the field for exact perforation intervals. c) Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d) Use Gamma/CCL to correlate. e) Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals after firing gun. f) The listed Sands are governed by Conservation Order 716.001. g) Sand intervals may be grouped or shot one at a time and flow tested to the system. If a sand makes water, then a plug or an isolation patch may be set prior to moving up to the next sand interval. h) A tubing plug with 35’ of cement dump bailed on plug will be set to isolate the Sterling B6 prior to perforating the Sterling B5 sand. 3. POOH. 4. RD e-line. 5. Turn well over to production to test. (Test SSV with-in 5 days of stable production on well – notify AOGCC 24hrs before testing) Safety Concerns for N2 x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (if venting Nitrogen during this job). x Ensure all crews are aware of stop work authority. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Coil Tubing BOP 4. Standard Well Procedure – N2 Operations + Post Perforation MIT-IA is required. Sterling B5 3215’ 3235’ 20’ 3215’ 3235’1110 psi Sterling B6U 3365’ 3385’ 20’ 3365’ 3385’1300 psi Sterling B6L 3390’ 3415’ 25’ 3390’ 3415’1380 psi Conservation Order 716.001. Downhole Revised 12/30/14 Updated by DMA 07-14-17 SCHEMATIC Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 1 C M T C E M E N T SIZE WT GRADE CONN TOP BTM LENGTH 22” Surf 30’ 13-3/8” 54.5 J-55 8rd Surf 3167’ 7” 29 N-80 Buttress Surf 303’ 303’ 7” 26 N-80 Buttress 303’ 1197’ 894’ 7” 23 N-80 Buttress 1197’ 4750’ 3553’ 7” 26 N-80 Buttress 4750’ 6160’ 1410’ 7” 29 N-80 Buttress 6160’ 7879’ 1719’ 7” 26 P-110 8rd LT&C 7879’ 9627’ 1748’ 7” 29 P-110 8rd LT&C 9627’ 11382’ 1755’ Tubing: 2-3/8” 4.6 L-80 SC BT&C Surf 5,480’(cut) with 3/8” methanol inj line from surf to 2498’ JEWELRY DETAIL NO. Depth Item 21.20’ 2-7/8” hgrw/Cameron “H” BPV profile 22’ 2-7/8” X 2-38” BT&C crossover 1 2498’ Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve 2 3648’ Packoff Plug 3 4309’ EL CIBP 4 4912’ SL Packoff Plug (capped w/ 52’ of cement) 5 5399’ Macco 2-3/8” D-SO GLM w/1” dummy 6 5447’ Baker FH Ret packer, 2-3/8” X 7” 26# C M T 800 sx pumped above DV @ 8007’ C E M E N T DV @ 1508’ 5 6 TOC @2000’ 50-6 sand Cmt Top @ 5395’ Tag Fill @ 4,934’ 8/03/14 4 47-6 sand 44-1 sand RKB to TBG Head = 21.20’ Tree connection: TC-3 Uni-bolt (2.5” Bowen) 36-9A sand Cmt Top @ 4,860’ Cmt Stringers @ 4,804’ 3 Tag Fill @ 4,706’ Cmt Top @ 4,174’ Tag Fill @ 4,271’ Tag Fill @ 4,058’ SLM 2 PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 8/13/14 3,684’ 3,693’ Beluga (36-9A) 1-11/16” Shogun Spiral 8/13/14 4,565’ 4,575’ Beluga (44-1) 1-11/16” Shogun Spiral 8/13/14 4,750’ 4,760’ Beluga (47-6) 1-11/16” Shogun Spiral 10/30/13 5,000’ 5,015’ Beluga (50-6) 1-11/16” Shogun Spiral 09/16/03 5,015’ 5,019’ Beluga (50-6) 1-11/16” PJ Spiral PBTD = 11,182’ TD = 11,383’ Straight hole, Max angle = 1q Current Downhole Revised 12/30/14 Updated by MJQ 9-25-20 PROPOSED SCHEMATIC Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 1 C M T C E M E N T SIZE WT GRADE CONN TOP BTM LENGTH 22” Surf 30’ 13-3/8” 54.5 J-55 8rd Surf 3167’ 7” 29 N-80 Buttress Surf 303’ 303’ 7” 26 N-80 Buttress 303’ 1197’ 894’ 7” 23 N-80 Buttress 1197’ 4750’ 3553’ 7” 26 N-80 Buttress 4750’ 6160’ 1410’ 7” 29 N-80 Buttress 6160’ 7879’ 1719’ 7” 26 P-110 8rd LT&C 7879’ 9627’ 1748’ 7” 29 P-110 8rd LT&C 9627’ 11382’ 1755’ Tubing: 2-3/8” 4.6 L-80 SC BT&C Surf 5,480’(cut) with 3/8” methanol inj line from surf to 2498’ JEWELRY DETAIL NO. Depth Item 21.20’ 2-7/8” hgrw/Cameron “H” BPV profile 22’ 2-7/8” X 2-38” BT&C crossover 1 2498’ Macco 2-3/8” SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve 2 3648’ Packoff Plug (35’ cement on top of plug) 3 4309’ EL CIBP 4 4912’ SL Packoff Plug (capped w/ 52’ of cement) 5 5399’ Macco 2-3/8” D-SO GLM w/1” dummy 6 5447’ Baker FH Ret packer, 2-3/8” X 7” 26# C M T 800 sx pumped above DV @ 8007’ C E M E N T DV @ 1508’ 5 6 2-3/8’ TOC @ 2042’ 50-6 sand Cmt Top @ 5395’ Tag Fill @ 4,934’ 8/03/14 4 47-6 sand 44-1 sand RKB to TBG Head = 21.20’ Tree connection: TC-3 Uni-bolt (2.5” Bowen) 36-9A sand Cmt Top @ 4,860’ Cmt Stringers @ 4,804’ 3 Tag Fill @ 4,706’ Cmt Top @ 4,174’ Tag Fill @ 4,271’ Tag Fill @ 4,058’ SLM 2 B5 B6 7” TOC @ 5480’ by CBL PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 Future 3215’ 3235’ Sterling B5 Future 3365’ 3385’ Sterling B6 Future 3390’ 3415’ Sterling B6 8/13/14 3,684’ 3,693’ Beluga (36-9A) 1-11/16” Shogun Spiral 8/13/14 4,565’ 4,575’ Beluga (44-1) 1-11/16” Shogun Spiral 8/13/14 4,750’ 4,760’ Beluga (47-6) 1-11/16” Shogun Spiral 10/30/13 5,000’ 5,015’ Beluga (50-6) 1-11/16” Shogun Spiral PBTD = 11,182’ TD = 11,383’ Straight hole, Max angle = 1q STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Swanson River Field, Undefined Beluga Gas Pool, SRU 12-15 Permit to Drill Number: 160-022 Sundry Number: 319-427 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this _day f September, 2019. 4BDMS�SEP 2 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 �P' 2 „• � rl:'011 '9 A& �uai `cs/r 1. Type of Request: Abandon 21 ' 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 0 Stratigraphic ❑ Service ❑ 160-022 ' 3. Address, 3800 Cenlerpoinl Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10138-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No Swanson River Unit (SRU) 12-15 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River Field / Undef Beluga Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,383' 11,383' 3,648' 3,648' 1,245 3,648' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 3,167' 13-3/8" 3,167' 3,167' 2,730 psi 1, 130 psi Intermediate Production 11,382' 7" 11,382' 11,382' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD See Attached Schematic See Attached Schematic 2-3/8" 4.6# / L-80 5,480 Packers and SSSV Type: - Packers and SSSV MD (ft) and TVD (ft): FH Packer; N/A 5,447' MD 8 TVD; WA 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 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: Christina Twogood Authorized Title: Operations Manager Contact Email: ctw0 OOd hilcof .com ?wyl'i fst(� Contact Phone: 777-8443 Authorized Signature: 1 // yo. Qo or k Date: d/ / 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: " 3i�� u2� L- Plug Integrity [� BOP Test Integrity Test ❑ Location Clearance ❑ /�Me�chanical Other: fC 1JZD r 7-9 %Q -e- Post Initial Injection MIT Req'd? Yes No U/ Spacing Exception Required? Yes ❑ No F9111' Subsequent Form Required: ,— ((,J -7- ;gDMS.IASEP 2 5 2019 ell APPROVED Approved by COMMISSIONER THEHECOMMISSION Date: 7 `� / �- Submit Form and rm 10-403h vised�4/2 017 Approved applicatttlo r v'1� 1 rl�o t iiiA��VVrr date of approval. attachments in Duplicate )"89'zo/f9 n llilcara Alaska. LL Well Prognosis Well: SRU 12-15 Date:09/11/2019 Well Name: SRU 12-15 API Number: 50-133-10138-00-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: 10-1-19 Rig: E -Line & Coil Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-022 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Maximum Expected BHP: - 1,614 psi @ 3,693' (Based on normal gradient of 0.437 psi/ft) Max. Potential Surface Pressure: - 1,245 psi @ 3,693' (Based on expected BHP and gas gradient to surface) Brief Well Summary In 1960, Swanson River Unit 12-15 was drilled and completed as an oil well targeting the Hemlock. In 1996, the Hemlock was fully abandoned and the well was recompleted as a gas well. In 1996, the Tyonek 80-2 sand was perforated but was not productive. It was abandoned in 1998. In 1999, the Tyonek 61-3 was perforated. In 2002, the Tyonek 58-1 and a 2"d interval of the 61-3 sands were perforated. In 2003, the Tyonek 58-1 and 61-3 (2 intervals) sands were abandoned and the Beluga 50-6 sand was perforated. In 2013, a second interval of the Beluga 50-6 sand was perforated. In 2014, the two intervals in the Beluga 50-6 sand were isolated with a Packoff Plug with 52' of cement on top. The Beluga 47-6, 44-1 and 36-9A sands were perforated. The Beluga 47-6 and 44-1 sands were isolated with a CIBP with 38' of fill and then 97' of cement on top. In 2017, the Beluga 36-9A sand was isolated with a Packoff Plug. The purpose of this work/sundry is to permanently P&A the SRU 12-15 wellbore. • Notes Regarding Wellbore Condition • Packoff Plug isolating Beluga 36-9A sand at 3,648' MD was pressure tested to 1720 psi for 30 min in 2017 Pre - Ops Work: 1. Provide 24 hour notice to AOGCC that P&A of well will commence per AOGCC regulations 20 AAC 112(h). Notify BLM of P&A as per 43 CFR 3160 G. 2. RU Pump Truck. RU on IA and perform a pressure test to 2,500 psi on chart for 30 min. Bleed down pressure. n llil.m M.A.. LL- E-Line L E-Line Procedure Well Prognosis Well: SRU 12-15 Date: 09/11/2019 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 2. RIH and tag plug (or fill if present). P 3. Dump bail 35' cement on top of plug (or fill if present). a. At this point, all perforations are isolated from the wellbore. / 2% i 4. RU perf guns. /-7 5. RIH and pert the lower perf interval: 3e �. Upper +3,114' +3,117' 1 +3' Lower +3,217' +3,220' +3' a. The upper casing interval may not be perforated. b. Proposed perfs shown on the proposed schematic in red font. c. Use Gamma/CCL to correlate. d. If perforating both intervals, record tubing pressures before and after each run. e. Record 5, 10 and 15 minute pressures after perforating. 6. POOH and RD E -Line. Cement Procedure (Surface Casing; Shoe/Intermediate) 1. MIRU Coiled Tubing. PT BOPE to 250 psi Low / 3,500 psi High. 2. Notify AOGCC 24 hrs in advance of BOP test. �- 3. MU and RIH with BHA. 4. Establish circulation through lower perf interval. a. If circulation cannot be established, perfthe upper interval. 5. Circulate hole with kill weight fluid. 6. RU cementers and pump cement through perfs into 13-3/8" x 7" casing annulus to cover 50' above and 50' below the shoe of the 13-3/8" surface casing for the 7" intermediate casing (production liner). Cement 1 +3,117' 1 +3,217' 1 >100' 7. PU above cement and clean out tubing. 8. If circulation cannot be established, then perform a Bradenhead squeeze. a. Spot cement across perf interval plus ±200' and pressure up to 500 psi and hold for 30 minutes to ensure cement is forced behind 7" casing to isolate the surface casing shoe. 9. POOH and laydown BHA. Fti 10. RD Cementers and Coiled Tubing. 11. RU Slickline. RIH with GR and tag top of cement (TOC). Ensure TOC is at or above approx. 3,117' to ensure at least 50' of cement above surface casing shoe. 12. POOH & RD Slickline. W 6 ` — 4�A— � � S�fly /a 5 Well Prognosis Well: SRU 12-15 tmcuru Alaska. LL Date: 09/11/2019 E -Line Procedure (Tubing Cut & Pull) 1. MIRU work platform and BOPE. PT BOPE to 250 psi Low/ 3,500 psi High. 2. RU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,500 psi High. 3. PU and RIH with tubing cutter. 4. RIH and cut tubing at+1,500'. a. TOC in 7" x2-3/8" annulus is approx. 2,000'. 5. POOH and RD E -Line, 6. RU Crane. �7. PU tension on the 2-3/8" tubing string. X a. If tubing is free, circulate hole with kill weight fluid. b. If tubing is not free, repeat steps 2 & 3. 8. POOH with tubing, laying down pipe. E -Line Procedure (Surface Isolation) 1. RU E -Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 2. PU and RIH with 7" CIBP or Mechanical BP and set at approx. 155' or deeper. 3. PU and RIH with Casing Punches to 155'. 4. Punch 7" casing. 5. POOH and RD E -line. Cement Procedure (Surface Isolation) 6. RU Pump truck and Cementers to backside. 7. Establish circulation down the IA through the casing punches and up the 7" casing. Circulate a cement plug from 150' to surface. RD Pump Truck and Cementers. 8. Place dry hole tree on well. 9. RDMO Pump Truck and Cementers. kif well requires a cleanout prior to perforatina: 1. MIRU Coiled Tubing, PT BOPE to 250 psi Low/ 3,500 psi High. 2. Notify AOGCC 14 hrs in advance of BOP test. 3. MU Cleanout BHA. 4. RIH and cleanout. 5. Circulate hole clean with two bottoms up, ensuring any rubber or cement is free from the hole. 6. POOH and laydown BHA. 7. RD Coiled Tubing. H Hilc ru Alaska, LL Well Prognosis Well: SRU 12-15 Date: 09/11/2019 Post -Rig Abandonment Procedures:r /} -C �T7 C //'' /�n 13.E ff casing 3' below natural GL. cv: . Notify AOGCC and BLM 48hrs ina va . 15. 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: a. Hilcorp Alaska, LLC b. PTD: 160-022 c. Well Name: SRU 12-15 d. API: 50-133-10138-00 16. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 17. Photo document casing cut-off and Welded Plate install. 18. Bac fill excavation, close out location. H llileom M.A.. LL, Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Schematic 4. Coil BOPE Schematic S. BOPE Schematic 6. RWO Sundry Revision Change Form Well Prognosis Well: SRU 12-15 Date:09/11/2019 Swanson River Unit Well: SRU 12-15 SCHEMATIC Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 Hikmrp Alaska, LLC RKB to TBG Head = 21.20' Tree connection: TC -3 Uni-bolt (2.5' DV @ 1508' Cott Top @ 4,174' Tag Fill @4,271'— Tag 4,271'Tag Fill @ 4,706' Con Stringer @ 4,804' Cunt Top' @ 4,860' Tag Fill' @ 4,934' 8/03/14 800 sx pumped above DV @ 8007' 36-9A sand SIZE WT GRADE CONN TOP BTM LENGTH 22" 3 8/13/14 3,684' Surf 30' 44-1 sand 13-3/8" 54.5 J-55 8rd Surf 3167' 4,750' 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-1108rd LT&C 7879' 9627 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubin Baker FH Ret packer, 2-3/8" X 7" 26# 2-3/8"1 4.6 1 L-80 SC BT&C Surf 5,480' cut • ='•: e.;�, Tag Fill with 3/8" methanol inj line from surf to 2498' BTM @ 4,058' SLM Tie-in log = Schlumberger TDT 11/16/96 r 3 8/13/14 3,684' 3,693' Beluga (36-9A) 44-1 sand 8/13/14 4,565' 4,575' Beluga (44-1) 47-6 sand 8/13/14 4,750' JEWELRY DETAIL Beluga (47-6) 1-11/16" Shogun Spiral NO. Depth Item Beluga (50-6) 1-11/16" Shogun Spiral 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 4 22' 2-7/8" X 2-38" BT&C crossover -.•.'•1 50-6 sand 1 2498' Macco 2-3/8" SMO -ICI Chem Inj Mdrl w/1000 psi chem inj valve 5 2 3648' Packoff Plug 3 4309' EL CIBP ,�,. 6 4 4912' SL Packoff Plug (capped w/ 52' of cement) r 5 5399' Macco 2-3/8" D -SO GLM w/1" dummy Cmt Top @ 5395' 6 5447' Baker FH Ret packer, 2-3/8" X 7" 26# PBTD =11,182' TD =11,383' Straight hole, Max angle = V PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 8/13/14 3,684' 3,693' Beluga (36-9A) 1-11/16" Shogun Spiral 8/13/14 4,565' 4,575' Beluga (44-1) 1-11/16" Shogun Spiral 8/13/14 4,750' 4,760' Beluga (47-6) 1-11/16" Shogun Spiral 10/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 09/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Revised 12/30/14 Updated by DMA 07-14-17 Swanson River Unit Well: SRU 12-15 PROPOSED SCHEMATIC Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00-00 Hilcoru Alaska, LLC RKB to TBG Head = 21.20' TOC to Surface T M T uv 1508' Casing Punches @155'& & 3217-3220 Cmt Top @ 4,174' Tag Fill @ 4,271' Tag Fill @ 4,706' Curt Stringer @ 4,804' Cmt Top' @ 4,860' Tag Fill' @ 4,934' 8/03/14 800 sx pumped above DV @ 8007' @2000' 36-9A sand ^•�•� Tag Fill ih 4,058' SLM 3 44-1 sand 47-6 sand 50-6 sand SIZE WT GRADE CONN TOP BTM LENGT H 22" 2-7/8" X 2-38" BT&C crossover 1 2498' Surf 30' TDT 11/16/96 13-3/8" 54.5 J-55 8rd Surf 3167' EL CIBP 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29N-80 I Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubiu 2-3/8" 4.6 L-80 SC BT&C Surf 5,480'(cut) with 3/8" methanol inj line from surf to 2498' Top @ 5395' JEWELRY DETAIL NO. Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile TOP 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl = Schlumberger TDT 11/16/96 w/1000 psi chem inj valve (cut) 2 3648' Packoff Plug (w —35' curt, TOC —3613') 3 4309' EL CIBP 4 4912' SL Packoff Plug (capped w/ 52' of cement) 5 5399' Macco 2-3/8" D -SO GLM w/1" dummy 6 5447' Baker FH Ret packer, 2-3/8" X 7" 26# T PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 8/13/14 3,684' 3,693' Beluga (36-9A) 1-11/16" Shogun Spiral 1, 8/13/14 4,565' 4,575' Beluga (44-1) 1-11/16" Shogun Spiral 8/13/14 4,750' 4,760' Beluga (47-6) 1-11/16" Shogun Spiral 10/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shugart Spiral 09/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral PBTD = 11,182' TD =11,383' Straight hole, Max angle = 1° Downhole Revised 12/30/14 Updated by DMA 09-18-19 H IlilnxP 14•k�. 1.l.l: Swanson River SRU 12-15 133/8 X 7X 23/8 BHTA, Otis, 2 9/16 5M FE X 3" Bowen quick Union Valve, Swab, WKM-M, 2 9/165M FE, HWO, DD trim Valve, Master, WKM-M, 2 9/16 SM FE, HWO, DD tr Valve, Master, WKM-M, 2 9/16 SM FE, HWO, DD trim Tubing head, Shaffer T55 -LI, 13 5/8 3M X 7 1/16 5M w/ 2- 21 /16 5M SSO, 7" Type 1 secondary seal in head Tubing head replaced in 1996 Casing head, Shaffer KD, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2" LPO, 7" KD slips and packoff assy in head Swanson River SRU 12 -15 -current 09/14/2019 Tubing hanger, Shaffer T55- AIO, 7 X 2 7/8 BTC lift and susp,w/2Y.TypeH BPV profile, 3/8 control line, PN: 421810 o� Q¢ J� 01 - Valve, - Adapter, Shaffer -A10, 7 1/16 5M stdd X 2 9/16 5M, % npt control line port Valve, WKM-M, 21/16 SM FE, H WO, AA trim Qty 2 plug, Rockwell, T' LPO, Kill W WHp 2" 1502 x2-1/ FlangedV, (Ma ,al 2-1116 10K IOK flange (Manu Coil Tubing BOP Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs 4-1/16" IOK Conventional Stripper 5K C062 Lubricator SK 0062 x 4-1116" 1 OK Flange 4-1/16" 10K Combi BOP Tap Sec Bund/Shear Sat nd Set. Rped%p 4-1116" 1 OK flow Cross Mangy 2x2 Valve 1 2" 1502 x 2-1/16'10K Range Manual 2x2 Valve 2'. 2-1116" 10K x 2-1116" IOK R.N. Manual 2x2 Va ve 3'. 2-1116" 10K x 2-1116" IOK Flange Manua 2x2 Valve 4. 2" 1502 x 2-1116" 10K Flange 4-1116" 1OK x Wellhead Adapter Flange Wellhead 7 1 6 1 5 4 3 1 2 11 BILL OF MATERIAL ITEMIQTYl PART NUMBER DESCRIPTION 1 1 95-0705-00013 ANNULAP ASSEMBLY, STUDDED TOP X FLG BTM, ISAX ABOP7 1 1/16-5000 MWRBOP PR1 (65.3) 1 2 1 1 70-0705-00029 TRBOP ASSEMBLY, RBOP 71/16-5000 MWP, PRI, STUDDED BOTTOM X TOP WITH (312 lllS-SK MWP, STUDDED OUTLET D D 1 1 (30.9) C C ® O TOP BORE-2a PIPE IIIIIIIIIIIID O®®OCJ�C�iGiQ46DD O DIIIIIIIIIIII E— RAMS MID M-2-71W PIPE (29.8) 1 BOTTOM BORE—CSO RAMS B B I 2-1/16" 5M MANUAL GATE VALVE 2-1/16" 5M HCR TNI& AWUNDNTANDALLTHE wFdtNAiIONC AILED HEREIN I& UNLESS OTHERWISE SPECIFIED "EV FDX ECN pESLRITI0.N GATE wDESCRIPTION A THE SOLE AND E%GWSINE PRGERTV NAME GATE S& ADLI. ANND. TILER NCE OFIMEGMTEO EONIFMENFMD&HALL DTPEDSEN. msQUPlAE TAA0S D ALLpLNTN GE GR&ININLNEB. ALLFIAu uluc Musrsmwmle STACK BCP, 7 1/16"- 5K YELLOWACKET D A F.TOX-A VI& wlmwT WOFINiFLR-.Eow CD"FXCE�1 VMEu ..A. x-:.W xx-... S BId2019 EWlS 'TTI OILFIELD SERVICES SNAPPEWEB OISM1NtlNI1M A' PE"�ENENf'TO EWE06REAM IIREOHEG HN 9F GOPHER PADA WXIMI L coucwTPlcm oIaTIA. NYX�i W5 - n %- NG AND SHALL SE RETURNED T I ocPArEoeoulPmwT. uFox INAY BIB12019 1 /1 �DMENESG g01N IP NO. REV Ni GRATSOMIPMEM NESERVESmEPIGxiiOCNANG[ 1 8"PEDFCATT DDS wiRlgli NOTICE . N"Ir�E.Ett'ION Fl... Ml P. MATERIAL: MATERIAL: SEE BOM 31-001147 8 7 6 5 4 3 2 1 UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well XXX (PTD XXX -XXX) 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? YIN HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED SEP 16 2014 1. Operations Abandon Repair Well Plug Perforations ✓ Perforate Other - -- - A Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate -Other ❑ Re-enter Suspended Well ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 160-022 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-133-10138-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 12-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Beluga Undef Gas 11. Present Well Condition Summary: Total Depth measured 11,383 feet Plugs measured 5,395 feet true vertical 11,383 feet Junk measured N/A feet Effective Depth measured 5,395 feet Packer measured 5,447 feet true vertical 5,395 feet true vertical 5,447 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 3,173' 13-3/8" 3,173' 3,173' 2,730 psi 1,130 psi Intermediate Production 11,382' 7" 11,382' 11,382' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic S LT Q C IT 02 2,U 1`n1rt . True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.6# / L-80 5,480' MD 5,480' TVD Packers and SSSV (type, measured and true vertical depth) FH Packer; N/A 5,477' MD 5,447' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 40 190 Subsequent to operation: 0 0 0 40 200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16, Well Status after work: Oil ❑ Gas [A WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-420 & 314-421 Contact Stan Porhola Email Sporhola @hllcorp.com Printed Name Stan Porhola Title Operations Engineer Signature W" Phone 907-777-8412 Dateitc Form 10-404 Revised 10/2012 / .7ZZ-/Y MC NIS SEP 17 201 Submit Original Only -MM awidr Hilcorp Alaska, LLC 0 Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 12-15 50-133-10138-00 1 160-022 8/3/14 8/19/14 Daily Operations: 08/03/2014 -Sunday MIRU Slickline on SRU 12-15. PT Lubricator to 250/2,500 psi - test OK. RIH w/ 1.85" GR to 4,242', work to 4,245' SLM. RIH w/ 1.75" x 4' DD bailer to 4,247', work to 4,253' SLM. Fall thru bridge to 4,934' SLM. Recover 1 cup of mud. RIH and set tubing plug at 4,912' SLM. Rig down. Demobe. 08/07/2014 - Thursday MIRU Slickline on SRU 12-15. PT Lubricator to 250/2,500 psi - test OK. RIH w/ 1.73" GR to 4,900' SLM, tag plug. RIH w/ 1.75"x15' dump bailer to 4,900' SLM (5 runs, 6.0 gals cement). Rig down. Move to SRU 32A-15. 08/08/2014 - Friday MIRU Slickline on SRU 12-15. PT Lubricator to 250/2,500 psi - test OK. RIH w/ slickline scratchers, star bits, and broaches. Work from 4 698' to 4 753' SLM. Rig down. SDFN. 08/09/2014 -Saturday MIRU Slickline on SRU 12-15. PT Lubricator to 250/2,500 psi - test OK. RIH w/ star bits, and broaches. Work from 4,753' to 4,804' SLM. RIH w/ 1.87" GR to 4,804' SLM. RIH w/ swab cups and swab fluid down from 2,380' to 4,740' SLM. Rig down. Demobe unit. 08/13/2014 - Wednesday PTW and JSA. Mobe to location and spot equip. Rig up lub and PT to 250 psi low and 3,500 psi high. RIH with 1-11/16" x 10' Spiral strip gun and set down at 4,770'. Run correlation log and send to town. Get ok. Spot shot from 4,750' to 4,760'. TP - 502 psi. Fired gun and psi went to 620 psi in 10 min. POOH. Tools were blown up hole and kinked line. Rehead line and strip line thru grease head. RIH with 1-11/16" x 10' Spiral strip gun and set down at 4,573'. Run correlation log and send to town. Get ok. Spot shot from 4,565' to 4 575'. TP - 770 psi. Fired gun and psi went down to 760 psi. POOH. Had to build another strip gun because strip was bent. RIH with 1-11/16" x 9' Spiral strip gun and set down at 4,573'. Run correlation log and send to town. Get ok. Spot shot from 3,684' to 3,693'. TP - 660 psi. Fired gun and psi went to 1,150 psi. POOH. Tools blown up hole. Stuck. Worked tools loose and pulled up to 500' and wait on daylight to strip thru lubricator. Got all tools out of hole and rig down. 08/14/2014 - Thursday MIRU Slickline on SRU 12-15. PT Lubricator to 250/1,500 psi - test OK. RIH w/ 1.75" DD bailer and bail down from 4,380' to 4,706' SLM (5 runs). RIH w/ 1.85" GR to 4,706' SLM. RIH w/ 1.50" GR to 4,706' SLM. RIH w/ 1.75" pump bailer to 4,706' SLM. RIH w/ 1.75" DD bailer to 4,706' SLM, no gain 2 runs). Rig down. SDFN. 08/15/2014 - Friday MIRU Slickline on SRU 12-15. PT Lubricator to 250/1,500 psi - test OK. RIH w/ 1.85" GR to 4,706' SLM. RIH w/ 2-3/8" AD -2 stop and set at 4,406' SLM. RIH w/ 2-3/8" D&D packoff plug to 4,403'. Unable to shear off plug. Jar free at 1,000 lbs overpull. Packing element missing from packoff. RIH w/ 2-3/8" GS pulling tool and recover AD -2 stop and packing element. RIH w/ 1.85" GR to 4,706' SLM. POOH. Rig down. SDFN. 08/16/2014 -Saturday PTW and JSA. Mobe to location and rig up. PT lubricator to 250 psi low and 3,000 psi high. RIH w/1.75" GR/JB to 4,309'. Worked tools and didn't make and hole. POOH. RIH w/ 1.71" CIBP and set at 4,309'. Plug did not shear. Pulled out ropesocket at 3,500 lbs. 08/17/2014 -Sunday Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 12-15 50-133-10138-00 1 160-022 8/3/14 8/19/14 Daily Operations: MIRU Slickline on SRU 12-15. PT Lubricator to 250/1,500 psi - test OK. RIH w/ 1.85" GR to 4,268' SLM. RIH w/ 1.75" DD bailer to 4,271' SLM. POOH. Recoverd full bailer of sand. RIH w/ 1.75" dump bailer and dump cement (5 runs). RIH w/ 1.89" GR to 4,200' SLM. Rig down. SDFN. Wait on cement. 08/19/2014 -Tuesday MIRU Slickline on SRU 12-15. PT Lubricator to 250/1,500 psi - test OK. RIH w/ 1.75" DD bailer to 4,174' SLM. RIH w/ braided line brush to 4,160' SLM. Bleed well to production. Well died. RIH w/ swab cups and make 1 run from 480' SLM. Well producing, making gas/water/sand. Rig down. Move unit to SRU 242-16. ACTUAL SCHEMATIC Hileorp Alaska, LIX RKB to TBG Head = 21.20' Tree connection: TC -3 Uni-bolt (2.5" Bowen DV @ 1508' Cmt Top @ 4,174' Tag Fill @ 4,271' Tag Fill @ 4,706' — Cmt Stringers @ 4,804' Cmt Top' @ 4,860' Tag Fill' @ 4,934' 8/03/14 800 sx pumped above DV @ 8007' Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE LJATOC .44 @2000' 1 F TOP BTM LENGTH ' 36-9A sand Cmt Top @ 5395' 5 +! ti Surf 30' r 4. 13-3/8" 54.5 J-55 2 44-1 Surf 3167' sand 7" 29 47-6 sand Buttress Surf 3 303' 7" 26 N-80 ,. 50-6 sand Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" Macco 2-3/8" D -SO GLM w/1" dummy Cmt Top @ 5395' 5 5447' Surf 30' 8/13/14 13-3/8" 54.5 J-55 8rd Surf 3167' 4,575' 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 1 11382' 1 1755' Tubing: 2-3/8" 1 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line from surf to 2498' JEWELRY DETAIL NO. Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1000 psi chem inj valve 4 2 4309' EL CIBP 3 4912' SL Packoff Plug (capped w/ 52' of cement) 5 \ 4 5399' Macco 2-3/8" D -SO GLM w/1" dummy Cmt Top @ 5395' 5 5447' Baker FH Ret packer, 2-3/8" X 7" 26# PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V Downhole Revised 8/19/14 Updated by STP 9/09/14 PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 8/13/14 3,684' 3,693' Beluga (36-9A) 1-11/16" Shogun Spiral 8/13/14 4,565' 4,575' Beluga (44-1) 1-11/16" Shogun Spiral 8/13/14 4,750' 4,760' Beluga (47-6) 1-11/16" Shogun Spiral 10/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 09/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Revised 8/19/14 Updated by STP 9/09/14 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, August 15, 2014 1:38 PM To: 'Stan Porhola' Subject: RE: Verbal approval to plugback water in SRU 12-15 (PTD 160-022) Stan, Go ahead and set CIBP... send in a 10-404 for the previous perfs and acid this to the report. If you end up perfing the 39-1 sands in the next 30 days add that to the report also. Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED 907-301-4533 cell SCANNED SEP 2 4 2014, 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Stan Porhola [mailto:sporholaOhilcorp.com] Sent: Friday, August 15, 2014 11:00 AM To: Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA) Subject: Verbal approval to plugback water in SRU 12-15 Guy, We recently perforated the SRU 12-15 well (PTD 160-022, Sundry 314-421) and found gas in the Beluga 36-9A,and water in the Beluga 44-1, and possibly sand in the Beluga 47-6. We are requesting verbal approval to plugback the well above the Beluga 44-1 sand by setting a CIBP at+1-4,400'. Also,we have deferred perforating of the Beluga 39-1 sand at this time.Attached is the proposed schematic. Regards, Stan Porhola j Operations Engineer North Kenai Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 THE STATE °fly"` GOVERNOR SEAN PARNELL Alaska Oil and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola Operations Engineer LL O Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Beluga Undefined Gas Pool, Swanson River Unit 12-15 Sundry Number: 314-420 Dear Mr. Porhola: 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 lday of July, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED 'JUL 14 014 Ai0GCC 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Al Change Approved Program ❑ Suspend ❑ Plug Perforations Perforate ❑ Pull Tubing[—] Time Extension ❑ Operations Shutdom ❑ 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 ❑ Stratigraphic ❑ Service ❑ 160-022 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number. Anchorage, Alaska 99503 50-133-10138-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(al(4) Will planned perforations require a spacing exception? Yes ❑ No ✓ ❑ Swanson River Unit (SRU) 12-15 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River Field / Undef Beluga Gas . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 1 Junk (measured): 11,383' 11,383' 5,395' 5,395' 5,395' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 3,173' 13-3/8" 3,173' 3,173' 2,730 psi 1,130 psi Intermediate Production 11,382' T' 11,382' 11,387 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6# / L-80 5,480 Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): FH Packer; N/A 5,44T MD & TVD; N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory n Stratigraphic❑ Development n Service ❑ 14. Estimated Date for 15. Well Status after propsed work: Commencing Operations: 07/21/14 Oil ❑ Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended 0 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. Contact Stan Porhola Phone: 907-777-8412 Email S orhola hilcor.com Printed Name Stan Porhoolla Title Operations Engineer SignaturesPhone 907-777-8412 Date 7 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: Spacing Exception Required? Yes ❑ No [V Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7 -17 - l7 / 7/S Ap �� "� Submit Form and Form 10-403 (Revised 10/ 2 Appro d p c ti v li f r nths from the date of pproval. Attachments in Duplicate RRCMS JUL 18 2�14V ,/� 7,1s -_,y Hilcorp Alaska, LLI Well Prognosis Well: SRU 12-15 Date: 7/14/2014 Well Name: SRU 12-15 API Number: 50-133-10138-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: July 21St, 2014 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-022 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 1,000 psi @ 5,015' TVD 2,100 psi @ 4,750' TVD 1,625 psi (Based on cumulative gas production along P/Z curve and tubing pressure.) (Based on offset wells (Based on actual reservoir conditions and gas gradient (0.10psi/ft)) Swanson River Unit 12-15 was drilled as an oil well in 1960 in the Hemlock. The Hemlock was abandoned in 1996 and the well recompleted in the Tyonek gas sands. A posiset plug was set in 1999 to isolate the lower Tyonek gas sands. The Beluga 56-0 was perforated below the tubing tail in April 2003 and was found to be unproductive. A cement packer was set in September 2003 and the well was completed thru-tubing in the Beluga 50-6. The zone was re - perforated in October 2013, but recently sanded up. Recent bailing operations were unable to remove sufficient fill to uncover the zone. The purpose of this work/sundry is toplugback the Beluga 50-6. A separate sundry will be submitted to add perforations in 4 new Beluga sands. Notes Regarding Wellbore Condition • Well is currently not flowing. Well has produced sand and is currently covering the perforations. Slickline Procedure: 1. MIRU Slickline, PT Lubricator to 2,000 psi Hi 250 Low. 2. RU 1.75" gauge ring, RIH and tag fill at +/-4,967'. 3. RU tubing stop/plug for 2-3/8" tubing, RIH and set at +/- 4,950' 4. Dump bail 35' of cement on tubing plug (6 gallons of cement). 5. Wait on cement for 12 hours. 6. RU 1.75" bailer and tag top of cement. 7. RIH w/ 2-3/8" swab cups. Swab fluid down to +/- 4,800'. 8. RD Slickline. Attachments: 1. As -built Schematic 2. Proposed Schematic Bleed off tubing pressure. DV 150 ACTUAL SCHEMATIC Hilcorp Alaska, LLC RKB to TBG Head = 21.20' PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" 2-7/8" X 2-38" BT&C crossover 1 2498' Surf 30' 13-3/8" 54.5 J-55 8rd Surf 3167' Baker FH Ret packer, 2-3/8" X 7" 26# 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 1 6160' 1 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubin 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line from surf to 2498' JEWELRY DETAIL NO. Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1000 psi chem inj valve 2 5399' Macco 2-3/8" D -SO GLM w/1" dummy 3 5447' Baker FH Ret packer, 2-3/8" X 7" 26# @ 5395' PERFORATION DATA DATE TOP BTM ZONE 'ie -in log = Schlumberger TDT 11/16/96 0/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 9/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Revised: 6/18/14 Updated by STP 7/09/14 r ir�OPOSED SCH EMATIL Hilcorp Alaska, LLC RKB to TBG Head = 21.20' Tree connection: TC -3 Uni-bolt 2.5" Bowen C C M M T T DV @ 1508' Tag Fill' @ 4,967' 6/18/14 E 800 sx pumped above DV @ 8007' TOC @2000' 1 Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" Depth Item Surf 30' 21.20' 13-3/8" 54.5 J-55 8rd Surf 3167' 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627 11382' 1755' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line from surf to 2498' PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 10/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 09/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Proposed Updated by STP 7/14/14 JEWELRY DETAIL NO. Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 2 22' 2-7/8" X 2-38" BT&C crossover 50-6 sand 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1000 psi chem inj valve 3 2 4950' CIBP (capped w/ 35' of cement) 3 5399' Macco 2-3/8" D -SO GLM w/1" dummy 4 4 5447' Baker FH Ret packer, 2-3/8" X 7" 26# Cmt Top @ 5395' PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 10/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 09/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Proposed Updated by STP 7/14/14 THE STATE OIAL ASKA GOVERNOR SEAN PARNELL Alaska Oil and Gas Cel'T'Iam is sic r, 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Foix: 907.276.7542 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 2- 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Undefined Beluga Gas Pool, Swanson River Unit 12-15 Sundry Number: 314-421 Dear Mr. Porhola: 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 L7day of July, 2014. Encl. A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUL 14/ 2014 '' ,,(/ � % ��—_ I®1O, 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well El Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑✓ - Pull Tubing❑ Time Extension ❑ Operations Shutdown ❑ 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 Stratigraphic ❑ Service ❑ 160-022 - 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number. Anchorage, Alaska 99503 50-133-10138-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a)(4) Will planned perforations require a spacing exception? Yes ❑ No E Swanson River Unit (SRU) 12-15 - 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River Field I Undef Beluga Gas 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): 11,383' 11,383' 5,395' 5,395' 5,395' NIA Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 3,173' 13-3/8" 3,173' 3,173' 2,730 psi 1,130 psi Intermediate Production 11,382' 7" 11,382' 11,382' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6# / L-80 5,480 Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): FH Packer; N/A 5,44T MD & TVD; N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory ❑ Stratigraphic❑ Development n Service ❑ 14. Estimated Date for 15. Well Status after propsed work: Commencing Operations: 07/24/14 Oil ❑ Gas ❑� WDSPL ❑ Suspended ❑ WINJ ❑ GINJ ❑ 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 7 Signature ,LPhone 907-777-8412 Date ! li 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: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY COMMISSIONER THE COMMISSION Date: Approved by:6t& 10 17—ILI 7- /iF l,( Submit Form and Ft 4 Rev' 1'11'201k / 0 ) Ap a plKilnW, Lhs from the/'t'f approval. Attachments in Duplicate Rt 201 Attachments in 7.14 Hilcorp Alaska, LL, Well Prognosis Well: SRU 12-15 Date: 7/14/2014 Well Name: SRU 12-15 AN Number: 50-133-10138-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: July 24th, 2014 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-022 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 1,000 psi @ 5,015' TVD 2,100 psi @ 4,750' TVD 1,625 psi (Based on cumulative gas production along P/Z curve and tubing pressure.) (Based on offset wells (Based on actual reservoir conditions and gas gradient (0.10psi/ft)) Swanson River Unit 12-15 was drilled as an oil well in 1960 in the Hemlock. The Hemlock was abandoned in 1996 and the well recompleted in the Tyonek gas sands. A posiset plug was set in 1999 to isolate the lower Tyonek gas sands. The Beluga 56-0 was perforated below the tubing tail in April 2003 and was found to be unproductive. A cement packer was set in September 2003 and the well was completed thru-tubing in the Beluga 50-6. The zone was re - perforated in October 2013, but recently sanded up. Recent bailing operations were unable to remove sufficient fill to uncover the zone. The purpose of this work/sundry is to perforate 4 sands in the Beluga. Notes Regarding Wellbore Condition • Well is currently not flowing. Well has produced sand and is currently covering the perforations. E -line Procedure: 1. MIRU E -line, PT lubricator to 2,000 psi Hi 250 Low. a. Tree connection is 2.5" Bowen. 2. RU 1-11/16" 6 spf Owen strip gun (will use 1 each 10' gun). 3. RIH and perforate Beluga (47-6) interval from 4,750'-4,760' (1 run, total of 6 spf). 4. RU 1-11/16" 6 spf Owen strip gun (will use 1 each 10' gun). 5. RIH and perforate Beluga (44-1) interval from 4,565-4,575' (1 run, total of 6 spf). 6. RU 1-11/16" 6 spf Owen strip gun (will use 1 each 15' gun). 7. RIH and perforate Beluga (39-1) interval from 4,110'-4,125' (1 run, total of 6 spf). 8. RU 1-11/16" 6 spf Owen strip gun (will use 1 each 9' gun). 9. RIH and perforate Beluga (36-9A) interval from 3,684'-3,693' (1 run, total of 6 spf). a. Bleed tubing pressure to 500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. d. Correlate using SLB TDT Log (dated 11/16/96). e. Use Gamma/CCL/ to correlate. f. Record tubing pressures before and after each perforating run. Well Prognosis Well: SRU 12-15 HilcorD Alaska, LL, Date: 7/14/2014 g. Distance to nearest well open in same sands = None (plugged back in SRU 32A-15). h. Spacing allowance is based on 20 AAC 25.055(a)(4), Undef Beluga Gas Pool. 10. RD E -line. 11. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic • Hileorp Alaska, LLC DV 150 RKB to TBG Head = 21.20' ACTUAL SCHEMATIC PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" 2-7/8" X 2-38" BT&C crossover 1 2498' Surf 30' 13-3/8" 54.5 J-55 8rd Surf 3167' Baker FH Ret packer, 2-3/8" X 7" 26# 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line from surf to 2498' JEWELRY DETAIL NO. Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1000 psi chem inj valve 2 5399' Macco 2-3/8" D -SO GLM w/1" dummy 3 5447' Baker FH Ret packer, 2-3/8" X 7" 26# @ 5395' PERFORATION DATA DATE TOP BTM ZONE ,ie -in log = Schlumberger TDT 11/16/96 0/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 19/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Revised: 6/18/14 Updated by STP 7/09/14 • Hilcorp Alaska, LLC RKB to TBG Head = 21.20' Tree connection: TC -3 Uni-bolt 2.5' C C M M T T DV @ 1508' r-ROPOSED SCHEMATIL. TOC @2000' Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" 44-1 sand JEWELRY DETAIL Surf 30' TDT 11/16/96 13-3/8" 54.5 J-55 8rd Surf 3167' 50-6 sand 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf 5,480' cut PBTD = 11,182' TD = 11,383' Straight hole, Max angle =1° Downhole Proposed Updated by STP 7/14/14 36-9A sand with 3/8" methanol inj line from surf to 2498' = 39-1 sand TOP BTM 44-1 sand JEWELRY DETAIL 47-6 sand NO. Depth Item = Schlumberger TDT 11/16/96 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 2 22' 2-7/8" X 2-38" BT&C crossover 3,684' 3,693' 50-6 sand 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl 1-11/16" Shogun Spiral w/1000 psi chem inj valve 4,110' 4,125' 3 2 4950' CIBP (capped w/ 35' of cement) sr, =• �� Tag Fill P Omp d _..rU..._ 3 5399' Macco 2-3/8" D -SO GLM w/1" dummy @ 4,967' 4,575' 4 4 5447' Baker FH Ret packer, 2-3/8" X 7" 26# 6/18/14 Proposed 4,750' 4,760' Cmt Top @ 5395' PBTD = 11,182' TD = 11,383' Straight hole, Max angle =1° Downhole Proposed Updated by STP 7/14/14 PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 Proposed 3,684' 3,693' Beluga (36-9A) 1-11/16" Shogun Spiral Proposed 4,110' 4,125' Beluga (39-1) 1-11/16" Shogun Spiral P Omp d _..rU..._ Proposed 4,565' 4,575' Beluga (44-1) 1-11/16" Shogun Spiral Proposed 4,750' 4,760' Beluga (47-6) 1-11/16" Shogun Spiral above 10/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral DV @ 8007' 09/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral PBTD = 11,182' TD = 11,383' Straight hole, Max angle =1° Downhole Proposed Updated by STP 7/14/14 Davies, Stephen F (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Wednesday, July 16, 2014 1:10 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, SRU 12-15 will be the only well open to the Beluga in that governmental section (Section 15, pending the plugback of SRU 32A-15). The nearest well open in the Beluga is SRU 23-22, completed in the Beluga 51-9 sand and is located 5,750' away in Section 22. Stan From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, July 15, 2014 2:46 PM To: Stan Porhola Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Stan, From your email dated July 11th (below), I had the impression that the plan forward was to plug back SRU 12-15, which is currently open in the Beluga, and then recomplete the well in Sterling reservoir sands following establishment of pool rules for the Sterling. The Sundry Application submitted yesterday by Hilcorp for SRU 12-15 states that the purpose of the sundry is to perforate four Beluga sands. Assuming the Beluga sands currently open to SRU 32A-15 well are plugged according to the operations plan in Sundry Application 314-419 (application received July 14, 2014 and currently in AOGCC's review process, with operations scheduled to begin July 18`h), what then will be the nearest well to SRU 12-15 that is open to the Beluga? Will SRU 12-15 be the only well open in that governmental section? Spacing for SRU 12-15 is regulated by 20 AAC 25.055 for all reservoirs except the Hemlock Oil Pool. Thanks for clarifying this. Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Stan Porhola [mailto:sporhola0)hilcorp.com] Sent: Monday, July 14, 2014 12:00 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, July 15, 2014 2:46 PM To: 'Stan Porhola' Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Sta n, From your email dated July 11`h (below), I had the impression that the plan forward was to plug back SRU 12-15, which is currently open in the Beluga, and then recomplete the well in Sterling reservoir sands following establishment of pool rules for the Sterling. The Sundry Application submitted yesterday by Hilcorp for SRU 12-15 states that the purpose of the sundry is to perforate four Beluga sands. Assuming the Beluga sands currently open to SRU 32A-15 well are plugged according to the operations plan in Sundry Application 314-419 (application received July 14, 2014 and currently in AOGCC's review process, with operations scheduled to begin July 18`), what then will be the nearest well to SRU 12-15 that is open to the Beluga? Will SRU 12-15 be the only well open in that governmental section? Spacing for SRU 12-15 is regulated by 20 AAC 25.055 for all reservoirs except the Hemlock Oil Pool. Thanks for clarifying this. Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Monday, July 14, 2014 12:00 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Will be submitting sundries per Option #2 as outlined below (including a withdrawal of the SRU 12-15 sundry already sent). Stan From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 14, 2014 9:28 AM To: Stan Porhola Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Stan, Option 2 would result in the clearest record. Steve bavies AOGCC From: Stan Porhola [mailto:sporhola(alhilcorp.com] Sent: Monday, July 14, 2014 9:23 AM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Which way do you recommend: Option #1: 1.) Submit sundry for plugback of SRU 32A-15. 2.) Submit revised sundry for plugback and perf of SRU 12-15. Or Option #2: 1.) Submit sundry for plugback of SRU 32A-15. 2.) Submit sundry for plugback of SRU 12-15. 3.) Submit sundry for perf of SRU 12-15. Stan From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 14, 2014 8:59 AM To: Stan Porhola Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Stan, Will Hilcorp submit a revised Sundry Application with an altered work program requesting approval for only the planned plugback operations? Steve Davies AOGCC From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, July 11, 2014 3:37 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Plan forward will be to plugback the SRU 32A-15 well (separate sundry to be submitted). We are planning to plugback this well (currently open in the Beluga) and recomplete in the Sterling (following the establishment of pool rules for the Sterling). Sta n From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, July 11, 2014 2:47 PM 2 Davies, Stephen F (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Friday, July 11, 2014 3:37 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Plan forward will be to plugback the SRU 32A-15 well (separate sundry to be submitted). We are planning to plugback this well (currently open in the Beluga) and recomplete in the Sterling (following the establishment of pool rules for the Sterling). Stan From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, July 11, 2014 2:47 PM To: Stan Porhola Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Stan, There are no pool rules for the Beluga and Tyonek gas sands in Swanson River Field. I cannot find any record of a spacing exception for either of these two wells. Steve Davies AOGCC From: Stan Porhola [mailto:sporhola(a)hilcorp.com] Sent: Friday, July 11, 2014 1:59 PIA To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 Sundry Application: Spacing Question / Request Nearest well open to the Beluga is SRU 32A-15 (PTD 194-084) and is located 80' from the SRU 12-15 well. Was a spacing exception made for these wells in the past? My understanding is there are no pool rules for these gas sands in Swanson River. Stan From: Davies, Stephen F (DOA) [mai Ito: steve.davies@alaska.gov] Sent: Friday, July 11, 2014 1:48 PM To: Stan Porhola Subject: SRU 12-15 Sundry Application: Spacing Question / Request Stan, The Sundry Application for SRU 12-15 will open to production additional sands in the Beluga Undefined Gas Pool. Regulation 20 AAC 25.055(a)(4) specifies one well completed in a given pool on any governmental section and no closer than 3000' to any well drilling to or capable of producing from the same pool. Will SRU 12-15 conform to these two criteria for the Beluga Undefined Gas Pool? Please provide the name of the closest well to SRU 12-15 that is open to the Beluga Undefined Gas Pool. Please provide the distance from SRU 12-15 to that well within the pool. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUL 10 2014 AOCCC 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well El Change Approved Program ❑ Suspend ❑ Plug Perforations Perforate Pull Tubing❑ Time Extension ❑ Operations Shutdovo ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing[] Other: 2. Operator Name: 4. Current Well Class: 5. Perm Drill Number. Hilcorp Alaska, LLC Exploratory 11Development 0 Stratigraphic 1-1ServiceEl 160-022 3. Address: 3800 Centerpoint Drive, Suite 100 API Number: Anchorage, Alaska 99503 50-133-10138-00 ; 7. If perforating: 8. W904ame and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a)(4) Will planned perforations require a spacing exception? Yes ❑ No ❑� Swanson River Unit (SRU) 12-15 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 wanson River Field ! Undef Beluga Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Ef clivy Depth TVD (ft): Plugs (measured): Junk (measured): 11,383' 11,383' 5,395 5,395' 1 5,395' N/A Casing Length Size < MD TVD Burst Collapse Structural Conductor 30' 22" >. > 0' 30' Surface 3,173' 13-3/8" 3,173' 2,730 psi 1,130 psi Intermediate 82' 11,382' Production 11,382' 7"V\2 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft)� Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Sch atic8" 4.6# / L-80 5,480 Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): ✓' J FHS Packer; N/A 5,447' MD & TVD, N/A 12. Attachments: Description SummaryP Proposal ❑✓ 13. Well Class after proprsed work: Detailed Operations Program ❑ QOP Sketch ❑ a Exploratory ❑ Stratigraphic❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: \ Commencing Operations: V� 07/16/14 " \ Oil ❑ Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Dat ,� Commission Representative: �� ;t GSTOR ❑ SPLUG ❑ o 17. 1 hereby certify that the foregoingNtrue an 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 Io Signature G Phone 907-777-8412 Date COMMISSION USE ONLY Conditions of approval: Notify Commissi n so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes i(❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 1 %4 � .. �NmA Submit Form and Form 10-403 (Revised 10/2012) A■^i„ii{",JTn� � t 12 months from the date of approval. t c inu I' at 6 2 4 Hileorp Alaska, M Well Prognosis Well: SRU 12-15 Date: 7/10/2014 Well Name: SRU 12-15 API Number: 50-133-10138-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: July 16`h, 2014 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-022 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: 1,000 psi @ 5,015' TVD Maximum Expected BHP: — 2,100 psi @ 4,750' TVD Max. Allowable Surface Pressure: — 1,625 psi Brief Well Summary (Based on cumulative gas production along P/Z curve and tubing pressure.) (Based on offset wells (Based on actual reservoir conditions and gas gradient (0.10psi/ft)) Swanson River Unit 12-15 was drilled as an oil well in 1960 in the Hemlock. The Hemlock was abandoned in 1996 and the well recompleted in the Tyonek gas sands. A posiset plug was set in 1999 to isolate the lower Tyonek gas sands. The Beluga 56-0 was perforated below the tubing tail in April 2003 and was found to be unproductive. A cement packer was set in September 2003 and the well was completed thru-tubing in the Beluga 50-6. The zone was re - perforated in October 2013, but recently sanded up. Recent bailing operations were unable to remove sufficient fill to uncover the zone. The purpose of this work/sundry is to plugback the Beluga 50-6 and perforate 3 sands in the Beluga. Notes Regarding Wellbore Condition • Well is currently not flowing. Well has produced sand and is currently covering the perforations. Slickline Procedure: 1. MIRU Slickline, PT Lubricator to 2,000 psi Hi 250 Low. 2. RU 1.75" gauge ring, RIH and tag fill at +/-4,967'. 3. RU tubing stop/plug for 2-3/8" tubing, RIH and set at +/- 4,950'. Bleed off tubing pressure. 4. Dump bail 35' of cement on tubing plug (6 gallons of cement). 5. Wait on cement for 12 hours. 6. RU 1.75" bailer and tag top of cement. 7. RIH w/ 2-3/8" swab cups. Swab fluid down to +/- 4,800'. 8. RD Slickline. E -line Procedure: 9. MIRU E -line, PT lubricator to 2,000 psi Hi 250 Low. a. Tree connection is 2.5" Bowen. 10. RU 1-11/16" 6 spf Owen strip gun (will use 1 each 10' gun). 11. RIH and perforate Beluga (47-6) interval from 4,750'-4,760' (1 run, total of 6 spf). 12. RU 1-11/16" 6 spf Owen strip gun (will use 1 each 10' gun). 13 14 15 Well Prognosis Well: SRU 12-15 Date: 7/10/2014 RIH and perforate Beluga (44-1) interval from 4,565'-4,575' (1 run, total of 6 spf). RU 1-11/16" 6 spf Owen strip gun (will use 1 each 15' gun). RIH and perforate Beluga (39-1) interval from 4,110'-4,125' (1 run, total of 6 spf). a. Bleed tubing pressure to 500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB TDT Log (dated 11/16/96). e. Use Gamma/CCL/ to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands = None. h. Spacing allowance is based on 20 AAC 25.055(a)(4), Undef Beluga Gas Pool. 16. RD E -line. 17. Turn well over to production. Attnrhmantc- 1. As -built Schematic 2. Proposed Schematic DV 150 I ACTUAL SCHEMATIC Hilcorp Alaska, LLC RKB to TBG Head = 21.20' PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" w/1000 psi chem inj valve 2 5399' Surf 30' Baker FH Ret packer, 2-3/8" X 7" 26# 13-3/8" 54.5 J-55 8rd Surf 3167' 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1 1755' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line from surf to 2498' JEWELRY DETAIL NO. Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1000 psi chem inj valve 2 5399' Macco 2-3/8" D -SO GLM w/1" dummy 3 5447' Baker FH Ret packer, 2-3/8" X 7" 26# @ 5395' PERFORATION DATA DATE TOP BTM ZONE 'ie -in log = Schlumberger TDT 11/16/96 0/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 9/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Revised: 6/18/14 Updated by STP 7/09/14 PROPOSED SCHEMATIC Hileorp Alaska, LIX RKB to TBG Head = 21.20' Tree connection: TC -3 Uni-bolt 2.5" Bc C C M M T T DV @ 1508' LjTOC @2000• Tag Fill' @ 4,967' 6/18/14 800 sx pumped above DV @ 8007' Yom• - 39-1 sand 44-1 sand rye, r 47-6 sand 2 ti tirtis 50-6 sand Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" Tie-in log = Schlumberger TDT 11/16/96 Surf 30' Proposed 13-3/8" 54.5 J-55 8rd Surf 3167' 4,575' 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line from surf to 2498' JEWELRY DETAIL NO. Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SMO- I C I Chem Inj Mdrl w/1000 psi chem inj valve 3 2 4950' CIBP (capped w/ 35' of cement) 4 3 5399' Macco 2-3/8" D -SO GLM w/1" dummy 4 5447' Baker FH Ret packer, 2-3/8" X 7" 26# Cmt Top @ 5395' PBTD = 11,182' TD = 11,383' Straight hole, Max angle = 1° Downhole Proposed Updated by STP 7/10/14 PERFORATION DATA DATE TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 Proposed 4,110' 4,125' Beluga. (39-1) 1-11/16" Shogun Spiral Proposed 4,565' 4,575' Beluga (44-1) 1-11/16" Shogun Spiral Proposed 4,750' 4,760' Beluga (47-6) 1-11/16" Shogun Spiral 10/30/13 5,000' 5,015' Beluga (50-6) 1-11/16" Shogun Spiral 09/16/03 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral Downhole Proposed Updated by STP 7/10/14 Davies, Stephen F (DOA) From: Donna Ambruz <dambruz@hilcorp.com> Sent: Monday, July 14, 2014 2:18 PM To: Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Cc: Stan Porhola Subject: Swanson River Unit (SRU) 12-15 - PTD 160-022 Attachments: SRU 12-15 AOGCC 10-403 Submitted Plugback 7-14-14.pdf; SRU 12-15 AOGCC 10-403 Submited Perf 7-14-14.pdf Guy — Please withdraw the 10-403 Application for Sundry Approval to Plug Perforations/Perforate submitted for SRU 12-15 last Thursday, July 101h and replace with two separate 10-403 Applications (copies attached) which are being sent to you this afternoon (July 14) by AMS courier. Thank you. lDomm Ct"d"U'UZ 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 Davies, Stephen F (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, July 14, 2014 12:00 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Will be submitting sundries per Option #2 as outlined below (including a withdrawal of the SRU 12-15 sundry already sent). Sta n From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, July 14, 2014 9:28 AM To: Stan Porhola Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Sta n, Option 2 would result in the clearest record. Steve Davies AOGCC From: Stan Porhola [mailto:sporholaCabhilcorp.com] Sent: Monday, July 14, 2014 9:23 AM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Which way do you recommend: Option #1: 1.) Submit sundry for plugback of SRU 32A-15. 2.) Submit revised sundry for plugback and perf of SRU 12-15. Or Option #2: 1.) Submit sundry for plugback of SRU 32A-15. 2.) Submit sundry for plugback of SRU 12-15. 3.) Submit sundry for perf of SRU 12-15. Stan From: Davies, Stephen F (DOA) [ma iIto: steve.davies@alaska.gov] Sent: Monday, July 14, 2014 8:59 AM To: Stan Porhola Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Stan, Will Hilcorp submit a revised Sundry Application with an altered work program requesting approval for only the planned plugback operations? Steve Davies AOGCC From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, July 11, 2014 3:37 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Steve, Plan forward will be to plugback the SRU 32A-15 well (separate sundry to be submitted). We are planning to plugback this well (currently open in the Beluga) and recomplete in the Sterling (following the establishment of pool rules for the Sterling). Sta n From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, July 11, 2014 2:47 PM To: Stan Porhola Subject: RE: SRU 12-15 (PTD #160-022) Sundry Application: Spacing Question / Request Stan, There are no pool rules for the Beluga and Tyonek gas sands in Swanson River Field. I cannot find any record of a spacing exception for either of these two wells. Steve Davies AOGCC From: Stan Porhola [mailto:sporholaCgbhilcorp.com] Sent: Friday, July 11, 2014 1:59 PM To: Davies, Stephen F (DOA) Subject: RE: SRU 12-15 Sundry Application: Spacing Question / Request Nearest well open to the Beluga is SRU 32A-15 (PTD 194-084) and is located 80' from the SRU 12-15 well. Was a spacing exception made for these wells in the past? My understanding is there are no pool rules for these gas sands in Swanson River. Stan From: Davies, Stephen F (DOA)[ma iIto: steve.davies(&alaska.gov] Sent: Friday, July 11, 2014 1:48 PM To: Stan Porhola Subject: SRU 12-15 Sundry Application: Spacing Question / Request 2 Sta n, The Sundry Application for SRU 12-15 will open to production additional sands in the Beluga Undefined Gas Pool. Regulation 20 AAC 25.055(a)(4) specifies one well completed in a given pool on any governmental section and no closer than 3000' to any well drilling to or capable of producing from the same pool. Will SRU 12-15 conform to these two criteria for the Beluga Undefined Gas Pool? Please provide the name of the closest well to SRU 12-15 that is open to the Beluga Undefined Gas Pool. Please provide the distance from SRU 12-15 to that well within the pool. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. • STATE OF ALASKA RECEIVED AL .AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NOV 2 6 2013 1.Operations Abandon U Repair Well U Plug Perforations Lf Perforate I ( Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 160-022 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10138-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 Swanson River Unit(SRU)12-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Beluga Undef Gas' 11.Present Well Condition Summary: Total Depth measured 11,383 feet Plugs measured 5,395 feet true vertical 11,383 feet Junk measured N/A feet Effective Depth measured 5,395 feet Packer measured 5,447 feet true vertical 5,395 feet true vertical 5,447 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 3,173' 13-3/8" 3,173' 3,173' 2,730 psi 1,130 psi Intermediate Production 11,382' 7" 11,382' 11,382' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached SchematicWOW APR 2 4 Z51 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/L-80 5,480'MD 5,480'ND Packers and SSSV(type,measured and true vertical depth) FH Packer;N/A 5,477'MD 5,447'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 11 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 98 0 0 140 Subsequent to operation: 0 286 0 60 500 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑✓ ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q• WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-560 Contact Stan Porhola Email sporholaehilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date (\/L 5 1.3I � ' i(• Z3'l y EV--,M S`� DEC 13 2013 Form 10-404 Revised 10/2012 7 ,,/ Submit Original Only 1:1Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 12-15 50-133-10138-00 160-022 10/30/13 10/30/13 Daily Operations: 10/30/2013 -Wednesday Rig up lubricator and PT to 250 psi low and 3000 psi high. RIH with 1-11/16" x 5' strip gun and tie into SLB Thermal Decay Time Log dated 16-Nov-96. Could not run below 5,017'. Called town and decision made to perf from 5,015'to 5,000'. Made 3 5' runs with TP at 250 psi. Saw no PSI change on ony run. Fluid level approx 3,600'. Rig down Pollard lubricator. Swanson River Unit Well: SRU 12 15 ACTUAL SCHEMATIC Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 Hilcorp Alaska,LLC RKB to TBG Head=21.20' SIZE WT GRADE CONN TOP BTM LENGTH Tree connection: TC-3 Uni-bolt 22" Surf 30' C C / 13-3/8" 54.5 J-55 8rd Surf 3167' M M , 7" 29 N-80 Buttress Surf 303' 303' T 7" 26 N-80 Buttress 303' 1197' 894' TOC @2000 4:4:, ..%4 i. , 7" 23 N-80 Buttress 1197' 4750' 3553' DV @ L 4., .i•L 1 s. 7" 26 N-80 Buttress 4750' 6160' 1410' 1508' +r- 7" 29 N-80 Buttress 6160' 7879' 1719' L4,4*''' h 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' —L' „14 ,_,A 7 Tubing: 7 ,;r 50-6 sand 2-3/8” 4.6 L-80 SC BT&C Surf 5,480'(cut) Tag Fill , ' ',.r with 3/8"methanol inj line from surf to 2498' @ 5,012' to;+ 2Cmt Top @ 5395' 11/02/13 It . , JEWELRY DETAIL " 3 NO. Depth Item ` "" " ' = 21.20' 2-7/8"hgrw/Cameron"H"BPV profile 22' 2-7/8"X 2-38"BT&C crossover 1 2498' Macco 2-3/8"SMO-1C1 Chem Inj Mdrl C I w/1000 psi chem inj valve 4` I 2 5399' Macco 2-3/8"D-SO GLM w/1"dummy 3 5447' Baker FH Ret packer,2-3/8"X 7"26# N ` T 800 sx .- PERFORATION DATA pumped DATE TOP BTM ZONE above 'AYE Tie-in log=Schlumberger TDT 11/16/96 DV @ 8007' I- *10/30/13 5,000' 5,015' Beluga(50-6) 1-11/16"Shogun Spiral V 09/16/03 5,015' 5,019' Beluga(50-6) 1-11/16"PJ Spiral 110- 1 lisp-M4 111 PBTD=11,182' TD=11,383' Straight hole,Max angle=1° Downhole Revised:10/30/13 Updated by STP 11/19/13 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,October 25,2013 3:57 PM To: 'Stan Porhola' Subject: RE:Verbal Approval request to perforate SRU 12-15 (PTD 160-022) You have verbal approval to perforate SRU 12-15 as proposed. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell SCANNED 907-793-1226 office From: Stan Porhola [mailto:sporhola@Thilcorp.com] Sent: Friday, October 25, 2013 3:52 PM To: Schwartz, Guy L(DOA) Subject: Verbal Approval request to perforate SRU 12-15 (PTD 160-022) Guy, We are requesting verbal approval to perforate SRU 12-15(PTD 160-022).Our anticipated start date is now 10/27/13.A sundry was submitted on 10/22/13. Regards, Stan Porhola I Operations ingineer North Kenai Asset Team Hilcorp Alaska, LLC sporholajthilcorTicon1 Office: (907) 777-8,112 Mobile: (907) 331-8228 1 THE STATE OIALASKA GOVERNOR SEAN PARNELL �,t Stan Porhoia SCANNED NOV 0 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100' V �� Anchorage, AK 99503 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: Swanson River Field, Beluga/Tyonek Undefined Gas, Hemlock Oil Pool, SRU 12-15 Sundry Number: 313-560 Dear Mr. Porhola: 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, P Cathy P. oerster Chair, Commissioner DATED this � day of October, 2013. Encl. 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO Is APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 T 2 2 2013 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair WeM❑ EWMhi1Ak%'rogram ❑ Suspend ❑ Plug Perforations ❑ Perforate Q Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing❑ Other ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory E] Development Q Stratigraphic El Service ❑ 160-022 ,. 3. Address: 3800 Centerpoint Drive, Suite 100 6• API Number. 50-133-10138-00 Anchorage, Alaska 99503 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 1236 Swanson River Unit (SRU)12-15 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field/Pool(s): _YWV--K IJ L• . 6--!, '�'", 1 10IL4I River Field / Beluga Undef Gas 0 FEDA028406 . Swanson meIIJ( 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,383' 11,383' 5,395' 5,395' 5,395' NIA Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 22" 30' 30 Surface 3,173' 13-3/8" 3,173' 3,173' 2,730 psi 1,130 psi Intermediate Production 11,382' 7" 11,382' 11,382 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6# I L-80 5,480 Packers and SSSV Type: Packers and SSSV MD (t) and ND (Ity FH Packer; N/A 5,447 MD & ND; N/A 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14. Estimated Date for 15. Well Status after proposed wont: Commencing Operations: 10/25/13 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. Contact Stan Porhola Phone. 907-777-8412 Email sDorho1aQhiIc2M&M Printed Name Stan Por la Title Operations Engineer II . 2 -2 - Signature Phone 907-777-8412 Date l (.9/2 - 2 - COMMISSION USE ONLY COMMISSION Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBEMS NOV -1 2W'3 - 3Spacing Spacing Exception Required? Yes ❑ No 2f/ Subsequent Form Required: d APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: l b ' 2 �• I PM I 21 Submit Form and Form 10-403 (Revised 10/2012) Approve! a�op LS tVnths from the da of approva�Attachments in Duplicate Hilcorp Alaska, LLI Well Prognosis Well: SRU 12-15 Date: 10/22/2013 Well Name: SRU 12-15 AN Number: 50-133-10138-00 Current Status: Gas Well Leg: N/A Estimated Start Date: October 24th, 2013 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-022 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP Max. Allowable Surface Pressure Brief Well Summary 1,000 psi @ 5,015' TVD 1,000 psi @ 5, 015' TVD 499 psi (Based on cumulative gas production along P/Z curve and tubing pressure.) (Based on cumulative gas production along P/Z curve and tubing pressure.) (Based on actual reservoir conditions and gas gradient (0.10psi/ft)) Swanson River Unit 12-15 was drilled as an oil well in 1960 in the Hemlock. The Hemlock was abandoned in 1996 and the well recompleted in the Tyonek gas sands. A posiset plug was set in 1999 to isolate the lower Tyonek gas sands. The Beluga 56-0 was perforated below the tubing tail in April 2003 and was found to be unproductive. A cement packer was set in September 2003 and the well was completed thru-tubing in the Beluga 50-6. Notes Regarding Wellbore Condition • Well is currently not flowing. Well has produced sand. Perforations may be plugged/damaged. OBJECTIVE OF WORKOVER Re-perf and add new perfs in the Beluga 50-6 gas sand. E -line Procedure: 1. MIRU E -line, PT lubricator to 3,000 psi Hi 250 Low. 2. RU 1-11/16" 6 spf strip wireline guns. V/ 3. RIH and perforate Beluga 50-6 interval from 5,000'-5,020' (20'). a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Utilize Pressure/Temperature tool on 15t run for each interval. d. Record tubing pressures before and after each perforating run. 4. RD E -line. 5. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic DV 150 • • ACTUAL SCHEMATIC Hileorp Alaska, LLC RKB to TBG Head = 21.20' Tree connection: TC -3 Uni-bolt PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" 2-7/8" X 2-38" BT&C crossover 1 2498' Surf 30' 13-3/8" 54.5 J-55 8rd Surf 3167' Baker FH Ret packer, 2-3/8" X 7" 26# 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line trom surt to 2498' )p @ 5395' JEWELRY DETAIL NO Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SMO -1C1 Chem Inj Mdrl w/1000 psi chem inj valve 2 5399' Macco 2-3/8" D -SO GLM w/1" dummy 3 5447' Baker FH Ret packer, 2-3/8" X 7" 26# PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral, 7.5 spf, 45deg Downhole Revised: 11/01/03 Updated by STP 10/22/13 DV 150 0 0 PROPOSED SCHEMATIC Hilcorp Alaska, LLC RKB to TBG Head = 21.20' Tree connection: TC -3 Uni-bolt PBTD = 11,182' TD = 11,383' Straight hole, Max angle = V Swanson River Unit Well: SRU 12-15 Completion Ran: 11/01/03 PTD: 160-022 API: 50-133-10138-00 SIZE WT GRADE CONN TOP BTM LENGTH 22" 2-7/8" X 2-38" BT&C crossover 1 2498' Surf 30' 13-3/8" 54.5 J-55 8rd Surf 3167' Baker FH Ret packer, 2-3/8" X 7" 26# 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 1197' 894' 7" 23 N-80 Buttress 1197' 1 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-110 8rd LT&C 7879' 9627' 1748' 7" 29 P-110 8rd LT&C 9627' 11382' 1755' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf 5,480' cut with 3/8" methanol inj line from surf to 2498' )p @ 5395' JEWELRY DETAIL NO Depth Item 21.20' 2-7/8" hgrw/Cameron "H" BPV profile 22' 2-7/8" X 2-38" BT&C crossover 1 2498' Macco 2-3/8" SM0-lC1 Chem Inj Mdrl w/1000 psi chem inj valve 2 5399' Macco 2-3/8" D -SO GLM w/1" dummy 3 5447' Baker FH Ret packer, 2-3/8" X 7" 26# PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 5,015' 5,019' Beluga (50-6) 1-11/16" PJ Spiral, 7.5 spf, 45deg 5,000' 5,020' Beluga (50-6) 1-11/16" Spiral (Proposed) Downhole Proposed Updated by STP 10/22/13 ... STATE OF ALASKA ... ALASKA _AND GAS CONSERVATION COM MISS_ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas[] Plugged 0 Abandoned 0 Suspended 0 WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development [] ExploratoryO GINJO WINJO WDSPL 0 No. of Completions Other Service 0 Stratigraphic TestO 2. Operator Name: 5. Date Comp, Susp, Aband 12. Permit to Drill Number: Union Oil Company of California December 5,1996 160-022 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 Jul-60 50-133-10138-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: - Surface: 2,285' FNL, 1,054' FEL, Sec. 15, T8N, R9W, SBM October 5, 1996 SRU 12-15 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 2,285' FNL, 1,054' FEL, Sec. 15, T8N, R9W, SBM RKB to tbg head 21.20' Swanson River Field/Beluga Total Depth: 9. Plug Back Depth(MD+ TVD): 2,285' FNL, 1,054' FEL, Sec. 15, T8N, R9W, SBM 5,016'/5,016' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 348,908 y- 2,480,077 11,383'/11,383' Swanson River Production Facility TPI: x- 348,908 y- 2,480,077 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 348,908 y- 2,480,077 n/a A-028406 18. Directional Survey: Yes LJ No [] Straight hole 19. Water Depth, if Offshore: 20. Thickness of Permafrost: n/a feet MSL n/a 21. Logs Run: none 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 22" 0 30 0 30' 13-3/8" 54.4# J-55 0 3,167' 0 3,167' 17.5 See Schematic 7" 23,26,29 N-ßO,P-110 0 11 ,382' 0 11,382' 12.25 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 5,016 to 5,018' TDITVD; see schematic for details. 2-3/8" 5,480' 5,447' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .'","\¡'':¡~'''.'' r>} DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ",<,n',';;.", ~Y!i n/a 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): December 20, 2003 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: 1 Gas-Oil Ratio: 12/20/2003 1/24/1900 Test Period ..... 0 825 0 n/a Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (carr): Press. 1,000 24-Hour Rate ..... 0 825 0 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit care chips; if none, state "none". none --- -- _co .._~ w~lllM~ DrL MAt< 1 í LUUb ~ Form 10-407 Revised 12/2003 AFE 16119511'61196 CONTI UED ON REVERSE 28. GEOLOGIC MARKERS ~ NAME MD" TVD Bel uga_MJF 3499 3499 Mid_Beluga_MJF 4561 4561 56-0 5560 5560 56-05B 5580 5580 Tyonek 5638 5638 53-Ocr 5641 5641 Tyonek 5854 5854 56-9ST 6069 6069 59-2 6277 6277 61-6cr 6500 6500 68-05T 7218 7218 77-3 8130 8130 80- 2ST 8401 8401 G1T 10885 10885 Base_Tyonek 11025 11025 Hemlock_MJF 11043 11043 H6B 11186 11186 H7T 11194 11194 H8B 11297 11297 H9B 11313 11313 HlOT 11327 11327 30. List of Attachments: wellbore schematic, daily summary 29. /' rORMATION TESTS Include and briefly sum e test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were canducted, state "None". none 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Contact: Steve Tyler Title: Drilling Manager Phone: 907-276-7600 Date: Sundry Number or NIA if C.O. Exempt: 3-7: c.?<.:." 303-189 INSTRUCTIONS General: This form is designed for submitting a complete and carrect well campletion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well campletion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool campletely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is campleted for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cares taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 AFE 161195 RKB to TBG Head = 21.20' Tree connection:· TC-3 U ni-bolt DV@ 1508' 4 TOC isolation plug@ - 5,100' 2 3 5 6 7 8 9 10 11 PBTD = 11,182' TD = 11,383' Straight hole, Max angle = 10 Surf 30' 54.5 J-55 8rd Surf 3167' 7" 29 N-80 Buttress Surf 303' 303' 7" 26 N-80 Buttress 303' 119?' 894' 7" 23 N-80 Buttress 1197' 4750' 3553' 7" 26 N-80 Buttress 4750' 6160' 1410' 7" 29 N-80 Buttress 6160' 7879' 1719' 7" 26 P-l10 8rd LT&C 7879' 9627' 1748' T' 29 P-110 8rd LT&C 9627' 11382' 1755' Tubin 2-3/8" 4.6 L-80 SC BT&C 5,480'(cut) with 3/8" methanol inj line rrom surf to 2498' 21.20' 22' 2498' 2-7/8" hgrlCameron "H" BPV profile 2-7/8" X 2-38" BT &C crossover Macco 2-3/8" SMO-ICl Chern Inj Mdrl w/l 000 psi chern inj valve Macco 2-3/8" D-SO GLM w/J" dummy Baker FH Ret packer, 2-3/8" X 7" 26# 2 3 5399' 5447' 4 5 6 7 8 9 10 11 12 ~5, 1 00' 5,670' 7,084' 7,615' 10,581 ' 10,900' 10,967' 10,994' ! 1,155' TOC isolation plug (didn't tag) "PosiSet" Plug wi 10' Cement Top of cut tubing "PosiSet" Plug wi 37' Cement (dump bailer lost in plug) Top of cement plug, WLM tag 11/21/96 Cement Retainer, could not inject thru on 11/17/96 2- 7/8" tubing cut Production packer 2-7/8" tubing tail, venturi shoe 5,016' 5,018' Beluga 50-0 7.5 09/16/03 1- ¡ ¡¡I 6" pivot, 60-deg 5,530' 5,538' Beluga (56-0) Isolated 5,561 ' 5,578 Beluga (56-0) Isolated 6,172' 6,178' 58-1 01/8/02 Abandoned 6,488' 6,501 ' 61-3 01/08/02 Abandoned 8,433' 8,443' 80-2 12/3/96 Abandoned 11,043' 11,210' Hemlock 1960 Abandoned REVISED: 03/02/05 DED DRAWN BY: JWS 8/25/03 e e Attend Simops with production at plant and go over Plan forward of crCO. PJSM talk about problems and plan fwd - Check, start and warm equipment. PU and stab injector head. Pump 26 bbls thru coil checking returns (clean from start). Tech working on trouble shoot elect. Remove injector head cut 25' of coil and crimp end of coil and drill holes in coil above crimp to catch balls. Load 5/8" ball follow by a nerf ball in coil and pump 24 bbls at 1 bpm at 2840 psi (very little scale before balls hit) recovered both balls. M/up bha #1- tech found one loose wire and bad control valve tighten wire and chg out valve (function test bops all working from cab except blind rams, but will operate from accumulator- Stab injector head and test coil 4000 psi and choke manifold to 250/ 4000 psi (ok). PJSM with all hands and go over Clean out plan - Open well (1200 psi) Bring pump on line at .8 bpm at 3000 psi maintaining 1000 psi on choke -Wash f/ surface to 500' at 20-30 fpm with little resistance - pooh to 250' returns cleaned immediately - Rih to 500' and wash to 750' at 30-40 fpm and up pump rate to 1.1 bpm at 2740 psi by adding friction reducer and maintaining 900 psi on choke - Rih to 750' and wash to hard tag at 822' and part coil. Shut slips and pipe rams on coil - PJSM - bleed well down and Rig injector head back (Coil stub folded over its self at top of 7" bowen connection on top of bops). Call town and discuss options - strip out 96' coil with crane (pipe getting light). Prep both ends of coil for splice and wait on splice from town - install splice and bleed off annulus (770 psi). Install injector head and bleed off annulus (400 psi). Open rams and Pooh (ok) Inspect and remove bha and set back Injector head. Secure equipment and well. Shut down for crew rest. 8/26/03 PJSM On cutting off bad coil and plan fwd. PU injector head and position by coil tank and cut off 716' +- in 10-12' pieces. Install internal coil connector. Pull test to 12k (ok) test to 2,500 psi (ok) MU BHA #2. Stab Injector head and tag swab and set depth. PJSM on plan fwd on clean out. Break circulation and shell test to 4,000 psi and bleed back side back to 1,500 psi and test duel check valves (ok). Open well 1,700 psi (straight gas) shut in well and line up on kill line and bull head 35 bbls at max rate of 2 bpm at 2,000 psi. Monitor well. Bull head #2 45 bbls at 2.5 Bpm at 2950 psi. Monitor well and wait on slick line 2380 psi to 250 in one hour. Remove injector head and set back same and prep crane and BOPs for slick line. RU slick line unit on Schlumberger crane and Bops and test to 2500 psi with Schlumberger pump (OK). RIH with 1.75" drive down bailer (Hand spang unable to pass first master valve). Remove slick line lubricator and drain stack and observe obstruction at 163" from top of BOPs. LD SL lubricator and remove BOPs XOs and swab valve - recover 2 pieces of 1.5" coil tubing - each one approx 4" long and pitched flat at both ends. Re-install swab XOs and BOPs. RU slick line lubricator. Test lubricator and all brks to 3000 psi (ok). RIH with 1.75" Drive down bailer TO tag at 5572' WLM RKB -Work bailer- Pooh - Recover 1/2 bailer full sand mud jello. RD slick line and secure equipment and well - Have Production bring SRU 242-16 back on line 8/27/03 Shut down for crew rest. Attend Simops with production at plant and go over Plan forward of Coil tubing RD and #1 cement job. PJSM with support hands and Schlumberger on plan forward. Check well pressures tubing less then 10 psi (gas) and bleed off immediately, 7" X tubing annulus = 110 psi (air/gas) 9-5/8" X 7" annulus = less then 10 psi (slight blow gas/air). Wait on Loader to start RU cementers (In use by production). RU Schlumberger cementers. RD Schlumberger coil tubing and heat 200 bbls of water with steam on wheels. Test lines to top of top master valve to 5100 psi (ok this test brings the swab valve connection to top master back to a 5k rating) #3 bull head 40 bbls of fresh water with J-313 friction reducer (left over from coil job) down tubing at 5.4 bpm at 3415 psi - down pump Tubing pressure in two min = 2350 psi and falling Bleed pressure to slow (4 min) to zero (just shy of 3 bbls back) - blend Mix water - #4 Bull head 15 bbls of fresh water with J-313 at 3.8 bpm at 2570 psi - down pump and Batch up 60 sx cement slurry. Pump 10 bbls 50 sx class "G" cement at 15.8 ppg with .3 galjsx D065 + .4 galjsx D167 + .1 gal/sx D800 + .02 galjsx D47 at 4.4 bpm at 3516 psi - down pump and shut in well and flush line to well head clean - open well and displaced with 20.8 bbls fresh slick water - CIP at 1437 hrs with 2366 psi on tubing and falling - bleed 1 bbl slow in attempt to stabilize pressure Tubing = 1373 psi - monitor pressure 10 min to 1100 psi. Monitor pressure 1100 psi to 850 psi 10 min - 850 psi to 800 psi in 10 min - Bleed 1/4 bbl back Pressure 400 psi and still falling bleed 1/4 bbl back pressure 240 psi. Pump 13.2 gal methanol down chemical injection line and tubing pressure increased f/ 240 psi to 540 psi. RU on 7" X tubing annulus and pump 172.5 bbls and pressure up to 1500 psi (ok) tubing to 620 psi. Secure cement equipment, clean up and monitor pressures and finish RD coil equipment and secure well. Shut down for rest and wait on cement (24hrs). SRU 12-15, 161195 morning report summary, CONFIDENTIAL: last revised 3/2/2006, Page 1. e e 8/28/03 Attend Simops with production at plant and go over Plan forward. Tubing perf, logistics and quizzed them on will 12-15 be ready to flow by 9/1/03 as in flow line, heater, choke and methanol pump. PJSM with Nabors and Peak hand. Check well pressures tubing = 690 psi, 7" X tubing annulus = 1900 psi and 7" X 13-3/8" annulus = less then 10 psi blow of gas/air- check temp cement water 74 deg. Clean location and prep for slickline and e-line. Load trailers for Happy Valley and chase trucks. Set and spot clean batch mixer. Haul off and return rental light plant. Spot and set APRS e-line unit and Pollard boom truck and slickline unit in containment and r/up same. Check and warm Sèhlumberger cement equipment. PJSM on test of P&A cement plug. S/L tag and E-line perf- Bleed 7" X tubing annulus back down to 1500 psi and prime pump. Pump down tubing 1/4 bbl and test P&A cement plug of 56-0 sand to 2055 psi to 2010 psi in 30 min on chart (ok). Pressure test S/L lubricator to 2000 psi (ok) Rih #1 with 1.75 gauge ring and set down at 4719' WLM RKB and work GR to 4773' WLM RKB - POOH. RIH #2 with 1.75" drive down bailer and set down at 4777' RKB and work bailer to 4796' RKB couldn't pass. Pooh--full bailer of soupy like contaminated cement. RIH #3 with 1.75" drive down bailer and set down at 4798' RKB and work bailer - couldn't pass - Pooh - 1/2 bailer of contaminated cement. RIH #4 with 1.75" drive down bailer and set down at 4802' RKB and work bailer couldn't pass - Pooh - full bailer of contaminated cement. RIH #5 with 1.78" GR and set down at 4804' RKB - Pooh. RIH #6 with 1.75" drive down bailer and set down at 4804' RKB and work bailer to 4805' RKB couldn't pass - Pooh - 1/4 bailer of soupy like contaminated cement. RIH #7 with 1.75" drive down bailer and set down at 4806' RKB and work bailer to 4808' RKB couldn't pass - Pooh - 1/4 bailer of soupy like contaminated cement. RIH #8 with 1.75" drive down bailer and set down at 4810' RKB and work bailer to 4811' RKB couldn't pass - Pooh - 1/2 bailer of soupy like contaminated cement. RIH #9 with 1.86" GR and set down at 4812' RKB - Pooh. RIH #10 with 1.75" drive down bailer and set down at 4812' RKB and work bailer to 4814' RKB couldn't pass - Pooh - full bailer of soupy like contaminated cement. RD and move S/L equipment to bull rail. Last report for abandonment AFE # 161195. Released equipment to recomplete AFE #161196. 8/29/03 Attend SIMOPS with production at plant and go over plan forward of coil tubing. RU to clean out cement and timing and travel to location. Check well pressures 25 psi gas on tubing and bleeds off immediately, 7" x tubing annulus = 1600 psi and 9-5/8" X 7" annulus less then 10 psi. Mobe coil tubing unit (unit except dirty batch mixer, 1.5" coil and pump was left in field). Travel to location. PJSM with support hands and go over plan forward. PJSM. RU 1.5" coil tubing unit and bleed air/gas cap off 7" X tubing annulus 1600 psi to 90 psi (fluid returns and shut in). Move in and spot 1.5" coil tubing equipment. RU coil tubing unit. Stab coil injector. Install internal coil connector and pull test same to 15,000 Ibs (ok). Test BOPs 250/3000 psi (ok), load coil with fresh water and pressure test connector to 2,500 psi (ok). Bleed air cap off 7" X tubing annulus from 500 psi to slight blow and pump 4 bbls fresh water into same to 1200 psi shut in and let flop secure equipment and well. 8/30/03 PJSM. Start and warm equipment check well pressures 7" X tubing annulus = 900 psi bleed air to fluid returns and shut in at 690 psi. PU injector head made up lubricator and extra joint. Drifted and check BHA with proper balls (5/8 ball disconnect and 7/16" circ sub) and MU BHA. Pressure test to 2500 psi (ok). Open well. No well pressure. RIH at 40-50 fpm with BHA #3 at min rate 1/4 bpm 500 psi with fresh water with J-313 friction reducer. Noting jewelry and weight checks. SD at 4,803' CfM RKB. Clout cement from 4,803' to 4,955' taking 10' to 20' bits and working back up hole 50' at.8 bpm at 1580 psi (soft cement). Clout Cement from 4,955' to 4,997 taking 5' to 10' bits and working back up hole 50' at 1.1 bpm, 2,830 psi (firm cement). Clout cement from 4,997' to 5,030' taking l' bits to 25' and working back up hole 50' at 1.3 bpm at 3,220 psi (hard cement). Clout cement from 5,030' to 5,310' at 1.0 - 1.5 fpm taking 25' bits and work pipe up hole 50' at 1.25 bpm at 3,200 psi (hard cement). Clout Cement from 5,310' to 5,450' taking 25' bites and working back up hole 50' at 1.25 bpm at 3,310 psi (soft cement). Circulate 5 bbl and POOH to 4,750' at 1.3 bpm at 3210 psi. Load and launch 7/16" ball. RIH to 5,450'. Shear circ sub. POOH. Remove injector head and lubricator. Check and LD BHA. 8/31/03 SRU 12-15, 161195 morning report summary, CONFIDENTIAL: last revised 3/2/2006, Page 2. · · Co;tinue LD and check BHA. pum!wn tubing 1.1 bbl and test PandA cementug of 56-0 sand to 2,065 psi to 1,992 psi in 30 min on chart (ok). SD ops. Attend SIMOPS with production. PJSM. Check well pressures 7" X tubing annulus = 150 psi, tubing pressure = 59 psi. RD Schlumberger coil tubing hard lines and BOPs. RU slickline with Schlumberger crane and test lubricator to 2,000 psi (ok). RIH #1 with 1.88" Gauge ring and SD at 4,812' WLM RKB and work GR to 4,829'. POOH. RIH #2 with 1.75" drive down bailer and SD at 5,062' WLM RKB and work bailer to 5,076'. POOH (1/2 bailer full of cement soup and 3/16" thick cement chunks). RIH #3 with 1.75" drive down bailer and set down at 5,076' WLM RKB and work bailer and fall thru to 5,084'. Work bailer and fall thru to 5,188'. POOH. RIH #4 with 1.75" drive down bailer and set down at 5,189' WLM RKB and work bailer and fall thru to 5,232' work bailer and fall thru to 5,245'. Work bailer and fall thru to 5,322'. Couldn't pass, pull up to 5,100' and RIH to 5,242' and hung same fire oil jars at 1600# for 15 min. Free tools, POOH. Cut 100' wire. Test same and re-head, check tool string. RIH #5 with 1.78" gauge ring and SD at 5,232' WLM RKB and work GR to 5,247'. POOH. RIH #6 with 1.75" drive down bailer and SD at 5,247' WLM RKB and work bailer to 5,284'. POOH. RIH #7 with 1.75" drive down bailer and SD at 5,284' WLM RKB and work bailer to 5,290' and fall thru to 5,318'. POOH. RIH #8 with 1.86" gauge ring and set down at 4,932' work GR and fall thru to 4,945'. Work GR and fall thru to 5,189' and work GR to 5,194' WLM RKB. POOH. Secure well and equipment. 9/1103 PJSM on RD of coil tubing BOPs and slickline and e-line work and cement job. Start and warm equipment check well pressures 7" X tubing annulus = 100 psi, tubing pressure = 35 psi. Break lubricator, check tools MU bailer. RIH #9 with 1.75" drive down bailer and set down at 5,334' WLM RKB and work bailer to 5,346'. POOH. RIH #10 with 1.75" drive down bailer and set down at 5,347' WLM RKB and work bailer to 5,363' and fall thru to 5,393' - work bailer to 5,403' and fall thru to 5,495'. POOH. RIH #11 with 1.84" gauge ring and set down at 5,212' WLM RKB and work GR to 5,390' and fall thru to 5,495'. POOH. RIH #12 with 1.866' gauge ring and set down at 5,495' WLM RKB. POOH. RD slickline and RU field pump truck and test lines to 3500 psi (ok). Pump down tubing (approx 1 bbl) and re-test PandA cement plug of 56-0 sand to 2,000 psi for 10 min (ok). RD pump truck and PJSM and perf check list. RU APRS e- line unit and arm tubing punch gun. Test lubricator to 2,000 psi (O-ring leaking at stuffing box). LD lubricator and change out O-ring and re-test (ok). RIH with 1-9/16" tubing punch 10' gun with 6' loaded (24 shots). Tag at 5,498' and tie in to tubing tail, pacler and GLM and place gun on depth. Pressure up tubing to 250 psi with Schlumberger cement unit and punch tubing from 5,418' to 5,423.5' (in middle of joint below GLM and lost pressure on tubing). POOH (all shots fired). RD. PJSM and test cement line to 4,000 psi (ok). Establish circulation (4 bbl tell returns) down tubing and up annulus and pump 30 bbls fresh water at 5 bpm at 1,550 psi. Blend hot mix water. Mix and pumped 120.9 bbl 575.6 sx of Class "G" Cement at 15.8 ppg with D047 at.02 galjsx + D065 at .3% bwoc + D167 at .35% bwoc + B155 at .04% bwoc and displaced with 23 bbl fresh water (2 bbl over displaced as planned). Extra cement slurry pump was do to Schlumberger #1 cement pump had troubles keeping prime and had two flat lines on pressure when rate was up switch to #2 pump and judged how much was not pumped and doubled it to error on high side. CIP at 2,105 hours and shut well in with 1,300 psi on tubing and left annulus open. Double block in tubing and monitor well and open annuals. RD and clean up cement equipment and Woc. 9/2/03 WOC and monitor open annulus. PJSM - cut 100' wire and test same (ok). RU slickline with encoder and test lubricator to 2,000 psi (ok) and equalized lubricator. RIH with 1.75" sedge to 5,100' (ok, did not tag WOC). POOH. Turn on gauges and RIH with tandem gauges to 2,747'. Guide wheel came loose and line jumped sheave at unit and kinked line. POOH. Pull off 2,900' of wire. Re-program gauges and turn on same. RIH with tandem gauges with base line at lubricator RIH at 60 fpm to 4,000' RKB and make 10 min stop and POOH at 60 fpm making 5 min stops every 1,000'. Turn off gauge. TOC at 2,042'. RD and clean up. Continued RD and clean up Schlumberger cement equipment and coil tubing unit. 9/3/03 Suspend operations and WOC. 9/15/03 SRU 12-15, 161195 morning report summary, CONFIDENTIAL: last revised 3/2/2006, Page 3. '" Tra:el to SRU, rig up SWS on 12-' e 9/16/03 Safety Meeting with Production. Bleed off well back to 250 psig, roustabouts rigging up choke manifold and tank. Pick up guns, BOP and lubricator PT to 500/2500. WH Pat 230 psig. RIH at 250 fpm. Start logging for tie-in log. Made 3 corrections totaling 7 foot to correlate log. Sent in tie-in log to office. Confirmed tie-in to position guns. 200psi WHP. Positioned guns at 5,016' top shot and fired guns. Pressure increase 100 psig. POOH, bleed down lubricator. Production unload well fluids to 500 bbl tank, 20.66 bbls returned to tank by tank strap. Finish RD SWS. SRU 12-15, 161195 morning report summary, CONFIDENTIAL: last revised 3/2/2006, Page 4. ~ RECEIVED APR 2 9 200S UNOCALe ,.,-Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com Alaska Oil & Gas Cons. COlTH11ission Anchorage April 29, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 Re: Request for Variance-Swanson River Mr. Aubert, We are requesting a variance of 20 MC 25.285 (c) (9) and (10). We are preparing to perform well intervention work with a "well servicing unit" provided by Nabors Alaska Drilling, currently stacked at Swanson River. We augmented the BOP equipment on the unit to satisfy our internal standards. Last year we worked with you to obtain a variance to work over several wells in the Swanson River field. We continue to believe the proposed system is superior in well control capabilities to BOPE configurations that are presently in use in the United States and Canada for wells with equivalent pressure and flow regimes. I bo - 0 a,'J-- We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the wells to be worked on; the highest maximum anticipated surface pressure (MASP) and the proposed BOP configuration. Additionally you will find a schematic of the proposed BOPE layout. ~7e'~ ~. c <h a Timothy 4ndenbUrg J Drilling Manager ..~~~,._- Attachments ~CANNED NO\¡ 1 "7 2005 Union Oil Company of California / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://www.unocal.com Well Descriptions Well Work Inventory SCU 32-08 SRU 23-15 SCU 22-04 SCU 314-04 SRU 14-15 SRU 12-15 \LDO- C ~;).. Reservoir The highest BHP of any well to be worked on at this time is 3000 psi @ 10,900' TVD (Hemlock) which is equivalent to a .275 psi/ft gradient or a 5.29 ppg EMW. Fully evacuated, the MASP would be as follows: 3000 psi BHP - (10,900' TVD x .1 psilft Gas Gradient) = 1,910psi MASP. Proposed Confiquration BOP's Annular, 5K 7-1/16" or 11" Double gate, 5K, 7-1/16" or 11" Mud Cross, 7-1/16" and 11" (optional based on BOP height) Accumulator 1 - 90 gallon Bounty Accumulator System 9-10 gallon Barksdale Control Valves Marsh Gauges 1 - Pump, Union Pump Comp., Model #BIT-532-55 1 - Newman Electric Motor 4 - 11 Gallon Nitrogen Bottles Pits The pit consists of a 150 bbl tank partitioned into 50 bbl compartments. Pump The pump is an Western Roughrider 1000 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 3000 psi Iron or 2", 5000 psi hoses with integral Fig 1502 hammer Unions. Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16",5K valves attached to either the mud cross or the tubing spool annulus valve. ,¡( , Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 2", 5,000 psi hoses with 2-1/16" 5m API Flange. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and four valves. Choke Return Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the three 50 bbl compartments of the pits. It is constructed with an open bottom that utilizes the hydrostatic level in the tank for the water leg. The gas buster vents vertically. Gas Detection We are proposing that a single gas LEL monitor be placed at the work platform. PVT We are proposing to work with out a PVT system as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. UNOCALSWANSON ~ ............... ---- I ~ ~ r--- I I I II Pipe Ram II I I II Blinds II I I I ~~SAI~ 2" 5M MGV 2" 5M MGV I [I] œ [JJ11" or 7-1/16" 5M Annular 5M Studded Top and Flanged Bottom ~11"or7-1/16"5M DBL ~ Optional 3111" or 7-1/16" 5M Drilling Spool w/2 ea 4" 5M OTL 12", 5m Hose wI flange connections. 1 11" or 7-1/16" 5M Hydril Annular BOP 2 11" or 7-1/16" 5M Shaffer LWS Double BOP 3 11" or 7-1/16" 5M Drilling Spool w/2 ea 4" 5M OTL (Optional) 4 2 1/16 5M Manual Gate Valve 521/16 5M Manual Gate Valve 6 2 1/16 5M Manual Gate Valve 7 2 1/16 5M Manual Gate Valve r--4"~... 2" 5m High Pressure hose. To Flow Back Tank ') STATE OF ALASKA .) ALASKA Oil AND GAS CONSERVATION COMMIS~rON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Performed: Alter Casing 0 Change Approved Program 0 2. Operator Unocal Alaska Name: Repair Well U Pull TubingO Operat. Shutdown 0 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 StratigraphicO StimulateU Other L:d Pool Correction WaiverO Time ExtensionO as of 5/18/2002 Re-enter Suspended WellO 5. Permit to Drill Number: ExploratoryO 160-022 ServiceD 6. API Number: 50-133-10138-00-00 9. Well Name and Number: SRU 12-15 10. Field/Pool(s): Swanson River, Beluga Undf Gas 3. Address: P.O. Box 19-0247 Anchorage, AK. 99519-0247 7. KB Elevation (ft): 334' 8. Property Designation: Swanson River Field/Swanson River Unit 11. Present Well Condition Summary: Total Depth measured 11383 feet true vertical 11383 feet Effective Depth measured 5650 feet true vertical 5650 feet Casing Length Size MD Structural Conducto r 30' 22" 30' Surface 3173' 13 3/8" 3173' Intermediate Production 11391' 7" 11391' Liner Perforation depth: Measured depth: 530' - 5538', 5561' - 557; True Vertical depth: 530' - 5538', 5561' - 557; Plugs (measured)¡650', 7578', 7615' 10581 Junk (measured) none TVD Bu rst Collapse 30' 3173' 853 psi 1130 psi 11391' 532 psi 3830 psi Tubing: (size, grade, and measured depth) 23/8" 4.6# L-80 surface to 5480' MD Packers and SSSV (type and measured depth) Baker FH Ret pkr @ 5447' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: SCi~NNED FEB (1 2; 2005 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 000 15. Well Class after proposed work: ExploratoryO Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 0 0 Tubing Pressure 0 0 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: Contact Larry Greenstein @ 263-7661 Printed Name Larry Greenstein Title Production Technician Signature ~ t ~ Phone 263-7661 , ",: Form 1 0-404 Revised 04/2004 0JÀ ¡:<jjj;yr¡s ~ ,/! /5 2/1/2005 Submit Original Only ') ) Greenstein, Larry P From: Sent: To: Subject: McMains, Stephen E -AOGCC Tuesday, January 18, 2005 10:27 AM Larry Greenstein Swanson River Wells Larry, The following wells require paper work to reflect the current pools the well is producing from at this time. The forms need to be back dated to when production started for each well in the current and correct pools. *The following wells have the pool number after the name that requires corrected paper work: * 160-018 50-133-1 0135-00-00 Swanson River 212-10 772550 162-006 50-133-10137 -00-00 Swanson River 211-15 772550 160-022 50-133-10138-00-00 Swanson River 12-15 772520 162-002 50-133-10162-00-00 Swanson River 21-33WD 772550 202-118 50-133-20515-00-00 Swanson River 213-10 772520 *The only paper work required is a Report of Sundry Well Operations (10-404) for each well with date started production. * Here are the current Field & Pool codes we have in RBDMS and currently use in Swanson River Field: 772036 SWANSON RIVER, UNDEFINED WDSP 772100 SW ANSON RIVER, HEMLOCK OIL 77211 0 SWANSON RIVER, UNDEFINED OIL 772500 SWANSON RIVER, TYONEK UNDF GAS 772520 SWANSON RIVER, BELUGA UNDF GAS 772550 SW ANSON RIVER, STERLING UNDF GAS 772555 SWANSON RIVER, GAS STORAGE If you have any question please call me, thanks Steve 1 Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCAL~ "",,""- Alaska Debra A Oudean G & G Technician February 26, 2004 DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7m Ave, Suite 100 909 W. 9th Avenue Anchorage, AK 99501-3539 Anchorage, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: ~~~ : COMPLETION RECORD SAFE 1.56 HSD PJ . .. . ',' ... .. . . . .' . PERF RECORD 111/16 POWER SPIRALS 7.5 SPF COMPLETION RECORD 1 11/16 POWER SPIRALS 7.5 SPF .. . .. . : COMPLETION RECORD 2 HSD 6 SPF POWERJET 60 5 INCH . DEGREE PHASED COMPLETION RECORD 2.5 HSD 6 SPF PJ . . . COMPLETION RECORD 1.56 HSD PJ 6SPF . . . . . . RESERVOIR SATURATION TOOL_SIGMA MODE " "" ,.,-,...., ..".. ,. "".. ""., ..."', ". ,,", ,.. ..." ... GAMMA RAY CCL 1.56 POWER JETS 1606 HMX 8/23/2003 3090-3614 6)c:ð ')" . 188- Jðr SRU 242.16 J 91"~ 0 ) ~ SRU 32A-33 I (R3-CO 'i- SR~..3.4~28... J 9 l/- 0515. SRU 41A-8 : 5 INCH 8/23/2003' 3590-4211 - - . . 5 INCH '11/12/2003:9360-10815 ... .. . .. .....' 5 INCH . ,,1.I.10/~004;4300~!300 5 INCH 2/12/200419740-10590 1 1, l 1 ,r ,1.1 Jd J...)L/1 0: _~Jó7 4 ~I I 1 J;;2J...JL)1 11-1 J[PILJ 1: 1 J~Jj4 1 ' 1 J ~ '-I L~ , r" . "1,) 8.l-J i..J 1 Jt).J.j~ RECEIVED S(CAfI~~~Eê) MAR 1 ~ 2004 FEB 2 7 2004 l-\laska Oil & Gas Cons.Comm- Anchorage of this transmittal or FAX to 907 263-7828. Date: ~~~ fy\ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROYAL 20 ACC 25.280 1. Type of request Abandon [] Suspend [] Operation Shutdown [] Perforate X z/ Variance [] Annular Disposal [] Alter Casing [] Repair Well [] Plug Perforations X Stimulate [] Time Extension [] Other [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-enter Suspended Well [3 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California/Unocal 60-022 3. Address: Development X Exploratory [] 6. APl Number: PO Box 19-0247, Anchorage, AK 99519 Statigraphic [] Service [] 50-133-10138-00 7. KB Elevation (ft): 334' RKB above MSL 9. Well Name/Number: SRU 12-15 / '8. Property Designation: Swanson River Field 10. Field/Pool(s): Swanson River Field/Tyonek ,, 11 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): TVD (ft): Elf Dep MD(ft): Eft Depth TVD (ft): Plugs (measured): 11,383 11,383 7,578 7,578 10581' cement, PosiSet bridge plug @7615' w/cmt @7578' Casing Length Size MD 'I'VD Burst Collapse Structural Conductor 30' 22" 30' 30' Surface 3173' 13-3/8" 3173' 3173' 853 psi 1130 psi Intermediate Production 11391' 7" 11391' 11391' 532 psi 3830 psi Liner Perf Depth MD (ft): Perf Depth 'I'VD (ft): Z/ Tubing Size:/ Tubing Grade: Tubing MD(ft): / 5530-5538', 5561-5578' 5530-5538', 5561-5578' 3-1/2" " 2-3/8", 4.6# L-80 5,480' Packers and SSSV Type: Packers and SSSV MD (ft): Baker FH Ret packer, 2-3/8" X 7" 26# 5447' 12. Attachments: Detailed Operations Summary 13. Well Class after proposed work: Description Summary of Proposal X BOP Sketch ID Exploratory [] Development X Service [] 14. Estimated date for commencing operations: 15. Well Status after proposed work: 8/1/2003 ,~ 16. Verbal Approval: Date: Oil [] Gas X Plugged [] Abandoned ID Comission Representative: WAG [] GINJ [] WINJ [] WDSLP [] 17. I hearby certify that the foregoing is true to the best of my knowledge. Contact: Printed Name: Steve Tyler Title: En.qineerin,q Technician Signature: J ~ ~ Phone: 907-263-7649 Date: 7/10/03 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Sundry Number: 3~llll~l~ l~l~f Plug integrity BOP Test Mechanical Integrity Test Location clearance Other: ~. iii,,,,=, !~,,~¢ ~:~. !:ii ~ ..... i ....... ,.,, ',' required 10 ~07 BY ORDER' '~*~OF ..... THE ,,~ . .. .., :.. /,'3 ~.. ~. ' Subsequent form ~ '/'! ~).~ Approved by: .~'"'"="'~;~t~Commissioner COMISSION Dat~'~t"":~~ ~. Submit in duplicate JUL 0 RIG IN l 04 Revised 2~2003 UNOCAL ) DV@ 1508' RKB to TBG Head = 21.20' Tree connection: TC-3 Uni-bolt 4/23/03 Tag at 1' with 1.75" bailer (sand) 800 SX pumped above DV ~ 8007' 2 ]6 ]7 8 11 12 13 14 15 16 PBTD = 11,182' TD = 11,383' Straight hole, Max angle = 1° Swanson River Field Well # SRU 12-15 Actual Completion 4/24/03 SIZE WT GRADE CONN TOP BTM LENGTH 22" Surf 30' 13-3/8" 54.5 J-55 8rd Surf 3167' 7" 29 N-80 Buttress Surf 3 03' 7" 26 N-80 Buttress 303' 1197' 7" 23 N-80 Buttress 1197' 4750' 7" 26 N-80 Buttress 4750' 6160' 7" 29 N-80 Buttress 6160' 7879' 7" 26 P-110 8rd LT&C 7879' 9627' 7" 29 P-110 8rd LT&C 9627' 11382' Tubing: 2-3/8" 4.6 L-80 SC BT&C Surf with 3/8" methanol inj line from surf to 2498' / JEWELRY DETAIL NO. Depth Item 21.20' 22' 2498' 2 5399' 3 5447' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO GLM w/l" dummy Baker FH Ret packer, 2-3/8" X 7" 26# 303' 894' 3553' 1410' 1719' 1748' 1755' 5,480' (cut) PERFORATION DATA. TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 ~" 4 5,530' 5,538' 8' Beluga(56-0) 5,561' 5,578 17' Beluga (56-0) ABANDONMENT DATA 1-11/16" Pivot, 4 spf, 0deg 1-_11/16" Pivot, 4 spf, 0deg 5 5,670' 8 7,084' 9 7,615' 11 10,581' 12 10,900' 13 10,967' 14 10,994' 15 11,155' "PosiSet" Plug w/10' Cement Top of cut tubing "PosiSet" Plug w/37' Cement (dump bailer lost in plug) Top of cement plug, WLM tag 11/21/96 Cement Retainer, could not inject thru on 11/17/96 2-7/8" tubing cut Production packer 2-7/8" tubing tail, venturi shoe ABANDONED PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6 7 10 16 6,172' 6,178' 58-1 6,488' 6,501' 61-3 8,433' 8,443' 80-2 11,043' 11,210' Hemlock 01/8/02 01/08/02 12/3/96 1960 Abandoned Abandoned Abandoned Abandoned REVISED: 06/09/03 DRAWN BY: JWS Dv @ 1508' 4/23/O3 Tag at 1' with 1.75" bailer (sand) UNOCAL ) 800 sx pumped above DV ~ 8007' Proposed Drawing RKB to TBG Head = 21.20' Tree connection: TC-3 Uni-bolt SIZE 22" 13-3/8" 7" 7" 7" 7" 7" 7" 7" ...... ~.~'~ 2-3/8" Swanson River Field Well # SRU 12-15 Actual Completion 4/24/03 GRADE CONN J-55 8rd N-80 Buttress N-80 Buttress N-80 Buttress 1197' BTM LENGTH 30' 3167' 303' 303' N-80 Buttress 4750' 6160' N-80 Buttress 6160' 7879' 1197' 894' 4750' 3553' 1410' 1719' P-110 8rd LT&C 7879' 9627' 1748' P-110 8rd LT&C 9627' 11382' 1755' L-80 I SC BT&C with 3/8" methanol inj line from surf to 2498' I Surf [ 5,480'(cut) [ JEWELRY DETAIL NO. Depth Item 21.20' 22' 1 2498' 2 5399' 3 5447' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO GLM w/l" dummy Baker FH Ret packer, 2-3/8" X 7" 26# 10 PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 4 5,530' 5,538' 8' Beluga(56-0) 5,561' 5,578 17' Beluga (56-0) 1-11/16" Pivot, 4 spf, 0deg 1-11/16" Pivot, 4 spf, 0deg 11 12 13 14 15 16 PBTD = 11,182' TD = 11,383' Straight hole, Max angle = 1° 5 5,670' 8 7,084' 9 7,615' 11 10,581' 12 10,900' 13 10,967' 14 10,994' 15 11,155' ABANDONMENT DATA "PosiSet" Plug w/10' Cement Top of cut tubing "PosiSet" Plug w/37' Cement (dump bailer lost in plug) Top of cement plug, WLM tag 11/21/96 Cement Retainer, could not inject thru on 11/17/96 2-7/8" tubing cut Production packer 2-7/8" tubing tail, venturi shoe ABANDONED PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6 6,172' 6,178' 58-1 01/8/02 Abandoned 7 6,488' 6,501' 61-3 01/08/02 Abandoned 10 8,433' 8,443' 80-2 12/3/96 Abandoned 16 11,043' 11,210' Hemlock 1960 Abandoned REVISED: 06/09/03 DRAWN BY: JWS SRU 12-15 P&A and Re-complete Summary 1. Mobe/Spot/RU CTU -/ 2. RIH w/Vortex Nozzle CO tbg t/PBTD w/produced water and/or N2. POOH. RD CT. 3. Mix/pump/squeeze/displace cement to P&A 56-0./~ 4. WOC 5. RU APRS. RIH w/tbg punch. Perf tbg ~ 5420'. POOH. 6. Mix/pump/circ/displace cement, down tbg and up 2-3/8" x 7" annuli to 2350' TOC. 7. Run Temp survey to confirm TOC. /' 8. WOC 9. Jug test Wellbore. 10. RU Eline. RIH p 50 ~and ~ 5007' to 5011'. POOH. RD. STATE OF ALASKA "-' ALASKA OIL GAS CONSERVATION CO v llSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: X Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 334' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Swanson River Unit 4. Location of well at surface 8. Well number 2,285' FNL, 1,054' FEL, Sec. 15, T8N, R9W, SM SRU 12-15 At top of productive interval 9. Permit number Same 60-022 At effective depth 10. APl number Same 50- 133-10138-00 At total depth 11. Field/Pool Same Swnason River Field / Tyonek 12. Present.well condition summary Total depth: ,..' measured 11,383' feet Plugs (measured) 10,581' Cement true vertical 11,383' feet PosiSet Bridge @ 7,615' / Cement @ 7,578' Effective depth: measured 7,578' feet Junk (measured) true vertical 7,578' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 30' 22" Yes 30' 30' Surface 3,173' 13-3/8" 1 stg 600 ax, 1,050 sx @ DV 3,173' 3,173' Intermediate Production 11,391' 7" 1 stg 700 ax, 800 sx @ DV 11,391' 11,391' Liner Scab Liner Perforation depth: measured Open: 6,427'-6,454' Abandoned: 8,433'- 8,443' ORIGINAL true vertical Open: 6,427'-6,454' Abandoned: 8,433' - 8,443' REC[~iV~D Tubing (size, grade, and measured depth) 2-3/8", 4.6#, L-80, Buttress SC @ 6,260' Packers and SSSV (type and measured depth) ~-~- r* ~--,. Baker Mod. "FH" Retrievable @ 5,447' 13. Stimulation or cement squeeze summary Alaska OiJ & Gas c-,-,-~,,.~. Co~lmis$iO[~ N/A Ancl~0rag~ Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/1/98 0 0 0 0 250 Subsequent to operation 2/3/99 0 1,182 0 600 1,025 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: ~( Oil: Gas: X Suspended: Service: ,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~~,( .1~~ Dan Williamson Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Work Summary Swanson River Unit, Well 12-15 11/23/98 - 1/5/99 DAY 1 (1219198) RU SCHLUMBERGER E-LINE UNIT. PRESSURE TEST LUBRICATOR. OK. RIH WITH POSISET PLUG. SET PLUG AT 7,615' WLM. POOH. RIH WITH 1-11/16" E-LINE BAILER AND TAG POSISET PLUG AT 7,615'. DUMP BAILER NO. 1 POOH. DAY 2 (12110/98) DUMP BAIL 3 ADDITIONAL RUNS. SHUT DOWN. RIG DOWN MOVE TO SCU 24A-5 TO PERFORATE. DAY 3 (12118/98) RESUME OPERATIONS. RU SCHLUIMBERGER E-LINE. PRESSURE TEST LUBRICATOR TO 1,500 PSI. OK. RIH WITH GAMA RAY, CCL AND GRADIOMANOMETER. TAG CEMENT PLUG AT 7,603'. POOH. SHUT DOWN FOR NIGHT. DAY 4 (12119198) RESUME OPERATIONS. PERFORM BAILER RUNS 5 AND 6. FILL BAILER NO. 7. RIH TO TAG CEMENT. ON BOTTOM NOTED CCL PASSING BAILER INDICATING THAT BAILER AND PARTED. POOH. FOUND BAILER HAD UNSCREWED IMMEDIATELY BELOW ACTUATOR. ALL 52' OF BAILER LEFT ON TOP OF PLUG. CONTACTED BLAIR WONDZELL AND INFORMED HIM THAT BAILER WAS IN CEMENT PLUG. SHUT DOWN. SCHLUMBERGER FLYING UP NEW BAILER BARREL FROM LOWER 48. NEW CEMENT TOP ESTIMATED AT 7,593'. DAY 5 (12/27/98) RESUME OPERATIONS. RU E-LINE UNIT. PRESSURE TEST LUBRICATOR TO 2,500 PSI. OK. RUN DUMP BAILER 8,9,10 AND 11 WITHOUT INCIDENT. SHUT DOWN FOR NIGHT. DAY 6 (12128198) RESUME OPERATIONS. PERFORM DUMP BAILER RUNS 12,13 AND 14 WITHOUT INCIDENT. ESTIMATED TOP OF CEMENT AT 7,570'. SHUT DOWN. DAY 7 (114199) PRESSURE TEST PLUG TO 1,500 PSI FOR 30 MIN. NO BLEED OFF (HAD CONTACTED BLAIR WONDZELL ABOUT TESTING TO 1,500 PSI DUE TO CONCERNS OF CASING AGE) TEST O.K. BLEED TUBING TO ZERO. DAY 8 (1/5/99) RU SCHLUMBERGER E-LINE UNIT. ARM GUNS. PRESSURE TEST LUBRICATOR. OK. RIH. CCL FAILED. POOH. CHANGE OUT CCL. RIH AND PERFORATE 6,427' TO 6,454' WITH 1-11/16" ENER JET GUNS, 6SPF, 0 DEG PHASING. POOH. RIG DOWN. TURN WELL OVER TO PRODUCTION. UNOCAL ) RKB to TBG Head = 21.20' Tree connection: TC-3 Uni-bolt DV~ 1508' TOC ~ 7,578'. 52', 1-11/16" Dump Bailer lost in plug! 800 sx pumped above DV ~ 8007' Tag fill/mud ~ 7,815' on 11/22/98 5 17 18 11 12 13 13a 14 15 16 PBTD = 11,182' TD = 11383' Straight hole, Max angle = 1 o SIZE WT Swanson -.ver Field Well # SRU 12-15 Actual Completion 1/5/99 GRADE CONN TOP BTM LENGTH 22" 13-3/8" 54.5 7" 29 7" 26 7" 23 7" 26 7" 29 7" 26 7" 29 Tubing: 2-3/8" 4.6 Surf 30' J-55 8rd Surf 3167' N-80 Buttress Surf 303' N-80 Buttress 303' 1197' N-80 Buttress 1197' 4750' N-80 Buttress 4750' 6160' N-80 Buttress 6160' 7879' P-110 8rd LT&C 7879' 9627' P-110 8rd LT&C 9627' 11382' L-80 SC BT&C Surf with 3/8" methanol inj line from surf to 2498' NO. Depth JEWELRY DETAIL Item 21.20' 22' 2498' 2 5399' 3 5447' 4 5492' 5 6262' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Macco 2-3/8" SMO- 1C 1 Chem Inj Mdrl w/1000 psi them inj valve Macco 2-3/8" D-SO GLM w/l" dummy Baker FH Ret packer, 2-3/8" X 7" 26# X nipple, min. ID = 1.875" Tubing tail (shear out sub) PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 17 6,427' 6,454' 27' Tyonek (61-3) 303' 894' 3553' 1410' 1719' 1748' 1755' 6,262' 1-11/16 EJ, 6 spf, 0deg ABANDONMENT DATA 18 7,615' 12 10,581' 13 10,900' 13a 10,967' 14 10,994' 15 11,155' ABANDONED PERFORATION DATA TOP BTM ZONE SPF DATE "PosiSet" Plug w/37' Cement Top of cement plug, WLM tag 11/21/96 Cement Retainer, could not inject thru on 11/17/96 2-7/8" tubing cut Production packer 2-7/8" tubing tail, venturi shoe COMMENTS 11 8,433' 8443' 16 11043 11043 11070 11132 11136 11141 11145 11162 12/3/96 Abandoned Hemlock 4 1960 Hemlock 4 1960 12-15 1-5-99 ~aw Rev ~VISED: 1/5/99 D~~ BY: TCB Unocal Corporation P,O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL ) December 31, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Blair Wondzell Subject: Swanson River Unit Well No. 12-15 APl No. 50-133-10138-00 Dear Mr. Wondzeli: As per our conversation this afternoon, Unocal will pressure test the abandonment plug (isolating the Tyonek 68-0 perforations) in SRU Well No, 12.-15 to 1,500 psi. The estimated top of cement is 7,570'. Using the .25 psi/ff standard would yield a pressure of 1,892 psi. Given the age of the 7" casing string (mn in October, 1960) the plug will be tested for 30 min, to 1,500 psi, equivalent to a. 198 psi/fi, gradient. Sincerely, Tim Brandenburg [/[ 'd [Lg$'ON 'd~OO 'lVOONIq IAId[l~:l~ 866[ '[8'oeG Unocal Corporation '"-" P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL ) November 23, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Blair Wondzell Subject: Swanson River Unit Well No. 12-15 APl No. 50-133-10138-00 Dear Mr. Wondzell: On Sunday, November 22, 1998, a gage ring was ran in SRU 12-15 to verify that the tubing was unobstructed and to verify fill depth in preparation for the proposed plug back. The gage ring sat down at 7815' sim, 618' above the perforations. A subsequent bailer run sat down at 7,818' SLM and recovered mud. In order to insure that the plug is being placed in clean fluid, it is proposed that the PosiSet plug be set at a minimum of 200' (7,615' MD) above the mud water interface. Please call Tim Brandenburg at 263-7657 if you have any questions. Sincerely, Dan Williamson Drilling Manager tl0V 2 t998 Cons. Anchor;~ IUNOCAL )] UNOCAL Alaska Drilling Department To: Mr. Blair Wonclz~ll AOGCC From: Tim Brandenburg Ph. (907) 263-7657 Re: SRU 12-15 Sundry Pages including cover sheet: 3 NOV 1 ¢ 1998 Alaska Oil & Cas t;o~. AnchoraDe 8/t 'd 8G6~'ON 'd~O3 -IVOONfl INd6L'~ 866L '6L'AON Unocal Corporation P,O, Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL November 19, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Blair Wondzell Subject: Swanson River Unit Well No. 12-i5 APl No. 50-133-10138-00 Dear Mr. Wondzell: Unocal request a variance from 20 AAC 25.105.h.c requiring that when abandoning a perforated interval via a bridge plug, that the plug be placed no more than 50 feet above the top perforations. When re-completed and perforated at 8,433'-8,443', the well SI~U 12-15 produced mud from the casing annulus. Subsequent attempts to unload the fluid from the well failed indicating that the cement behind pipe is providing little isolation from the perf depth at 8,433' to the stage tool at 8,007'. Unocal proposes to place the bridge plug at 7,50~ to protect the well from potential leaks in the casing below the stage tool or t--~ tool itself, ~ Additionally, the Sundry indicates tha~tthe Tyone~ 68-0 and 6i-3A __sands are to be perforated. These intervals Will not be perforated at-t-hiS-time, instead the 59-2 Sand will be perforated frown 6,302'-6310', 6,313'-6,345', 6,356'-6,376', Please call me at 263-7657 if you have any questions.~%,~.,;%~'"==.t V ~-~ Sincerely, Tim Brandenburg Ale.Aa 0 11 C. sC0ns. C0nmhSion £/Z 'ct ~q~Z'ON 'dH03 qVOONn 866[ '6L'AON DV @ 1508' UNOCAL ) RI~ to TBG Head = 21,20' Tree connection: TC-3 Uni-bolt 800 sx pumped above DV ~ 8007' Tag fill/mud ~ 8426' on 10/27/98 18 goo-/ ]I oq,~3 12 13 13a 14 15 I6 PBTD --' 11,182' TD = 11383' Straight hole, Max angle = 1° SIZE WT Swanson River Field Well # SRU 12-15 Proposed Completion Rev. III GRADE CONN TOP BTM b m_l LENGTH 22" 13-3/8" 54.5 7" 29 7" 26 7" 23 7" 26 7" 29 7" 26 7" 29 Tubing: 2-3/8" 4.6 Surf 30' J-55 8rd Surf 3167' N-80 Buttress Surf 303' N-80 Buttress 303' I 197' N-80 Buttress 1197' 4750' N-80 Buttress 4750' 6160' N-80 Buttress 6160' 7879' P-110 8rd LT&C 7879' 9627' P-110 8rd LT&C 9627' 11382' L-80 SC BT&C Surf with 3/8" methanol inj line from surf to 249 8' NO, Depth JEWELRY DETAIL Item 21.20' 22' 2498' 2 5399' 3 5447' 4 5492' 5 6262' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Maooo 2-3/8" SMO-1C1 Chem Inj M&I w/1000 psi chem inj valve Macco 2-3/8" D-SO GLM w/l" dummy Balc~ FI-I Ret packer, 2-3/8" X 7" 26g X nipple, min. ID = 1.875" Tubing tail (shear out sub) PERFORATION DATA TOP BTM ZONE T/e-in log = Schlumberger TDT 11/16/96 17 6,302' 6,310' Proposed Tyonek (59-2) 6,313' 6,345' Proposed Tyonek (59-2) 6,356' 6,376' Proposed Tyonek (59-2) 303' 894' 3553' 1410' 1719' 1748' 1755' 6,262' ABANDONMENT DATA 18 7,500' 12 10,581' 13 10,900' 13a I0,967' 14 10,994' 15 11,155' ABANDONED PERFORATION DATA TOP BTM ZONE SPF DATE "PosiSet" Plug w/20' Cement Top of cement plug, WLM tag [ 1/21/96 Cement Retainer, could not inject thru on 11/17/96 2-7/8" tubing cut Production packer 2-7/8" tubing tail, venttm shoe COMIV~NTS 11 16 8,433' 8443' 12/3/96 Proposed Abandon 11043 1 I043 Sqzd 11070 11132 Hemlock 4 1960 I 1136 1114I ' Hemlock 4 1960 11 I45 11 I62 Hemlock 4 1960 12-15ABdraw Rev II.doc REVISED: 11/19/98 DRAWN BY: TAB $/$ 'd 8cj6;~'ON 'd~OO "IV30NI3 I/qd6t'g 866[ '6['AON ?-" STATE OF ALASKA '~" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: X Other: 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface 2,285' FNL, 1,054' FEL, Sec. 15, T8N, R9W, SM At top of productive interval Same At effective depth Same At total depth Same 5. Type of well: Development: Exploratory: Stratigraphic: Service: 6. Datum elevation (DF or KB) 334' RKB above MSL 7. Unit or Property name Swanson River Unit 8. Well number SRU 12-15 9. Permit number 6O-O22 10. APl number 50- 133-10138-00 11. Field/Pool Swnason River Field / Tyonek feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 30' Surface 3,173' Intermediate Production 11,391' Liner 11,383' 11,383' 8,426' 8,426' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 22" Yes 13-3/8" 1 stg 600 sx, 1,050 sx @ DV 7" 1 stg 700 sx, 800 sx @ DV 10,581' Cement Measured depth 30' 3,173' 11,391' True vertical depth 30' 3,173' 11,391' Perforation depth: measured 8,433' - 8,443' true vertical 8,433' - 8,443' Tubing (size, grade, and measured depth) 2-3/8", 4.6#, L-80, Buttress SC @ 6,260' Packers and SSSV (type and measured depth) Baker Mod. "FH" Retrievable @ 5,447' OR/Gl RECEIVED L Alaska 0il & Gas Cons. Commission Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: 14. 15. Status of well classification as: Estimated date for commencing operation 11/9/98 16. If proposal well verbally approved: Name of approver Date approved Oil: Gas: X Suspended: Service: 17. , here~e,~ify t~at tl'~f~g~oing is true and correct to the best of my knowledge. Signe~)~d~[~[_ _ _ n Williamson Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /-(~- Approved by order of the Commissioner 0avid W, Johnston Form 10-403 Rev 06/15/88 Commissioner Date //--(~ ~"'~ SUBMIT IN TRIPLICATE UnocalCorporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL ) October 30, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David 'Johnston Subject: Swanson River Unit Well No. 12-15 APl No. 50-133-10138-00 Form 10-403, Proposal to Plug back and Perforate Dear Commissioner Johnston: Unocal proposes to abandon Tyonek 80-2 sands and perforate the Tyonek 68-0, 61-3A sands in Swanson River .Unit Well No. 12-15. Unocal proposes to isolate the lower Tyonek sands via the setting of an E-Line conveyed, through tubing "PosiSet" Plug and dump bailing cement on top of the plug as proposed for SRU 43-28. The new Tyonek gas zones will then be perforated with through-tubing guns. Attached in triplicate are the 10-403 form with a procedure and schematics. Estimated start date is November 12,1998. Please direct any questions to Tim Brandenburg at 263-7657. Sincerely, Dan Williamson Drilling Manager RECEIVED 1998 Alaska 011 & ~Im~ Cons. Commission Aneh0rage · Unocal Alaska Business Unit Swanson River Well No. SRU 12-15 Prepared by: Tim Brandenburg OCAL0 Plug Back and geperforate U N No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Plug Back 1 MIRU Schlumberger E-Linc. 4.0 4 0.2 2 Pressure test Lubricator to 4,000psi. 1.0 5 0.2 3 Pick up PosiSet Plug for 7", 29# Casing. 1.0 6 0.3 4 RIH with CCL/PosiSet Plug. 2.0 8 0.3 5 Set Plug at 8,390' MD. 3.0 11 0.5 6 POOH. 0.5 12 0.5 7 MU 1-11/16" Bailer/Mix Cement. 2.0 14 0.6 8 RIH making runs as requires to dump bail 20' of cement. 16.0 30 1.2 9 Allow cement to Cure for 24 hours. 24.0 54 2.2 10 Pressure test plug to 2,500 psi. 1.0 55 2.3 11 Perform E-Line Tag prior to perforating. 1.0 56 2.3 Perforate 12 Swab well to achive 300# underbalance. 3.0 59 2.4 13 MU 1-11/16" guns, RIH and Perforate Tyonek (68-0) 7,344'-7,366' 1.0 60 2.5 14 POOH. 1.0 61 2.5 15 MU 1-11/16" guns, RIH and Perforate Tyonek (68-0) 7,224'-7,242' 1.0 62 2.6 16 POOH. 1.0 63 2.6 17 MU 1-11/16" guns, RIH and Perforate Tyonek (61-3A) 6,434'-6,454' 1.0 64 2.6 18 POOH. 1.0 65 2.7 19 Rig Down. 3.0 68 2.8 12-15 Reperf Attach.xls Page 1 of 1 10/30/98 UNOCAL RKB to TBG Head = 21.20' Tree connection: TC-3 Uni-bolt 1508' 800 sx pumped above DV ~ 8007~ Tag fill/mud ~ 8426' on 10/27/98 12 13 13a 14 15 16 PBTD = 11,182' TD = 11383' Straight hole, Max angle = 1 o SIZE WT Swanson River Field Well # SRU 12-15 Actual Completion, 11/20/96 GRADE CONN TOP BTM LENGTH 22" 13-3/8" 54.5 7" 29 7" 26 7" 23 7" 26 7" 29 7" 26 7" 29 Tubing: 2-3/8" 4.6 Surf 30' J-55 8rd Surf 3167' N-80 Buttress Surf 303' N-80 Buttress 303' 1197' N-80 Buttress 1197' 4750' N-80 Buttress 4750' 6160' N-80 Buttress 6160' 7879' P-110 8rd LT&C 7879' 9627' P- 110 8rd LT&C 9627' 11382' L-80 SC BT&C Surf with 3/8" methanol inj line from surf to 2498' NO. Depth JEWELRY DETAIL Item 21.20' 22' 2498' 2 5399' 3 5447' 4 5492' 5 6262' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Macco 2-3/8" SMO- 1C 1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO GLM w/l" dummy Baker FH Ret packer, 2-3/8" X 7" 26# X nipple, min. ID = 1.875" Tubing tail (shear out sub) 303' 894' 3553' 1410' 1719' 1748' 1755' 6,262' ACTUAL PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 11 8433' 8443' Tyonek 80-2 12/3/96 ItEMLOCK ABANDONMENT DATA 12 10,581' 13 10,900' 13a 10,967' 14 10,994' 15 11,155' ABANDONED TOP BTM Top of cement plug, WLM tag 11/21/96 Cement Retainer, could not inject thru on 11/17/96 2-7/8" robing cut Production packer 2-7/8" robing tail, venturi shoe HEMLOCK PERFORATION DATA ZONE SPF DATE COMMENTS 16 11043 11043 Sqzd 11070 11136 11145 11200 11132 Hemlock 4 1960 11141 Hemlock 4 1960 11162 Hemlock 4 1960 11210 Sqzd 12-15 draw. doc REVISED: 10/30/98 DRAWN BY: TAB UNOCAL RKB to TBG Head = 21.20' Tree connection: TC-3 Uni-bolt DY @ 1508' 800 sx pumped above DV ~ 8007' 17 Tag fill/mud ~ 8426' on 10/27/98 18 12 13 13a 14 15 16 PBTD = 11,182' TD = 11383' Straight hole, Max angle = 1 o SIZE WT Swanson River Field Well # SRU 12-15 Proposed Completion GRADE CONN TOP BTM LENGTH 22" 13-3/8" 54.5 7" 29 7" 26 7" 23 7" 26 7" 29 7" 26 7" 29 Tubing: 2-3/8" 4.6 Surf J-55 8rd Surf N-80 Buttress Surf N-80 Buttress 303' N-80 Buttress 1197' N-80 Buttress 4750' N- 80 Buttress 6160' P-110 8rd LT&C 7879' P- 110 8rd LT&C 9627' 30' 3167' 303' 1197' 4750' 6160' 7879' 9627' 11382' L-80 SC BT&C Surf with 3/8" methanol inj line from surf to 2498' NO. Depth JEWELRY DETAIL Item 21.20' 22' 2498' 2 5399' 3 5447' 4 5492' 5 6262' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO GLM w/l" dummy Baker FH Ret packer, 2-3/8" X 7" 26# X nipple, min. ID = 1.875" Tubing tail (shear out sub) PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 17 6,434' 6,454' Proposed Tyonek (31-3A) 7,224' 7,242' Proposed Tyonek (68-0) 7,344' 7,366' Proposed Tyonek (68-0) ABANDONMENT DATA 303' 894' 3553' 1410' 1719' 1748' 1755' 6,262' 18 8,390' 12 10,581' 13 10,900' 13a 10,967' 14 10,994' 15 11,155' TOP "PosiSet" Plug w/20' Cement Top of cement plug, WLM tag 11/21/96 Cement Retainer, could not inject thru on 11/17/96 2-7/8" robing cut Production packer 2-7/8" tubing tail, venturi shoe ABANDONED PERFORATION DATA BTM ZONE SPF DATE COMMENTS 11 8433' 8443' 12/3/96 16 11043 11043 11070 11136 11145 11132 11141 11162 Hemlock 4 1960 Hemlock 4 1960 Hemlock 4 1960 Proposed Abandon Tyonek Sqzd 12-15ABdraw.doc REVISED: 10/30/98 DRAWN BY: TAB UNOCALe P. O. Box 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax February 3, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commisioner David Johnston ORIGINAL Subject: Swanson River Unit Well #12-15, Approval # 396-207 Recompletion Report Form 10-407 Commissioner Johnston: Attached is the Form 10-407 for the recompletion of Swanson River Unit Well #12-15. The Hemlock oil zone was abandoned during this rig workover and the well was recompleted as a Tyonek gas producer. A cement bond log was run during the workover which indicated the cement quality below a DV tool at 8007' was suspect. However, there were indications that adequate bond was present so it was decided that a remedial squeeze during the workover would have a Iow chance of success and that the lowest potential gas zone would be perforated. Unfortunately, the first set of perforations at 8433'-8443' produced only a thick substance which was probably old drilling mud from behind the casing. At present, the well is shut-in. Unocal's plan is to wait for warmer weather to mobilize a coiled tubing unit to clean out the well and abandon the perforations at 8433'-8443'. After the abandonment of the lower zone, a gas zone above the DV tool at 8007' will be perforated. A sundry application form 10-403 will be submitted to you for your approval prior to commencing this proposed work. If there are any questions about this report or the situation at Swanson River, please call me at 263-7659. Sincerely, Tim Billingsley~' Drilling Engineer RECEIVED FEB 5 1997 Alaska 011 & Gaa Cons. commissior~ Anchoraoe U AOC-CCOV. DOC 1 2/3/97 · STATE OF ALASKA ALASKA AND GAS CONSERVATION 'OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Statue of Well Classification of Service Well OIL: GAS: SUSPENDED X ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 60-022/396-207 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10138-00 4. Location of well at s~l~ace i ~"~~ 9. Unit or Lease Name 2285' FNL, 1054' F, EL, Sec. 15, T8N, R9W, SBM I '-~~ Swanson River Unit At Top Producing Interval;!~;;~,~~~--"~f"~ i 10. Well Number Same ! ~'~ ~'~ *~i SRU #12-15 At Total Depth ~- ~' '~'.~-? 11. Field and Pool Same 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Swanson River Field/'l'yonek 334' KBI A-028406 22. Typa El~tri¢ or Other Logs Run IDI, USIT ~orro~ion, USIT cament, CBL, GRICCL, Pivot Gun Perf 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22.' 0 30' To surf 0 13-3/8" 54.5 J-55 0 3167' 17-1/2" 600 ex, 1050 ex ~ DV 0 7" 29~, 26~, 23~ N-80 & P-110 0 11382' 9-5/8" 700 ex, 800 sx Q DV 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" 6262' 5447' 8433'-8443' TVD and MD 4 spf, 0.34" dia hole 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ORIGINAL 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12/3/96 lGas Zone would not flow due to poor cement quality behind casing causing mud to flow into wellbore. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 12/5/96 NA TEST PERIOD --> 0 0 0 NAI NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 0 0 24-HOUR RATE => 0 0 0 NA 28. CORE DATA Bdef description of lithology, porosity, fractures, apparent diPs and presence of oil, gas or water. Submit core chips. None RECEIVED FEB 5 1997 Alaska 011 & Ga~ Cena. Commission Aneherage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. 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. Tyonek 80-2 Bench 8433'-8443' 8433'-8443' Recovered only drilling mud due to poor quality cement behind casing. RECEIVED FEB 5 Alaska 011 & Gas CoM. ~)mm~s~ Anchorage , 31. LIST OF A'I-rACHMENTS Wellbore schematic, Summary of Rig Workover Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /2~- ~~ Title Drilling Mana.qer Date Form 10-407 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 space 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 productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Summary of Rig Workover Operations Swanson River Unit Well No. 12-15 11112/96- ACCEPT RIG ~ 04:00 1115196. ND TREE, NU BOPE. TEST BOPE (WITNESS BY JOE RUSSELL-BLM) 11113196- WELL TAKING FLUID, PUMP SIZED SALT PILL TO STOP LOST RETURNS. PULL 4044' OF TUBING. STRING WAS PARTED AT TOP OF GLM #5. RIH WITH OVERSHOT AND ENGAGE OD OF GLM. CIRC AND POOH WITH FISH. 11114196- FINISHED POOH WITH 1847' OF TUBING FISH. CORROSION ON COUPLINGS. TOP OF FISH LEFT IN HOLE ~ 5899', MIDDLE OF JOINT. RIH WITH 5-314" OVERSHOT WITH 2-7~8" GRAPPLE AND MILL. PU KELLY AND MILL OVER FISH, ENGAGE FISH. PULL 100K (15K OVER STRING WEIGHT TO PACKER), NO RELEASE. RU APRS E-LINE UNIT. RIH WITH 2-118" JET CUTTER. 11/15196- RIH WITH 2-118" JET CUTTER. CUT TUBING (~ 10,967', MIDDLE OF JOINT BETWEEN LOWEST GLM AND CC SAFETY JOINT. POOH WITH WIRELINE. CIRC TWO BOTTOMS UP TO REMOVE GAS. EST 30 CUFT ASPHALTENES RETURNS. POOH WITH FISH. RIH WITH 6" BIT AND 7" CASING SCRAPER ON 2-718" TUBING. 11116196- WASH FROM 10,958' TO TOP OF STUB AT 10,964'. CIRC HOLE CLEAN, ESTIMATE 20 CUFT ASPHALTENE RETURNS. POOH WITH SCRAPER. RUN SCHLUMBERGER. RIH AND SET RETAINER (~ 10,900'. PRESSURE TEST CASING TO 1500 PSI, GOOD. RIH WITH TDT LOGGING TOOLS. LOG FROM 8500' TO 3650'. 11117196- RIH & LOG WITH USITICBT FROM 8500' TO 3650'. RD SCHLUMBERGER. RIH WITH RETAINER STAB-IN TOOL ON 2-7~8" TUBING. STAB IN TO RETAINER AT 10,900' AND ATTEMPT INJECTIVITY TEST. NO INJECTION INTO FORMATION AT 3000 PSI, PRESSURE COMMUNICATION BEGAN TO ANNULUS. PU OUT OF RETAINER. TEST CASING TO 1500 PSI, OK. POOH LOOKING FOR TUBING LEAK, NO LEAK FOUND. LD STINGER, RIH WITH OPEN ENDED TUBING TO LAY CEMENT ON TOP OF RETAINER. os~'^~.~ w.~^, ^r.r..ov^, ~.OM ^o~cc-s,^~. wo.~z~,,~o ^~^.~o..~M,OCr~ ~¥ ,^'.'~.~ C~M~.~' r',U~ O. 'ro, o~ RETAINER. R E C E IV E D 1997 Al~k~ Oil & G~s Cans. Commission An0h0rage 11118/96- RU CEMENT UNIT & PTEST TO 2500 PSI WI TBG ~l~ 10,905. MIX AND PUMP 12 BBLS 15.6 PPG CMT WI ADDITIVES DISPLACING W/59 BBLS LEASE WATER. PU TO 10,352 & CBU. MIX AND CIRCULATE 6% KCI LEASE WTR WI 1% CORROSION INHIB. POOH LD TBG. ND BOP TO CIO SPOOL. 11119196-CHANGE OUT WELLHEAD PACKOFF. NU TUBING HEAD AND BOP STACK. TEST WELLHEAD PACKOFFS TO 3000 PSI. CHANGE RAMS TO 2-3~8", TEST TO 5000 PSI. RUN 2-3~8" COMPLETION, METHANOL INJECTION VALVE IN MANDREL WOULD NOT HOLD BACK PRESSURE. CHANGE OUT MANDREL WITH NEW VALVE, HELD 700 PSI BACK PRESSURE ON PUMP THROUGH TEST AT SURFACE. CONTINUE RUNNING COMPLETION WITH METHANOL INJECTION MANDREL TO 2500'. 11120196- LAND HANGER, TEST METHANOL INJECTION LINE, TEST HANGER SEALS. OVERDISPLACE TUBING WITH DIESEL. DROP BALL AND SET PACKER WITH 3000 PSI. SHEAR OUT BALL AT 3500 PSI. PRESSURE TEST ANNULUS TO 1500 PSI. ND BOPE, NU TREE AND TEST TO 5000 PSI. RELEASED RIG AT 18:00 HRS 11120196. MOVE RIG TO SRU 212-27. 11121/96- RU SLICKLINE UNIT. RIH WITH 1.75" BLIND BOX. NO INDICATION OF SHEAR OUT SUB AT 6260'. TAG TOP OF CEMENT AT 10,581'. 12/03196- RU SCHLUMBERGER E-LINE UNIT. RIH WITH PIVOT GUNS. PERFORATE 8433'-8443'. GOOD INDICATION OF GUNS FIRING, TUBING PRESSURE INCREASED TO 1200 PSI. POOH AND RD SCHLUMBERGER. OPEN WELL TO FLOW, PRESSURE BLED IMMEDIATELY FROM 1200 PSI TO 0 PSI. NO FLOW. 12/04196- RU SLICKLINE UNIT. SWABBED WELL. DROPPED FLUID LEVEL AS LOW AS 3800' WITH NO SIGNIFICANT GAS PRODUCTION. 12/05196- CONT SWABBING WITH FLUID LEVEL REMAINING AT 3600'. RIH WITH BAILER AND TAG MUD AT 7022', POOH WITH SAMPLE OF CEMENT/MUD/WATER. RIH WITH SWAB AND TAG FLUID AT 3592'. SHUT-IN WELL, EVALUATING ALTERNATIVES. UNOCALe DV@ 1508' RKB to TBG Head -- 21.20' Tree connection: TC-3 Uni-bolt 800 sx pumped above DV ~ 8007' ]11 12 13 13a 14 15 16 PBTD = 11,182' TD = 11383' Straight hole, Max angle = 1° SIZE WT Swanson River Field Well # SRU 12-15 Actual Completion, 11/20/96 GRADE CONN TOP BTM LENGTH 22" 13-3/8" 54.5 7" 29 7" 26 7" 23 7" 26 7" 29 7" 26 7" 29 Tubing: 2-3/8" 4.6 Surf 30' J-55 8rd Surf 3167' N-80 Buttress Surf 303' N-80 Buttress 303' 1197' N-80 Buttress 1197' 4750' N-80 Buttress 4750' 6160' N-80 Buttress 6160' 7879' P-110 8rd LT&C 7879' 9627' P-110 8rd LT&C 9627' 11382' L-80 SC BT&C Surf with 3/8" methanol inj line from surf to 2498' NO. Depth JEWELRY DETAIL Item 21.20' 22' 2498' 2 5399' 3 5447' 4 5492' 5 6262' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi them inj valve Macco 2-3/8" D-SO GLM w/l" dummy Baker FH Ret packer, 2-3/8" X 7" 26# X nipple, min. ID = 1.875" Tubing tail (shear out sub) 303' 894' 3553' 1410' 1719' 1748' 1755' 6,262' PROPOSED PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 11 8433' 8443' Tyonek 80-2 12/3/96 HEMLOCK ABANDONMENT DATA 12 10,581' Top of cement plug, WLM tag 11/21/96 13 10,900' Cement Retainer, could not inject thru on 11/17/96 13a 10,967' 2-7/8" tubing cut 14 10,994' Production packer 15 11,155' 2-7/8" tubing tail, venturi shoe ABANDONED HEMLOCK PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 16 11043 11043 Sqzd 11070 11132 Hemlock 4 1960 11136 11141 Hemlock 4 1960 11145 11162 Hemlock 4 1960 11200 1~210 SC1215D.DOC REVISED: 2/3/97 DRAWN BY: TAB Sqzd UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519-6247 90%276-7600 90%263-7884 fax January 2, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ORIGINAL Attn: Commisioner David Johnston Subject: Swanson River Unit Well #12-15, Approval # 396-:~7~ 0 Recompletion Report Form 10-407 Naka 0il & Commissioner Johnston: Attached is the Form 10-407 for the recompletion of Swanson River Unit Well #12-15. The Hemlock oil zone was abandoned during this rig workover and the well was recompleted as a Tyonek gas producer. A cement bond log was run during the workover which indicated the cement quality below a DV tool at 8007' was suspect. However, there were indications that adequate bond was present so it was decided that a remedial squeeze during the workover would have a Iow chance of success and that the lowest potential gas zone would be perforated. Unfortunately, the first set of perforations at 8433'-8443' produced only a thick substance which was probably old drilling mud from behind the casing. At present, the well is shut-in. Unocal's plan is to wait for warmer weather to mobilize a coiled tubing unit to clean out the well and abandon the perforations at 8433'-8443'. After the abandonment of the lower zone, a gas zone above the DV tool at 8007' will be perforated. A sundry application form 10-403 will be submitted to you for your approval prior to commencing this proposed work. In the mean time, perforating work in Tyonek gas intervals will commence on the other three recompleted wells at Swanson River; SRU 23-22, 212-27 and 14-15. If there are any questions about this report or the situation at Swanson River, please call me at 263-7659. Sincerely, Tim Billingsley''J Drilling Engineer u AOGCCOV. DOC I 12/31/96 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED X ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 60-022J396-207 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10138-00 4. Location of well at surface 9. Unit or Lease Name 2285' FNL, 1054' FEL, Sec. 15, T8N, Rgw, SBM ~ ,.i~'~-~1'~'i~ Swanson River Unit At Top Producing Interval 10. Well Number Same..~,~~rf''--~ / /'" ~ SRU #12-15 At Total Depth ~,l{,~i 11. Field and Pool Same 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Sedal No. Swanson River Field/Tyonek 334' KBI A-O28406 12. Date Spudded 7/60 13' Date I'D' Reached I 14' Date C°mp" Susp' °r Aband' 10/5/1996 12/5/96 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°ns NA fset MSL 1 17' T°tal Depth (MD+TVD) 10' Plug Back Depth (MD+TVD) J 19' Directional SurveY I 20' Depth where SSSV set I 21' Thickness °f Permafr°stl 1303'/11303' 10581 '/10501' Yes: No: X ,A feet MD NA 22. Type Electric or Other Logs Run TDT, USlT corrosion, USIT cement, CBL, GR/CCL, Pivot Gun Perf 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" 0 30' To surf 0 13-3/8" 54.5 J-55 0 3167' 17-1/2" 600 sx, 1050 sx i~ DV , 0 7" 29~, 26~, 23~ N-80& P-110 0 11382' 9-5/8" 700 sx, 800 sx Q DV 0 '~)4. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET/MD) PACKER SET (MD) 2-3/8" 6262' 5447' 8433'-8443' TVD and MD 4 spf, 0.34" dia hole , 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ORI( I AL DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12/3/96 I Gas Zone WOuld not flow due to poor cement quality behind casing causing mud to flow into wellbore. "~)ate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 12/5/96 NA TEST PERIOD => 0 0 0 NAI NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 0 0 24-HOUR RATE => 0 0 0 NA 28. CORE DATA , Brief deSCriptiOn of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. JAN 03 1997 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. 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. Tyonek 80-2 Bench 8433'-8443' 8433'-8443' Recovered only drilling mud due to poor quality cememnt behind casing. 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Rig Workover Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~(~_~J ~(~/~~~ 1 ~/-~.~ ~:;~ T~tle Drilling Manager Date INSTRUCTIONS General: This form is designed for submitting a complete and correct wall 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 space 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 productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Form 10-407 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~ ,le=,~'--- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". UNOCALe RKB to TBG Head -- 21.20' Tree connection: TC-3 Uni-bolt 1508' 800 sx pumped above DV ~ SO07'-- ]11 12 13 13a 14 15 16 PBTD = 11,182' TD = 11383' Straight hole, Max angle -- 1° SIZE WT Swanson River Field Well # SRU 12-15 Actual Completion, 11/20/96 GRADE CONN TOP BTM LENGTH 22" 13-3/8" 54.5 7" 29 7" 26 7" 23 7" 26 7" 29 7" 26 7" 29 Tubing: 2-3/8" 4.6 Surf 30' J-55 8rd Surf 3167' N-80 Buttress Surf 303' N-80 Buttress 303' 1197' N-80 Buttress 1197' 4750' N-80 Buttress 4750' 6160' N-80 Buttress 6160' 7879' P-110 8rd LT&C 7879' 9627' P-110 8rd LT&C 9627' 11382' L-80 SC BT&C Surf with 3/8" methanol inj line from surf to 2498' NO. Depth JEWELRY DETAIL Item 21.20' 22' 2498' 2 5399' 3 5447' 4 5492' 5 6262' 2-7/8" hgrw/Cameron "H" BPV profile 2-7/8" X 2-38" BT&C crossover Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve Matte 2-3/8" D-SO GLM w/l" dummy Baker FH Ret packer, 2-3/8" X 7" 26# X nipple, min. ID = 1.875" Tubing tail (shear out sub) 303' 894' 3553' 1410' 1719' 1748' 1755' 6,262' PROPOSED PERFORATION DATA TOP BTM ZONE Tie-in log = Schlumberger TDT 11/16/96 11 8433' 8443' Tyonek 80-2 12/3/96 HEMLOCK ABANDONMENT DATA 12 10,581' Top of cement plug, WLM tag 11/21/96 13 10,900' Cement Retainer, could not inject thru on 11/17/96 13a 10,967' 2-7/8" tubing cut 14 10,994' Production packer 15 11,155' 2-7/8" tubing tail, venturi shoe ABANDONED HEMLOCK PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 16 11043 11043 Sqzd 11070 11132 Hemlock 4 1960 11136 11141 Hemlock 4 1960 11145 11162 Hemlock 4 1960 11200 11210 SC1215D.DOC REVISED: 12/31/96 DRAWN BY: TAB Sqzd Summary of Rig Workover Operations Swanson River Unit Well No. 12-15 11112/96- ACCEPT RIG (~ 04:00 1115196. ND TREE, NU BOPE. TEST BOPE (WITNESS BY JOE RUSSELL-BLM) 11113196- WELL TAKING FLUID, PUMP SIZED SALT PILL TO STOP LOST RETURNS. PULL 4044' OF TUBING. STRING WAS PARTED AT TOP OF GLM #5. RIH WITH OVERSHOT AND ENGAGE OD OF GLM. ClRC AND POOH WITH FISH. 11114196- FINISHED POOH WITH 1847' OF TUBING FISH. CORROSION ON COUPLINGS. TOP OF FISH LEFT IN HOLE (~ 5899', MIDDLE OF JOINT. RIH WITH 5-314" OVERSHOT WITH 2-718" GRAPPLE AND MILL. PU KELLY AND MILL OVER FISH, ENGAGE FISH. PULL 100K (15K OVER STRING WEIGHT TO PACKER), NO RELEASE. RU APRS E-LINE UNIT. RIH WITH 2-118" JET CUTTER. 11115196- RIH WITH 2-118" JET CUTTER. CUT TUBING ~ 10,967', MIDDLE OF JOINT BETWEEN LOWEST GLM AND CC SAFETY JOINT. POOH WITH WIRELINE. ClRC TWO BOTTOMS UP TO REMOVE GAS. EST 30 CUFT ASPHALTENES RETURNS. POOH WITH FISH. RIH WITH 6" BIT AND 7" CASING SCRAPER ON 2-718" TUBING. 11116196- WASH FROM 10,958' TO TOP OF STUB AT 10,964'. ClRC HOLE CLEAN, ESTIMATE 20 CUFT ASPHALTENE RETURNS. POOH WITH SCRAPER. RUN SCHLUMBERGER. RIH AND SET RETAINER (~ 10,900'. PRESSURE TEST CASING TO 1500 PSI, GOOD. RIH WITH TDT LOGGING TOOLS. LOG FROM 8500' TO 3650'. 11117196- RIH & LOG WITH USITICBT FROM 8500' TO 3650'. RD SCHLUMBERGER. RIH WITH RETAINER STAB-IN TOOL ON 2-718" TUBING. STAB IN TO RETAINER AT 10,900' AND ATTEMPT INJECTIVITY TEST. NO INJECTION INTO FORMATION AT 3000 PSI, PRESSURE COMMUNICATION BEGAN TO ANNULUS. PU OUT OF RETAINER. TEST CASING TO 1500 PSI, OK. POOH LOOKING FOR TUBING LEAK, NO LEAK FOUND. LD STINGER, RIH WITH OPEN ENDED TUBING TO LAY CEMENT ON TOP OF RETAINER. OBTAINED VERBAL APPROVAL FROM AOGCC-BLAIR WONDZELLTO ABANDON HEMLOCK BY LAYING CEMENT PLUG ON TOP OF RETAINER. 11118196- RU CEMENT UNIT & PTEST TO 2500 PSI WI TBG ~1~ 10,905. MIX AND PUMP 12 BBLS 15.6 PPG CMT WI ADDITIVES DISPLACING WI 59 BBLS LEASE WATER. PU TO 10,352 & CBU. MIX AND CIRCULATE 6% KCI LEASE WTR WI 1% CORROSION INHIB. POOH LD TBG. ND BOP TO CIO SPOOL. 11119196-CHANGE OUT WELLHEAD PACKOFF. NU TUBING HEAD AND BOP STACK. TEST WELLHEAD PACKOFFS TO 3000 PSI. CHANGE RAMS TO 2-318", TEST TO 5000 PSI. RUN 2-318" COMPLETION, METHANOL INJECTION VALVE IN MANDREL WOULD NOT HOLD BACK PRESSURE. CHANGE OUT MANDREL WITH NEW VALVE, HELD 700 PSi BACK PRESSURE ON PUMP THROUGH TEST AT SURFACE. CONTINUE RUNNING COMPLETION WITH METHANOL INJECTION MANDREL TO 2500'. 11120196- LAND HANGER, TEST METHANOL INJECTION LINE, TEST HANGER SEALS. OVERDISPLACE TUBING WITH DIESEL. DROP BALL AND SET PACKER WITH 3000 PSI. SHEAR OUT BALL AT 3500 PSI. PRESSURE TEST ANNULUS TO 1500 PSI. ND BOPE, NU TREE AND TEST TO 5000 PSI. RELEASED RIG AT 18:00 HRS 11120196. MOVE RIG TO SRU 212-27. 11121196- RU SLICKLINE UNIT. RIH WITH 1.75" BLIND BOX. NO INDICATION OF SHEAR OUT SUB AT 6260'. TAG TOP OF CEMENT AT 10,581'. 12/03196- RU SCHLUMBERGER E-LINE UNIT. RIH WITH PIVOT GUNS. PERFORATE 8433'-8443'. GOOD INDICATION OF GUNS FIRING, TUBING PRESSURE INCREASED TO 1200 PSI. POOH AND RD SCHLUMBERGER. OPEN WELL TO FLOW, PRESSURE BLED IMMEDIATELY FROM 1200 PSI TO 0 PSI. NO FLOW. 12104196- RU SLICKLINE UNIT. SWABBED WELL. DROPPED FLUID LEVEL AS LOW AS 3800' WITH NO SIGNIFICANT GAS PRODUCTION. 12/05196- CONT SWABBING WITH FLUID LEVEL REMAINING AT 3600'. RIH WITH BAILER AND TAG MUD AT 7022', POOH WITH SAMPLE OF CEMENT/MUD/WATER. RIH WITH SWAB AND TAG FLUID AT 3592'. SHUT-IN WELL, EVALUATING ALTERNATIVES. NOV-23-96 SR? 11',37 UNOCAL P.. O. Box 196247 · Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fnx ............................................................... i i ............................... Cl._...~ ........ November 23, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax: 276-7542 Attn: Blair Wondzell Subject: Swanson River Unit Well #12-15, Approval # 396-207 Notification of Revised Perforation Interval Mr. Wondzeli: Unocal proposes to perforate SRU 12-15 in the following intervals: 8429'-8443' Tyonek 80-2 Sand We would like to do this work as early as Tuesday, November 26, 1996. After flow testing this interval, the following perforations will be added: 8315'-8357' Tyonek 71-9 Sand These perforation selections are based on a TDT log ran during the recently completed workover and are deeper than the estimated intervals mentioned in the original Sundry Application (Approval #396-207) dated 10/16/96. The upper intervals in the Sundry Application may be perforated in the future, Do you require a revised sundry application for the above perforation intervals? A Completion Report, Form 407 will be submitted following the perforating of this well. Please call me at 263-7659. Sincerely, Tim Billingsley RECEIVED NOV ?- 5 199G u AOC, CPI~RF.DOC ]. I 1/33/96 'NOV-18-96 lION 09:28 all P, 01/01 ~ p'r'~ ~o -o '8. 8. Unocal Drilling Dat~: .,Monday, No.,v,,.ember 15~ 1996 Number of pages including cover shest: I To: AOGCC Blair Wondzell Phone: 279-1433 Dan William~on Phone: 907-263-7677 F~ phone: 90%263-7554 ..... ~ ...... II . .. Llll .............. llll REMARI~: [] Urgent [] For your r~vi~w I-I Reply ASAP Ceme_o_t Retainer Stinper I.D_.for Swanson RiverSRO 12:!5 [] Plea.~ comment During our phone conversation of yesterday you requested the ID of the Baker cement retainer stinger. Its is 1 1/4". Thank you for your cooperation. Regards Dan Williamson ... ' ...... . ~ -. Iii ................. ILl . .1.11 II 1.11_ RECEIVED ~OV 1 8 1996 OCT-14-96 [I0~I 12:23 P~I · · P. 01/07 P,O, Box 196247 Anchorage, Alaska 9951 9D7-265-7660 UNOCAL ) Dale A. Haines Dnllin9 Man,gM Wednesday, October 09, 1996 Alaska Oil & Gas Cons Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject' Swanson Rivet Unit Well #12-15 APl #50-133-10138-00 Form 10-403, Proposal to Abandon Hemlock and Recomplete to U, Tyonek Dear Commissioner Johnston: Unocal proposes to abandon Hemlock perforations in Swanson River Unit Well # 12-15 and recomplete in an Upper Tyonek gas interval. This well is currently shut-in due to high water production. The proposed work will require a rig workover. The Upper Tyonek gas zone will be perforated with through-tubing guns. Attached in triplicate are the 10-403 form with BOP schematic, detailed operations program and schematics of the existing wellbore and the proposed abandonment and recompletion. Estimated start date is November 1, 1996 so your timely consideration of this proposal would be appreciated. Please direct any questions to Tim Billingsley at 263-7659 or Karla Lenz at 263-7643, Sincerely, Tim Biilingsley RECEIVED OCT 1 4 1996 Ala~k1011 & alia Cona. Commission Anchorage 0CT-14-96 NON 12:23 · STATE OF AI.~SK~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P, 02/07 A~ ~sln~ ........ Re~ir'~ll: Pluggi~: X ~Time ~e~n: St~u~te: '". C~e approval program; Pull tu~ing: X Variance: P~o~e: X O~er: 2, Name of'b~ .............. s. ~e'of we,: .... UNION OIL COMPANY OF CAU~gR,NIA (UNO~L) ._ De~lopment: x .... ~ f~t '3. Add~s " Explomto~ ,' 7. d~it ~ Prop~'~e ....... P, O, Box 1~47, ANCHORAGE AK 99519 Str~igmphi¢: S~n~n Ri~r UnR Se~ice: 4, Lo~on of ~ ~ su~a~ ............ 8. W~ ~Um~r .... ~ FNL, 1~ FEL S~ 15, TSN, Rgw, SBM 12-15 At t~ ~ pm~e inte~l 9, Petit numar Same 60~22 At effe~i~ de~ 10. APl numar S~e At t~al ~h 1 Same S~nson ~Z Pm~M ~ cond~i~"~~ .... To-ld.h: v~m"sured--ieal 11,383 f,,, ,383 f.t Plugs(measured) ORIGINAL Eff~ive depth: measured 11, t~ f~t Junk (me~umd) t~ ~bal 11,182 Casing Len~h S~e Cem~ed M~sumd d~h Tree ~1 dep~ a~uml Co~r 30' ~' Yes 3~ Suda~ 3,1~' 1~" 1 ~g 600 ~,1~0 ~ ~ DV 3,167 3,16T In~iate f 1,391' ~ I s~ 7~ ~, 8~ Pr~u~ion Liner t~ venial Same OCT 1 4 1996 Tung (sEe, gmS, and measur~ depth) 2-7/8" 6.~ N~ EUE 8RD with tubing ~ ~11 Packem and SSSV ~ and m~sur~ dech) ~ 011 & 8aS Cons, Comml~ion Br~ HS-16.~ p~ker ~ 10,~4' A~r~e 13. A~c~e~ ~crip~o~ s~maw~ ~ro~i: _ "... Detailed o~mtio~ pr~mm: ~.~ BO~ s~ch: ~ ...... 14. E~m~ted d~ f~ common,rig o~tio~ ............. 15. ~atus"of ~11 cl~'~ation as: ..... 11~1~ 1 ~; if ~r~l ~11 ve~al~ a~'~v~: .............. Oil: X Gas; Suspen~d'. . ~ame of ap~.~[ Date appr~ed Se~ce: 17. I hereby c~iN that t~e fore~i~g'je true and'~0~e~ ~ th~' ~ of my k~le~e, .............. . , .. FOR COMMISSION USE ONLY Mechanical I~rEy T~ Subs~ueM farm requir~ 1~_~ ~:: :-- - ......... 0ri~inal 8i~neo David W. Johnston Form 10403 Rev 06/15/88 Copy SUBMIT IN TRIPLICATE 0CT-14-96 MON 12:23 PM · · P. 03/07 UNOCAL Swanson River Field SRU 12.15 Workover Program 10110196 Ill I jljj ...... iiii ...... Il ...... U_ -~ ..... Ill _ ~ Abandon the Hemlock in SRU 12-15 and recomplete as an Upper Tyonek Gas Producer. Status: Shut-in Hemlock oil producer. Tubing may be parted at 4,038'. Well design: Based on recomplefing the well as an Upper Tyonek gas producer. =RKB =21~20' from_~ubin.~ ha...n._qer. Well is a straight, bole (re,a, x. dev,!,,aflon is ,,1, °30· ~ 8720'.. last ..SrU~eypoint is 0°35'~.~. t0.900!)_ I. Ri¢~ ..Mpbilizati0...~ and P....r..e. pare Well for New Como.l.e.,t.i.0n Note: Notify BLM and AOGCC 24 hours in advance of BOPE tests. Note: Notify AOGCC for possible witness of Hemlock abandonment. 1. Kill well. 2. RU ISSCO and install I~PV in Cassasco BPV profile in 2-7/8" tubing. 3. MIRU Alaska Well Service RIG 5. 4. ND tree. 5. NU BOPE, choke line, kill line, and choke manifold. Pressure test BOPE. 6. Pull 2-7/8" tubing above production packer 7. RIH with bit and scraper to 10,950· 8. RIH and set a cement retainer at 10,950' Squeeze 8.5 bbls cement below the retainer and put approximately 200' of cement on top of the retainer. 9. POOH to 9,000'. Circulate well to 6% KCl lease water with corrosion inhibitor. Pressure test cement plug and casing to 2500 psi. POOH and LD bit and scraper. ND BOPE. ND tubing head. Change out primary casing packoff in casing head. 10. 12. NU tubing head. NU BOPE and test. U 1215AOG2,DOC I RECEIVED OCT 1 4 199G Na~ka 011 & GaB (ion~. Gommtseton .6,n~orige 10/10/96 001'- ~. 4-96 lION ]2', 23 ?I'I ~ P, 04/07 UNOCAL ) II. Run 2.318" ComPletion- Swanson River Field SRU 12-15 Workover Program 10110196 fl] .... i Illll II. 13. RIH with new 2-3/8" completion as follows:. 1) 3) 4) /5) 7) 8) 9) lO) 11) 12) Baker 2-3/8" ball catcher/shear out sub one joint 2~3/8" buttress tubing X nipple (minimum ID = !.875") one joint 2-3/8" buttress tubing 2-3/8" x 7" 26# Baker Model "FH" Ret packer set at approximately 5500'. one joint 2-3/8" buttress tubing 2-3/8" Macco D-SO BT&C gas lift mandrel with dummy with handling pups. 2-3/8" 4.6# L-80 buttress tubing up to 2500'. 2-3/8" Macco SMO-lCl Chem inj mandrel w/1000 psi chem inj valve with handling pups, set @ ~2500'. 2-3/8" buttress tubing to surface with 3/8" ss control line strapped to tubing. Crossover from 2-3/8" tubing to 2-7/8" tubing. New 2-?18' Shaffer extended neck hanger with Cameron H BPV profile and prepped for 3/8" control line. 14. Land tubing, set packer and test. 15. ND BOPE. 16. NU tree and test. 17. Release rig. The perforation intervals shown below are approximate. The actual depths may need to be adjust based on logs obtained dudng the workover. The estimated perforation depths are: 56-9 sand @ 6,069' to 6,093' 58-1 sand (~ 6,168' to 6,185' 61-3 sand @ 6,422' to 6,452' 76-2 sand @ 8,028' to 8,074' 7%3 sand ~ 8,130' to 8,145' RECEIVED OCT 1 4 199t; Ahaka 011 & O# Cons. CommlHion ,~b~horage U 1215AOG2, DOC 2 "00T-14-96 ~ON 12:23 PM ,, P. 05/07 FILL-UP, ii .. . > ~¢___J~ FLOW --~ -- l.:'. .... -" ...-' 1 i - ill L .... ' ' _ PI~E RAMS . I0" 8000 10" D LINE 8000 psi P~ ~ !0" 6000 CHOKE LINE ~" 5000 ps~ J , :-: - i i ii .__ iii ii I BOP STACK 10~' 5:000 psi- RECEIVED OCT 1 4 1996 Na~ka 011 & ~a. ~n~. Commls~on ' 00T-14-96 M0N 12:24 06/07 UNOCAL ) ..................... i!)~Liji ilil i RKB to TBG Head = 21.20' connection: TC-3 Uni-bolt* Parted Tbg 4038' Swanson River Field Well # SRU 12-15 Actual Completion 4/63 oJitll. U .._ CASING AND TUBING DETAIL SIZE___WT GRADE __C..Q~.__ TOP 22" Surf 13-3/8" 54,5 J-55 8rd Surf 7" 29 N-gO Buttress Surf 7" 26 N-gO Buttress 303' 7" 23 N-80 Buttress 1197' 7'; 26 N-80 Buttress 4750' 7" 29 N-80 ' Buttress 6160' 7" 26 P-110 8rd LT&C 7879' 7" 29 P-110 8rd LT&C 9627' Tubing: 2-7/8" 6.5 N-80 8rd Surf Parted Tbg suspected at 4038' ,JEWELRY DETAIL NO. Depth Item 1-12 7 21.20 10 11 BTM.. LENGTH 30' 3167' 303' 303' 1197' 894' 4750' 3553' 6160' 1410' 7879' 1.7.19' 9627' 1748' 11382' 1755' 11,155' Tubing hanger Hole in tbg 6' from surfak, 1981 Camco GLM #1-12 as follows: 1474', 2458', 3165', 3682', 4042', 4356' 54.81', 6492', 7380', 8138', 9537', 10938' 4038' Suspected parted 2-7/8" tubing 13 10983' I4 10,994 15 11,061 16 11,155 Brown CC saf~y joint Brown Ret. packer, HS-16-1, 2-7/8" x 7" Camco D nipple Bottom of V~nturi shoe Note: Crude Loaded in Annulus, 4163 12 13 15 16 17 ~,1) ,z.co PBTD - 11,182~ ID ~ 11383~ ~tralght hole, M~ ~gle ~ 1~ AOOI21$A,DOC _.T_O._~ ....... BTM 17 110~- 11070 11136 11145 11200 PERFORATION DATA ZONE ..... SPF DATE. COUNTS 11043 Sqzd 11132 Hemlock 4 1960 11141 Hemlock 4 1960 11162 Hemlock 4 1960 11210 Sqzd RECEIVED OCT 1 4 1996 ~JW~ Oll ~A~g GOmml.~n REVISED: 10/10/96 DRAWN BY: TAB ,~ ' 00T-14-96 150Iq 12:24 P. 07/07 UNOCAL ) ................. ...~.~.E_7 nllllllll ilil ~ I I RKB to TBG Head -- 21.20' Tree co ~nectJon: TC~3 Uni-bol~ 4 5 6 8 10 11. 13 14 15 , · 16 FBTD = 11,182' TD - 11383' 5trnight hole, Max angle -- 1° Swanson PAver Field Well # SRU 12-15 Proposed Completion ..i _ _ IIIII I ..... SIZE WT GRADE 22~ 1.3-3/8" 54.5 $-55 T' 29 N-80 7" 26 N-80 7" 23 N-80 7" 26 1~1-80 7" 29 N-80 7" 26 P-Il0 7" 29 P=I10 Tubing: 2-3/8" 4.6 L-80' CONN TOP ___ Surf 8rd Surf Buttress Surf BulIrcss 303' 15uttross ! 197' Buttress 4750' Buttress 6160' 8rd LT&C 7879' $rd LT&C 9627' $C BT&C Surf ._BTM.. LENGTH 30' 3167' 303' 303' 1197' 894' 4750' 3553' 6160' 1410' 7879' 1719' 9627' 1748' 11'382' 1755' 5,560' NO. Depth 21.20' 2 3 5,500' 4 5,530' 5 5,560' JEWELRY DETAIL Item 2-7/8" hgrw/Cameron "IT' BPV profile 2-7/8" X 2-38" BT&C cwssovor Macco 2-3/8" SMO-1C I Cheat hj Mdrl w/1000 psi chem inj valve Mac~o 2-3/8" D-SO GLM w/l" dummy Baker FH Rot packer, 2-3/8" X 7" 26# X nipplo, mM. ID = 1.875" Tubing tail (shear out sub) PROPOSED PERFORATION DATA TOP BTM ZONE 6 ...... 6,069' 6,093' Tyonek 56.9 7 6,168' 6,185' Tyonek 58-1 8 6,422' 6,452' Tyonek 61=3 9 8,028' 8,074' Tyonek 76=2 10 8,130' 8,145' Tyonek 77-3 11 8,232' 8,250' 12 13 14 15 RECEIVED OCT 1 4 1996 Tyonek 78-2 Alasl~ Oil & (las Cons. ~mmlsslo~ HEMLOCK ABANDONME~NT D~,TA ~r~t 10,750' , Top of ~ment plug 10,930' ~SV 10,994' PrMuc~on packer 10,950'-11,182' ~mem ABANDONED HEMLOCK PERFORATION DATA TOP BTM ZONE SPF DATE CQMMENTS 16 11043 11043 5qzd 11070 11132 Hemlock 4 1960 11136 11141 Hemlock 4 1960 11145 11162 Hemlock 4 .1960 11200 11210 AOG121$B.DOC P~VISED: 10/I0/96 DRAWN BY: TAB/KKL Form ~160-5 (JUNE 1990) UNITED ~-"~S DEPARTMENT OF i HE 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. Type of Well Oil Gas ~: Well ~ Well I-'] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. 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. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION Notice of Intent [] Subsequent Report Final Abandonment TYPE OF ACTION [] Abandonment [] Change of Plans [] Recompletion I-'] New Construction ~ Plugging Back [--] Non-Routine Fracturing [-] Casing Repair [] Water Shut-Off ~ Altering Casing [~ Conversion to Injection [~ Other Temporarily Abandon ~ Dispose Water (Note: Rel:xxt rasults of multiple conmpletion on Well Completion or Recom~ Report and Log form.) 13. Describe Proposed or Completed Operations Cleady slam all pertinent details, and give pertincmt dates, including estimated date of slardng any Ixoposed work. If well is directionally drilled, give subsurface 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 1,1996 to March 31,1997: Soldotna Creek Unit (0~- j CJ SCU 21-8 .MISCU 34-9 ~:~Y') ~SRU 212-10 (O1" ~,~SCU34-8 ~r~scu41B-9 (.eO'~RU 12-15 (~O." I SCU 243-8! [~C.~ U 14-34 OO-! N~SRU 14-15 S I-~ SCU 13-9 L~.~ SRU 41A-15 ~0 "3oe'-~-''/ ~ I '~ SRU 23-22 Swanson River Unit SRU 43-~ G I _ SRU 21-33WE b APR 0 SBU W 7 * High GOR well that may be produced intermittently 14. I hereby certify th~ the foregoing is true and correct. Signed Dennis L. Groboske Petroleum Engineer o,~ 3/29/96 Approved by T~le C,<mditions of approval, if any: 'FCde 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any lalse, fictitious frauduler~ s~_temenls or represe~l~__'_tlc~s as to am/n~-,~ within its jurbdiction. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A Shut-in Wells during Field Blowdown Hemlock Producers Future Shallow Gas P~'oducer with the Hemlock Abandoned SCU 34-8 $CU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 7 Wells 2 Wells 5 Wells ~,~ ~.~lh GOR well that may be produced intermittently 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 Recompleted in Tyonek G1 and G2 zones · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status,, · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. tk ClvED ~PR o ~ 1~6 Unocal North Ame,~"-~,' Oil & Gas Division Unocal Corporation 909 West 9th Ave.. P.O. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region March 31, 1994 Re: Mr. Joseph A. Dygas -..~ Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 ,, 1994 Sundry Notice Request for TA Wells in Swans<)n River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same.format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 Nask~ Uil & Gas Cons. Commission ~chorage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma ~~~..Dennis L.' ~~rd~0ske Petroleum Engineer Attachment cc: L.R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Form 3160- 5 (JUNE 1990) UNIT, ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas [] Well r~ Well [-] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage~ AK 99519 (907) 276-7600 4. Location of Well (FOOtage, Sec., T., R., M., or Sun/ey Description) Swanson River Unit --- 19 wells Soidotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No, 1004-0135 Expire~: Maroh 31r 1993 5. Lease Deelgnation and Serial No. 6. ff Indian, Allottee or Tdbe Name · , · ,, 7. ff Unit or CA, Agreement Deelgnatlon Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Poot, or Exploratory Area Swanson River Field 11. County or Path, State Kenal, Alaska - 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION Notice of Intent Subsequent Repo~ Final Abandonment TYPE OF ACTION [-'] Abandonment r-] Change of i~lans FI Recompletion I'-] New Construction r"] Plugging Back O Non-Routine Fracturing 0 Casing Repair r-I Water Shut-Off [-] Altering Casing r"l Conversion to Injection [] Other Temporarily Abandon r-] Dispose Water 13. Describe Proposed or Completed Operations (Clearly slate all pennant detaib, and gh~ perlineat d~. including eslimated date o~ Marring any IXOlx~ed wm'k. 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 ~ !' * SCU 23B-3 SCU 243-8 .: <~ I SCU 13-4 SCU 341-8 · i <~ i * SCU 21A-4 SCU 13-9 ~i SCU 34-4 * SCU 34-9 5' ! * eCU 43A-4 SCU 14-34 [ -0//_-* SCU 21-8 *High GOR wells that may be produced Intermittently. Swanson River Unit SRU 212-10 ./'"SRU 14-22 $ I SRU 43-28 SRU I 5 ~usr 14-15 ~//-~/,~RU 2-1 ~ SRU 14A-33 5/ SRU 23-15 ~1 SRU 23-22~'uspSRU 24-33 'Susl~ SRU 34-15 ~1 SRU 23-27. ': SRU 32-33WD %i. SRU 41A-151c~'SRU 212-27 SRU 21-33WD1~-~_~ J 5~5~ SRU 43A-15G~ SRU 331-27 ~ u~ SRU 432-15 ~;! SRU 34-28 14. (This space for Federal and l~ate~e use) Approved by T~tle Conditions of approval, if any: RECEIVED APR - 1 1994 Tree 18 U.$.C. Section 1001, makes it a crime for any pemon knowingly and willfully m make Io any ~ or agency of the United Sta~fa~la,~rlS' C0mmissior fraudulert statements or repraserdafions as to any melter within ils ~urb(~on. *See Instruction on Reverse Side A~h0rage Attachment No. I · 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 -7 5-t5 SCU 13-4 ~ -~SCU 34-4 [e~-~ SCU 341-8 ~0o--I~ SRU 212-10 (~[- 05 SRU 23-15 (~.-~o SRU 41A-15 (~;~-..'7 SRU 34-28 e~{ SRU 14-22 ~[-~ SRU 43-28 ~_t3~SRU 23-22 ~0~[t~ SRU 32-33WD "I-~%SRU 212-27 (~-b~ SCU 243-8 ~o-~ SRU 331-27 (~7--Z SRU 21-33WDa0~ZZ-SRU 12-15 Ioo-~&SCU 14-34 &o-qc/SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown _ Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned ~z-[=t SCU 21-8' Cb-I~ SRU 14-15 ~\-~5 SCU 13-9 (~0-u~ SRU 34-15 {=~-~ SCU 34-9' SRU 43A- 15 ~{--~SCU 23B-3' %~-b~ SRU 432-15 ~u<-5~ SCU 43A-4' -~_-o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED Alaska Oil & ~as Cons. Commissio~ Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15: Shut-in gas lift producer with casing communication, Evaluate for repair or abandonment, · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate, Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3: · SRU 33-5' Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover. tO RECEIVED ~,PR - 1 1994 Gas Cons. Commission Anchorage Furm P-- 7 SUB:MIT IN DU:~ oATE* _ STATE OF ALASKA <se,~otn~r in- st ructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ~,,, ,~wE o~. wE~,L-: ' - o., ILl ' ~AS [~ II W ELL W ELL DR Y Other b. TYPE OF COMPLETION: WF, LL OVER EN BACK gESVR. Other __ NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL-('Report location clearly and in accordance with any State requirements)* 5, API NUlVLF2~CAL CODE ?. IF INDIA.N, ALLOTTEE OR At surface At top prod. interval reported below At total depth TOTAL DEPTH, ~LD & TVD~19. PLUG, BA~CK PRODUCING !NTERVAL(S), OF ~IS COMP~TIO~--TO~, BOSOM, N~E (~ AND ~)* TYPE ELECTRIC AND OTHEt~ LOGS RUN 8. UNIT,FARM OR LF~kSE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDC&T 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) DATE 'CO'MP SUSP OiR:ABAND. [16. MD & TVD[20. IF 1Vt-ULT:~PLE COMPL., I{OW 1V/~N Y * 12. PERMIT NO. I ELEVATIONS (DF, RKB, l{'r, GR, ~I'C)"Jl7. ELEV. CASINGHEAD I 21. INTERVALS DR(LLED BY fl0TABYTOOLS CABLE TOOLS 9.3, '~VAS DIRECTIONAL ! SURVEY MADE I i iii CASING RECORD (Report all strings set irt wtll) CASIiqG SIZE WEIGHT, LB,'FT. DEPTH SET (MD) HOLE SIZE CEMLNTING RECO}LD 26. LINER 28. PER2WORATt/ONS OPEN TO P~O~O~ ([ngerval, size and number) l[l~- f/l&2 DATE OF TEST, . II-{OURS TESTED ' 'ICI-1OI'2E SIZEPROD'N FO'l% [ T-EST PJ~ik!OD FLOXV, TUBING ICA~G PRESSURE [CAL~T~ OI~BBL. r~SS. ] ,[24-HOUR RA~ 3].omrosrrmN or aas (Sold, used for ~uel, vented, etc.) i i 30. PI%ODUCTION DATE FIRST P£1ODUrCTION [ P~P~ODUCT1ON 1VIEI[-[O~D (Flowi~g, gas lifL pumping--size and type of pump) OIL--BDL. I GAS--~v[C'~. 1 i ASOUNT PULLED I 27. TUBING REcorkD SCi:EEN (i~fD) SIZE DEPTH SET (MD) ~PACIfiER SET (MD) , 2~. ACID, Si!OT, FiIAC2 URE, C~;iENT SQUE2Z2, ETC. D~i 1N'I'~V.~ (MD) ~ AS,ioUNr /~D I'2!ND OF M~IEP~AL,]US~ [%VELL .~'FATUS ( Producing or [WA'rEr~--~L. I G~xS-OIn n.~TIO WATER--BBL. I OIL GRAVITY-~I (CORR.) TEST WITNESSED BY 32. Lint OF ATTACHMENTS 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available r'ecords SIGNED TITLE DATE *'~'~__~ ~[_'*- ~l~ ..... *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in cther spaces on this form and in any ~ttachments. Items '~0, and 22:: If this well is completed for separatc prc, duction from more th,~n one interval zone (mulliple completion), so state in item 20, and in item '22 show the p~cduci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a sep,3rate report (page) on this form, adequately identified, for each additional interval to be seperately produce,J, show- ing the additional data pertinent to such interval. ,' Item'~: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiPle'stage cementing and the location of the cementing tool. I.t~m 28: Submit a separate completion report on this forrn for each interval to be separately produced. (See instruction for items 20 and 22 above).' FORMATION T~S'I'S IN('LUI)IN(; IN'I'EItVAL T~..STED, l'r?~-.'e~gUt-tE DATA. A_N~ ~COVE'ItI~ C)F OIL. GAS. r . : . 35, G~GIC MARK~ WAT~: AND MUD MEAS. D~ ~ V~T. ?xTA. A'~'rAClt BRIE~ D~CRIm~NS Or LITItOLOGY. POROS~Y ~HAC~R~. . ,. ...~::-,. . ~ , ~: . ~. ~.,. :': ~'" '":"X~'~q'[i; ~,iow's ~r o~. ~ ou ~v.T~'. ,,, COMPLETION REPORT - PACKER AND GAS LIFT INSTALLATION STANDARD OIL COMPANY OF CALIFORNIA, ¥~ESTERN OPERATIONS, INC - Operator AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No.: A-028406 PROPERTY: Swanson River Unit WELL NO.: SRU 12-15 Section 15, T. 8 N., R. 9 W., Seward B & M LOCATION: Surface: 2285' South and 1054' East from Northwest corner of Section 15. ELEVATION: 334' K. B. K. B. is 15' above ground. DATE: July 11, 1963 C.V. CHATTERTON~ Distri6t Superin'bend~ent CONTRACTOR: Santa Fe Drilling Company, Rig #35 DATE COMMENCED REMEDIAL WORK: April 3, 1963 DATE COMPLETED RE~DIAL WORK: April 7, 1963 TOTAL DEPTH: 11,383 ' PLUGS: 11,182 ' - 11,383 ' CASING: 22" cemented at 30' 13 2/8" cemented at 3167' 7" cemented at 11,382' SWANSON RIVER UNIT' t2-15 Section 15,.T. 8 N?, R. 9 W., Seward B &. M STANDARD OIL 'COMPANY OF CALIFORNIA, ~JSESTERN OPERATIONS, INC - Operator April_.3, 1963.: C'ommenced rigging up at 1:00 PM. Conditioned Black Magic Mud. Apri.~ 4~ 1963..:. Ran dewaxing tool on wire line. x-mas tree and installed BOPE. Lost wax scraper in tubing. Killed well, removed April 5, 1963: Pulled ~ 7/8ii tubing. Ran casing scraper to 11,162' mud. Unable to get below 11,162'. Circulated and conditioned April 6,~ 1963: Pulled scraper. Reran a total of 352 joints 2 7/8", 6.5#, N-80 EUE 8R Rg 2 tubing equipped with packer and mandrels. K. B. to tubing head Shaffer Donut Two 2 7/8" pup joints 46 joints 2 7/8" tubing Camco MM Mandrel w/RD (#1) 31 joints 2 7/8" Camco MM Mandrel 22 joints 2 7/8" Camco MM Mandrel 16 joints 2 7/8" Camco MM Mandrel tubing (#2) tubing w/Ro tubing w/RD 11 joints 2 7/8" tubing Camo o MM Mandr el w/RD (#5) 9 joints 2 7/8" tubing Camco MM Mandrel w/RD (#6) 36 Joints 2 7/8" Camco MM Mandrel 32 joints 2 7/8" Camco ~ Mandrel 28 joints 2 7/8" Camco MM Mandrel 24 joints 2 7/8" Camco MM Mandrel 46 joints 2 7/8" Camco MM. Mandrel 45 joints 2 7/8" tubing w/RD (#7) tubing w/RD (#8) tubing w/RD (#9) tubing w/RD (#10) tubing w/ D (#z,,) tubing Camco MM Mandrel w/CEV (#12) 1 joint 2 7/8" tubing Brown CC Safety joint One 2 7/8" pup joint Brown 2 7/8" X 7" HS-16-1 packer 2 joints 2 7/8" tubing Camco "D" Nipple 3 joints 2 7/8"" tubing Venturi Shoe Tubing landed at Tubing Detail 21.20' .85' 17.69' 1434.01' 12.83 ' 971.62' 13.04' 693.37' 12.68' 504.66 ' 12.89 ' 31,6.94' 12.78' 2 81.81 ' 13.03 ' 1131.72 ' 12.70' 998.48' 12.71 ' 874.96' 12.75' 745.13' 12.73' 1386.77 ' 12.71 ' 1388.oo' 13.03' 31.59' 1.06 ' 10.02 ' 6.O1 ' 60.85 ' .91' 92.86' .68' 1 ,155,o? - K.B. Depth 22.05' 39.74' 1473.75' 1486.58' 2458.20' 2471.24' 3164.61' 3177.29' 3681.95' 3694.84' 4041.78' 4054.56' 4336.37' 4349.40' 5481.12' 5493.82' 6492.30' 6505.01' 7379.97' 7392.72' 8137.85' 815o.58' 9537.35' 9550.06' 10,938.06 ' 10,951.09' 10,982.68' 10,983.74' 10,993.76' 10,999.77' 11,060.62' 11,061.53' 11,154.39' 11,155.07' SWANSON RIVER UNIT 12-15 S.ect...i. on. 15, T. 8 N., R. 9 W,~ Sewa~.d B &'M ~ STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPEP_J~Ti~S, INC - Operator Ap,ril 7, 1963_: Removed BOPE and installed x-mas tree. Displaced mud with oil and set packer at 10,994'. Returned well to production. Rig released at 4:00 PM. S.R. HANSEN SRH/sat UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY :.x ~ O.~ OPERATIONS LESSgE'S 5AONTHL¥ RE,PC ~ ...... ~* ,,,'~.~) p,r t,,~;c ,,~,,,,";'~ ~.,/'. ...... ~r$L ?63 ....... S~naon ~ver ung~ ............... :~(,,,~,', ~,';4r,'..,'.; P 0 ~X _7'839 (/o,,~.;:',~ ,; :v 8~~ O~ 00. OF. C~!F., W.O.I. ............................................................................~o~ { . ........ { ........................ { ........... { ~ SW~SON NIT ~- ~ 8N 9w~ ~ Co~nce~ ~m~alal work April 3, ~1963. ~llea Black ~gic med. Remo~ x-~a $~e and insured ~lle~ t~bing~out of hole a~ ~ casi~ 'sc~per. 2 7/8" t~bing~equipped With ~ek~r and ~4 tCbi~ at 11,155'. ~6~ ~PE 8nd ins~lled. t~e. D~sp~eed ~d wi~ oil a~ set ~9ker at 10,99%'. Rig U.S.G.S.1 i- M. iH. Soyste~ SVelte- ~. R. Marshall Riehflel~ - C W. Perry R. R. Rittez Marathoni - Oe¢Irge 8owardm Unio~- t' M.. Lian Fish & Wl l~[liJ~e Service !- J. B. ~iles- ,rodu¢lng Petroleum Branch ~l¥1s~oB ....... source~ · '' Of Nkines anci' MinetaJ'~' Ai.ska Dept. ot No~u,~} Re No?~.--There were ...................................................... runs or sales of oil; ............................................... M cu. ft. of gas sold; runs or sales o[ g'r~soline during the month. (Write "m)" where applicable.) No'r~:.--- ]:l.epor[ on Chis form is required for ea(d~ eMenda, r monLh, regardless of tho :4~t~tus of opera[ions, and mus~ be filed in duplicate wi[h the supervisor by Che 6[h of t;he succeeding mo'n~h, unless ot. herwise direct, ed by the supervisor. (J~uary 1050) PRODUCING DEPARTMENT TELI~PHONE 47~0'1 J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX 839 · A N C H O R A G E · A LA S KA January 3, 19,61 Mr. R. V. Murphy Alaska Oil & Gas Conservation Commission 329 ,Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, is the Completion Report for Swanson River Unit Well 12-15 (12) for your information and files. Very truly yours, STANDARD OIL COMPANY OF CALIFORNIA Western Operations, Tnc. Enclosure J. T. CROOKER WELt. RECORD INVENTORY Fi e ] d: Swanson River ,m mm - Loca ti on · 2. 3. 4,, 5. 6. 7. ....... Swanson' Rive; V~,: ~'~12-15 , Drilling Permit: No. Pages 2 Survey Plat: Monthly Reports (P-3): Completion Report (P-7): _ 1 , -il i i i ILIIII I ~ t I Well ttisto~: Other: Mi s ce 11 aneous: , ,, 0 Total Pages: Deviation Survey(s): NONE Wel 1 Logs: _(! ) IEL-2 m m (2) SL _(3)_ _ (4) _(5), _(_6) N CL&PR (7) (8) (lO) i i ii i m i i m COMPLETION HEPOHT - NEW OPERATIONS_, _I~{C. ~ Ker~ Penins~ Cook In,et Area PROPF~TY~ ~anson l~ver Unit LAND OFFICE, Anchorage Lease No. 028/~06 WELL NO.: LOCATION: SRU 12-15 SEC. 15, T. 8 N., R. 9 W., Seward 2285, S & 1~5~, E from N~ Corner Section 15 projected, T. 8 N., R. 9 W., Seward E~EVATION: 33~' K. B. DATE: November 29, 1960 K. B. is 15' above ground DRILLED ~: Coastal D~:~ing Oompar~ DATE COalESCED D~XLLING: July 24, !~0 DATE COMPLETED DRILLING: October ~, 1960 DATE QF IKiTIAL PRODUCTION: October 13, 1960 PRODUCTION: Dai~y Average 331 B~D Flying Oil.......... 328 B.~· Gravity......... 31.8° Water........ 3 B/D TP.............. 22~ Gas.......... 41 MEF~ Bean........ · · ·. 16/64" TOTAL DEPTH: 11,383' PLUGS, JUNK: None 11,383'-11,300' 11, 300 ' -11,182 ' CASING, 22" Conductor cemented'at 30' 13-3/$' Casing cemented at 3167' in 2 stages. 1st stage around shoe with 600 sacks 2nd stage through DV @ 1508' with 1050 sacks 7" Casing cemented at 11,382' in 2 stage~. 1st stage around shoe with 700 sacks 2nd stage through DV @ 8007' with 800 sacks 4. 6. 4- ?. 8. 4' 9. 4- ~" Jet holes per ft. 11,200'-11,210', 10' 41 shots squeezed) ? jet holes at 11,043' (squeez.ed) ~' jet holes at 11,163~'-11,164~' "jet holes per ft 11, O70'-11,132', 62', 249 shots ~' Jet holes per ft 11,136'-11,141', ~', 21 shots ~' jet holes per ft 11,146'-11,162', 16', 6~ shots ~.." Jet holes per ft 11, O70'-11,132', 62', 249 shots re -perf ' d) ? Jet holes per £t 11,136'-11,141', 5', 21 shots ' re-perf ' d) "jet holes per ft 11,145'-11,1%1', 6', 2~ shots re-perf'd) W~.~L SURVEYS: 1. Schlumberger IES log interval 11,388'-3167' 2. " Sonic log interval 11,385'-3167' 3. " Micro log interval 11'387'-3167' 4. " Neutron log interval 11,300'-30OO' 5. Core Lab. Mud Log interval 9,000'-11,383' DXLL STE~ TESTS 1. HFT ~1 Open hole interval 3406'-3425' 3. ~ #3 " " " 5005'-502~' ~. H~ ~ " " " 5566'-55~1' 5. ~T ~ on ~rforated ~te~al 11~2~-~210~ ~ 6. ~T ~6 on ~orations at ~,043~ ~ _ ?, HOT ~7 ~ ~rfo~tio~ at 11,~3}' 11,~4~' W~ COMPIETION REPORT - NE~ WELL S~ANSON-RIVER UNIT 12-15 ,.S.,ecti. on 15. T. 8 N.. R. 9_~.,,. Seward B&M ..... STANDARD OIL CO. OF C~iFORNIA, WOi' OPERATOR Spudded at 12:00 midnight, July 24, 1960. Page 3. Drilled 12~" hole. 30' - 1507' 1477' drilled 75 pcf mud Drilled 12¼" hole 1507' - 2699' 1192' drilled 75 pcf mud necessary during drilli~ operations. Reamed tight spots as July,,,,,2,6, !960 Drilled 12~" hole 2699 ' - 3167 ' 468 ' drilled Opened 12¼" hole to 17½" hole 30' - 259' Opened 12¼" hole to 172!'' hole 229' opened 259' - 19P3' Opened 12{" hole to 17~' hole 1734 ' opened 1993 ' - 3167 ' 1174' opened Conditioned hole. 76 pcf mud 75 pcf mud 86 pcf mud Cemented 13-3/8" casing a t 3167' in two stages, with 1650 sacks of construction cement, using Halliburton Power Equipment, used 1 top and 1 bottom rubber plug, ~irst stage with 600 sacks around shoe. Pumped in 40 bbls of water, mixed 600 SaCks in 32 rain with Halliburton truck and dis~aced in 43 rain with rig pumps. Working press. 500 psi, final press. 1000 psi. Average slurry w~. 115 pcf. Good circ. Pipe froze on bottome Second stage through DV collar at 1508'. Opened DV collar. Pumped in 20 bbls water, mixed 1050 sacks in 70 rain with Halliburton truck, displaced in 24 rain with rig pumps. Final press. 1650 psi. Average slurry weight 115 pcf. GOod circulation throughout. COMPLETION REPORT - N~J WELL SWANSON HIVER UNIT 12-15 Section 15, T. 8 N, R..~ W,,. Seward 'STAND~d~D'~' OiL 'CO. OF ' ~A~:., woi' i' 'OPE~TOR Page Casing Detail Ail 77 its or 3172.7' 13-3/8" 54.5~, J-55, 8R, equipped with Baker guide shoe. Baker flexi-flow float collar at 1462'. Halliburton dv collar at 1508'. Centralizers at 3028, 3073 and 3120'. Ail 77 jts or 3172.7' Above KB 5.7.,_ ~i~nded ~[t ...... -3167.0' Finished landing casing. Tested head with 15OO psi-okay. Installed BOPE and tested ~ith 15OO psi-okay. Drilled out DV collar at 1508'. Cleaned out to 3146'. Drilled out cement 3147'-3167' · Drilled 121~'' hole. 3167' - 3283' 116' drilled 75 pcf mud ~,ugust ,!, 1969 Drilled 121,'' hole 3283' - 3395' 112' drilled Cored ~" hole, Core #1 3395' - 3425' Core Description #1 30' cored, 10' recovered Top 10' SS reed gry MG SA-SR Fair sorting V Fri Num Carb partings in Lams Bottom 20' No recovery cleaned out. Made up Halliburton tester. HFT #1, 3406'-3425'. Tool assembled as follows: 2 outside BT recorders, 7' of perfs, left hand safety joint, single end wall packer assembly, VR safety Joint, hydraulic jars, 2 inside BT recorders, hydrospring tester, 90' of D.C. and TC adjustable choke. Set packer at 3406', tail to 3425'. Opened tool at 4:25 for 20 rain ISI pressur'~'~ .... ~0pehed'":t~°l ~t~ surface at 4.45. Tool open 1 hr 42 min. Immediate strong blow. ~,.. subs...urf.a, ce bean~ open 1 hJr lO min. Representative flow rates: 3/8" surface bean 1~70 MCF/.D gas, 690 psi tbg. press. ~" surface bean 1910 MCF/D g~s;,"'-240"p~[ ~bg~Press. 3/8". sub.sUr.,face bean open 32 min. ,R, epresentative flow rates. 3/~8 ...s.ur..face. bean 4ooo MCF/D, 780 psm t g. press. 1 surface bean 4420 MCF/D ga~, 250' psi t~g. Press. One hr. FSI press.. Recovere~'~30""~'"net ri%-~all, thin drilling fluia. CO~.~LETION REPORT - NEW WELL SWANSON RiVER UNIT 12-15 S~ction.15, T- 8~N,, R~i9 W.~ Seward B&M -STA~DA~"'OiL':'6~)" OF' C~b~O'RN~, wOI',' OP~T'OB .... Page 5. A ugust Z, (C.o t PRESSURE DATA: IH ISI IF Bottom outside recorder 1815 1406 1406 Top " " 1785 1392 1392 Bottom inside recorder 1768 1378 1358 Top " " 1758 1379 1357 FF 1406 1392 1227 1221 FSI 1406 1392 1381 1380 1790 1777 1758 1755 FH Opened 8½" hole to 9-5/8" 3395 ' - 3425' 30' opened Drilled 9-5/8" hole 3425' - 4995' 1570' drilled Cored 8~" hole, Core 4995' - 5025' 30' cored, 30' recovered ~_0re._Des. c...r.iption , core Top 5' Greenish gry Sltstn - firm, clayey, slightly sandy, micaceous, greenish gry Sltstn Next 19 ' Gry Snd -Massive, fine grained to locally coarse grained, soft, crumbly, locally mushy, clayey, finely micaceous, greenish gry Snd with streaks of coal Next 3 ' Ory Sltstn & Clystn as above Bottom 3 ' Lime cemented, hard, dark gray carbonaceous shale. HFT #2, 5005'-.5025' Tool assembled as before. Setp~cker at 5005' · Opened t~0ol at 6':3'~ ~ fo~ 30 m_in ZSI pressure. Opened tool to surface at 7:03 PM for 1 hr 30 min flow period. ~". bean open 33 rain; 3/8" bean open 57 min. Medium blow throughout test - no gas to surface. Shut in tool at 8:33 PM for 30 rain FSi pressure. Recovered 25' of gassy drilling fluid. Chart showed perforations plugged. Test inconclusive. 85 pcf mud August .5., 1960 Ran in with core barrel cleaned out from 4995'-5025'. COMPLETION REPORT - NE~ WELL SWANSDN RIVER UNIT 12-15 Section 15, T. 8 N.~ R- 9 W., Seward .~_.~opERATORB&M Page 6. ~.~Ug~s.t _.5, 1960 cont'd. HFT#3 5005'-5025' Tool assembled as follows: 1 outside BT recorder, 12' perforated tail pipe, safety joznt, 7 open hole pacer, VR safety joint, hydraulic Jars, 2 inside BT recorders, hydrospring tester, 1 stand 7" DC (air cushion) and T.C. valve on 4887' 4½" DP. Used 450' 83.5 pcf mud cushion. Set packer at 5005'. Opened tool at 8:03 A~ for 31 rain ISI press. Opened tool to surface at 8:34 AM for 1 hr 56 rain flow period. ~" subsurface bean open 1 hr 56 min. Medium blow increasing to strong in 1 min. Gas to surface in 3 min. Shut tool in at surface 8:53 - 9:07 to repair flow meter. Gas flared at stack at 9:07. Representative flow rates of dry gas as follows: Surface Bean Subsurface Bean T.P. Gas Rate 3/8" 1/4" 1125 psi 3300 MCF/D 1/4" 700 psi 3450 " ., /, 2,' 1/4" 275 psi 4500 "' Cushion to surface in fine spray 1 hr 36 rain after tool opened. Spray continued until end of test. Shut tool in at 10:30 AM for 30 rain FSI press. Recovered 300' mud cushion. :Press. ,~ur,,e' Da~t~a IH ISI IF FF FSI FH Outside BT 2881 2113 2113 2113 2113 2881 Inside BT 2864 2099 2025 2036 2101 2864 Inside BT 2887 2151 2080 2089 2153 2876 Opened ~" hole to 9-5/8" hole. 4995' - 5025' 30' opened Drilled 9-5/8" hole 5025' - 5247 ' 222 ' drilled 84 pcf mud August 6, .!9._6~ Drilled 9-7/8" hole 5247' - 5555' 308' drilled Cored 8½" hole, .Cor~ #3~ 5555' - 5568' 13' cored, recovered 13' 85 pcf mud COMPI~'~TION REPORT - NE~ WELL SWANSON RIVER UNIT 12-15 Section 15~ T. 8 N ~ R. 9 W., Seward B&M STANDARD OIL CO. OF CALIFORNIA, WOI -OPERATOR' Page 7. Au st .6. !96.o.. cont'd Core~ Description.,_- Core Top 12" Interbedded fine grained, clayey, friable, micaceous, greenish gray sand and dark gray sandy Sltstn. Bottom l' Lime cemented sandy dk gry Sltstn _..August_ .7,~ ,lp6Q Cored 8½" hole, ,C, or, e,, #.4 5 68' - 558t' 13' cored, recovered 9' Core Description - Core #4 Top 1½' Lime cemented med. gry sndy sltstn with vertical fractures Ne~t 7½' Gry snd masive, fine to med. grained, slightly, clayey, Micaceous, fairly clean, greenish gry snd faint flash. Last 2" - hard burned limy siltstone. Bottom 4' No recovery Conditioned mud. HFT #4, 5566'-5581'. Tool assembled as follows: 1 outside BT recorder, 7' of '5L3/4" perf0rated'~il pipe, left hand safety joint, 7" single end open hole packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester, I stand 7" DC and TC valve on 5423' of 4½" DP. No cushion. Set packer at 5566'. Opened tool at 9:22 PM for 30 min ISI pressure. Opened tool to surface at 9:52 PM for I hr 40 minflow period. ¼" subsurface bean open i hr 6 min. Immediate strong blow. Shut well in'at surface at 9~59 PM-lO:07 PM to repair surface fittings. Flare lit at 10:07 PM. Representative unstabilized flow rate as follows: 3/8" surface bean 1620 MCF/D 800 psi tbg. press. 1/2" surface bean 2640 MCF/D 500 psi tbg: ~ress. l" surface bean 2640 MCF/D 125 psi tbg. press. 3/8" subsurface bean open 34 min. Representative unstabilized flow rate 1" surface bean 4200 MCF/D, 200 psi tbS. pressure. Shut in tool at 11:32 PM for 30 min FSI pressure. Recovered 240' net rise, all sandy drilling fluid. Charts indicate partial plugging of tail pipe perforations during test period · but test conclusive, COMPI~TION REPORT - NEW ¥~ELL SWANSON RIVER UNIT 12-15 Section 15~ T.~ 8 N.~ R. 9 W.~. Seward B&M STANDA'~ O~rL CO"' OF "C~- f 0 iX, "wb'r '-" OPERATOR- Page 8. Aug_uat 7¢,. 1..960 cont ',d~ Pressure Data: IH ISI IF FF FSI FHS Outside recorder Inside recorder Inside recorder 3246 2407 2062 3214 2435 2010 3210 2433 2001 2070 2338 3246 698 2355 3207 687 2356 3201 Aug s_t 8_, 85 pcf mud Opened 8½" hole to 9-5/8" 5555 ' - 5581' 26' opened Drilled 9-5/8" hole 5581' - 5945' 364' drilled 85 pcf mud August 9-September 14. 1960 Drilled 9-5/8" hole 5945 ' - 1t. 307 ' 5362 ' drilled 84-96 pcf mud (Installed mud logging equipment 8/28/60) Drilled 9-5/8" hole 11,307' -~ 11,383' 76' drilled Conditioned mud. Ran Schlumberger I-ES, Sonic and Micro logs interval 11,383'-3167'. Mud logging equipment released. 96 pcf mud ~eptemb~._,r 16, 1960 Conditioned mud. Laid down DP ~LS~p,,te.~mb,,er 17 ~ 1960 Cemented 7" casing at 11,382' in 2 stages with 1500 sacks of construction cement treated with retarder using Halliburton power equipment. Used I top and 1 bottom rubber plug. _lst_s~age~ around s hoe with 700 sacks. Pumped 40 bbls of water ahead, mixed 700 sacks in 30 min with Halliburton trucks displaced in 42 minwith rig pumps. 800 psi working pressure, 1700 psi final pressure. Good circulation until last 5 mins when returns lost. Average slurry weight ll6-117 pcf. 2,pd,s~ag,e through DV collar at 8007~ with 800 sacks. Pumped 20 bbts of water ahead, mixed 800 sacks in 35 min with Halliburton truck and displaced in 30 min using rig pumps. 900 psi working pressure, 2000psi final pressure. Average slurry weight ll6-117 pcf. Full circulation throughout. COMPLETION REPORT S~ANSON RIVER UNIT 12-15 ~ection 15~ T' 8 N.~ R. 9 W., Seward B&M ~NDARD OIL'CO. '6F 'cALiFoR~,' WOI ' 'OPE~.'To~ Page 9. _S~ep~ember 17~ .1960 cont'~ ~C asing Detail Top 7 jts Next 27 jts " 82 its " 42 jts " 39its " 1 X-over " 43 jts '~ 32 its 311.75' of 29# N-80, B.T. 893.94' of 26~ N-80, B.T. 3553.4o, of N-80, 1410.76' of 26# N-80, B.T. 1718.O7' of 29# N-80, B.T. 7.65' of 29# N-80, B.T.' to L8R 1740.11' of 26# P-ilO inc. DV L8R t354.15' of 29# P-110, L8R 1 pup marker 9~30' of 29~ P-ilO, L8R B~ot~om 9~.~s:...~_ _392.29' of 29# P-110, L8R Equipped with Baker flexiflow shoe on bottom of 1st jt., Baker flexiflow collar at 11,337 ', D.V. collar" 8007 I centralizer pr. jt. in interval llO00' to ll300'. Centralizer at 7970' and at 8041'. Scratchers ~t 10' intervals llO40' to ll070', lll60' to lllgO' and 11240' to 11260'. 1All 283 jts or 11,391.42' Above KB .............. 9..0~' Csg. landed at 11,382' Installed tubing head. S?pt~ber ,,1,8~, !9, 6,0 Installed and tested BOPE to 1500 psi - Okay. Picked up DP. Sept,.e,mber l?~ .196.,9 Drilled out DV collar and bottom plug at 11,274'. Tested DV collar at 3000 psi for 30 min-Okay. Tested BOPE at 1500 psi for 30 min-Okay. Cleaned out from 11,265'-11,300'. Conditioned mud. 94 pcf mud .$,,ep,t..e~mber ,2,0~,,, ,196C) Ran Schlumberger Neutron-Collar log 11,300'-3000'. Ran Schlumberger jet gun and perforated 4 - ½" holes per ft. ll,200'-ll, 210'. Ran in with Halliburton tester. Tool would not set, Pulled out, left half of safety joint, packer, recorders and tail in hole. Top of fish 11,278'. Ran back with top half ~f safety joint and tried to screw into .fish. Did ne%~e~o.Ver .~ish, ~ mud COMPLETION REPORT - NEW WELL SWANSON RIVER UNIT 12-15 Section 15, T. 8 N, R. 9 W.,.. Seward B&M OIL "OF b:P m-To Page 10. sep~Sembe.r. 21722, ~960 Ran Bowen slip socket. Recovered fish. ,HCT #5.. on perfs ll,GO0'-ll, 210'. Tool assembled as follows: Outside BT recorder, 5' perforated tailpipe, Junk pusher, 7" packer, VR safety joint, hydraulic jars, inside BT recorder, hydro-spring tester, dual closed in pressure valve, lifting nipple. Used 3000' W.C. Set p. acker....at ~1,.110'_. Opened tool at.^ll:25~PM f.or .45 min ISI pressure. Opened ~&0i'tO surface'at 12:10 AM for 3 hr 5u rain xiow %es%. Water cushion to surface in 5 rain at 12:15 AM. Mud to surface in 1 hr 40 rain at 1:50 AM. Oily water to surface in 2 hrs and flowed for remainder of test. Shut in well at 4:00 AM, reversed out water until 5:20 Ai~i. Samples average 96% water; 2% sand and mud~ Salinity 2100 g/g; flow rate 1200 B/D. Pressure Data: IH ISI IF FF FSI FH Inside BT recorder Outside BT recorder 7141 5601 1771 5084 5561 7141 7254 5678 2095 5085 ...... Set Halliburton cement retainer at 11,180'. Broke down formation with 3500 psi. Pumped in5 bbls of water followed by 19 bbls (100 sacks) cement followed by 5 bbls of water thru tool. Closed tool, pumped in 28 bbls of mud, leaving 1 bbls cement in D.P. Final pressure 1000 psi. Backscuttled 1 bbl of cement out of D.P. Cement in place at 11:30 PM. Estimated 94 sacks cement behind casing. Ram in, checked retainer at 11,182~ · 94 pcf mud S~ e?bember 2_3,. 1960..~ Well stood cemented 24 hrs. Ran Schlumberger jet gun and perforated 5 - ½" holes at 11,043'. Halliburton WSO test on perfs 11,043'. Tool assembled as follows: Dual shut in valve, hydraulic jars, safety joint, 2 outside BT recorders, 2 inside BT recorders. Used 3000' WC. Set pacRer at 10,996', tail to 11, O16'. Opened tool for 45 rain ISI pressure. Opened tool to surface for 1 hr flow test. Strong ~eady blow throughout test. Shut tool in for 45 min FSI pressure. Recovered 950' net rise, oil & oil~ gas cut mud. Pressure Data: IH ISI IF FF FSI FH Top inside BT 7121 5~.74 1311 1735 5576 7095 Bottom Inside BT 7077 5551 1310 1718 555~ 6880 Top Outside BT 7136 5552 1311 1707 5560 7018 WNSO COMPLETION REPORT - NA~W WELL SWANSON RIVEH UNIT 12-15 Sect ion 15, T. 8 N.,, R. 9 W., Seward C0' ' CAL F o N , September 24, 1960 cont'd. Set Halliburton DM packer at 11,002'. Broke formation down with 6000 psi~ Fluid pumped away at 2 bbl/min at 3200 psi. Pumped in 10 bbls of water followed by 9.5 bbls of construction cement treated with 3% HR-4 retarder. Mixed to 117# :~lu slurry, followed with 2 bbls water and 33 bbls mud. Closed tool with 13.5 bbls mud and 1 bbl of cement in DP. 1.5 bbl cement in casing below packer. Estimated 39 sacks outside casing. 94 pcf mud S..ep$.e..mber 2~5,~. 1960 Stood cemented 24 hrs. Drilled out cement retainer at 11,001'. Drilled out hard cement 11,002 ~ -11~ 041 ~. 92 pcf mud Se.p,t,e, mber. 26,~ 19~69 Condit_ioned mud. Ran Schlumberger jet gun and perf'd 5 r ~' holes 11,163~'- 11,164~'. Halliburton WSO test on perfs ..1!,.!.63~',!!,164~!~. Tool assembled as follows:~-'~""2 '~6{side' BT re60r6~rs'' -1 inside PRD,~ 5' Perf'd tail, junk pusher, 7" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydro spring tester, lifting nipple, dual closed in pressure valv~ 11,143' 2-7/8" D,P., 30' W.C. Set p~.. cker at 11,116', tail to 11,130', 3000' W.C., at 1:36 PM. Opened tool ~6r'""4'~ min'I'~i '~essu~'e.' ~o~en~d~ ~ooi-to surface at 2:~1 PM for 1 hr flow test. No blow. Closed tool for 4% min FSI pressure. Recovered 20' net rise all drilling fluid. Pressure Data~ IH ISI IF FF FSI FH #1 inside BT 7114 1601 1329 1311 1408 7114 #2 inside BT 7096 1594 1334 1317 1408 7086 #1 outside BT 7141 1576 133~ 1326 1398 7138 W. SoO.-O.K. Attempted to run Schlumberger jet gun, stopped a t 11,072', would not go. Pulled out and found 200 capsules missing from shot strip. Ran in, cleaned out to 11,182'. Conditioned mud. 94 pcf mud Ran Schlumberger jet gun and perf'd 4 - ~" holes/ft 11, 070 ' -11,132 ' ~ 11,136'-11141' 11,146'-11,162'. Reamed from 11,062'-11,178'. Circulated and conditioned mud. 92 pcf mud COMPLETION REPORT - N~ ~LL SWANSON RIVER UNIT 12-15 Section 15, T. 8 N., R. 9W., Seward B&M _ Page 12. ~SeRtember 28, 1960 , , . -,~ ....~, .~ :. ~ Laid down D.P. Laid down D.C.'s and Kelly. Made up tubing. Tubing stuck at 11,135'. Circulated and washed out to 11,166'. Landed 2-7/8" tubing at 11,152'. Tore o~t BOPE. · 92 pcf mud ,.S..eptember 29,,_~,, 3,9, !96~ Installed Xmas tree. Ran production test. Production test. Started to circulate at 2:15 PM. Returns to surface at 6':l~"p~"'shut'Halliburton equipment off at 6:15 PM. Pumped in 435 bbls. From 6:45 to 9:10 flowed out of casing in a dribble about the size of a pencil 50 psi tubing pressure. Began flowing thru tubing at 9:10 PM. Flowed dead oil until 1:25 AM. At 1:25 AM gassy live oil at estimated rate of 300 Well died at 1:45 AM. Began flowing again at 2:20 AM. From 3:00-4:40 AM flowed oil at 316 B/D rate, 28.3 gravity; 105 cut (7.6% water, 2.4% sand & mud); 16/64" bean; 55 M~F~ gas; tubing pressure 50-1OO psi, Csg. press: vacuum. Well died again at 4:40 AM. Dead until 5:00 AM. Changed to 32/64" bean at 5 AM. From 5 AM to 7AM flowed (gauged) 508 B/D rate, 28.4 gravity (dry), 105 cut (7.4% water, 2.6% sand and mud), 32/64" bean, 80 MCF/D gas, 50-125 psi tubing~ pressure; casing pressure: vacuum. Flowed 1OO bbls to sump and 80 bbls thru meter. 7 AM until 12:30 PM well flowed oil at average rate 540 B~, 75 MCF/D, 60-100 PSI tubing ~ressure, casing pressure - vacuum, 30-40 psi trap ~r essure. 12:30 PM until 2:30 PM well flowed oil at average rate of 650 B/D, 85 MCF~ gas, 100 psi tubing pressure, 40 psi trap pressure. Shut well in at 2:40 PM. Flowed 370 bbls total, estimated 120 bbls to sump. Shut in well at 4:00 PM 9/30/60 prep to k~ll well. Conditioned mud. 90 pcf mud ~,.b,obe,r .1, !96~_ Displaced oil with mud. Killed well at 7:00 AM. Circ and cond mud thru Y~nas tree. Installed BOPE. Pulled tubing. 90 pcf mud ~ctober 2,,. 196.0. Conditioned mud to 11, 182'. Spotted 12 bbls oil emulsion mud. Ran Schlumberger jet gun, stopped at 3400'. Ran 4-5/8" bit, and broke circulation in stages 10, $49~ to bottom. 90 pcf mud COMPLETION REPORT - NEW WELL SWANSON RIVER UNIT 12-15 Section 15, T 8 N., R. 9m W., Seward B&M ~ST~~D ~0iL-' ~'0~j ' OF CALiF0~ ~ ~OI' ",l"-Op~'jOR Page 13. Conditioned mud. Ran Schlumberger jet gun and perf'd 4 - ~' holes/ft ll, O70'-ll,132'; ll, 136'-ll, 141'; ll, 145'-ll,151'. Cleaned out to 11,182' Conditioned mud. 90 pcf mud ?~t. 0ber .4, !960__. Ran 2-7/8" tubing with venturi shoe to 11,181'. C~'culated and conditioned mud for 2~ hrs. Landed tubing at 11,135'. Tore out BOPE. Installed and tested Xmas tree. Tested to 3500 psi- okay. October 5, 1960 Starte4 circulating down tubing at 1:50 AM. Pump~ d 40 bbls of water ahead follow~ by 425 bbls of oil. Oil to surface at 5:10 AM. Oil flowed through casing a.~ following rates: 5:45 AM - 5 gals in 57 sec; 6 AM - 5 gals in 54 sec; 6:15 AM - 5 gals in 51 sec$ 6:30 AM - 5 gal in 49 sec. Tubing pressure 50 psi while flowing thru ca?ing. Switched flow to tabing at 6~40 AM, Flowed dead oil at 340 B~ rate untml 10:00 ~. Gassy oil to surface at 10:O0 AM. Turned well to trap at 10:10 AM. 10:20 - 4:30 PM well flowed at average 500 B/D oil, 65~ MCF/D gase Tr~ pressure 15 psi. Tubing pressure 50 psi. Casing vacuum. 32/64" bean. Well flowed by heads from 12:10 until 6:00 PM, Rig realeased 9:00 PM, October 5, 1960 . - · .:. : ~,1 i .,,. ~i .. ~ ': ' . : : ,1~ ~ : :~ COMPLETION REPORT * NEW ~ELL S~JANSON RIVER UNIT 12-1% Section 15, T. 8 N.~ R. 9 W.~ Seward B&M -STANDARD.... OIL" co '."'OF 'C~oRN~KA,' WOI ~i ~ O~ RATOR Page 14. 207' 348,~ 678' 978' 1278' 16o%, 2413 ' 2822' 3395' 4710' 4885' 5412' 5887' 6130' 6459' 6778' 6905' 7015' 7278' 7439' 7527' 7706' 7857' 8228' 845o, 8568' 8720' 9306 ' 9570' 9993 ' 10,172' 10,387' 10,749' 10,900' oO_4o, 0°- 5' oO-10, 0°-15, 0°-30 ' 0o-30' 0° -10 ' 0o.45, 00-20' o°-55, 1°_0, 0%45 ' 0°-45' l°-30' 0o-30' 1°- O' lO_0, 00-45' lo.O, 0o-10, 0o-30' O°-i0 ' 00-45, o°-~5, 1%10' l°-30, l°-15, 0°-45, oO-So, 0o-30' oO-55' 1°-5, 0°-35, PRODUCING DIrPARTM ENT TELEPHONE 47001 J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX 839 · ANCHORAGE · ALASKA October 17, Alaska Otl & Gas Coasemtlo~ Com~.sslo~ 329 ~cend A~nue ~cho~ Dear Slr: Enclose~, herewith, are one sepia copy an~ oae blueline print of the In~uctlon Electric Log Co~osite on the SwansOn River Unit Well No. 12-1~ (12) for your infor- mation ~ files. Very truly yours, S~. OIL COMPANY OF CALIFORNIA Western Operations, Iac. J. T. CROOKER RECEIVED 19 1950 Oil. & (]~s Section Division of b,,'~i,'('~ and Alaska Dept. of Natural }iesourc~ ~. ~o:b ~ ooi ;o~ax j- . ~x~ Operator: Well: STANDARD OIL COMPANY 40F CALIFORNIA. Swanson River Unit # 12-15 Release Date: The Files contain the following material: Office File 1. Permit to drill and location plat ........... 2. Reports of operations and sundry notices ....... 3. Well history ...................... 4. Completion report ................... 5. Directional survey Net necessar~ 6. Electrical log, f~/~J~%~ and sepia 7. Lithology or mud log and sepia ............ 8. Other log Remedial work , ,, 10. 11. 12. 14. 15. Completion Date: Oct. 5, 1960 Nov. 5, 1962 Release File Remarks: Budget Btmw, u No. Approval exi., res 12-31-6o. UNITED STATES LAND OYrlC~' ..~~.~ .... : DEPARTMENT OF THE INTERIOR LE~E ~: ','~'[~ O~ GEOLOGICAL SURVEY u~T ........ ~~. LESSEE'S MONTHLY 'REPORT OF OPERATIONS state ......... A~._..s_.~ ............. County .... Ke..~... ...r..e~.~uXa ~'Zeta ...... __._SWa~°a_~ver ................................... The followin~ is a correct report of operations and pro(h~ctio~ (incl~dinv. drillin~ and producin~ wells) for the month of ......... 0~ber ........... 1:/~ ~9~. ~ver ~ S~~ OIL CO. OF C~~ D~$ CU. FT. OF OAS WELL BARRELS OF OIL (JRAY1TY GASOLINE [ WATER (If (lC drilling. ,iai}th: if ~hut down. eau~; NO. I I'a ...... (In thousands) , dst .... d r~ult of t~t for g~olm. ~ ~EcOYERED nonib s~, stat,9 content of g~) .............................. .......................................... - ~ ~- ~ : I~llea ~. Cle~a out to 11,~2'. ~-~e~o~a 11,070 - 11,1~; 11,~36 - ~,~1'; ~,1¢5 - ~z, 15~', ~th ~ - ~" Jet hokes/~. ~ tubi~ a~ ~,135'~ I~~ed ~ ~est~ ~st~s ~e~ ~~ced '~d ~th oil. _Flo~d ~. 3° g~ty oil a% estl~ted 5~ B/D. 32/6~" ~EC. AND --, ~{ANGE ~or~ I 'JWr. 15 8li 9w Rig releases 10/5/60. i t NOTE.---Thero were ........................................ runs or sales of oil; ................................................ .M cu. ft. of gas sold; ............................................... runs or sales of gasoline dlli'~li,< Lb? 1EODt}I. (Write "no" whet,' a/;plicrble.) NOTE: I~cl)orC on tbis form is required for each cah-~cl~r month, regardless of the st:~tt:.~ of ~q~,~ra~ k)n>,, and mus~ be filed i~ duplicate with thc supervise.ri' },v ti,.e Gth t~f the succeeding month, un!e~.s otherwi,~t~ directed i~v th,, sm:crvi.~or. (January 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42.-R356,5, Approval expires 12-31-60, L,,o omcE ..__A~_.c~_9.ra_. ge ............. U.~T ......... ~~~_ ~Ye~. ...... LESSEE'S MONTHLY REPORT OF OPERATIONS The followin[~ is a correct report of operations and prodgctio~ (incl~di~ff drillin~ and prod~cin~ · ~e~) for ~ mont~ of ........... ~~er ............ , m_~ ....... _~_~_~...~~_ ~ ................................. , S'~~:' OTL 0~ ~0~ ................................ ~9~q~__~~ ........................... Si~ed ......... ::_~~ ............... / , Dri¢led ~ 7/8" boil, 9,599 - 11,~3'o mn ~S, ~ , mere lo~ ~,~3 -~ 3,167', ~e~n~a 7" casi~ az ~, 382'~ I~,~ll.d ~E. ~s~ed ~ i5~ psi j ~ Neuron Cgl~r ~g~ re~o~ted ~ · ~s~e~ ia~~ 10~2~ , 10,210'~ ~lo~d oi~ ~r at esti~ 12~ B/D~ S~ueezed pe~ 10,~0 -. 10,210' ~ 100 sacks c~nt wit~ pe~ent relier set at ~,!82'o ~ ~0 ~st om pe~s at 11,0~3~ ~. ~covere~ 950'~ oil ~ oily ~s ~t ~d. · ~0. S~ueezed pe~s ~t~ 11,0~3' ~th 55 sa~m ce~nt. ~ ~0 ~st 'oa ~,~'~ ~11~136 - ~~', ~,1~ ~ ~,162'~. ~ tubi~ at ~,1~2'. cC: RECEIVED OCT 6 1960 Oil & Gas Section Division of Mines and Minerals Alaska Dept. of Natural Resource~ NOTE.--There were ...................................... runs or sales of oil; ...............................................[VI cu. ft. of gas sold; ............................................. runs or sales o£ gasoline during the month. (Write "n,¢' where applicable.) NoTz.--Report on this form is required for each calendar ~nonth, regardless of the status of operations, and mus~ be /~;ed ir duplicate with the supervisor by the 6th of the succeeding mon~h, unless otherwise directed by the supervisor. Form 9-329 .;6--25706-8 u.S. ¢-o¥£RNM£NT PalNTINa 0PFICr (Jammry 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY B~tdgc[ Bureau No, · ApprovM cxplrvs LA.o omc~ .~.~::tcJlo/*'a~",'e ............ LESSEE'S MONTHLY REPORT OF 'OPERATIONS State .... A.],&$~ ................. Co~ty _[S.~J~.~.~]~_I~_~t~__a. .... ~ield .__~~a._~e2 The followi~E is a correct report of operations a~d prod~ctio~ (incI~din~ drilli~ a~d prod~ci~E wells) for the mo~th o~ .......... AQ~i~% ................... ,~__, ......... ~0n..~er U~t 15 8~ 9~ ~s~ed tatem~l 6 - 3~25'. Repmsen~ttve flow m~ 1" ~, ~ D~klea ~ 7/8" hole fm~ 3395 - ~9~'o 0o~6 ~" bole from ; ~ ~025'~ ~s~6 in~e~ 5~ - ~025'. ~sen~[lve flow ~e 8? hole f~m ~', ~o 5~81'. Tes%ed ia%e~ 5566' ~ R~sen~%&~ flow ~te i" su~ace be~ ~0 ~F/D. D~ed 9 7/8" ~ze ~mm 3~8z' %¢ ~: u.s[e.s, -~. s. s~s~r' (3) , / W~ C, Bi sh~ 0~6 Oil Co. - ~oxge U~$n Oil Co. - C. ~. S~th / ~l~: ~lo~tiom P~duc~ I No,cs.--There were ........................................ runs or sales cf oil; ........ _-_ ..................................... M cu. ft. of gas so]d; .............................................. runs or s~les of gasoline during the mon[.h. (WrH:e "no" where No~.~Re[)ort on this ~orm is required for each'c-flcm]~u, nto~'l[h, regardless o~ Ibc slat, m: of ~pe:':i.ti~,ns, :~td must be filed in duplicate with the supervi:sor by thc Otb of the ~uccv~ ~.~m~ ~o:.~t!, ~in]cs.q odierwise dh'ec~-d by Ibc For~ 9-329 (January 1950) lc *'.~:,7,;¢-~; Budget Bureau No. 42-R356.5. Approval expires UNITED STATES Oil & Gas Sec~ .omc~ o ~.~. DEPARTMENT OF THE ~)~rRtO~in~s an .a~it~l~--D2~h~ -----_-~ ............ GEOLOGICAL SUI~I/IS~ Dept. o[ Haturakr~~~OJ5.-~ .............. LESSEE'S MONTHLY REPORT OF OPERATIONS State ....i~.a~k~', .................. County .i.~f:r-!~-:~---~§~=~?-K~---a. .....Field ~ ~ ye ~e followinE is a correct report of operations and prod~otio~ (i~cl~i~E d~lli~5 a~ prod~ci~E ~~,~ '~:n. ~n '_ .............. . ...... .~ .... ~ ..... co~. ~~ ~a~~._.n~ .......... JEe~'s address __3:,_.~.__E~x--7-~23 .............................. ...... ~ ~--~---¥~,?;~.:~--- ~ ....... .............. ............................. ~.~_~e,._~a~ ............................ _ - ~ ff~+ ~ .... erint~nde~t-i~ s~ ~o~ ................... ~_7.=C_a~l ................................................ Zie=~' s ~it?~*~'~*--~-~: .......... ~--~--:--': ..... '=- ~EC. AND ~4or ~/ .... C ~'~ ............. ::...;: · ...-;,;...': .-.: ..; .~::., i ic);ff ie ld , i~4isbe NoTE.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of .gas sold; ........ runs or sales of gasoline during %he month. (Write "~o" where applic~ble.) ..A ..................... NoTz.---Report on this form is required for each calen ,ar month, regardless 0f the 'status of operations, and must be filed in duplicate with the su~rvisor by lhe 6th of %he succeeding mon~h, unless otherwise directed, by the supervisor. 16--25766-5 U, S. O0~N~ENT ~I~TI~ OFFIC~ Form (January { I',.b. I'151) UNI'TED STATES DEPARTMENT OF 'THE INTERIOR GEOLOGICAL. SURVEY Anchorage . o284o6 .'.I nl t · SUNDRY NOTICES AND REPORTS ON WELLS NOTIC£ OF' IN'TEN] ION TO DRILl. NOFICE OF iN t£NTION TO CHANG[. PLANS NOIICE' OF iNTENTION TO }['_S.T y,,~I'I:.N SHiiT-(,Fr NOTICE OF INTENTION ~O RI! DPILI. u!"e iiE;..',iR W£LL NOTICE: OF IN]ENiI,7;N 'TO Sfh)O'i OP /.CIDIZI. NOTICE OF INTENflON TO PIiL[ or? At 5[ q C:~.'~ING . NOTICE OF INTENTION TO AbqNDON ','~E'Lt SUBSEQUEN} RI'.POP, T L'F WATER SHUT ©i' 5UBS~QUEN" f'EPORT ,'.F AL'FER~NG CAS,:;(~ huL:,i 3uL',IF REPOR'~ OI Ffh.DRll t_l~,G ,.".i; F'F,'AiR SUPPt. EM~NT,~RY WELL HISTORY _ ~y 19 mpp ,roximately ' Nj Well No. !2-15 is !c,cal,',!/ 2144)0 ft. fron~ EE lin,' and ([~ S.t'¢ :,', i c N,,.¢, ',"[ 'a p.)' ( _ 8w~$on River Kens& ?eni~sula LFI, 1<1) {~ h,,i .... . , ' '~i~,l:', ,:,:,,h) KB The elevation of tt~c~ al)ove sea level is 335 825 ft..from Seward t :~t ,,~, ii:m) lo 60 ft. appz~ximately. sec 15 . 1. Drill to 3000', run somle log, cement 13 3/8" in two stages. 2. Drill hole For T" casing to !1~ 510'. Reduce hole and formation test selected intervals mbove 5600 '. 3. Run electric log. Based., on, correlation consider drilling ahead to penetrate "I" poi~,~t~ 5. Run final series of logs. ............ 6. Cement 7" casing througj~ productive sand in two stages.' 7. Obtain WS0' s as required. 8. Selectively jet perforate productive sands. 9- R'um 2 1/2" tubing and. complete. Oil & Gas Sccdo'o Company. S~~ 0il Comp~ of Califo~, Weste~ ~e~tio~ Inc. , Address. P. O. BOx 7'839 Anchorage, Alaska Approved.--TK~h-~ ............. - ........ ~'"";' ' ' 'Z ....'- ~~---- ...... '2~;" ! "' D. D. Bruce, Petroleum Geologist Division o~ Mines and Minerals AlaCm Dept. o{ Natural Re~u~ ~is~ct Superintendent 34. 2~ Approved~ ........ D. D. Bruce, Petroleum C~ologlst Division of Mines and Minerals Alhska Dept. o£ Na~al ltk~oum~ RECEIVE[ ' 0il & G:~s Section Division of Mines and Mineral~ Standard Oil. Co. of California Swanson River Unit No o 12-15 (12) Permit No. 22 Issued 4-25-60 Ele: Spud: IP: Perf: Plugs: Csg: 2285' !~NL & 1095' FWL, Sec 15, TSN,R9W, SB&M 3~4'KB, 319' grd Contr: Coastal Drlg Co. 7-24-60 Cmpltd: POW 10-5-60 TD 11383' 500 B/D, 28.a°API, GOR 130/1, %" ck, TP 50 psig 4-~" @ 11070!-11132', 11136'-11141', 11146'-11162' 11383' -11182' 22" @ 30' 13-3/8" @ 3167' w/600 sx amd shoe & 1050 sx thru collar @ 1508' 7" @ 11382' w/?O0 sx amd shoe & 800 sx thru col. @ 8007' 2-7/8" tbg hung @ 11181' APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO Dt{ILI,~] DEEPEN' [] PLUG BACK [] .W~kME OF COMPANY OR OPERATOR Ad ~ress City DESCRIPTION OF XVELL AND LEASE DATE State Name of lease [ Well number Elevation (ground) Well location (~ive footage from section lines) Section--township--range or block & survey Field & reservoir (If wildcat, so state) County Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location to property or lease line: Distance from proposed location to nearest drilling. completed or applied--for well on the same lease: feet Proposed del)th: 1~, ~ID feet Rot~try or cable tools Approx. date work will start Number of acres in lease: ?Jumber of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more Name Address wells drilled, from whom purchased: Status of bond Remarks: (If this is s ................. :¢epen or plug back, briefly describe work to be done, giving present producing' ' , · new producing zone) } AY _t CERTIFICATE: I, the undersigned, state that I am th~-,~* of the (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my s,.~?~vi, sioq and direction and that the facts stated therein are trye, ~.9r4c~ and complete to ....'"-'J~-~ t,i "?;,'-'7 ............. the best of my ~owledge. ,~"}7 ' Z, ,U;. ~:"~c¢, Petroleum Ge01o~ Permit Number: ~ :);..i~:m 0f Mines and Minerai~ ~), D. Bruce, Petroleum G~lo~st Notice: Bef. ':" ' ' 1;"' :~t! *' ' ' ' ' ' Naa~t..'t J'~ t have given ail .... ,,i ~,,~ .... ' .... correspond- ence,w~q '[n~ ~ masza ~ep. $l°~ral B~our¢es See Instruction on Reverse Side of Form Application to Drill, Deepen or Plug Back Form. No. P-1 Authorized by Order No. 1 Effective October 1, 1958