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Home My WebLink About175-055STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED NOV 19 2018 WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑Q Suspended E] 1b. Well Class: z0a 025.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: _ 0 Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 9/6/2018 14. Permit to Drill Number,/ Sundry: 175-055 / 318-289 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 12/19/1975 15. API Number: 50-133-20262-01-00 4a. Location of Well (Governmental Section): Surface: 1267' FNL & 1465' FWL of Sec. 34, T7, R1 OW, SM Top of Productive Interval: WA Total Depth: 654' FSL & 2099' FEL of Sec. 27, T7, R10W, SM 8. Date TD Reached: 1/17/1976 16. Well Name and Number: Beaver Creek Unit (BCU) 05RD' 9. Ref Elevations: KB: 178.4' GL:160.4' BF:160.4' 17. Field / Pool(s): Beaver Creek / Beaver Creek Oil Pool 10. Plug Back Depth MD/TVD: 14,238' MD / 13,778' TVD 18. Property Designation: FEDA028083 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 317318.8 y- 2433983.0 Zone- 4 TPI: x- N/A y- N/A Zone- 4 Total Depth: x- 319054.3 y- 2435883.1 Zone- 4 11. Total Depth MD/TVD: 15,655' MD / 15,061' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes LJ (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 14,238' MD / 13,778' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20" 94# H-40 Surface 432' Surface 432' 26" 1000 sx 13-3/8" 61# K-55 Surface 3,511' Surface 3,511' 17-1/2" 2500 sx 9-5/8" 47# P-110 Surface 11,698' Surface 11,465' 12-1/4" 3120 sx 7" 32# P-110 11,531' 14,238' 11,322' 13,778' 8-1/2" 1010 sx 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd):/,� ' {pN fT1ATE q/ /I _0 V2 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD/TVD) NIA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVVERIFIEDL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Date of Test: N/A Hours Tested: Production for Test Period Oil -Bbl: Gas-MCF:Water-Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017A 9 Ep ON PAGE 2 RDDMS OV ^ Cv 2 1 2618 Submit ORIGINIAL only ��Izof/' /q =srq 6 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No E] If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation at total depth: Tyonek 31. List of Attachments: P&A Daily Reports, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdjr1 er hilcor .com Authorizedpp Contact Phone: 777-8389 — ` ) Signature: Date: /1,/?- U INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only n Hileorn Alaska, LLC KB Elev.: 178.4'/ BF/GL Elev.: 160.4' TD =15,655' (MD) / TD=15,061'(TVD) PBTD =14,238' (MD) / PBTD = 13,779MO) SCHEMATIC Beaver Creel Unit Well: BCU 05RD Abandoned: 9/6/18 PTD: 175-055 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor N/A/N/A/N/A N/A Surface 432' 13-3/8" Surface 61/K-55/ 12.415 Surface 3,511' 9-5/8" Production 47/P110/ 8.681 Surface 11,698' 7" Liner 32/P-110/ 6.184 11,531' 14,238' GENERAL WELL INFO liAPI: 50-133-20262-01-00 Initial Completion -10/1/1983 Revised By: GD 11/19/2018 Hilcorp Energy Company Composite Report Well Name: BCU-05RD2 Field: Beaver Creek Unit County/State: Kenai, Alaska i (LAT/LONG): evation (RKB): 18 API #: 50-133-20262-02-00 Spud Date: Job Name: 1810833P BCU-05RD2 PreDrill Contractor AFE #: AFE $: Ops Summary Sign in. More to location. PTW,JSA. and SIMOPS with Cole's creew. Spot equipment and rig up lubricator. PT to 250 psi low and 4000 psi high. TP - 50 psi RIH 8/3/2018 w/CCL-GR, 2.58" gauge ring and tie into pert log dated 2-18. Ran down hole to 15,250'. Logged back up to 14,390' . Looks like FL at 5000' coming out of hole. Had no trouble going in or coming out. Sent log to town.,RIH w/CCL-GR, 1.81"OD Spiral plug and tie into GR log. Had to run in hole at 50' per min according Plug setting instructions. Ran correlation log. Set plug at 14,990' due to collar at 15,000'. Lost 150' when plug set. Waited 15 min and picked up 30' and went back down and lightly tagged plug. POOH. Setting tool look good.,RIH w/2 -1/2X20' dump bailer filled with beads down to 14,990'. Dump 4' of beads on top of plug. POOH. Good dump.,Mix and fill 2-1/2'x30' dump bailer with 17 lb cement. Run in hole to top of beads at 14.986'. Dump bail 6.3 gals (approx. 91) on top of beads. POOH. Good dump.,Rig down lubricator and secure well. Break down bailers and tools to clean up for tomorrow morning. Will continue with dump bailing cement n the morn no 8/4/2018 PTW. Hold safety meeting and SIMPOS meeting with TI#1,Ru PESI E -line unit. Start Mixing cementfor dump bail run. Load 2.5" x30' bailer. RIH. stack weight at 49. Pooh and check bailer. Glass broke and cement has been dropped. Called town to discuss. Start filling hole with garden hose. Dump bailer is full of paraffin. Load water and RIh . Work bailer up and down around 46 to dilute cement.,Load sugar and diesel mix in dump bailer. RIH and work mixture through cement . POOH. RIH with 2.5" bailer. Looks like wellbore is clear. Pass 6500' No weight bobbles. POOH to surface.,Mix up cement and install in 2.5" Dump bailer x 30' RIH and tag at 14420'. POOH. Glass broke. lost cement. Load sugar and water in 2.5" dump bailer x 30'. RIh and tag same depth 14420' Work tools up and down to attempt to spread sugar and dilute cement. Called out slick line for the am. SDFN. 8/5/2018 PTW, JSA at Beaver Creek office with Slick line crew.,On location spot equipment. Begin rigging up. PT 500 psi low, 2500 psi high. Test good. Rlh w/ 1.75" tool string w/ 15' WB (rigid no KJ) w/ 2.5" GR to 14,445' KB - beat down 3x gain 1'. End at 14.446' POOH.,RIH w/ 2.75" LIB to 14,446' OOH LIB does not show any definitive marks.,RIH w/ KJ w/ 2"x 4' Drive down bailer wl mule shoe flapper bottom to 14,445 W/T to 14,460' OOH with full bailer. Ball of detination wire and three blasting caps along with chunks of set up cement.,RIH with same to 14,460' wor to 1'4,464' OOH full bailer. Loose dry cement (sand like),RIH with 2.5" x 4' Drive down bailer to 14,462' to 14,463'. OOh bailer empty. Bottom of bailer plugged of with unset cement.,RIH with 2.5" fluted centralizer with 1.5" x 5' stem with 10" long chisel bottom spear to 14,463' work to 14, 464'.,Rlh with 2" x 4' drive down bailer to 14,464' work to 14,466'. OOH ailer has about 114 cup of cement rocks. Smaller eraser size pebbles.,Lay down lubricator and secure well. Departfleld. 8/7/2018 Ptw, safety meeting,Lay 100x100 pit liner. Spot return tank. Build containment berm. Rig up hot oil pump truck to the iA. Rig up return line fro, tubing to return tank. Load hot oil truck and run waterline from water well to truck.,Online with fluid down 7"x3.5" annulus. Heating to 178'F . GLM pulled at 13,681'. iA volume to GLM 333 Shia. Tubing volume to GLM 118 Bbls. 451 Bbls system volume. Pumped 500 Bbls at 165-175'F and never saw any returns. 8/8/2018 PTW, JSA,Pumping down IA at 1.8 bbls/min at 175"F. No returns Pressure climbing from 100 to 320 psi. Looks like we are lifting a column of fluid. Returns at surface after 227 bbis pumped (previous day 500 bbis pumped) 727 bbls to get returns to surface. Returns are crude oil for the first 45 bbls. Pockets of gas surges attank. Changed out 2" hose from the water well house to the hot oil truck.,Continue circulating. Pumping 2 bbls/mm 437 psi. Fluid temp in @ 171"F. Returns at 130'F. Return pressure increasing at 405 bbis pumped to 156`F. Retums brown. No signs of solids or paraffin. Increase pump rate when tank gets full to 3 bbis/min. Drop rate to 1.8 bbls/min when hot oil tank level drops. 926 bbls pumped after returns made it to surface. Cruz vac truck being held up at G&I.,Return tank full. Shutdown. Close in tubing and IA wellhead valves. Shut in water well valves. Secure location. Slick line scheduled for the AM to run brushes and tag top of cement. We will circulate well during scraper runs and do 3 tubing volume bottoms up post slick line work. 8/9/2018 Pollard SL on location. PTW.,Start rigging up. Crews forgot to bring Brushes. Make up 2.75" Gauge ring.; RIH tag at 14,454'. At surface,make up Slick line brush 2.8"-2.9" OD of bristles. RIh and make three passes to 5000'. Popoff. One small weight bobble at 180'. No indications of paraffin. Install night cap.,Online pumping down IA. Heat fluid to 175`F 136 bbis pumped. Return fluid temperature was 155`F. Shut down pumping. Cruz vac truck on location hauling returns.,RIH with Slick line brushes to clean tubing. RIh to 14,445'twice. Make 3 more trips to 5000'. Tubing looks clean. Rig down PESI. Start pumping down IA. 175"F @,Pump 250 total bbls. returns look clean. Pressure test wellbore to 2500 for 30 minutes. Pressure slowly dropping. Bump pressure backup. Starting to flat line. While closed in and recording start rigging down.,Bleed off Pressure test. noticed Natural gas coming back. Hada gas bubble in IA. Rig down hot oil truck. Finish rigging down pit liner, and return tank. 8/15/2018 Doyon released at 06:00, no rig crew on location. Peak rig support palletizing tools and equipment for shipment. Pason Rep on location at 08:00 and rigging down, Total Safety on location at 09:00 and rigging down. Shipped 400 bbl upright to BCU, loaded and shipped service shacks and Weatherford equipment. Peak support crew and Expediter traveled to BCU and layed steel plates over cellars, removed discharge line off,poorboy degasser, removed cuttings slide and victrolic plumbing from centrifuge, spotted crane and removed centrifuge from stand, loaded centrifuge, feed pump and control panel for shipping, tore out gen three, loaded same and shipped to BCU. All American crews and management met at Swanson River Field office for field orientation given by John Coston, then �`f�t1�l AJ V took both crews to rig for walkthrough/orientation.,Day crew stayed at rig, night crew checked in to housing. Removed bales, Kelly hose and service loop from topcinve. Mechanic found and replaced broken bolts on floor motor driveline. Started derrick inspection for scope down. Secured items in pits for road travel. Prepared choke house for road travel.,Finished up derrick inspection„Unpin top drive from torque tube and traveling blocks , set in cradle . Lower down from rig G floor. Nipple down low pressure mud lines between pits �j 1,2 &3 Remove mud pump suction lines. Disconnect air and water lines between modules. R/D torque tube including upper section. Scope down poor boy Degasser. Peak crew and expediter Layed felt, liner and matting boards on BC Iocation.,Continue RD and move out rig to Beaver creek. Clear rig floor UD rotary tongs, x overs elevators and subs. Flush out HP lines in pump room. Install shipping pins in iron roughneck. Palletizing Subs, load on trailers at Taylor pad. Pin up shaker chutes. Pin upper section of torque and prep for removal. 8/16/2018 RD Handy Berm, remove stairs from shaker deck, tear out degasser skid, Peak on location at 07:00. Tore out change shack and pump 2. RU bridal lines and scoped down mast while prep pump 1 and pits for move. Tore out boiler skid, folded up pit 1 landings, tore out pump 2, lowered vac degasser, lowered roof tops on pits and tore out pit 3. Spool drill off drum and hung in derrick. Folded back beaver slide and tore out pits 2,and 1. Tore out catwalk/choke house. Spotted crane, transferred BOP stack from trollies to crane and set same in shipping carriage. Lowered carriage and moved off location. Tore out gen 1-2 skid. Prepped and layed mast over. Lowered doghouse into water tank, picked iron roughneck off rig floor. Tore out water tank/doghouse. Lowered windwalls on derrick house, RU on derrick and set on trailer. Rig Super and Topdrive,Eng!near inspected derrick for welding project while setting drill line spool on derrick trailer. Shipped derrick to D&D welding. Picked carrier off sub, picked sub off pony walls.,Secured sub on trailer, sent small crane to D&D, sent big crane to Beaver Creek. Load out and ship pony subs, Test pump and HPU units. move and stack matting boards to side of location. Remove liner and felt. Clear, clean location. Load out all pallets with subs, bails and misc equipment. Flush out cellar and clean up. 8/17/2018 Rig crew traveled from Swanson River to Beaver Creek, Peak on location at 06:30. Set pony walls, set sub base, centered up over well, set carner.,Waiting on arrival of derrick from D&D welding, rig team held pre-spud meeting at BCU office with reservoir Engineer and Geologist. Derrick on Iocation.,Spot cranes, RU and set derrick on carrier and pinned lift rams, raise windwalls on derrick board, set pits 1-2-3, raise pit roof tops, hang shaker slides and raise vac degasser, set dog house and raise same, set iron roughneck on floor, pull upper Tesco torque tube with crane, Simi prep rig office trailers at Swanson River field for travel to Beaver Creek field, start down highway at 16:00 hrs, Set both pump skids„drop shaker landings, set centrifuge with crane, set boiler skid, inspect derrick prior to standing, installed dogbone on crown section to hang new torque tube„Stood mast with both rig crews. Set poorboy degasser skid, set office trailers and tied in to gen set, RU comm's, set VFD skid, HPU/glycol skid, transfer switch, C32 skid and installed muffler. Strung electrical cords, installed lights on roof tops, start work on pump #2 for pod changes, install dognut on drawworks drum, prep to slip drill line, clean and organize throughout the rig. 8/18/2018 Layed felt and liner for catwalk, slipped extra drill line on drum, scoped derrick up, brought in the GO gen set for topdrive and spotted same, set catwalk with cranes, flew becket to rig floor and pinned to blocks, pinned service loop hanger on board frame, installed Handy Berm, Pason Rep set up doghouse wireless transmitter to Push shack, cont dismantling pump 2 fluid end for pod changes„flew beam clamp to backside of derrick for lower torque tube "T” bar and bolted on same. Broke down torque rail sections while layed out on catwalk. Started floor motor to start raising blocks, starter solenoid stuck, starter damaged, shut down motor. Notified Rig Super.,Hoisted service loop cables out of storage box with crane and coiled up in hose baskets, while waking on new starter to be delivered from warehouse. Flew all 3 used pump pods out with crane.,Notified of small hydraulic oil spill on BCU Pad 1A (staging pad) by rig support (Peak). Documented drum, pallet, gravel and notified EH&S Specialist John Coslon. Bagged up contaminated gravel. Received new floor motor starter and installed same. Flew 3 new pods into pump 2 skid. Installed stairs on shaker deck, installed vent line on poorboy degasser and raised vessel, installed discharge line on poorboyto shakers-set centrifuge feed pump and control panel, attempted to insert pin in lower becket eye, eye slightly mis-aligned, dressed becket eye with Flapper disc as per Engineer and Rig Super, PJSM with NOV Rep and PU assemble torque rail, top rail section hanging off carriage and slings, with blocks nearly crowned out we were about 1' short of reaching dogbone to hang off crown. NOV Rep timed out at 02:00, set rail on rig floor.,Cont installing pump pods on pump 2, cont plugging in electric cords, install mud manifold on rig floor. 8/19/2018 Cont assemble pump #2, Spot crane over crown, RU on torque rail, PU and latched onto dogbone hanging off crown, RD crane. S/O on blocks to lower and remove carriage from torque rail. Had to hammer carriage down over new/un-used section of rail. LD carriage. At this point floor motor died. No fuel. Trouble shot for an hour and finally found fuel line on gen skid roof was not plugged in to system.,Staged topdrive and lower rail section on rig floor with crane. Pinned topdrive to becket. Folded up racking fingers at board, PU topdrive with lower rail and engaged upper rail section. Set all 4 service shacks, strung cords and plugged in. Continue to assemble pump #2. Spot both cranes and start stringing out service loop lines for install. Hammer up 3 sections 2” hardline to water well.,Crane up and pin both service loop sections at the board, off driller side of the derrick. Continue to dress out # 2 mud pumps pods with liners,ewabs and pump rods. Clean out rig water tank and begin taking on water from water well,Complete dressing out mud pump # 2 with liners, valves, seats,swabs and piston rods. Nipple up HP shock hose from pumps to sub. Make up Kelly hose to top drive. Clean up pump room. repair agitator in pit#6 M/U rig water lines and circ. back to water tank 8/20/2018 Installed secondary retention on service loop bracket, in derrick. Strung main power loop and electrician plugged in same. Completed assembly of pump #2 fluid end and cleaned pump room. Ran power and control lines for centrifuge. Detroit Diesel Tech did top job on floor motor, pump motors and gen motors. Hung hydraulic/glycol service loop in derrick to topdrive. Hung the auxiliary service loop saddle in derrick.,String out auxiliary service loops (3) in derrick. Installed retaining plates in derrick. Replaced driveline bolts on floor motor transmission. Installed pit equalizer winch pulleys. Pason Rep terminated torque and RPM wiring into drillers top drive control panel. Sent BLM 48 hr notice of initial BOP test at 09:20.,Confinue rig up of IDS-350 Top Drive. Plug in service loop. Re hang 1 service loop to align it with others. Clean out suction and discharge screens on mud pumps. Install pulleys on risers in mud pits .Re-route electrical lines to prevent trip hazards. Install pressure gauge on IA valve to monitor annulus.,lnstall safety wires on top drive service loop clamp. Connect control lines to top drive. Mount rubber gaskets on shaker beds. Load pit 9 with produced water start testing low pressure lines and valves In mud pits.lnstall kelly hose to Top Drive. M/U HP hose from kill line to top of wellhead. Dressed out shakers with 200 screens 8/21/2018 PU topdrive enough to engage hang off dogs, SIO and hung topdrive on rail. RU winches and hung blocks off. Removed brake bands on draw-works. Wired up service loop retainer bolts. Powered up topdrive for function test. Lot's of alarms, started troubleshooting. Dismantled remaining tesco torque tube in yard for shipping, moved fluid around in pits testing pumps and valves. Test ran #2 pump through bleeder.,lnstalled new brake bands in draw-works, PU on topdrive and removed hang off dogs, S/O topdrive to rig floor and cont troubleshooting. Changed bad rubbers on suction valves in pits. Peak cleaned out mousehole sleeve previously set in cellar box. Staged BOP carriage near cellar entrance and stood same. RU 2” HP hose from annulus valve to catwalk choke line, RU shock hose from catwalk choke manifold line to poorboy degasser,RU Geronimo line. Installed last of pulley's on pit riser winch cables. Removed choke HCR on BOP stack for reconfigure. Replaced bad 6" butterfly valve in pits. Test ran vacuum degasser in pit #4. Spotted Swaco MPD choke skid.,'Topdrive issues: Had loose connection on service loop, tightened and fixed. Overcurrent while trying to rotate was a bad RTAC card for encoder. Found we are missing the clamp positioning safety bolt and cotter pin, for holding grabber in place during MU of IBOP, saver sub etc.,continue to troubleshoot top drive. Change out 2 butterfly valves in #2 hopper room. Adjust and tighten up suction valves in pits 1,2,3,4,5,6, Tie back all the service lines on back of kelly hose, Close top and front hatches on Top Drive installation complete ( missing on pin on pipe handler grabber) Make up IBOP torque clamp to 185ft/Ibs .,Check pulsation dampers on # 1 MP to 9DOpsi #2MP to 800psi Continue to repair suction valves on mud pumps All repairs complete on mud pits. Change out shaker screens on #3 shaker to 140.,Line up on kill line to wellhead with Returns to Poor Boy degaser for well killing operations . Open up well with 10pal on the annulus 0 on the tubing. Begin pumping at 31bbl min 220psi Increase to 4.2bbls min 550psi 5900stks in to kill operations at 0600hrs. Note: rig accepted at 04:30hrs 8/22/18 8/22/2018 Cont. Circulating Surface to surface at 4 bpm-564 psi, down tubing taking returns through annulus, choke manfold and poor boy degasser. Burned in new brake pads on draw-works while circ and worked top drive up/down through derrick to verify service loops and kelly hose are free and clear. Shut down pum.p,Monitor well 15 minutes, seeing slight flow at shakers. Lined up tubing on bleeder and have slight flow. Shut in choke and tubing, no pressure build. Removed circ hose from tree cap and opened tubing to cellar box. Well dead static after 1 minute, no flow at shakers. RD circ Iines.,Wellhead Rep installed BPV in hanger, then checked ports for hanger void pressure, no pressure, secured ports.,Removed safety valve from tree, removed tree from wellhead and hung on cellar trolly's. Folded beaver slide back. Brought crane in from staging pad and spot at cellar. Removed tree from cellar. R/U on BOP stack, broke out single gate, turned stack and MU single gate. Broke out double gate, turned stack and MU double gate. Removed stack from carriage and transferred to cellar holly's. Removed 16" spacer spool from,single gate, installed stack on wellhead. Removed plumbing from annulus valve in cellar box. Simops: Set liner and mats for tank farm. Set 4 upright tanks and pump in place, built berm. Welders installed 2" collar on flow line for bleeder, repaired handrail on mezzanine deck (cut out for MPD valves) built plug for 6" hammer seal in possum belly, shaker #2.,Opened up lower pipe ram doors to obtain measurement for testjoint. Only 1/2" from top of hanger neck to bottom of rams. (Received variance from AOGCC Rep Guy Schwartz and BLM Amanda Eagle on testing upper rams only) Installed manual choke valve, blocks & HCR's, choke and kill armored lines to mud cross. Torqued up stack to wellhead. PIU rotating head assembly and nipple up to annular preventor,lnstalled koomy control lines to BOP stack. M/U flow nipple to rotating head and installed flow line. Hammered up MPD head. C/O lower pipe rams to 3 1/2". Pulled BPV and set two way check in hanger. Changed upper pipe rams to 2 718" x 5" variable rams. Installed 6" globe valve on MPD head. N/U flow line. 8123/2018 Cont NU flowline, continue to hammer up bolts on rotating head. Hang all catwalk lines on hangers, install stopper on trolley beam. (removed to install flowline).,Rig up test equipment. Test joint (3.5"), cross overs, FOSV, Dart valve, Fill stack with fresh water. Shell test 4500psi. UPR's bad door seal. Replace same. Refill stack with water. Attempt to pressure up to 1500 psi. Test pump regulator failed. Retrieve test pump from Production. Switch out pumps. Start shell test. Pressure up to 1500 psi, cycle all choke manifold valves. On high pressure test to 4500 TWC began Ieaking.,Tighten up lock downs. Total Safety tested and calibrated all gas alarms and lights.,Tighten up lock downs on TWC. Good shell test to 4500 psi for 10 mins. Begin BOPE test. State Inspector Jeff Jones waived witness via email ( 8.23.18112:15 pm.) 2 BLM Inspectors on location to witness. Test #1:Annular, 250 psi low, 2500 psi high, 10 mins each. Good. Test #2: UPR's Dart valve, Mezzanine kill line valve, (Dart failed), test against FOSV. 250 psi low good, failed on high test. leaking TWC.,Rig down test joint, tighten up leaking gland nut on hanger, Dart valve had lost O ring. Replace O ri ng.,Retest #2: UPR's , Dart valve, Mezzanine kill line valve, CM 1,2,3,11. 250 psi low, 4500 psi high. Good test. Crew change.,Continue testing BOPS: 250/4500 10 mins hold. test HCR and kill line valves choke valve 7,9 and 13. attempt to test upper pipe rams flange on lower pipe rams leaking hammer up and retest, Test choke manifold valve 13, Test Choke HCR Valve test failed grease and retest. Perform accumulator drew down test obtained 200psi in 22 sec full system recovery in 91 sec. all components passed. R/D test joint.,Test IBOP and manual TIW all components passed. Pul, RID testjoint . Install 4" orbit valve and S-flange 8124/2018 Remove TWC. Complete install of new aluminum drip pan around trip nipple. Install fill up line from trip tank. Mechanic rebuild hot tap tubing punch (Hilcorp owned.) Install U bolts for link tilt for top drive. Install bail guide.,Service hands arrive on location. Weatherford, Pollard, Baker, Wellhead hand. Rig up Pollard sheave on Driller side in derrick, and over top of the dog house for pulling control line. Rig up Weatherford power pack, tongs, pick up 125 ton elevators, air slips. Off load 2ISO's of OBM into pits #9, #10. Rig up tank farm valves and 4" transfer lines. Remove lock down screw Pull hanger unseat Nr/ 00k aria put m .a4k no movement. Work string 1 O Xs. Attempt to pump, no flow, bleed off from 750 psi. Pressure up to 900 psi, gain returns. 4 BPM, 480 PSI. Consult with Drilling Manager to pull to 100%. Action agreed upon. Pull up to 190k, began to get hung up in stack. Drain stack. Snap ring that held'junk ring', (pressure ring), had popped free on one of the up ward movements.,Snap ring and pressure plate were trapped directly below the MPD riser. Land hanger. lay down landing joint. Close blinds. Nipple down aluminum drip pan. Attached safety wires to both the mangled snap ring and the trapped pressure plate. Knocked the snap ring down, removed ring. Nipple drip pan back up.,Made landing joint back up to hanger. Unseat @ 100k. Work string to try and free snap latch landed @ 14657' X� \{ MO.,Attempt free up snap latch free , pulling up to 193k 4X times no movement . Decision made to sever pipe any movement was due to pipe stretch Move Center stack, with chain bonders. Unload 228 bbl of OBM to mud pits and 228bbls of LVT in up right tank farm. 577 BBLS OBM on location. 64 BBLS of LVT.,Set 3.1/2 tubing with 45K compression while B/O of top drive & lay down tubing hanger. make up to landing joint and work pipe.,PJSM: Rig up pollard e- line sheaves and line wiper and safety valve . Make up 7' of weight bars, CCL tool and 2.5 jet cutter and stab into tubing string. Run in hole with 2 .5 Jet Cutter on E-Line to 14451.5' Pick up 50k in tension park jet cutter at 14429'WLM . Fire cutter charge and move down with CCL tool to confirm cut. POOH with E- line F- 14429' and lay down E-Iine tools. R/D pollard and move out.,Make up X-overs to top drive and circulate B!U @ 14,429' 338 gpm 1271psi 139spm No gas on B/U small traces of oil.,PJSM: Rig up weatherford tools POOH f-14429' 13,960' laying down 3 1/2 tubing with control ,lines cutting off bands & spooling control line down to pollard reel. Up wt 110k. total of 27joints L/ D with recovery of 82 bands. 812512018 PJSM: Weatherford/Pollard. Laying down 9.3# EUE 3.5" L-80 completion string from 13960' MD to 10384' MD. Retrieved 2 GLM's, Reeling up the 1/4" control line. Proper hole fill. SIMOPS: Take on 3500 gallons diesel, Mechanic working on Cat #2 designated for TDS 350. Bad fan bearing. Conditioning the OBM, weighting up to 9.5 ppg.,Continue to lay down 9.3# EUE 3.5" L-80 completion string from 10384' MD to 7428' MD. Retrieved GLM's, Reeling up the 1/4" control line. Proper hole fill.,Cont. to lay down 9.3 EUE 3.5 L-80 completion string F- 7428' - 3623' Counting bands and spooling up the control line on to pollard reel. Conducted BOP drill, all hands on station in 22sec. received 124bbls of LVT and blended into mud pits, continue mixing mud to build volume and maintain mud weight at 9.5 ppg, correct hole fill.,Continue to lay down 9.3 EUE 3.5 L-80 completion string F- 3623' - 0 Recovered 8 GLM. Cut was made 12' in on joint #457 leaving 4.5 joints in hole with Packer including X nipple Chemical injection mandrel and Mule shoe.. Hole fill as caculated Top of tubing cut off left in hole 14,440',Rig down weatherford tubing handling tools and pollard control line sheave and spooler. 8/26/2018 Prejob: Continue to rig down Pollard Spoolers, sheave to derrick, and Weatherford tongs, elevators. Retrieved 1727 SS bands, missing 61 from original tubing tally.,Service rig. Crown, draw works, all motors, top ddve.,Monitor well. Static. Pressure down accumulator. Open lower pipe ram doors, remove 3.5" rams, install 4.5" rams, close doors and tighten up LPR's. Found half of the lower hanger seal in the lower cavity.,Rig up test equipment. Fill stack with water. Prepare to shell test stack.,Begin shell test. Observe leak while testing upper pipe rams. Switch to lower pipe rams. Good test. Pressure down accumulator. Open upper pipe ram doors. Found a two inch piece of rubber from the hanger in the upper cavity. Close doors. Tighten bolts. Pressure up accumulator.,Test #1. Upper pipe rams. 250 psi low. Good. On high test saw slow leak, Fail. Bleed off. No leaks in stack or out annulus. Locate leaking needle valve and ball valve on test manifold. Replace two 10k ball valves, two 1 Ok needle valves. Production hand came to service leaking IA tree valve.,Re-start test #1 Upper pipe rams, 250 psi low 10 mins, good. 4500 psi Failed high test. Test #2 Lower rams, 250 psi / 4500 psi 10 mins. each. Good. Test annular. 250 psi 12500 psi 10 mins, each. Good.,Pressure down accumulator/ open doors on upper rams, switch out variables to 4.5" solid body rams. Crew change.,Complete installation of 4.5 solid body rams also replaced door seals. re position pancake on dead line so its above weight indicator. Indicator now showing correct weight for blocks and top drive.,4 way valve on accumulator for upper pipe rams leaking. Remove and replace with new valve.,Test upper pipe rams 250/4500, upper pipe ram failed to test at 4500psi. troubleshoot all test lines, found leak between upper flange lower pipe rams. Tighten up studs and re-test to 4500psi test good, Remove test plug, set 9 .125ID wear bushing ren in 2Ids, BID test joint and lay down, PJSM Rig up pollard E-line sheaves and e4me. RIH with 5.71 Gage ring /Junk Basket and CCL. Gage ring/Junk hung up at 1308U work stuck gage ring with 1000# over pulls to free up POOH with Gage ring/Junk basket on a-line , and lay down .While running a- line replace bladder in pulsation dampener on # i mud pump. No debris in junk basket .,Decision made to run5.750 OD lower and upper 5.979 OD string mills with flex joint and drill pipe. Tally and drift 4 1/2 drill pipe ( 2.54od rabbit) and stand back in derrick 8/27/2018 Strap and tally 4.5" CDS 40 DP, single in the hole with 56 joints to 1764'. Rack back. (SIMOPS: Locate a 5 5/8" insert tooth bit and bit sub to makeup to string mills. Peak truck arrive with needed 4" XT 39 HWDP, subs.),Strap and tally BHA components. Stage all tools on rig floor and catwalk. BHA#1 Gauge run. Insert bit HTC / VGD 20 DX. Used. 55/8" OD, bit sub / DP XO / Lower mill 5.75"/ flex joint/ upper mill 5.979 / XO / 3 jts XT39 HWDP/ Jam/ 2 jts XT 39 HW DP / 64 jts 4" XT 39 DP / XO to CDS 40,P/U BHA#1. as per Baker hand. Single in with HWDP and jars to 349.,Level the derrick. Shim one inch on off driller side.,Strap and tally 4" XT 39 DP from 340' to 991'. Single in off catwalk. Mixing OBM, redress shakers with 170's on 1 & 3, and 200's on 02. Set up new pressure washer to wash shakers with LVT. 105 bbls LVT in upright #4. Uprights 1 & 2 are full of OBM 9.5 ppg. 1230 bbls of OBM ready to go.,Cont. to single in hole, strap and rabbit 4" D.P. 14#, 5-135 HT -38 F/ 991' to 2,384' MD. P/U 36K, SLK 40K. No losses.,PJSM C/O Elevators to 4.5". Cont. to single in hole, strap and 2.5" rabbit 4.5" D.P. 16.6#, 5-135 CDS40 F/ 2,384' to 9,335' MD. P/U 126K, SLK 134K.,OBM on location: 1,236 bbl LVT on location: 105 bbl 8/282018 Continue to single in with 4.5" CDS 40 drill pipe. from 9335'to 9585'. SIMOPS: Rig up MPD system, Mud Loggers, Mix a 25 bbl hi -Vis sweep. All OBM ready to go, 1236 bbls. Still waiting on 2 loads of LVD. Clean and install 4 magnets in ditch.,Service rig. Blocks, Top drive, Iron roughneck, Draw works, Check all fluids.,Continue to single in with 4.5" CDS 40 drill pipe. from 9585'to 1017N.,Continue to trip in out of the derrick with 4.5" CDS 40 drill pipe. from 10174'to 10732'.,NOV Tech changed out die blocks in top drive, and install grabber box pin. Continue to assist MPD crew in Swaco rig up. Adjust link tilt.,Continue to trip out of the derrick with 4.5" CDS 40 drill pipe. from 10732' to 11,911: ,Continue to single in with 4.5" CDS 40 drill pipe. from 11,91 Via 12,740'. MPD rigged up to 75%. Geo -Span set in place. Repaired mouse hole returned from welder.,12,740' MD, tag up with 10k down. Pick up 20 feet establish circulation. 220 GPM, 500 PP, 40 RPM. 3k free torque. Tag up and maintain torque 3-5k. Clean up. Work through with no rotary or pump.,Singled in from 12740' to 13004, tag up 1 O down. Ream from 13,004 to 13,009. 220 GPM, 500 PP, 40 RPM. 3k free torque. Tag up and maintain torque 3-5k. Clean up. Work through with no rotary or pump. Trip in to 13,065 tag up 10k. Ream from 13,065' to 13,084'. The bit clean up the area first, then no torque for 5 feet distance to first mill, kept torque from 3- 5k, cleaned up, and then 13 feet Iater.,13,084'. The upper 5.979" OD mill began to work the same spot. Torque flagged from 3 to 8k it/lbs. 317 units of gas on bottoms up.,Rotated down F/ 13,084' to 13,095' MD 219 GPM, 392 PSI, 54 RPM, 4.SK free TRQ. From 13,095'to 13,101' increased erratic torque F/ 4.5 to 10K at 54 RPM. Worked through area several times with 15K over pull and 10K dawn. Increased rotary to 66 RPM, 469 GPM, 1,558 PSI. Appeared middle and upper mill was causing torque, bit appeared to be good.,Attempted to pull through with out rotation and hook load was still 15K over and I OK down. Decision was made to pump Hi Vis sweep and increase lube content to 0.5%.,Rotate and reciprocate working tight spots F/ 13,054'to 13,115' MD 470 GPM, 1,600 PSI, 66 RPM, TRQ 4.5-9K. Pumped 300 Vis 15 bbl Hi Vis sweep. Sweep came back with little increase in metal debris but magnets showed about 5# of sliver metal. Pulled through area with no ration only seeing minimal drag 231K. P/U 180K, SLK 184K.,Single in hole strapping and rabbit 4.5" D.P. F/ 13,115' to 14,397' MD. Tagged top of cut with 7K down Tin on joint 393. Depth of tag=14,397'. No issues RIH.,UD joint 393. Pump Hi Vis sweep at 14,387' MD 300 Vis 18 bbl at 40 RPM, 470 GPM, 1,550 PSI. P/U 190K, SLK 194K.,Incident occurred at 23:48 Motor stalled on Drawworks. Elevators and bails came in contact with rig floor. Damaging bails and elevators. No injury to personnel. Contacted all key personnel and secured area. Cont. pumping sweep to surface with minimal increase at shakers.,PJSM UD Elevators and Bails. Inspect top drive, crown and Derrick. Expeditor was sent for another set of bails. Clean cellar stack, prep Herculite for installing on cellar. Work on MP #2. Monitor well with trip tank.,PJSM Function testtop drive.,POOH Racking back 4.5" D.P. F/ 14,387'to 13,454' MD. P/U 180K, SLK 182K.,OBM on location 1,247 bbl LVT on location 327 bbl 8/292018 Trip out of the hole on elevators from 13,454'to 12,833.,Visually inspect load bearing areas on bail ears. No hair line cracks seen.,Trip in the hole past the 'debris area'. Trip from 12,833' to 13140'. No issues, no drag.,Trip out of the hole on elevators from 13,140' to 10,968'. SIMOPS: Rolling OBM in tank farm. Rigging up MPD equipment, rigging up Sperry hardline for GeoSpan.,Continue to trip out on elevators from 10,968' to 10,472' MD. Proper hole fill.,Expected Hilcorp Inspectors arrive on location. Stop tripping, Inspectors request access to topdrive. Full access granted. Crew removed bails, obtained Hot Work Permit from Production and began to wire wheel the areas to be inspected. All areas cleaned to specification. Mag particle inspection conducted. The weight bearing bail ears, and arms, the link tilt brackets and eyes were the main focus. No damage was found.,New link tilt cylinders were installed. Normal operations began. SIMOPS: Continue to rig up MPD, hang new spill catch tarp in the cellar, Install new bearings in lop drive generator, pulley.,PJSM Finish putting bails and elevators back on top drive.,PJSM POOH racking back 4.5" D.P. F/ 10,607'to 4,160' MD P/U 72K, SLK 74K.,PJSM Cut 125' of drilling line. Set crown amatic and Pason weight indicator.,PJSM UD singles 4.5" D.P. F/ 4,169to 2,791' MD. (44 Joints) P/U 56K, SLK 58K. C/O dies on Iron Roughneck. 8/30/2018 Continue to lay down 4.5" CDS 40 DP from 2790' to 2232' . Laid down 62 joints total of 4.5",Lay down 4" XT 39 DP from 2232' to BHA @ 208'. Laid down 64 joints of V DP.,Lay down jars and 5 XT 39 HWDP. lay down upper mill, still 5.9" OD, flex joint, lower mill, 5.75" OD. Fish in hole. 4.35' long. Bit / bit sub / double pin XO. Clean back off of lower mill box. No markings.,Pre job safety meeting with Pollard. Rigging up wireline.,Rig up Pollard. Hang sheave on elevators with provided T bar. Bring tools to floor. RIH with 5.7" OD gauge ring and junk basket. POOH from 14,420' WLM to surface.,Rig down gauge ring run #1, pick up CIBP run #2. SIMOPS: Change out pump on mix hopper#2. Installed herculite liner in wooden cellar. Work on MPD hoses.,RIH with CIBP to 14318' MD. Set plug. POOH to surface.,Mixing cement in buckets with Pollard for the first of three dump/bail runs,PJSM RIH W/ Wireline bail cement 3 runs at 14,360' WLM. W/ a total of (1.3 bbl) 52.2 gallons of cement 36' in 7" casing. SIMOPS Work on rigging up Geospan. Set Herculite in cellar and suck out Poor Boy.,PJSM RAl test Equip. and chart recorder. Test 9 5/8" and 7" casing to 2,500 PSI for 30 min. Pumped 11 bbl, W/ 9.5 bbl returned. RID test Equip. Witnessed by Co Rep. SIMOPS Pollard C/O Bailer to CIBP.,Pollard RIH W/ Baker CIBP run 93 to 13,091' WLM, made numerous attempts to pass tight spot setting down and running into it at 80 fpm. Pulling over 250-350 Ib. Decision was made to POOH.,POOH and found CIBP had backed off stroker and upper die was cocked. Re tightened CIBP and stroker. RIH at 6,200' WLM.,OBM on location 1,246 bbl LVT on location 327 bbl 8/312018 Continue to RIH with Baker 5.7" CIBP from 5200-13,090' MD WLM. Hung up. Set down with faster rate up to 1507min. Stop. normal up weight=2900 lbs. Pulled Fee with 3850 lbs. POOH.,Lay down Baker 5.7" OD CIBP, Pick up Pollard 5.61" OD CIBP, CCL, gamma ray string. Unable to get past same depth of 13,090' MD. WLM. POOH.,Lay down gamma my tool. Shorten tool string. Suspect slightly cork screwed pipe, tool length issue. RIH with Pollard 5.61" OD CIBP, CCL only. Still unable to get past 13,090'. POOH, lay down Pollard tools. Release Pollard. SIMOPS: Remove WMT 2 1/16" 5k valve leaking on mezzanine, install Cameron 2 1/16" 5K valve.,Remove wear bushing. Install test plug and test joint. Pick up 4" TJ.,Pressure down accumulator and open up upper pipe ram doors. Remove 4.5" solid body rams. install 2 7/8" x 5" variable rams. Close doors. hammer up.,Fill BOPE and choke manifold with water. Perform shell test to 4500 psi 20 mins. Good. SIMOPS: Remove WMT 2 1/16" 5k valve leaking on mezzanine, install Cameron 2 1/16" 5K valve. Rebuild charge pump for hopper#2. Install. Total safety on location„PJSM Assign personnel to work areas. Ensure all line up on stack. Post high Press. signs and announce high Press. testing to third party. BOLDS,PJSM Test BOPE 4” test joint 250 PSI low, 4,500 PSI high for 5 Min on chart. Annular, COS40 Dart, TIW, VBR Upper Rams, HCR Kill, Mezz Kill, Choke Valve 1-8. Tested PVT and Gas alarms with Total Safety. Witnessed by AOGCC Matt Herrera.,While testing 4.5" test joint on Upper Pipe Rams found ram shaft started leaking out of body tattle tail. Released Matt Herrera.,Contacted Weatherford BOPE specialist and mechanic. Bleed down Koomey, open ram door and prep for rebuild. Dismantle Cylinder Head, Cylinder. Take apart ram and ram shaft. Rebuild ram shaft seals and start putting back together. SIMOPS Work on MPD Iines.,Work on mud pump maintenance, hopper pump, lines and valves. Roll uprights W/ OBM.,OBM on loaction: 1,246 bbl LVT on Location: 327 bbl 9/1/2018 Continue with upper pipe ram repairs. Finish replacing ram shaft seal. Complete hammering up bolts. Hooking up hydraulic lines. Function rams.,Fill BOP stack with water. Bleed air out/ Perform shell test to 4500 psi. Find Driller side blind ram tattle tale weeping oil. Stop shell test. Pressure down accumulator. Remove plug on blind rams, energize existing packing and reload with packing.,Perform shell test to 4500 psi. CM valve #7 leaking, needle valve on test manifold leaking. Two gland nuts on wellhead Ieaking.,Change out needle valve, tighten all gland nuts. Take CM #7 apart. Inspect sealing surface and seals. Swap seats around on valve, put back together.,State Inspector arrived. Perform shell test to 4500 psi. Good.,Test BOPE. Test#3 UPR, manual kill, CM 7,9,13,TIW. CM #13 failed. Bleed pressure off. Pull test joint check seal on test plug. Change out seal. Re-grease CM #13.,Shell test. Failure at the HCR choke valve, leaking at the all thread packing area.,Prejob : Remove choke HCR. Mount new choke 31/8" HCR.,PJSM Start Test #3. HCR Choke ram packing had slight leak. Still having pressure loss on 4,500 PSI. Isolate testing manifold and found two 6,000 PSI valves leaking. Remove test manifold and rebuilt. Checked chart recorder and hose, C/O fitting. Serviced sensator . NOS replaced packing in HCR Choke.,Start working air out and test test manifold. Good test. Start Test #3 found Upper Variable Rams leaking on low 250 PSI and held at 4,500 PSI. Pull and UD 4.5" test joint. Close blind rams and R/U to kill llne.,PJSM Test F/ 250 PSI low to 4,500 PSI high on chart. Tested Blind Rams, Mezz Kill, Valves 7-10 and 13, HCR Choke, Manual Choke, Super and Manual Choke and IBOP. Manual IBOP Failed. Perform Koomey Draw down test initial Press. Manifold 1,600 PSI, Accumulator 3,000 PSI, Annular 790 PSI.,Charge time 26 sec for 200 PSI full charge 104 sec. Final Press. Manifold 1,600 PSI, Accumulator 2,950 PSI, Annular 700 PSI. Average Nitrogen 4 bottles 2,625 PSI. Witnessed by AOGCC Mat Herrera.,PJSM Drain stack and change rams out to 4.5" solid body upper and 4" solid body lower. Found slight grooves in top ram cavities, used Emery cloth to smooth out. C/O Manual IBOP on IDS350. Torque Saver Sub and IBOP to 46K.,OBM on loaction: 1,235 bbl LVT on Location: 327 bbl 9/2/2018 After changing IBOP on topdrive, installed die blocks in grabber, torqued up bolts and wired same on lock rings.,Performed shell test on stack at 250/4500 psi. Good test. Tested upper pipe rams, lower IBOP, TIW, manual kill and choke valves at 250/4500 psi. Good tests. Removed 41/2" test jnt, installed 4" test jnt. Attempted a lower ram test. Could not test due to bottle neck/port hole location in lower rams. Found another 4" test jnt at Tuboscope and made arrangements to have it delivered. Changed out washpipe on topdrive while,waiting on test jnt. Installed 4" test jnt and tested lower ams at 250/4500. Good test. Flooded choke manifold and tested CMV #12. Good test. Testing witnessed by AOGCC Rep Matt Herrera. Total test time 46 hm with fail pass tests. RD test equipment.,Removed drip pan and trip nipple from MPD head. Installed MPD test plug in head and flooded Swaco surface lines. Tested Swaco MPD plumbing at 250/1200 psi as per Swaco Reps. R/D Test Equip.,PJSM Test Sperry Geo Span to 3,000 PSI as per Sperry DD and MWD onsite.,PJSM Pull test plug and set Wear Ring 9.125" ID.,PJSM P/U 1 Jnt HWDP and build BHA #2 Mill Assy as per Baker rep onsite. P/U M/U 5.625" Rock Bit, 5.75" Lower Mill, 4.75" Flax Joint, 5.979" Upper Mill, X/O and 1 Jnts4.5" HWDP to 52.1 VMD. Release Baker Rep from location.,PJSM Install lift ring on Annular BOP, Install MPD trip nipple. Install mouse hole.,Make up X10 for floor valve. Cont. RIH W/ 2 Jnts 4.5"HWDP, 4.875" Jars and 2 Jms 4.5" HWD to 204'. Cont. to single in hole W/4" D.P. (64 Jnts) 14#, S-135 HT38 F/204'to 2,228' MD.,C/O Elevators to 4.5". Kelly up. PJSM Unstring drilling line off Drawworks and re spool due to spacing. Install service loop cover.,OBM on loaction: 1,235 bbl LVT on Location: 327 bbl 9/3/2018 Finish installing service loop wrap.,Single in 62 joints 41/2" DP from 2228'to 4149' using mousehole.,Cont TIH on 41/2" DP from derrick to 7692'. Kelly hose getting pretty tore up against derrick leg when slacking off up high.,Held PJSM for C/O Kelly hose. Removed 55' hose from topdrive, then from standpipe and staged on ground level. Went to remove new 62' hose from box and discovered it has wing halves on both ends. We have no hardware at the rig to make double pin XO. Re-install 55 foot hose on standpipe only. Borrowed more OMNI wrap from Swaco MPD crew to cover worn spot of hose.,Cont TIH with stands from 7692' to 12953' correct hole displacement,At 12,953' MU Kelly hose and adjust to have clear travel in derrick. Fill lines and pressure test kelly hose to 1200psi, no issues,RIH F-12,953' tag up on debris / obstruction at 13,060' with 5k down wt. Begin Milling out F-13060 to 13086' 389gpm. 716psi work through problem area seeing torque ranging F-31k to 8k. as upper 5.797 mill passed through. Back ream f-13086 up to 13050' shut down rotary and pumps RIH f- 13,050 to 13,086 casing cleaned up Dn.Wt.172k Up.Wt. 172k. Tq. 3k-8k,RIH on elevators F- 13086'to 14330' no problems. correct hole displacement,Circulate and pump 201bbl Hi-Vis sweep at 14330' 420 gpm 1486 psi. Surface to surface strokes 15,097stks. Sweep returned with no increase material over shakers. 137units of gas on B/U,POOH on elevators F-14330' - (13,086 to 13,060' no excessive drag or over pulls ) continue to POOH F. 13060'- 11,343' Correct hole fill. 9/4/2018 Cont POOH from 11,343' to 2785', racking back 41/2" in derrick.,Cont POOH LD 4 1/2" DP from 2785' to 2230', C/O elevators to 4".,Cont POOH LD 4" from to surface (64 jnts DP, Sims HWDP and jars). Tri-cone bit had one broken button, outside of cones were worn/scarred somewhat, Baker string mills looked Q2230' good and in gauge.,Cleaned and cleared dg floor. Serviced rig. Pollard a-line on location at 17:30. Called out Weaver Bros to transport our 300 bbis LVT to OSK, for shipping to Steelhead Platform.,RU Pollard a-line, MU tool string with 5.7" gauge ring/Junk basket CCL RIH passing through 13,060-13,086' WLM with out any problems. Cont. rih to 14,436' well bore clean. POH and lay down Gage ring/Junk basket and CCL tools.,Make up 5.69 OD Baker COP setting tool and GR , RIH passing through 13060-13086' with no problems. continue RIH to 14,309' and set down on hard cement. Make correlation log f-CCL and gamma tool, Determined setting depth by condition of 7" casing & coal seams. Set CIBP at 14.239'- 5' above casino collar with no coals. Set CIBP saw 200 pound decrease in e- line weight. Hold for 5min set down to confirm setting.,POOH with pollard E-line lay down CIBP setting and gamma tools . R/D pollard E-line sheaves and Tools,Make up 7" Gen 2 whipstock assembly with 45k shear bolt to starter mill, Anchor set up with 5 screws and a 17k shear value. MU TM and DM collar, float sub and UBHO sub.,TIH on 4" drill pipe from 21'to 766', Pulse test MWD at 766'. Continue TIH at reduced rate filing pipe every 15 stands from 766' to 1591' Shipped 297 bbis of LTV to OSK dock. Switched to drilling mode at 06:00 hm.,OBM on location: 1,235 bbis LVT on Location: 30.2 bbls nHilcorp Energy Company Composite Report Well Name: BCU-05RD2 Field: Beaver Creek Unit County/State: Kenai, Alaska i (LAT/LONG): evation (RKB): 18 API #: 50-133-20262-02-00 Spud Date: 9/6/2018 Job Name: 1810833D BCU-05RD2 Drilling Contractor RIG 169 AFE #: AFE $: Activity Date`� M " �' Ops Summary 9/5/2018 TIH with Baker Gen II WindowMaster whipstocklanchor assembly (ramp is 13,33' long), 5.875" starter mill, 5.75" lower mill, 6 55'Flex jnt, 5,979" upper mill, one jnt 4" HWDP, Sperry DM and TM collars, Gyro -Data UBHO sub, and 2023' of 4" DP from 1591'to 2123'. C/O handling equipment to 4 1/2".;PU and single in hole with 18 jnts 4 1/2" CDS40 DP, 2123' to 2310'.;Cont TIH on 4 1/2" OP stands from 2310'to 11,419', filling pipe every 2000'. Sperry getting good detection on their / tools each time we filled pipe.;Service rig, topdrive and drawworks.;Cont TIH on 41/2" stands from 11,419to 12,662 Had Baker Rep on location to watch as we J( entered top of liner at 11,698' ( no issue) Continue RIH to 12662' while filling pipe saver sub started Ieaking.;Remove and replace Saver sub damaged threads I 1\ lay down joint # 340 and replace with joint of equal Iength.;Cont. F 12,665'- 14,156' Pump @ 250gpm 735psi and orient whipstock to 52 deg. right. Continue �/ RIH and tag CIBP at 14255.6. Set down 15k and engage anchor P/U and pulled 10k to verify anchor set. SIO set 35k down to shear off and set whipstock placing top at 14238 bottom at 14259.;PJSM: Line up mud pumps and pits to displace well bore with 9.5ppg taking water returns to cutting box vacuum trucks and pits 3&7 then transfer water to UR tanks. Pump 20bbl hvs spacer followed by 863 bbls OBM . Pump at 6bbls min 1085psi Up Wt 180 Dn.Wt. 182 At 14238 MD. 13,777 TVD.;Complete displacement. Clean clear pks.;OBM on location: 1,235 bills OBM Diesel on Location: 268 bills 9/6/2018 Cont cleaning all produced water from pits while circulating OBM with both pumps to help shear new mud. 227 gpm-1415 psi. Starter mill sitting at 14,230' (8' above whipstock ramp). Fluid packed Swaco MPD plumbing with OBM in case needed later (purged water from their system).;Running on pump #2 at 241 gpm- 1622 psi, 80 rpm -3500 fillbs off bott torque. Increased rpm to 103-330010 4400 fl/lbs on bottom and began milling window from 14,238' to 14,271' at 3 to 6 ftlhr ROP. Capturing and weighing metal at shakers. Adding diesel and building OBM volume. MW 9.5/vis 57.;Up wt 178K, dwn wt 178K, rot wt 178K. Mud loggers seeing 5 to 10% cement in cuttings samples. We did have one small spike of gas up to 31 units, BGG at 15 units.; Pumped a 20 bbl hi -vis sweep at 14,271' to clean hole for FIT. 340 gpm-2988 psi, 108 rpm3063 ft/lbs off bolt torque. Worked mill assembly in/out window as per Baker Rep with no issue. #2 mud pump discharge manifold leaking shut down pump, continue circulating out hi -vis sweep at 225 gpm.;P/U to 14238' R/U test lines and chart for Fittest at 13,777 TVD . Circulate & purge all test lines. Using mud pump pressure up to 2149psi 14,238 MD 13,777 TVD 9.5 MW 2149psi =12.5 EMW. Pumped 9.4 bbl Bled back 8.5 bbls . R/D all test Iines.;Mill/Drill F- 14,271 -14,299 at 90 spm 241 gpm 1616 psi Up Wt. 178k. Din Wt. 178k Rt wt. 178k. Tq. 3.5-6k/lbs. 102rpm ROP 6- 10 FPH.. Mw. 9.5J Vis 57 Continue building volume at 10 bbls per hr. Work mills through window no issues window clean.;Circulate B/U at 14238' at 180spm 342gpm 2880psi. No increase in cuttings returning over the shakers on B/U. Max gas on B/U 27units Up Wt. 180k Dn. Wt. 1781k Rt. 178k Take slow pump rates at 14,238 Md 13,777 TVD Pump # 1 @ 47stks.=398psi @ 57stks.=524psi Pump # 2 @ 47stks=400psi @ 57stks=528psi.;Monitor well for 15min. well static no gain or loss. Pump dry job pooh F-14238'- 13360'.;OBM on location: 1,235 dials OEM Diesel on Location: 268 bbls Daily Metal 121 lbs Cumulative Metal 130lbs — STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed ByY, P.I. Supry BOPE Test Report for: BEAVER CK UNIT 05RD Comm Contractor/Rig No.: Hilcorp 169 PTD#: 1750550 DATE: 9/2/2018 Inspector Matt Herrera Insp Source Operator: HILCORP ALASKA LLC Operator Rep: Wall/Amend/Pederson Rig Rep: Brreswter/Wilson Inspector _ .. __. _ _... ...... _...... ,,,, _.... "... _. ..,__..... .m,. ................. . Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopMFH180905094344 Rams: Annular: Valves: MASP: 289 Type Test: WKLY 318- 250/4500 250/4500 250/4500 ' 3723 ` Related Insp No: MISC. INSPECTIONS: FLOOR SAFTY VALVES: P/F Location Gen.: P Housekeeping: P PTD On Location P ding Order Posted P Well Sign P__ Drl, Rig P Hazard Sec. P_ Misc NA FLOOR SAFTY VALVES: TEST DATA MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators n u Flow Indicator Meth Gas Detector H2S Gas Detector MS Misc Y " Y P P- P P NA NA_ ACCUMULATOR SYSTEM: Quantity P/F Upper Kelly 1 .•P _ Lower Kelly Pressure After Closure 1600 Ball Type - 1 - _P_ Inside BOP 1 FP FSV Misc 0 NA TEST DATA MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators n u Flow Indicator Meth Gas Detector H2S Gas Detector MS Misc Y " Y P P- P P NA NA_ ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3000 P Pressure After Closure 1600 P 200 PSI Attained 26 P Full Pressure Attained 104 P Blind Switch Covers: YES P Nitgn. Bottles (avg): 4(&,2625 P ACC Mise 0 NA BOP STACK: Quantity Size P/F Stripper 0 NA Annular Preventer 1 __11" P #1 Rams 1 2 7/8" x 5" FP #2 Rams 1' Blinds P #3 Rams 1 4 1/2" P #4 Rams 0 #5 Rams _ 0 __NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" P HCR Valves 2 3 1/8'-2 1/16" - FP Kill Line Valves 2 2 1/16" P Check Valve 0 _NA BOP Misc 2 ' Flange/Seal FP CHOKE MANIFOLD: Quantity P/F No. Valves 13-, FP Manual Chokes 1 P Hydraulic Chokes 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 8 ' Test Results Test Time 43.5 Remarks: CMV #7,13 F/P service Retest good. Lower IBOP F/P Changed out retest good. TIW/Inside BOP Valve F/P serviced retest gbo pper ams F/P were changed from 2 SBR to 4.5" fixed retest good.pper rams sea waL retest good. Flan -g -51 -555F -B-07 Misc F/P retest good HCR Valve Failed was replaced Failed ffgain was rebuilt retest good. Lower Pipe Rams chahg—eUTo-WTixed SCANNEV NO V , 91 a 10, • Regg, James B (DOA) 40 �eewc'creev—u'4c� From: Robert Wall - (C) <rwall@hilcorp.com> Sent: Monday, August 27, 2018 10:51 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA) 1� � r I ti/ l� Cc: Monty Myers ` Subject: Hilcorp Rig 169. Notice of ram test after tubing pull. Attachments: Hilcorp Rig 169 Notice of BOP Ram Test after tubing pull. 8.26.2018.docx Jim, Guy, Please find attached our description of the ram test after we safely retrieved our tubing. Thank you for your consideration in this matter. Respectfully, Robert Wall @ Drill Site Manager Hilcorp Alaska, LLC HAK 169 907-776-6776 SCANNED SEP U 5 Z016 1 Notice of BOP Ram Test After tubing pull. • Date/Time: 8/26/2018 at 10:00 hrs to 22:00 hrs. • Well: BCU 05RD2 • Location: Beaver Creek % • PTD: 175-055 Sundry: 318-289 • Rig Name: Hilcorp 169 • Operator Contact: Robert Wall at 907-776-6776 / rwall@hilcorp.com • Operation Summary: After the Initial BOPE test to BLM requirements conducted on 8.24.18,(Witnessed by BLM, waived by Jeff Jones), the tubing string was pulled from the well. 456 joints were retrieved. The lower rams were not tested due to the hanger neck height obstructing the test joint. Guy Schwartz AOGCC gave approval to delay testing lower pipe rams. Email 8:39 PM 8.22.18. • Reason For BOP Ram Test: To complete the initial test as agreed upon, and to test lower pipe rams, and test upper and annular with 4.5" test joint. • Actions Taken: All tests were with 4.5" test joint. (Test #1)Tested upper rams, fail/pass. Changed out variables to 4.5" solid body. Good test to 250 psi low 10 mins, 4500 psi 10 mins. (Test #2) lower 4.5" solid body ram. Good test to 250 psi low 10 mins, 4500 psi high 10 mins. Ll (Test#3) Annular. Good test to 250 psi low 10 mins, 2500 psi 10 mins. • Accumulator part change: The 4 way valve assigned to the upper pipe ram was changed out. This valve was leaking by in closed and open position. New valve installed. 8.26.2018. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 09, 2018 9:18 AM To: 'Taylor Nasse' Cc: Subject: Taylor, Chad Helgeson; Donna Ambruz RE: BC-05RD (PTD 175-055) revised procedure for sundry 318-289 Thanks for the updated procedure. You have approval to proceed as proposed in the attached document. The final reservoir abandonment pressure test will be at 18b as indicated to 2500 psi (.Make sure the test is charted) The variance for moving isolation plug greater than 50 ft above perfs is also approved. The IBP is still there just above perfs but will not be tested as no cement was dumped on it would likely fail the 2500 psi test. Update the MOC form as required. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office SChpiE0 AUG G 9 Lt )) CONFIDENTIAUIYNOTICE., 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: Taylor Nasse <tnasse@hilcorp.com> Sent: Wednesday, August 08, 201810:46 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Chad Helgeson <chelgeson@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: BC-05RD (PTD 175-055) revised procedure for sundry 318-289 Hi Guy - Per our conversation yesterday, attached is a revised procedure and proposed schematic for sundry 318-289 for your review and approval. We were successful in setting an expandable bridge plug in the well; however, when they were running in to dump bail cement on top of the plug they inadvertently left cement in the tubing at 14,466'. After further discussion, they believe this occurred due to running in at a high rate of speed while going in the well which caused the glass disk in the bottom of the bailer to break upon hitting fluid. We were unsuccessful in our attempts to chip away the cement to make it back down to the plug, so our proposed revised procedure is to pull the tubing and then set a cast iron bridge plug and 35' of cement just above the packer. If you have any questions or need additional information, please feel free to contact me. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team A• • ItilL Well Prognosis Rev. 1 Well: BC 05RD Date:8/7/2018 Well Name: BC-05RD API Number: 50-133-20262-01 Current Status: Plugged Leg: N/A Estimated Start Date: July 20th, 2018 Rig: Rig # 169 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-055 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Maximum Expected BHP: 5,200 psi @ 14,764' TVD Static Buildup on 11/19/16 (Extrapolated) Max. Potential Surface Pressure: — 3,723 psi (0.10 psi/ft gas gradient) Brief Well Summary Well BCU-05RD was drilled and completed as a sidetrack of the original BCU -05 in 1976. The well was fracture stimulated in 1991 but it is believed that the sand fracture failed due to improper proppant crush resistance. The tubing was replaced in 2014 to remove an unset tubing patch in the old tubing. The purpose of this work/sundry is to plug back the existing open intervals and prep the well for a sidetrack. Notes Regarding Wellbore Condition • Well is currently plugged back with an expandable bridge plug at 14,990'. Cement was inadvertently dumped in tubing, with hard cement at 14,466'. Slickline Procedure: 1. MIRU Slickline, PT lubricator to 250 psi low/4,000 psi high. RIH with expandable plug and set at 14,990' (unable to bail cement due to cement in tubing` 3. RIH with kick -over tool and pull gas lift valve at . POOH and RDMO. 4. RU pump truck and circulate 6% KCL/PW by pumping down annulus and taking returns up tubing. =5. Glese wing valve and pFeSSUFe test eement plblg and EaSiAg tO 2,500 PS*g fGF 30 minbites. Saxon #169 Procedure 6. MIRU Saxon #169 Rig. 7. Circulate 6% KCL/PW by circulating down tubing and taking returns up annulus. 8. Set BPV. ND Tree. 9. Notify AOGCC 24hrs and BLM 48hrs in advance of BOP Test. 10. NU BOPE. 11. Test BOPE to 250 psi Low/ 4,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test. b. Notify AOGCC 24 hrs in advance of BOP test. c. Test VBR rams on 3-1/2" test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Well Prognosis Rev. 1 Well: BC 05RD Ilileorp Alaska, 1J. Date: 8/7/2018 e. Follow steps 10.1 to 10.4 in the PTD Sundry. 12. L/D BOP test equipment. 13. Pump PW down tubing and up casing to ensure well is dead. 14. Pull tubing hanger free, tubing and Baker snap latch seal assembly from Model "SC -11-" packer. Expect =30k overpull to release snap latch. Contingency - It tubing doesn't pull tree from the snap latch seal assembly: 14A. RU e -line. a. RIH with jet cutter and cut tubing in middle of joint just above top of cement at 14,466'. 14B. Adjust CIBP depths in step #18 accordingly. 15. Pull tubing string (3-1/2" 8RD) and lay down tubing. Number and label each joint. 16. Clean and clear floor. 17. Ensure well is full of fluid. 18. RU a -line. a. RIH with 7" CIBP and set at±14,590' (just above packer). b. Dump bail 35' of cement on top of CIBP. Pressure test cement plug and casing to 2,500 psig for 30 minutes. Note: Hilcorp Alaska requests a variance from the requirement in 20 AAC 25.112(c)(1)(E) that requires the mechanical bridge plug and cement to be set within 50' of the open perforations. Due to a cement plug in the tubing, the CIBP and cement will be set just above the packer. c. RIH with 7" CIBP and set at ±14,500' (5' above a collar) for whipstock. 19. RD a -line. ***Remaining procedure to be included on the Permit to Drill for the sidetrack Starting at 11.0 of PTD*** httarhmantc 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form ttilvorp AlaAa. LLC Permit #: 175-055 API #: 50-133-20262-01 Prop. Des: A-028083 KB elevation: 173' (18'AGL) Spud: 12/19/1975 TD: 15,655' Rig Released: 3/23/1976 Tree cap = 6-112" Otis 1 BC - 5RD Pad 3 1,195' FNL, 1,495' FWL, Sec. 34, T7 N, R1OW, S.M. Debris on casing wall 13,073' Tag w/ 5.75" OD overshot (3/24/14) 13,123' Tag w/ 5.50" LIB (3/28/14) jewelry Depth I.D. 1.9-5/8"x7" Liner Hanger -11,698' ? 2. 7" CI BP -14,500' 432' 3. 7" CI BP w/ 35cement -14,590' 61 ppf 4. Baker'SC-1 L' Packer & Seal bore Ext. 14,596' 4.000" 5.Otis'X'Nipple 14,627' 2.813" 6. Baker'F-1' 83-40 Packer & Seal bore Ext. 14,667' 4.000" 7. Baker Tubing locator - Snap Latch Seal Assy. 14,661' 2.992" B. TIW Seal Assy. in TIW PBR & Liner Hanger 14,693' 3.000" 9. Expandable Bridge Plug 14,990' 32 ppf 2ea - 5' x 1-1/2" cutter bar Bottom MD 11,531' (4/16/14). TVD 11,322' 14,377' Unknown depth. 18 ppf Lost 30' tool string (2.25" bailer) 15,244' SLM (4/21/14). 7 8 -.. 9!I PROPOSED SCHEMATIC Conductor Casing 20" H-40 94 ppf Ton Bottom MD 0' 432' TVD 0' 432' Surface Casing 13-3/8" K-55 61 ppf TOP Bottom MD 0' 3,511' TVD 0' 3,511' Intermediate Casing 9-5/8" P-110 47 ppf TOP Bottom MD 0' 11,698' TVD 0' 11,465' Liner 7" P-110 32 ppf TOP Bottom MD 11,531' 14,918' TVD 11,322' 14,377' Liner 5" P-110 18 ppf Tom Bottom MD 14,693' 15,655' TVD 14,182' 15,061' 9 10-C Tagged w/ 2.70" GR @ 15,272' on 04/20/17 Tvonek Perfs: Beaver Creek Unit #5RD Baker Setting Tool 1.0" rod @ 15,325'. Beaten to TD 15,655' MD PBTD 15,607' MD MD TVD Net Ft Zone SPF Date Status 15,010'-15,025' 14,465-14,478' 15' G1 -B 6 02/10/18 Open 15,015'-15,030' 14,469'-14,482' 15' G-1 6 412412014 1 Schematic Revision Date: 81712018 15,062'-15,072' 14,510'-14,519' 10' G1 -C 6 02/10/18 Open 15,150'-15,180' 14,589'-14,616' 30' G1 -D 6 02/09/18 Open 15,344'-15,390' 14,768'-14,811' 46' Lower G Multiple 15,395'-15,430' 14,816-14,849' 35' Lower G Reperfs 15,450'-15,508' 14,868-14,923' 58' Lower G Well Name & Number: Beaver Creek Unit #5RD Baker Setting Tool 1.0" rod @ 15,325'. Beaten to TD 15,655' MD PBTD 15,607' MD bottom. Max OD is 1.360" at bottom. 17' Long. E -line patch setting tool used to set Otis patch. Tag 1.25" DD 15,061' TVD 15,015' TVD w/ bailer at 15,480' SLM (11/21/13). Well Name & Number: Beaver Creek Unit #5RD Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska I Country: USA Angle @KOP and Depth: 260 @ 14,918' 1 Angle/Perfs: 28° Maximum Deviation: 29.00 @ 14,200' Date Completed: 3130/2014 Ground Level (above MSL): 155' 1 RKB (above GL): 18' Revised By: Taylor Nasse Downhole Revision Date: 412412014 1 Schematic Revision Date: 81712018 THE STATE 01ALASK-A GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission SCANN% Jud' 11 LOib Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 05RD Permit to Drill Number: 175-055 Sundry Number: 318-289 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.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. �t DATED this day of July, 2018. BDMS JUL i 2018 Sincerely, Hollis S. French Chair RECEIVED STATE OF ALASKA JUL 5 2010 l ALASKA OIL AND GAS CONSERVATION COMMISSION -7 I APPLICATION FOR SUNDRY APPROVALS ®C(® 20 AAC 25280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Progrpm ❑ Plug for Redrill ❑Q 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 ❑✓ - Stratigraphic ❑ Service ❑ 175-055 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 P 6. API Number: Anchorage Alaska 99503 50-133-20262-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 2378 ❑ Q Beaver Creek Unit (BCU) 05RD Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028083 Beaver Creek / Beaver Creek Oil Pool 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): 15,655' 15,061' 15,607' 15,015' —3,723 psi N/A 15,272' (f sh) Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530 psi 520 psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090 psi 1,540 p i Intermediate 11,698' 9-5/8" 11,698' 11,465' 9,440 psi 5,300 psi Production 3,387' 7" 14,918' 14,377' 12,460 psi 10,780 psi Liner 962' 5" 15,655' 15,061' 13,940 psi 13,470 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 7 Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3# / N-80 14,596 Packers and SSSV Type: Baker SC -1 L Pkr; Packers and SSSV MD (ft) and TVD (ft): 14,596' MD - 14,089' TVD; Baker F-1 Pkr; N/A 14,667' MD - 14,153' TVD; NA, 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 20, 2018 OIL ❑ WINJ❑ WDSPL ❑ Suspended ❑� ' GAS E]WAG ElGSTOR ElSPLUG ElCommission 16. Verbal Approval: Date: Representative: GINJ ElOp Shutdown ElAbandoned '', El 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: Chad Helgeson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnaSS2 hilcor .com Contact Phone: 777-8354 Authorized Signature: Date: 7 S to COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:of �I y L Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 27 /��r AA07 ,ae %O AO Td W /Tib S � �P� E r637" o �r A �Biv�/J osr9�rJV sur G &5,_',7 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes❑ No d Subsequent Form Required: APPROVED BY COMMISSIONER THE COMMISSION Date:`Q- Approved by: `/`t RBDMS%�UL 1 1 2010 Submit Form and tpl\ Form 10-403 Revised 4/2017 Approved application t o date of approval. A c ents in Duplicate -onta°f IN , .� -7 i Hilcorp Alaska, LL' Well Prognosis Well: BC 05RD Date: 7/3/2018 Well Name: BC-05RD API Number: 50-133-20262-01 Current Status: Gas Lifted Oil Producer Leg: N/A Estimated Start Date: July 20th, 2018 Rig: Rig # 169 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-055 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Maximum Expected BHP Max. Potential Surface Pressure 5,200 psi @ 14,764' TVD 3,723 psi Static Buildup on 11/19/16 (Extrapolated) (0.10 psi/ft gas gradient) Brief Well Summary Well BCU-05RD was drilled and completed as a sidetrack of the original BCU -05 in 1976. The well was fractur; stimulated in 1991 but it is believed that the sand fracture failed due to improper proppant crush resistances. The tubing was replaced in 2014 to remove an unset tubing patch in the old tubing. The purpose of this work/sundry is to plug back the existingopenintervals and prep the well for a sidetrack. r✓ COrGO�. ��oatvctrO� lil4� 6N�1 ��f�•� �?c�NieJ 1'dr Notes Regarding Wellbore Condition Vc,43 Aec mr outer peyfafaft kew Zones 4-4 ", 5y1 3 r'A fr07("Ct'01 / r not (off te-i6 i&a' cif, • Well is currently online flowing 22 BOPD, 0 BWPD, 6 MSCFD gas at 65 psig. P' �,�/ r%,f we�1 7 vl Slickline Procedure: 07rll� 4lA��d s,gNo� `e / 1 ,,,,/�0 rrecdveh�r MIRU Slickline, PT lubricator to 250 psi low/4,000 psi high.eft Alt RIH with expandable plug and set at 15,000' and dump bail 35' of cement!�r� { f /f RIH with kick -over tool and pull orifice valve at 14,432'. POOH and RDMO. �r/v�/ 4. RU pump truck and circulate 6% KCL/PW by pumping down annulus and taking returns up tubing. 5. Close wing valve and pressure test cement plug and casing to 2,500 psig for 30 minutes. ✓ axon #169 Procedure 6. MIRU Saxon #169 Rig. 7. Circulate 6% KCL/PW by circulating down tubing and taking returns up annulus. 8. Set BPV. ND Tree. 9. NNotiNsAOGCC 24hrs and BLM 48hrs in advance of BOP Testy", /40trCCG ©,p _TU" 7S W II—AIA�r.S 11. Test BOPE to 250 psi Low/ 4,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each Tay -T� 721 ram/valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. % a. Perform Test.+' r.yo© S� b. Notify AOGCC 24 hrs in advance of BOP test.-f,'►�[`�.�,C,.�� c. Test VBR rams on 3-1/2" test joint. _-. zi�'�.�''°� d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. f 6�ruNtrG�i2 e. Follow steps 10.1 to 10.4 in the PTD Sundry. 12. L/D BOP test equipment. — /AO(,,6} I�itOlxl G� Well Prognosis Well: BC 05RD Hilcoro Alaska, LLI Date' 7/3/2018 13. Pump PW down tubing and up casing to ensure well is dead. 14. Pull tubing hanger free, tubing and Baker snap latch seal assembly from Model "SC -1L" packer. Expect =30k overpull to release snap latch. 15. Pull tubing string (3-1/2" 8RD) and lay down tubing. Number and label each joint. 16. Clean and clear floor. 17. Ensure well is full of fluid. 18. RU a -line. a. RIH with 7" CIBP and set at ±14,500' (5' above a collar). 19. RD a -line. ***Remaining procedure to be included on the Permit to Drill for the sidetrack Starting at 11.0 of PTD*** Attachments 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form Hilcorp Alaska, LLC Permit #: 175-055 API #: 50-133-20262-01 Prop. Des: A-028083 KB elevation: 173' (18' AGL) Spud: 12/19/1975 TD: 15,655' Rig Released: 3/23/1976 Tree cap = 6- SS�ofoarll 9g af112d" oOrtSais :OB • Depth Valve Type Port GLM 2,010' qq 2 6; 13; 8 9 1" Press. Val 1 ress, Valve 1" Press. Vave 1" ReValve ress. �V�//ave 1�� 4" �6/ 6/ #2 ;; # 13 7777778 14;43' ess Va� to 1" Press Va ve Orifice Z % 2 56 #9 • BC - 5RD Depth Pad 3 1,195' FNL, 1,495' FWL, Sec. 34, T7N, R10W, S.M. 1 2. 9-5/8"x7" Liner Hanger -11,698' J 3. Chemical Injection Mandrel (New) 14,509' 2.813" J 14,586' 2.813" 5. Baker'SC-1 L' Packer & Seal bore Ext. 14,596' 4.000" J +� 2.992" 7. Otis'X'Nipple 2 Debris on casing wall 13,073' Tag w/ 5.75" OD overshot (3/24/14) 13,123' Tag w/ 5.50" LIB (3/28/14) 3 6' 9 10 Jewelry Depth 1.13- 1. Tubing Hanger (new) 21' 2.992" 2. 9-5/8"x7" Liner Hanger -11,698' ? 3. Chemical Injection Mandrel (New) 14,509' 2.813" 4.'X' Nipple (New) 14,586' 2.813" 5. Baker'SC-1 L' Packer & Seal bore Ext. 14,596' 4.000" 6. Baker Snap Latch Seal Assy (new; drifted to 2.80") 14,595' 2.992" 7. Otis'X'Nipple 14,627' 2.813" B. Baker'F-1' 8340 Packer & Seal bore Ext. 14,667' 4.000" Baker Tubing locator - Snap Latch Seal Assy. 9'Bake r 14,661' 2.992" 10. TIW Seal Assy. in TIW PBR & Liner Hanger 14,693' 3.000" 2ea - 5' x 1-1/2" cutter bar (4/16/14). Unknown depth. rJ J !r J 4 SCHEMATIC Conductor Casing 20" H-40 94 ppf TOP Bottom MD 0' 432' TVD 0' 432' 3-3/8" K-55 61 ppf TOP Bottom MD 0' 3,511' TVD 0' 3,511' 9-5/8" P-110 47 ppf TOP Bottom MD 0' 11,698' TVD 0' 11,465' Liner GLV Port T' P-110 32 ppf MD TOR Bottom MD 11,531' 14,918' TVD 11,322' 14,377' Liner GLV Port 5" P-110 18 ppf MD Top Bottom MD 14,693' 15,655' TVD 14,182' 15,061' Tubing GLV Port 3-1/2" L-80 9.3 ppf BIRD MD TOP Bottom MD 0' 14,596' TVD 0' 14,089' Tyonek Perfs: GLV Port TempCa Kenai Peninsula Borough State/Prov: Alaska MD TVD Net Ft Z2m SPF # Size Depth TCF PSC •--• 02/10/18 Open D . 5 1 16 98 0.923 1036 1197 1230 IPOR-1/IPOC-1/PPOR-1 6 2 16 119 0.885 1001 1140 1225 IPOR-1/IPOC-1/PPOR-1 14,768'-14,811' 3 16 137 0.855 967 1085 1220 IPOR-1NPOC-1/PPOR-1 - 7 4 16 153 0.830 937 1034 1215 IPOR-1/IPOC-1/PPOR-1 5 16 167 0.810 911 991 1210 IPOR-1/:POC-1/PPOR-1 � 8 6 20 179 0.793 882 971 1340 IPOR-J/IPOC-1/PPOR-1 7 20 188 0.781 854 906 1325 IPOR-18POC-1/PPOR-1 8 20 194 0.773 827 858 1310 IPOR-1/IPOC-1/PPOR-1 9 20 197 0.769 ORIFICE -1 Tagged w/ 2.70" GR @ 15,272' on 04/20/17 Tyonek Perfs: Beaver Creek Unit #51113 Lease: A - 028083 15,244' SLM (4/21/14). Kenai Peninsula Borough State/Prov: Alaska MD TVD Net Ft Z2m SPF J12419 Status 15,010'-15,025' 14,465'-14,478' 15' G1-14 6 02/10/18 Open 15,015'-15,030' 14,469'-14,482' 15' G-1 6 a 15,062'-15,072' 14,510'-14,519' 10' GI -C 6 02/10/18 Open 15,150'-15,180' 14,589'-14,616' 30' G1 -D 6 02/09/18 Open 15,344'-15,390' 14,768'-14,811' 46' Lower G Multiple 15,395'-15,430' 14,816-14,649' 35' Lower G Repents 15,450'-15,508' 14,868-14,923' 58' Lower G Lost 30' tool string (2.25" bailer) Beaver Creek Unit #51113 Lease: A - 028083 15,244' SLM (4/21/14). Kenai Peninsula Borough State/Prov: Alaska Baker Setting Tool 1.0" rod @ 15,325'. Beaten to Angle @KOP and Depth: TD 15,655' MD PBTD 15,607' MD bottom. Max OD is 1.360" at bottom. 17' Long. E -line patch setting tool used to set Otis patch. 1.25" DD bailer 15,480' SLM Date Completed: 15,061' TVD 15,015' TVD Tag w/ at (11/21/13). 1 RKB (above GL): 18' Well Name & Number: Beaver Creek Unit #51113 Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: I USA Angle @KOP and Depth: 26° @ 14,918' 1 Angle/Perfs: 28" Maximum Deviation: 29.0" @ 14,200' Date Completed: 3/30/2014 Ground Level (above MSL): 155' 1 RKB (above GL): 18' Revised By: Donna Ambruz Downhole Revision Date: 4/24/2014 1 Schematic Revision Date: 1 2/21/2018 BC - 5RD Pad 3 1,195' FNL, 1,495' FWL, Hilcorp Alaska. LLC Sec. 34, T7N, R10W, S.M. Permit #: 175-055 API #: 50-133-20262-01 Prop. Des: A-028083 KB elevation: 173' (18' AGL) Spud: 12/19/1975 TD: 15,655' Rig Released: 3/23/1976 Tree cap = 6-1/2" Otis PROPOSED SCHEMATIC Debris on casing wall 13,073' Tag w/ 5.75" OD overshot (3/24/14) 13,123' Tag w/ 5.50" LIB (3/28/14) Jewelry Depth Conductor Casing 1. 9-5/8"x7" Liner Hanger -11,698' ? 2. 7" CIBP 20" H-40 94 ppf ,/r 3. Baker'SC-1 L' Packer & Seal bore Ext. 14,596' 4.000" TOS Bottom 14,627' 2.813" 5. Baker'F-1' 83-40 Packer & Seal bore Ext. 14,667' MD 0' 432' 6. Baker Tubing locator - Snap Latch Seal Assy, 14,661' 2.992" 7. TIW Seal Assy. in TIW PBR & Liner Hanger TVD 0' 432' 3.000" 8. Expandable Bridge Plug w/ 35' cement 15,000' TVD 14,182' 15,061' Surface Casinq Tvonek Perfs: 2ea - 5'x 1-1/2" cutter bar 13-3/8" K-55 61 ppf MD TVD (4/16/14). Date Status Ton Bottom Unknown depth. 02/10/18 Open MD 0' 3,511' i' TVD 0' 3,511' 10' G1 -C 6 02/10/18 Open {?{ Intermediate Casing 30' G1 -D 6 02/09/18 Open {{{ 9-5/8" P-110 47 ppf 46' Lower G Multiple 1�.r. Bottom 36 Lower G Reperfs 3Top MD 0' 11698' Debris on casing wall 13,073' Tag w/ 5.75" OD overshot (3/24/14) 13,123' Tag w/ 5.50" LIB (3/28/14) Jewelry Depth 1. D. 1. 9-5/8"x7" Liner Hanger -11,698' ? 2. 7" CIBP -14,500' ,/r 3. Baker'SC-1 L' Packer & Seal bore Ext. 14,596' 4.000" 4.Otis'X'Nipple 14,627' 2.813" 5. Baker'F-1' 83-40 Packer & Seal bore Ext. 14,667' 4.000" 6. Baker Tubing locator - Snap Latch Seal Assy, 14,661' 2.992" 7. TIW Seal Assy. in TIW PBR & Liner Hanger 14,693' 3.000" 8. Expandable Bridge Plug w/ 35' cement 15,000' TVD 14,182' 15,061' 6/29/2018 Tvonek Perfs: 2ea - 5'x 1-1/2" cutter bar MD TVD (4/16/14). Date Status " 15,010'-15,025' 14,465'-14,478' Unknown depth. 02/10/18 Open Lost 30' tool string (2.25" bailer) 15,244' SLM (4/21/14). 6 7 2 3 /3�� ✓�'/ TVD 0' 11,465' A - 028083 " t 5 � /� �/ / p `� Liner t j ,/r 7" P-110 32 ppf Two Bottom MD 11,531' 14,918' USA Angle @KOP and Depth: TVD 11,322' 14,377' Liner T ' 14,200' Date Completed: 5" P-110 18 ppf Ground Level (above MSL): 155' Tom Bottom 18' Revised By: MD 14,693' 15,655' Downhole Revision Date: 4/24/2014 TVD 14,182' 15,061' 2 3 TD PBTD 15,655' MD 15,607' MD 15,061' TVD 15,015' TVD Baker Setting Tool 1.0" rod @ 15,325'. Beaten to bottom. Max OD is 1.360" at bottom. 17' Long. E -line patch setting tool used to set Otis patch. Tag w/ 1.25" DD bailer at 15,480' SLM (11/21/13). Well Name & Number: 4 Lease: A - 028083 5 � /� �/ / p `� State/Prov: Alaska Country: USA Angle @KOP and Depth: 26° @ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0° @ 14,200' Date Completed: 8 Tagged w/ 2.70" GR @ 15,272' on 04/20/17 Ground Level (above MSL): 155' �Dr3 Q 18' Revised By: Taylor Nasse Downhole Revision Date: 4/24/2014 1 Schematic Revision Date: 6/29/2018 Tvonek Perfs: MD TVD Net Ft Zone SPF Date Status " 15,010'-15,025' 14,465'-14,478' 15' G1 -B 6 02/10/18 Open 15,015-15,030', 14,469'-14,482' 15' G-1 6 15,062'-15,072' 14,510'-14,519' 10' G1 -C 6 02/10/18 Open {?{ 15,150'-15,180' 14,589'-14,616' 30' G1 -D 6 02/09/18 Open {{{ 15,344'-15,390' 14,768'-14,811' 46' Lower G Multiple 1�.r. 15,396-15,430' 14,816-14,849' 36 Lower G Reperfs 15,450-15,508 14,868-14,923' 58' Lower G TD PBTD 15,655' MD 15,607' MD 15,061' TVD 15,015' TVD Baker Setting Tool 1.0" rod @ 15,325'. Beaten to bottom. Max OD is 1.360" at bottom. 17' Long. E -line patch setting tool used to set Otis patch. Tag w/ 1.25" DD bailer at 15,480' SLM (11/21/13). Well Name & Number: Beaver Creek Unit #5RD Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 26° @ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0° @ 14,200' Date Completed: 3/30/2014 Ground Level (above MSL): 155' 1 RKB (above GL): 18' Revised By: Taylor Nasse Downhole Revision Date: 4/24/2014 1 Schematic Revision Date: 6/29/2018 Beaver Creek BC-05RD BOP 06/29/2018 Hi" .AlaAa. IIA: • Beaver Creek Field BC #5RD Current 10/03/2017 Beaver Creek Tubing hanger, FMC-TC-lA- BC # 5RD EN -CL, 11 X 3 A EUE lift and 20 X 13 3/8 X 9 5/8 X 3 Y. susp, w/ 3" Type H profile, Y. control line port, 7.115" neck Tree cap, Otis, 3 1/8 5M FE X 6 % Otis Quick Union Valve, upper master, WKM-M, 31/85M FE, HWO, DD trim Valve, upper master, Valve, Swab, •�e� \�y,�i� 'J5 yjc��S�,6.F WKM-M, 3 1/8 SM FE, Jb 00 \�e• ,1\� 00 HWO, DD trim e�O• O Ja03 e�, yt oQ ' Q�GOa�e` Valve, upper master, WKM-M, 31/85M FE, HWO, DD trim Valve, upper master, WKM-M, 31/85M FE, HWO, DD trim ' Adapter, FMC-A5P{CL, 11 SM stdd X 3 1/8 5M, prepped for 7.115" extended neck Tubing head, FMC -TC, - - —, 135/85MX115M,w/ 2-21/165M EFO, BG bottom)''. Grade Level �p Valve, OCT -20, 2 1/16 SM FE, HWO Casing spool, OCT -22 -BP, 21 Y. 2M X 135/85M, w/ 2-2 1/16 SM SSO, Valve, OCT -20, 3 1/8 5M FE, 00 bottom prep HWO Casing head, OCT -22, 21 Y. 2M X SOW, w/Valve, OCT -20, 2 1/16 5M FE, 2-21/165M EFO r HWO Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for BC-05RD (PTD 175-055) Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date 0 U Rixse, Melvin G (DOA) From: Taylor Nasse <tnasse@hilcorp.com> Sent: Tuesday, July 10, 2018 11:53 AM To: Rixse, Melvin G (DOA) Cc: Schwartz, Guy L (DOA); Chad Helgeson; Monty Myers Subject: RE: [EXTERNAL] RE: PTD(175-055) BCU 05RD Sundry for Plug for Redrill Hi Mel - There will be a pipe ram in the upper cavity of the double ram as well as in the single ram. For pulling the 3-1/2" completion, the BOPE order from top to bottom will be: -11" annular -11" double ram fitted with: -2-7/8" x 5" VBR in upper -blind ram in lower -11" single ram with 2-7/8" x 5" VBR The VBR rams will be tested against a 3-1/2" test joint per the sundry procedure step #11. In discussing with Monty Myers, he will plan on utilizing the 2-7/8" x 5" VBR's in his BOPE configuration for the drilling, portion, as well, rather than solid pipe rams that were listed in the 10-401 Section 10.2. Thanks, Taylor From: Rixse, Melvin G (DOA) [mailto:melvin.rixse@alaska.gov] Sent: Tuesday, July 10, 2018 11:07 AM To: Taylor Nasse <tnasse@hilcorp.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Chad Helgeson <chelgeson@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD(175-055) BCU 05RD Sundry for Plug for Redrill Taylor, Per 20 AAC 25.258 (c) (2)(C) for an operation, other than a casing or liner operation, with a maximum potential surface pressure of greater than 3,000 psi, at least four preventers, including (i two equipped with pipe rams that fit the size of the drill pipe or tubing being used, except that pipe rams need not be sized to BHAs and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blind/shear rams in place of blind rams; and (iii) one annular type, and From your email below, it appears from your attachment, you are running a 4-1/2" ram in you lower ram cavity? Regulations require two pipe rams equipped with rams that fit the size of the tubing. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 1 • Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Res onsib e 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). "Suspended" Instead, check the box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 107407 for the redrill is received, the Stat Tech will Stat Tech change the original well's .status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. BCU 05RD2 Drilling Procedure 4 1 Rev 0 Ilifeurp Alaska, 11C 10.0 BOP N/U and Test IOA BOPE was NU and tested on prior decompletion sundry, We will test BOPS on 7 day cycle until the window is milled, at that point we will switch to the 14 day test cycle. Continue on to step 11. 10.2 N/U I I" x 5M BOP as follows: • BOP configuration from Top down: 11" x 5M annular BOP/l I" x 5M double rain/I I" x 5M i-nud cross/I I" x 5M single ram. • Double ram should be dressed with 4" solid ram in top cavity, blind ram in btm cavity. Single ram should be dressed with 4-1/2" solid ram. • N/U bell nipple, install flowline. 10.3 Run BOP test asst', land out test plug (if not installed previously). • Test BOP to 250/4500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! Test rams on a 4-1/2" and 4" test joint. • Ensure gas monitors are calibrated and tested in conjunction w/ ROPE. 10.4 R/D BOP test asst'. 10,5 Continue mixing mud for 5-7/8" hole section. 10.6 Set wearbushing in wellhead, Ensure ID of wearbushing > 5.875". Page 12 Revision 0 May 2018 100,000 LL V 1,000 � O O y N � U i w O 100 .Q 3 V M O H 10 HILCORP ALASKA LLC, BEAVER CK UNIT 05RD (175-055) BEAVER CREEK, BEAVER CREEK OIL Monthly Production Rates Cum. Prod Oil (bbls): 1,486,452 01 Cum. Prod Water (bbls): 19,181 Z rD Cum. Prod Gas (mcf): 612,853 100 O� o Produced Gas (MCFM) 'y°'�o y�°'y ti00o 'VOOy ti0yo ;V�yy _ GOR - o Produced Water (BOPM) - — — — - o Produced Oil (BOPM) - Q 0 SP _ MD R-0 R"08 ,5o ntv 0.10 API aw 1 aw+w, 2000 es w.,=cc 2e 6A5114A) RHOS 7VD98a RasM NPOR(NPHI) 500 95 GM= 2 0'WM moo 10 VIV--- 41D Ras °TCP(oT)�`:. OIM1M 2000 170 U&=fT 7 �s�a 5111 Snsl ®e - A% ° a 14900 .. _ e� 1 _711 ° ° 8 ° e AAF 1 iib °° ° e ° 8 �g ° °- ° ° a ° A° a At aA°'IFraQ a b° °.. ° ° e A .;..,. 15100 8... 6 pap ° ° ! e ° I ° °° p ° i �. .� 15200 t° --- --- --- - -- w _.._.w..�.._ .,.. _.... �..._. O 15300 m:& 100,000 W Mf�D N 10,000 O� 1 10 9 O 3 e -F S _ 01 1 Z rD 100 O� 10 9 O 3 e -F S SPREADSHEET Production Curve Well V103 1750550 BCU-05RD 20180706.xlsx — — — — — — — 7/6/2018 _ 1 'y°'�o y�°'y ti00o 'VOOy ti0yo ;V�yy ;�O�o SPREADSHEET Production Curve Well V103 1750550 BCU-05RD 20180706.xlsx — — — — — — — 7/6/2018 RECEIVED • STATE OF ALASKA AL OIL AND GAS CONSERVATION COMM SION FEB 2 REPORT OF SUNDRY WELL OPERATIONS 2018 1.Operations Abandon Lf Plug Perforations U Fracture Stimulate U Pull Tubing U aCfs n U Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing El Change Approved Program Cl Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 175-055 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-133-20262-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 Beaver Creek Unit(BCU)05RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beaver Creek Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,655 feet Plugs measured N/A feet true vertical 15,061 feet Junk measured 15,446&15,307(fill)feet 14,596 Effective Depth measured 15,607 feet Packer measured 14,667 feet true vertical 15,015 feet true vertical 14,089 feet 14,153 Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530 psi 520 psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090 psi 1,540 psi Intermediate 11,698' 9-5/8" 11,698' 11,465' 9,440 psi 5,300 psi Production 3,387' 7" 14,918' 14,377' 12,460 psi 10,780 psi Liner 962' 5" 15,655' 15,061' 13,940 psi 13,470 psi Perforation depth Measured depth See Attached SchematicSt True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 14,596' 14,089'TVD Baker SC-1 L Pkr; 14,596'MD 14,089'TVD Packers and SSSV(type,measured and true vertical depth) Baker SC-1 L Pkr;N/A 14,667'MD 14,153'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: 46 6 1 620 100 Subsequent to operation: 41 7 2 580 61 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data Cl 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: 317-540 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerehilcorp.com Authorized Signature: /0%/iXII(r' Date: 2/2 t:f/1 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 �j�Ji/ /l ;,2 t Submit Original Only /�' RBUI ,3 i,C., Feu ,' 2:,;18 • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-05RD E-Line 50-133-20262-01 175-055 2/9/18 Future Daily Operations: 02/09/2017- Friday Sign in. Mobe to location. PTW and JSA. Work on crane. Spot equipment. Rig up lubricator, PT to 250 psi low and 3,000 psi high.TP- 1,025 psi. RIH w/2.5" x 20' CONNEX HC, 6 spf, 60 deg phase perf gun, tie into CBL and tag fill at 15,208'. Ran correlation log and send to town. Get ok to perf the G1D zone (30' total) from 15,160'to 15, 180'. Spotted and fired gun with 1,025 psi on tubing. After 15 min TP was 1,027 psi. POOH. All shots fired. We couldn't get deep enough to perf the G1E Sand. RIH w/2.5" x 10' CONNEX HC, 6 spf, 60 deg phase perf gun and tie into CBL. Ran correlation log and send to town (top 10' of G1D sand). Down shifted log 1'. Spotted and fired gun from 15,150'to 15,160'with 1031.2 psi on tubing. After 15 min pressure was 1,032 psi. POOH and all shots fired. Rig down lubricator and secure well. Will be back in the AM to perforate last 2 zones. 02/10/2017 -Saturday Sign in. Mobe to location. PTW and JSA. Rig lub back up. PT to 250 psi low and 3,000 psi high.TP- 1,041 psi. RIH w /2.5" x 10' CONNEX HC, 6 spf, 60 deg phase perf gun and tie into CBL. Ran correlation log and send to town. Get ok to perf the G1C zone from 15,062'to 15, 072'. Spotted and fired gun with 1,044 psi on tubing. After 15 min TP was 1,045.5 psi. POOH. All shots fired. No trouble running in and out of well. RIH w/2.5" x 15' CONNEX HC, 6 spf, 60 deg phase perf gun and tie into CBL At approx 11,700'the gamma ray tool started acting funny. Tried different things and finally determined it was something in the tool. POOH and tool started working again at 11,600'. Decided to still POOH. Got out of hole. Changed CCL/GR tool and checked gun and rope socket. RIH w/2.5" x 15' CONNEX HC, 6 spf, 60 deg phase perf gun and tie into CBL. Ran correlation log and send to town. Get ok to perf the GIB zone from 15,010'to 15, 025'. Spotted and fired gun with 1,051 psi on tubing. After 15 min TP was 1,052.5 psi. POOH. All shots fired. Rig down lubricator and turn well over to production. • • i • II BC - 5RD Pad SCHEMATIC 1,195'FNL,1,495' FWL, Hilcorp Alaska,LLC Sec. 34,T7N,R10W,S.M. Permit#: 175-055 1 Conductor Casing 20" H-40 94 ppf API#: 50-133-20262-01Top Bottom Prop.Des: A-028083 J MD 0' 432' KB elevation: 173' (18'AGL) TVD 0' 432' Spud: 12/19/1975 e. TD: 15,655' 1 J � Surface Casinq Riq Released:3/23/1976 13-3/8" K-55 61 ppf -1:0 P_ Bottom k' MD 0' 3,511' J TVD 0' 3,511' Tree cap=6-1/2"Otis ',,,i r-,' ' Intermediate Casinq Gas Lift Data Ite 1 J 9-5/8" P-110 47 ppf S aI g MN1 � -lI� ir, T. T� Bottom luIor all 21.992 Latc�ldfolr aII:OBK2 TVD 0'MD 0' 1111 11,465' Depth Valve Type Port GLM J a7g 2,010 1" ress.Va ve 166/64 ; • Liner 4 82 1" ress.Va ve 6 6,54 1' ress.Va ve 16/6 3 32 ppf 8, 7 1° ress:Va ve 16% aq4 2 ..-a I k 0 --A.' 7" PTo�O Bottom � ; ;p resssyave ii,/ 4" .1. MD 11,531' 14,918' 14'432 �" fessiflcave , 4„ 9 TVD 11,322' 14,377' 66644 ii4s! -I ,`, Liner •,.3 5" P-110 18 ppf Tom Bottom Debris on casing wall iMD 14,693' 15,655' 13,073'Tag w/5.75"OD overshot(3/24/14) S 4 TVD 14,182' 15,061' 13,123'Tag w/5.50"LIB(3/28/14) Tubing J 3-1/2" L-80 9.3 ppf 8RD 3 Top Bottom I MD 0' 14,596' TVD 0' 14,089' I 4 GLV Port Temp ig " r # Size Depth TCF PSC PSO PTRO Description 6 .'' ■ 5 16 98 0.923 1036 1197 1230IPOR-1/IPOC-1/PPOR-1 �+ 16 119 0.885 1001 1140 1225 IPOR-1/IPOC-1/PPOR-1 z" - j., 7 16 137 0.855 967 1085 1220 IPOR-1/IPOC-1/PPOR-1 in rr 16 153 0.830 937 1034 1215 IPOR- ,11-1/PPOR-1 fI` 16 167 0.810 911 991 1210 IPOR-1/IPOC-1/PPOR-1 9 tit t 8 20 179 0.793 882 971 1340 IPOR-1/IPOC-1/PPOR-1 20 188 0.781 854 906 1325 IPOR-1/1POC-1/PPOR-1 '1 ` 20 194 0.773 827 858 1310 IPOR-1/IPOC-1/PPOR-1 10 ' ,. 20 197 0.769 ORIFICE-1 • si Jewelry Depth I.D. 1.Tubing Hanger (new) 21' 2.992" + Tagged w/2.70"GR @ 15,272'on 04/20/17 2.9-5/8"x7"Liner Hanger -11,698' 7 3.Chemical Injection Mandrel(New) 14,509' 2.813" e:. 4.'X'Nipple(New) 14,586' 2.813" .- 5. 5.Baker'SC-1 L'Packer&Seal bore Ext. 14,596' 4.000" 6.Baker Snap Latch Seal Assy(new;drifted to 2.80")14,595' 2.992" 1 Tvonek Perfs: 7.Otis'X'Nipple 14,627' 2.813" # ' MD TVD Net Ft Zone SPF Date Status 8.Baker'F-1'83-40 Packer&Seal bore Ext. 14,667' 4.000" .Sv - 9.Baker Tubing locator-Snap Latch Seal Assy. 14,661' 2.992" '�=vr 15,010'-15,025' 14,465'-14,478' 15' G1-B 6 02/10/18 Open 10.TIW Seal Assy.in TIW PBR&Liner Hanger 14,693' 3.000" ;'4 15,015'-15,030' 14,469'-14,482' 15' G-1 6 '- 15,062'-15,072' 14,510'-14,519' 10' G1-C 6 02/10/18 Open 11.-tirti= 15,150'-15,180' 14,589-14,616' 30' G1-D 6 02/09/18 Open 1'....".• 15,344-15,390' 14,768'-14,811' 46' Lower G Multiple 2ea-5'x 1-1/2"cutter bar .$ 15,395'-15,430' 14,816-14,849' 35' Lower G Reperfs (4/16/14). 1.......:P41: • 15,450'-15,508' 14,868-14,923' 58' Lower G Unknown depth. : tirti t 1':i, \ 1'.1' a - 4.1. ti Lost 30'tool string(2.25"bailer) p 1''i 15,244'SLM(4/21/14). Baker Setting Tool 1.0"rod @ 15,325'. Beaten to TD PBTD bottom.Max OD is 1.360"at bottom.17'Long. 15,655'MD 15,607'MD E-line patch setting tool used to set Otis patch. 15,061'TVD 15,015'TVD Tag w/1.25"DD bailer at 15,480'SLM(11/21/13). Well Name&Number: Beaver Creek Unit#5RD Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 26°@ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0°@ 14,200' Date Completed: 3/30/2014 Ground Level(above MSL): 155' RKB(above GL): 18' Revised By Donna Ambruz Downhole Revision Date: 4/24/2014 Schematic Revision Date: 2/21/2018 k05� Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 RECEIVED Tele: 907 777-8308 IIikirh Alsu+ka.l.l.t; Fax: 907 777-8510 LOGGED DATA E-mail: snolan@hilcorp.com � DEC Y�17 K BENDER DATE 12/05/2015 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 5 Prints: PERF RECORD CD: 1 DATA .,BCU-05_PERF_19NOV17 LAS.zip 11/15/20173:22 PM Compressed(zippe... 32 KB 1 BCU-05 PERF_19NOV17.pdf 11/15/2017 2:18 PM Adobe Acrobat Doc... 491 KB BCU-05 PERF_19NOV17_img.tif 11/15/2017 2:18 PM TIF File 1,525 KB SGA a 0 b 201g Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: OF to, • y/, c, THE STATE Alaska Oil and Gas of e T e cL1ZV��.1-1 Conservation Commission 1 1 ist _ 333 West Seventh Avenue 1,,W111177- ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson �� jl £ '?, Operations Manager S Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 05RD Permit to Drill Number: 175-055 Sundry Number: 317-540 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this tl day of November, 2017. R C S L�--�. ,;;' 7 2017 • • RECEIVED STATE OF ALASKA NOV 15 2tij ` ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 2 ' Other Stimulate El Pull Tubing El Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing El Other: 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 2. 175-055 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20262-01-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237B ' Beaver Creek Unit(BCU)05RD • Will planned perforations require a spacing exception? Yes ❑ No 0 - 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 . Beaver Creek/Beaver Creek Oil Pool • 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): 15,655' . 15,061' ' 15,607 15,015' —3,723 psi N/A 15,430;15,272(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530 psi 520 psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090 psi 1,540 psi Intermediate 11,698' 9-5/8" 11,698' 11,465' 9,440 psi 5,300 psi Production 3,387' 7" 14,918' 14,377 12,460 psi 10,780 psi Liner 962' 5" 15,655' 15,061' 13,940 psi 13,470 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/N-80 14,596 Packers and SSSV Type: Baker SC-1L Pkr; Packers and SSSV MD(ft)and TVD(ft): 14,596'MD-14,089'TVD; Baker SC-1L Pkr;N/A 14,667'MD-14,153'TVD; NA 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic ❑ Development Q • Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: November 27,2017 OIL ❑ • WINJ El WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned o 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com j/ierContact Phone: 777-8420 Authorized Signature: Date: I�7 � I J 5 111 4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 /7 to Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: RBDM S LL__,,, , , 7 20i7 Post Initial Injection MIT Req'd? Yes No Ei Spacing Exception Required? Yes ❑ No Subsequent Form Required: t 0 LI D f' APPROVED BY 1 Approved by: kNO0 COMMISSIONER THE COMMISSION Date: 14 t'q 1C4 �� Submit Form and:\ � Form 10-403 Revised 4/2017 Approved applicati0000i J2 nV of approval. ttachme sin Duplicate l • • Well Prognosis Well: BCU-05RD Hilcorp Alaska,LU Date: 11/14/2017 Well Name: BCU-05RD API Number: 50-133-20262-01 Current Status: Oil Producer Leg: N/A Estimated Start Date: November 29, 2017 Rig: E-line Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-055 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907)903-0341 (C) AFE Number: Maximum Expected BHP: 5,200 psi @ 14'764' TVD Static Buildup on 11/19/16 (Extrapolated) Max. Predicted Surface Pressure: - 3,723 psi (0.10 psi/ft gas gradient) Brief Well Summary Well BCU-05RD was drilled and completed as a sidetrack of the original BCU-05 in 1976. The well was fracture / stimulated in 1991 but it is believed that the sand fracture failed due to improper proppant crush resistance. The purpose of this work/sundry is to perforate additional intervals of the G-1 sand. As part of this work, Hilcorp may elect to set a retrievable plug below the G-1 sands so that these intervals can be tested separately from the lower G perforations. This plug will be removed after testing and diagnostic work is completed. �Z E-Line Procedure 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. 2. PU RIH with Gauge Ring to 15,050'. POOH. 3. PU Perf guns and RIH to 15,000'. Log on depth to perforate the following G-1 Sands: Zone Top Md Btm Md Top Btm TVD TVD G1-B 14,480 15,030 14,291 14,476 7 G1-C 15,058 15,075 14,333 14,348 - G1-D 15,150 15,183 14,417 14,447 J G1-E 15,240 15,280 14,498 14,516 4. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. 5. Fire guns. 6. POOH. 7. RD e-line. 8. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Wellhead Drawing • • BC - 5RD SCHEMATIC Pad 3 1,195' FNL, 1,495' FWL, Hilcorp Alaska,LLC Sec.34,T7N,R10W,S.M. Permit#: 175-055 + Conductor Casing 1 ' 20" H-40 94 ppf API#: 50-133-20262-01 ,=a, T� Bottom Prop.Des: A-028083 ', J t= MD 0' 432' KB elevation: 173' (18'AGL) W TVD 0' 432' Spud: 12/19/1975 ..N ' TD: 15,655' 4 1 J Surface Casing Riq Released:3/23/1976 .. 13-3/8" K-55 61 ppf T Bottom MD 0' 3,511' k J '; TVD 0' 3,511' Tree cap=6-1/2"Otis lit Intermediate Casing •Vt 9-5/8" P-110 47 ppf Gas Lift Data I J µ . Top Bottom SS� for aII g "M ndr I SAO '<, t4 MD 0' 11,698' fDor all 2:992 rag for all: Bk2 ,.s TVD 0' 11,465' Depth Valve Type Port GLM IM, J4 2,01Q ress.Va ve 16/64" 11 a 4,382 1, ress.Va ve 116g/6g4q" 2 Liner 6,543 1' ress.Va ve 16/64; 3 2 J -. 41 _ 7" P-110 32 ppf 8'199 1" ress. //22 � � 1„ ress.ya ve % $q Tom Bottom 13 Igo 1' fess Valve 2 / 4" MD 11,531' 14,918' 14,432 Orifice 20/64" 9 TVD 11,322' 14,377' J Liner 5" P-110 18 ppf Tom Bottom Debris on casing wall MD 14,693' 15,655' 13,073'Tag w/5.75"OD overshot(3/24/14) 1,i TVD 14,182' 15,061' 13,123'Tag w/5.50"LIB(3/28/14) ° Tubing J 3-1/2" L-80 9.3 ppf 8RD 3 Top Bottom MD 0' 14,596' 1 TVD 0' 14,089' a• GLV Port Temp @ =a - if Size Depth TCF PSC PSO PTRO Description 6 # 3 I 5 1 16 98 0.923 1036 1197 1230 IPOR-1/IPOC-1/PPOR-1' „y1j 3 2 16 119 0.885 1001 1140 1225 IPOR-1/IPOC-1/PPOR-1 44 7 3 16 137 0.855 967 1085 1220 IPOR-1/IPOC-1/PPOR-1 ..... ...�p4 16 153 0.830 937 1034 1215 IPOR-1/1POC-1/PPOR-1 �'(t 5 16 167 0.810 911 991 1210 IPOR-1/1POC-1/PPOR-1 9 ` r 8 6 20 179 0.793 882 971 1340 IPOR-1/1POC-1/PPOR-1 v, 7 20 188 0.781 854 906 1325 IPOR-1/IPOC-1/PPOR-1 8 20 194 0.773 827 858 1310 IPOR-1/IPOC-1/PPOR-1 10 • -`' 9 20 197 0.769 ORIFICE-1 Jewelry Depth LD. 1.Tubing Hanger (new) 21' 2.992" �, 2.9-5/8"x7"Liner Hanger -11,698' ? t ,. 3.Chemical Injection Mandrel(New) 14,509' 2.813" ki 4.'XNipple(New) 14,586' 2.813" Tagged w/2.70"GR @ 15,272'on 04/20/17 5.Baker'SC-1L'Packer&Seal bore Ext. 14,596' 4.000" '; t'. - - - --- - 6.Baker Snap Latch Seal Assy(new;drifted to 2.80")14,595' 2.992" 7.Otis'X'Nipple 14,627' 2.813" 8.Baker'F-1'83-40 Packer&Seal bore Ext. 14,667' 4.000 �` 9.Baker Tubing locator-Snap Latch Seal Assy. 14,661' 2.992" �•1 ' Tvonek Perfs: 10.TIW Seal Assy.in TIW PBR&Liner Hanger 14,693' 3.000" "'r MD TVD Net Ft Zone SPF ti 15,015'-15,030' ' 14,469'-14,482' 15' G-1 6 1Ctirti 15,344'-15,390' • 14,764-14,807' 46' Lower G Multiple r15,395.-15,430' • 14,812-14,845' 35' Lower G Reperfs 2ea-5'x 1-1/2"cutter bar64.4.::::X1. 15,450'-15,508' . 14,864-14,919' 58' Lower G (4/16/14). r j Unknown depth. �� titi I titi rel '' ti{{ tir; .i Lost 30'tool string(2.25"bailer) ,�_6 '" 15,244'SLM(4/21/14). Baker Setting Tool 1.0"rod @ 15,325'. Beaten to TD PBTD bottom.Max OD is 1.360"at bottom.17'Long. 15,655'MD 15,607'MD E-line patch setting tool used to set Otis patch. 15,061'ND 15,015'TVD Tag w/1.25"DD bailer at 15,480'SLM(11/21/13). Well Name&Number: Beaver Creek Unit#5RD Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 26°@ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0°@ 14,200' Date Completed: 3/30/2014 Ground Level(above MSL): 155' RKB(above GL): 18' Revised By: Donna Ambruz Downhole Revision Date: 4/24/2014 Schematic Revision Date: 11/15/2017 • • BC - 5RD PROPOSED .H Pad 3 SCHEMATIC 1,195' FNL, 1,495' FWL, Hilcorp Alaska,LLC Sec.34,T7N, R10W, S.M. - , Conductor Casing Permit#: 175-055 1 / 20" H-40 94 ppf API#: 50-133-20262-01 A. T g Bottom Prop.Des: A-028083 J MD 0' 432' KB elevation: 173' (18'AGL) TVD 0' 432' Spud: 12/19/1975 TD: 15,655' ' I J Surface Casing Riq Released:3/23/1976 13-3/8" K-55 61 ppf Tont Bottom MD 0' 3,511' J TVD 0' 3,511' Tree cap=6-1/2"Otis Intermediate Casinq 9-5/8" P-110 47 ppf Gas Lift Data J ti TOS Bottom gaze for aa�I 33§"M dr SAO MD 0' 11,698' ID Tor all-2:992 Lafc�1 for all: Bk2 TVD 0' 11,465' Depth Valve Type Port GLM J 2,010' 1" ress.Va ve 16/64" 1 '. 4,382' 1' ress.Va ve 16/64" 2 Liner 6 5433 1" ress.Va ve lit:, ;; 3 2 _ , 7" P-110 32 ppf ress.Vave 6g11;1 f ress Valve 4;, Tom Bottom 1 garess MD 11,531' 14,918' 14;432' 1" reesiflceVe 20/64" 9 TVD 11,322' 14,377' U J Liner 5" P-110 18 ppf Top Bottom Debris on casing wall MD 14,693' 15,655' 13,073'Tag w/5.75"OD overshot(3/24/14) k J TVD 14,182' 15,061' 13,123'Tag w/5.50"LIB(3/28/14) 'Nit" Tubin �; J 3-1/2" L-80 9.3 ppf 8RD Top Bottom 3 t ( I MD 0' 14,596' *- TVD 0' 14,089' 4 flr GLV Port Temp @ .x # Size Depth TCF PSC PSO PTRO Description 6 ,** 5 16 191800.9523 1036 1197 1230 /POR-1//POC-1/PPOR-11. t* ' 16 119 0.885 1001 1140 1225 /POR-1/1POC-i/PPOR-1 i !t i.. 16 137;0.855 967 1085 1220 IPOR-1/IPOC-1IPPOR-1 i '+t4 in;, 7 •i 16 15310.830 9371034 1215 IPOR-1//POC-1/PPOR-11 16 167 0.810 911 991 1210 IPOR-1//POC-1/PPOR-11 9 I 8 20 1790.793 882 971 1340 IPOR-1//POC-1/PPOR-1 .11( - 20 188:0.781 854 906 1325 IPOR-1//POC-1/PPOR-1 , 20 194 0.773 827 858 1310 IPOR-1//POC-1/PPOR-1 10 20 197 0.769 ORIFICE-1 -a Jewelry Depth I.D 1.Tubing Hanger (new) 21' 2.992 ,? tri Tagged w/2.70"GR @ 15,272'on 04/20/17 2.9-5/8"x7"Liner Hanger -11,698' 7 'a .. 3.Chemical Injection Mandrel(New) 14,509' 2.813 "r= 4.'X'Nipple(New) 14,586' 2.813 _ 4. 5.Baker'SC-1L'Packer&Seal bore Ext. 14,596' 4.000 6.Baker Snap Latch Seal Assy(new,drifted to 2.80")14,595' 2.992 y Tyonek Perfs: 7.Otis'X'Nipple 14,627' 2.813 8 MD TVD Net Ft Zone SPF 8.Baker'F-1'83-40 Packer&Seal bore Ext. 14,667' 4.000 " Jd. 9.Baker Tubing locator-Snap Latch Seal Assy. 14,661' 2.992 ±14,980'-±15,030' ±14,432'-±14,476' ±50' G1-B 10.TIW Seal Assy.in TIW PBR&Liner Hanger 14,693' 3.000 ` r^u ,- 15,015'-15,030' 14,469'-14,482' 15' G-1 6 ±15,058'-±15,075' ±14,433'-±14,348' ±17' G1-C ~f~ ±15,150'-±15,183' ±14,417'-±14,447 ±33' G1-D Zea-5'x 1-1/2"cutter bar ;r; ±15,240'-±15,280' ±14,498'-±14,516' ±40' G1-E (4/16/14). }- 15,344'-15,390' 14,764-14,807' 46' Lower G Multiple Unknown depth. ' ti?1 15,395-15,430' 14,812-14,845' 35' Lower G Reperfs 1r; ' 15,450'-15,508' 14,864-14,919' 58' Lower G ;.ti i, l'::: i Lost 30'tool string(2.25"bailer) 15,244'SLM(4/21/14). Baker Setting Tool 1.0"rod @ 15,325'. Beaten to TD PBTD bottom.Max OD is 1.360"at bottom.17'Long. 15,655'MD 15,607'MD E-line patch setting tool used to set Otis patch. 15,061'TVD 15,015'TVD Tag w/1.25"DD bailer at 15,480'SLM(11/21/13). Well Name&Number: Beaver Creek Unit#5RD Lease: A-028083 County or Parish: Kenai Peninsula Borough _ State/Prov: Alaska Country: USA Angle @KOP and Depth: 26°@ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0°@ 14,200' Date Completed:_ 3/30/2014 Ground Level(above MSL):_ 155' _ RKB(above GL): 18' Revised By. Donna Ambruz Downhole Revision Date: 4/24/2014 Schematic Revision Date 11/9/2017 0 0 II Beaver Creek Field BC #5RD Current 10/03/2017 Hikorp Ala.ka,i.14: Beaver Creek Tubing hanger,FMC-TC-1A- BCN5RD EN{L,11X3Y EUE lift and 20 X 133/8 X 95/8 X 3Y susp,w/3"Type H.profile,'. control line port,7.115"neck Tree cap,Otis,3 1/8 5M FE X 6':Otis Quick Union ®®ac�s�.oa aae Valve,Swab, �� e•s s. F ,e<14'�,6:F WKM-M,31/85M FE, ,1e''<;:,') QC) ,e',y\b 00 HWO, DD trim 6-1% � Jep'' et` O 15 yoQ Valve,upper master, it WKM-M,3 1/8 5M FE, HWO,DD trim Valve,upper master, �� WKM-M,3 1/8 5M FE, HWO,DD trim Adapter,FMC-A5P-CCL, - 115M stdd1 X 3 1/8 SM,prepped for =T'. ,i 7.115"extended neck Tubing head,FMC-TC, `` 13 5/8 5M X 11 5M,w/ 2-21/165M EFO,BG i b -' ottom ill II( Grade Level r 1- ---- : ,---_ E g -i-i A. i Imo; � I illP i1 ol�III�u I-i,=y Valve,OCT-20,21/165M FE, p lit HWO �'' - - \�- iti _ 11 IL .. III Casing spool,OCT-22-BP, _, ,__ 21`A2MX135/85M, '� w/2-2 1/16 5M 550, III- I i I Valve,OCT-20,3 1/8 5M FE, 00 bottom prep = - r - '_, HWO �� 1 ""'"'"°1# w«„• # ' a'` ri)li-- III iii • Casing head,OCT-22, (r 21 Y.2M X SOW,w/ Iii" I I Valve.OCT-20,2 1/16 SM FE, 2-21/16SM EFO - f Fl HWO i �1 STATE OF ALASKA D AL.OIL AND GAS CONSERVATION COMMON IVE REPORT OF SUNDRY WELL OPERATIONS NOV 16 2017 1.Operations Abandon Li Plug Perforations Lf Fracture Stimulate Li Pull Tubin s down Performed: Suspend ❑ Re-Perforate g U Li ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory Li 175-055 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic III Service ❑ 6.API Number: AK 99503 50-133-20262-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 Beaver Creek Unit(BCU)05RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beaver Creek Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,655 feet Plugs measured N/A feet true vertical 15,061 feet Junk measured 15,446&15,307(fill)feet 14,596 Effective Depth measured 15,607 feet Packer measured 14,667 feet true vertical 15,015 feet true vertical 14,089 feet 14,153 Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530 psi 520 psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090 psi 1,540 psi Intermediate 11,698' 9-5/8" 11,698' 11,465' 9,440 psi 5,300 psi Production 3,387' 7" 14,918' 14,377' 12,460 psi 10,780 psi Liner 962' 5" 15,655' 15,061' 13,940 psi 13,470 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED °A ' 0 5 .7( 1 V Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 14,596' 14,089'TVD Baker SC-1L Pkr; 14,596'MD 14,089'TVD Packers and SSSV(type,measured and true vertical depth) Baker SC-1L Pkr;N/A 14,667'MD 14,153'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: 67 45 0 600 62 Subsequent to operation: 51 8 1 780 75 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL Li Printed and Electronic Fracture Stimulation Data ❑ 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: 317-476 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager •��, ��tf Contact Email: tkramer@hilcorp.com Authorized Signature: fi. L __ C-�"•v 0/1/{Date: ' /j Contact Phone: 777-8420 Form 10-404 Revised 4/2017 ��—/ / R2O DIS ti Ufa e L 117 Submit Original Only Ie a4/7. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-05RD E-Line 50-133-20262-01 175-055 10/16/17 10/19/17 Daily Operations: 10/16/2017- Monday Arrive at PWL shop. Pickup crew and tools. Arrive at Beaver Creek. Talk with Mike about well work do permit and JSA. Rig up slickline. P/T Lub and WLV, GOOD. 1,000 PSI, GOOD. RIH w/2.73" G-ring to 15,142' KB, light set down, cont to 15,282' KB w/t sticky. POOH, drag 300 overpull to 15,250' KB came free, run back down to 15,272' KB,just stop, no set down, pickup see same overpull to about 15,250' KB. Pickup to 15,200' KB,go back down to 15,240' KB, pickup do not see overpull. Possible Reasons for overpull: there are numerous fish in the hole, could be wire. Also, tag depths are above most perfs, could be sand or possibly both. POOH, will run survey to 15,215' KB. RIH w/tandem PT gauges to 15,215' KB, doing stop then POOH, doing stops 50' below and above all mandrels. See stop sheet for detail. OOH, download gauges, Data is Good. Send to Jerry Butler. Rig down slickline. Fuel equipment, turn in permits,JSA, and sign out of field. Leave location. Arrive at PWL shop, offload tools, park equipment. 10/18/2017 -Wednesday Sign in at office. Mobe to location. PTW and JSA. Rig up lubricator. Pressure test to 250 psi low and 4,000 psi high. Shut well in. RIH w/2-1/2" x 20' (loaded w/15' perf charges) Geo HC, 6 spf, 60 deg perf gun and was having trouble going down hole. Had to work tools from 50'to 750'. Worked tools up and down. Sprayed WD-40 on line and tools went down hole better. The grease tubes had 2 runs on them so they were a snug fit on the line. After 750'tools were running in hole at 150' per min and came to a stop at 1,530'. Couldn't go up or down. Pulled safe, max pull on line at 1,650 lbs. Called town and discussed. Pumped approx. 200 gal of methanol and worked tools. Brought well back on and tools slowly came free. Started coming out of hole and check engine light came on the wireline truck. Halliburton's mechanic was on an airplane so they called Peak mechanic. POOH while waiting on mechanic. Line and tools looked ok. Decision was made to perforate in the morning after the truck is fixed. Rig off well. Start flowing well again. Mechanic showed up. Put computer diagnostic on truck and found that temp coming from turbo was outside of guidelines going back in or out of another part of the engine. They need to put truck grill cover on is one thing. Anyway we will be able to perforate tomorrow. 10/19/2017-Thursday Sign in at office. Mobe to Location. PTW and JSA. Rig up lubricator. Pressure test to 250 psi low and 4,000 psi high. Shut well in. RIH w/2.75" GR/JB to 1,560' and worked tools to 1,900'. Pulled out of hole and had paraffin in JB. Call town and discussed. Brought well on at 700K flow at 1,000 psi. RIH with same tools and worked not hard from 1,900' to 2,200' a couple times and cleared up. Went on down to 3,330' with no problem. POOH with no drag. Shut well in. RIH w/2-1/2" x 20' (loaded w/15' perf charges) Geo HC, 6 spf, 60 deg perf gun and tie into CBL log dated 1-22-76. Run correlation log and send to town. Get ok to perf from 15,015' to 15,030'. Log on depth and fired gun with 1,009 psi on tubing. After 5 min - 1,010 psi, 10 min - 1,010.5 psi and same after 15 min. POOH. All shots fired. Rig down lubricator and turn well over to field. • • • BC - 5RD Pada SCHEMATIC 1,195' FNL,1,495' FWL, Hiker')Alaska,LLC Sec.34,T7N,R1 OW,S.M. 1 # R Conductor Casing Permit#: 175-055 ;fit 20" H-40 94 ppf API#: 50-133-20262-01 ti' TOg Bottom Prop.Des: A-028083 JMD 0' 432' KB elevation: 173' (18'AGL) TVD 0' 432' Spud: 12/19/1975 gl - TD: 15,655' J 0 Surface Casing . Rig Released:3/23/1976 l. 13-3/8" K-55 61 ppf Top Bottom - 12r" MD 0' 3,511' Jr TVD 0' 3,511' Tree cap=6-1/2"Otis Intermediate Casing 9-5/8" P-110 47 ppf Gas Lift Data J Top Bottom S' a� s MMal rE � ii� t'�'' MD 0' 11,698' iu for all 21.992 Latcndiolr all:OBK2 TVD 0' 11,465' Depth Valve Type 1gPogrtt GLM ' J o 4'382; 1 ress.Va ve 16/64' 2 " Liner 6, 43 ress.Va ve6 ' 3 2 , r = 7" P-110 32 ppf 8 459' 1" ress.Va ve 6/ ' Ig l;; [ess:yave % gg Top Bottom 14 432 r ss.Va 20/ ' g MD 11,321' 14,918' 14,377' 13,7 0' 1" ren ice 20/ TVD 11,322' 3 -iiiiiiiiiiiiiiiiiill . Liner 5" P-110 18 ppf Debris on casing wall Top Bottom MD 14,693' 15,655' 13,073'Tag w/5.75"OD overshot(3/24/14) , r« TVD 14,182' 15,061' 13,123'Tag w/5.50"LIB(3/28/14) Tubing J ' 3-1/2" L-80 9.3 ppf 8RD 3 Top Bottom MD 0' 14,596' TVD 0' 14,089' 4 .o 1 ,_ GLV Port Temp @ 6 Size Depth TCF PSC PSO PTRO Description +�,I. 5 1 16 98 0.923 1036 1197 1230IPOR-1/IPOC-1/PPOR-1 6 '15,„ 2 16 119.0.885 1001 1140 1225'IPOR-1/1POC-1/PPOR-1 4.' 7 33 16 137 0.855 967 1085 1220 IPOR-1/IPOC-1/PPOR-1 c 4 16 150.830 937 1034 1215 IPOR-1/IPOC-1/PPOR-1 it 5 16 167:0.810 911 991 1210 IPOR-1/IPOC-1/PPOR-1 9 '-'1 : 8 6 20 179,0.793 882 971 1340 IPOR-1/IPOC-1/PPOR-1 7 20 188 0.781 854 906 1325 IPOR-1/IPOC-1/PPOR-1 8 20 194,0.773 827 858 1310 IPOR-1/IPOC-1/PPOR-1 10 :4 E _ 9 20 197 0.769 ORIFICE-1 Jewelry Depth I.D. 1.Tubing Hanger (new) 21' 2.992" 2.9-5/8"x7"Liner Hanger -11,698' ? 3.Chemical Injection Mandrel(New) 14,509' 2.813" .: 4.'X'Nipple(New) 14,586' 2.813" Tagged w/2.70"GR @ 15,272'on 04/20/17 5.Baker'SC-1L'Packer&Seal bore Ext. 14,596' 4.000" 6.Baker Snap Latch Seal Assy(new;drifted to 2.80")14,595' 2.992" j+ 7.Otis'X'Nipple 14,627' 2.813" , - 8.Baker'F-1'83-40 Packer&Seal bore Ext. 14,667' 4.000" ' • 9.Baker Tubing locator-Snap Latch Seal Assy. 14,661' 2.992" ' Tyonek Perfs: 10.TIW Seal Assy.in TIW PBR&Liner Hanger 14,693' 3.000" MD TVD Net Ft Zone SPF 15,015-15,030' 14,469'-14,482' 15' G-1 6 tirti 15,344'-15,390' 14,764-14,807' 46' Lower G Multiple —'11:: ,' 15,395'-15,430' 14,812-14,845' 35' Lower G Reperfs 2ea-5'x 1-1/Z'cutter bar ti.ti (4/16/14). ;f{�k 15,450'-15,508' 14,864-14,919' 58' Lower G Unknown depth. tirti R ti:{ & tif'. 1 :A ,", 5 'S tc :ie. r Lost 30'tool string(2.25"bailer) =� '' 15,244'SLM(4/21/14). Baker Setting Tool 1.0"rod @ 15,325'. Beaten to TD PBTD bottom.Max OD is 1.360"at bottom.17'Long. 15,655'MD 15,607'MD E-line patch setting tool used to set Otis patch. 15,061'TVD 15,015'TVD Tag w/1.25"DD bailer at 15,480'SLM(11/21/13). Well Name&Number: Beaver Creek Unit#5RD Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 26°@ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0°@ 14,200' Date Completed: 3/30/2014 Ground Level(above MSL): 155' RKB(above GL): 18' Revised By: Donna Ambruz Downhole Revision Date: 4/24/2014 Schematic Revision Date: 11/15/2017 8., OF T� • 4.'� I77.6, THE STATEAlaska Oil and Gas � ��, ®f Conservation Commission ==_= ALAS tst� �z _ -7.:= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF 441,AB Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson NOV 2 22017 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 05RD Permit to Drill Number: 175-055 Sundry Number: 317-476 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 04. Hollis S. French Chair DATED this t Z day of October, 2017. RBDMS ' C 11 'd 2017 f'- M, I'rt4,1:ilk STATE OF ALASKA OCT 0 5 Z �7 ALASKA OIL AND GAS CONSERVATION COMMISSION /2 / APPLICATION FOR SUNDRY APPROVALS /48/ 67 20 AAC 25.280 1.Type of Request: Abandon ❑ it Perforations ID Fracture Stimulate ID Repair Well ID Operations 1Operations shutdown Suspend t e-'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 2. 175-055 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20262-01(x'✓ 7.If perforating: 2,-.7 8.Well Name and Number: S 17 What Regulation or Conservation Order governs well spacing in this pool? CO /�/vS (7 Will planned perforations require a spacing exception? Yes IDNo ❑✓ • Beaver Creek Unit(BCU)05RD 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028083 • Beaver Creek/Beaver Creek Oil Pool 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): 15,655' r 15,061' • 15,607' 15,015' -3,723 psi N/A 15,430; 15,272(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530 psi 520 psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090 psi 1,540 psi Intermediate 11,698' 9-5/8" 11,698' 11,465' 9,440 psi 5,300 psi Production 3,387 7" 14,918' 14,377' 12,460 psi 10,780 psi Liner 962' 5" 15,655' 15,061' 13,940 psi 13,470 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/N-80 14,596 Packers and SSSV Type: Baker SC-1L Pkr; Packers and SSSV MD(ft)and TVD(ft): 14,596'MD-14,089'TVD; Baker SC-1L Pkr; N/A 14,667'MD-14,153'TVD; NA 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: CommencingOperations: October 19,2017 OIL ✓ • WINJ WDSPL P ❑ ❑ 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerOhilcoro.com Contact Phone: 777-8420 Authorized Signature: ,i�f Date: lots'/? COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3n • L )6 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ /�No Subsequent Form Required: / ` ° RBDPAS V/ UU I 1 3 2017 ---� APPROVED SI 1 Y Approved by: COMMJ,�SIQNEB. THE COMMISSION Date: d la �Z ( r —ORIGIN '° -,0 -/7 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 1 mons from the date of approval. Attachments i Duplicate • • Well Prognosis Well: BCU-05RD Hileorp Alaska,LLQ Date: 10/5/2017 Well Name: BCU-05RD API Number: 50-133-20262-01 Current Status: Oil Producer Leg: N/A Estimated Start Date: October 19, 2017 Rig: E-line Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-055 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Maximum Expected BHP: 5,200 psi @ 14'764' TVD Static Buildup on 11/19/16 (Extrapolated) Max. Predicted Surface Pressure: —3,723 psi (0.10 psi/ft gas gradient) Brief Well Summary Well BCU-05RD was drilled and completed as a sidetrack of the original BCU-05 in 1976. The well was fracture ✓ stimulated in 1991 but it is believed that the sand fracture failed due to improper proppant crush resistance. . The purpose of this work/sundry is to perforate the G-1 sand. This sand is open and is productive in the offset well BCU#4. E-Line Procedure 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. 2. PU RIH with GR to 15,050'. POOH. 3. PU Perf guns and RIH to 15,000'. Log on depth to perforate the G-1 sand from 15,015'to 1593.0'. 4. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. 5. Fire guns. 6. POOH. 7. RD e-line. 8. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Wellhead Drawing • • • • IiiBC - 5RD ACTUAL Pad3 SCHEMATIC 1,195' FNL, 1,495' FWL, Hilcorp Alaska,LLC Sec. 34,T7N,R10W,S.M. Permit#: 175-055 1 i 01 Conductor Casing20" H-40 94 ppf API#: 50-133-20262-01 i, 1* Top Bottom Prop.Des: A-028083 1_I MD 0' 432' KB elevation: 173' (18'AGL) TVD 0' 432' Spud: 12/19/1975 e I TD: 15,655' Surface Casing Rig Released:3/23/1976 13-3/8" K-55 61 ppf +� Top Bottom MD 0' 3,511' J TVD 0' 3,511' Tree cap=6-1/2"Otis ' Intermediate Casing 9-5/8" P-110 47 ppf Gas Lift aalDatgga MM . . 4 Top Bottom fD o�arll21:9925 LatchdTolr:::00K2ipirt: ,, MD 0' 11,698' Depth Valve Type GLM J TVD 0' 11,465' 22pp11op11 ' ; 4;38 �ess.Va 2 Liner g 5 ress.Va ve 2 7" P-110 32 ppf 1 r J ToP Bottom MD 11,531' 14,918' TVD 11,322' 14,377' 14 Liner 5" P-110 18 ppf Debris on casing wall ,m, To�1 Bottom 13,073'Tag w/535"OD overshot(3/24/14) 11 - tr- MD 14,693' 15,655' TVD 14,182' 15,061' 13,123'Tag w/5.50"LIB(3/28/14) ` r Tubing .' 3-1/2" L-80 9.3 ppf 8RD 3 . N, Top Bottom S'* MD 0' 14,596' •; I � °" TVD 0' 14,089' k 4 ry -! GLV Port Temp @ I # Size Depth TCF PSC PSO PTRO Description 6 5 16 98'0.923 1036 1197 1230 IPOR-1/IPOC-1/PPOR-1 s• 16 119 0.885 1001 1140 1225 IPOR-1/IPOC-1/PPOR-1 4 i 7 16 137 0.855 967 1085 1220 IPOR-1/IPOC-1/PPOR-1 et,... ,w�4 16 153 0.830 937 1034 1215 IPOR-1/IPOC-1/PPOR-1 16 167 0.810 911 991 1210 IPOR-1/1POC- 11 -1 g 8 20 179 0.793 882 971 1340 IPOR-1lIPOC-1/PPOR-1 20 188 0.781 854 906 1325 IPOR-i/IPOC-1/PPOR-1 .. ' 20 194 0.773 827 858 1310 IPOR-1/IPOC-1/PPOR-1 10 4`". !1 _ 20 197 0.769 ORIFICE-1 a "i1 Jewelry Depth I.D. 1.Tubing Hanger (new) 21' 2.992" 2.9-5/8"x7"Liner Hanger -11,698' 7 1" Ir. 3.Chemical Injection Mandrel(New) 14,509' 2.813" 0 4.'X'Nipple(New) 14,586' 2.813" Fill Tagged w/2.70"GR @ 15,272'on 04/20/17 5.Baker'SC-1L'Packer&Seal bore Ext. 14,596' 4.000" 6.Baker Snap Latch Seal Assy(new;drifted to 2.80")14,595' 2.992" r 7.Otis'X'Nipple 14,627' 2.813" , 8.Baker'F-1'83-40 Packer&Seal bore Ext. 14,667' 4.000" 9.Baker Tubing locator-Snap Latch Seal Assy. 14,661' 2.992" .' [�. •� Tyonek Perfs: 10.TIW Seal Assy.in TIW PBR&Liner Hanger 14,693' 3.000" -1�, 3 MD TVD Net Ft Zone SPF 15,344'-15,390' 14,764-14,807' 46' Lower G Multiple -0- 15,395'-15,430' 14,812-14,845' 35' Lower G Reperfs {f{ 15,450'-15,508' 14,864-14,919' 58' Lower G 2ea-5'x 1-1/2"cutter bar ' :fti : (4/16/14). ▪ ` Unknown depth. i, ti}. w .rti $, ;rti .1 Lost 30'tool string(2.25"bailer) > .7.:::▪ :. " 15,244'SLM(4/21/14). Baker Setting Tool 1.0"rod @ 15,325'. Beaten to TD PBTD bottom.Max OD is 1.360"at bottom.17'Long. 15,655'MD 15,607'MD E-line patch setting tool used to set Otis patch. 15,061'TVD 15,015'TVD Tag w/1.25"DD bailer at 15,480'SLM(11/21/13). Well Name&Number: Beaver Creek Unit#5RD Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 26°@ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0°@ 14,200' Date Completed: 3/30/2014 Ground Level(above MSL): 155' RKB(above GL): 18' Revised By: Stan Porhola Downhole Revision Date: 4/24/2014 Schematic Revision Date: 10/5/2017, • • BC - 5RD PROPOSED Pad 3 SCHEMATIC 1,195' FNL, 1,495' FWL, Hileorp Alaska,LLC Sec. 34,T7N, R10W,S.M. Permit#: 175-055 1 Conductor Casing 20" H-40 94 ppf API#: 50-133-20262-01 Top Bottom Prop.Des: A-028083 - J , MD 0' 432' KB elevation: 173' (18'AGL) r" TVD 0' 432' Spud: 12/19/1975 v TD: 15,655' lJSurface Casing Rio Released:3/23/1976 13-3/8" K-55 61 ppf Top Bottom MD 0' 3,511' r4-1:d TVD 0' 3,511' Tree cap=6-1/2"Otis Fi Intermediate Casing G 9-5/8" P-110 47 ppf GGas Lift aalDat33a MMan VI -1:)p_ Bottom lutorall"21.992� Latcildrtolrall:: BK2 MD 0' 11,698' TVD 0' 11,465' Depth Valve Type Port GLM J zz 0 ress.Va ve 111/ r �,F+ _ , Liner 4;g� "' ress.Va ve 1 / ;55 ress.Va ve / 2 7" P-110 32 ppf 77 ress.Va ve / "13RBottom I ; ess ve MD 11,531' 14,918' 1 g ress ve / 14;43 fe6nflceve 1 r. TVD 11,322' 14,377' J Liner , 5" P-110 18 ppf Tot Bottom Debris on casing wall MD 14,693' 15,655' 13,073'Tag w/5.75"OD overshot(3/24/14/ TVD 14,182' 15,061' 13,123'Tag w/5.50"LIB(3/28/14) Tubing 3-1/2" L-80 9.3 ppf 8RD 4,` y. Top , Bottom MD 0' 14,596' TVD 0' 14,089' 4 GLV Port Temp @ * ' # Size Depth TCF PSC PSO PTRO Description 6 5 1 16 98 0.923 1036 1197 1230 IPOR-1/IPOC-1/PPOR-1 ° i 2 16 119''0.885 1001 1140 1225 IPOR-1/IPOC-1/PPOR-1 y,+ 3 16 137 0.855 967 1085 1220 IPOR-1/IPOC-1/PPOR-1 44 4 16 153 0.830 937 1034 1215 IPOR-1/IPOC-1/PPOR-1 +r, 5 16 167 0.810 911 991 1210 IPOR-1/IPOC-1/PPOR-1 9 "1 . 8 6 20 179 0.793 882 971 1340 IPOR-1/IPOC-1/PPOR-1 , 7 20 188 0.781 854 906 1325 IPOR-1/IPOC-1/PPOR-1 8 20 194 0.773 827 858 1310 IPOR-1/IPOC-1/PPOR-1 10 4.6; = . • f 9 20 197 0.769 ORIFICE-1 Jewelry Depth I.D. ,iJ 1.Tubing Hanger (new) 21' 2.992" 2.9-5/8"x7"Liner Hanger -11,698' ? 3.Chemical Injection Mandrel(New) 14,509' 2.813" d. 4.'X'Nipple(New) 14,586' 2.813" Fill Tagged w/2.70"GR @ 15,272'on 04/20/17 5.Baker'SC-1L'Packer&Seal bore Ext. 14,596' 4.000" 6.Baker Snap Latch Seal Assy(new;drifted to 2.80")14,595' 2.992" 7.Otis'X'Nipple 14,627' 2.813" 8.Baker'F-1'83-40 Packer&Seal bore Ext. 14,667' 4.000" 9.Baker Tubing locator-Snap Latch Seal Assy. 14,661' 2.992" +x. Tyonek Perfs: 10.TIW Seal Assy.in TIW PBR&Liner Hanger 14,693' 3.000" MD TVD Net Ft Zone SPF r xfig=l ±15,015'-±15,030' ±14,469'-±14,482' 15' G-1 6 - tir • lig-. ig 15,344'-15,390' 14,764-14,807' 46' Lower G Multiple 2ea-5'x 1-1/2"cutter bar ti• f; 15,395-15,430' 14,812-14,845' 35' Lower G Reperfs (4/16/14). '-e{f- { 15,450'-15,508' 14,864-14,919' 58' Lower G Unknown depth. ;fti •J. 1.1 ' f,r, Lost 30'tool string(2.25"bailer) 1+t eroJI %.% 15,244'SLM(4/21/14). Baker Setting Tool 1.0"rod @ 15,325'. Beaten to TD PBTD bottom.Max OD is 1.360"at bottom.17'Long. 15,655'MD 15,607'MD E-line patch setting tool used to set Otis patch. 15,061'TVD 15,015'ND Tag w/1.25"DD bailer at 15,480'SLM(11/21/13). Well Name&Number: Beaver Creek Unit#5RD Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 26°@ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0°@ 14,200' Date Completed: 3/30/2014 Ground Level(above MSL): 155' RKB(above GL): 18' Revised By: Stan Porhola Downhole Revision Date: 4/24/2014 Schematic Revision Date: 10/5/2017 • 0 r Beaver Creek Field BC #5RD Current 10/03/2017 Hiknrp Ala.ka,I.0 Beaver Creek Tubing hanger,FMC-TC-1A- BC#5RD EN-CL,11 X 3%EUE lift and 20X133/8X95/8X3Y= susp,w/3"Type Hprofile,Y. control line port,7.115"neck Tree cap,Otis,3 1/8 5M FE X 6 Y Otis Quick Union rf ��4c' �4\ Valve,Swab, �� ,e,,,,,,,,,,,,*,,, yyjcy�S�,a.F WKM-M,3 1/8 5M FE, Al.0pN4w,\4 OC) HWO, DD trim 6"1"y�O' , O� eco O 1ti CoQ F�'0al- i, 1 0 / \= - - `''. ns la nec CI Valve,upper master, c) ., 0 WKM-M,31/8 5M FE, ,4i +' HWO,DD trim Ira::": Valve,upper master, 4116,71-7 'ill:7".:j WKM-M,3 1/8 5M FE, HWO,DD trim a , Adapter,FMC-ASP-CCL, - ""' 11 5M stdd X 3 1/8 5M,prepped for 1 ! 7.115"extended neck Tubing head,FMC-TC, - . ., 13 5/8 5M X 11 5M,w/ -- — �_ 2-2 1/16 5M EFO,BG bottom 111 ' 1 Ilii Grade Level it i w* ;ire.... ® Valve,OCT-2Q 2 1/16 5M FE, I�.. ..-,...-...",.:. i ' ' ' HWO 1!1 • .I Casing spool,OCT-22-BP, -, IL �� 21Y.2MX135/85M, �- n w/2-2 1/16 SM SSO, I1I�4 ilIli Valve,OCT-20,3 1/8 SM FE, 00 bottom prep t = - - .; HWO Mille '' i' III ... - 111 I!1 Casing head,OCT-22, lit i r 21 Y.2M X SOW,w/ i 11�` j Valve,OCT-20,2 1/16 5M FE, 2-21/165M EFO �''•. t ? HWO II STATE OF ALASKA R G�.r G'�� ` ALA.. .OIL AND GAS CONSERVATION COMM, )N REPORT OF SUNDRY WELL OPERATIONS MAY 0 G 2 2014 1.Operations Abandon U Repair Well U Plug Perforations L] Perforate U Other Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑�� y►' J' 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 ❑✓ Exploratory ❑ . 175-055 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 • 50-133-20262-01 7.Property Designation(Lease Number): 8.Well Name and Number: . FEDA028083 Beaver Creek Unit(BCU)05RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beaver Creek Oil 11.Present Well Condition Summary: Total Depth measured . 15,655 feet Plugs measured N/A feet true vertical 15,061 feet Junk measured 15,446&15,307(fill) feet 14,596 Effective Depth measured . 15,607 feet Packer measured 14,667 feet true vertical 15,015 feet true vertical 14,089 feet 14,153 Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530 psi 520 psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090 psi 1,540 psi Intermediate 11,698' 9-5/8" 11,698' 11,465' 9,440 psi 5,300 psi Production 3,387' 7" 14,918' 14,377' 12,460 psi 10,780 psi Liner 962' 5" 15,655' 15,061' 13,940 psi 13,470 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED MAY 2 7 2014 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 14,596' 14,089'ND Baker SC-1L Pkr; 14,596'MD 14,089'ND Packers and SSSV(type,measured and true vertical depth) Baker SC-1L Pkr;N/A 14,667'MD 14,153'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A RBDM*MAY 1 6 2014 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: 54 0 0 785 115 Subsequent to operation: 50 0 0 821 75 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil . ❑✓ Gas ❑ 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: 314-161 Contact Stan Porhola Email sporholaOhilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature //�) Phone 907-777-8412 Date VO VA/ licr -,z:2--1`( Form 10-404 Revised 10/2012 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-05RD 50-133-20262-01 175-055 3/21/14 3/30/14 Daily Operations: 03/21/2014-Friday RU Moncla rig 405. Winterize equipment,pump tank manifold. NU flow line to tubing. Blow well down to gas buster,work on valve for casing(will not open)had to remove flange on gas injection side. ND prod tree. NU flow cross,BOP and Hydril. Make up test subs for BOPE test,blow down casing. (Witness waived by Jim Regg,AOGCC). 03/22/2014-Saturday Test BOPE and Koomey,test all valves 250 low-3,000 high,hold for 5 mins. Pump 20 bbls 3%KCL,remove BPV. Back out, hold down pins,bleed down casing. Attempt to shoot fluid level with echometer,pump 50 bbls 3%KCL down casing. Pump 25 3%KCL bbls down tubing. Work pipe to release snap latch,pull up to 180K,work and jar pipe-no luck. Remove tubing hanger. Work pipe-no luck. MIRU Priority E-Line. RIH with tubing punch,punch hole @ 13,510'. POOH,lots of paraffin on tool. RIH with radial torch cutter on eline,can't get down pass 1,000. POOH,get stuck in paraffin, wait on hot oil unit and truck. 03/23/2014-Sunday MIRU Pollard hot oiler,pump 35 bbls of 180 degree 3%KCL. E-Line tools came free and whiplashed pulling out of rope socket. Prepping to pump 65 bbls of 180 degree KCL and fishing with slickline. Pump 65 bbls of 180 degree 3%KCL to clean tubing. MIRU Pollard slickline to fish lost E-line tools. RIH with 2.25"GR to 13,577', tag fish. POOH,RIH with a 1"JAD retrieval tool with 2.25"bonnet to 13,577'. Tag fish,latch up. POOH,have all of fish. LD fish, wait on tubing brush and TIW valve. RIH with 3.5"tubing brush,work from surface to 5,000'. Pump 30 bbls 3%KCL to flush tubing. RU E-Line,pull 10K over string weight to 141K,set in slips,lay over blocks with elevators latched. RIH with radial torch cutter and cut tubing @ 13,484'. POOH,RD E-line,PU on pipe,pipe is free,prep to LD tubing. POOH and LD 225 jts of 3-1/2"IBT tubing. 03/24/2014-Monday Finish LD all tubulars 432.5 jts. LD 14 GLM and 1 SCSSV. Prep to PU BHA and workstring change out, elevators slips roll and tally drill collars,and 1st layer of pipe. Set up pipe racks and PU machine. PU BHA, 1 overshot guide OD 5-3/4",ID 4.812", length 77". 1 hollow mill ext.OD 5-3/4",ID 3-1/2",length 1.50",overshot bowl OD 5-3/4",ID 3-1/2",length 1.54",overshot top ext OD 5-3/4",ID 4.312",length 1.95",overshot top sub 5-3/4"OD ID 3.062",FN 4.678",length 1.11",bumper sub OD 4- 3/4", ID 2-1/4", L 10.85",oil jar OD 4-3/4",ID 2-1/4",L 9.65",9 drill collars OD 4-3/4",ID 2-1/2",L 276.11",1 pump out sub OD 4-3/4",ID 1-7/8",L 1.65",1 XO. Start PU workstring 2-7/8"P110 PH6 7.9 ppf tally pipe in hole. Continue to PU workstring to jt 418 tag at 13,073',411'high,had to jar to get out of it,run back in hole and tag up same place 3 more time. POOH,LD tag jt prepare to pump down tubing. 03/25/2014-Tuesday RU to pump down tubing pump 105 bbls 3%KCL. No pressure differential. Prep to pull tubing and rack back. POOH,SB 2-7/8" PH6 workstring 417 jts,9 4-3/4"DC's. LD oil jar bumper sub and overshot. Found light gouging on outside of over shot,no marks on end of cut lip guide. MIRU Pollard slickline. RIH with 4-3/4"LIB and tag fish at 13,484'. POOH,find nice imp of fish. RIH with 5.10 LIB,tag fish,good impression. POOH,RIH with 5.78 LIB,get inside 7"casing,got sticky. RIH to 12,800',can't get any deeper. POOH,lots of drag to get in 9"on LIB. MU BHA 4-11/16"overshot,1 XO,1 bumper sub,1 oil jar,9 4-3/4"DCs,1 pump out sub,1 XO. RIH with workstring to depth of 9,000'. 03/26/2014-Wednesday Continue tripping in hole to 13,484'. Engage fish at 13,484'. 91K do wt/95K up wt. Begin working snap latch free. Worked up to 50K over up wt(145k)with jar activation. Pull up to 160K(65K over). Pipe free with drag. Pipe moving at 160K up. After+/• 30'weight fell to 110-115K. Rack 30 stands. End of fish @+/-12,800'. Break for lunch. Evaluate whether to make clean out trip. Decision made to POOH laying down singles. Gas alarms went off. Gas to surface. Shut well in via Hydril and TIW valve. Vent through gas buster. 165 joint of 2-7/8"Hydril in hole. Pump 100+bls down annulus. Well dead. Continue to pull and lay down 2-7/8"PH-6. 03/27/2014-Thursay Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-05RD 50-133-20262-01 175-055 3/21/14 3/30/14 Daily Operations: Continue to lay down 2-7/8"PH6 workstring. 4 3/4"Drill collars at rig floor. Lay down collars. Overshot at rig floor. Fish engaged in overshot. Breakout/Lay down bumper sub,jars and overshot. Begin laying down fish. Lay down 34 joints 3-1/2" production string,3 GLM,Otis X nipple,Baker snap latch seal assy. Fish out. Complete recovery. RIH 30 stands of 2-7/8"PH6 from derrick. POOH laying down same. Rig up slickline. RIH w/5.90"gauge ring. Tag at 12,782'. POOH/RIH with scratcher tool-4.50"OD. Tag at 14,546'. Several attempts to work deeper unsuccessful. POOH with scratcher. Pick up/make up 4.00" gauge ring. RIH/Tag at 14,546'. POOH,pick up/make up 2.50"bailer. RIH. 6 runs made with bailer. +/-1 gallon of substance (looks like mud)recovered each run. Bailer broke through. RIH to total depth of 15,307'with 2.50"bailer. POOH. Plan to pick up 4.00"gauge ring and brushes. RIH and clean packer bore. 03/28/2014-Friday RU to test BOPE. Test witnessed by AOGCC rep Lou Grimaldi(250 low-3000 high). Rig down from BOP test. Rig down slickline. Pollard installed gas lift valves into mandrels. Prepare to run completion. Rig up slickline sheave. Pick up snap latch seal assy. RIH with completion. Very slow running. Installing six bands per joint until we get out of the 7"liner. Completion includes Baker snap latch seal assy,1 ea.Chem injection valve and 9 ea.gas lift mandrels spaced out in hole. 03/29/2014-Saturday Continue to run 3-1/2"EU 8rd completion,includes Baker snap latch seal assy,1 ea.Chem injection valve and 9 ea.gas lift mandrels spaced out in hole. Crushed Chem injection line on joint 247. Splice line+/-3'down from coupling on jt.247. Pressure test splice. RIH,continue to RIH with completion. 400 joints in hole at 0600 hrs.+/-61 more joints to run. 03/30/2014-Sunday RIH w/3-1/2"EU 8rd completion string,includes Baker snap latch seal assy,1 ea.Chem injection valve and 9 ea.gas lift mandrels spaced out in hole. 105k up wt, 100k dn wt. Sting into packer. 96k dn wt when seals enter seal bore. Slack off and engage snap latch. Pick up to 110k to insure good latch. Slack off to 91k. Mark pipe for space out. Pick up and release snap latch at 125k(20k over). Pull seals from packer. Required 135k(30k over)to pull seals free from packer. Space out. Install hanger. Land hanger w/6k down on packer. Rig up slickline. RIH with blind box and find fluid level at 1,925'. POOH. Run plug and set plug at 14,658'per slickline counter. X nipple is at 14,590'pipe measurements. Lower X nipple is at 14,620'per historical data. RIH and set prong. Rig up to test tubing. Fill tubing 16.25 bls. Pressure test tubing to 1,500 psi f/30 minutes. Bleed off tubing. Fill casing 115bls. Work air out of casing. Gas in annulus. Getting gas back when bleeding off. Eventually obtained casing test. 1,500 psi f/30 minutes. Rig up to bleed off tubing. Bleed off tubing. Rig down slickline. Bleed off tubing. Set BPV. Rig down floor. Nipple down BOP. Nipple up tree. Terminate and test control line. Test hanger void 250 psi/10 min. 5,000 psi/15 min. Currently testing tree and prep rig and site for move to BCU-11. BC - 5RD ACTUAL Pada SCHEMATIC 1,195' FNL, 1,495' FWL, 1lilcorp Alaska,LH Sec. 34,T7N,R10W,S.M. ' - ' Conductor Casing Permit#: 175-055 1 20" H-40 94 ppf API#: 50-133-20262-01 Top Bottom Prop.Des: A-028083 J MD 0' 432' KB elevation: 173' (18'AGL) TVD 0' 432' Spud: 12/19/1975 TD: 15,655' J Surface Casing Riq Released:3/23/1976 13-3/8" K-55 61 ppf Top Bottom __ MD 0' 3,511' TVD 0' 3,511' Tree cap=6-1/2"Otis Intermediate Casing 9-5/8" P-110 47 ppf Gas Lift Data Top Bottom gg�z fora/ 3�" drelSAO-11 MD 0' 11,698' ID teor all 2.992' Latch for all: BK2 TVD 0' 11,465' 2Deeptth Valve Type Port GLM 4; 82' 1"Press.Valve 16%64 # " #2 Liner 8q Press. #g I I 7" P-110 32 ppf ,459' 1"Press.PValve 16/64" ##45 2 J Top Bottom 111,747' 1"P .Valve 20/64" #6 S*,r MD 11,531' 14,918' 12,878' 1"Press Valve 20/64" #7 TVD 11,322' 14,377' 13,730' 1"Press Valve 20/64" #8 ' 14,432' Orifice 20/64" #9 J '; Liner 5" P-110 18 ppf Tom Bottom � MD 14,693' 15,655' TVD 14,182' 15,061' ' Tubing 3-1/2" L-80 9.3 ppf 8RD • 3 Top_ Bottom MD 0' 14,596' . TVD 0' 14,089' '- 4 = GLV Port Temp @ '..I # Size Depth TCF PSC PSO PTRO Description 6 ' 5 1 16 98 0.923 1036 1197 1230 IPOR-1/1POC-1/PPOR-1 • 2 16 119 0.885 1001 1140 1225 IPOR-1/1POC-1/PPOR-1 . r 7 3 16 137.0.855 967 1085 1220 IPOR-1/1POC-1/PPOR-1 4 16 153.0.830 937 1034 1215 IPOR-1/1POC-1/PPOR-1 5 16 1671.0.810 911 991 1210 IPOR-1/1POC-1/PPOR-1 9 •I 8 6 20 179,0.793 882 971 1340 IPOR-1/1POC-1/PPOR-1 7 20 18810.781 854 906 1325 IPOR-1/.P0C-1/PPOR-1 8 20 19410.773 827 858 1310 IPOR-1/1POC-1/PPOR-1 10 _ 9 20 19710.769 ORIFICE-1 i t) ewe/ , Depth I.D. 1.Tubing Hanger (new) .- .--- 21' 2.992" Fill Tagged©15,446'on 10/16/91 2.9-5/8"x7"Liner Hanger -11,698' ? Soft fill @ 15,350'on 01/12/92 3.Chemical Injection Mandrel(New) 14,509' 2.813" Soft fill 15,342'on 4/17/13 4.'X'Nipple(New) 14,586' 2.813" @ 5.Baker'SC-1L'Packer&Seal bore Ext. 14,596' 4.000" Soft fill @ 15,307'on 3/28/14 6.Baker Snap Latch Seal Assy(new;drifted to 2.80")14,595' 2.992" 7.Otis'X'Nipple 14,627' 2.813" 8.Baker'F-1'83-40 Packer&Seal bore Ext. 14,667' 4.000" 9.Baker Tubing locator-Snap Latch Seal Assy. 14,661' 2.992" Tvonek Perfs: 10.TIW Seal Assy.in TIW PBR&Liner Hanger 14,693' 3.000" .q MD TVD Net Ft Zone SPF 15,344'-15,390' 14,764-14,807' 46' Lower G Multiple 1::::•• 15,395'-15,430' 14,812-14,845' 35' Lower G Reperfs '*~}�' 15,450'-15,508' 14,864-14,919' 58' Lower G stirt. .• r. S•1• •r• • fr• S•L• Baker Setting Tool 1.0"rod @ 15,325'. Beaten to ITD PBTD bottom.Max OD is 1.360"at bottom.17'Long. 15,655'MD 15,607'MD E-line patch setting tool used to set Otis patch. 15,061'TVD 15,015'TVD Tag w/1.25"DD bailer at 15,480'SLM(11/21/13). Well Name&Number: Beaver Creek Unit#5RD Lease: A-028083 County or Parish: Kenai Peninsula Borough _ State/Prov: Alaska Country: USA • Angle @KOP and Depth: 26°@ 14,918' Angle/Perfs: 28° Maximum Deviation: 29.0°@ 14,200' Date Completed: 3/30/2014 Ground Level(above MSL): 155' RKB(above GL): 18' Revised By: Stan Porhola Downhole Revision Date: 3/30/2014 Schematic Revision Date: 5/2/2014 Regg, James B (DOA) From: Stan Porhola [sporhola@hilcorp.com] Sent: Thursday, March 27, 2014 2:32 PM To: DOA AOGCC Prudhoe Bay Cc: Pete Solomon - (C) Subject: Reporting BOPE Use to Prevent Flow of Fluids from Well - BCU-05RD (PTD 175-055) Moncla 405 AOGCC Representatives, Per Guidance Bulletin No. 10-003, we are reporting the following use of BOPE to Prevent Flow. 1.) 3/26/2014 @ 21:30 ' 2.) BCU-05RD/Beaver Creek Field/PTD 175-055 3.) Rig: Moncla 405 4.) Contact: Pete Solomon, 318-243-6239 or 907-776-6778 5.) After running an overshot to engage cut tubing to free the snap latch out of the SC -11L packer, there was 430 joints of 2-7/8" workstring in the hole. After pulling out of hole with 165 joints remaining plus the fish (1,100' of cut tubing and snap latch), a gas bubble migrated to surface. The well was shut in with the Annular Preventer and a Floor SafeY ty Valve (TIW) stabbed onto the workstring. Gas was vented thru the choke and gas buster. A total of 140 bbl of 3% KCI was pumped. The well was monitored for 15 minutes and no gas flow was observed. Crews continued to pull out of hole. The last of the workstring and fish was laid down around 12:00 on 3/27/14. 6.) BOPE Used: Annular, Floor Safety Valve (TIW), choke manifold. 7.) Reason for use: Migrating gas bubble. 8.) Plan to rig up slickline and do intervention work. Plan to do full BOPE test on Friday 3/28/14, 1 day early of our required weekly test due on Saturday 3/29/14. BOPE test will be done before entering hole with pipe. Next run with pipe is planned to be completion string. Regards, Stan Porhola ( Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC sporholaPhilcorp.com Office: (907) 777-8412 Mobile: (907) 3:31-8228 THE STATE of,1 /'I' V GOVERNOR SEAN PARNELL Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beaver Creek Oil Pool, BCU 05RD Sundry Number: 314-161 Dear Mr. Porhola: i k-1 5- M5 � Cil.S'�:L0—,E-7V Itµ a�S,F lam' 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED thisL? day of March, 2014. Encl. Sincerely, Cathy P. Foerster c -- Chair SCANNEV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ,RECEIVED /�7M'�R 3 �120%4S 4L, AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑Z - Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 175-055 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99503 50-133-20262-01 ' 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 ❑✓ - Beaver Creek Unit (BCU) 05RD 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028083 Beaver Creek / Beaver Creek Oil Pool 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): 15,655 15,061 15,607 15,015 N/A 15,446 & 15,350 (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 432' 20" 432' 432' 1,530 psi 520 psi Surface 3,511' 13-3/8" 3,511' 3,511' 3,090 psi 1,540 psi Intermediate 11,698' 9-5/8" 11,698' 11,470' 9,440 psi 5,300 psi Production 3,387' 7" 14,918' 14,383' 12,460 psi 10,780 psi Liner 962' 5" 15,655' 15,064' 13,940 psi 13,470 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" N-80 14,666 Packers and SSSV Type: Baker SC -1 L Pkr; Packers and SSSV MD (ft) and TVD (ft): 14,596' MD - 14,094' TVD; Baker SC -1 L Pkr; N/A 14,667' MD - 14,158' TVD; NA 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ✓ Exploratory I I Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 03/20/14 Oil 0 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 s orhola hilcor .com Printed Name Stan Porhola Title Operations Engineer > / Signature �° Phone 907-777-8412 Date ) COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3aop fez 't- RBDM65�- MAY 10 1014 Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: ! AP/PROVED BY Approved by: C M I I ER THE COMMISSION a Date: �j - 7— Form 10-403 (Revised 10/2 3• AppUXLUJiJ3iA for 12 months from the date of approval. /y r( Submit Form and Attachments in Dyplicate / Hilcorp Alaska, LLI Well Prognosis Well: BCU-05RD Date:3/12/2014 Well Name: BCU-05RD API Number: 50-133-20262-01 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: March 20th, 2014 Rig: Moncla 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-055 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: — 3,750 psi @ 14,768' TVD -y 3,750 psi @ 14,768' TVD Max. Allowable Surface Pressure: — 0 psi Static fluid level at 4,350' MD/TVD Brief Well Summary (Flowing survey April 2013 top pert 15,344' MD) (Flowing survey April 2013 top pert 15,344' MD) (Based on actual reservoir conditions and min water cut of 0% (0.360psi/ft) Beaver Creek #5RD was drilled as a sidetrack of the original #5 oil well in 1976 to target the Tyonek G and Hemlock oil sands. This well was worked over in 1991 to fracture stimulate and change out the tubing string and install isolation packers in the 7" liner. A tubing patch was set across a leaking gaslift mandrel. The tubing patch was not fully set and the setting rod was lost in the well. This setting rod was beaten out of the patch and is currently a fish on the bottom of the well. The purpose of this work/sundry is to change out the tubing string to remove the unset tubing patch. y/, Notes Regarding Wellbore Condition • Last tag at 15,480' SLM on 11/21/13 w/ a 1.25" Drivedown Bailer. WO Rig Procedure: 1. MIRU Moncla #405 WO Rig. 2. Set BPV. ND Tree. 3. NU BOPE. Test to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 1,500 psi High (hold each valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance to witness. 4. Bleed any pressure off tubing. Pull BPV. 5. MU landing joint and pull 10k tension over string weight on tubing hanger. 6. MIRU E -line, PT lubricator to 3,000 psi Hi 250 Low. a. BOPE connection is 11" studded top for lubricator on top of annular. 7. RU 3.5" Tubing Jet Cutter. 8. RIH and jet cut tubing at +/- 13,500' MD. a. Have backup cutters on location if tubing does not part. b. Make cut above Tubing Patch at 13,513'. 9. RD Eline. 10. POOH and lay down 13,500' of 3-1/2" 9.2# IBT tubing. a. Lay down all gaslift mandrels (14 each) and SCSSV. 11. MU 5-3/4" overshot and jars. . H Hilcorp Alaska. LlL, Well Prognosis Well: BCU-05RD Date: 3/12/2014 12. PU +/- 13,500' of 2-7/8" 7.9# workstring. 13. RIH and engage cut tubing at 13,500'. 14. Pull snap latch out of SC -11- packer at 14,596'. a. Expect 10-20K overpull to release snap latch. 15. POOH and lay down 2-7/8" 7.9# workstring. 16. Lay down 1,095' of 3-1/2" 9.2# tubing. a. Lay down gaslift mandrels (3 each), Otis tubing patch, X -profile, and snap latch. b. Lay down overshot and jars. 17. PU completion jewelry. a. 3-1/2" 5-22 snap latch, X -Profile, and 14 new 3-1/2" 8RD gaslift mandrels. b. Will run in hole without SCSSV. 18. RIH w/ +/- 14,400' of 3-1/2" 8RD tubing, jewelry and land out in SC -1L packer 14,596'. 19. MIRU Slickline, PT lubricator to 3,000 psi Hi 250 Low. a. BOPE connection is 11" studded top for lubricator on top of annular. 20. RU 3.5" PX plug body. 21. RIH and set plug in X -profile at +/- 14,627' MD. 22. Drop prong. Test tubing to 1,500 psi for 30 min. C–A C T— 44 23. RIH and pull prong and PX plug body. 24. RD Slickline.S:- 25. Set BPV. ND BOPE. NU tree. Pull BPV. 26. RD Moncla #405 WO Rig. 27. Turn well over to production. 28. Replace IA x OA pressure gauge if removed (9-5/8" x 13-3/8"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic Hilcorp Alaska, LLC Permit #: 175-055 API #: 50-133-20262-01 Prop. Des: A-028083 KB elevation: 173' (18' AGL) Spud: 12/19/1975 TD: 15,655' Rig Released: 3/23/1976 Gas Lift Data Depth 1. D. Iz-e for T17-3.5" Mandrel for all: Daniels DSO ID for all 2.875" Latch for all: BK2 MD Depth Valve Type Port GLM 2,483' Dummy N/A #1 3,997' 1" Press. Valve 3/16" #2 5,255' 1" Press. Valve 3/16" #3 6,346' 1" Press. Valve 3/16" #4 7,337' 1" Press. Valve 3/16" #5 8,195' 1" Press. Valve 3/16" #6 8,901' 1" Press. Valve 3/16" #7 9,532' 1" Press. Valve 3/16" #8 10,125' 1" Press. Valve 1/4" #9 10,715' 1" Press Valve 1/4" #10 11,321' 1" Press Valve 1/4" #11 11,940' 1" Press. Valve 1/4" #12 12,506' 1" Press. Valve 1/4" #13 13,042' Orifice 3/8" #14 13,518' Dummy Fish #15 13,966' 1" Press. Valve 5/16" #16 14,441' Orifice 5/16" #17 All GLV's fitted w/ Tecpacxylene-resistant packing. GLM #15 (13,518') Patched. Jewelry Depth 1. D. 1. FMC 11x31/2" TC -IA -EN 3-1/2" Buttress top & 18' 2.992" bottom thread w/3" IS BPV Profile MD 0' 2. Otis 3.5" Ball Valve Landing Nipple (BV Removed) 225' 2.813 w/1/4" SS Control Line, Sliding Side Door Surface Casing 13-3/8" 3. 9-5/8"x7" Liner Hanger -11,698' ? 4. Otis Pepeata-B Tubing Patch across 13,513' 1.375" washed-out GLM #15 (Not fully set) 3,511' TVD 5. Otis'X' Nipple 14,580' 2.813" 6. Baker'SC-1 L' Packer & Seal bore Ext. 14,596' 4.000" 7. Baker Tubing locator - Snap Latch Seal Assy. 14,595' 2.992" 8.Otis'X'Nipple 14,627' 2.813" 9. Baker'SC-1 L' Packer & Seal bore Ext. 14,667' 4.000" 10. Baker Tubing locator - Snap Latch Seal Assy. 14,661' 2.992" 11. TIW Seal Assy. in TIW PBR & Liner Hanger 14,693' 3.000" BC - 5RD Pad 3 1,267' FNL, 1,465' FWL, Sec. 34, WN, R10W, S.M. m ACTUAL SCHEMATIC Conductor Casing 20" H-40 94 ppf Ton Bottom MD 0' 432' TVD 0' 432' Surface Casing 13-3/8" K-55 61 ppf 9/17/1991 TOL]_ Bottom MD 0' 3,511' TVD 0' 3,511' Intermediate Casing 9-5/8" P-110 47 ppf TOP Bottom MD 0' 11,698' TVD 0' 11,471' Liner 7" P-110 32 ppf Top Bottom MD 11,531' 14,918' TVD 11,322' 14,378' Liner 5" P-110 18 ppf i22 Bottom MD 14,693' 15,655' TVD 14,182' 15,054 Tubing 3-1/2" N-80 9.2 ppf IBT Tots Bottom MD 0' 14,596' TVD 0' 14,095' Otis patch not fully set @ 13,513'. Min ID is 1.375". Tag w/ 1.60" swedge (11/22/13). Baker Setting Tool 1.0" rod @ 15,325'. Beaten to bottom. Max OD is 1.360" at bottom. 17' Long. E -line patch setting tool used to set Otis patch. Tag w/ 1.25" DO bailer at 15,480' SLM (11/21/13). Tvonek Perfs: MD TVD Net Ft Zone SPF 15,344'-15,390' 14,768-14,811' 46' Lower G Multiple 15,395'-15,430' 14,816-14,849' 35' Lower G Reperfs ,/ R 15,450'-15,508' 14,868-14,923' 58' Lower G 'Fi 7;� Fill Tagged @ 15,446' on 10/16/91 ' Soft fill @ 15,350' on 01/12/92 Soft fill @ 15,342' on 4/17/13 TD PBTD 15,655' MD 15,607' MD 15,061' TVD 15,015' TVD Well Name & Number: Beaver Creek Unit #51RD Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country USA Angle @KOP and Depth: 26° @ 14,918' Angle/Peds: 28° Maximum Deviation: 29.0° @14,200' Date Completed: 9/17/1991 Ground Level (above MSL): 155' RKB (above GL): 18' Revised By: Stan Porhola Downhole Revision Date: 11/22/2013 Schematic Revision Date: 3/12/2014 Ilileorp Alaska. LLI. permit #: 175-055 NPI #: 50-133-20262-01 prop. Des: A-028083 (B elevation: 173' (18' AGL) Spud: 12/19/1975 rD: 15,655' Rig Released: 3/23/1976 Sas Lift Data ,¢e' e for afF7.5" Mandrel SFO -1 D for all 2.992" Latch for all: BK2 BC - 5RD Pad 3 1,267' FNL, 1,465' FWL, Sec. 34, WN, R10W, S.M. PROPOSED SCHEMATIC Conductor Casing 20" H-40 94 ppf TOP Bottom MD 0' 432' TVD 0' 432' Surface Casing 13-3/8" K-55 61 ppf 9/17/1991 TOP Bottom MD 0' 3,511' TVD 0' 3,511' Intermediate Casing 9-5/8" P-110 47 ppf TOP Bottom MD 0' 11,698' TVD 0' 11,471' Liner 7" P-110 32 ppf TOP Bottom MD 11,531' 14,918' TVD 11,322' 14,378' Liner 5" P-110 18 ppf Top Bottom MD 14,693' 15,655' TVD 14,182' 15,054 Tubing 3-1/2" N-80 9.3 ppf 8RD Top Bottom MD 0' 14,596' TVD 0' 14,095' Well Name & Number: Beaver Creek Unit #5RD Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 26° @ 14,918' 1 Angle/Perfs: 28° Maximum Deviation: 29.0° @ 14,200' Date Completed: 9/17/1991 Ground Level (above MSL): 155' 1 RKB (above GL): 18' Revised By: Stan Porhola I Downhole Revision Date: Proposed I Schematic Revision DateT 3112/2014 Beaver Creek Moncla #405 BOP 3/12/2014 7/8 -5 variables ind I Kill Updated Surface Locations, Beaver Creek Subject: Updated Surface Locations, Beaver Creek Date: Tue, 20 May 2003 11:10:32 -0800 From: "Eller, John G." <JGEller~MarathonOil.com> To: "Bob Fleckenstein (E-mail)" <bob_fl¢ckenst¢in@admin.statc.ak.us> CC: "Tank, Will" <WJTank~MarathonOil.com> t Type: Plain Text (text/plain) ~Part 1.1,1Encoding: quoted-printable 1 ofl I~BD~S BFL 5/20/2003 11:30 AM Bob - Your question regarding the surface location of well BC-6 is similar to a question that arose recently regarding well BC-3rd. In an e-mail of 4/1/03, Will Tank described.~'~' au that the surface location of BC-3 was ~':'" 'e accurately assessed in 1992 using improved surveying methods. The same e~,~,,anation applies to wells BC-6 and BC-5rd.~.. ,~r your convenience, I have tabulated below the updated surface coordinates for wells BC-3rd, BC-5rd, and BC-6. I want to emphasize that these are not new wells, but simply updated, more accurate surface locations for the old wells. Please update your files to reflect these surface locations. BC-3rd: 1227' FNL, 1501' FWL, Sec. 34, T7N, R10W, S.M. BC-5rd: 1195' FNL, 1495' FWL, Sec. 34, T7N, R10W, S.M. BC-6: 1164' FNL, 1487' FWL, Sec. 34, T7N, R10W, S.M. J. Gary Eller Operations Engineer Alaska Region, Marathon Oil Company 907-564-6315 2003 RE: Updated Surface Locations, Beaver Creek Subject: RE: Updated Surface Locations, Beaver Creek Date: Tue, 20 May 2003 14:06:03 -0800 From: "Eller, John G." <JGEller~MarathonOil.com> To: "Bob Flcckenstein" <bob_flcckenstein~admin.state.ak.us> CC: "Tank, Will" <WJTank~MarathonOil.com> Bottomhole locations: BC-3 (original hole, not the 2003 redrill): 934' FSL, 3625' FWL, Sec. 27, T7N, R10W, S.M. ~ 6387' MD BC-5rd: 723' FSI~, t195' FWL, Sec. 27, T7N, R/XI~ .... ~. g 15,~5f~~ ~ BC-6: 1803' FNL, 3390' FWL, Sec. 34, T7N, R10W, S.M. @ 15,844' MD ..... Original Message ..... From: Bob Fleckenstein [mailto:bob_fleckensteinOadmin.state.ak.us] Sent: Tuesday, May 20, 2003 11:29 AM To: Eller, John G. Subject: Re: Updated Surface Locations, Beaver Creek Gary, Please send me the revised bottom hole locations on the three wells as well. Thanks, BobF "Eller, John G." wrote: > Part 1.1 Type: Plain Text (text/plain) > Encoding: quoted-printable toll 5/20/2003 3:13 PM Alaska ;!on Domestic ~roduction Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 25, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Johnston: Enclosed is the AOGCC "Report of Sundry Well Operations" of the workover of Beaver Creek Well BC-5RD. Should you have any questions regarding the report, please contact E. V. Oberts at (907) 564-6436. Si ncerely, Operations Engineering Supervisor Attachment \docs\ml\6.doc RECEIVED MAR 2 ? 1992 Alaska Oil & Gas Cons. ~umm~,s~ Anchorage A subsidiary of USX Corporation STATE OF ALASKA 0 ~ I ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate __ Plugging Pull tubing __ Alter casing __ Repair well __ Pedorate __ Other X_~ Workover 2. Name of Operator Marathon 0i] Company 3. Address P. 0. Box 190168 Anchorage, AK 995.9 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-TN-lOW-SM At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Service 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-lOW-SM 6, Datum elevation(DForKB) 18! KB above GL z Unit or Property name Beaver Creek Unit feet 8. Well number BC 5RD 9. Permit number/approval number 91-241/?;, ,,~ 1©. APl nun~ber 50-- 133-20262-01 11. Field/Pool Beaver Creek Field 6-Zone 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 11,698' Production 3,387 ' Liner 962' Perforation depth: measured true vertical 15,655' feet 15,061' feet 15,607' feet 15,015' feet Size 9 5/8" 7" 5" Plugs (measured) None Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Junk (measured) Cemented 450 sx Lower G-Zone 15,344' - " 15,395' - " 15,450' - 3 1/2" N-80 @ 14,666' ,one RECEIVED Measured depth True vertical depth MAR 2 ? 1992 Alaska 0il & Gas Cons. Commission Anchorage 11,698' 14,918' 14,337' 15,655' 15,061' 15,390' MD 14,763' - 14,807' TVD 15,430' MD 14,812' - 14,845' TVD 15,508' MD 14,864' - 14,919' TVD tbg 13. Stimulation or cement squeeze summary Pull tubing; perforate and fracture stimulate well. Re-run new Intervals treated (measured) 15,340' - 15,410; RKB Treatment description inclui:iing volumes used and final pressure : 11 bbl fluid. 10~500 psi; Frac #2 14. ..R..epresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl w/redesigned GL .stri 61,000# Casing Pressure proppant, q95 bb Tubing Pressure Prior to well operation Subsequent to operation 135 142 0 550 145 0 0 8O0 125 120 1.5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X__ Gas__ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, l Signed ~~'~]) ~_~ TitleOperati°ns Form lO-4~/~ev 06/15/88 Engineering g. Supervisor Date ygJ'/~,z SUBMITIN DUPLICATE Attachment #1 Daily Report of Well Operations Beaver Creek Well 5RD 08/07/91 SI well. Bled tubing and casing to separator. R/U wireline and perfed tubing 14,650'-14,653. Spot frac tanks. Started filling tanks with water. 08/08/91 Filled tanks and mixed 24 KCL. Circulated KCL down tubing and up annulus, until returns of KCL cleared up. Set valve in X-nipple. Set BPV. Secured well for rig mobilization. 08/09/91 Spread pad and novethane liner. Started trucking in rig. RECeiVED 08/10/91 MAR 2 1 t99~ Spread pad and novathene liner. Continued trucking in rig~laskaOii& Gas Cons. Gommis$ion Anchorage 08/11/91 Set matting, and rig components. Scoped up derrick. Performed maintenance and misc repairs. Ran suction, steam and water lines. Performed maintenance on mud pump. 08/12/91 Finished rigging up. N/D tree and N/U BOP's. P/U rig floor. R/U floor. Accepted rig from mobilization at 900 hrs 8/11/91. Function tested BOP's from accumulator room. Changed top rams to 3-1/2". Filled pits with water. Trouble shoot remote BOP control. 08/13/91 Finished N/U BOP's and tested same. Pulled test plug and dummy ball valve. Pulled tbg hanger to rig floor. Filled hole and circulated. POOH, L/D tubing. 08/14/91 POOH L/D 3-1/2" prod. tbg, GLM's and seals. Had full recovery. M/U and RIH with retrievable bridge plug to 1000' and attempt to set same. 08/15/91 Attempted to set retrievable bridge plug w/o success. RIH w/2000' DP below storm packer and set same. N/D BOP's. Inspected tubing spool. N/U BOP's. Retrieved storm packer on third attempt. Beaver Creek Well BC-5RD Daily Report of Well Operations Page 2 08/16/91 RIH w/hyd, bailer. 08/17/91 Finished RIH with bailer. Worked bailer 15,467'-15,470' DPM (15,470'-15,474 OKB). Lost bailer action. POOH. Recovered 5 gal. sand and debris. Redressed bailer and assembly. RIH. 08/18/91 RIH with bailer. Tagged at 15,466'. Worked bailer to 15,468' DPM. POOH with wet string. No recovery in bailer. RIH with mill shoe on 2-1/16" tubing. 08/19/91 RIH with mill shoe on 2-1/16" tubing and 3-1/2" drill pipe. Attempted to reverse out fill. Attempted to circulate out fill. Cleaned pits. Filtered brine. Displaced hole with filtered brine. 08/20/91 Circulated and filtered brine, POOH L/D work string. Rack and tally 3-1/2" frac string. 08/21/91 Rack, tally, P/U and RIH with 3-1/2" frac string. 08/22/91 RECEIVED MAR ~ 7 1992, Alaska Oil & Gas Cons. 6ommisslor~ Anchorage RIH with frac string to 7357'. Test frac string to 7500 psi. RIH with frac string. 08/23/91 Finished RIH with frac string, latched into packer. Tested frachead. Made up frachead to string and tested same. R/U slick line and retrieved plug. R/U electric line and RIH with temp-GR and logged 15,444' to 14,500'. RIH with perf guns. Started taking wt. POOH. 08/24/gl POOH. Left perf guns in hole. L/D frac head. RIH with slick line and tagged guns at 664'. RIH with alligator clamp and latched onto fish. Released from packer and POOH, cutting slickline. Recovered all of guns. RIH. Stung into packer, tested backside to 1500 psi. RIH and perfed 15,360'-15,390' DIL. R/U frac head and W/O daylight. 08/25/91 Held safety meeting. Tested lines to 12,000 psi. Performed data frac - injection test, pumpin-flowback test, and calibration test. R/U electric line and RIH with temp-GR tools and logged going down 14,500' to 15,400'. Beaver Creek Well BC-5RD Daily Report of Well Operations Page 3 08/26/91 R [IVED MAR 2 7' 199~ Alaska Oil & Gas Cons. Anchorage Finished temp-GR log. R/U surface lines. Held safety meeting tested surface lines to 12,000 psi. Fraced well-screened out. Put 12,000# proppant into formation. Attempted to reverse out. POOH to 14,305'. Reversed out. RIH to top of packer reversing out sand. POOH. 08/27/91 POOH, L/D packer seals. M/U and RIH with 2-1/16" tubing and hydrostatic bailer. Bailed sand from 14,641' to 15,315'. POOH. 08/28/91 Finished POOH w/bailer. Recovered approximately 10 bbls of sand. Tested BOP's. M/U and RIH w/bailer. 08/29/91 Finished RIH with bailer on 3-1/2" drill pipe. Tagged fill 15,291'. Bailed fill 15,291'-15,456' DPM. POOH with 3-1/2" drill pipe. Recovered 4 bbl frac sand. RIH with GR tracer scan. Repair wireline depth counter. 08/30/91 POOH w/wireline. P/U "RR" nipple and anchor. Tested to 7500 psi. RIH with 3-1/2" drill pipe to 9069'. Tested drill pipe to 7500 psi. RIH and latched anchor in packer at 15,428' okb. Attempted to test drill pipe at 7500 psi leaked. 08/31/91 Tested annulus 2500 psi. Leaked up drill pipe. Attempted to release anchor. Could not rotate anchor. RIH to recover "RR" plug on wireline. No recovery. RIH with bailer - no recovery. RIH w/retrieving tool - no recovery. Latched plug w/o equalizing plug. Release POOH. Bailed w/no recovery. RIH with retrieving tool - no recovery. RIH with bailed several runs. Recovering frac sand. 09/01/91 Attempted to recover "RR" plug w/o success. Worked pipe. Rotated anchor free. POOH with wet string. Rigged up wireline for GR-tracer scan log. 09/02/91 Ran GR-tracer scan. 15-449'-14,600'. Change out logging tool. Ran GR-tracer scan 15,439'-14,600' (4 passes). RIH w/perforating gun. Perforated 6 SPF 15,375'-15,396'. RIH w/second perforating gun. 09/03/91 RIH and perforated 15,265'-15,385' at SPF. RIH and perforated 15,355'-15,375' at 6 SPF. RIH with 2-1/16" tubing on 3-1/2" drill pipe. Tagged junk at Beaver Creek Well BC-5RD Daily Report of Well Operations Page 4 15,389'. Worked junk to 15,407'. Reverse circulated. Plugged drill pipe. Circulated. 09/04/91 Circulated and filtered brine. Attempted to reverse. POOH. Pulled tight at 15,387' Worked free. Finished POOH and laid down 2-1/16" tubing. Tested BOP. Picked up anchor latch, bumper sub, MSV. Tested lines 8000 psi. Tested drill string 7500 psi. RIH with frac string. 09/05/91 RIH w/DP. Tested internally every 30 STDS to 7500 psi. Tested frac head to 12,000 psi. Stung into pkr. Tested DP to 7500 psi. Tested backside to 2500 psi. W/O daylight. 09/06/91 R/H surface lines. Held safety meeting. Performed injectivity test. Performed calibration tests. Analyze data and refined frac design. Pumped 87,000# of proppant, screened out after 61,000# proppant through perfs. Unable to reverse out. POOH, wet. 09/07/91 POOH, wet. L/D 15 jts. RIH w/7" and 9-5/8" casing scrapers. Repaired hydromatic clutch. Continued RIH. 09/08/91 RIH w/7" and 9-5/8" casing scrapers to 14,661'. Reverse circulated and filtered fluid until returns below 50 NTU. POOH. 09/09/91 Finished POOH, L/D 7" and 9-5/8" casing scrapers. P/U and RIH w/2-16" tubing and hydrostatic bailer. Bailed sand 15,041' to 15,333'. CDT-repaired broken links on drawworks chain. POOH. 09/10/91 POOH w/bailer. Recovered two barrels of sand RIH w/2-1/16" tubing, POOH L/D same. M/U 7" casing scraper and RIH with same. 09/11/91 Finished RIH w/7" scraper to top of 5" liner. Pumped 332 bbl gel sweep and displaced with filtered 2% KCL. Started POOH. 09/12/91 Finished POOH with 7'l scraper. Tested BOPE. Cleaned suction pit. CDT repaired drawworks motor. RIH with 2-1/16" tubing and bailer. RECEIVED MAR ?__ 7 1992 Alaska Oil & Gas Cons. commission Beaver Creek Well BC-5RD Daily Report of Well Operations Page 5 09/13/91 RIH with bailer. Tagged at 15,266'. Worked bailer to 15,380'. Bailer quit. POOH. Recovered 10 cu. ft frac sand. RIH with bailer. 09/14/91 Finished RIH with bailer. Bailed sand 15,368"15,402' DPM. Could not work deeper. POOH recovered 6 cu. ft. frac sand. Picked up isolation packer assembly and tested to 5000 psi. RIH with isolation assembly on 3-1/2" drill pipe. 09/15/91 Continued RIH with isolation assembly, set pkr at 14,596'. Tested to 2500 psi. POOH. L/D drill pipe. Rack and tally tubing. 09/16/91 R/U and RIH with 3-1/2" completion string. 09/17/91 Finished running 3-1/2" completion string. Started nippling down BOP's. 09/18/91 Nippled down BOP's. Nippled up tree and tested to 5000 psi. Rigged down. Waited on daylight to move rig away from well. Rig released at 03:00 hrs 9/18/91. 09/19/91 Moved rig away from well. Pulled BPV. Pulled plug in safety valve. Load out extra tubing and materials. Manifested waste. 09/20/91 Unloading well. 09/24/91 Continue unloading well at 10-30 bph. Have unloaded 1888 bbls of water, 0 bbls of oil. Have 2538 bbls of water to recover. 09/25/91 Continued unloading well. Produced in the last 24 hrs: 122 BF, 98 BW, 24 BO, 80.3% WC. Well is heading. Have 2440 barrels of load fluid to recover. 09/26/91 Running gas lift survey. No production report. RECEIVED MAR ~ 7 1992 Alaska 0il & Gas Cons. Commissior~ Anchorage Beaver Creek Well BC-5RD Daily Report of Well Operations Page 6 09/27/91 Changed GLV #9. Installed orifice in GLM #17. Put well on production. Produced 27 BO and 0 BW in 9 hours. 09/28/91 Oil BPD: 122, BWPD: 20 09/29/91 Oil BPD: 29, BWPD: 16 09/30/91 Oil BPD: 70, BWPD: 14 10/01/91 24 hour well test: 86 BOPD, 10 BWPD, 95 psi FTP, 775 psi CP. Cumulative water recovery to date: 2056 barrels. 10/02/91 24 hour well test: 121BOPD, 16 BWPD, 100 psi FTP, 700 psi CP. Cumulative water recovery to date: 2072 barrels. Total load fluid = 4460 barrels 10/03/91 24 hour well test: 157 BOPD, 22 BWPD, 115 psi FTP, 710 psi CP. Cumulative water recovery to date: 2094 barrels. Total load fluid = 4460 barrels 10/04/91 24 hour well test: 123 BOPD, 17 BWPD, 120 psi FTP, 820 psi CP. Cumulative water recovery to date: 2111 barrels. Total load fluid = 4460 barrels 10/05/91 24 hour well test: 125 BOPD, 14 BWPD, 120 psi FTP, 940 psi CP. Cumulative water recovery to date: 2125 barrels. Total load fluid = 4460 barrels 10/06/91 No test data. 120 psi FTP, 1110 psi CP. Drop well from report while performing laboratory test to determine if xylene/mutual solvent treatment is required for clean-up. Final report. 10/8-10 Gas lift line froze up. 10/10-17 Well on production. RECEIVED I , AR 7 t992 Alaska Oil & Gas Cons. Commissior~ Arichora§~ Beaver Creek Well BC-5RD Daily Report of Well Operations Page 7 10/18 First xylene squeeze - leaking check valves, treatment went into casing. 10/19-22 Well on production. 10/23-25 Gas lift compressor down, RU wireline unit. Replace leaking valve with dummy in preparation for 2nd xylene squeeze. 10/25-29 Well on production. 10/29-11/3 Second xylene squeeze - no injectivity, fill above all perforations. 11/3-6 Well on production. 11/6-7 Bailing fill w/ slickline. Slow progress w/ 2-1/4" bailer. 11/7-10 Well on production. 11/10-12/15 Gas lift compressor down. Bail remaining fill w/ slickline. Use coiled tubing to squeeze xylene and Super ASOL into formation to remove suspected asphaltene blockage. 12/15-23 Well on production. 12/23-25 Valve #1 leaking severely. Replace valve, still leaking. Dummy mandrel twice before it would hold casing pressure. 12/26-30 Well on production. 12/30-31 Gas lift compressor down. RECEIVED Alaska Oil & 6as Oons. oommissiOr~ Anchorage Beaver Creek Well BC-5RD ~Daily Repo~rt of Well Operations Page 8 12/31-1/2 Well on production. 1/2-6 Could not lift below valve #15. Attempt to pull valve, was cut in half. Attempt to drive bottom half out of pocket. No success. Set dummy. 1/6-10 Well on production. 1/10-12 Successfully beat cut valve out of pocket. Replace all remaining valves #2-14. Kick off well. 1/12-2/12 Well in test pending further action. 2/13 Well turned over to production. \bc~bc5rd.doc RECEIVED Alaska Oil & Gas Cons. bummission Anchorage V/ELL, BCU-5RD Spud Dcte~ 12/75 Original RKO: 173' AnnuLus FLuid', LiFt Gas, KCL ReFerence Log'. DIL oF 1-17-76 depths cite RKO MD to aC equipment, HARATHON OIL COHPAI BEAVER CREEK UNIT API fi: 50-133-20E62-01 CompLetion D~te~ 2-20-76/ 9-17-91 Maximum Hate AngLe: 2B°~ 1t,400' AngLe Through PerFs: 18° JEV/ELRY O±is 3.5' BaLL Vc~Lve Landing NippLe (BY Removed) W/ 1/4· SS Control Line, St;ding Side Door Otls 'X' NippLe Baker Tubing Locator - Snap Latch Seal Assy. Baker 'SC-1L' Packer & Seat Bore Ext. Otis 'X' NippLe Baker Tubing Locotor - Snap Latch Seal Assy. Baker F-1 Packer & Seat Bore Ext. TI~/ Sea[ Assy. in TI~/ PBR & Liner Hanger ~/ett Type: Producer' New [] Redrlt( [] Workover [] Recompletlon [] DEPTH [. D.._= 225' 8.813' 14,580' 8.813' 14,595' 2.998' 14,596' 4.00' 14,627' 2.813' 14,661' 2.998" 14,667' 4.00' 14,693' 3.00' CASING & TUBING Size Weight Gr'ode Top 3ottom 9-5/8' 47# P-ilO SurFace !1,698' 7' 38# P-llO 11,531' i4,918' 5' 18ff P-11O 14,693' 15,655' 3-~/8' 9.8~ N-80 Sur¢~ce ~4,666' Descript.. Intermediate Originol BE-5 Liner BC-SRD L;ner Buttress Tbg. GAS LIFT DATA Depth Size 1 2,483' 3.5- 2 3,997' 3 5,855' 4 6,346' ' 5 7,337' ' S 8,195' 7 8,901' 8 9,532' 9 10,125' 10 10,715' 11 11,381' 12 11,940' 13 12,506' 14 13,048' 15 13,518' 16 13,966' 17 14,441' Handrel DanieLs DSO 2.B75' · · · Vo, Lve Type Dummy I' Press, Vo. tve OriFice Lctch Por,t 3/16' · 1/4· 5/16· 5/16' · RECEIVED Alaska Oil & Gas O0ns, u0mmis', Anchorage z PERFORATION DATA Int~rv(iL Zon~ F~T 15,344' - 15,390' Lower G 46' 15,395' - 15,430' 35' 15,450' - 15,508' 58' SPF Date Gun Type MULTIPLE Through- Tubing REPERFS FiLL Taggecl 8 15,446' on 10/16/91 (SoFt PiLL I~ 15,350' on 1118/98) PBTD 15,607' TD !5,655' DATUM, Revision Date: 3/11/92 Revised By: TAM/tam Re~son: Changeout GLV's ~2 - 15 Previous Revision: 1/8/98 Marathon Oil Company Alaska F n Domestic r roduction P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 August 7, 1991 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Johnston: Attached for your approval is an "Application for Sundry Approvals" with a revised procedure for a Sundry Application that was previously approved (#91-176) for Beaver Creek Well #5RD. Should you have any questions regarding any application or report, please contact E. V. Oberts at (907) 564-6436. Sincer~~ .~C.(ibele Operations £ngineerin9 Supervisor Attachment em\docs\mi\6 R CEIVED AUG 1 2 1991 Alasl~a Oil & Gas Cons. Commissien ~chorage A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program ~ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Pull tubing __ Variance __ Perforate __ Other ~,.-V i S e d 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 995 9 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-lOW-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-lOW-SM workover/ 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 18' KB above GL 7. Unit or Property name Beaver Creek Unit 8. Well number BC 5RD 9. Permit number .. 10. APl number 5o- 133-20262-01 feet 11. Field/Pool Beaver Creek Field G-Zone 12. Present well condition summary Total depth: measu red true vertical 15,655' 15,061' Effective depth: measured 15,607 ' true vertical 15,015' Casing Length Structural Conductor Surface Intermediate 11,698' Production 3,387 ' Liner 962' Perforation depth: measured true vertical Size 5/8" 7" 5" feet feet feet feet Plugs(measured) None RECEIVED Junk(measured) None AUG 1 2 1991 Cemented Measured de pth~la$~l ~jl ~LCi~ir~l~misS 'Anchorage 450 sx 11,698' 14,918' 14,337' 15,655' 15,061' Lower G-Zone 15,344' - 15,390' MD 14,763' " 15,395' - 15,430' MD 14,812' " 15,450' - 15,508' MD 14,864' - 14,807' TVD - 14,845' TVD - 14,919' TVD Tubing (size, grade, and measured depth) 3 1/2" N-80 e 14,678' Packers and SSSV (type and measured depth) Baker F-1 pkr @ 14,678' 13. Attachments Description summary of proposal __ Detailed operations program BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: August 7, 1991 16 If proposal was verbally approved Oil ~ Gas ~ Suspended Name of approver Date approved Service 17. I hereby certify~ the forc~sting..is~X¢,~ ~d correct to the best of my knowledge. Signed ~~])~ Title Operations Engineering Superv. Date v - ~/ 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 Commission ORIGINAL SIGNED RUSSELL A. DOUGLA~I~ ., Form 10-403 Rev 06/15/88 Approved Copy ]Approval No¢ / Commissioner frac ~n Attachment #1 BEAVER CREEK WELL BC-5RD Revised Procedure for Workover/Frac 1. Shut in gas lift and allow well to die. RU E-line and perforate circulation holes in tubing above packer. RD E-line. 2. RU pumping unit and circulate 24 KC1 kill fluid to surface. RD pumping unit. 3. RU slickline and set dummy ball valve in X profile ~ 244'. Set BPV. 4. Move in rig over Well BC-5RD. ND tree. NU and test BOPE. 5. Pull 3-1/2" completion, keeping hole full of 24 KCl, 6. RIH w/ work string and 2-1/16" stinger through F-1 packer. Clean out fill to PBTD. Filter fluids while circulating hole clean. POH. 7. RIH with anchor seal assembly on frac string and sting into packer. 8. RU E-line unit. Record temperature log and base GR pass (run through frac string). Reperforate Lower G-Zone w/ 4 SPF, 90 degree phased through-tubing guns. RD E-line. 9. RU frac equipment. Perform datafrac, tagging fluid with Scandium. RU E~line to run another GR and temperature pass. RD E-line. 10. Modify frac design based on datafrac results. 11. Fracture treat Lower G-Zone, tagging proppant w/ Au 198 (2.7 day half-life). RD pumping equipment. 12. POH with frac string. 13. RIH with stinger on work string. Clean out hole to PBTD. POH. 14. RU E-line and run after-frac spectral GR pass. RD E-line. 15. PU and run redesigned 3-1/2" gas lift string and locator seal assembly. Space out and land tubing. 16. ND BOPE. NU and test tree. 17. Unload well and return to production. Test well until stabilized rate is obtained. \docs\BC\BC5rd. doc RECEIVED AUG 1 2 ~99! Oil & Gas Cons. gommissten Rn~:t~orage Attachmen~ #2 C L .~ELL, BCU-5RD Spud Da~e, 18/75 Original RKB: 173' AnnuLus FLu;d, LiFt G&s, Bit Eere~ence Log~ D[L o~ t-[7-76 MARATHON OIL CDMPANY TRAD[N~ BAY UNIT _ APl fl, 50-t33-2026P-Ot CompLetion Date, 2-20-76 Max;mum HoLe AngLe. 88° 8 1L400' AngLe Through PerFs, 18° WeLt Type: Producer New [] Redrit[ [] Vorkover [] RecoMptetion [] ALt depths are RKB MI) to top o¢ equipment. JEWELRY Fl'tis 3.S' Bc~IL V(xlve (ReMoved) B(ikem- HodeL °L° SLiding St,eve' Baker Model 'O' Seo( Assy. In B~ke~ F-t P~cke~ Hu[e ~hoe TI~ PBR ond Llne~ H~nge~ w/ TIW Se~t Assy. DEPTH 8.75' 244' 8.87' 14,674' 3.00' 14,677' 3.00· 14,678' 8.992° 14,698' 4.89' 14,693' GAS LIFT DATA Death Size Mandrel ID 3,151' 3.5' CAMCO MMG 8.875 4,567' ' ' ° 5,845' ' 7,049' 8,156' 9,147' 10.076' 10,974' 11,499' ' ' ° 1~8t9' · USI-CF-2 S/S Conven'tlOna[ 3.00 I~,799' 13,260' ' 13~639' ° ° · 14·863' · · · CASING L TUBING Size Welght: Grade 9-5/g' 47t P-IlO 7' 3~1t P-IlO $' 18# P-IlO 3-1/2' 9.2# N-GO -. Too BOt:~OM Descript. Surface 11,698' 11~531' 14,9t8' Dr~cJIna[ BC-5 Liner 14,693' 15,655' BC-5RD Liner PERFORATION. DATA Interval Zone FT 15,344' - l:L3cJiY Lo~,ee G 46' SPF ~ (Sun Type MUL?IPL£ lhrouoh-Tub~g 15,395' - 15.430' · t~4:~r - 15,5o~ · Flit T,gged 8 15,416' o~ 4/10/91 · · PBT]] 15,607' TO 15,655' REP£RFS DATU~ Revision Date, Rev;sed By, Rea$onm .,RECEIVED AUG 12 t99! Alaska 011 & Gas Cons. Commissien S/9/m Anchorage TAH/evo Replace GLO t9 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 __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Pedorate __ Other ~__Workover 2. Name of Operator ~ 5. Type of Well: 6. Datum elevation (DF or KB) Marathon 0il Company I Developmentx 18' KB above GL Exploratory __ Stratigrapnic __ 7. Unit or Property name 995 9 Service__ Beaver Creek Unit 3. Address P. 0. Box 190168 Anchorage, AK 4. Location of well at sudace 1,267' FNL, 1,465' FWL, Sec. 34-TN-10W-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-TN-10W-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-TN-10W-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-TN-10W-SM 8. Well number BC 5RD 9. Permit number 75-55 10. APl number 5o- 133-20262-0! feet 11. Field/Pool Beaver Creek Field G-Zone 12. Present well condition summary Total deptm measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Sudace Intermediate 11,698' Production 3,387 ' Liner 962 ' Perforation depth: measured true vertical 15,655 ' feet Plugs (measured) 15,061' feet 15,607 ' feet Junk(measured) 15,015' feet Size Cemented 5/8" ?" 5" 450 sx Lower G-Zone 15,344' - " 15,395' - " 15,450' - None None Measured depth , .- r, .... Truevert~caldepih; ~, 11,698' 14,918' 14,337' 15,655' 15,061' 15,390' MD 14,763' 15,430' MD 14,812' 15,508' MD 14,864' - 14,807' TVD - 14,845' TVD - 14,919' TVD Tubing (size, grade, and measured depth) 3 1/2" N-80 8 Packers and SSSV (type and measured depth)Baker F- l pkr 13. Attachments # 1 ~i Description summary of proposal ---x 2 14. Estimated date for commencing operation × July 15, 1991 16. If proposal was verbally approved Name of approver Date approved RECEIVED ¢ 14,678' Detailed operatio~ratn2_~99J BOP~ R ~.C E jV l--D 15 Statu~ u Anchorage · . Oil ~ Gas ~ Suspended Opor'ations Eng. Service .Signed Title Operations .Engineering Superv. 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. 1(o ~/L Approved by order of the Commission Form 10-403 Rev 06/15/88 J Approval No. · Commissioner Date SUBMIT IN TRIPLICATE Marathon Oil Company Alaska i ~n Domestic r-roduction P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 13, 1991 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Johnston: Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well #5RD. Should you have any questions regarding any application or report, please contact E. V. Oberts at (907) 564-6436. Since~y~ .~C. 'Ibele Operations Engineering Supervisor Attachment em\docs\m1\6 A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Alter casing __ Repair well __ Change approved program __ 2. Name of Operator Marathon Oil Company Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Putltubing ~ Variance __ Pedorate j Other ~..~_Workover 3. Address ~ P. O. Box 190168 Anchorage, AK 995 9 J5. Type of Welt: Development X Exploratory __ Stratigraphic __ Service __ 4. Location of ~ell at surface 1,267 FNL, 1,465' At top of productive interval FWL, Sec. 34-7N-lOW-SM 6. Datum elevation (DF or KB) 18' KB above GL 7. Unit or Propedy name Beaver Creek Unit 8. Well number BC 5RD feet 9. Permit number 75-55 10. APl number 5o- 133-20262-01 11. Field/Pool Beaver Creek Field G-Zone 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-tOW-SM 12. Present well condition summary Total depth: measured true vertical 15,655' feet 15,061' feet Plugs (measured) Effective depth: measured 15,607 ' true vertical 15,015' Casing Length Structural Conductor Surface Intermediate 11,698' Production 3,387 ' Liner 962' Perforation depth: measured feet Junk (measured) feet Size Cemented 9 5/8" 7" 5" 450 sx true vertical Lower G-Zone 15,344' - " 15,395' - " 15,450' - Measured depth , ~ TrUevertibaldepth'-: 11,698' 14,918' 14,337' 15,655' 15,061' 15,390' MD 15,430' MD 15,508' MD 14,763' 14,812' 14,864' - 14,807' TVD - 14,845' TVD - 14,919' TVD Tubing (size, grade, and measured depth) 3 1/2" N-80 Ca 14,678' Packers and SSSV (type and measured depth)Baker F- 1 pkr Ca 14,678' 13. Attachments # 1 & Description summary of proposal 2 Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation ~ July 15, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil.z: Gas__ Suspended__ Service 17. I hereby certify th'~,t the foregoin,,~ is]cue and correct to the best of my knowledge. // ~', ~/. ~~ Title Operations Engineering Superv. Date Signed ~m /,~..~ ,,,~-~ , FOR COMMISSION USEONLY Conditions of approval: Notify Commission sq representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test __ / Subsequent form required 10- /¢C~ ~ Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE Attachment #1 BEAVER CREEK WELL BC-5RD Procedure for Workover/Frac 1. Move in rig over Well BC-5RD. 2. Kill well. Fill tubing and annulus with reservoir-compatible kill fluid. 3. ~erify that well is dead. ND tree. NU and test BOPE. 4. Pull 3-1/2" completion. Mill F-1 packer. Make bit and scraper run; clean out fill to 15,520'. Filter fluids and circulate hole clean. 5. Reperforate Lower-G with 12 SPF0 60 degree phased TCP guns. 6. RIH with treating packer to about 15,000' and RU frac equipment. Record temperature log and base GR pass. Perform step-rate test and datafrac, tagging fluid with scandium. Run another GR and temperature pass. 7. Modify frac design based on datafrac results. 8. Fracture treat Lower G-Zone. RD pumping equipment. 9. POOH with frac string. 10. RIH with bit and scraper. Clean out hole to 15,520'. 11. RU E-line and run after-frac GR pass. RD E-line. 12. RIH with permanent packer/seal assembly and set at 14,678'. 13. PU and run redesigned 3-1/2" gas lift string. 14. ND BOPE. NU and test tree. 15. Unload well and return to production. Test well until stabilized rate is obtained. \docs\BC\BC5rd.doc Attachment #2 ..... MARATHDN OIL COMPANY TRADING BAY UNIT WELL, BCU-5RD Spud Dance, 12/75 Orlginot RKB: 173' Annutu~ Fluid, LiF't; G(ls, ReFerence Log, DIL oF 1-17-76 API fi, 50-133-20262-01 Compl, etlon Dote, 2-20-76 M~xlmum Hole AngLe, 28° ~ 1L400' Angle Through PerFs, 18° Welt Type: Producer New [] Redrltt [] Workover [] Recompletion [] Alt depths ~xre RKI~ MD ~:o ~cop o? equlpmen-~. JEWELRY I'l~ls 3.5' Bc~tt V~tve (ReMoved) ]~6ker Hodet 'L' Sliding Sleeve' B(~ker Model 'O' Se(it Assy. In Bc~ker F-I Pc~cker Mule Shoe TIW PBR oncl L:ner Hcmger w/ TIW Se(il A$$y. DEPTH 2.75' 244' 2.87' 14,674' 3.00' 14,677' 3.00' 14,678' 2.992' 14,698' 4.29' 14,693' GAS LIFT DATA Depth Size Mcndrel ID 3,t5t' 3.5' C~mco MM6 i~.875 4,567' ' ' ' 5,845' ' ' ' 7,049' ' ' ' 8,156' ' ' ' 9,[47' ' ' ' 10,076' ' ° ' 10,974' ' ' ' 11,499' 1~2t9' , USI-CF-~ S/S 3.00 Conven-tlomlt 1P~799' ' ' · 13,260' ' ' · 13,639' ' 13,980' ' 14,263' ' ' ' Valve Type, Latch Port McMurrmy VR-STD-D RK 3/16' 1.5' WL Re~rlevoble · · · · C~nco R-20 1.5' · - McMurr~y VR-STD-D · · 1.5' VL Retrievable 1.5· Dummy ~ -- 1.5· Or~cz ' 5/16' H~cco CH~ Pressure V~ivz - 5/16' CASING & TUBING Size Weight Grcide 9-5/8' 47# P-llO 7' 3;2# P-110 5' 18# P-IlO 3-1/E' 9.;~# N-80 Too Bottom Descmip% SurFace 11,698' 11,531' 14,918' Original BC-5 Liner 14,693' 1~G55' ~C-5RD Liner Sur?~ce 14,698' Dut~e~s PERFDRAT]DN DATA ~[nterv~t Zone. Fl' 15,344' - 15,390' Lower O 46' 15,395' - 15,430' ' 35' 15,450' - 15,508' ' 58' , · Fltt T~ooed @ 15,416' on 4/10/91 DATUM: P3T]] 15,607' TD 15,655' Revision D~e, Revised By, Reason, SPF Dote Gun Type MULTIPLE Throuoh-Tub~o REPERFS 5/9/91 TAM/evo Reptoce GLO #9 Marathon Oil Company Alaska. . ~gion Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 21, 1990 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" canceling work on Beaver Creek Well #5RD. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, T. J. Kovacevich District Operations Engineer Attachment ~docs\ml\6.doc A subsidiary of USX Corporation AEASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS IGINAL 1. Operations performed: Operation shutdown -- Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator I 5. Type of Well: I Marathon. Oil Company 3, Address t P. 0. Box 190168 Anchorage, AK 995 9 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-TN-10W-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-lOW-SM Perforate __ OtherX__Notice of Cancel l Development X__ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) 18' KB above 7. Unit or Property name Beaver Creek Unit 8. Well number BC 5RD 9. Permit number/approval number 9-~0'~ 10. APl number 50- 133-20262-01 feet 11. Field/Pool Beaver Creek Field G-Zone 12. Present well condition summary Total depth: measured true vertical Effec!ive depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 11,698' Production 3,387 ' Liner 962' Perforation depth: measured true vertical 15,655' feet 15,061' feet 15,607' feet feet 15,015' Size 9 5/8" 7" 5" Lower II Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3 1/2" Rai~er 13. Stimulation or cement squeeze summary Intervals treated (measured) Plugs (measured) Junk (measured) Cemented None None Measured depth G-Zone 450 sx 15,344' - 15,395' - 15,450' - 11,698' 14,918' 15,655' 15,390' MD 15,430' MD 15,508' MD N-80 @ 14,678' F-1 pier fa True vertical depth 14,763' 14,812' 14,864' 14,337' 15,061' - 14,807' TVD - 14,845' TVD - 14,919' TVD Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil _~ Gas m Suspended Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ /~~~ ~,/?~/.A,-g¢¢Title District Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE .tion Marathon Oil Company Alaska ion _ Domes~,,, Production0 R P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 September 8, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Beaver Creek Well #5RD. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment em\docs\m1\6 Anchorage A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI5510N APPLICATION FOR SUNDRY APPROVALS OR IG IN A 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 995 9 Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate X Pull tubing __ Variance __ Perforate __ Other __ 5. Type of Well: Development Exploratory Stratigraphic Service Loc io ell urfa e 4. a~,~8~ ieJq~, ~,465' FWL, Sec. 34-7N-lOW-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM Att°~q~c~qpthCSL, 2,099' FEL, Sec. 27-7N-lOW-SM 6. Datum elevation (DF or KB) 18' KB above GL feet 7. Unit or Property name Beaver Creek Unit ~cVV~l~mber 9. Permit number 75-55 10. APl number 5o- 133-20262-01 11. Field/Pool, , ueaver creek Fi eld 6-Zone 12. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Length Structural Conductor Surface Intermediate 11,698' Production 3,387 ' 962' Liner Perforation depth: measured true vertical 15,655' feet Plugs (measured) 15,061' feet 15,607 ' feet Junk (measured) 15,015' feet Size Cemented 9 5/8" 7" 5" 450 sx None RECEIVED None S EP 1 1 _989 Alaska Oil & Gas Cons, Commissiol Measured depth Tr ~l~l~f8~ledepth 11,698' 14,918' 14,337' 15,655' 15,061' Lower G-Zone 15,344' - 15,390' MD 14,763' " 15,395' - 15,430' MD 14,812' " 15,450' - 15,508' MD 14,864' - 14,807' TVD - 14,845' TVD - 14,919' TVD Tubing (size, grade, and measured depth) 3 1/2" N-80 @ 14,678' Packers and SSSV (type an d m easu red depth)B a k e r F- 1 p k r ~ 14,678 ' 13. Attachments I & 2 Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation September 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ___X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DlStrlct Operatl Signed Z~,,~,~ Title ons Engineer ...~" ? ~' 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- /2¢'4' Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Date JApproval No. Commissioner Approved Copy Returned Date (-~'_ f/'~ ,,, Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 AFE 8139-9 Beaver Creek Well #5 Asphaltene Cleanout and Xylene Squeeze Procedure 1. Obtain fluid sample for analysis. 2. RU 1.25" coiled tubing and pump truck to BC-5RD. PT equipment to 4500 psig. 3. RU Hydroblaster wash tool on coiled tubing. RIH w/ CT to 15,430' CTM while gas lifting well. CHECK PICK-UP WEIGHT EVERY 500' NEAR TD. 4. Jet casing with xylene at as high a pump rate as possible (2 BPM). Wash while moving CT uphole to 15,300' CTM. Repeat until xylene volume of 1500 gals is depleted. Pull uphole with CT to 12,000'. 5. Shut off gas lift and allow well to die. 6. RIH with CT to 15,400' CTM. Fill tubing with lease crude (60 bbls). 7. Squeeze 1500 gals xylene into formation while moving CT up and down perf interval. NOTE: MONITOR CASING PRESSURE MAX TUBING PRESSURE = 3000 psi 8. POH w/ CT, displace coil with lease crude. 9. Allow xylene to soak for 12 hours. 10. Bring well on production and test. 11. Obtain second fluid sample after unloading for 12 hours. \docs\afe\23.doc Attachment #2 Coiled Tubing BEAVER CREEK Lubricator w/Associated BOPE Double BOP w/1 1/4' Rams 5000 psi WP Tree Cap Swab Valve Hydraulic Rams ./~ 2' Wing Valve ,-~ ,~ ~ 1~C~(~(ii Alaska Oil & Gas Cons,, Commission Anchorage Maeter Valve~ 4 1/2' 5000 psi Christmas Tree Seal Flange Marathon Oil Company Alaska. ~ion DomesUc Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 July 5, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with appropriate attachments for Beaver Creek Well #BC-5RD. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, District Operations Engineer Attachment ~docs~l~6.doc A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging __ PerforateX_._ Pull tubing __ Alter casing __ Repair well __ Other 2. Name of Operator ~ 5. Type of Well: Marathon Oi 1 Company Development~ Exploratory __ 3. Address Stratigraphic __ P. 0. Box 190168 Anchorage, AK 995 9 Service__ L°ca~n2¢t~/gll~l~lac~,465' FWL, Sec. 34-TN-10W-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM Att°t~l~thFsL, 2,099' FEL, Sec. 27-7N-lOW-SM 6. Datum elevation (DF or KB) 18' KB above GL feet ¢.eU nit or Pr,,opertyn~one. aver breeK unit ¢cW~l~r~mber 9. Permit number/approval number 9-523 10. APl number 5o- 133-20239-01 1;L Field/Pod t~eaver t. reek Field G-Zone 12. Present well condition sUmmary Total depth: measured true vertical 15,655' 15,061' Effective depth: measured 15,6 0 7 ' true vertical 15,015 ' Casing Length Structural Conductor Surface Intermediate 11,698' Production 3,387 ' Liner 962 ' Perforation depth: measured true vertical Size 9 5/8" 7" 5" feet Plugs (measured) feet feet Junk (measured) feet Cemented None None 450 sx Measured depth Lower G-Zone 15,344' - " 15,395' - " 15,450' - 11,698' 14,918' 15,655' 15,390' MD 15,430' MD 15,508' MD 14,763' 14,812' 14,864' True vertical depth 14,337' 15,061' - 14,807' TVD - 14,845' TVD - 14,919' TVD Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3 1/2" N-80 @ 14,678' Baker F-1 pkr @ 14,678' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6/21/89 Subsequent to operation 6 / 27/89 52 12 0 1120 70 17 0 1163 160 115 15. AttachmentsX 1 Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~,¢~z-/- District Operations Engineer Signed Title Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well BC-5RD 6/23/89 Daily Summary of Well Operations RU E-line and PT lubricator to 1500 pSi,oOK. MU ~nd RIH w/ 2-5/8" Jumbo Jet hollow carrier guns, 4 SPF, 90 and 270 phasing. With well flowing, correlate and perforate 15,410' - 15,430' DIL. Flow well 5 min. and POH. 6/23-6/24 6/25/89 Gas lift compressor breakdown, unable to fl ow well. S/D perforating operation until compressor repaired. RU E-line and PT lubricator to 1500 psi, OK. Made two RerforatiF~g runs w/ 2-5/8" Jumbo Jet hollow carrier guns, 4 SPF, 90v and 270v phasing. Tag fill @ 15,437'. With well flowing, perforate 15,395' - 15,410' and 15,362' - 15,390'. POH, RD and put well in test. 6/26/89 RU E-line and PT lubricator to 1250 psi,,OK. MU ~nd RIH w/ 2-5/8" Jumbo Jet hollow carrier guns, 4 SPF, 90v and 270 phasing. Correlate and tag fill @ 15,437'. With well flowing, perforate a new interval from 15,344' - 15,362'. POH, RD. ~docs~bc~bc5rd Marathon Oil Company Alaska R, ~n Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 ORIGIN June 9, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton' Attached for your approval is an "Application for Sundry Approval" to perforate the Lower G-Zone in Beaver Creek Well BC #5RD and a Report of Sundry Well Operations for the xylene treatment of Beaver Creek Well BC #5RD (approval #9-346). Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment em~docs~ml~6 RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchorage A subsidiary of USX Corporation ..... STATE OF ALASKA "~- A LA...,,A OIL AN D GAS CONSERVATI ON COM M IS.... ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Alter casing __ Repair well __ Change approved program __ 2. Name of Operator Marathon Oil Company Operation shutdown __ Re-enter suspended well ~ Plugging ~ Time extension ~ Stimulate ~ Pull tubing __ Variance ~ Perforate X-- Other Type of Well: Development X Exploratory __ Stratigraphic m Service ~ 3. Address P. 0. Box ].90].68 Anchorage, AK 995 4. Location of welt at surface ],,267' FNL, ].,465' FWL, Sec. 34-7N-],0W-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-],0W-SM 6. Datum elevation (DF or KB) ],8' KB above GL feet 7. Unit or Propertyname Beaver Creek Unit 8. Well number BC 5RD 9. Permit number 75-55 10. APl number 5o- ],33 - 20239-0], 11. Field/Pool Beaver Creek Field 6-Zone 12. Present well condition summary Total depth: measured 15,655 ' feet true vertical 15,061 ' feet Plugs (measured) None Effective depth: measured ]' 5,607 ' feet true vertical ]. 5,0 ]' 5 ' feet Junk (measured) None Casing Length Size Structural Conductor Surface Intermediate ]' ]',698' 9 5/8" Production 3,387 ' 7" Liner 962' 5" Perforation depth:measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented Measured depth 450 SX 11,698' 14,918' 15,655' Lower G-Zone 15,362' - 15,386' MD 14,781' " 15,395' - 15,405' MD 14,812' " 15,410' - ].5,430' MD 14,826' " ]5,450' - 15,508' MD ].4,864' 3 1/2" N-80 @ 14,678' Baker F-1 pkr @ 14,678' RECEIVED 3UN I z,, 19 9 Alaska 0il & Gas Cons. Commj True v~flOttO~ 14,337' 15,061' - 14,803' TVD - 14,821' TVD - 14,845' TVD - 14,919' TVD 13. Attachments 1 & 2 Description summaryof proposal_.Z. Detailed operations program __ BOP sketch Date approved 14. Estimated date for commencing operation June 1909 16. If proposal was verbally approved Name of approver 15. Status of well classification as: Oil ~X Gas__ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_.~. p. Title District Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner OR!GINAL SIGNED BY LONNIE C. SMITH FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well #5RD Procedure 1. RU E-line unit. PT to 2500 psi. 2. Per~orate the Lower G-Zsne using 2-5/8" hollow carrier guns, 4 SPF, 180 phasing, offset 90 , with 500 psi underbalance. Run Interval Footage 1 15,413~ - 15,430~ 17~ 2 15,395~ - 15,413~ 18~ 3 15,367~ - 15,390~ 23~ 4 15,344~ - 15,367~ 23~ 3. RD E-line unit. 4. Bring well on line slowly and put in test. em~docs~BCkBC5RD Alaska Oil & Gas Cons, Oommission Anchorage Attachment #2 BEAVER CREEK Wireline Lubricator w/Associated BOPE Manually Operated BOP Grease Head (Hydralically Activated) Lubricator Tree Cap Swab Valve R.ECE[VED Alaska Oil & Gas Cons. Commission 2' Wing Valve Anchorage Master Valves 4 1/2' 5000 psi Christmas Tree Seal Flange STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate ...Z.. Plugging ~ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator 1~. TypeOf well: Marathon 0i 1 Company Development~ Exploratory m 3, Address Stratigraphic ~ P. 0. Box 190168 Anchorage, AK 995 Service__ Perforate __ Other __ 6. Datum elevation (DF or KB) 18' KB above GL 7. Unit or Property name Beaver Creek Unit 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-lOW-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-10W-$M At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM At total de~)th 654 FSL, 2,099' FEL, Sec. 27-7N-lOW-SM 8. Well number BC 5RD 9. Permitnumbedapprovalnumber 9-346 10. APl number 50- 133-20239-01 feet 11. Field/Pool Beaver Creek Field G-Zone 12. Present welt condition summary Total depth: measured true vertical 15,655' feet 15,061' feet Plugs (measured) None Effec!ive depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 11,698' Production 3,387 ' Liner 962' Perforation depth: measured 15,607' feet 15,015' feet true vertical Size 5/8" 7" 5" Lower Tubing (size, grade, and measured depth) 3 Packers and SSSV (type and measured depth) Baker Junk (measured) 13. Stimulation or cement squeeze summary Intervals treated (measured) Cemented 450 SX None Measured depth G-Zone 15,362' 15,395' 15,410' 15,450' 1/2" N-80 @ 14,678' F-1 pkr @ 14~678' See Attachment #1 11,698' 14,918' 15,655' - 15,386' MD - 15,405' MD - 15,430' MD - 15,508' MD Treatment description including volumes used and final pressure True vertical depth 14,781' 14,812' 14,826' 14,864' 14,337' 15,061' - 14,803' TVD - 14,821' TVD - 14,845' TVD - 14,919' TVD RECEIVED JUN 1 989. ' Alaska 011 & Gas Cons. C0mmissio Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior t° well operation 4/9/89 Subsequent to operation 5/20/89 108 7 0 1100 160 41 144 0 1140 110 15. AttachmentSx: #1 Copies of Logs and Surveys run __ Daily Report of Well Operations _~X 16. Status of well classification as: Oil _~X Gas m Suspended Service 17. I hereby certify that thef0regoing is true and correct to the best of my knowledge. . , Signed~o.T~.fHA,u,4¢~ .,~-'~).)4'. L/lo~~ Title District Operations Engineer Date Form 10-404 Rev 06/1:5/88 SUBMIT IN DUPLICATE Attachment # I Daily Summary of Well Operations Beaver Creek 5RD 5/10/89 RU 1-1/4" CTU and PT to 4500 psi, OK. RIH w/ CT while filling back side of tubing with lease crude. Fill CT with xylene and squeeze away at 1/2 BPM while moving CT across perforated intervals. Tubing pressure increased to 3000 psi while pumping at 1/4 BPM. Shut down pumps. Pressure bled to 2500 psi within 15 min. Begin injecting xylene at 1/4 BPM to maximum pressure of 3000 psi, then shut down for 7 minutes and allow pressure to bleed to 2500 psi. Repeat pressure up/bleed down cycle 19 times, injecting approximately 1.5 bbls each cycle. Squeeze a total of 30 bbls into formation. Leave an additional 6 bbls of xylene in casing across perforations. POOH with CT and RD. Allow xylene to soak for 12 hours and bring well on line. em\docs~BC~BC5RD RECEIVED ~aska Oil & Gas Cons. Commission Anchorage Marathon Oil Company Alaska F,~gion Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 May 4, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approval" for a xylene treatment in Beaver Creek Well BC #5RD. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment em~docs~ml~6 RE£EiVED MAY - 8 }.9R ~aska _0il &' 8as Cons..CO. lrlIi~8[01t ' ".~' Anchorage A subsidiary of USX Corporation STATE OF ALASKA AL/-,..,(A OIL AND GAS CONSERVATION COMMIS,=ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well ~ Alter casing ~ Repair well ~ Plugging __ Time extension __ Stimulate X__._ Change approved program ~ Pull tubing __ Variance ~ Perforate ~ Other __ 2. Name of Operator ! 5. Type of Well: 6. Datum elevation (DF or KB) Marathon Oil Compan;y I Development X___ 18' KB above GL Exploratory ~ 3. Address Stratigraphic N 7. Unit or Property name P. O. Box 190168 Anchorage, AK 995 9 Service__ Beaver Creek Unit feet 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-10W-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-lOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-lOW-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-lOW-SM 8. Well number B6 5RD 9. Permit number 75-55 10. APl number 50- 133-20239-01 11. Field/Pool Beaver Creek Field G-Zone 12. Present well condition summary Total depth: measured true vertical 15,655' feet 15,061' feet Effective depth: measu red 15,607 ' true vertical 15,015 ' Casing Length Size Structural feet feet Plugs (measured) Junk (measured) Cemented None None Measured depth RECEIVED! I MAY - 8 .ggQ J ! Conductor Surface Intermediate 11,698' 9 5/8" Production 3,387' 7" Liner 962' 5" 450 sx 11,698' 14,918' 15,655' 14,337' 15,061' Perforation depth: measured true vertical Lower G-Zone II II II Tubing (size, grade, and measured depth) 3 1/2" Packers and SSSV (type and measured depth) Baker 15,362' 15,395' 15,410' 15,450' - 15,386' MD - 15,405' MD - 15,430' MD - 15,508' MD N-80 @ 14,678' F-1 pkr @ 14,678' 14,781' 14,812' 14,826' 14,864' - 14,803' TVD - 14,821' TVD - 14,845' TVD - 14,919' TVD 13. Attachment¢' 1, 2, Description summary of proposal __ &3 Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X__ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~/[C°~//x./{?'~'-- Title District Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- Approved C.opy Returned ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH Commissioner J Approval No. ? ... ~.~ ~, Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Beaver Creek Well #5 ×ylene Treatment Procedure 1. Obtain fluid sample for analysis. Shut in lift gas to well 12 hours prior to beginning the job. Leave tubing open to production and allow well to die. 2. Fill back side with crude oil (-737 bbls). 3. RU coiled tubing and pump truck to BC-5RD. Pump truck should be loaded w/ 130 bbls lease crude. Vac truck should have 1500 gal xylene on board. 4. PT equipment to 4500 psi. 5. RIH w/ coiled tubing to 14,693' (tubing tail) while pumping hot oil at 1/4 BPM to prevent coil from collapsing and/or plugging. Make necessary stops while RIH to evaluate pick up weights. 6. Establish circulation. 7. Take on 1500 gal xylene from vac truck and heat to 110-120o F. 8. Spot 1 bbl xylene around coil. Close wing valve. Pump 20 bbls xylene. SD for 30 minutes. Pump 6 bbls. SD for 30 minutes. Pump 6 bbls. Displace w/ crude, leave 2 bbls xylene across perforations. Note. Monitor casing pressure. Max tubing pressure : 3000 psi. 9. POH w/ CT, displace coil w/ water, and RD. 10. SI well for 12 hours. I1. Bring well on slowly and test. em~docs~afe\4 RE£E, .VED MAY ..... fi, 1%~ Alaska ,Oil & Gas Cons, ~,. ~nchorage g 5/8" 471 P-IlO Csg. 3's" 9.21 N-30 Tbg. 7' 321 P-110 Csg. Atrachmen£ #2 Beaver Creek #5RD Current Completion De.,th (TI-:) 1.0. 244 2.75 3,151 2.375 4,567 · 5,U45 · m- 7,049 80156 · 9,147 · · 10.076 · 10,974 11,499 11,531 11,693 12.219 3.00 120799 ' . 13,260 · 13,639 · · 13,980 14,2G3 14,67~ 14,677 14,676 14,693 · · 2.87 ' 3.00 3.00 I)escr iht ion Otis 3'~' Ball Valve (removedl GLV fl Ilc:.:urry Ilu~hes YP.-STO-O retrievable press. Oper. GLV ,~2 1.50" O.183"port, Camco GLV 13 I:/lr, Ilaltdrei,flK latch GL¥ .~4 Camco R-20, 1~t' 0.183' port GLV 15 Same as !1 GLV f6 ' · . GLV 17 · ' · GLY ~8 ' · · GLY 19 " · · GLV ~10 USI-cr-2 S/S conven- tional I.~ndrel & tlacco Press Valve Cl~ 5/16' GLV III · · · GLY ~12 ' · · · GLY ~13 · · GLV 114 · · · GLV 115 · · " Baker }bdel L Sliding Sleeve 8aker Locator Sub Baker ~:ode) G Seal Assy. in Baker F-I Packer w/2.992' I.~. Ilule Shoe · ?IW PB~ & Liner Ilanger with Tlg Seal Assy. S" 131 P-IlO Csg. 14,918 Tagged fill g 15,43E'(b'LM] 7-57 15,362'- 15,306 15,395 - 15,405 15,410 - 15,430 15,450 - 15,508 I 15,G07 POTO · · .. ~as~ Oil & Gas Go~s. c misst0n ~E£ 9-57 Note: Proposed completion is che same ~tch the excepclon o£ gas lift mandrel type and spacing. All mandrels uill have ~ireline retrievable, valves. Attachment #3 BEAVER CREEK Coiled Tubing Lubricator w/Associated BOPE Double BOP w/1 1/4' Rams 5000 psi WP Hydraulic Rams Tree Cap Swab Valve / 2' Wing Valve Master Valves 4 1/2' 5000 psi Christmas Tree Seal Flange STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMrw,oSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing I] Alter Casing [] Other ~ Notice of Cancellation of Approved Workover 2. Name of Operator 5. Datum elevation (DF or KB) Marathon Oil Company 18' KB above GL Feet 3. Address 6. Unit or Property name P. O. Box 160168 Anchorage, AK 99510 Beaver Creek Unit 7. Well number BC-5RD 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-iOW-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-10W-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-10W-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-10W-SM 8. Approvalnumber 8-465 9. APInumber 50-- 133-20262-01 10. Pool G-Zone 11. Present well condition summary Total depth: measured true vertical 15,655 ' feet Plugs (measured) 15,061' feet None Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 11,698 ' Production 3,387 ' Liner 962' Perforation depth: measured true vertical 15,607 ' feet Junk (measured) None 15,015 ' feet Size Cemented Measured depth ~ue Verticaldepth 9 5/8" 11,698' 7" 14,918' 14,337' 5" 450 SX 15,655' 15,061' Lower G-Zone 15,362' - 15,386' MD 14,781' " 15,395' - 15,405' MD 14,812' " 15,410' - 15,430' MD 14,826' " 15,450' - 15,508' MD 14,864' ~bing(size, grade and measured depth) 3 1/2" N-80 @ 14,678' Packers and SSSV(type and measured depth) Baker F-1 Packer @ 14,678' 12. Stimulation or cement squeeze summary - 14,803' TVD - 14,821' TVD - 14,845' TVD - 14,919' TVD i~ L ~.., L I V Intervals treated (measured) Treatment description including volumes used and final pressure AUG 1 1988 Oil & Gas Cons. Commission ~choraga 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run II 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Region Operations Engineer Date g/Zf,/~ Form 10-404 Rev. 12-1-85 Submit in Duplicate Marathon Oil Company Alaska R~ n Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 7, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is the Application for Sundry Approval for Beaver Creek Well BC-1A, BC-3 and BC-5RD. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC / em/6/M1 A subsidiary of USX Corporation 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 El Alter casing I ] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [3 Perforate ~1 Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Marathon Oil Company 18' KB above GL feet 3. Address 6. Unit or Property name P. O. Box 190168 Anchorage, AK 99519 Beaver Creek Unit 7. W~(~ n~l~er 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-lOW-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-10W-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-10W-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-10W-SM 8. Permit number 75-55 9. APl number 50-- 133-20262-01 10. Pool G-Zone 11. Present well condition summary Total depth: measured true vertical 15,655 ' feet Plugs (measured) 15,061 ' feet None Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 11,698 ' Production 3,387 ' Liner 962' Perforation depth: measured true vertical 15,607 ' feet Junk (measured) None 15,015' feet Size ~e~t~di V E [~easured depth 9 5/8" Alaska 0il & Gas Cons. C0mmissi0nt 1,698' 7" ~ · .....'~L Anchorage 14,918' 5" 450 sx 15,655' True Vertical depth 14,337' 15,061' Lower G-Zone 15,362' - 15,386' MD 14,781' - 14,803' TVD " 15,395' - 15,405' MD 14,812' - 14,821' TVD " 15,410' - 15,430' MD 14,826' - 14,845' TVD " 15,450' - 15,508' MD 14,864' - 14,919' TVD ~bing(size, grade and measured depth) 3 1/2" N-80 @ 14,678' Packers and SSSV(type and measured depth) Baker F-1 Packer @ 14,678' 12.Attachments 1, 2 & 3 Description summary of proposal :4El Detailed operations program ~1 BOP sketch 13. Estimated date for commencing operation August 1988 14. If proposal was verbally approved Name of approver Subsequen~ Work 1Reported on lq'orm No.~¢Dated ~__.~/.~,~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/(C~ ~/~'~ TitleDistrict Operations Engineer Commission Use Only Date /~/?/5~ Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Approved Copy . Returned,~,,~"~ 0RICINAL SlCNED BY ~:2 ~'~ Approved by LONNIE C. SMITH Commissioner by order of g _/~ _~2(~) the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Attachment #1 Beaver Creek #5RD Workover Procedure 1. Shut off lift gas and allow well to die. Bleed tubing and casing to zero and fill both sides with lease crude. 2. RU WL and RIH w/sinker bars and CCL to check depth of fill. 3. MIRU workover rig. Set BPV, ND tree, NU BOPE and test to 3000 psi. 4. POH and LD completion tubing. 5. PU DP and rotary mill. Mill packer at 14,678'. RIH w/spear and retrieve packer assembly. 6. Clean out fill as necessary. Polish off tieback sleeve, and run TIW SNAT-6 tieback packer to packoff leaking liner top. 7. RIH w/TCP system and correlate to perforate select G-Zone intervals between 15,362' and 15,510'. Set packer in 7" liner and perforate with 1500 psi underbalance (reservoir pressure is ±4000 psi). 8. Circulate to kill well and POH w/TCP system. 9. RIH w/ 7" x 4" SB packer and set packer at ±14,650'. 10. PU new 3-1/2" tubing and RIH w/seal assembly and new gas lift equipment. Space out and land tubing in packer at ±14,650'. Set BPV. ND BOPE. NU tree. Release rig. 11. Return well to production. PMO/em/50A/Sundry RECEIVED j"t;i ].-::' .,- , .laoKa Oil & 6~s Cons. Commission Anchorage Attachment #2 Beaver Creek #5RD Current Completion g 5/8" P-ll0 Csg. 3? 9.2# N-80 Ibg. 7" 32~ P-llO Csg. De!in (tEl 244 3,151 4,567 5,~145 7,049 8,156 9,14Z 10,076 10,974 11,499 11,531 11,698 12.219 12,799 13,260 13,639 · 13,980 14,263 14,674 14,677 14,678 14,693 i.D__._..~_ Descrintion 2.75 Otis 3? Ball Valve (removed) 2.875 GLV fl Ilc~.!urry Ilughes VR-STD-D reLrievable press. Oper. " GLV f2 1.50" O.183"port, Camco HNG Ila,dreI,RK latch "~. GLV ~3 " GLV f4 Camco R-20, 17 0.188" port GLV f5 Same as ~1 " GLV f6 " " " " gLV f7 ..... " GLV fib " " " ' GLV fig ..... 3.00 GLV 810 USI-CF-2 S/S conven- tional l,landrel & Ilacco Press Valve CH2 5/16" " GLV fill ~LV ~12 GLV fl3 " " " " GLV #14 .... GLV ~15 " " 2.87 ' Baker Nodel L Sliding Sleeve 3.00 Baker Locater Sub 3.00 Baker Nodel G Seal AssX. in Baker F-! Pacher w/2.992" I.D. Hule Shoe 'TI~ PBR & Liner Hanger with TIW Seal Assy. 5" 18# P-110 Csg. Tagged fill @ 15,436' (NLM 7-$7 14,918 15,362~- 15,386 15,395 - 15,405 ls,410 - lS,430 lS,45o - lS,5O8 15,GD7 PBTD 15,655 TD WE£ 9-87 Note: Proposed completion is the same with the exception of gas lift mandrel type and spacing. All mandrels will have wireline retrievablevalves. RECEIVED JUN t i~ .1.9;' .. Alaska Oil & Gas Cons. Commission Anchorage Attachment ¥/3 I~,ARATHON OIL COMPAI~t' BEAVER CREEK WELL NO. 5RD · 13-5/8' 5000 psi BOP Assembly Mud Pan Flowllne Drilling Nipple Rotating Head Clamp Connector . 13 ,.Annular 5/8' x 5000~ Preventer (Hydril) Clamp Connector. · ~ (Plpe~ama). ' ~ :3 3/8' Double-Gate-CIW. . . x 5000~ Choke Line 3 x 5000~ Kill Line _ ~ _ _ ,. I° gv' ' ' 12' x 3000~ Casin Head w/Flanged Outletl & alvea 13 3/8' Surface Casing . __~ 3 O' Conductor Marathon Oil Company Alaska Reg~o. Domestic Production R O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 April 11, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 'Dear Mr. Chatterton: Attached is the AOGCC Report of Sundry Well Operations for Beaver Creek elL~~nd Spark Platform Well S-1RD. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/M1 STATE OF ALASKA -- ALASK,. ,.)IL AND GAS CONSERVATION COMM. 51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ER Plugging [] Perforate Lq Pull tubing Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-10W-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-10W-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-TN-10W-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-10W-SM 5. Datum elevation (DF or KB) 18' KB above GL 6. Unit or Property name Beaver Creek Unit 7. Well number BC-5RD 8. Approval number 8-80 9. APl number 50-- 133-20262-01 10. Pool G-Zone Feet 11. Present well condition summary Total depth: measured true vertical 15,655' feet 15,061' feet Plugs (measured) None Effective depth: measured 15,607 ' true vertical 15,015' feet feet Junk (measured) None Casing Length Structural Conductor Surface Intermediate 11,698 ' Production 3,387 ' Liner 962' Perforation depth: measured true vertical Size 9 5/8" 7" 5" Cemented 450 sx Measured depth 11,698' 14,918' 15,655' Lower G-Zone 15,362' - 15,386' MD 14,781' " 15,395' - 15,405' MD 14,812' " 15,410' - 15,430' MD 14,826' " 15,450' - 15,508' MD 14,864' ~bing(size, grade and measured depth) 3 1/2" N-80 @ 14,678' Packers and SSSV(type and measured depth) Baker F-1 Packer @ 14,678' True Vertical depth 14,337' 15,061' - 14,803' TVD - 14,821' TVD - 14,845' TVD - 14,919' TVD RECEIVED 12. Stimulation or cement squeeze summary 13. Intervals treated(measured) Lower G-Zone 15,362' - 15,508' Alaska 0il & Gas Cons~ Commissiori Treatment description including volumes used and final pressure 31 bbls Xylene displaced by 102 bbls diesel @ 3000 ~)si Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3/03/88 101 234 0 570 psi 110 psi Subsequent to operation 4/01/88 136 102 0 620 psi 120 psi 14. Attachmentm: Daily Report of Well Operations Copies of Logs and Surveys Run iii 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed District Operations Engineer Title Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment ~ 1 Beaver Creek Well BC-5RD Daily Summary of Well Operations 3/12/88 RU coil tubing and pumping unit and pressure test to 5000 psi. RIH pumping diesel at 1/4 bbl/min to 10,000'. Start xylene displacement. Pump 19 bbls and squeeze across perfs 1/bbl/15 min. @ 3000 psi. Hold for pressure to drop, pump 1 bbl and hold (3 BPH rate). Pumped total of 31 bbls through CT. Pump diesel @ 3 bbl/hr until xylene displaced. Held 4 bbls in CT for pick up displacement. POOH, displacing rest of xylene above perfs. RD CT. Leave well SI for 12 hrs, then bring on slowly. em / 50 / Sundry f-- STATE OF ALASKA -~ ALA. .A OIL AND GAS CONSERVATION COl ,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ER Plugging [] Perforate [] Pull tubing Lq Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 190168 Anchorage, AK 99519 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-10W-SM 5. Datum elevation (DF or KB) 18' KB above GL 6. Unit or Property name Beaver Creek Unit 7. Well number BC-5RD At top of productive 653' FSL, At effective depth 654' FSL, At total depth 654' FSL, interval 2,111' FEL, Sec. 27-7N-10W-SM 2,103' FEL, Sec. 27-7N-10W-SM 2,099' FEL, Sec. 27-7N-10W-SM 8. Approval number 8-80 9. APl number 50-- 133-20262-01 10. Pool G-Zone Feet 11. Present well condition summary Total depth: measured 15,655 ' feet true vertical 15,061' feet Plugs (measured) None Effective depth: measured 15,607 ' feet true vertical 15,015' feet Junk (measured) None Casing Length Structural Conductor Surface Intermediate 11,698 ' Production 3,387 ' Liner 962' Perforation depth: measured true vertical Size '- Cemented Measured depth 9 5/8" 11,698' 7" 14,918' 5" 450 SX 15,655' Lower G-Zone 15,362' - 15,386' MD " 15,395' - 15,405' MD " 15,410' - 15,430' MD " 15,450' - 15,508' MD ~bing(size, grade and measured depth) 3 1/2" N-80 @ 14,678' Packers and SSSV(type and measured depth) Baker F-1 Packer @ 14,678' True Vertical depth 14,337' 15,061' 14,781' - 14,803' TVD 14,812' - 14,821' TVD 14,826' - 14,845' TVD 14,864' - 14,919' TVD 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) Lower G-Zone 15,362' - 15,508' Treatment description including volumes used and final pressure 31 bbls Xylene displaced by 102 bbls diesel @ 3000 psi Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3/03/88 101 234 0 570 psi 110 psi Subsequent to operation 4/01/88 136 102 0 620 psi 120 psi 14. Attachment~ #1 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed District Operations Engineer Title Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment # 1 Beaver Creek Well BC-5RD Daily Summary of Well Operations 3/12/88 RU coil tubing and pumping unit and pressure test to 5000 psi. RIH pumping diesel at 1/4 bbl/min to 10,000'. Start xylene displacement. Pump 19 bbls and squeeze across perfs 1/bbl/15 min. @ 3000 psi. Hold for pressure to drop, pump 1 bbl and hold (3 BPH rate). Pumped total of 31 bbls through CT. Pump diesel @ 3 bbl/hr until xylene displaced. Held 4 bbls in CT for pick up displacement. POOH, displacing rest of xylene above perfs. RD CT. Leave well SI for 12 hrs, then bring on slowly. em / 50 / Sundry · Marathon Oil Company Alaskan i ict Productiob-, dnited States RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 February 5, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached is the AOGCC Application for Sundry Approval for Beaver Creek Well BC-5RD. Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/M1 STATE OF ALASKA ALASK. ,)IL AND GAS CONSERVATION COMN. .~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well E] Alter casing Time extension [] Change approved program [] Plugging [] Stimulate I~ Pull tubing [] Amend order Eli Perforate /l Other 2. Name of Operator 5. Datum elevation (DF or KB) Marathon Oil Company 18' KB above GL feet 3. Address 6. Unit or Property name P. O. Box 102380 Anchorage, AK 99510 Beaver Creek Unit 7. Well number BC-bRD 4. Location of well at surface 1,267' FNL, 1,465' FWL, Sec. 34-7N-10W-SM At top of productive interval 653' FSL, 2,111' FEL, Sec. 27-7N-10W-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-10W-SM At total depth 654' FSL, 2,099' FEL, Sec. 27-7N-10W-SM 8. Permit number 75-55 9. APl number 50-- 133-20262-01 10. Pool G-Zone 11. Present well condition summary Total depth: measured true vertical 15,655 ' feet 15,061 ' feet Plugs (measured) Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 11,698 ' Production 3,387 ' Liner 962' Perforation depth: measured true vertical 15,607 ' feet 15,015 ' feet Size 9 5/8" 7" 5" Junk (measured) None Cemented Measured depth 450 sx 11,698' 14,918' 15,655' Lower G-Zone 15,362' - 15,386' MD 14,781' " 15,395' - 15,405' MD 14,812' " 15,410' - 15,430' MD 14,826' " 15,450' - 15,508' MD 14,864' Tubing (size, grade and measured depth) 3 1/2" N-80 @ 14,678' Packers and SSSV (type and measured depth) Baker F-1 Packer @ 14,678' Tr,~e~ ~/t~f~l depth 14,337' 15,061' - 14,803' TVD - 14,821' TVD - 14,845' TVD - 14,919' TVD 12.Attachmentsx ¢~1 Description summary of proposal [] Detailed operations program FI BOP sketch 13. Estimated date for commencing operation February 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, certify foregoing Signed is true and correct to the best of my knowledge Title District Operations Engineer Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned - ORIGINAL SIGNED .Y .~_~'--"~/,,--~-,~ LONNIE (;. SMITH Approved by Commissioner Form 10-403 Rev 12-1-85 by order of the commission Dat Submit in triplicate Attachment #1 Beaver Creek #5RD Coiled Tubing Procedure 1. Rig up tanks necessary to hold 150 barrels diesel. (Xylene will be held on vac truck). A covered and vented returns tank will be needed. 2. Shut in lift gas to well - leave tubing open to production. 3. RU coiled tubing. 4. Pressure test to 5000 psi. 5. RIH with jet and tag bottom. Make necessary stops while RIH to evaluate pick-up weights. 6. Circulate with diesel to returns tank to clear gas from tubing. 7. Pump xylene. 8. Displace xylene to top perf at 15,362' with jet at 15,500' CTM. Displacement fluid will be diesel. 9. SI well and squeeze xylene away. Leave 3 barrels xylene in casing across from perfs. Maximum tubing pressure = 3000 psi. 10. POH, RD CT and pump. Pull returns tank with vac truck and dump to production. 11. Allow xylene to soak 12 hours and bring well on production. WLB/em/627/OE27 STATE OF ALASKA -- ALA & OIL AND GAS CONSERVATION COl. ,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Feet Marathon Oil Company 3. Address P. O. Box 102380 Anchorage, AK 99510 4. Location of wellatsurface 1,267' FNL, 1,465' FWL, Sec. 34-7N-10W-SM Attop of productiveinterval 653' FSL, 2,111' FEL, Sec. 27-7N-iOW-SM At effective depth 654' FSL, 2,103' FEL, Sec. 27-7N-IOW-SM Attotaldepth 654' FSL, 2,099' FEL, Sec. 27-7N-10W-SM 177' KB 6. UnitorPropertyname Beaver Creek Unit 7. Well number BC-5RD 8. Approval number 9. APl number 50-- 133-20262-01 10. Pool G-Zone 11. Present well condition summary Total depth: measured 15,655' feet true vertical 15,061 ' feet Effective depth: measured 15,607 ' feet true vertical 15,015' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 11,698' 9 5/8" 3,387' 7" 962' 5" Perforation depth: measured See Attachment #1 true vertical Plugs (measured) 15,440' - 15,607' fill Junk (measured) None Cemented Measured depth True Vertical depth 11,698' 14,918' 14,337' 450 sx 15,655' 15,061' Tubing(size, grade and measured depth) 3 1/2" N-80 @ 14,678' Packers and SSSV(type and measured depth) Baker F-1 Packer @ 14,678' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7/27/86 144 56 .29 9/2/86 161 26 . 16 Subsequent to operation 9/14/86 186 38 .19 920 psig 1,100 psig 770 psig 520 psig 135 psig lO0 p~ig 14. Attachment~ #2 :Oa~l~ Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge , Signed ~/f~ / ~ TitleDistrict Operati°ns Engineer Date '~/~'7/g6 Form 10-404 Rev. 12-1-85 Submit in Duplicate ATTACHMENT #1 WELL BC-5RD Perforations 15,362' - 15,386' MD 15,395' - 15,405' MD 15,410' - 15,430' MD 15,450' - 15,508' MD 14,781' - 14,803' TVD 14,812' - 14,821' TVD 14,826' - 14,845' TVD 14,864' - 14,919' TVD MDC/em/50/Sundry ATTACHMENT #2 DAILY REPORT OF WELL OPERATIONS Well BC-5RD 7/31/86 1. RU wireline company. 2. RIH w/paraffin scratcher to 11,540' MD. 3. Change out GLVs #5, 7, 8, and 9. 811186 1. Change out GLVs #4, and 6. 8/2~86 1. Change out GLVs #1, 2, and 3. 2. Return well to production, not producing properly. 8/3/86 1. RU wireline company 2. RIH to check #4 GLV. 3. Run new #4 GLV. 4. Return well to production. 9/4/86 1. RD perforating company. 2. Repair equipment and test lubricator. 3. Return well to production. 9~5~86 1. RIH w/perforating guns. 2. Perforate G-Zone 15,362' - 15,386', 15,395' - 15,405' & 15,410' - 15,430' with 4 SPF. 3. Return well to production. MDC/em/50/Sundry STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Marathon 0il Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of Well Surface: 1267' FNL, 1465' FWL, Sec. 34-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) 177' KB 6. Lease Designation and Serial No. A-028083 OTHER [] 7. Permit No. 75-55 8. APl Number 50- 133-20262-01 9. Unit or Lease Name Beaver Creek Unit lOB~el I._N u~) 11. Field and Pool Beaver Creek Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). BC Well #5RD It is Marathon's intention to repair and reperforate the well beginning April 21, 1986, by the following procedure: 1. Rig up wireline and lubricator, test to 2500 psi. 2. Run a 2.70" gauge ring to 15,440'. 3. Change the upper 9 gas lift valves with wireline. 4. Production test and gas lift survey the well. 5. Perforate with deep penetrating guns, 4 SPF, 0° phasing under drawdown as follows: 15,410' - 15,430' 15,395' - 15,405' 15,362' - 15,386' 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of APproval, if any: Approved by .......................... By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ..,IL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~D~ 2. Name of Operator 7. Permit No. Marathon Oil Company 75-55 3. Address 8. APl Number P. O. Box 2380, Anchorage AK 99510 5o-133-20262-01 OTHER 4. Location of Well ' Surface: Beaver Creek, Well Pad #3 1267' FNL, 1465' FWL, Sec 34-7N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) 177 ' KB 6. Lease Designation and Serial No. USL-A-028083 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #5RD 11. Field and'Pool G-Zone 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Perforated and reperforated the following intervals under drawdown with a 2-1/8" enerjet gun, 4 HPF on 9/22 - 9/23/81. Perforated: Reperforate: 15,395' - 15,405' 15,362' - 15,384' 15,410' - 15,430' Production rates average 10 days prior to shooting (9/11/81 through 9/21/81): 75 BFPD, 75 BOPD, .225 BWPD, .3% BS&W 36.6 MCFPD gas used for lift or lease use Production rates average 10 days after shooting (9/23/81 through 10/3/81): 161 BFPD, 160 BOPD, .483 BWPD, .3% BS&W 78 MCFPD gas used for lift or lease use RECEIVED Alaska 0it & 6as (;,0ns~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~--~' f'~'~ - Title 0,,~,~,'~'. The space below for Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [2% OTHER [] 2. Name of Operator 7. Permit No. MarathOn Oil Company 75-55 3. Address 8. APl Number P.O. Box 2380, Anchorage, AK 99510 50- 133-20262-01 4. LocationofWell (Surface Location) Beaver Creek, Well Pad #3 1267' FNL, 1465' FWL Sec 34-T7n-R10W-SM 5. Elevation in feet (indicate KB, DF, etc.) 177' KB 6. Lease Designation and Serial No. USL-A-028083 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #5RD 11. Field and Pool G-Zone 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting permission to reperforate two intervals, and perforating one interval in the G-Zone. The intervals are as follows: Perforate: Reperforate: 15,395'-15,405' DIL 15,410'-15,430' DIL 15,362'-15,384' DIL 2-1/8" Gun, 4 HPF 2-1/8" Gun, 4 HPF 2-1/8" Gun, 4 HPF Estimated startup date: September 21, 1981 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'"~'X '~'~'~' ' T it,e O perat ions Superint endent The space below for Commission use Date 9/4/81 Conditions of Approval, if any: Approved by COMMISSIONER By Order of ~he Commission Dale _ Form 10403 ;R~v 7-1-RO Suhm~! "Intentions" ~n Triplicate and "Subsequent Reports" in Dupl,cale FROM: DEPT. ADDRESS · VIA MARATHON 0IL CoMpANy ISENDER .?Dick Atchison Anchorage, Alaska.' 99 $10 QUANTITY 1 each 1 each 1 each 1 each TO: Harry Kugler COMPANY State of,.,.Alaska DDRESS --Beaver Creek ~5 Redri~sCRIPTION DATE SHIPPED DIL 2" and ~" blue line and sepia 'Sonic 2" & 5" blue line and sepia FDC 5" blue line and sepia CNL 5" blue line and sepia 1 each Computed log 5"-blue line and sepia 1 each Saraband 5" blue line an~ sepia -, 2 each Saraband tabular listing September 27, 1976 PLEASE RETURN ONE SIGNED COPY TO THE ABOVE ADDRESS , / RECEIVED BY DATE i L 07-01-76 DIVIS!Ohl ,DF ,11;" ' Harry' .~.~c ;r As we discussed this morning, here are the delinqu, ent reports on BC 5, RD and BC 7. I'm going to set up a new system of report'ing that will eliminate this problem. Sorry for the. inconvenience this has caused you. We are drilling BC 7 as a tight hole, but BC 5, RD records are not confidential. Dick Atchison handles logs, and he is out of the office on vacation for a couple weeks. I will check with him about the BC 5, RD logs when he returns. Les 1 ie Haywood Mid-Continent Supply Co., 322'7 Arctic Blvd., Anchorage 279-$551 Anchorag, division Production Exploration US & Canada Marathon Oil Company PO Box 2380 Anchorage Alaska 99510 Telephone 907/274 1511 Hr. O. K. Gilbreth, Jr. Chairman, Alaska Oil and Gas Conservation Committee State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 April 21, 1976 Dear Mr. Gilbreth: Enclosed for your files are two copies of our Well History for Beaver Creek 5, RD. The completion report for this well was mailed to your office on April 15, 1976. DTC:I Very truly yours, DALE T. CADDY Operations Superintendent ~nclosures SUBMIT IN DL ..... ,rE* STATE OF ALASKA ~ Se,, 4th,,r In- si rtlct lorl~ on OIL AND GAS CONSERVATION COMMITTEE i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* i i la. TYPE OF WELL: oli, [] GAS ~ [] WELL WELL ~ DRY Other b. TYPE OF COMPLETION: ~:w ~ wo~ r-~ D~E~- ~ P~'~"[-I ~'~' [~ Redrill WELt, OVrR ~ EN BACK RESVR. Other , 2. NAME OF OPERATOR Marathon Oil Compagy 3. ADDRESS OF OPERATOR P. 0. Box 2380, Anchoraoe. AK 99510 4. LOC^TtO,~ oF WrLL (Report location cle~rl~ and in accordance with any State requirements)* At surface 1267'FNL & 1465'FWL, Sec. 34, T7N, glOW, Sa,'~i~ 1-=~ 0~,~ ~:'i,,,,, A~ top prod. interval reported below __,L~~'~ tls';, 653'FSL & 2111'FEL, Sec. 27, TTN, R10W, SM At total depth 654IFSL & 2099'FEL, Sec. 27, T7N, R10W, SM ,!~)!, ,~ O I6fNAt 5. APl NUMF_ALICAL CODE 50-133-20262-01 6. LEASE DESIGNATION A.ND SEI%I2kL NO. USL-A-028083 -~. 1F INDiA-N, ALLO'I'TEE O1{ TRIBE NA2~IE 8, UNIT,FAiLM O1< LhDISE NAME Beaver Creek Unit 9. WEJ-,L NO. No. S~ Redrill 10. FIELD AND POOL, Olt WILDC&T G Zone 27, T7N, R10W, SM @TD 12, PERA~IT NO, 75- 55 DATE SPUDDED t4. DAT'E T.D. RE~CHED IS: DATE COliP SUSP Ca ABACI ~I~V~rlONS ~f)~;'~K~'. i'l", GR, *STC}. 17. ELEV. CASiNGttEAD 11-01-75 J 01-17-76 03-17- ~= '":~"':' ...... '::"~ 157.6I '~O~AL DE~H 2v~ & TVD~9. PLUG, B~CK MD ~ ~D~, ~ ~LT~LE CO~L., [ 21. " INTERVAI,S I)RtLI,ED BY ' D 3~0~5'TVD Sin9le All PRODUCING ~N~RVAL(S), OF ~.Ig CO.~P~TIO~TO~, BOSOM, NA~E (MD AND ~)* ,23. WAS DH~ECTIONAL ~ SUR k'EV MADE Tyonek a Zone: Top: ~ 5,332'~ ~ ~, 76~ ' TVD ~ Bottom: ~5,607'~D 35,0~5'TVD ~ Yes 24. TY~PE ELECT~IC AND OTHIKP~ LOGS RUN DIL/SP, Sonic/GR, FDL-CNL CASING RECORD (Report all strings set in well) Red'ill (~ee Item 29[for. ne~ liner),. Wi.,dow,, in ][" cs9 from 1tt.918.'- 1./t.. . 78'MD. ......" 2~. LI~ZX ~.ECOaD · [ 2v. TUmNC; n~or:a.~ --5'-rr---'' [ 14,693' [ 1'~,~,52' J 450 sX* I 3½" ] lh,698' j.14.67q' ........ · Cement s{]ueezed l in~r !a~ w/ t[50 sx, 01-: ~-~6. .I [ . ..' I '28. '~%I=tF6R.ATIONS OP~_LN TO PRODUCTIOlq' (interval, size and number) 29, ACID. S~:OT. I,';~A7 '[ Gt,~E. C~L,i£,N'i' SQ'J/L';JZi,;, 'IGTC. ,,,,.D.P-a-~T~i IN'I'F~4y.~L (MD, ] 9M©UNF AND I.,.!ND t)[,' P,,1A,'IE/:iAI~ USED (See Attached Perforation Record) 15,h68'-15,5o8']_ 1000 gals MCA Acid 15,366'-1S,k58~1-5000 gals S2O HCl & 4000 9als 12% HCl, 102o HF Acid i ii n PRODUCTION DATE FIi~ST PItODUCTION 03-0~-76 DATE OF T~ST, Iq_OURS TESTiffD "]C}tOZ-SE SiZE [P~OD'rg FOt~ tTES ' 04-07-76 169 [ , FLOW, TUBING CASING PRESSUR~ CALC~T~ OI~BBL. 9o psi 9oo ps~ ] ~ 238 21. D~SPOam'~ON Or ~aS (8otd, u~ed for ]uet, vented, etc.) I nj ected P~RODUCTION 1V~EI[{OD (Flowitag, gaz. lift, pamping--size and type of pump, Gas Lift OI~B~L. G.kS--RiCF. ] 1615 ,,l q18 GAS--RICF. I 28 32. LIST OF ATTACHMENTS Perforation Record, Directional Survey "'g3.'I hereby certify that the foregoing and attached information is complete and correct as determined from all-avail:al)lc rec.rd~ SIC.NED _ TITLE 0perat ions S _rintendent D,vri,: 07-01-76 II I I , (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- ments given in cther spaces o.n this form and in any attachments. Items 20, and 22:: If this well is completed for separate, production from more than one interval zone (multiple completion), so state in item 20, and ir~ item 22 show the p~cJuci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produceJ, show- ing the additional data pertinent to such interval. Item26: "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. Item 28: Submit a separate completion report on this forrn for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAH. Y OF FO{-IMATION I'ES'I','q IN('L, UI)IN(; INTEIIVAL TESTED, PHE~'-iSURE DATA. A. ND /LF_,COVERIES OF OIL, (iAS, 35. G }DOLOG I C M ARKIKHS WATER AND MUD Tyonek g Zone 15,332'MD 15,607'MD Sand, Conglomerate, & Silt ~.~.^s. ~m~ .~urv~v.~i, ..... (14,761'TVD) (15,015'TVD) Tyonek G Zone 15,332' 14,761' G Zone DST #1 Interval Tested 15,013' - 15,026'MD w/ 9200' fresh Water Cushion & Packer 14,962': I HP 9988 ps i IFP 4371-4484 psi [20 min) ISIP 7923 psi (60 min) FFP 4496-4081 psi (6 hrs)* FSIP 8635 psi (12½ hrs) FHP ., 9~02 Ds i .. A:ND~ [)lg'l~ECqqgl) Stl¢)WS O~ ()IL., GAS OH WA'I~-"II. Reversed out 25 bb]s mud-cut water. NOTE: This DST was taken in the original BC 5 hole before cutting the window in 7" from 14,918' - 14,978' to sidetrack the well. ~ ,, *Tools plugged during final flow. Ticket FLUID SAMPLE DA'I ,, Dote 11-29-75 Number 607944 .......... Sampler Pressure .P.S.I.G. at Surface Kind Halliburton ' Recovery: Cu. Ft. Gas of Job HOOK WALL District ANCHORAGE ;. ........ cc. Oil , cc. Water Tester MR. BOWEN Witness MR. TtlOMA .... '' cc, Mud Drilling Tot. Liquid cc. Contractor BRINKERHOFF DRILLING COMPANY BC S Gravity ' APl @ °F. EQ U I PM E N T &' , C~s/Oil Ratio cu. ft./bbl. Formation Tested.. High.· Press.ure...0i 1 S~nd ...... RESISTIVITY CHLORIDE Elevation 155' GL Ft. CONTENT .. Net Productive lnterval 13' 15013' - 15026' ,, Ft. · Recovery wa'ter @ °F. ppm All Depths Measured From - Recovery Mud ~ @ °F. ppm Total Depth Plug..Back Depth ?? Ft. Recovery Mud Filtrate ~@~°F. ppm Main Hole/Casing Size9 5/8'.'. Casing & 7',' ,,32# Finer Mud Pit .Sample @ °F. ppm Drill Collar Length280,01' I.D.2.25" Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length10324.71 '-4320.66.b. 4.276"-2.764" Packer Depth(s) 14962 ' Ft. 'Mud: Weight 12.9 vis 66 Cp' D. ,epth Tester Valve 149 37' Et. TYPE AMOUNT Depth Back Surface Bottom C_~shi~n 9200' Water . . Ft. Pres. Valve ....... 14926' Choke ~,, Choke ½" · '. Recovered Feet of Recovered Feetof ~ : ~ ~i ~ ~ ;~"~ ~ .... · -i < Recovered Feet of .......... Recovered Feet of Remarks Tool opened for a 20 minute first flow with a light bubble hose blow. Closed tool for 62 minute first closed in pressure. Reopened to01 for 112 minute second flow with a light bubble blow decreasing to dead in 5 hours Closed tool for 647 minute second closed in pressure. CHARTS INDICATE TOOLS PLUGGING DURING FINAL F[O~ PERI'0D. ONLY '11"2 MIN ~L CLOSED IN PRESSURE INCREMEHTED TO POINT WHERE TOOLS APPARENTLY WEI~E MOVED ..... r Gauge No. 1107 Gauge No. 1108 GaUge'l~lo. TEMPERATURE TIME Depth: 14951 ' Ft. Depth: 14976' -... . ................ 48 HourCIock 72 Hour CIock HourClock Tool I I'L'2'9'-75^.M. ~ ~st.. 240 'F. Blon'ked~f,.No BiankedC~f Yes Opened 5'00 A.M. . Actual 'F. Pressures ~ Pressures Pressures Bypass I 1 - 30 P.M. Field Office Field J Office Field Office Reported Computed -initial H~,dr:~st~tic 9988 ..... 9963 Minutes Minutes ,~ ~nitia~ 4371 4364 ~'c Flow ............ ~-~. .... Final 4484 4444 20 20 Closed ir~' ..... 7923 791'2 " 60 62 ....... 'o~o Initial 4496 ...... 420'1. ' ........ c.g Flow ......... ~ ~in~ 408'~ 4033 360 112_~ Closed in 8635 __ , ,-IniiiaI ,. . ~ Flow ........................ ~.~. Final Clos,d in ....... ']Fi^al H'¥d~0s,~,ic ......... 9502_Q ' 940-8 ..... ............. Q = ,Quest. i,onat~le ................. m ---t -T- o o o LITTL£'$ 96~71 lam 1/74 (D Gouge No. 1107 j Depth First Flow Period Time Deft. PSlG Temp. .000" Corr. .0000 4371 · 0068 4391 .0136 4423 · 0204 4444 .0272 4516 .0340 First Closed In Pressure .~ PSIG Time Deft. Log Temp. .000" Corr. · oooo ,4484 .0134 6512' · 0235 6940 7186 .O436 7377 7_5._06 76]9 7721 780Z__ 7866 7923.. J Gouge No. L_0.~._000o ] ii!' 0038 .0076 .. .0114 ! 4, ·0152 -s ·0190 12 Readinm Interval , . · REMARKS: 1108 4364 It .0000 4377 4402 4444 4452 4444 .0090 .0158 .0226 .0294 .0361 .0429 .0497 .0565 .0632 .0700 Depth 4444 6540* 6941 7226 7389 '7531 , ._ 7623 7715 7799 7866 7912 14951 ' Second Flor Period Time Deft. .000" 0000 · 1870 PSIG Temp. Corr. 4496 4081 Clock No. 10054 Second Closed In Pressure Time Deft. .000" .0000 .0787 .1624 PSIG Temp. Corr. 4081 7049** 7429 .2461 7680 PLUGGI I, IG... . 3298 7862 .4135 8000 .4971 8137 .5808 8245 .6645 .7482 · 831 9 .9156 .9993 14976' I'OOL MOV 1.0830 AFTER 1.6510 8321 8398 8474 8534 859O 8635 !MENT 8948 .0000 Clock No. 13867 .1270 PLUGGI~ 4201 4033 .~e e e *Interval : 8 minHtes **Incerval= 47 minu_tes .0000 _-0.525_I lO841 .3319 .3878 .4436 .4995 .5554 .... 6!_1_3 · 66_7! I ,7230_ A_ .F T E _ R__ ~T_O_O]._~] 1. ogsflt _4Q33 . Z046'* 4Z2.3 7657 -782_~ 7.9_Z9 . 8O88 8193 8282 8357 8.4.29 8~87 85_42 8597 !FJ.!ENT 50 JTicket 48hour No. Third Flow Period Time Deft. .000" PSIG Temp. Corr. 72 hour 607944 Third Closed In Pressure Time Deft. , t + (~ .000" '°gT I PSIG Temp. Corr. Minutes o .... , .... .~,,~=~,.u ..... SPECIAL PRESSURE DATA LITTL£'$ 96673 75C 8,/74 TICKET NO. 607944 Drill Pipe or Tubing ................ Reversing Sub ...................... Go g. 11 Water Cushion Valve ................ Drill Pipe ........................ 5" '- 3~" Drill Collars ...................... ,,4 3/4" Handling Sub & Choke Assembly ...... 5" Dual CIP Valve ................... 3.75" Dual CIP Sampler .................. Hydro-Spring Tester ................ - 3.90" Multiple CIP Sampler ......... · ...... Extension Joint ........ (.2) ......... 3.88" AP Running Case .................. 3.87" Hydraulic Jar .................... 3.88" VR Safety Joint ................ 3.88" Pressure Equalizing Crossover ......... Packer Assembly ................... 5.75" Distributor ........................ Packer Assembly .......... ~ ........ Flush Joint Anchor ................. Pressure Equalizing Tube ........... · Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ 2 7/8" 3.87" Packer Assembly ................... Distributor ........................ Packer Assembly ... ................ / // · Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... e' ' !. D. LENGTH DEPTH 4.276"-2.764", 2.25" ' . 5II °87" · 50" · 88" 3" · 75" 2,36" 2" 3" 12" 14824' 10324.71' - 4320.66' 280.01' 54" 64.9,7" 114.20" 14937' 50.43" 50.43" 46.20" 14951' 31.84" 30.32" 45.62" 14962' 8' 48.34" 14976' ????PBD -NOMENCLATUP. E b --- Approximate Radius of Investigation ........................ Feet 13~ -- Approximate Radius of Investigation (Net Pay Zone h~) ......... Feet D.R.-- Damage Ratio ............................................ El =_ Elevation ' Feet GD = B.T. Gauge Depth (From Surface Reference) ............... i...Feet h --- Interval Tested ......................................... Feet h~. -' Net Pay Thickness ' Feet K --' Permeability ' ' md K~ '-' Permeability (From Net Pay Zone hl) ....... . ................. md m -- Slope Extrapolated Pressure Plot (Psi2/cy. cle Gas) .............. psi/cycle OF~ ~ Maximum Indicated Flow Rate ............................ MCF/D OF2 -- Minimum Indicated Flow Rate ............................ MCF/D OF3 -- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF4 "- Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D P s --' Extrapolated Static Pressure ............................... Psig. P F -- Final Flow Pressure ............................... : ...... Psig. P °t o -- P°tentiometric Surface (Fresh Water * ) ...................... Feet Q = Average Adjusted Production Rate During Test ................ bbls/day -- Theoretical Production w/Damage Removed ................ ... bbls/day --Measured Gas Production Rate .......... . .................. ~CF/D R -- Corrected Recovery ...................................... bbls r w -- Radius of Well Bore .... - ........... · ....................... Feet t --- Flow Time ............................................. Minutes t o -- Total Flow Time ................... ~.'. ...... .' .............. Minutes T -- Temperature Rankine ...... .............................. °R Z -- Compressibility Factor ...................................... ,/U '-' Viscosity Gas or Liquid ................................... CP Lo9 = Common Log * Potenfiometr;c Surface Reference to Rotary Table When Elevation Not Given, Fresh Woter Corrected to I00° F. /! i Beaver Creek Well #5, Redrill Zone Perforation Record Date F rom To Gun' S i ze HPF 02-05 02-07 02-08 02-26 O3-Ol '03-02 03-02 '03-03 15,488' 15,488' I5,468' 15,483' 15,450' 15,410' 15,366' 15,508' 15,504' 15,488' 15,493' 15,468' 15,460' 15,430' 15,386' 2-1/8" 2-1/2" 2-1/2" 1-3/4" I-3/4" 1-3/4" 2 2 4 4 2-1/2 2-1/2 2-1/2 4 4 F~OR~ 484, R~v. 3-63 DATE 04- 21 - 76 ~I~:~ATH~::~N t~IL COMPANY HISTORY OF OIL OR GAS WELl_ FIELD ___B_~aver Creek _ WELL NO. _ 5,1R ~ . LEASE. Beaver Creek PARISH Kena i STATE Alaska COUNTY Peninsula BoroU9h KB ELEV. 177' ~toP Or OIL STRING MEASUREMENTS ! kToP OF ROTARY TABLE__ TAKEN FROM / LgrD. or MAT. I ELEV. __ ELEV. ELEV. _~-~ BLOCK SEC. i 34 TWP. 7N r. lOW HISTORY PREPARED BY K. A. Thorne TITLE Dri 11 in.q En.qineer It is of the greatest importance to hove a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1975 o9-13 1o-17 - ll-O1 11-02 11-o3 11-o4 11-o5 11-06 1t-07 11-08 t!-09 ti-I0 WELL HISTORY - BC 5, REDRILL (Marathon AFE 1702) NOTE: Report is to 7 AM for previous 24 hours operation. Pulled BPV. RU DA. Perf tbg, 4 HPF @ 14,887'. HOWCO displ hole w/ 740 bbls mud. SI well. RU Brinkerhoff Rig No. 43. Rig accepted 12 Noon, 11-01-75. RU Otis to pull BPV. Mixed 300 bbls mud & laid kill line to well. Thawed Xmas tree. Pulled BPV. Filled hole w/ 45 bbls mud. Circ out gas-cut mud. Mud wt in 10.5, out 9.1. incr mud wt to 11.5. Mud out now @ 10.3. Circ & cond mud to kill well down tbg & up annulus against ½" choke. 7.2#/gal return gas-cut mud. Circ to ll///gal. RU Otis. Tested lub to 2500 psi. Set BPV. RD Otis. Removed Xmas tree. Began flanging up BOPE ~ 4 AM. Flanged up BOPE. Installed kill line, choke line, flow lines, accumulator lines, chg pipe rams from 5" to 3{-", and PU landing jr, screwed into tbg hgr, & closed pipe rams. Tested w/ Koomey pump. Repaired 2 leaks in kill line. Attempted to press up rams & leaked. Bag preventor held. Called out Shaffer service man. Installed a set of 48 series, 3½" pipe rams--would not hold. Installed set of 60 series 3½"--tested to 5000 psi & held. Koomey pump control failed--repairing controls. Installed kill line. Tested kill, choke, & choke manifold to 5000 psi--held OK. Tested bag preventor to 2500 psi--OK. Mixed & built mud volume before pulling tbg. Finished testing BOP & mani-fold equip. PU & worked tbg (~} !30,000#. Tbg parted in hgr. PU OS. Engaged Fish (~ 60'KB. Pull in9 th9 i~ 80 ,ooo#. Cont laying down 3~-" tbg 0700 hfs to 17OO hrs. Unloacted 8500' 5" DP, Chg pipe rams to 5" PU 7-5/8'.'"x 3-~;TM OS. RIH w/ 5I' DP. Rubberi ng DP. RIH w/ 5" DP. Engaged fish S 81OO' hole & cond mud. POH. Vlorked out of: pkr. Circ Welt History - BC 5, .-~ Page 2 11-12 11-13 11-14 11-15 11-16 11-17 11-18 11-19 11-20 11-21 11-22 11-23 11-24 11-25 tl-26 1-27 ]1-28 15,555'PBTD 15,330'PBTD 15,330'PBTD 15,330'PBTD 15,330'PBTD !5,330'PBTD 15,330'PBTD ') PBTD t5,3~0' Finished PU DP. Tag pkr ~ 14,931'. Milled to 14,933' Circ hole. POH. No rec. Test BOP. RIH w/ mill #2. Lost wt. RIH w/ mill #2. Engaged fish @ 14,931' Worked fish up hole. Lost wt. POH. No rec. RIH w/ mill //3 w/ 16' WP on btm. Milled on pkr 5 hrs. POH. Rec mandrel & slip assy. RIH w/shoe //4. RIH w/ mill shoe #4 to 14,933' Milled ~. hr. Pkr came loose. Pushed pkr to 15,390' (top of perfs in G Zone). POH to chg mill shoe. RIH w/ mill shoe #5. RIH w/ mill shoe #5. Milled over junk 3-~- hrs. Made 3' POH. Rec small parts of pkrs. RIH w/ mill shoe #6 to 15,393'. Milled to 15,412'. DP torqued up & lost 40,000// wt. POH. Finished POH. 3½" DP had back off @ 12,689'. Left 2749.89' of drl string in hole. R1H w/ OS. Tagged fish ~o 12,689'. Could not get over fish. POH. RIH w/ 3½'~ IF pin tap. Screw into fish. POH. Rec fish. Found split box on DP. RI H w/ mill shoe. Finished running mill shoe #7. Broke & checked all tool jts on 3½" DP. CO 15,440' - 15,479'. POH. CO junk basket. RIH w/ mill shoe #8. Tagged pkr #2 @ 15,479'DPM. Milled on pkr #2. Came loose. Went down hole. POH. Replaced mill. Milled on pkr #3 from 15,480' - 15,484I. POH. Milled & pushed pkr to 15,555'PBTD. Circ hole clean. Laid down 4-3/4" DC's. Finished laying down 4-3/4" DC's. Ran in OEDP. Set 30 sx 14.5# cmt plug from 15,536' - 15,397'. Rev out DP. POH. PU HOWCO cmt ret. Finished RIH w/ ret. Set ret.@ 15,330'. Break down press 3000 psi @ 2 BPM. Mixed 150 sx 15.5# slurry. Initial press 2600 psi, final press 3600 psi. Left 15 sx on top of ret. Rev out DP. BIdg mud wt. Built mud wt to 12.8#. POH. Tested BOP @ 5000 psi. Tested lines & manifold to 5000 psi. Flanged up & tested lub. Tested lub to 1500 psi. RIH w/ GR & clr log. Perf w/ 4 ½" holes @ 14,9OO' Ran Halliburton cmt ret on WL @ 14,832'. RIH. Cmtd w/ 200 sx class G 4% gel, 18% salt, 15.5# slurry. Min press 3000 psi @ 2 BPM, max press 4800 psi. Break back to 3000 psi over displ cmt. Prep to re-cmt. (Block sqz ~ 14,900' to isolate HP wtr sd @ 14,700' from HP oil sd @ 15,013'.) Circ & cond mUd ~ 14,830'. Stab into ret. Broke down. 4700 psi ~ 2 BPM. Sqz w/ 200 sx type G, 15# slurry. Min press 3500 psi, max press 4200 psi. Overdispl--rev circ. Started sqz //3 ~ 6'30 AH Finished cmt sqz ~ 14,900' Broke down 1-~- BPM ~ 4500 psi, 150 sx class G, 1% CFR-2, 0.5% HR7, 15.7# slurry. Min press 3300 psi, max press 4500 psi. Rev out. WOC. POH w/ cmt tools. RIH w/ 5-7/8" bit. Drld cmt & ret. Tested ~ hr Held OK to 3000 psi for :~- . . RIH w/ 5-7/8" bit & csg scraper to 15,249' Circ & cleaned tip hole. RU 7" lub. RIH w/ Schl GR, clr locator. Perfd 4 HPF w/ csg gun from 15,013' - 15.,026~WLM. POll. RD Schl & lub. Instal ling drlg nipple. Instal ted Otis test separator. Well History - BC 5, .~D 'Page B 11-30 12-01 12-02 12-03 12-O4 12-05 12-06 12-07 12-O8 12-09 12-10 12-11 12-12 t2-13 ]2-14 12-15 15,330'PBTD 15,330'PBTD 15,330' PBTD 14,984'PBTD 14,984'PBTD 14,984'PBTD 14,984' PBTD 14,984'PBTD 14,984' PBTD 14,984'PBTD 14,984'PBTD t4,984'PBTD 14,984'PBTD 14,984'PBTD 14,984'PBTD 1J' 98L:- ' PBTD Made up Halliburton test tools. RIH. Tested all surface lines to 2000 psi. Set pkr ~ 14,962'. Tail pipe @ 14,980'. DST #1, perfs 15,013' - 15,O26', pkr @ 14,962', 9200' wtr cushion. IH 9959 psi IF 30 min 4504 psi ISi 1 hr 7953 psi FF 6 hrs 4093 psi FSI 12 hfs 8972 psi Recovery: 9200' wtr cushion, 3380' (25 bbls) mud & wtr. Cont DST #1. Info on report dated 11-30-75. POH w/ test tools. RIH w/ 5-7/8" bit. RIH to 15,330' Circ hole clean. POH w/ bit. RIH w/ cmt ret. Set @ 14,984' RU Halliburton. Break down 4100 psi @ 1½ BPM. Sqz perfs 15,O13' - 15,026' w/ 150 sx class G, 1% CFR-2, 0.3% HR7, 15.5# slurry. Min pumping press 2000 psi, max press 3100 psi. Final press 3100 psi. CIP @ 6:30 AM. Rev circ. Cond mud. POH. Made up Servco section mill. RIH to 14,918'DPM. Started milling window. Milled section in 7" from 14,918' - 14,961'. Finished milling 7" section from 14,961' - 14,978' @ 11 AM. Circ from 11 AM to 4 PM. Cut mud vis from 250 cc to 130 cc. Started out of hole. Pulled to 11,690'. Pipe stuck. Attempted to circ. Would not come loose. Preparing to run free point. RIH w/ free point. Pipe free to the tool. Ran back-off 1 DC above tool. Did not back off. Ran back-off #2 two I)C's above tool. Would not back off. Ran back-off //3 two jts above tool. Backed off. Started' POH. PU tools. RIH. Circ & cond hole. RIH. Attempted to screw into fish. Couldn't catch fish. POH to 5985'. Draw works main input shaft failed. Shut down for rig repairs. Repairing draw works. Pulled bearing on input shaft. Circ @ 5985'. Work on draw works. Circ @ 5985'. Finished rig repair @ 4:30 AM. POH. PU OS 10' WP extension, oil jars, bumper sub, six 4-3/4" clrs, accelerator jars. Pump out sub. Tagged on fish. Circ 2 hrs. Went over fish--couldn't circ. Bumped down on 'Fish 2½ hrs. Moved fish 9'--tools stopped working. Couldn't get off fish. Ran free point. Last free point 11,550'. Will back off @ 11,535' Dia-log backed off @ 11,534', Rev circ 13' hrs. POll. Laid down 1 DC. Made up Tri-state mill shoe, 2 jts VIP, four l~-3/4'~ clrs, 2 bum. per subs, oil jars, six 6-1/4" DC's, accelerator jars, and 5'~ DP. RtH to top of fish ~ 11,531~' RIH w/ WO pipe. Tagged fish r~ 11,534' WO fish to top oF Rev circ on btm ½ hr. PU to 11,532'. Rev circ 2 hrs. POI4 w/ WP. RIH w/ screw-in sub. Jarred on fish /,."~. Came loose. POH. Rec all of fish #2. Finished laying down fish ,i:2. RIH w/ mi il shoe $ WP. Tagged Fish ? 11,584~ Washed to 11,650' (7 hfs). Rev circ 2 hrs. POH w/ WP. pIJ fishing string for 'Fish //I. Well History - BC 5, ~,~ Page 4 12-16 t2-17 12-18 12-19 12-20 12-21 12-22 12-23 12-24 12-25 12-26 12-27 12-28 ~2-29 ~2-30 14,984'PBTD 14,984'PBTD 14,902' PBTD 14,928'PBTD 14,957'TD 14,986'TD 15,000'TD 15,000'TD 15,0OO'TD 15,037'TD 15,073'TD 15,081 'TD 15,~35'TD i5,1~0'TD 15,21 t 'TD Finished RIH w/ 3½" screw-in sub on three 4-3/4" DC's w/ 2 bumper subs & oil jars, six 6-1/4" DC's, accelerator jars, & six 6-1/4" DC's. Screw into fish ~ 11,584'. Jarred up 4 times @ 385,000#. Fish came loose. POH to top of lnr--dropped tool to open pump out sub. POH & rec all of fish. Laid down WP & fishing tools. Tested BOPE (blind & pipe rams to 5000 psi, Hydril to 2500 psi). Ran bowl protector. RIH w/ 3~-" DP & pulled rubber pipe protectors on 3½" RIH OEDP to set plug. RIH to 11,640' & rev circ. RIH to 11,702', rev circ. Rev circ @ 11,733', 11,764' & 11,952I. Rev out fine cuttings & cond mud. RIH to 14,90~'. Circ btms up--well fluids clean. RIH to 14,984' & circ & cond mud. PU to 14,980' & pumped 10 bbls wtr, 50 sx class G, 1% CFR-2, 0.66% HR-12, mixed volume 57 ft3, 16# slurry, and 10 bbls wtr behind, followed w/ 1177 ft3 mud. Cmt plug in place @ 5:40 AM. POH 200' to 14,778' & rev out. Plan to WOC 24 hrs. Rev mud circ @ 14,778'. Rec 20 bbls wtr & approx 1 bbl cmt. POH to 14,685'. Circ to clean DP. Pulled 7 stds. Closed Hydril & held 800 psi for 2 hrs. POH & PU drlg assy. RIH to 13,936'. Circ & WOC. RIH to 14,758'. WOC. Samples in cups still soft. Circ & WOC @ 14,778' RIH & tagged cmt @ 14,902', 2:30 PM, held 20,000# @ 1800 psi. CO 14,902' - 14,908' w/ 5000# in 5 min. WOC & cir¢ 7:30 PM, 20' in 30 min. Drld to 14,928'. Circ hole & POH. PU DD & tools. RIH. Finished RIH w/ DD, filling DP every 25 stds. Orient DD. Drld from 14,928' - 14,957'. Drld w/ DD to 14,958'. DD stalled out. POH to 14,928'. Circ hole clean. POH. Laid down DD. Made up drlg assy. RIH. CO to 14,958'. Drld to 14,986'. Drld 14,986' - 15,000'. POH to 14,909'. Circ hole clean. Transfer mud to storage. Clean mud system. Haul oil-based mud from storage. Cond mud. Re-cond oil-based mud. Raised wt from 10.2 to 12.1. Displ hole. Cond oil-based mud. Build mud wt to 12.2. On btm drlg @ 3 AM. Drld to 15,037'. Circ. Drop survey. POH to 14,910'. Attempted to ret survey w/ WL. Couldn't ret. POH to chg bit. RIH. Ream 30' Drld to 15,067' Ran survey--no reading. Drld to 15.,073'. Ran survey--no reading. Drld to 15,081'. Drop survey. POH w/ bit #5. Cut drlg line. RIH w/ bit ~,6 Finished TIH. Drld to 15,135' No survey. RIH. Drlg ~ 7 AM. Surveyed. Trip out to chg bit. Drld to 15,179' Drop survey. POH to chg bit. No survey. RIH. Drld to 15,190'. Drld 5-7/8" hole to 15,211' On btm drlg ~ 7 AM. Drop survey. Trip for' new bit /!9. 12-31 15,237'TD brld from 15,212' - 15,237' No survey, \Va!! History - BC 5, Page 5 1976 O1-01 O1-02 01-03 01-04 . . 01-05 01-06 ol-o7 01-08 01-09 O1-10 01-11 01-12 01-13 01-14 o]-15 0~-16 15,256~TD 15,276'TD 15,293'TD 15,311'TD 15,353'TD 15,373'TD 15,405 ' TD 15,427'TD 15,458'TD 15,493'TD 15,52I 'TD 15,552'TD 15,567'TD 15~533'TD !5,o21 'TD 642 'TD Dropped survey. Tripped for bit //10. Laid down jars. RIH. Drld 15,239' - 15,256' Drld to 15,265'. Ran multishot angle surveys. POH. Tested BOPE--OK. RIH w/ bit #11. Drld to 15,276' Multishot surveys as follows' Depth Ang 1 e Depth Ang ! e~ 14,890 14,930 14,962 14,994 15,024 15,056 26-1/4 15,087' 26 26 15,119' 25 26-1/4 15,151' 24-1/4 28 15,182' 24 28-3/4 15,214' 22-1/4 28 15,249' 22 Drld from 15,276' - 15,293'. Dropped multishot survey. Surveyed from 15,273' - 14,860'. POH for bit #12. Drld to 15,303'. No reading on multishot survey. Drld to 15,311'. Circ & RU DA. Ran Sperry-Sun gyro & DA CL. Surveyed from 15,290' - 14,900' Gyro indicated that side- tracked hole was drlg approx 15' below & to the right of the old wellbore. Drld 5-7/8" hole from 15,324' - 15,353'. Tripped for new bit. 1½ hrs spent repairing compound chain. Ran back w/ bit //14. Finished RIH w/ bit //14. CO bridge from 15,117' - 15,132'. RIH.& drld 15,353' - 15,373'. Dropped survey. POH. Cut drlg line. RIH. RIH w/ bit //15. Bridge @ 15,069' Drld ahead to 15,405'. (Gradually raising visc.) Drld to 15,427'. Tripped for new bit. Had tight hole for 30' off btm. Finished RIH w/ bit //16. CO 15' fill to btm ~ 15,427', Drld to 15,458'. Surveyed. Tripped for bit. Did not rec survey-- instrument came apart in pipe. RIH w/ bit //17. Found survey instrument lodged in x-over between 5" & 3½" DP. Drld to 15,493'. Dropped survey. Finished tripping out of hole for new bit. Trip for new bit. Repair rotary master chain. Finished trip. Had 5' fill on btm. Drl'd 15,493' - 15,521'. POH for new bi.t. Finished trip. RIH. CO 15' of fill. Drlg 5-7/8" hole ~ 15,552'. Drld to 15,567'. Tripped for new bit. Ch9 bit & cut drlg line. RIH w/ bit #20. Finished RIH w/ bit //20 & CO bridge ~ 15,387'. Drld from 15~567' - 15,593' POH for new bit. RIH w/ bit 1 CO 15 535 - 15 593' , - 15,621 #2 . , ~ , . Drld 15 593' ' Dropped survey. POH to chg bit. Testing BOPE. Pulled test plug after testing BOPE. RIH w/ bit #22. CO 15,600' - 15,621' Drld to 15,642' Dropped survey & started out of hole. Well History - BC 5, RD Page 6 01-17 01-18 01-19 O1-20 O1-21 O1-22 ? 01-23 01-24 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD POH to chg bit. RIH. Drld 15,642' - 15,655'. Drl string torqued up. POH. Tight hole 15,655' - 15,545'. Worked & circ out of hole to 14,918' (7" csg shoe). Cond hole. Ran. back in hole. Had bridge @ 15,606'. Wash &circ to btm. C irc & cond mud on btm to cond for OH logs. Circ & cond mud. PU to 14,900' Wait -~~ hr & ran back to btm. CO 8' fill. Cond hole. Dropped survey. POH. Strapped DP. No correction. RU Schl. Ran DIL, GR-BHC Sonic, FDL/CNL from 14,918' - 15,612'. Finished logging. RD Schl. RIH w/ drlg assy. CO 20' fill. Circ & cond mud 4 hrs. POH. Tight hole 15,635' - 15,438'. Pulled to 14,900'. SD 1 hr. RIH. Had 5' fill. Circ & cond mud 3¼ hrs. POH to 14,900'. Tight hole @ 15,615'. (Will make one more wiper trip.) RIH to TD. 6' fill on btm. POH. RU & ran 22 its 5" 18//, P-110 FJ-P Hydril lnr w/ TIW hgr. Circ lnr shoe to 15,652'. Set lnr hgr @ 14,732' & top of lnr tie-back @ 14,693'. Cmt clr @ 15,607' & shoe @ 15,652'. Backed out preparing to cmt. See below for 5" lnr detail: 5" LINER DETAIL i rem Length From T~o TIW PBR w/ 6' Tie-back sleeve on top X-O, Hydril FJ-P Down X 8rd Up TIW Lnr Hydro Hgr 21 jts 18//-Hydril FJ-P P-110 lnr TIW Landing Clr 1 jt 18# Hydril FJ-P P-110 TIW Diff Fill Shoe 39.02' 14,692.72' 14,731.74' .72' 14,731.74' 14,732.46' 5.82' 14,732.46' 14,738.28' 868.50' 14,738.28' 15,606.78' .76' 15,606.78' 15,607.54' 42.56' 15,607.54' 15,650.10' 1.90' 15,650.10' 15,652.00' Top of Liner @ 14,693' Top of Liner Hanger @ 14,732' Top of Landing Collar @ 15,607' Bottom of Shoe @ 15,652' Dropped ball & set TIW Hyd hgr w/ 2200 psi & 30,000// wt down. Pumped 7 bbls diesel w/ Hy-flo & 7 bbls mud flush ahead of 125 sx class G cmt w/ 18% salt (by wt of mix wtr), 1% Halad 14, O.1% HR-12 (slurry wt 15.7#/gal). Displ cmt w/ 218 bbls mud & PU lnr wiper plug. Displ lnr w/ 15.5 bbls & bumped plug w/ 2000 psi. Floats held OK. Job by HOWCO. CIP @ 7:20 AM, 01-20-76. Rev c irc but rec. no cmt. Finished trip w/ 4-1/8" bit. CO lnr to 15,607' RU DA. Prep to run bond log. Cond hole. POH. Ran DA CBL & GR/CCL logs. RD DA. Logs indicated good bond across G sds. PtJ & ran HOg/CO 7" E-Z Drill ret. Set ~ 1/~,490:. Broke down 1hr lap w/ 4800 psi ~! -~ BPH & incr rate to 2 BPM ~ 3500 psi. Cmtd w/ 175 sx neat cmt. Final rate 1 BPM @ 4000 psi. Over-displ 1hr ]ap. Job compl ~ 7 PM. Re-cmtd ~ 5 AM (sqz #2). Broke down lap w/ 4200 psi C~ 1 BPM. Cmtd w/ 150 sx t5.5# slurry. Stii] pumping ~ 1½ BPM @ 4200 psi !~ report time. Finished sqz #2 w/ final press 3100 psi. Would not hold so cleared lap. Rev circ. WOC. Stabbed back into ret {!i 3'30 PH & broke down w/ 5200# ~ 3 BPM. Sqz w/ 150 sx 18% salt, 15# slurry. Initial rate 3 BPH {~ 4000 psi. Sqzd ~! l.~500 psi & held. Rev o~t 25 sx cmt of DP. Laid do,.,;n tool':;. Te~te{I goP~. ¥10C. Well History - BC 5, RD Page 7 01-25 O1-26 O1-27 01-28 01-29 O1-30 O1-31 O2-01 02-02 02-03 O2-O4 15,655'TD 15,655'TD 15,655'TD t5,655'TD 15,655'TD 15,655'TD 15,6551TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD Finished test BOPE. RIH w/ 5-7/8" bit. Circ & WOC. Drlg on ret @ 14,490' Drld cmt from 14,510' - 14,693'. (Top PBR.) Circ hole. POH. Put on 4-1/8" bit. RIH. Drld cmt to 14,730' Tested tnr lap to 2500 psi for 30 min--held OK. Drlg & pushing cmt plug to 14,740' Drld & pushed plug from 14,730' - 15,607' POH. PU TIW mill & RIH to polish PBR. Circ hole clean. Finished TIH w/ mill to dress PBR. Polished PBR. POH to top of lnr. Cond mud for storage. POH. Making up HOWCO test tools to run dry test on lnr lap. Made up HOWCO test tools for dry test on lnr lap. RIH & set RTTS pkr @ 14,623'. Tool open @ 12:50 PM. Very light blow for 5 min & died. Open 6 hrs & then SI 4 hrs. Lost 8' mud from annulus. Open circ sub. Rev out 5 bbls 12.8// mud. Rel pkr @ 2:45 AM. POH. Finish POH & laid down HOWCO test tools. RIH w/ OEDP. Had 60' fill on btm. Circ clean to 15,607'. POH. PU HOWCO 5" RTTS pkr. RIH to 15,597'. Prep to circ diesel. Circ & cond mud. Displ mud w/ diesel. Final circ press 4450 psi. POH to 14,792'. Pkr had drag from 15,582' - 15,510'. Set pkr @ 14,792' & hooked up dead wt tested & Camco recorders. Si well ~ 4 AM. After 3 hr SI, had no press incr on DP or annulus @ surface. Finish running lap test w/ diesel in hole. No incr on DP, 20# incr on annulus in 6 hrs. POH. Laid down 2-7/8" DP & took rubbers off 5" DP. PU TIW PBR 5" spacer & Baker Model F-1 pkr. Set pkr ~ 14,677'. RU to lay down DP. (Detail of TIW PBR & Baker pkr is shown w/ 3½" tbg tally.) Circ hole & POH. Laid down DP. Moved DP off location. Moved 3½'~ tbg to location. Laid down DCls. Pulled wear bushing. Chgd 3½" rams. Prep to run tbg. RU DA & ran gage ring & clr locator to 15,494' to check pkr & PBR--all OK. RD DA. PU 3½Il tbg, Baker stinger & circ sleeve, and gas lift mandrels. Test mandrels to 5000 psi, tbg to 8000 psi w/ Gater Hawk. Had 211 its in hole @ 7 AM. Finished running 476 jts 3½" Buttress tbg (w/ Atlas-Bradford modified couplings). Test tbg to 8000 psi, mandrels to 5000 psi. All gas lift mandrels open & circ sleeve closed. Spaced tbg & test hgr--OK. BAKER PACKER & TIW SEAL ASSEMBLY DETAIL ! tern Length Fro__m To #83-40 Baker Model F-1 Pkr 1.58' Seal Bore ExtenSion, 4'~ID 5.04' Seal Protector, 4¼'~ ID 16.40' Chg over 8rd x 3~-~ Butt 4~-'~ I D 0.98' TtW Seal Assy w/ Locator Sub (5.50'~0D) & Chg over clr (3.00"ID) on seal nipple 34.10' 14,667.00' 14,668.58' 14,673.62' 14,690.02' 14,691.00' 14,668.58' 14,673.62' 14,690.02' 14,691.00' 14,725.10' Weli History - BC 5, RD Page $ 3½" TUBING DETAIL I tern Length F rom To_ KB to Btm of OCT Hgr 22.40' 22.40' (incl 0.80' for hgr) 1 jt 9.2#, Butt., N-80 Tbg 7.35' 22.40' 29.75' Pup 7 jt 9.2#, Butt., N-80 Tbg 214.25' 29.75' 244.00' 1 Otis Vall Valve (2-75" 2.50' 244.00' 246.50' ~D) 96 jts 9.2#, Butt., N-80 2,904.69' 246.50' 3,151.19' Tbg 1 Camco MMG GL Mandrel & 8.72' 3,151.19' 3,159.91' Macco Valve #7 46 jts 9.2#, Butt., N-80 1,406.97' 3,159.91' 4,566.88' Tbg 1 GLV (//2) same as #1 8.72' 4,566.88' 4,575.60' 42 jts 9.2#, Butt., N-80 1,269.O2' 4,575.60' 5,844.62' Tbg 1 GLV (//3) same as #1 8.72' 5,844.62' 5,853.34' 39 jts 9.2#, Butt., N-80 1,195.27' 5,853.34' 7,048.61' Tbg 1 GLV (//4) same as #1 8.72' 7,048.61' 7,057.33' 36 jts 9.2//, Butt., N-80 1,098.76' 7,057.33' 8,156.09' Tbg 1 GLV (//5) same as //1 8.72' 8,156.09' 8,164.81' 32 jts 9.2//, Butt., N-80 981.95' 8,164.81' 9,146.76' Tbg 1 GLV (#6) same as #1 8.72' 9,146.76' 9,155.48' 30 jts 9.2#, Butt., N-80 920.84' 9,155.48' 10,076.32' Tbg 1 GLV (//7) same as #1 8.72' 10,076.32' 10,085.04' 29 jts 9.2//, Butt., N-80 888.83' 10,085.04' 10,973.87' Tbg 1 GLV (#8) same as #1 8.72' 10,973.87' 10,982.59' 17 jts 9.2//, Butt., N-80 516.56' 10,982.59' 11,499.15' Tbg 1 GLV (//9) 8.72' 11,499.15' 11,507.87' 23 jts 9.2#, Butt., N-80 711.32' 11,507.87' 12,219.19' Tbg 1 GLV (#10) USI-CF-2 s/s 7.82' 12,219.19' 12,227.01' Mandrel & Macco Press Valve 19 jts 9.2//, Butt., N-80 571.98' 12,227.01' 12,789.99' Tbg 1 GLV (#11) same as #10 7.82' 12,789.99' 12,806.81' 15 jts 9.2#, Butt., N-80 453.48' 12,806.91' 13,260.29' Tbg 1 GLV (//12) same as #10 7.82' 13,260.29' 13,268.11' 12 jts 9.2#, Butt., N-80 370.70' 13,268.11' 13,638.81' Tbg 1 GLV (#13) same as #10 7.82' 13,638.81' 13,646.63' 11 its 9.2#, Butt., N-80 333.47' 13,646.63' 13,980.10' Tbg 1 GLV (//14) same as ;~lO 7.82' 13,980.10' 13,987.92' 9 jts 9.2#, Butt., N-80 274.75' 13,987.92' 14,262.67' Tbg 1 GLV (~15) same as #10 7.82' 14,262.67' 14,270.L:9' 13 j~s 9.2#, Butt., N-80 403.49' 14,270.49' 14,673.98' Tbg I Baker Model L Sliding 3.07' 14,673.98' 14,677.05' Sleeve (2.87'~1D & I Baker Locator Sub (3~ID 0.83' 14,677.05' 14,677.85~ ~ ~-"OD) I Baker Model g Sea] Assy 20.44' 14,677.88' 14,698.32' w/ Hule Shoe (3'~ID) Well History - BC 5, ,~:D Page 9 02-05 O2-06 02-07 02-08 02-09 02-10 O2-11 02-12 O2-13 02-14 02-15 02-16 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15~655'TD 15~655'TD Finished removing BOP. Installed tree & tested to 5000 psi-- OK. Installed surface lines. Pulled BPV. Installed & tested lub to 3000 psi. Held OK. RU DA & ran clr locator, GR & Neutron log. Tool stopped @ 15,491'. PU & ran Otis bailer to clean out solids. CO to 15,501'. Rec barite fill that ap- parently fell out when circ out Invert mud ~,~/ diesel. Ran Otis bailer 'on DA WL. CO 15,491' - 15,510'. Ran Neutron log & perfd w/ 2-1/8'l Jumbo Jet w/ 4 HPF from 15,488' - 15,508'. RD DA. RD lub & prep to gas lift. Started gas lifting well @ 6'30 AM, 02-06-76. Rec 897 bbls diesel by 10 PM. Cont to GL to 2 AM. No rec. SI ~ 2 AM. No build up from 2 AM to 7 AM. SI well & bled off press. Load tbg w/ 75 bbls diesel. RU DA. Press tested lub to 2500 psi. Checked well for fill--OK. Ran 2½" Dresser bar gun & perfd 15,488' - 15,504' w/ 4 HPF. RD DA. Started GL @ 12:30 AM, 02-08-76. Rec 92 bbls diesel @7AM. GL well. Rec 126 bbls diesel. No fm fluid rec. Si. RU HOWCO & loaded tbg w/ 102 bbls diesel. RD HOWCO. RU DA. Tested lub to 2500 psi. Ran 20' 2½" Jumbo Jet bar gun, 4 HPF. Perfd 15,468' - 15,488'. RD DA. Started GL. Rec 170 bbls diesel by 5:30 AM. From 5:30 AM to 7 AM--no rec. GL well until 11 AM. Bled off csg & tbg. RU HOWCO on csg & tbg. Filled tbg w/ 30 bbls solvent in diesel & 74 bbls diesel. Filled csg w/ 764 bbls diesel. RU HOWCO on tbg to pump solvent into fm. Waited for daylight to press surface lines to 9000 psi. Repaired leaks. Press annulus to 3700 psi & tbg to 8700 psi. 14 bbls to bring up to press. Held for 2 hrs, but fm would not take fluid. Bled off press & RD HOWCO. Set BPV. Removed tree & started flanging up BOP. Flanged up BOP. Had trouble making BOP's hold press. Chgd ring gaskets. Tested to 4000 psi---OK. Tested Hydril to 2500 psi--OK. Test kill & choke lines & manifold to 4000 psi--OK. Pulled seal assy out of Baker F-1 pkr @ 148,000//. Pulling tbg. Finished pulling tbg. Dressed seals f/ Baker Model F-1 pkr. Ran 833' of 2-1/16" tbg below seal assy. RIH w/ 3½" tbg & installed Otis BV & tbg hgr. Circ hole & spotted 24 bbls acid. Displ w/ diesel w/ emulsion breaker in diesel. Closed BV. RD HOWCO. Installed BPV. Landed tbg & installed Xmas tree. Flanged up & tested tree to 10,0OO#. RU HOWCO. Tested lines to 9000 psi. Press up to 8500 psi & annulus to 3500 psi. Would not take fluid. Held press for 15 min. Press bled to 8000 psi. Pumped ½ BPM ~ 8500 psi. Rate incr to 1 BPH after pumping 20 bbls. SD 50 rain & press bled off to 6000 psi. Pumped 4 bbls ~ 1 BPM @ 6500 psi & SI. RD HOWCO. Started GL @ 4 PM, 02-13-76. Rec @ 6 AM was 516 bbls diesel. Cut .6% BSW, CP 1390 psi, TP (heading) 75 to 750 psi, GL Gas 1035 MCF. Gas lifted well & rec total of 901 bbls diesel by 12 Midnight. Circ gas. SI well but had no press build up on surface. SI well w/ no press build LIp. Bled press off cs9 & hauled diesel. RU HOWCO. Tested lines & tree 'to 9000 psi. Hauled & pumped 60 bbls of crude oil followed ~/ 25 bbls diesel w/ mutual solvent. Tbg press held ~ 1500 psi. Loaded annulus w/ 73L~ bbls diesel. Well History - BC 5, RD Page 10 02-17 02-18 02-19 02-20 02-21 02-22 02-23 02-24 02-25 02-26 02-27 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD Started pumping into fm @ 8500 psi. Pumped 54 bbls crude oil into fm in 12 hrs. Final rate 2.67 BPH (.25 ft3/min). Bled off to 7800 psi in 5 min, 7200 psi in 10 min, & 6700 psi in 15 min. RU Otis (slick line unit) to pull BV. Valve unseated but pulled tight. Jarred on tools & pulled out of rope socket. BV dropped down the tbg. Prep to fish BV w/ Otis braided line. RU Otis braided line w/ fishing tools to ret BV & BV ret tools. Fishing tools stopped ~ 2004' No rec. Ran impression block. No impression. Re-ran w/ no impression. Set BPV & pulled tree. Installed BOP & tested. Tested pipe rams to 5000 psi--OK. Manifold to 5000 psi--OK. Hydril to 3000 psi--OK. POH w/ tbg, checking GL mandrels. Found GLV #5 washed out. POH. Laid down seal assy. Laid down 2-1/16" stinger. Re-dressed seal assy f/ Baker Model F-1 pkr. RIH w/ seal assy & 3½': Butt., tbg (A-B Modified). RIH w/ 3½~' Butt tbg & GL prod equipmt. Ran Otis BV. Tested to 5000 psi--OK. Landed tbg & tested seals in pkr to 1500 psi--OK. Nippled down BOP & RU tree. Tested to 5000 psi--OK. RU GO & tested l ub. Tested GO lub to 2500 psi--OK. Ret dummy.BV. Ran GR/Neutron log. Stopped in stinger @ 14~653'. Pulled out & added sinker bars. Re-ran log. Tagged fill ~ 15,488'. Ran Otis 2-1/16" drive bailer ~ rec barite & shooting debris. RD GO & RU Otis. RU lub but would not test. Shut down. Waiting on new seals for Otis lub. Tested lub to 2500 psi--OK. Ran 2-1/16" bailer to 2004'-- would not go deeper. Found bad line. Cut line & RIH w/ bailer. Not enough line for safe operation. Otis began spooling on new line. Otis spooling on new line, but could not get line to spool. Released Otis @ 6 PM, 02-22-76. Never did get new line on drum. Camco RU & tested lub.' Ran Otis 2-1/16" bailer. Bailer stopped @ 1450I. Ran sinker bars & pushed to 1900'. Ran impression block--no impression. Ran inside spear. No rec. Ran JB. No rec. Suspect rubber from oil saver or lub is blocking tbg. Ran Camco WL inside spear w/ no rec. Obstruction ~ 1900'. Moved to 2300'. POH. Ran outside grab w/ no rec. Ran hydrostatic JB w/ no rec. Ran sinker bar & moved obstruction. to 2800'. RU HOWCO & circ 300 bbls diesel. Circ out parts of Otis lub. RU Camco & found obstruction ~ 2800'. Ran 1-5/8" sinker bars & pushed obstruction to 15,488' POH w/ sinker bars. RIH w/ sand pump. RIH w/ suction sand pump. CO fill from 15,488' to 15,590'. ~Jill check Camco's measurements w/ GO log. RD Camco & RU GO. Ran GR/Neutron & collar log. Tools stopped ~ 15,493'--not 15,590' POH. RU & ran Otis suction bailer on GO line. Stopped ~ 15,493' w/ no rec. Re-ran bailer--no rec. Re-ran bailer--no rec. Ran impression block. No definite impression. Ran magnet--couldn't get to 15,493' POH. RU GO. RIH w/ GR tool. Logging tool failed. POH. Ran Neutron log from 15,Zt93' -- 14,500' POH. RU & 'tested lub. PU 10' Swing Jet (1-3/4") gun & shot 25 holes from 15,493' - 15,483' SI 30 min. No press incr. POH. Started GL ~ 11 PM. Compressor went down @ 3:30 AH. ' Rec 116 bbls diesel to 3:30 AM. Well History Page 11 02-28 02-29 o3-01 03-02 03-03 03-04 o3-o5 03-06 03-07 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD ,655' 15 TD Repaired compressor & resumed gas lifting well. Compressor went down again @ 9:30 AM. Had rec 181 bbls diesel. Bled off press. RU HOWCO. Filled tbg & annulus w/ diesel & press up to 3500 psi on annulus & tbg. Tested lines & had a number of leaks in HO~ICO lines. SD until daylight to press up to 8500 psi. Tested HOWCO lines & put 3500 psi on annulus & tbg. Press tbg to 8500 psi. Had no bleed off. SI & RD HOWCO. Started gas lift ~e 2 PM, 02-28-76. Lifted 43 bbls diesel an hr from 2 PM to Midnight, 11.5 bbls/hr from Midnight to 6 AM, & 28 bbls/hr from 6 AM to 7 AM--all diesel. Rec total of 550 bbls. Cont gas lifting to 9 AM, 02-29-76. SI & RU Camco & tested lub to 2500 psi--OK. Ran Hewlett-Packard gauge & Amerada press bomb. RU surface press recorders. Started gas lifting @ 6 PM & lifted to 1:45 AM, 03-O1-76. Rec 15 bbls. Now running press build up test. Cont running press survey until 10:30 AM. Bled off press & POll. RU HO~a~CO. Loaded tbg w/ 64 bbls diesel. RU lub & tested to 2500 psi. Ran GO GR/CCL log. Tool stopped working @ 14,200' POH. Ran new logging tool. Stopped working @ 10,000'. POH. Ran neutron log from 15,486' to 14,600'. Ran 10' 1-3/4" Swing- Jet gun & perfd 2½ HPF from 15,458' - 15,468'. Had no incr in press. Prep to run gun //2. RIH w/ 1-3/4" GO Swing-Jet gun & shot from 15,450' - 15,460' (2½ HPF) on run //2. RIH w/ run //3- Hung up in circ slv@ 14,674'. ~/orked gun loose & RIH. Wouldn't fire. POH w/ run //3. Pulled tight coming out but ret entire gun. Run blind box on WL w/ jars & sinker bars & GR/CCL. RIH to 15,441'--OK. POH. RIH w/ GO 1-3/4" Swing-Jet. Stopped ~ 9600'--POH. RIH w/ 2" carrier gun (DML Vlll Go Winder), 4 HPF (O.4~l dia hole) & shot from 15,410' - 15,430' (20'). POH. Observed well. No press @ surface. RU GO. Tested lub to 2500 psi--OK. RIH w/ 2" Hollow Steel carrier (DML VII Go Winder) w/ CCL & perfd 20' from 15,366' - 15,386' w/ 4 HPF. Tagged top of fill @ 15,437' RD GO & RU to gas lift. Began lifting @ 2:30 PM, 03-03-76. Prod diesel to surface ~ 7:30 PM & had prod 130 bbls diesel @ 10:30 PM. Had crude oil to surface @ 10:30 PM & began prod thru flow- line to battery. Rec 99 bbls crude oil from 10:30 PM to 6:30 AM. Prod choke plugged w/ perf debris. Down 1 hr cleaning. Prod 58 bbls oil in last 2 hrs, 1.2% BS&W (0.5% wtr), 35.6° Grav@ 60°F., 1.1 MMCFD lift gas, 1300 psi csg press, 100- 500 psi tbg press (heading). Cont GL well w/ 1.2 MMCFD. Average rate from 7 AM, 03-04-76, to 5 PM was 26.8 BPH (645 BPD). High rate was 33 BPH (790 BPD). from 5 PM to 7 PM rate decr & csg press dropped from 1300 to 1100 psi. At 7:30 PM incr lift gas to 1.5 MMCFD. Average rate @ Midnight 20 BPH w/ 1.5 MMCFD lift gas, 1% BS&W (0.2% wtr), 75 psi. tbg press, 1100 psi csg press. At 7 AM prod 20 BPH w/ 1.5 MMCFD. Well prod ~ 20 BPH @ 7 AM, 03-05-76. Rate decr & ~. 9 PH rate was 3 BPH. I ncr GL to 1 . 7 MMCFD (was 1.5) · Gas we I I began 'to freeze off. Reduced lift rate to 1.1 MMCFD. Cum prod last 24 hrs was 285 bbls. Cum prod since Midnight, 03-03-76, was 910 bbls. ~hile prod 20 BPH, had TP of 65 psi, CP of 900 psi.. 7.5% BS&Vl (0.5% wtr), 36°APl Grav@ 60°F. GL well w/ no rec. SI for press build up. Gas lifted well 'to run survey to determine i'f all valves are working. Gas well froze off down hole. Well History - BC 5, RD Page 12 o3-o8 03-o9 o3-10 o3-1~ 03-12 03-13 O3-14 03-15 O3-16 O3-17 O3-18 03-19 03-20 03-21 · 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 15,655'TD 1 5,655 'TD 15,655'TD RU Camco to check GLV's. Gas lifted well. Prod 148 bbls in 3 hrs then gas started blowing around. Lifted 6 bbls in next hr. Ran press & temp gradient. Found fld @ 13,680' indicating well lifting down. Put Brinkerhoff Rig #43 on standby. Gas lifted well & rec 197 bbls. RU DA. Ran line to 15,441' (top of fill). RD DA. Put well on gas lift. Cut 2.8% BS&W (.2% wtr), Grav 35.2° @ 32°. Cont to GL well from 7 AM to 2'30 PM. Rec 121 bbls. SI GL @ 2:30 PM. RU Camco WL unit. Tested lub to 2500 psi--OK. RIH w/ shifting tool, but couldn't get thru BV nipple. POH. RIH w/ Garrett shifting tool & closed sly on GLV //13 @ 13,646" RD Camco. Returned well to GL. Rec additional 46 bbls to 6 AM. GL rate 1.6 MMCFD, 35.2°AP1 Grav@ 42°F, w/ 4.5% BS&W (.2~o wtr). SI GL @ 8:30 AM & bled press off csg & tbg. RU Dowel l & loaded tbg w/ 16OO gals of 5% HC1 followed w/ 4000 gals 12-10 UMA (loaded annulus w/ 771 bbls diesel). Pumped another 1200 gals 5% HCl + 16OO gals 5% HC1 w/ 300 gals L-42 (clay stabilization additive), followed w/ 600 gals 5% HC1 (all acid containing additives). Held 3000 psi on annulus & had fm breakdown press of 6800 psi. Press immediately dropped to 6000 psi @ 1 BPM. Rate stabilized @ 1.9 BPM @ 5100 psi. Acid in place @ 7:15 PM lSiP 5900 psi & dropped to 5400 psi in 5 min. Returned well to GL @ 8 PM. Had rec 685 bbls diesel @ 7 AM. Lift rate 1.5 MMCFD @ 1250// CP & 100# TP. GL well from 7 AM, 03-11, to 7 AM, O3-12 w/ total of 290 bbls rec. Fluid prod in heads. Rate too low to check hourly rate. Decr GL rate from 1.5 MMCFD to 1.O MMCFD. CP 800//, TP 25 psi. Grav 37.4°API @ 42°F. Cut 0.5% BS&W (0.4% wtr). GL well using 1,005 MCFD lift gas. Well prod 102 bbls oil, cut 0.2% wtr, grav 34.8° @ 35°F- TP 55-100 psi, CP 700 psi. RU Camco & ran gradient survey. Placed well on GL w/ 1200 MCFD. CP 600#, TP 75//. Prod 127 bbls in last 24 hrs. Cut 1.8% BS&W, Gray 35.6° @ 36°. Lifting from valve #12 @ 13,268'MD. Press ~ 14,320'MD was 1,O02psi. Prod temp was 208°F. GL well & rec 157 bbls in last 24 hrs. Cut 1.6% BS&W, Grav 36.8° @ 42°F, TP 75//, CP 600//, using 1.2 MMCFD lift gas. Rec 173 bbls in last 24 hrs. Used 1.2 MMCFD lift gas, TP 75//, CP 600//, Grav 35.2° @ 38o. Cut 1.4% BS&W w/ .3% wtr. Prod 192 bbls in last 24 hrs. Used 1.2 MMCFD lift gas, TP 75#, CP 600#, Grav 38° @ 60°F- Cut 1.6% BS&W. Shipped 781 bbls (32,802 gals) diesel to battery. Prod 208 bbls in last 24 hrs. Used 1.2 MMCFD lift gas, TP 75//, CP 600//, Grav 39° @ 60°. Cut 2% BS&W. Prod 197 bbls in last 24 hrs. Used 1.2 MMCFD lift gas, TP 75#, CP 600#, Gray 38.8° ~$ 60°F- Cut 1.5% BS&W. Released rig ~ 11'30 AM, 03-19-76. Began to RD rotary. GL well & prod 223 bbls in last 24 hrs. Cut 1.5% BS&W, Grav 39.7° @ 60°F. SI well to dismantle rig. Attempted to run BV bLlE would not go. Ran BP. Would not go. Washed w/ solvent & installed BPV ~ 3 PM. Laid down derrick. hq-?? 15 r~p TD Dismantled rio & moved rotary to BC 7 location. Well History - BC 5. RD Page 1 3 03-23 03-24 03-25 03-26 15,655'TD 15,655'TD t5,655'TD 15,655'TD Moved Brinkerhoff Rig #43 off location and cleaned tanks. RU Camco. Pulled BPV. Began flowing well ~ 10 PM, 03-22-76. Prod 91 bbls ti l 7 AM, 03-23 (10 BPH). CP 910//, TP 80#, Gray 38.7° @ 60°F. Cut 1.9% BS&W (1.6% wtr), using approx 1.2 MMCFD lift gas. Well prod 211 bbls in last 24 hrs. Used 1.2 MMCFD lift gas, Gray 38° @ 60°F, cut 0.5% BS&W (0.4% wtr). Prod 209 bbls in last 24 hrs. Used 1.15 MMCFD lift gas, TP 90#, CP 900#, Gray 38.4° @ 60°F. Cut 0.5% BS&W w/ 0.4% wtr. Cleaning last mud tank on BC 5, RD location and getting ready to move house trailer. FINAL REPORT Prod 227 bbl~ in last 24 hrs using 975 MCFD, CP 550#, TP 75#, Grav 37.5 ~ 60°, cut 0.5% BS&W. Ran Camco press survey bomb in well @ 1 AM, 03-26-76. ' M A I~.-~-TP. Otr-O-ZL---~fq P/~NY .... BEAVER CREEK 61ELL NO, BEAVER CREEK ALAS'I~A 5RD · JUL2 19-70 PAOE JANUARY '5, 1975 SURVEY DATE VERTICAL SECTION COMPUTED ALONG CLOSURE SPERRy-SuN WELL SURVEYING COMPANY SU2-16042 RECORD OF. SURVEY TRUE~ MEARURED VERTICAL SUB-SEA DEPTH DEPTH DEPTH ~NcbINA'T'ION--DIR'EC'TION---DOG-LE6 SEVERITY DEG PIN DEG MIN DEG/IO0 VERTICAL SECTION RECTA'NeUh'AR COORDINATES lqgUo, 14560,80 14187,80 14930, 14587,76 14`214,76 ORIGIN 26 0 26--0 AT 14`900 FEET MD N 76, 0 E 0,00 2572,61 N--79~--0 .... E~4`';'&8 ........ 2385~08 1876,67 1879,85 ' 1'882¥56 1444`,24` E 1457,00 E i469'790~E 14990, 14~41.45 14266,45 1~020, iq467rS-2'"-'--I'4`294,82 " 15050, 14`49~,12. 14521,12 27 0 · 28--50 28 45 N 77. 0 E 4,46 N~77i-'O-"E .... N '79, 0 E '3,~0 2594.21 1885,42 N 2405.;90-~1888~6~ N 2417.59 1891,59 N 1465.18 E 14`97,--1.-2 £ 1511,29 E 150'80,-----1 q, 520-;"-75'--'-'1- 4` 547 ~-75 -- 15110, 1~5~7.58 14574.58 15140. 14574`. 66 1~401,66 27--30 26 ~0 25 ~0 N-.79-,--O--E' 4`.~16 N 78, 0 E 5,66 N'80, 0 E 4,43 2428-~-42 t894~-0~-'-N 2459.21 1896,82 N 2459,56 1899,06 N .... t52~-89--E--- 1557.~8 E 1550.T0 E 15170. 14601.90 14428,90 15200, 14629,~1 144`56.~1 1-5250~ i4656-~92--~4485~92 15260, ib270, 15573, 14684.69 14511.69 i9-7t2755--~z~559%55 14790~55 14617,55 ~5493~---74904-;85--14751-~8~ 15567, 14975.97 14802.97 15621, 15028.19 14855.19 24` 4-5 24` 0 25---0' 22 15 -~'1--'4`5 20 0 N 81', 0 E N 80, 0 E N-80 ~.-O-E 2,87 2459,09 2,85 2468,67 -- ~'~55 ...... 2477~'88 N 82, 0 E 5,58 N'-79~"-O'-E .... 4~09 N 82. 0 E 2,4`7 --1~-%5 N--8%i--O--E 1,-95-- 16 0 N 84, 0 E 2,$6 14` 45 N 84, 0 E 2,31 1901,03 N 1905.15 N 1905~1-8 N 2q86,55 1906,76 N 2q95~4`0 t908i'-88~N 2517.08 1912.85 N 254`4`~16~1-916~66-N 2559.27 1918,79 2569,4`5 1920,25 1563,10 1575.~ 1597.91 E 1608r85 5'- 1656,9~ E t675~-52 E - 1695.61E 1707,28 E 15655. 15061,10 14888,10 lq ~0 N 84`, 0 k 0,75 2575.75 1921,12 N 1715,75 E ~:***---TH E--CA L-C U L-A-T-I 0 N-P R O gED URES-A RE--B AS E~--B N--TH E-HJS ~-0 F--T HE--TA N G E N-T-tA L~ ~C H O R ~M E T H O~** HORIZONTAL DISPLACEMENT - 2575,75 FEET AT NORTH 4`1 DEG, ~6 MIN, EAST(TRUE) LOCATED IN THE 'APPENDIX [21 WFL gl IPR LOG [~ CALIPER SURVEY ~ VOLAN ~ CURVE DATA ~ [21STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER' ~~~,-~ Rrm N'o. P..~-4 R]DV. STATE OF ,~.LASKA OIL AND GAS CONSERVATION COMMII~EE A~ONTHLY REPORT OF DRILLIhlG AND WORI(OVER OPERATIONS SUBMIT IN DL?LICAT~ AP1 NL'A.'I~R.ICAJ~ CODE 50-133-20262-01 I,~SE DESiGI',IATION AXD SERIAL NO USL-A-028083 I~,/DiAF$'. ALK')'f"i~'1~ 0]~ T~IBE NAME I. OIL ~ Oa~ WELL OTHER 8 L-NiT F.~.I O~ LEASE ~athon 0fl Comply Beaver Creek Un5~ ~ ADDRESS OF OPhiR 9 ~g~ NO P. O. Box 2380 ~chor~e, ~aska 99510 No. 5 Redri~ 4. LOCA~ION OF 1267' FNL & 1~65' FWL of Sec. 34, T7N, RIOW, Sm G Zone 639' FSL & 2242' FEL of Sec. 27, T7N, RiOW, SM G Zone~ Beaver Creek Field I',. SEC . T.. R., A! (P_,OTTOM HOt-E OBJ~CTT~ Sec. 27, TTN, RiOW, SM 12 P~-'?~MIT 1~'0 ?5-55 13. RL~ORT TOTAL DEP%'H AT ~ND OF MONT%I. CPT~N'G~ IN HOLE SIZE, CASING A~ C~--M~NT!~G JOES INCLUDING DEPTH SET A~ VOL~qVI-ES USED. ~F_J~ORATIONS, T-'~T$ ~ ~SULT'S FISHING JO~ JL~;K LW HOL~ ~qD SIDE-~CKED HOLE ~D ~Y 0~ SlGNIFIC~T ~G~ ~ HO~ CO~ITIONS 3/1- 3/9/76 After several attests to get bel~ 15,k93' , the interval 15,k93' - 15,k83' was perforated with 25 holes using a lO foot swing jet casing ~. The well was then placed on production with gas lift but recovered only diesel. The swing jet casing ~was then used to perforated 2~ holes per foot in the following intervals: 15,458'- 15,~8', 15,k50' - 15,b60' , and b holes per foot from 15,410' - 15,430'. Obse~ed we~ - no press~e increase at s~face. ~ additional 20-foot interv~was then~rforated with ~ holes per foot from 15,366' --15,3~' ~d 'the well placed on production with gas lift. Initial production was 500 BOPD with a l~water cut. After about 48 ho~s the rate had ~opped to mpproximmtely 150 BOPD~th 3~ to 4{ BS~ which was mostly b~ite. A sider b~ r~ indicated no fill over the upper two sets of perf- orations. 3/lO- 3/19 The well was acidized on March 10 through the G Zone perforations with 5000 gallons of 5% HC1, 4000 gallons of ]P-lO UMA, and 300 gallons of clay stabilization additive. Pumping rates and surface pressures indicated a successful treatment. Breakdown pressure was 6800 psi. and average treat- ing pressure was 5100 psi @ 1.9 BPM. The well was placed on gas lift and increased steadily in production with the following rates: Date BBLS/Day ~BS&W ~Water GL Volume (.MMCFD) 03-14 127 1.8 -- 03-15 157 1.6 0.2 03-16 173 1.k 0.3 03-17 192 1.6 - 03-18 208 2.0 - The rig was 1.2 1.2 1.2 1.2 1.2 t ' li DWlStON O~ ()~L AbID GA'3 14 I hereby ~2rzif.'.' t.h~t the~oregoing ~ t~e ~ ~ ~___.~ ......... _.-_= .. , , . · ~ ....._ NOTE --R~port on this fo~ i~ requlr~d for ~Ch cct~nder ~,th~ reg~,dles~ ~ the t~tu$ ~f o~tati~, end ~u~t ~ fi~d ~n duplicot, ,x;ffl file oil and ga~ conlervation comml~ae b~ the 15~ of fha ~ucc~ding mon~,unl~ ~tberwise d~rected. F~rm N*o. P--4 1R~V, $- 1-70 STATE OF ALASKA SUBMrr ~ mm. LZCA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~:: APl NUA{ER1CAL CODE 50-133-20262-01 6 LEASE DESIGNATION AND SEMIAL NO. USL-A-028083 2. NA/~.W. OF OPERATOR Marathon Oil Company , -~. ADDRESS OF OPIgR~TOR P. O. Box 2380 A~chorage~ Alaska 9~510 4. LOCAT/ON OF WELL 1267' FNL & 1465' FWL of Sec. 34, T7N, RIOW, SM G Zone 639' FSL & 2242' FEL of Sec. 27, T7N, RiOW, SM 8. L.~IT FAR~ OR LEASE NA3dE Beaver Creek Unit g WELL NC) No. 5, Redrill 10 FIF, LJ:) A_ND POOL, OR WILDCAq' -_G. Zona - g~_aver Creek Field Il ~C, T., R., M. (BOSOM HO~ O~~ Sec. 34, TTN, RiOW, SM 12. PERMIT i~© 75--55 REI~ORT TOTAL DEPTH AT END OF MON/q-I, CI-IA?~GES IN HOLE SIZE. CASING A~ C~ENT!NG JOBS INCLUDING DEPTH SET A~ VOL~ USED. P~O~TIONS, ~TS ~ ~SULTS FISHING JO~ JI~K ~ HO~ AND SIDE-TRACKED HOLE ~D ~Y O~R SIGNIFIC~T ~~ ~ HO~ ~ITIONS A 20-foot interval from 15,488 - 15,508' in the lower "G" Zone was perforated and the well placed on gas lift. No formation fluid was recovered. The same 20-foot interval was reperforated and placed back on gas lift, but only diesel was recovered. The 20-foot interval immediately above the bottom interval was then perforated and placed on gas lift, but again only diesel was recovered. The tubing was loaded with diesel and an attempt was made to pump into .the formation. At 8,700 psi. surface pres- sure (about 13,800 psi bottom hole pressure), the formation took no fluid. After spotting 1,000 gallons of acid (MCA 3-6) across the 40 feet of perf- orations and letting soak, it was pumped into the formation slowly at high pressure. The well was placed on gas lift, but no formation fluid was re- covered. The tubing was then partially filled with 60 barrels G Zone crude oil from Well #4 and this was displaced with diesel. After pumping away 54 barrels, there was no indication of fluid entry from the formation. The tubing was pulled, the 2-1/16" stinger removed, and the tubing rerun. The interval from 15,485' to 15,505' was reperforated with swing jet guns. Testing did not recover any formation fluids; gas lifted only diesel. 1976 14. I hereby certify that~the foregoing is true and eorre~ .... ~r,.~. Operations Superintenden~A~ March 9, 1976 ,, .... : S NOTE --Report on this form is ~uired for each calendar month~ regordles$ of the status of operations, and must ~ filed In duplicate with the oil and gas conservatlon commi~ee by the 15~ of the suoe~diflg ~n~, u~le~ otherwise dirocted. Form I~L'V. STATE OF AL/kSKA susMrr ~ ~u.,.~c^~- OIL AND GAS CONSERVATION COMMITTEE /~ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPIXLATOR Marathon 0il Company ~. ~i~DRCss or P. O. Box 2380, Anchorage, Alaska 99510 LOCATION OF 1267' FNL & 1465' FWL of Sec. 34, T7N, RiOW, SM G Zone 639' FSL & 2242' FEL of Sec. 27, T7N, RiOW, SM 5o-133-2o26~-Ol 6 LF,3%SE DESiGNAT'ION AND SEHIAL NO USL-A-028083 . IF INDIA)S, ALOTTEE OR 'IR1BE NAME 8. L.~IT, FAIt~I OR LEASE N~,ME Beaver' Creek Unit 9 WELL NO No. 5, Redrill 10, FIF-IJ-) A_ND POOL OR WILDCAT G Zone - Beaver 'Creek Field I1. SEC., T., R., .M. (BO'FTOM PIO12~ OBJECTIVE) Sec. 34, TTN, Ri(Y~I, SM -- 19-. PIgRIVXIT NO. 75-55 13. REPORT TOTAL DE/~TT~ AT END OF BfON'I'H. CI-tANGF,~ IN HOLE SIZE, CASING AND CEAiENTING JOBS INCLUDING DEPTH SET ~N~ WOLL~ES USED. P~ORATIONS. ~TS ~ ~SUL~. FISHING JO~. J~K IN HO~ ~D SIDE-~CKED HOLE AND ~Y O~R SIGNIFICANT ~G~ ~ HO~ ~DITIONS. ! Continued drilling 5-7/8" hole from 15,256' to 15,373'. After changing bits at 15,353', a bridge was cleaned out from 15, llT' to 15,132'. z/6- z/z While running in hole after changing bits at 15,373', a bridge at 15,069' was-encountered without serious difficulties. Drilling of 5-7/8" hole then continued to total depth of 15,655'. After cleaning out fill and conditioning hole, DIL, GR, BHC Sonic, FDL, and CNL logs were run from 14,918' to 15,612'. 22 joints of 5" 18~ P-110 FJ liner waS~"~un from 14,693' to 15,652' and cemented with 125 sacks. ]_/aa- z/3z The liner lap from 14,693' to 14,893' was squeezed three times with a total oF 600 sacks of cement. Final pressure was 4500 psi. A. dry test of the 5" liner lap indicated a p0~si_b~le._~eak of the .liner~laP. Further testing showed that if a leak is present, it is very small. A packer wa.~s se~t in 'the 7" casing at 14,677.' to isolate the_5'_'__!i~_~ap. 14. I hereby ce~tliy tt~a~.~ the_fore_goLng ~e ~ ~ sz~ ~~ ~'~ ~ O~rations Superintenden~A~ February 11, 1976 - NOTE ~Report on thi~ form ~e~utred for each calendar ~t~ re~rdless of l~e ~totus of operations, and must ~ filed In dupl/:of, with Ih e oil and gas conlervatlon commi~ee by the 15~ of the tucc~ding mon~, unle~ Otherwise directed. Nm ~o. ~---. STATE OF AI. ASKA suBMrr n~ D~LtCA~ 1R~LtV, 3"1-?0 ~ APi"~6~ERlC~ ~ODE ....... OIL AND GAS CONSERVATION CO~I~EE 50-133-20262-01 ...... "" ' ~ LEASE D~:G~ATION AND ~ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS USL-A-028083 ' ~ELL , ~ ..... , ,. Ma~athon Oil Company Beaver Creek Unit P. O. Box 2380, AnChorage, Alaska 99510 No. 5, Redrill '~. ~cxno~ o~ w~ G Zone "!267' FNL & 1465' FWL of Sec. 34, T7N, R10W, h~.]~d'.'.~.,~..M. (~O~oM~O~m 'SM o~~ Sec. 34, T7N, R10W, G Zone 639' FSL & 2242' FEL of Sec. 27, T7N, ~.~~o. ' .......... R10W, SM 75-55 .... 13. REPORT TOTAL D~PTtI AT ]~ND OF MONTH, CI-L~NGES IN HOLE SIZE. CASING A~ C~TING JOBS INCLUDING DEPTH SET ~ VOLb~ USED, P~ORATIONS, ~TS ~ ESUL~. FISHING JO~. JL~K LN HO~ ~D SIDE-T~CKED HOLE ~ND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. 12-01- 12-08 The.drill stem test perforations from 15,013' to 15,026' were squeezed off with 150 sacks cement. A window was milled in the 7" casing from 14,918' to 14,978'. While pulling out of hole, the drill pipe became stuck at 11,690'. The drill pipe was backed off 2 joints above the tool. 12-09 -- 12-16 After bumping down on the fish for 2-1/2 hours and moving it down 9'~f~et, the tools stopped working and could not get off the fish. The drilled pipe was backed off and the top fish (60.47') was recovered with washover pipe and an overshot. The bottom fish was then recovered after screwing into and jarring up four times at 375,000#.. All of the fish was recovered. 12-17'- 12-23 A 50-sack'cement plug was placed.across the window. After drilling out cement from 14,902' to 14,928', the sidetracked hole was kicked off with a Dyna-drill at. 14,928'. 12-24 to 31 5 7/8" - ~- A - · sidetracked hole was drilling at a depth of 15,256' at month- end. . 14 I hereby eertffy that the~regotng t~ ~rue ~ eorr~c~ · iii I I Il I I Il II I I iii I II I t II I i i m i i NOTE--Report on this form is required for each calendar month~, regardless of Ina itatus of operations, <]nd must be filed In duplicate with the oil and gel conlervotion commlflee by the loth of the succeeding month, unle~ otherwise directed. l~rm No. STATE OF ALASKA OIL AND GAS cONSERVATION COMMITTEE /ViONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WtLL WELL OTHER 2. NAME OF OPEIIATOR Marathon Oil Compa,ny, 3. ADDRESS OF OPEP,,A. TOR SUBMIT IIN DUPLICATE USL-A-028083 T IF INDIA)4'. ALOTYEE Olq TRIBE 8. L.~I~ FA_RAi OI{ LEASE NAME Beaver Creek Uni 9 WELL NO Post Office Box 2380, Anchorage~ AK 99510 No. 57 Redrill LOCA'nON OF W~LL ' ........ 10.' ¥i~.D A_ND G Zone 1267' FNL & 1465' FWL of Sec. 34, T7N, R10W, II. SEa..T.R..M. Sec. 34 ,T7N G Zone 639' FSL & 2242' FEL of Sec. 27, T7N, R10W, SM 75-55 REPORT TOTAL DP~ AT ~ND OF MONIM, CHkN'G~ IN HOLE SIZE. CASING A~ CH~TING JOBS INCLUDING DEPTH SET ~ VOLL~ USED. P~O~ATION5, ~T5 ~ ~SULTS. FISHIHG JO~. J~K IN HO~ ~D SIDE-~CKED ItOLE ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~DITIONS. 11-02 11-07 - 11- 06 - 11-18 11-19 - 11-28 11-29 - 11-30 ! Rigged up, killed well with mud, set B tree, and flanged up BOPE and tested s Pulled tubing; it was parted twice, ne jobs at 60'KB and 8100'. While millin drill pipe'parted at a depth of 12,689 fish in the hole. On recovery, the dr have a split box. PV, removed Xmas ame. cessitating fishing g packer at 14,931', ' leaving a 2750-foot ill pipe was found to After drilling out the bottom two packers, a 30-sack cement plug was placed on top of the cast-iron bridge plug located above the Hemlock perforations. A cement retainer was set at 14,832~' and the G zone perforations were squeezed off in three stages with a total of 550 sacks of cement. Final pressure was 4300 psi. A so-called hi to 15,026' for barrels of mud the gh pressure oil sand was.perforated at 15,013' a drill stem test. The test recovered 25 and water with no indication of oil or gas. smmm?~),~F-.4,/.. ~_~&~ ~~r~ Operations Superint%r~ent ........ 12-10-75 Illl Il { [ 11_ _ . ~ I I Il ..... I il NOTE--Report on this form i~re~red for each coiendar ~nth~ regardless of the itofus of operation:, and must ~ flied In duplicate wif~ the oil and gat conservation commi~ee byfhe I~ of the ~ucc~ding ~n~,unle~ otherwise directed. September 26, t975 Re: Beaver Creek 5 Redrilt ~rathon Oil ~pany 75-55 Mr. Dale T. Caddy ~rations Superin .tenet Marathon Oi I Company P. O. Box 2380 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for pemit to drill the above referenced ~li at a location in ~tton 34, Township TN, Ran.qe lOW, SM. ~ll samples, core chips, and a mud log are not required. A directional survey is required. A 10-407 form (Completion Report) is required for the Beaver Creek Unit No. 5 ~ll. Many rivers in Alaska and their drainage systems have been classified as important for the spawni~ or migration of anadromous fish. Operations in these areas are subject to ~ 16.50.870 and the regulations promulgated there- under {Title 5, Alaska Administrative Code). Prior to commencing operations you ~y ~ contacted by the )(abitat Coordinator's office, Department of Fish and Game. Pollution of any raters of the State is prohibited hy AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Co~, Chapter 70) and by the Federal Water Pollution Control Act, as amended. ~ior to conmmncing operations you may be contacted by a represen~tive of the ~partment of Environmental Conservation. Dale To Caddy O. K. Gilbreth, Jr. Page 2 September 26, 1975 Purs~nt to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present. Very truly yours, O. K. Gi lbreth, Jr. Cha i ~n Alaska Oil and Gas Conservation Committee OK Enclosure cc: Department of Fish and Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enclo Depar~nt of Labor, Supervisor, Labor Law Compliance Division w/o ~cl. Anchorag ~ision Production ~xploration US & Canada Marathon Oil COmpany September 18, 1975 State of Alaska Division of Oil and Gas 3001 Porcupine Dr. Anchorage, Alaska RE' Beaver Creek Unit Well No. 5 PO Box 2380 Anchorage Alaska 99510 Telephone 907/274 1511 Gentlemen' We previously submitted an application for permit to re-drill Beaver Creek No. 5 well. It is our desire now to withdraw said application and submit the enclosed application for the re-drilling of said No. 5 well. Also, attached to said application are three copies of well location plats and survey of surface location, together with Marathon's check No. 1153 in the amount of $1oo. M. L. L or'ma MLL/ro Enclosure Form I0'-- 401 , STATE OF ALASKA OIL AND GAS CONSERVATIO'N COMMITTEE ~UBMIT IN' TRFPI~ (Other instructions reverse side) PERMIT TO DRILL OR DEEPEN 'JR. TYPI~ OF WORK DRILL [] Redrill DEEPEN b. TYPI~ or WELL O,L [] °" I-1 WJLb WELL OTHER 2ONE SOW E 2. NAME OF OPEH~TOR Marathon 0il Company 3. ADDRESS O5e OP~TOR P. 0. Box 2380, _Anchorage, Alaska 99510 API#50-133-20262-01 I. 6. LEASE DESIGNATION A.ND SE1RA.AL NO. USL-A-028083 1. IF INDIAN, A. LL~E OR TRIiqE NAME 8. UNIT~FARM OR LEAS}] NAIVE Beaver Creek Unit 9. WELL NO. 5 Redrill 10. I;'IELD AND POOL, OR WILDCAT G-Zone III. SEC., T., R., M., (BO'VTO.M HOLE OBJECTIVE) Sec. 34, T7N, R10W, SM 12. 4. LOCATION OF WELL At surtace Beaver Creek Well Pad #3 1267' FNL & 1465' FWL of Sec. 34, T7N, R10W, SM At proposed prod. zone G-Zone - 639' FSL & 2242' FEL of Sec. 27, T7N, R10W', SM 13. DISTANCE IN MILES AND DIRECT£ON FI~OM NEAREST TOWN OR POST OFFICE* 11 Miles Northeast of Kenai, Alaska BOND INFORMATION: TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 2,030 l (Also to nearest drig, unit, if any) 1~. DISTANCE FROM PROPOSED TO NEAREST %VELL DRILLING, COMPLETED. OH APPLIED FOR, F~. 60' surface t 16. NO. OF ACRES IN LEASE 2,560 19. PROPOSED DEPTH 15,669 ' MD 15~ 100' TVD 21. ELEVATIONS (Show whether DF, HT. CH, etc.} Approximate KB - 173' Ground Level 155' [17. NO. ACRES ASSIGNED 20. ROTARY OR CABLE TOOLS Rot ary 22. APPROX. DATE WORK WILL START* September 15~ 1975 23. ED CASING AND CEMENTING PROGRAM SIZE OF' }-rOLE SIZE OF CASING WEIGHT PER FOOT GRAD~E SETTING DEPTH qvonti , 5-7/8" 5" z8 r-zzo z5,669' 405 SEP i 9 1975 ................ We plan to circulate the well with water base mud. Pull the~__~tubing and drill packers. Set a cement reatiner above the G-Zone and squeeze~em~_th~ G-Zone perforations 15,345'-15,435', 15,461'-15,511'. Cut a window~t 14,840]~nd drill a directionally 'controlled hole to a new location. The G-Zone i~objective is located at a .measured depth of 15,307' and a true vertical depth of 14,746'. The objective location is 639' FSL and 2,242' FEL, Section 27, T7N, R10W, SM. Logs to be run include a Dual Induction, Gamma-Ray, Sonic and Density. Casing will be a 5", 18# liner run and cemented with about 400 sacks. Cement Bond and Collar Logs will be run for correlation 1~ ABOVE SPAC'~ DESCRIBE I~ROI~OS~D PROC;R.~: If I~opo~al is to deepen 'give data on present p~oduc~lve zone a. nd propo~d me',,,,-' productive zone. 1! propOSal ts to drtll or aeepen du-eet.[onallY, give pertinent da~a' on st/bsurface Ioc~tior~ and meas. ured and true 'Vertical depths. Give-bif~wo'u{ prev~_nter' program. '" ' s,o.~ 0_¢.' '~%~.L-. ~A~ ~SEP 19 1975 -,-,-,,~ ; ; ,,', ,,- , , ,-;~ - "iThis sbabe fo'r S~te offi~ ' ' u'~) ' ' /./' CONDI~ONS OF ~PROV~, IF A~: SAMPLEDTM A~D,,~NoCORE CHIPS ~~ JBvmj MU.D LOC~NO J ~ DI~fflON~ SURVEY R~~ [ A.P.I. ~C~ COD~ . . September 26 ]975 , 6/ ,, A,P~OV~ ...... . _ /~'~~ In~u~ons ~ Reve~ Side ' ' Application for Permit to k ~rill BCU Well No. 5 Proposed Casing. and Cementing p.rog.r.am..(.Cont'd.) and perforating control. The drilling mud program will be an oil base invermul mud system. The blowout equipment will consist of a 10" double ram hydraulic preventer with a 5000 psi WOG, 10,000 psig test, and a 10" Hydril 5000psig WOG. Location at total depth is 646' FSL and 2169' FEL of Section 27, T7N, R10W, SM. Imm m m m mmmim m m m m mm m m mmm ~.Bmm-'~ ~7 26 gMll 3 TeN ----m ~ ~----~ I I L m mmm mmm i mmmm I mm~ I m I I I I m I MARATHON OIL COMPANY ANCHORAGE DIVISION BEAVER CREEK UNIT PROPOSED B.C.U.NO. SRD. Sept. 1975 35 435, £15 8 515~ 831..35 SECTION 34 PROTRACTED 1465' T Set wood stoke w/nail on berm ~.~...___Elev: 15754 ft °ni NW Y: 2, 455, 929 x: ~l 7, 288 Xmas tree BCU. No4 ~ Xmas tree BCU No 3 Elev : 158 56 top conc Set wood stoke w/nail on berm well cellar LEGEND AND NOTES · Found ex~sting well x-mas tree X and Y values are State plane coordinates for Zone 4. Elevahons refer to M. SL. datum of 0.0 ft. MARATHON OIL COMPANY OPERATOR BEAVER CREEK UNIT NO. SURFACE LOCATION IS 1267 FT SOUTH AND IZ165 FT. EAST FROM NW COR. PROTRACTED SEC. 34, T7N, RIOW, S.M. AK. Surveyed by -- SS Mc Lane R. L. S DATE"OF SURVEY ! SCALE Porto I 0 -- 4 0 I , reverse side v. rv. ~-~-?~ · t "IttFJ p ' ASKA OIL '~ fllD:: '~S~O NSER VAZIO,N ,COIMM ITT EE' SUBMIT IN THIPT. (Other instructions 0,. API#50-133-20262-01 PERMIT TO DRILL OR DEEPEN ZONE 11[. TYPm OF WOIIK DRILL ~ Redrill 2. NAME OF oPERATOR Marathon Oil Company DEEPEN [] ,. ' I c. USL-A-.02808 Beaver Creek .~c .......... Beaver Creek ...... J' 2~'~°~ -'j ..... G-Zone [1. SEC., T., R.. M., ~BO~O~ ~oLz os~cr~v~, -F~L~L ................. Sec. 34,T7N~ ~2' Kenai Peninsula Borough Alaska 3. ADDRESS O~ OPF_,IL~TOR Pi..: 0,:.Box .,2380, Anchorage~ Alaska 99510 4. LOCATION OF' WELL At surface Beaver Creek Well Pad #3 Atp,.o~oseap~.~.2,'~ FNL & 1465' FWL of Sec. 34, T7N, R10W, SM G-Zone, 315' FSL & 2300' FEL of Sec. 27, T7N, R1GW, SM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 11 Miles Northeast of Kenai, Alaska 14. BOND INFOFd~ATION: TYPE Surety and/or No, DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 2,030" 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST SVELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 60' surface Il6. NO. OF AC/IFS IN LEASE 2,560' Ii~. raoros~o Dm'T~ 15,530' MD 15,100' TVD 17. NO. ACRES ASSIGNED TO T/tiS WELL 160 20. ]ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CH, etc.) 22. APPROX. DATE WORK WILL START* Approximate KB- 173' Ground Level 155' September 15~ 1975 ~-~. PROPOSED CASING AND CEMENTqNG PROGR~M SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAD~ SETTING DEPTH q u a n t i tM of c e m?~~ _ 8-1/2" 7" 32~ P-110 ~ ;~'::' : .... 15,,~6~'~->"~ 300 Sacks j.r'~ '' I-- ~ Ai ,: We plan to circulate the well with wat. m~ b mud,? ~Pull the .,tUbing and drill packers. Set a cement retainer above the ,G-Zo~ a~kd squeeze cement tBru G-Zone perforatzons at 15,345'-15,435', 15'461'-15,511'2 T~e ceaent ~ueeze Of ~,e'he G-Zone will back up the bridge plugs at the top of the 5" Li~er a~ further support the abandonment of the : ~" ~ ' ' 28 ' Hemlock as well as the G-Zone. ~ p~n to~ perforate.~a G-Zone sand at 15,018 to 15,0 and run a drill stem test. Set a~. cem~ r~tainer a.t 14,950' and cement squeeze the DST perforations. Cut a window a% 11~350' ~drilt-'a directionally controlled hole to a new location. The G-Zone formkti°n objective is located at a measured depth of 15,155' and a true vertical depth of 14~4~9'. The objective location is 250' FSL (see 'attached) IN ABOVE: SPAC'~ DIBSCRIBE _1~. OPOSE?. PROGRA.~:_~I ..p~m~al is to deepen give, data .on present produc~iv.e zone an.d .p.ro~P~e~'(i new productive zone. _I f_ .p_r_o_pg_sa.l ~$_ tq. dr~ll_ or aeepen',~l~ect_tonally, give pe.r,t,l~_ent _data on subsurface locationz aha .meaaur~a ~na tru Vertical depths. Give blowout preve_nter program. ~ 24. I hereby cer~ify, that; the Foregoing is True anti Correct (~hi~ spaoe Jo~ ~e o~fi~e ~) ' ~" CO~I~O~ jSAMPLES AND CORE CHIPS R.F.,QU~ J MUD LO'~N [] Yms '~NO [] YES O [ m~c'rIoN;a, s'URvEY jYES [] NO APPROV]~) BY SEE TRANSMITTAL LETTER *~, Indructio., O. Reverm Side Operations Superint enden PERMIT TO DRILL OR DEEPEN and 2,390' FEL, Section 27, T7N, RiOW, SM. Logs to be run include a Dual Induction, Gamma-Ray, Sonic and Density. Casing will be a 7" 32# liner run and cemented with about 900 sacks. Cement Bond and Collar logs will be run for correlation and perforation control. The drilling mud program will be an oil base invermul mud system. The blowout ~quipment will consist of a 13-5/8" double ram hydraulic preventer with a 5000 psi WOG, 10,000 psig test,and a 13-5/8" Hydril 5000 psig WOG. Location at total depth is 315 FSL and 2300 FEL of Section 27, T7N, RIOW, SM. CHECK LIST FOR NEW WELL PERMITS 1. Is the permit fee attached ..................... Company //~//~i Fo ?~ o bq Yes No Remarks 2. Is well to be located in a defined pool ............... 3. Is a registered survey plat attached ................ 4. Is well located proper distance from property line ........ 5. Is well located proper distance from other wells .......... ~' 6. Is sufficient undedicated acreage available in this pool ...... ~[ 7. Is well to be deviated ....................... H~' 8. Is operator the only affected party ............... 9. Can permit be approved before ten-day wait ............. O. Does operator have a bond in force ................. ~. 1. Is a conservation order needed ................... 2. Is administrative approval needed ................. 3. Is conductor string provided .................... 4. Is enough cement used to circulate on conductor and surface .... 5. Will cement tie in surface and intermediate or production strings . 6. Will cement cover all known productive horizons .......... 7. Will surface casing protect fresh water zones ............ Will all casing give adequate safety in collapse, tension & burst 9. Does BOPE have sufficient pressure rating .............. ~,ddi tional Requirements' Approval Recommended' Geology Engi neeri rig' TR~', HWK/r/~. 0KG HHH Revised 1/15/75 Well History File APPE'NDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIx. No special'effort has been made to chronologically organize this category of information. TAPE ];DENT. L-50120,MARATH[.t~ UIL, CO.,BEAV~;R CREi<K #5(.]4-2?),Bt<AVER CK,Rf;DHI. ~.AIeAI'i4UN UIb COMPANY ~NAI ADA6KA · 1~, 280 0,, O. O. O, O. O, O. 0.000 0,000 0.000 0o000 0o000 0o000 O. O. Oo O, O, O. O. O. O. O, Oo O. O. O. O. O, Oo O. 0.00 0.00 0.00 0o00 0o00 0.00 0.0 0.0 0.0 0.0 0.0 0.0 ,000 0,000 0,000 0,000 0,000 0.000 O. Oo O, O, O, O. I~ ' 2 3 ~ 5 ~ ? ~ 9 10 li 12 1~ 1~ 1,5 I~ 1~ 1~ 19 2~ 21 ~2 0 0 0 I 0 I i 0 2 0 0 0 0 0 I 0 ! 0 0 0 0 12.2 0,bO 5.8B 198, 15610, 40, 9.00 UO. o.ggo 0,ggl O,Sb0 SPCA O, 0,20 I5~90,, 14BB2. 0,000 1,00 0,000 2,40 10,00 0,2 WHY PHIDEV BR ~Li~ AK PA ~{i STUPI~ Pldl{qAX PH1NCI. Pitli)Ci~ ,~00 O,000 ,lO O,30 b2500o o,0 2,0 O, 0.220 0.422 P~ !80 88. ,015 6B. 40, 2t~, 88, lb0. 150. 1.00 ,200 EDI&~ PNbl-~ PDbIM 0,,00 0.42 Oo2b la V ' T .LI~4 GRhlM Ai~C CO~ ~< [.t p VAial,l M C.sP'' 2,5 tooo,O O.O'~ 0,333 b,~O 0,Y.O O,bO 1488~.0 ',8 , 14883.0 0.4 11,,4 11.7 17.9 ~ 0 14922,0 0,2 i.,0 l i49~]~0 0~2 10,5 149~6,0 0,9 10,4 ,b ,b . 1.5 6. .4 ,5 .2 I00 97 I00 74 54 73 b4 100 87 5~ 00 O0 I00 tO0 10o 100 100 100 oo O0 100 94 I00 I00 il O0 O0 v rl L, ij M E % 9 2a 49 4~ 41 34 ~8 21 30 43 29 45 4~ 49 50 44 41 4b 40 41 31 it) C tJ N, POi'lO& I T Y FEET 5 'I , 4 b U6.51 56.0I 55,8~ 55.14 55.03 34.82 ~4,71 ~4.39 54.29 54,17 54.00 53.53 53.24 5~,22 5],18 ~3.11 52,9~ 52,87 52.78 52,54 ~2.43 52.~0 $I.q3 51.~7 I Jo 13. H ~(C bO ou 13.59 13.57 13.b$ 13.53 13. 13. 13. i3. 13. 1 3. 12. 12. 12. 12. 12. i2. 12. 12. 12, 12. 12. lZ. 12. 12. 12, i2. i2. 12, 5J 48 ~9 27 18 lo O9 09 Od 0'~ 01 9o ~b ~5 85 85 85 85 85 ~3 G~tCC CbA¥ % P t.)i~tl;S I TY . H¥C 6,7 ,2 ,? ,0 I . 9 8o 4,1 .o .1~067.0 i !-3.b 100 100 100 oo O0 O0 100 100 lO0 I00 {tOO lO0 100 lO0 lO0 100 100 oo 100 100 O0 I O0 100 O0 00 O0 100 100 3J 3u 41 41 40 45 44 4U 44 4~ 4b 47 47 1¢ o o 0 51, 51. Si, 51, bi, $0. ~0. ~0. ~0. 49. 49. 49. 47. 47,,, 47. 47. · ,~ '], 84 Ol 51 41 31 17 14 07 90 74 ..18 210 10 Ob ?1 6i:, bi 50 47 29 11 92 21 12.83 12.83 12.83 12,83 12.B3 12.8J 12,83 12.~3 I2o83 12.,3 12.83 12.83 12,83 12,83 12.83 12.83 12,8~ i2.8~ 12.83 12.83 12.8~ 12.8i 12,82 12,81 12,81 12, 12, 12, 12, 12. 12, 12. 12, 12. 12, 12, 12,, 12, 12, 12, 12, Ul 81 81 81 81 81 81 81 81 80 74 7~ % CU~, CUM. HYCARh FE~T 4 t1,3 ,3 22.9 I00 Oo lOO I0O 10o ~4 !oo 1oo 3 5 ,7 .0 ,9 io.~ IO.S $ 11. 5 ,4 ,5 ,0 1 :tO 8 v. 100 f00 I oO I00 100 100 I00 I00 I00 9~ q9 O0 10o I00 00 . oo 98 9 92 0ol ~o7 ~2 17 lZ 21 37 19 21 29 .t4 20 14 19 21 25 21 21 24 46.93 ~b. B1 ~0,48 40.30 ~b,18 46.08 45°90 45.b9 45°49 4b,28 44.52 43,84 43.7~ 43.6q 43.41 43.10 q3,13 4.3.0O ~2,9b 42,b2 42,bo 42o40 42.30 42,01 41,~0 ~l.b8 41,55 41o31 41,21 41.10 ~i.00 ~0.~0 40,81 12.73 12,'13 12.73 12.73 12.73 12,73 12.73 12,72 12,~4 i2. 12. 5~ 5b 12.55 l~.sb 12.55 12.55 12.5b l~.Sb 12.bb 12.55 ~2.5b 12.55 12.55 12.55 12,5b l~.b4 12.54 12.54 12.b4 12.54 12.b4 12.54 12.54 12.54 12.b4 12,52 12.bl t2.bl 12,51 12.50 12,4u 12.45 12,44 PORO~ 9,6 12.4 12.5 t0,2 io.~ 0 1 0.4 8,2 2 I0,~ ti, 1.1 · 3 10.9 4 11.2 4 ii~ b 11,8 4 II.4 Ib2al .,0 .9 0.7 lb.O 77 7~ ~3 I00 I00 ?0 67 74 100 10o 1 O0 100 O0 iO0 loc, I00 i00 O0 100 tOO t00 I00 100 I00 82 ?O a¥CAka Ga/CC Cl.,AY % 14 -/ 1{~ 11 14 4~ 47 44 4~ 49 ¢8 4~ 22 2,~ 21 17 22 20 22 2~ 11 19 C Ut't, FEET 40.72 40,~2 ~0.49 40.27 ~0olb 40.01 J9o69 39,5~ 39.15 JS,l~ ~.00 ~7.9o .. J7,37 JT.~2 37.25 ~7.14 37.0~ 3~.v2 30,~8 3b,33 3~.22 3b,lO 3b,97 3b,Sb 35,74 35,02 3b,3~ ~5.28 ]5,13 3S,00 3~,68 CU~, HYCAP. B FELT 12.42 12.40 12.3~ 12.35 i2.35 12.32 12.29 12.23 12.18 12,13 12.11 12,11 12,11 12.11 12.11 12.10 12.10 12,10 12.0'1 12.0'1 12.07 12,07 12,07 12,0t 12.07 12.0'1 12,07 12,0'/ 12,07 i 2.0'1 12,07 12.0'1 12.06 12.Ob 12,03 12,01 11.99 11.9~ 11.9~ 1{.9~ 11,9~ ll.g5 11,92 ~AT~R ¥ OI~tJt'tE CU~o POHOSITY FELT lb264,0 1~2~7,0 iU268.0 ,0 .o IU2~I ,0 !5274,0 5276 0 I~278, 19279o~ g.O .0 0.0 0.0 0.0 0.0 0,0 0.0 0,0 0.0 0.0 0.0 4 1i 100 100 10~ I00 100 I00 0.3 0°2 1 2~ 3'/ 4~ 34.b $4.0 33.7 3 3,7 33.b II.OO I1.~1 11.7~ 11,70 ll,b3 il.Sb II.52 ll,bO 11.47 11.47 i i,4t I 1.4'7 1 ! 11.4't I~ 14 lb lb 17 18 19 20 21 22 '0 ~0 0 ! O 1 O 0 U 0 ~tlD XblT BITDZ BHT ~HTD~P"P 8UF~'~ '~ R~F RaFT R[laFb PIilMFS DA$11.. I].2 0,50 5,88 t98. lSblO, 4U, ~,00 O0. 0.qgb 0,997 0.850 ..,DIA~ PNI. IiM Pi>I, IM '..)6. 1~0o 150. 1.00 .200 2o~ IO00,O O,O~ 0.333 0.~0 0.20 O,~0 RESIStiVITY S i'A~iISTIC~, l~VE~ E~T'IRE 1~-rEi~V^h SONIC STATTSTiC~ OVE{I E~TIRE INT~Ji~V~L P~M~ABtblT~ bX Tt~,UR SP COE~F, FROM.. 8rATI~.I SO.~IC CoEFF' FROM ~AT % % ~/CC CbA¥ PEET HYCARB 5, Y 1OO ' I 7.7 4,9 3 11 2 . ii 0 . . · 1~56,0 30 ~S~o ~o ~o.~ 19,2 15.8 .9 i6'4 100 O0 71 1 O0 I00 lO0 100 100 i00 100 OO HO ~9 60 ~ o ~o ~0 4o 0.5 0.5 0,4 0,3 4~ 45 27 20 11 44 47 2J 22 2J 2~ ? ? ~2 ~2 ~2 ,58 ,47 .17 ,77 o4. .43 ~2.30 32.22 ]2.11 32.00 ~I,BO 31.7b 31,30 ~1.14 30,95 ]0,74 ~0,53 30,33 30,02 29,b7 ~9,28 29,08 ~8,88 28.51 28.19 28,03 21.53 ~'1.37 11.4'1 11,47 11.47 !1.47 11,47 11.47 11,47 11.41 I 1.3'1 11,37 Il.J/ 11.3't 11.37 11.]7 1 I..30 ll,Jb II.3b 1i,3o i1.30 11.3~ lJ.2B 11,22 11,i7 11,09 10.99 10.88 10,79 10,73 lO,b4 lO,bb 10,47 lO..~O 10,25 10.13 10,02 9.92 9,79 9.72 9.65 9.51 9.43 C-bAY % CU~. PORO&ITY CU~t. HYCARtS FEET 50 ~0 0.4 ~3 72 74 94 ~4 90 1oo tO0 59 0,4 63 0,3 68 0,5 oo 7 09 bO 100 9 4 I 2 1 I 10 7 7 I 0 11 12 7 7 41 12 14 I1 11 17 14 14 12 12 11 9 27 26 2.5 24 24 24 24 23 2,~ 22, 22° 21o 21. 21, ,20 ,07 °74 ,49 .12 .42 .57 ,52 ,85 ,70 .42 O~ 87 72 27 99 91 8b 79 9°34 9.22 9,20 9.19 9,10 9,!4 9,11 9.09 9,00 9.Ob 9.04 9.02 9,02 9°02 9o0~ 9,02 8.98 8.90 8,75 8.09 8.b9 ~°b9 ~o~9 8ob2 8.34 8,29 ~,2~ ~elb 8,Ob ~.OO '1,93 ~,~9 7,88 7.8~ 7.88 HYCAf~ .. FE~T C U ~v~ · .1 ,4 !5,4 5.4 5.~ 15.2 16.4 18.~ 17. i0.~ ,o 9 . 1~ 0 4 14.7 75 7 47 44 44 47 0 b7 70 ~9 0.4 0.4 0.4 0.4 0.4 0,5 0.7* 0,7 0o8~ O,B~ 0,8~ 14 12 10 12 I1 14 lU It) Il 12 10 / 12 12 lu 12 lO 12 lo 20 14 14 It; IO 11 21.6~ 21,53 21.17 20.99 20.58 20,3b 20,14 19.92 ~9.72 i9,54 iq. J8 i9.05 i~,87 18,7U i~,Sb iH.40 i8.09 i'!.94 il,bO i7.51 i6,70 ih.s1 ib,,J3 ib.ol ih,B7 15,74 iS.bO i5,47 i5.20 lboO1 i4.~4 i4.54 i4,08 7.8~ 7.7B 7.b9 7.37 7,2b 7.13 7.01 b.91 5.69 6,b2 b,54 6.]8 b,20 5,11 b,07 5.91 5.7? 5.bl 5.55 5.50 b,42 b.3b b,31 5.2~ b.27 b.25 5.20 5.13 5.07 5.01, 4~94 ~nr,Tm~ C U M, C U l~i. HYC AI-'IB F E t5., T 14.3 , ii,8 io.2 0 !2,9 4 11:2 'i ,' 15482.0 30 !~ 9 , 15'I , 14,~ 14,8 (~,4 ?! 54 49 4~ bO 4v 0 100 '1 , 100 loo 7 ~ ?o 43 0,5 0,4 0~ 0o?~ 1o 7 1 ~7 1'~ 1o 11 19 tJ 14 tl 1'! 13,9:~ 4.77 13.79 4.72 i3,65 4.6b i3,40 4.52 i3.17 4.51 i~.04 4.4'7 i2o91 i2.79 i2.b7 4,3~ i2,5t, J2.44 4.31 1~,31 4,21 i2,1~ 4.21 il,HO il.43 il,22 il.02 3.59 i0.~3 3,49 io.b~ 3.41 i0.5i lO.3b t.2'1 i0,21 3,20 9,92 9,~4 3,0z 9.80 9.7'! 9,74 3.U2 9.72 3,02 9,bU 3.0~ 9,59 2.99 9,37 2.8B 9.19 2.80 9.11 2.7! 9.04 ~.gb 2,72 8,Ih 2.b4 H,bb 2,60 8.5~ 2.bb 8,44 2,49 8.3~ ~,44 ~tATo C ~A'T C U M, PUR[)~ I TY FE~;T HYC At41~ 1551],0 15514,0 15515.0 ,0 .0 40 18.5 50 20,0 3 i3.0 20O 24 9 100 24'6 90 22. ~ 50 0o0 3B J~ 15528-0 0.0 b .3 10o 15532.0 0.0 4.9 lO0 15536,0 0.0 4.4 I00 ,0 14. i5,8 i6,5 i0 1~ o 20 i9:0 5 lb,9 20 19,6 5 15,7 20 18,7 3 14 9 3 14,8 7 16'g 10 i~,3 10 5 lO 4 70 23.~ 20 I0 lb,9 5 14.6 15,? .0 0 0 ,,0 0 .0 0 o 15586.0 100 I00 99 97 97 ql 8.5 98 I00 IOO 79 72 8~ 97 97 79 ~2 94 70 50 47 51 53 57 57 55 0,5 0,3 0,2 O, 2 0,2 0,4 0,5 lb 19 4{, 4b 4¸8 3~ 20 to i1 11 13 1J lZ 11 11 14 lb 1! 19 lo it) 11 8.17 1.96 7.79 7.o5 '1.40 '1,1o b.q4 b.~iO bo90 5,75 5.5~ 5.42 5.24 5,05 4,70 3.60 3.51 3.21 .3,05 2,6~ 2.37 2°2.3 2,04 1,8i 1o58 1.3b 1,0i 0.86 0,'10 . l, 1, I. I, 1. 1, 1. 1, 1. 1, 1o 1. 1, 1° 1, 1. 1. 1, 1, l, 1. 1, 1, 0, O, O. 0, O, O, O, 3 ..~ 21 10 04 ~ 3 5~ 53 53 53 53 53 .52 40 44 44 44 43 41 40 29 2Z 17 12 10 02 91 79 t,.' '1 5 9 51 iCC CbAY % ti ¥ C A R t:,~, .6 9 15,4 44 42 Oe7* 0,~ 0.7. Il 11 lO lu 0,54 U, J9 0.08 0,30 0,22 0,14 O,Ob