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Home My WebLink About210-0501a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Beluga River Field GL: 74' BF:74' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" X-65 108' 9-5/8" L-80 2,832' 7" L-80 2,887' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl:Flow Tubing N/A 2,907' MD / 2,887' TVD N/A 6,565' MD / 6,545' TVD 2,907' MD / 2,887' TVD N/A 1785' FNL, 97' FWL, Sec 24, T13N, R10W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 26# Surface 154# 40# 108' Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: N/A Gas-Oil Ratio: AMOUNT PULLED 323438 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. BRU 212-24TJune 28, 20102054' FNL, 144' FWL, Sec 24, T13N, R10W, SM, AK 92.5' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORDSETTING DEPTH TVD 2633845 TOP HOLE SIZE Sterling - Beluga Gas Pool ADL 21128 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 323477 2633581 50-283-20136-00-00June 14, 2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 9/12/2022 210-050 / 322-031 N/A PACKER SET (MD/TVD) Cond 12-1/4" Driven Surface 948 sx Surface 2,851' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface 2,907' (TOW) Surface ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 280 sx8-3/4" N/A SIZE DEPTH SET (MD) WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by James Brooks at 3:20 PM on 12/6/2022 Abandoned 9/12/2022 JSB RBDMS JSB 121422 xGWCB 1-23-2025 DSR-1/3/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval N/A N/A 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Beluga I Wellbore Schematic, P&A Reports Authorized Title: Drilling Manager Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 12.6.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.12.06 15:06:19 -09'00' Monty M Myers _____________________________________________________________________________________ Updated by CJD 12/6/22 P&A Schematic Beluga River Unit Well: BRU 212-24T Abandoned: 9-12-2022 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,342’ TVD = 4,322’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 4 8 6 9 X5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,932’ 10/24/20 7 D1-E5 C2-C3 B4 CIBP @ ~3553’w 25’cmt Jet Cut @ 3565’ CIBP @ 3575’ TOW @ 2,907’ CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 154.19#X-65 WELD 19.13''108' 9-5/8"Surface 40#L-80 BTCM 8.835''2,851' 7''Production 26#L-80 BTCM 6.276''6,535' TUBING DETAILS 3-1/2"Production String 9.2# L-80 8RD EUE 3,565’- 4,301’ JEWELRY DETAIL ID.Depth MD (ft.) ID (in.)Description 2,907’Whipstock 2,924’CIBP 3,553’7” CIBP (Dump Bail 40 gal cmt EST. TOC 3,528’/ rig tag 3,524’) 3,565’Jet cut tubing 3,575’3-1/2 “CIBP 4 3,580 DHL Packer 5 3,600 2.813”X-Nipple 6 4,302 WLEG 7 4,360 Spiral Plug w/ 18’ cement (TOC @ 4,342’) 12/24/20 8 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 9 6,350’Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Date Status Sterling B4 3,594'3,601'3,574'3,581'3/26/2021 Open Sterling C2 3,644'3,654'3,624’3,634’4/11/2021 Open 3,670’3,680’3,650’3,660’3/26/2021 Open 3,680’3,690’3,660’3,670’3/25/2021 Open Sterling C3 3,711'3,721'3,691’3,701’4/11/2021 Open Beluga D1 3,861'3,864'3,842’3,845’12/31/2020 Open 3,872'3,877'3,853’3,858’12/31/2020 Open Beluga D5 3,957'3,961'3,937’3,941’12/31/2020 Open 3,970'3,973'3,950’3,953’12/31/2020 Open Beluga D6 4,008'4,021'3,988’4,001’12/31/2020 Open Beluga E5 4,219'4,223'4,200’4,204’12/30/2020 Open 4,254'4,264'4,234’4,244’12/30/2020 Open Beluga F1 4,382’4,393’4,362’4,373’7/22/2020 Isolated Beluga F4 4,432’4,442’4,412’4,422’7/21/2020 Isolated Beluga F7 4,696’4,719 4,676’4,699’7/9/2020 Isolated Beluga F10 4,735’4,740’4,715’4,720’7/9/2020 Isolated Beluga G2 4,864’4,871’4,844’4,851’7/9/2020 Isolated Beluga G3 4,873’4,878’4,853’4,858’7/8/2020 Isolated Beluga G4 4,922’4,927’4,902’4,907’7/8/2020 Isolated Beluga H2 5,187'5,200'5,167'5,180'8/19/2012 Isolated 5,187’5,200'5,167'5,180'8/17/2018 Isolated Beluga H3 5,217'5,224'5,197'5,204'8/17/2018 Isolated Beluga H7 5,354’5,362’5,335’5,343’8/17/2018 Isolated Beluga H9 5,411'5,421'5,391'5,401'8/16/2012 Isolated 5,411’5,421’5,392’5,402’8/17/2018 Isolated Beluga H10 5,496'5,511'5,476'5,491'8/16/2012 Isolated 5,496’5,511’5,476’5,491’8/16/2018 Isolated Beluga H13a 5,586'5,596'5,566'5,576'8/15/2012 Isolated Beluga H13 5,586’5,614’5,566’5,594’8/16/2018 Isolated Beluga H13b 5,604'5,614'5,584'5,594'8/15/2012 Isolated Beluga H16 5,740’5,748’5,720’5,728’8/16/2018 Isolated Beluga I2a 5,786'5,794'5,766'5,774'7/28/2010 Isolated Beluga I2b 5,818'5,830'5,798'5,810'7/28/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing FISH DETAIL @ 4,932’ 10/24/20 Perf Gun Activity Date Ops Summary 3/30/2022 Arrive at Beluga River. PJSM and PTW, orientation and warm-up equipment,Mobilize to location, spot equipment, check flow tubes and re-head cable. R/U and stab on well. 570psi SITP,P/T Lubricator to 1500psi/250psi - Test good,M/U and RIH w/ CCL and 3.5" CIBP (2.75" OD). CCL to center of element 7.75ft.,Correlate on depth and set 3.5" at 3575ft. Pick up and tag plug, good tag. POOH, the plug set.,Lay down the lubricator. Secure well and E-line SDFN,Bleed tubing down from 570 psi to 0 psi to fluid pack for pressure test. 3/31/2022 PJSM and PTW. Head to location and warm-up equipment.,Fluid pack the tubing and pressure test against CIBP to 3,000psi for 30min. Test good,R/U E-line tools and stab lubricator on well. Pressure test 3x and had to change o-rings Final lubricator pressure test to 250psi/1500psi - test good,M/U and RIH with CCL and 3.5" (2.50"OD) jet cutter, CCL to jet cutter 5.0ft. Pressure up the tubing (T/IA) (400psi/10psi),Correlate and cut tubing at 3,565ft (6ft above collar). Tubing pressure came around to IA (T/IA) (100psi/100psi). POOH Bleed down tubing and IA to blow down tank while POOH. (T/IA - 0psi) Spent jet cutter recovered,Secure well. Rig down E-line and move to C pad. SDFN 4/12/2022 Organize trailers for the Barge load out, Move Carrier to Rig Tenders dock, spot same, install derrick and pin. Raise derrick, install drill line, scope up derrick and straighten cables and scope down derrick. 4/13/2022 Lay down derrick and secure same for move, prep equipment and load out on trailers for mob. load out barge with equipment trailers. 4/14/2022 Continue to prep trailers for barge load out to Beluga River, fly over to Beluga River field, meet with production lead, fill out permits, assists production with removing flow line and well house. return to Kenia. loaded out Barge Polar Bear with Carrier, support equipment (pickup trucks, tool truck, loader, rig mats. generator, & fluid pump.) 4/15/2022 Load out 401 rig support equipment (load #3), fuel tank, base beam, choke house, gas buster, tong baskets, liner and dunnage racks. 4/16/2022 Meet up at Kenia Terminal, travel to Beluga River field, sign in fill out permits, move carrier to location at K pad, lay out liner, spot base beam, carrier raise derrick and scope same. Spot Koomey house, bang board, pits. fuel tank, place Dunnage in place. 4/17/2022 continue to rig up 401 support equipment, weld post on pit roof, spot open top tank, hooking, up hoses finish in stalling berm,circulate hole clean with 8.4 ppg fluid, shut down pump, monitor well (well static),Set BPV and nipple down tree, prep well head,Nipple up 13-5/8 bope and torque up same, install choke and kill hoses,Install rig floor. SDFN 4/18/2022 PJSM install 2-7/8 test jt. and fluid pack test equipment, trouble shoot koomey remote pannel, swap fittings on annular, prep handling equipment for pooh with 3.- 1/2 completion, shell test BOP equipment to 3000 psi,Test BOP equipment as per AOGCC and Hilcorp specs, to 250 psi low and 3000 psi hi held each test 5 minutes on chart, no failures, witnessed waived by AOGCC Jim Regg, perform Koomey drawdown test Quadco rep set up gas Alarms and tested same,Lay out test equpment and pull blanking sub and BPV, make up landing Jt in hanger, unseat hanger at 60k, string 50k, lay out Vetco NB-230 hanger,,POOH laying down 3- 1/2", 9.2#, EUE, L-80 tbg, removing cannon clamps, while spooling up 1/4" chemical injection line., laid out 2 GLM & Chemical injection mandrel and cut jt. , tested the 7" 26# csg to 3000 psi ( held good) bleed off same , secure well . SDFN. 4/19/2022 Finish rigging down power tongs, and pipe skate, clear pipe rack area for logging truck, Eline arriver in Beluga, sign in fill out permits, startup equipment and travel to K pad,Spot E-line equipment and rehead, rig up sheaves, make up 7" 26# CIBP,RIH with 7" CIBP; set down at 3564' ELM, run correlation pass sent log to Town (on depth) set 7" CIBP AT 3553' ELM, pick up and tagged CIBP, CIBP set. pooh,,Lay out CIBP setting tool and pick up CBL tools string, Head ( 8x2) CCL/ cent,/ CBL/CENT/ GR/CENT, OAW=330 LB OAL25" MAX OD 3.125",RIH with same set tools up at 500 ft. log free pipe at 427 ft. continue in hole tagged CIBP @ 3553 ELM, log repeat pass over enterval f/ 3536 -3300 run back in hole log pass over interval 3533 ft to surface TOC AT 2442 FT OOH lay down tools,rig up and test CIBP & 7" 26# csg to 3000 psi for 30 minutes on chart (good test) 4/20/2022 Sign Permit PJSM, started up Eline equipment, pick up Bailer, arm and load cmt RIH w/ tool string CCL 40 ft. dump bailer loaded with 20 gallons Neo super slurry system P/n 0105-175-017 70* to 175*F service temperature, tagged CIBP at 3553 ft ELM dump cmt. pooh Reload bailer w/ 20 gallons of Neo super slurry system P/n 0105-175-017 for 70* to 175* service temperature RIH dumping cmt at 3541 ft. EST top of cmt at 3528',,Rig down E-line,Rig down rig floor,Nipple down 13- 5/8 bops' & load on trailer,Install and torque up Dry hole tree,Rig down Rig and stage & spot at production shop,Had no response from the AOGCC on test notification to witness the MIT on CIBP set at 3553 ft. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: BRU 212-24T Beluga River Hilcorp Energy Company Composite Report , AK Contractor AFE #: AFE $: Job Name:222-00413 BRU 212-24T Decomplete - Sidetrack Prep Spud Date: continue to rig up 401 support equipment g gpp Had no response from the AOGCC on test pqpy notification to witness the MIT on CIBP set at 3553 ft. Fluid pack the tubing and pressure test against CIBP to 3,000psi for 30min. Test good, p held each test 5pqpp minutes on chart, no failures, witnessed waived by AOGCC Jim Regg, Eline equipment, pick up Bailer, arm and load cmt RIH w/ tool string CCL 40 ft. dump bailer loaded with 20 gallons Neo super slurry gpqppp gpgpy system P/n 0105-175-017 70* to 175*F service temperature, tagged CIBP at 3553 ft ELM dump cmt. pooh Reload bailer w/ 20 gallons of Neo super slurry systemypggpp P/n 0105-175-017 for 70* to 175* service temperature RIH dumping cmt at 3541 ft. EST top of cmt at 3528',, gg g p g p p p p gg g g g ppqp Spot E-line equipment and rehead, rig up sheaves, make up 7" 26#CIBP,RIH with 7" CIBP; set down at 3564' ELM, run correlation pass sent log topp qp Town (on depth) set 7" CIBP AT 3553' ELM R/U E-line pqp tools and stab lubricator on well. Pressure test 3x and had to change o-rings p gg Final lubricator pressure test to 250psi/1500psi - test good,M/U and RIH with CCL and 3.5" (2.50"OD) jet cutter, CCL to jet cutter 5.0ft. Pressure up the tubingpppg (T/IA) (400psi/10psi),Correlate and cut tubing at 3,565ft (6ft above collar). pqp p RIH w/ CCL and 3.5" CIBP (2.75" OD). CCL to center of element 7.75ft.,Correlate on depth and set pp g 3.5" at 3575ft. Pick up and tag plug, good tag. POOH This last line is referring to the COA on Sundry 322-031 for a 3000 psi MIT on the 7" CIBP. -WCB yp pg pp gqp Test BOP equipment as per AOGCC and Hilcorp specs, to 250 psi low and 3000 psi hi qp yppg y unseat hanger at 60k, string 50k, lay out Vetco NB-230 hanger,,POOH laying down 3-qp p 1/2", 9.2#, EUE, L-80 tbg Activity Date Ops Summary 9/4/2022 Final report for BRU 222-34. Released rig, moved to well BRU 233-23 AFE @ 12:00 hrs.;Brought in CCI crane, spotted, picked, and installed BOP’s in cradle. Loaded out and hauled off boiler #1 and diesel auxiliary tank. Got pod #1 on MP #2 removed. Pulled rotary table cover, cleaned, and replaced broken off grease fitting make it easer to lock table.;R/D the TD torque bushing. Hauled off MWD shack and 400 bbl vertical water tank to staging pad. Installed transport beams in sub base. Performed EAM's on misc. rig equip. Changed oil in floor motor. R/D boiler and change conex. Disabled catwalk HYD control;valve bank and capped lines. Prepped mud pits for transport. Removed equalizer lines in pits. Removed shaker rubbers, metal brackets, and inspected shaker beds for cracks (ok). Prepped rig floor for scoping derrick.;Continue to work on Mud pump #2. R/D move mud lab and geolog shack. R/D and L/D topdrive and put in cradle. Adjust travel distance on rig tongs. R/D change house. Clean out vacuum degasser and adjust cables. Replaced rubbers on shaker beds. Clear remaining tools and equipment from rig floor.;Remove stand pipe hard lines, Pressure wash pits, Pull expendables out of MP #1 for inspection. Fixed hydraulic leak and added nitrogen to a bottle in koomey. Pressure wash rig floor and equipment.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 0 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 0 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 0 bbls Losses Downhole 0 bbls Total 0 bbls 9/5/2022 Spot cane L/D poor boy. Move crane over by MP #2 P/U and install manifold and pulsation dampener and finish putting it together. Remove H2S/LEL sirens and unplug and roll up pason cables.;Replaced 4’ discharge valve to trip tank, free up the gun lines on pits 6,8,9. Re-installed valve bank on pipecat, connect all the lines and pressure test. Prepped rig floor and derrick to scope down. Scoped derrick.;Inspect valves and suction rubbers in all pits. Prepped rig floor and derrick to scope down. Scoped derrick. Clean mezzanine and cellar areas. Remove lower section of torque tube. Secure boom line. Lower roofs on pits 2 and 3. Fold up derrick board. Power was the outside of all the rig components.;Inspect MP #2 pod #1 removed hydraulic lines from sub and secured. Secure kelly hose and service loop for move. Remove jumper hoses from sub to pit. Clean pit walls and pipe skate. 9/6/2022 Secure BOP hoist. Remove brake handle driveshaft. Re-wire trip tank pump. Rig down pits for move to K pad. Grease crown. Added foot chain for brake handle. Put nitrogen in Accumulator bottles. Organize inventory. Clean generator 2 radiator.;Drill holes in catwalk gates for retention pins, lower dog runs on pit roofs. Clean frac tank #2.;Pressure wash rig matts and catwalk, modify JSA's for rigging down/up derrick board. R/D controls for pipe cat;Complete EAM's, organize parts conex. Cont. modifying JSA's , Repair centrifuge discharge line, suck out containments and cont. washing rig 9/7/2022 Continue to clean rig and location. Repair centrifuge discharge line. Recharge koomey bottles. Change fuel filter on boiler. Grease HP valves in pump houses. Organize 40' connex. Grease both MP transmissions. Remove lights from top of pits. Create JSA for operating skate.;Lay down catwalk and derrick prepping rig for move. R/D coms and offices and start moving to K pad. Set rig matts and spot expeditor-DSM and Gen shacks. Assist with pad leveling;Cont. setting matts and placing pusher trailer- change room and meeting trailer on K pad. Dig down shifting and burying 1 in pipe next to 233-23 for rig matt placement. Noticed freshly finished cellar on BRU 214-13 looked high. Measurement confirmed top of cellar box was 5 inches above pad level.;Discussion with town and decision was made to cut and lower cellar box to pad level.;Moved and set 2nd change room to K pad, Back filled first 4ft of BRU 214-13 cellar box with dirt. Sucked rain water out of containment around rig. Staged felt and rig matts on K pad for rig move. Conducted Pre-spud meeting with night crew. 9/8/2022 Continue perform general maintenance, clean and organize rig modules and prep to move, Rig movers tear out cat walk and pits and pump modules, pull water tank and gen skid, pull top drive HPU, Clean up location, pull mats and load out on trailers, stage modules on J pad, clean up liner and felt.;Welders cutting 6'' off cellar and rewelding grating supports, Coms up and running, Notify AOGCC of upcoming BOP Test 9/8/2022 3:39 PM.;Continue welding on cellar, continue cleaning all trash and debris from F pad, compact k pad extension, Finish welding cellar, back fill and grade location.;Continue grade and compact location, transport mats to K-pad and lay felt around well.;Lay liner and set rig mats around well. Move light plant back to F-pad and set up for rigging down derrick and sub. Cont working on JSA modifications for rig move operations.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 0 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 0 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 0 bbls Losses Downhole 0 bbls Total 0 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: BRU 241-24T P&A Beluga River Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:Sidetrack BRU 241-24T -> BRU 233-23 Spud Date: gp Notify AOGCC of upcoming BOP Test 9/8/2022 3:39 PM. 9/9/2022 Spot in cranes around sub, un pin and hoist derrick off sub on to trailer and secure for transport, hoist draw works skid onto trailer, Pick sub off pony walls and load on to bed truck, load mats and pony subs onto trailer and ship to K pad, pick up remaining mats and clean up location, set pony;subs over well, spot in cranes and set sub on pony subs, hoist draw works into position, spot in test pump, AOGCC waived witness of BOP Test @ 9/9/2022 8:35 AM.;Set derrick on sub and pin, spot in water tank, Raise derrick and pin, raise dog house, fold out landings and install handrails, hook up electrical, Spot in pit modules #1 & #2 set jig in place, spot in pump #1 , Raise pit rooves fold down landings and walk ways, fold out grasshopper, set pump #2.;roll out felt and liner for catwalk, set mats in place for catwalk, spot in bubble for pump house, spot in gen set, set in top drive HPU building, spot in gas buster.;Spot in boiler and 40' parts conex, spot in catwalk, plug in electrical and hydraulics throughout rig, install outer lights and gas alarms. Make up jumper hoses from pump house to pits and hoppers as well has mud lines to rig floor.;Spot up right water tank, plug in pason . Install centrifuge and set cuttings box. Spot mud engineer and mud logger shacks.;Cont. to plug in pason, set sperry shack and power up third party shacks . Install dog nut and spool drilling line onto draw works, Install lower section of torque tube, Scope up derrick- install turnbuckles and T-bar. Bridle down, rig up to top drive and P/U to rig floor. 9/10/2022 Continue Rigging up top drive, install torque bushing, hook up service loops and kelly hose, install S pipe on stand pipe, hook up mud lines, Crane setting wind walls and gas buster,. hook up pason lines, power up and rig up third party shacks, Handi Berm Rigging up containment around rig, work on;welding projects around rig, agitator guides in pit bottoms worn out, fix broken bracket on stand pipe, build mud docks and stage mud product on docks, dress top drive Saver sub and bails, bring handling equipment to floor remove shipping beams in cellar, transfer BOP stack to bridge cranes.;Finish rig acceptance checklist, finish welding projects in pits, fill with water and check for leaks, Continue N/D Dry hole tree and repositioning annulus valves, N/U BOP stack, N/U Choke and Kill lines, Hook up Koomey Hoses.;Cont. N/U Choke, Kill and Koomey hoses, Installed chain binders flow line and hole fill line. Build mud. Flood all surface lines with water checking for leaks. Grease fitting cracked - replaced and PT surface lines.;Bring subs, XO's and well control valves to rig floor. Test TQ on iron roughneck and top drive.;Obtain RKB's, Rig up testing equipment, install test plug on 4.5" test jt. and run in 2 LDS, Fill all surface equipment and purge air from system. Perform shell test. Cont to build mud in pits.;Test BOP's on 4.5" test JT as per AOGCC regulations. 250 psi Low/3500 psi High for 5/5 min.. Bring drill pipe and HWDP tubs to location and set staging racks. Cont. to build mud in pits. Rig accepted at 02:00 hrs.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 0 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 0 bbls ISO Tanks Loaded 104 bbls ISO Tanks Total 104 bbls Losses Downhole 0 bbls Total 0 bbls 9/11/2022 Continue Testing BOP's w/ 4.5'' test Jt t/ 250/3500 psi Test CMV 1-13, Upper Lower and Blind rams, TIW and Dart, HCR and Man Choke and Kill valves, outside kill line valve, Auto and Man IBOP, Annular t/ 250/2500 psi Perform Accumulator Draw down test 28 sec t/ 200 psi 93 sec t/ full pressure, State;Inspector Jim Regg Waived witness, had three fail passes, Blinds - Replace Elements retest pass, Annular- Function retest pass, Lower pipe rams - Function retest pass.;Blow down lines and R/D test equipment, pull test plug set wear ring, Load strap and tally DP.;P/U Clean Out BHA, Mule shoe float and 6.125'' upper string mill HWDP and Jars, Single in the hole P/U DP tagging TOC @ 3524' with 5K down 2 times, Picked up to 3518', worked pipe F/2867' T/2930' 35 RPM, 3.5K TQ while RIH.;Displace well from produced water to 9.3 PPG 6% KCL PHPA mud, 8 BPM, 404 PSI. Monitor well= static.;POOH on elevators F/3518' T/surface - L/D Mule shoe float and upper 6.125" string mill.;Rig up Alaska E-line sheaves and run E-line, M/U CCL and Gamma tools, rig up to CIBP, Zero at rig floor, RIH on E-line @ 150 Ft/min to 3250' tying in with gamma and ccl logs from 212-24T CBL. Locate collar at 2929' and set CIBP @ 2924'.;Let rest for 5 min pick up 10' running back down and tagging plug verifying plug set. POOH and R/D E-line.;Close the blinds rig up and pressure test CSG/CIBP to 3200 PSI for 30 min- good test. Pumped 57.5 gal bleeding back 57.5 gal. R/D testing equipment and blow down choke and kill lines.;M/U window mill, lower mill, flex pup and upper mill, on btm of flex collar, M/U DM-Scribe DM to slide with a 221.9 Deg offset. M/U TM and perform shallow hole test. P/U whipstock and M/U with 35K shear screw. RIH with whip stock to 588'.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 0 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 0 bbls ISO Tanks Loaded 104 bbls ISO Tanks Total 104 bbls Losses Downhole 0 bbls Total 0 bbls 9/12/2022 Continue RIH w/whipstock BHA f/588' to 2878', filled pipe and orient whipstock t/31°L slack off and tag CIBP @ 2924' DPM, set anchor w/10k SOW, sheared whipstock bolt w/ 23k SOW. Up wt 55K, dwn wt 50K.;Begin milling window in 7" casing from 2907' (TOW) to 2920' (BOW), 1-3K wob, 250 gpm-850 psi, 100 rpm- 3400 ft/lbs torque, 1 to 6 ft/hr ROP. At 2920' milling ahead 3K wob, 193 gpm-556 psi, 10 to 15 ft/hr ROP, at 2925' 7 to 8K wob, 190 gpm-890 psi, 4-5 ft/hr ROP. Milled rathole;from 2920' to 2941'. Mudloggers seeing good show of cement and claystone on shakers.;At 2920' pumped a 20 bbl hi-vis nutplug sweep around at 189 gpm-887 psi, 90 rpm-2500 ft/lbs off bott torque. Worked mills through window as per Baker Rep.;Racked back 1 std to 2896', Rig up test equipment, Purge air from system and Perform FIT at 2887' TVD to 782 psi- 14.4 ppg EMW holding for 10 min bleeding down to 710 psi, pumped 14.4 gal. beld back 13.5 gal., Rig down test equipment and blow down kill line.;Pumped dry job and POOH F/2896' T/494' observing Calculated displacement, monitor well - static.;Rack back 8 stds of HWDP, L/D Float-TM collar and DM collar one piece. Break down mill assembly and L/D flex collar. Upper and Lower mill in gauge, Starter mill 3/16" under gauge.;M/U Jet sub and flush stack, drain stack and pull wear ring cleaning off profile and wear ring, reinstall wear ring and RILDS.;Pick up mud motor ( 1.5 deg Bend ) and M/U DM and TM, M/U 6 1/8" bit and scribe motor to DM with a 341.96 Deg offset. M/U 2 Flex collars and RIH with 8 plus jar stand of HWDP to 675'. Shallow hole test @ 250 gpm, 950 psi.;Single in the hole F/675' T/2530', PU 52K, SO 46K.;Dragon Boxes Loaded 0 bbls Total Dragon Boxes 0 bbls Cuttings Totes Loaded 0 bbls Total Cuttings Totes 0 bbls ISO Tanks Loaded 0 bbls ISO Tanks Total 208 bbls Losses Downhole 0 bbls Total 0 bbls Continue RIH w/whipstock BHA f/588' to 2878', filled pipe and orient whipstock t/31°L slack off and tag CIBP @ 2924'DPM, set anchor w/10k SOW, shearedppppg@ whipstock bolt w/ 23k SOW. Up wt 55K, dwn wt 50K.;Begin milling window in 7" casing from 2907' (TOW) to 2920' (BOW), Continue Testing BOP's w/ 4.5'' test Jt t/ 250/3500 psi Test CMV 1-13, Upper Lower and Blind rams, TIW and Dart, HCR and Man Choke and Kill valves, outside gppp kill line valve, Auto and Man IBOP, Annular t/ 250/2500 psi Perform Accumulator Draw down test 28 sec t/ 200 psi 93 sec t/ full pressure, State;Inspector Jimpppp Regg Waived witness, had three fail passes, Blinds - Replace Elements retest pass, Annular- Function retest pass, Lower pipe rams - Function retest pass pqgpp gp qp g Perform FIT at 2887' TVD to 782 psi- 14.4 ppg EMW holding for 10 min bleeding down to 710 psi, pumped 14.4 gal. beld back 13.5 gal., RIH with whip stock to 588' pg p py AOGCC waived witness of BOP Test @ 9/9/2022 8:35 AM Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/20/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 212-24T (PTD 210-050) Jet Cut 3/30/2022 Please include current contact information if different from above. PTD:210-050 T36590 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 11:55:21 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 212-24T (PTD 210-050) CBL 4/20/2022 Please include current contact information if different from above. PTD:210-050 T36581 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.10 10:13:34 -08'00' From:Howard Hooter - (C) To:DOA AOGCC Prudhoe Bay;Regg, James B (OGC);Brooks, Phoebe L (OGC) Subject:Emailing: Hilcorp Rig # 401 4-18-22 test RPT Date:Friday, April 22, 2022 5:27:01 PM Attachments:Hilcorp Rig # 401 4-18-22.xlsx [Some people who received this message don't often get email from howard.hooter@hilcorp.com. Learn why this is important at http://aka.ms/LearnAboutSenderIdentification.] CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Please see test rpt for BRU 212-24T Thanks ED Hooter Your message is ready to be sent with the following file or link attachments: Hilcorp Rig # 401 4-18-22 Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. ________________________________ The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ________________________________ %HOXJD5LYHU8QLW7 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:401 DATE: 4/18/22 Rig Rep.: Rig Phone: 907-283-2580 Operator: Op. Phone:318-452-8947 Rep.: E-Mail Well Name: PTD #22100500 Sundry #322-031 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250 / 3000 Annular:250 / 3000 Valves:250 / 3000 MASP:936 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.NA Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 13-5/8 5m P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5" VBR P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3-1/16 5M P Inside Reel valves 0NA HCR Valves 1 3-1/16 5M P Kill Line Valves 1 3-1/16 5M P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1800 P Quantity Test Result 200 psi Attained (sec)20 P No. Valves 8P Full Pressure Attained (sec)101 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 6 @ 2050 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:3.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/16/22 13:03 Waived By Test Start Date/Time:4/18/2022 10:00 (date) (time)Witness Test Finish Date/Time:4/18/2022 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 2-7/8" and 3-1/2" test joints, PVT and GAS dector and alarms tested by Quadco, Annular closing time 27 seconds Chris Hannevold Hilcorp Ed Hooter BRU 212-24T Test Pressure (psi): howard.hooter@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0418_BOP_Hilcorp401_BRU_212-24T 9 9 9 9999 9 9 9 9 -5HJJ Annular closing time 27 seconds 4/18/22 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert; Regg, James B (OGC) Cc:Howard Hooter - (C); Juanita Lovett; Dan Marlowe; Jacob Flora Subject:RE: BOPE for BRU 212-24T(PTD#210-050) Date:Monday, April 18, 2022 2:27:00 PM Attachments:BRU_212-24T_BOPE(2022).pdf Ryan, Approval granted for substituting the attached 13-3/8” stack for the 11” stack in the Sundry. 322- 031 Any changes to ram configurations would need to be reviewed/approved by AOGCC. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, April 18, 2022 2:09 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Howard Hooter - (C) <Howard.Hooter@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Jacob Flora <Jake.Flora@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: BOPE for BRU 212-24T(PTD#210-050) Bryan/Jim- Just wanted to reach out and inform you that the BOPE being used for current RWO well BRU 212- 24T (PTD#210-050) is slightly different than the one in approved sundry #322-031. Although the same ram configuration, we’ll be using the attached BOPE (13-5/8” instead of 11”) for all the BRU workovers. The diagrams in the other sundries appear to correctly reflect the 13-5/8” stack. The only exception well will be BRU 211-03 which we’ll reconfiguring for dual strings (subject of a separate email chain between Bryan and myself). Thank you Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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ϭϬΖ ϭϮͬϯϬͬϮϬϮϬ KƉĞŶ ĞůƵŐĂ&ϭ ϰ͕ϯϴϮ͛ ϰ͕ϯϵϯ͛ ϰ͕ϯϲϮ͛ ϰ͕ϯϳϯ͛ ϭϭ͛ ϳͬϮϮͬϮϬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ&ϰ ϰ͕ϰϯϮ͛ ϰ͕ϰϰϮ͛ ϰ͕ϰϭϮ͛ ϰ͕ϰϮϮ͛ ϭϬ͛ ϳͬϮϭͬϮϬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ&ϳ ϰ͕ϲϵϲ͛ ϰ͕ϳϭϵ ϰ͕ϲϳϲ͛ ϰ͕ϲϵϵ͛ Ϯϯ͛ ϳͬϵͬϮϬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ&ϭϬ ϰ͕ϳϯϱ͛ ϰ͕ϳϰϬ͛ ϰ͕ϳϭϱ͛ ϰ͕ϳϮϬ͛ ϰ͛ ϳͬϵͬϮϬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ'Ϯ ϰ͕ϴϲϰ͛ ϰ͕ϴϳϭ͛ ϰ͕ϴϰϰ͛ ϰ͕ϴϱϭ͛ ϳ͛ ϳͬϵͬϮϬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ'ϯ ϰ͕ϴϳϯ͛ ϰ͕ϴϳϴ͛ ϰ͕ϴϱϯ͛ ϰ͕ϴϱϴ͛ ϱ͛ ϳͬϴͬϮϬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ'ϰ ϰ͕ϵϮϮ͛ ϰ͕ϵϮϳ͛ ϰ͕ϵϬϮ͛ ϰ͕ϵϬϳ͛ ϱ͛ ϳͬϴͬϮϬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ,Ϯ ϱ͕ϭϴϳΖ ϱ͕ϮϬϬΖ ϱ͕ϭϲϳΖ ϱ͕ϭϴϬΖ ϭϯΖ ϴͬϭϵͬϮϬϭϮ /ƐŽůĂƚĞĚ ϱ͕ϭϴϳ͛ ϱ͕ϮϬϬΖ ϱ͕ϭϲϳΖ ϱ͕ϭϴϬΖ ϭϯ͛ ϴͬϭϳͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϯ ϱ͕ϮϭϳΖ ϱ͕ϮϮϰΖ ϱ͕ϭϵϳΖ ϱ͕ϮϬϰΖ ϳ͛ ϴͬϭϳͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϳ ϱ͕ϯϱϰ͛ ϱ͕ϯϲϮ͛ ϱ͕ϯϯϱ͛ ϱ͕ϯϰϯ͛ ϴ͛ ϴͬϭϳͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϵ ϱ͕ϰϭϭΖ ϱ͕ϰϮϭΖ ϱ͕ϯϵϭΖ ϱ͕ϰϬϭΖ ϭϬΖ ϴͬϭϲͬϮϬϭϮ /ƐŽůĂƚĞĚ ϱ͕ϰϭϭ͛ ϱ͕ϰϮϭ͛ ϱ͕ϯϵϮ͛ ϱ͕ϰϬϮ͛ ϭϬ͛ ϴͬϭϳͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϭϬ ϱ͕ϰϵϲΖ ϱ͕ϱϭϭΖ ϱ͕ϰϳϲΖ ϱ͕ϰϵϭΖ ϭϱΖ ϴͬϭϲͬϮϬϭϮ /ƐŽůĂƚĞĚ ϱ͕ϰϵϲ͛ ϱ͕ϱϭϭ͛ ϱ͕ϰϳϲ͛ ϱ͕ϰϵϭ͛ ϭϱ͛ ϴͬϭϲͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϭϯĂ ϱ͕ϱϴϲΖ ϱ͕ϱϵϲΖ ϱ͕ϱϲϲΖ ϱ͕ϱϳϲΖ ϭϬΖ ϴͬϭϱͬϮϬϭϮ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϭϯ ϱ͕ϱϴϲ͛ ϱ͕ϲϭϰ͛ ϱ͕ϱϲϲ͛ ϱ͕ϱϵϰ͛ Ϯϴ͛ ϴͬϭϲͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϭϯď ϱ͕ϲϬϰΖ ϱ͕ϲϭϰΖ ϱ͕ϱϴϰΖ ϱ͕ϱϵϰΖ ϭϬΖ ϴͬϭϱͬϮϬϭϮ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϭϲ ϱ͕ϳϰϬ͛ ϱ͕ϳϰϴ͛ ϱ͕ϳϮϬ͛ ϱ͕ϳϮϴ͛ ϴ͛ ϴͬϭϲͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ/ϮĂ ϱ͕ϳϴϲΖ ϱ͕ϳϵϰΖ ϱ͕ϳϲϲΖ ϱ͕ϳϳϰΖ ϴΖ ϳͬϮϴͬϮϬϭϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ/Ϯď ϱ͕ϴϭϴΖ ϱ͕ϴϯϬΖ ϱ͕ϳϵϴΖ ϱ͕ϴϭϬΖ ϭϮΖ ϳͬϮϴͬϮϬϭϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ/ϭ ϲ͕ϬϮϮΖ ϲ͕ϬϯϲΖ ϲ͕ϬϬϮΖ ϲ͕ϬϭϲΖ ϭϰΖ ϳͬϭϲͬϮϬϭϬ /ƐŽůĂƚĞĚ EŽƚĞ͗^͘^͘ďĂŶĚƐƵƐĞĚŽŶ^͘^͘ƚƵďŝŶŐŽŶϰ͘ϱ͟ƚƵďŝŶŐ;ϱƚŽƚĂůͿ͘ ĂŶŶŽŶůĂŵƉƐƵƐĞĚKŶϯ͘ϱ͟ƚƵďŝŶŐ &/^,d/>Λϰ͕ϵϯϮ͛ϭϬͬϮϰͬϮϬ WĞƌĨ'ƵŶ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ:>>ϬϭͬϭϵͬϮϮ WZKWK^ ĞůƵŐĂZŝǀĞƌhŶŝƚ tĞůů͗ZhϮϭϮͲϮϰd >ĂƐƚŽŵƉůĞƚĞĚ͗ϲͲϮϴͲϮϬϮϬ Wd͗ϮϭϬͲϬϱϬ W/͗ϱϬͲϮϴϯͲϮϬϭϯϲͲϬϬͲϬϬ ϮϬ͟ ϵͲϱͬϴ͟ ϳ͟ Z<ƚŽD^>сϵϲ͘ϱ͛Z<ƚŽ'>сϭϴ͘ϯ͛ dсϲ͕ϱϲϱ͛dsсϲ͕ϱϰϱ͛ Wdсϰ͕ϯϰϮ͛dsсϰ͕ϯϮϮ͛ DĂǆŶŐůĞсϭϬ͘ϬϴĚĞŐΛϭ͕ϰϭϭ͘Ϯ͛ dKΛϮ͕ϴϲϬ͛ ĞůƵŐĂ,^ĂŶĚƐ ,Ϯ ,ϯ ,ϳ ,ϵ ,ϭϬ ,ϭϯ ,ϭϲ ZdĂŐΛϯ͕ϬϬϴ͘ϭϰ͛ ZdĂŐΛϯ͕ϱϬϲ͘ϴϰ͛ ZdĂŐΛϰ͕ϴϭϵ͘ϲϳ͛ ϰ ϴ ϲ ϵ yϱ &ϭͲ&ϰ &ϳͲ&ϭϬ 'ϮͲ'ϰ dŽƉŽĨ&ŝƐŚΛ ϰ͕ϵϯϮ͛ϭϬͬϮϰͬϮϬ ϳ ϭͲϱ ϮͲϯ ϰ /WΛΕϯϱϰϬ͛ ǁϮϱ͛ Đŵƚ :ĞƚƵƚΛΕϯϱϲϬ͛ /WΛΕϯϱϳϬ͛ ^/E'd/> ^ŝǌĞ dǇƉĞ td 'ƌĂĚĞ ŽŶŶ / ƚŵ ϮϬΖΖ ŽŶĚƵĐƚŽƌ ϭϱϰ͘ϭϵη yͲϲϱ t> ϭϵ͘ϭϯΖΖ ϭϬϴΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬη >ͲϴϬ dD ϴ͘ϴϯϱΖΖ Ϯ͕ϴϱϭΖ ϳΖΖ WƌŽĚƵĐƚŝŽŶ Ϯϲη >ͲϴϬ dD ϲ͘ϮϳϲΖΖ ϲ͕ϱϯϱΖ dh/E'd/>^ ϯͲϭͬϮΗ WƌŽĚƵĐƚŝŽŶ ^ƚƌŝŶŐ ϵ͘Ϯη >ͲϴϬ ϴZhцϯ͕ϱϲϬ͛Ͳϰ͕ϯϬϭ͛ :t>Zzd/> /͘ĞƉƚŚD ;Ĩƚ͘Ϳ / ;ŝŶ͘Ϳ ĞƐĐƌŝƉƚŝŽŶ цϯ͕ϱϰϬ͛ /WǁͬϮϱ͛ĐĞŵĞŶƚ;Ɛƚ͘dKϯ͕ϱϭϱ͛Ϳ цϯ͕ϱϲϬ͛ :ĞƚĐƵƚƚƵďŝŶŐ цϯ͕ϱϳϬ͛ /W ϰ ϯ͕ϱϴϬ ,>WĂĐŬĞƌ ϱ ϯ͕ϲϬϬ Ϯ͘ϴϭϯ͟ yͲEŝƉƉůĞ ϲϰ͕ϯϬϮ t>' ϳ ϰ͕ϯϲϬ ^ƉŝƌĂůWůƵŐǁͬϭϴ͛ĐĞŵĞŶƚ;dKΛϰ͕ϯϰϮ͛ͿϭϮͬϮϰͬϮϬ ϴ ϰ͕ϵϵϱ dƵďŝŶŐWůƵŐǁͬϮϱ͛ĐĞŵĞŶƚ;dKΛϰ͕ϵϳϬ͛ͿϲͬϮϯͬϮϬ ϵ ϲ͕ϯϱϬ͛ ,ĂůůŝďƵƌƚŽŶƌŝůůƌŝĚŐĞƉůƵŐϳͬϯͬϮϬϭϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ĂƚĞ ^ƚĂƚƵƐ ^ƚĞƌůŝŶŐϰ ϯ͕ϱϵϰΖ ϯ͕ϲϬϭΖ ϯ͕ϱϳϰΖ ϯ͕ϱϴϭΖ ϯͬϮϲͬϮϬϮϭ KƉĞŶ ^ƚĞƌůŝŶŐϮ ϯ͕ϲϰϰΖ ϯ͕ϲϱϰΖ ϯ͕ϲϮϰ͛ ϯ͕ϲϯϰ͛ ϰͬϭϭͬϮϬϮϭ KƉĞŶ ϯ͕ϲϳϬ͛ ϯ͕ϲϴϬ͛ ϯ͕ϲϱϬ͛ ϯ͕ϲϲϬ͛ ϯͬϮϲͬϮϬϮϭ KƉĞŶ ϯ͕ϲϴϬ͛ ϯ͕ϲϵϬ͛ ϯ͕ϲϲϬ͛ ϯ͕ϲϳϬ͛ ϯͬϮϱͬϮϬϮϭ KƉĞŶ ^ƚĞƌůŝŶŐϯ ϯ͕ϳϭϭΖ ϯ͕ϳϮϭΖ ϯ͕ϲϵϭ͛ ϯ͕ϳϬϭ͛ ϰͬϭϭͬϮϬϮϭ KƉĞŶ ĞůƵŐĂϭ ϯ͕ϴϲϭΖ ϯ͕ϴϲϰΖ ϯ͕ϴϰϮ͛ ϯ͕ϴϰϱ͛ ϭϮͬϯϭͬϮϬϮϬ KƉĞŶ ϯ͕ϴϳϮΖ ϯ͕ϴϳϳΖ ϯ͕ϴϱϯ͛ ϯ͕ϴϱϴ͛ ϭϮͬϯϭͬϮϬϮϬ KƉĞŶ ĞůƵŐĂϱ ϯ͕ϵϱϳΖ ϯ͕ϵϲϭΖ ϯ͕ϵϯϳ͛ ϯ͕ϵϰϭ͛ ϭϮͬϯϭͬϮϬϮϬ KƉĞŶ ϯ͕ϵϳϬΖ ϯ͕ϵϳϯΖ ϯ͕ϵϱϬ͛ ϯ͕ϵϱϯ͛ ϭϮͬϯϭͬϮϬϮϬ KƉĞŶ ĞůƵŐĂϲ ϰ͕ϬϬϴΖ ϰ͕ϬϮϭΖ ϯ͕ϵϴϴ͛ ϰ͕ϬϬϭ͛ ϭϮͬϯϭͬϮϬϮϬ KƉĞŶ ĞůƵŐĂϱ ϰ͕ϮϭϵΖ 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ϱ͕ϲϬϰΖ ϱ͕ϲϭϰΖ ϱ͕ϱϴϰΖ ϱ͕ϱϵϰΖ ϴͬϭϱͬϮϬϭϮ /ƐŽůĂƚĞĚ ĞůƵŐĂ,ϭϲ ϱ͕ϳϰϬ͛ ϱ͕ϳϰϴ͛ ϱ͕ϳϮϬ͛ ϱ͕ϳϮϴ͛ ϴͬϭϲͬϮϬϭϴ /ƐŽůĂƚĞĚ ĞůƵŐĂ/ϮĂ ϱ͕ϳϴϲΖ ϱ͕ϳϵϰΖ ϱ͕ϳϲϲΖ ϱ͕ϳϳϰΖ ϳͬϮϴͬϮϬϭϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ/Ϯď ϱ͕ϴϭϴΖ ϱ͕ϴϯϬΖ ϱ͕ϳϵϴΖ ϱ͕ϴϭϬΖ ϳͬϮϴͬϮϬϭϬ /ƐŽůĂƚĞĚ EŽƚĞ͗^͘^͘ďĂŶĚƐƵƐĞĚŽŶ^͘^͘ƚƵďŝŶŐŽŶϰ͘ϱ͟ƚƵďŝŶŐ;ϱƚŽƚĂůͿ͘ ĂŶŶŽŶůĂŵƉƐƵƐĞĚKŶϯ͘ϱ͟ƚƵďŝŶŐ &/^,d/>Λϰ͕ϵϯϮ͛ϭϬͬϮϰͬϮϬ WĞƌĨ'ƵŶ 7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG ϭϭΗ ^ƉŚĞƌŝĐĂůŶŶƵůĂƌ ,ĞŝŐŚƚ͗ϰϮΗ ϭϭΗ >t^ŽƵďůĞKW ϮͲϳͬϴΗƚŽϱΗDƵůƚŝƌĂŵƐƚŽƉ ůŝŶĚƌĂŵƐďŽƚƚŽŵ ,ĞŝŐŚƚ͗ϯϯΗ ϭϭΗ DƵĚƌŽƐƐtͬϰͲϭͬϭϲΗ KƵƚůĞƚƐ ƵĂůϮͲϭͬϭϲΗDĂŶƵĂů'ĂƚĞ sĂůǀĞƐtͬ^ƚŽϰͲϭͬϭϲΗ tŝĚƚŚƚŽĨůĂŶŐĞ͗ϯϰΗ ϮͲϭͬϭϲΗDĂŶƵĂů'ĂƚĞsĂůǀĞ ΘϮͲϭͬϭϲΗ,Ztͬ^ƚŽϰͲ ϭͬϭϲΗ &Ƶůů DƵĚƌŽƐƐƐƐǇ͘ǁŝĚƚŚ ǁͬǀĂůǀĞƐŝŶƐƚĂůůĞĚ tŝĚƚŚ͗ϵϲΗ <ŝůůƐŝĚĞ ŚŽŬĞƐŝĚĞ KW^ƚĂĐŬtŝĚƚŚ͗ϵϲΗΛǀĂůǀĞƐ ,ĞŝŐŚƚĚĚŝƚŝŽŶĨŽƌZŝŶŐ'ĂƐŬĞƚƐ͗͘ϳϱΗ KWdŽƚĂů ,ĞŝŐŚƚ͗ϭϬϭ͘ϳϱΗ ϭϭΗϱŵKW WĂĐŬĂŐĞ tͬϮͲϭͬϭϲΗsĂůǀĞƐ David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: DATE: 07/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 212-24T (PTD 210-050) PERF RECORD 03/27/2021 Please include current contact information if different from above. Received By: 07/26/2021 37' (6HW By Abby Bell at 10:54 am, Jul 26, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,565 feet 4342, 4970, 6350 feet true vertical 6,545 feet 5,881 feet Effective Depth measured 4,342 feet 4,855 feet true vertical 4,322 feet 4,835 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 4,301' MD 4,283' TVD Packers and SSSV (type, measured and true vertical depth)DHL Packer 3,580' MD 3,559' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 108' 2,851' 0 Oil-Bbl measured true vertical Packer 7"6,535'6,516' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beluga River / Undefined GasN/A measured TVD Tubing Pressure 1610 Beluga River Unit (BRU) 212-24T N/A ADL0021128 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-050 50-283-20136-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-103 170 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 440 Authorized Signature with date: Authorized Name: 430 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 108' 2,851' 6,535' Conductor Surface Intermediate Production 5,410psi Casing Structural 20" 9-5/8" Length 5,750psi Collapse 3,090psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 7,240psi 108' 2,832' t Fra O 6. A G L PG , R r: Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 7:05 am, May 12, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.11 15:36:20 -08'00' Taylor Wellman (2143) RBDMS HEW 5/12/2021 BJM 8/10/21 DSR-5/12/21 SFD 5/13/2021 Rig Start Date End Date 3/24/21 4/11/21 Morning meeting, JSA PTW. Stand up PCE. Rig up 2.5" x 10' strip gun. Equipment issues. Rig down guns. RIH without guns to test equipment. Rig up guns RIH with 2.5" x 10' strip gun to perf at 3,670' - 3,680'. Correlate log sent to town. Shot 10' strip gun at depth 3,670' - 3,680' (CCL -25.2' 3,644.8' shot at 3,644.6') well pressure 475# POOH. OOH Rig up 2.5" x 7' strip gun to perf at 3,594" -3,601' Correlation log sent to town. Shot 2.5" x 7' strip gun at depth 3,594' - 3,601' (CCL -25.2' 3,568.8' shot at 3,568.7') well psi 475# after shot 480# POOH all shots fired. Rig down. 04/11/2021 - Sunday Arrive on location, Permit and JHA, Rig up, PT 250# low 2,500# high, RIH with 2" x 10' gun to perf at 3,711' -3,721' correlate 3,900' to 3,500', 2"x10' gun perf at 3,711'-3,721' (CCL -8.6' 3,702.4'). 105# on tubing, Attempt to POOH stuck in perfs. pulled out of rope socket. OOH Rig up 2.25" LIB RIH sat down at 4,161' attempt to get impression. POOH, LIB came back clean. Rig up 2"x10' gun, Correlate at 3,750' to 3,500' Shot depth 3,644'-3,654' (CCL -15.6 3,628.4'), 140# on tubing, POOH all shots fired, rig down. 03/24/2021 - Wednesday At Hilcorp hanger on weather hold. Arrive at Beluga JSA and prep equipment. Spot equipment. COB and resume tomorrow 03/25/2021 - Thursday Conduct JSA and PTW. Equipment issues with truck. Rig up and prep to RIH. Drum Transmission failure in draw works. Popped out of gear. dropped tool on surface. Repairing. PT 250 psi low 2,500 high. RIH with 2.5" x 10' gun to perforate 3,680' - 3,690'. Correlation log sent to town. Town requested add 5'. Made adjustment. (CCL -25.2' set depth to 3654.8') moved tool and stopped at 3654.9' Shot success. Shot PSI 750#, 5 minute 650#, 10 minute 550#, 15 minute 510#. POOH. OOH. All shots fired. Laying Down PCCE. Will resume operation in the morning. 03/26/2021- Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 Shot 10' strip gun at depth 3,670' - 3,680' perf at 3,711'-3,721' o perforate 3,680' - 3,690'. Shot 2.5" x 7' strip gun at depth 3,594' - 3,601' Shot depth 3,644'-3,654' _____________________________________________________________________________________ Updated by DMA 05-06-21 SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,342’ TVD = 4,322’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 2 1 3 4 8 6 9 X 5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,932’ 10/24/20 7 D1-E5 C2-C3 B4 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3-1/2" Production String 9.2# L-80 8RD EUE 4,301’ JEWELRY DETAIL ID. Depth MD (ft.) ID (in.) Description 1 1,616 Camco KBMG GLM 2 3,036 3-1/2” PSPOL-M Gas Lift Mandrel 3 3,115 3-1/2” PSPOL-Chemical Injection 4 3,580 DHL Packer 5 3,600 2.813” X-Nipple 6 4,302 WLEG 7 4,360 Spiral Plug w/ 18’ cement (TOC @ 4,342’) 12/24/20 8 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 9 6,350’ Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Sterling B4 3,594' 3,601' 3,574' 3,581' 7’ 3/26/2021 Open Sterling C2 3,644' 3,654' 3,624’ 3,634’ 10' 4/11/2021 Open 3,670’ 3,680’ 3,650’ 3,660’ 10' 3/26/2021 Open 3,680’ 3,690’ 3,660’ 3,670’ 10' 3/25/2021 Open Sterling C3 3,711' 3,721' 3,691’ 3,701’ 10' 4/11/2021 Open Beluga D1 3,861' 3,864' 3,842’ 3,845’ 3' 12/31/2020 Open 3,872' 3,877' 3,853’ 3,858’ 5' 12/31/2020 Open Beluga D5 3,957' 3,961' 3,937’ 3,941’ 4' 12/31/2020 Open 3,970' 3,973' 3,950’ 3,953’ 3' 12/31/2020 Open Beluga D6 4,008' 4,021' 3,988’ 4,001’ 13' 12/31/2020 Open Beluga E5 4,219' 4,223' 4,200’ 4,204’ 4' 12/30/2020 Open 4,254' 4,264' 4,234’ 4,244’ 10' 12/30/2020 Open Beluga F1 4,382’ 4,393’ 4,362’ 4,373’ 11’ 7/22/2020 Isolated Beluga F4 4,432’ 4,442’ 4,412’ 4,422’ 10’ 7/21/2020 Isolated Beluga F7 4,696’ 4,719 4,676’ 4,699’ 23’ 7/9/2020 Isolated Beluga F10 4,735’ 4,740’ 4,715’ 4,720’ 4’ 7/9/2020 Isolated Beluga G2 4,864’ 4,871’ 4,844’ 4,851’ 7’ 7/9/2020 Isolated Beluga G3 4,873’ 4,878’ 4,853’ 4,858’ 5’ 7/8/2020 Isolated Beluga G4 4,922’ 4,927’ 4,902’ 4,907’ 5’ 7/8/2020 Isolated Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing FISH DETAIL @ 4,932’ 10/24/20 Perf Gun Sterling B4 3,594' 3,601'3,574'3,581'7’ 3/26/2021 Open Sterling C2 3,644' 3,654'3,624’3,634’10' 4/11/2021 Open 3,670’ 3,680’3,650’3,660’10' 3/26/2021 Open 3,680’ 3,690’3,660’3,670’10' 3/25/2021 Open Sterling C3 3,711' 3,721'3,691’3,701’10' 4/11/2021 Open /p( )()p( )() Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/04/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 212-24T (PTD 210-050) PERFORATING RECORD 04/08/2021 Please include current contact information if different from above. PTD: 2100500 E-Set: 35079 Received by the AOGCC 05/04/2021 05/04/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/12/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 212-24T (PTD 210-050) PERFORATING RECORD 03/26/2021 Please include current contact information if different from above. PTD: 2100500 E-Set: 34954 Received by the AOGCC 04/12/2021 04/12/2021 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: __ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?Spacing Exception CO 629 Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,565'5,881' Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng tkramer@hilcorp.com 6,545'4,342'4,322'1,288 4342, 4970, 6350 DHL Pkr; N/A 3,580' MD / 3,559' TVD; N/A, N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0021128 210-050 50-283-20136-00-00 Beluga River Unit (BRU) 212-24T Beluga River / Undefined Gas Length Size Undefined Gas Pool, Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 TVD Burst 4,301' 7,240psi MD 5,750psi 108' 2,832' 108' 2,851' 6,516'7" 20" 9-5/8" 108' 2,851' 6,535' Perforation Depth MD (ft): See Attached Schematic 6,536' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: March 15, 2021 3-1/2" m n P 66 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:48 am, Mar 02, 2021 321-103 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.02 08:40:54 -09'00' Taylor Wellman (2143) 10-404 DSR-3/2/213/2/2021BJM 3/11/21 Comm. 3/12/21 dts 3/12/2021 RBDMS HEW 3/15/2021 Well Prognosis Well: BRU 212-24T Date: 3/1/2021 Well Name: BRU 212-24T API Number: 50-283-20136-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 3/15/2020 Rig: E-line Reg. Approval Req’d: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 210-050 First Call Engineer: Ted Kramer (907) 777-8420 (O) (907) 865-0665 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) AFE Number Current Bottom Hole Pressure: ~1,669 psi @ 3,819’ TVD Calc’d using 0.437 Psi./ft. Max. Expected BHP: ~1669psi @ 3,819’ TVD (Virgin Pressure) Max. Potential Surface Pressure: ~1288 psi (0.1 gas gradient to surface) Brief Well Summary: Originally drilled in 2010 as a single I sand completion. Two I sands were perforated (36' total) and came online making 3 MMCFD. Completed as a single 3-1/2" tbg string to 4892' with a single packer @ 4855' (just below the Bel G sand). The well was on a pretty steep decline, 37% effective annual decline for a solid two years until it was decided to move up hole and complete the H sands - with a fracture stim treatment. The I sand cum'd just over 1.5 BCF, they were isolated and the H sands were perf’s and frac'd thru tbg. A total of 4 zones were frac'd (58' total) with ~75,000 lbs. 20-40 curable resin coated ceramic proppant and gel. The well came online making just under 4 MMCFD then operations have done well to get well just under 5 MMCFD and has sustained a flat rate of just over 3MMCFD for the past few years. The H sands have cum'd 6 BCF to date. During most of 2019 the well had been struggling to flow smoothly without holding back pressure and then fell from 3.0 MMCFD to about 2.0 MMCFD and then completely died in December 2019. In July 2020, a workover was completed moving the packer and tbg up-hole enable to access the rest of the intervals. 7 of the Beluga G and F sands were perf’d thru the month of July bringing on about 500 mcfd rate but also sand and water production – eventually sanding up entirely and dying off. On 10/24/2020 a slick line tag was made to 4,932’ with a 2.50” bailer. In February of 2021, a second tag was made at 4,375’. Procedure Summary: The objective of this work is to perforate the Sterling C5, C3, C2, and B4 sands thru tubing. No plug will be set. E-line / Slickline Procedure: 1. MIRU slickline/ E-line Combo unit. PT lubricator to 250 psi low / 2500 psi high. 2. RIH with GPT Tool and determine Fluid level. 3. PU drift for 2” guns. Drift to 3,900’. If unable to drift to depth, contact Operations Engineer. E-Line Procedure: 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low / 2500 psi high. 2. Perforate the below sands : o perforate the Sterling C5, C3, C2, and B4 sands t Well Prognosis Well: BRU 212-24T Date: 3/1/2021 Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Sterling B4 ±3,594' ±3,601' ±3,574' ±3,581' ±7’ TBD Proposed Sterling C2 ±3,645' ±3,690' ±3,645' ±3,690' ±45’ TBD Proposed Sterling C3 ±3,709' ±3,724' ±3,689' ±3,704' ±15' TBD Proposed Sterling C5 ±3,756' ±3,769' ±3,736' ±3,749' ±13' TBD Proposed Sterling C5 ±3,787' ±3,819' ±3,799' ±3,819' ±32' TBD Proposed a. Proposed perfs also shown on the proposed schematic in red font. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. Use Gamma/CCL to correlate. d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Beluga River Unit falls under the Beluga River undefined Gas Pool. The undefined gas pool at Beluga River includes both the Beluga and the Sterling gas sands. Well - BRU 212-24T has a spacing exception covered by CO 629. 1. POOH. RD E-line. 2. Turn Well over to Production. Attachments: 1. Actual Schematic 2. Proposed Schematic The undefined gas pool at Beluga River includes both the Beluga and the Sterling gas sands. Well - BRU 212-24T has a spacing exception covered by CO 629. _____________________________________________________________________________________ Updated By DMA 01-08-21 SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,342’ TVD = 4,322’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 2 1 3 4 8 6 9 X 5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,932’ 10/24/20 7 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3-1/2" Production String 9.2# L-80 8RD EUE 4,301’ JEWELRY DETAIL ID. Depth MD (ft.) ID (in.) Description 1 1,616 Camco KBMG GLM 2 3,036 3-1/2” PSPOL-M Gas Lift Mandrel 3 3,115 3-1/2” PSPOL-Chemical Injection 4 3,580 DHL Packer 5 3,600 2.813” X-Nipple 6 4,302 WLEG 7 4,360 Spiral Plug w/ 18’ cement (TOC @ 4,342’) 12/24/20 8 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 9 6,350’ Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga D1 3,861' 3,864' 3,842’ 3,845’ 3' 12/31/2020 Open Beluga D1 3,872' 3,877' 3,853’ 3,858’ 5' 12/31/2020 Open Beluga D5 3,957' 3,961' 3,937’ 3,941’ 4' 12/31/2020 Open Beluga D5 3,970' 3,973' 3,950’ 3,953’ 3' 12/31/2020 Open Beluga D6 4,008' 4,021' 3,988’ 4,001’ 13' 12/31/2020 Open Beluga E5 4,219' 4,223' 4,200’ 4,204’ 4' 12/30/2020 Open Beluga E5 4,254' 4,264' 4,234’ 4,244’ 10' 12/30/2020 Open Beluga F1 4,382’ 4,393’ 4,362’ 4,373’ 11’ 7/22/2020 Isolated Beluga F4 4,432’ 4,442’ 4,412’ 4,422’ 10’ 7/21/2020 Isolated Beluga F7 4,696’ 4,719 4,676’ 4,699’ 23’ 7/9/2020 Isolated Beluga F10 4,735’ 4,740’ 4,715’ 4,720’ 4’ 7/9/2020 Isolated Beluga G2 4,864’ 4,871’ 4,844’ 4,851’ 7’ 7/9/2020 Isolated Beluga G3 4,873’ 4,878’ 4,853’ 4,858’ 5’ 7/8/2020 Isolated Beluga G4 4,922’ 4,927’ 4,902’ 4,907’ 5’ 7/8/2020 Isolated Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing FISH DETAIL @ 4,932’ 10/24/20 Perf Gun _____________________________________________________________________________________ Updated By TRH 23Feb2021 PROPOSED Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,342’ TVD = 4,322’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 2 1 3 4 8 6 9 X 5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,932’ 10/24/20 7 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3-1/2" Production String 9.2# L-80 8RD EUE 4,301’ JEWELRY DETAIL ID. Depth MD (ft.) ID (in.) Description 1 1,616 Camco KBMG GLM 2 3,036 3-1/2” PSPOL-M Gas Lift Mandrel 3 3,115 3-1/2” PSPOL-Chemical Injection 4 3,580 DHL Packer 5 3,600 2.813” X-Nipple 6 4,302 WLEG 7 4,360 Spiral Plug w/ 18’ cement (TOC @ 4,342’) 12/24/20 8 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 9 6,350’ Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Sterling B4 ±3,594' ±3,601' ±3,574' ±3,581' ±7’ TBD Proposed Sterling C2 ±3,645' ±3,690' ±3,645' ±3,690' ±45’ TBD Proposed Sterling C3 ±3,709' ±3,724' ±3,689' ±3,704' ±15' TBD Proposed Sterling C5 ±3,756' ±3,769' ±3,736' ±3,749' ±13' TBD Proposed Sterling C5 ±3,787' ±3,819' ±3,799' ±3,819' ±32' TBD Proposed Beluga D1 3,861' 3,864' 3,842’ 3,845’ 3' 12/31/2020 Open Beluga D1 3,872' 3,877' 3,853’ 3,858’ 5' 12/31/2020 Open Beluga D5 3,957' 3,961' 3,937’ 3,941’ 4' 12/31/2020 Open Beluga D5 3,970' 3,973' 3,950’ 3,953’ 3' 12/31/2020 Open Beluga D6 4,008' 4,021' 3,988’ 4,001’ 13' 12/31/2020 Open Beluga E5 4,219' 4,223' 4,200’ 4,204’ 4' 12/30/2020 Open Beluga E5 4,254' 4,264' 4,234’ 4,244’ 10' 12/30/2020 Open Beluga F1 4,382’ 4,393’ 4,362’ 4,373’ 11’ 7/22/2020 Isolated Beluga F4 4,432’ 4,442’ 4,412’ 4,422’ 10’ 7/21/2020 Isolated Beluga F7 4,696’ 4,719 4,676’ 4,699’ 23’ 7/9/2020 Isolated Beluga F10 4,735’ 4,740’ 4,715’ 4,720’ 4’ 7/9/2020 Isolated Beluga G2 4,864’ 4,871’ 4,844’ 4,851’ 7’ 7/9/2020 Isolated Beluga G3 4,873’ 4,878’ 4,853’ 4,858’ 5’ 7/8/2020 Isolated Beluga G4 4,922’ 4,927’ 4,902’ 4,907’ 5’ 7/8/2020 Isolated Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing FISH DETAIL @ 4,932’ 10/24/20 Perf Gun 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,565 feet 4350, 4970, 6350 feet true vertical 6,545 feet 5,881 feet Effective Depth measured 4,342 feet 4,855 feet true vertical 4,322 feet 4,835 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 4,301' MD 4,283' TVD Packers and SSSV (type, measured and true vertical depth)DHL Packer 3,580' MD 3,559' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 7,240psi 108' 2,832'5,750psi Collapse 3,090psi 5,410psi Casing Structural 20" 9-5/8" Length 108' 2,851' 6,535' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 302 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-470 286 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 120 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-050 50-283-20136-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 10 Beluga River Unit (BRU) 212-24T N/A ADL0021128 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beluga River / Undefined GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7"6,535'6,516' WINJ WAG 0 Water-Bbl MD 108' 2,851' 0 t Fra O 6. A G L PG , R r: Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:08 am, Jan 19, 2021 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.18 08:48:36 -09'00' Taylor Wellman Perforate SFD 1/26/2021DSR-1/19/21gls 2/1/21 RBDMS HEW 1/27/2021 Plug Perforations Rig Start Date End Date 12/24/20 12/31/20 Ops safety meeting. MU 13' gun + 3' gun with GR/CCL. Open swab RIH. Run Correlation pass 4,200'-3,820' send log to GEO. Position guns Perf 3 at (4,008'-4,021')(13')(CCL to TS -15' 3,993' ) Perf 4 at (3,970-3,973')(3')(CCL to TS -7.5' 3,962.5')POOH. MU guns 5,6,7. Run Correlation pass Send to GEO. Positions guns Perf 5 @ (3,957'-3,9561') (4')(CCL to TS -23.5 3,933.5')Perf 6 (3,872'-3,877')(5') (CCL to TS -15.5 3,856.5') Perf 7 (3,861'-3,864')(3')(CCL to TS -10 3,851') POOH. OOH RD End ticket. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 12/24/2020 - Thursday JSA, PTW, Move AK E-line to location and begin rig up. MU GPT 7" spiral plug. PT lubricator. RIH. Fluid @ 2,270' log up from 4,460'-4,250' . Send correlation log to town to verify depth. Set 7" spiral plug @ 4,360'. Run 20' bailer of bridging material. OOH. Fill cement bailer #1 RIH. Set @ 4,350' dump cement #1 POOH. Mix and fill bailer #2. RIH. Set @ 4,345' dump & POOH. Mix and fill bailer #3. RIH Set @ 4,342' dump and POOH. Rig down, Police area, Stage equipment @ D- pad, turn in JSA, weigh bags and wait for chopper. 12/30/2020 - Wednesday 12/31/2020 - Thursday Arrive at the Hilcorp hanger catch a flight to Beluga. Arrive at location, start equipment, perform JSA, build guns for job. Mobilize to K-pad and rig up. made up CCL with one 4' gun and one 10' gun. PT 250L/3,000H. RIH with gun 1(4,254'- 4,264')(10') & gun 2 (4,219'-4,223')(4'). Run correlation 4,322'-3,800' sent to GOE. Pass 8 pulling into position, Fire guns, POOH. OOH, lay down for the night. _____________________________________________________________________________________ Updated By DMA 01-08-21 SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,342’ TVD = 4,322’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 2 1 3 4 8 6 9 X 5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,932’ 10/24/20 7 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3-1/2" Production String 9.2# L-80 8RD EUE 4,301’ JEWELRY DETAIL ID. Depth MD (ft.) ID (in.) Description 1 1,616 Camco KBMG GLM 2 3,036 3-1/2” PSPOL-M Gas Lift Mandrel 3 3,115 3-1/2” PSPOL-Chemical Injection 4 3,580 DHL Packer 5 3,600 2.813” X-Nipple 6 4,302 WLEG 7 4,360 Spiral Plug w/ 18’ cement (TOC @ 4,342’) 12/24/20 8 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 9 6,350’ Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga D1 3,861' 3,864' 3,842’ 3,845’ 3' 12/31/2020 Open Beluga D1 3,872' 3,877' 3,853’ 3,858’ 5' 12/31/2020 Open Beluga D5 3,957' 3,961' 3,937’ 3,941’ 4' 12/31/2020 Open Beluga D5 3,970' 3,973' 3,950’ 3,953’ 3' 12/31/2020 Open Beluga D6 4,008' 4,021' 3,988’ 4,001’ 13' 12/31/2020 Open Beluga E5 4,219' 4,223' 4,200’ 4,204’ 4' 12/30/2020 Open Beluga E5 4,254' 4,264' 4,234’ 4,244’ 10' 12/30/2020 Open Beluga F1 4,382’ 4,393’ 4,362’ 4,373’ 11’ 7/22/2020 Isolated Beluga F4 4,432’ 4,442’ 4,412’ 4,422’ 10’ 7/21/2020 Isolated Beluga F7 4,696’ 4,719 4,676’ 4,699’ 23’ 7/9/2020 Isolated Beluga F10 4,735’ 4,740’ 4,715’ 4,720’ 4’ 7/9/2020 Isolated Beluga G2 4,864’ 4,871’ 4,844’ 4,851’ 7’ 7/9/2020 Isolated Beluga G3 4,873’ 4,878’ 4,853’ 4,858’ 5’ 7/8/2020 Isolated Beluga G4 4,922’ 4,927’ 4,902’ 4,907’ 5’ 7/8/2020 Isolated Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing FISH DETAIL @ 4,932’ 10/24/20 Perf Gun 4342 ' Spiral Plug w/ 18’ cement (TOC @ 4,342’) 12/24/20 Beluga perfs Beluga D1 3,861' 3,864'3,842’3,845’3'12/31/2020 Open Beluga D1 3,872' 3,877'3,853’3,858’5'12/31/2020 Open Beluga D5 3,957' 3,961'3,937’3,941’4'12/31/2020 Open Beluga D5 3,970' 3,973'3,950’3,953’3'12/31/2020 Open Beluga D6 4,008' 4,021'3,988’4,001’13' 12/31/2020 Open Beluga E5 4,219' 4,223'4,200’4,204’4'12/30/2020 Open Beluga E5 4,254' 4,264'4,234’4,244’10' 12/30/2020 Open Bl D1 3 861'3 864'3 842’3 845’3'12/31/2020 O g ,,,p//, (D1- E5) Be 4995 ' 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: __ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,565'5,881' Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng tkramer@hilcorp.com 6,545'4,970'4,950'1,303 4,970; 6,350' DHL Pkr; N/A 3,580' MD / 3,559' TVD; N/A, N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0021128 210-050 50-283-20136-00-00 Beluga River Unit (BRU) 212-24T Beluga River / Undefined Gas Length Size CO 629 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 TVD Burst 4,301' 7,240psi MD 5,750psi 108' 2,832' 108' 2,851' 6,516'7" 20" 9-5/8" 108' 2,851' 6,535' Perforation Depth MD (ft): See Attached Schematic 6,536' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: November 16, 2020 3-1/2" m n P 66 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:49 am, Nov 04, 2020 320-470 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.03 17:01:25 -09'00' Taylor Wellman DLB 11/04/2020 gls 11/5/20 10-404 Perforate CO 629 was the original spacing exception for this well. DLB Plug Perforations DSR-11/4/2020 GAS X Comm 11/5/2020 dts 11/5/2020 JLC 11/5/2020 RBDMS HEW 11/12/2020 Well Prognosis Well: BRU 212-24T Date: 11/2/2020 Well Name: BRU 212-24T API Number: 50-283-20136-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 11/16/2020 Rig: E-line Reg. Approval Req’d: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 210-050 First Call Engineer: Ted Kramer (907) 777-8420 (O) (907) 865-0665 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) AFE Number Current Bottom Hole Pressure: ~1907 psi @ 4,362’ TVD Max. Expected BHP: ~1687psi @ 3,840’ TVD (Virgin Pressure) Max. Potential Surface Pressure: ~1303 psi (0.1 gas gradient to surface) Brief Well Summary: Originally drilled in 2010 as a single I sand completion. Two I sands were perforated (36' total) and came online making 3 MMCFD. Completed as a single 3-1/2" tbg string to 4892' with a single packer @ 4855' (just below the Bel G sand). The well was on a pretty steep decline, 37% effective annual decline for a solid two years until it was decided to move up hole and complete the H sands - with a fracture stim treatment. The I sand cum'd just over 1.5 BCF, they were isolated and the H sands were perf’s and frac'd thru tbg. A total of 4 zones were frac'd (58' total) with ~75,000 lbs. 20-40 curable resin coated ceramic proppant and gel. The well came online making just under 4 MMCFD then operations have done well to get well just under 5 MMCFD and has sustained a flat rate of just over 3MMCFD for the past few years. The H sands have cum'd 6 BCF to date. During most of 2019 the well had been struggling to flow smoothly without holding back pressure and then fell from 3.0 MMCFD to about 2.0 MMCFD and then completely died in December 2019. In July 2020, a workover was completed moving the packer and tbg up-hole enable to access the rest of the intervals. 7 of the Beluga G and F sands were perf’d thru the month of July bringing on about 500 mcfd rate but also sand and water production – eventually sanding up entirely and dying off. On 10/24/2020 a slick line tag was made to 4,932’ with a 2.50” bailer. Procedure Summary: The objective of this work is to set a plug at ±4,350’ MD to isolate the Beluga G and F sands and perforate Beluga E and D sands thru tubing. E-line / Slickline Procedure: 1. MIRU slickline/ E-line Combo unit. PT lubricator to 250 psi low / 2500 psi high. 2. RIH with GPT Tool and determine Fluid level. 3. PU drift for 2” guns. Drift to 4,200’. If unable to drift to ~4200’ contact Operations Engineer. E-Line Procedure: 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low / 2500 psi high. 2. Depending on fluid level, Nitrogen may be needed. If so RU nitrogen unit and pressure test lines. 3. RIH with GPT and spiral plug setting assembly to 4,350’ (+/-). 4. Pressure up on well with N2 (if needed) and push fluid away below plug set depth. 5. Set Plug @ 4,360’ (+/-) and dump 10’ of cement on top of plug (Est. TOC = 4,350’). 6. Perforate the below sands : . In July 2020, a workover was completed moving the packer and tbg up-hole enable to access the rest of the intervals. On 10/24/2020 a slick line tag was made to 4,932’ with a 2.50” bailer. isolation plug at 4360 ft No fill over perfs? Well Prognosis Well: BRU 212-24T Date: 11/2/2020 Sand Top, MD ft Bottom, MD ft Total ftg, MD Beluga D1 ±3,861' ±3,864' 3' Beluga D1 ±3,872' ±3,877' 5' Beluga D5 ±3,957' ±3,961' 4' Beluga D5 ±3,970' ±3,973' 3' Beluga D6 ±4,008' ±4,021' 13' Beluga E5 ±4,219' ±4,223' 4' Beluga E5 ±4,254' ±4,264' 10' a. Proposed perfs also shown on the proposed schematic in red font. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. Use Gamma/CCL to correlate. d. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Beluga River Unit falls under the Beluga River undefined Gas Pool. The Conservation Order governing this well is for a spacing exception for this well - BRU 212-24T and is CO 629. 1. POOH. RD E-line. 2. Turn Well over to Production. E-line Procedure (Contingency): 1. If any zone produces sand and/or water or needs isolated 2. MIRU E-line, PT lubricator to 2,000 psi Hi 250 Low. 3. RIH and set a through tubing plug at depth above zone. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Nitrogen Standard Beluga D1 ±3,861' ±3,864' 3' Beluga D1 ±3,872' ±3,877' 5' Beluga D5 ±3,957' ±3,961' 4' Beluga D5 ±3,970' ±3,973' 3' Beluga D6 ±4,008' ±4,021' 13' Beluga E5 ±4,219' ±4,223' 4' Beluga E5 ±4,254' ±4,264' 10' _____________________________________________________________________________________ Updated By DMA 11-02-20 SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,970’ TVD = 4,950’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 2 1 3 4 7 6 8 X 5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,932’ 10/24/20 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3-1/2" Production String 9.2# L-80 8RD EUE 4,301’ JEWELRY DETAIL ID. Depth MD (ft.) ID (in.) Description 1 1,616 Camco KBMG GLM 2 3,036 3-1/2” PSPOL-M Gas Lift Mandrel 3 3,115 3-1/2” PSPOL-Chemical Injection 4 3,580 DHL Packer 5 3,600 2.813” X-Nipple 6 4,302 WLEG 7 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 8 6,350’ Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga F1 4,382’ 4,393’ 4,362’ 4,373’ 11’ 7/22/2020 Open Beluga F4 4,432’ 4,442’ 4,412’ 4,422’ 10’ 7/21/2020 Open Beluga F7 4,696’ 4,719 4,676’ 4,699’ 23’ 7/9/2020 Open Beluga F10 4,735’ 4,740’ 4,715’ 4,720’ 4’ 7/9/2020 Open Beluga G2 4,864’ 4,871’ 4,844’ 4,851’ 7’ 7/9/2020 Open Beluga G3 4,873’ 4,878’ 4,853’ 4,858’ 5’ 7/8/2020 Open Beluga G4 4,922’ 4,927’ 4,902’ 4,907’ 5’ 7/8/2020 Open Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing FISH DETAIL @ 4,932’ 10/24/20 Perf Gun _____________________________________________________________________________________ Updated By DMA 11-02-20 PROPOSED SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,970’ TVD = 4,950’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 2 1 3 4 7 6 8 X 5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,932’ 10/24/20 6A CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3-1/2" Production String 9.2# L-80 8RD EUE 4,301’ JEWELRY DETAIL ID. Depth MD (ft.) ID (in.) Description 1 1,616 Camco KBMG GLM 2 3,036 3-1/2” PSPOL-M Gas Lift Mandrel 3 3,115 3-1/2” PSPOL-Chemical Injection 4 3,580 DHL Packer 5 3,600 2.813” X-Nipple 6 4,302 WLEG 6A ±4,350 Plug w/ ~10’ cement 7 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 8 6,350’ Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga D1 ±3,861' ±3,864' ±3,842’ ±3,845’ 3' Proposed TBD Beluga D1 ±3,872' ±3,877' ±3,853’ ±3,858’ 5' Proposed TBD Beluga D5 ±3,957' ±3,961' ±3,937’ ±3,941’ 4' Proposed TBD Beluga D5 ±3,970' ±3,973' ±3,950’ ±3,953’ 3' Proposed TBD Beluga D6 ±4,008' ±4,021' ±3,988’ ±4,001’ 13' Proposed TBD Beluga E5 ±4,219' ±4,223' ±4,200’ ±4,204’ 4' Proposed TBD Beluga E5 ±4,254' ±4,264' ±4,234’ ±4,244’ 10' Proposed TBD Beluga F1 4,382’ 4,393’ 4,362’ 4,373’ 11’ 7/22/2020 Isolated Beluga F4 4,432’ 4,442’ 4,412’ 4,422’ 10’ 7/21/2020 Isolated Beluga F7 4,696’ 4,719 4,676’ 4,699’ 23’ 7/9/2020 Isolated Beluga F10 4,735’ 4,740’ 4,715’ 4,720’ 4’ 7/9/2020 Isolated Beluga G2 4,864’ 4,871’ 4,844’ 4,851’ 7’ 7/9/2020 Isolated Beluga G3 4,873’ 4,878’ 4,853’ 4,858’ 5’ 7/8/2020 Isolated Beluga G4 4,922’ 4,927’ 4,902’ 4,907’ 5’ 7/8/2020 Isolated Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing FISH DETAIL @ 4,932’ 10/24/20 Perf Gun STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other:Perm Slv, Iso SSSV, New Completion Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,565 feet 6,350 feet true vertical 6,545 feet 5,881 feet Effective Depth measured 6,350 feet 4,855 feet true vertical 6,350 feet 4,835 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 4,301' MD 4,283' TVD Packers and SSSV (type, measured and true vertical depth) DHL Packer 3,580' MD 3,559' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 108' 2,851' 0 Oil-Bbl measured true vertical Packer 7" 6,535' 6,516' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beluga River / Undefined GasN/A measured TVD Tubing Pressure 10 Beluga River Unit (BRU) 212-24T N/A ADL0021128 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-050 50-283-20136-00-00 4. Well Class Before Work: 5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-055 & 320-227 286 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 120 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 302 0 Representative Daily Average Production or Injection Data 108' 2,851' 6,535' Conductor Surface Intermediate Production 5,410psi Casing Structural 20" 9-7/8" Length 5,750psi Collapse 3,090psi tkramer@hilcorp.com Senior Engineer: Senior Res. Engineer: Burst 7,240psi 108' 2,832' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:57 pm, Aug 21, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.21 13:36:48 -08'00' Taylor Wellman DSR-8/21/2020 RBDMS HEW 8/24/2020 SFD 8/28/2020 SFD 8/28/2020 gls 9/17/20 Perm Slv, Iso SSSV, New Completion Rig Start Date End Date 2/3/20 6/8/20 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 02/03/2020 - Monday 8:00 ARRIVE AT POLLARD SHOP GATHER TOOLS AND CREW 9:00 ARRIVE AT AIRPORT, STAND BY FOR WEATHER 15:30 DEPART FROM AIRPORT, LAND IN BELUGA, PERMIT,JSA, GO OVER JOB SCOPE 16:45 RIG UP .125 S/L 20:05 RIH W/ 3 1/2 GS TO 495'KB W/T POOH W/ LOCK AND DONGLE 20:30 BEGIN LAYING DOWN LUB 21:00 DEPART FROM LOCATION, END TICKET 02/04/2020 - Tuesday 5:30 MORNING MEETING, JSA, PERMIT 6:20 ARRIVE ON LOCATION, P/U LUB 7:45 P.T. LUB TO 2000 PSI, TEST GOOD 8:40 RIH W/ 3 1/2 SLB SSSV LOCK OUT TOOL TO 495'KB, TAP DOWN NO-GOS OUT, FILL TUBING W/ TRIPLEX, PUMP 15BBLS TUBING NOT PRESSURING UP, POOH, LOCK OUT TOOL ONLY HALF WAY ACTUATED, RESET TOOL, ADD 5' OF 2.25'' STEM 10:35 RIH W/ SAME TO 495'KB SIT DOWN , PUMP UP SSSV, STAND BY FOR WATER;12:00 START PUMPING,PRESSURE TUBING TO 950 PSI, HIT DOWN, TUBING BLLEDS TO 200 PSI, PULL UP WAIT FOR FLUID TO BYPASS TOOL, COMES FREE POOH - L/O TOOL FULLY ACTUATED 13:30 RIH W/ SCRATHER W/ BRASS PINS ON 4' STEM W/ 2.84'' CENT. TO 495'KB W/T POOH - PINS NOT SHEARED 14:10 RIH W/ 2.5'' x 5' DD BAILER TO 4765'KB W/T 4785'KB POOH - FULL OF CLAY LIKE MUD 15:25 RIH W/ SAME 4787'KB W/T 4800'KB POOH - 1/4 FU;16:30 RIH W/ SAME TO 4800'KB W/T 4809'KB POOH - 1/4 FULL SAME 02/05/2020 - Wednesday 5:30 MORNING MEETING, JSA, PERMIT 6:15 CHECK AND START EQUIPMENT, P/U LUB, P.T TO 1500 PSI TEST GOOD 7:20 RIH W/ 2.80'' GRING TO 4797'KB W/T POOH 8:10 RIH W/ 2.5'' x 5' DD BAILER TO 4797'KB W/T 4801'KB POOH - EMPTY 9:05 RIH W/ 1.75'' x 4' DD BAILER W/ 3' STEM TO 4800'KB W/T POOH - SMALL AMOUNT OF SAND 10:05 RIH W/ 1' SPEAR W/ 3' STEM TO 4800'KB W/T POOH 10:45 RIH W/ 1.75'' x 4' DD BAILER 4800'KB W/T TO 4802;11:55 RIH W/ 1' SPEAR ON 3' STEM TO 4802'KB W/T 4804'KB POOH 12:40 RIH W/ 1.75'' x 4' DD BAILERW/ 3' STEM TO 4802'KB W/T 4804'KB POOH - SMALL MUD PLUG IN BTM 13:50 RIH W/ 8' x 2.25'' PUMP BAILER TO 4802'KB W/T 4803'KB POOH - EMPTY TAKE OIL JARS OFF, SLIP AND CUT 20' WIRE, RETIE ROPE SOCKET 15:50 RIH W/ 3 1/2 SWAB MANDREL & CUPS, SEE SWAB REPORT 16:55 LAY DOWN LUB 17:30 ARRIVE AT CAMP END TICKET Rig Start Date End Date 2/3/20 6/8/20 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 02/10/2020 - Monday Swab. 02/09/2020 - Sunday 5:30 MORNING MEETING, JSA, PERMIT 6:30 CUT 70' WIRE, PULL TREE CAP, P/U LUB 8:45 RIH W/ 2 MANDRELS AND CUPS - SEE SWAB REPORT 17:00 LAY DOWN LUB, SECURE WELL 02/06/2020 - Thursday 02/08/2020 -Saturday Bail/Swab 5:30 MORNING MEETING, JSA, PERMIT 6:30 STAND UP LUB, RIG UP 2'' HOSE TO TREE, SEE SWAB REPORT 9:30 ADD SECOND MANDREL SPLIT W/ 5' STEM 11:40 RIH W/ 2.11 GRING TO FIX WRAPS ON DRUM, TAG 4802'KB POOH 12:15 RIH W/ MANDREL AND CUPS 15:30 LAY DOWN TOOLS, CUT 100' WIRE, RETIE ROPE SOCKET 16:10 RIH W/ MANDREL AND CUPS 16:55 LAY DOWN LUB, SECURE WELL, 17:30 ARRIVE AT CAMP 02/07/2020 - Friday 5:30 MORNING MEETING, JSA, PERMIT 6:30 PULL TREE CAP, C/O STEM TO 1.75'', PICK UP LUB 7:45 RIH W/ MANDREL AND CUPS, SEE SWAB REPORT 14:15 LAY DOWN TOOLS STRING, CUT WIRE, RETIE ROPE SOCKET 14:40 RIH W/ MANDRELS AND CUPS 15:50 RIH W/ 1.75 x 4' DD BAILER TO 4803'KB W/T POOH - 3'' PLUG OF CLAY/MUD 16:40 RIG DOWN, MOVE OVER TO BRU 244-23 17:30 ARRIVE AT CAMP Rig Start Date End Date 2/3/20 6/8/20 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 06/08/2020 - Monday Met with Reservoir Engineer and Geologist. Made decision to move up hole with a Rig Work over to Upper Beluga and Sterling. 5:30 Morning Safet meeting, talk w/ company rep, sign permits. 6:30 Start up equipment, have to jump crane and unit. Cut and test wire/ re-head. 8:00 Rih w/ 2.25 Pump Bailer to 4803' kb, w/t pooh slow. Ooh empty. 9:00 Rih w/ 1.6 " Starbit to 4803' kb, w/t pooh. 9:50 Ooh w/ tools, purge weight pod. 10:20 Go down to welding shop and grind down Centrilizer. 10:50 Rih w/ 2.79 Cent w/ 1 3/4 DD Bailer to 4806' kb, w/t 4807' kb,;11:45 Rih w/ same to 4808' kb w/t pooh. Ooh w/ 1" hard packed mud. 12:30 Rih w/ same to 4807' KB W/T pooh. OOH empty. 13:15 Rih w/ 2.79 Cent, 1.6 Starbit to 4807' kb, w/t pooh. 14:00 Ooh w/ tools, begin rigging down. 15:15 Done rigging down, park equipment. 18:15 Flight Home 19:00 ETA PWL. 06/04/2020 - Thursday PT lubricator low/high. RIH and tag obstruction at 4,802'. Set down a couple times to verify. POOH. RDMO 02/12/2020 - Wednesday 5:30 MORNING MEETING, JSA, PERMIT 6:30 GRAB HOSE FROM J-PAD, RIG UP 8:30 P/U LUB 8:45 RIH W/ 1.75 x 4' DD BAILER TO 4803'KB W/T POOH - 1/3 FULL CLAY/MUD 9:30 REMOVE OIL JARS, CREW C/O 11:05 Rih w/ 1.75 DD Bailer to 4804' kb, w/t pooh. Ooh 1/3 full clay. 12:20 Rih w/ 2 1/2 DD Bailer to 4805' kb, w/t pooh, ooh w/ 6" of clay/ beluga mud. 13:00 Rih w/ same to 4805' kb, w/t pooh. Ooh empty.;13:40 Rih w/ 1 3/4 DD Bailer to 4805' kb, w/t pooh. Ooh empty. 14:30 Ooh w/ tools, add 5' stem. 14:45 Rih w/ 1" Spear/ Digging tool to 4805' kb, w/t pooh. 15:20 Add KJ below spangs, Rih w/ 2.5 DD Bailer to 4805' kb, w/t pooh. Ooh empty. 16:05 Rih w/ 2.49 LIB to 4805' kb, w/t pooh, ooh no marks. 16:40 Lay down lub, secure well for the night. 17:00 End ticket. 02/13/2020 - Thursday start 320-227 (RWO) End sundry 320-055 operations. Rig Start Date End Date 6/20/20 7/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 06/23/2020 - Tuesday JSA & PTW Backup GR/CCL arrived on plane. On location and MU spiral plug. RIH with spiral plug and tag high at 4,995'. Desired plug set depth of 5,100'. Confirm with town engineer and set plug at 4,995'. POOH. Dump bail 25' of cement on top of plug. Estimated TOC ~ 4,970'. R/D Unit Move off well Blade pad, spread gravel level f/ rig. Swap Rig AFE f/ 212- 35T, mark out rig foot print, lay felt, liner and matting boards prep to spot in pony walls and sub base. 06/20/2020 - Saturday 06/22/2020 - Monday E-line crew arrived in Beluga, checked out equipment. No grease head/flow tubes with equipment in Beluga. Call out for equipment to get flown over on next otter. Equipment arrives and start to RU. MIRU. MU 7" spriral plug toolstring. PT lubricator to 250/3,000 psi. RIH with spiral plug. GR/CCL not working properly. GR counts are extreme range and cannot be repeated on overlay pass. POOH. No backup GR/CCL on location. Laydown toolstring for the evening. Arrive in Beluga. Review JSA and PTW. MIRU coiled tubing equipment. BOPE test. Low 250 psi / high 4,000 psi. AOGCC waived witness of BOP test per Jim Regg. MU BOPs on top of well. Load batchmixer with water. Shut down for the evening. 06/21/2020 - Sunday Review JSA and sign PTS MU slim 1.75" BHA. Dual checks, stingers, down jet nozzle. PT low to 300 psi, high to 2,500 psi. RIH and tag at 4,808' ctmd. PU and re-tag to confirm. Unable to get past. Start down jetting with water, break through and RIH to 4,827'. Cool down N2 unit to pump foam to clean any other solids in tubing/casing. Pump N2 @ 700 scf/m and water/gel at 0.6 bpm. RIH jetting, take bites, clean out to 5,165' ctmd. POOH, stop pumping gel and pump only N2 to blowdown reel and tubing to N2. Coil at surface, shut in well with 977 psi. Rig down equipment and stage at pad. 06/24/2020 - Wednesday Remove SSV from tree and install blind for substructure clearance /crane in sub and center over well and shim for level / crane in draw works skid and pin same / R/up hyd / crane in Mast and pin same set all modules and begin running elect, hyd, equalizers lines and mud pump bleeders and pop-offs and install stairs and walk ways Crane in choke house / lay felt liner for cat walk / crane in pipe skate / raise and pin derrick wind walls / Crane in IR and rig floor wind wall / raise beaver slide / raise gas buster and hook up same / r/up choke lines / r/up TDS hyd line to carrier / spool drill line on drum / Prep to scope up derrick / hook up weight indicator continue install starting heads on H& F pads Scope Derrick, prep and P/U top drive, continue hooking up interconnects, working on rig acceptance checklist, hook up top drive hydraulic lines and service loop, begin bleeding off annulus 200 psi initial pressure, bleed down to 20 psi, swap to the tubing side initial pressure 850 psi bleed down to 160 psi continue working on rig acceptance check list, roll both mud pumps through bleeders, function test top drive. BOPE test. Low 250 psi / high 4,000 psi. AOGCC waived witness of BOP test per Jim Regg. MU BOPs on top of well. MIRU rig 169 Desired plug set depth of 5,100'. plug. RIH with spiral plug and tag high at 4,995' Rig Start Date End Date 6/20/20 7/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 06/25/2020 - Thursday Continue Bleed tbg and annulus / Continue work rig acceptance chk list chg out floor motor engine kill / test mud lines t/ 3,000 psi / r/up to circ Pump and bleed 47.7 bbls fresh water dn tbg / finish install of starting heads and test same / two heads failed / weld repair and re-test OK Chg out pressure Regulator on dwks / pump one bbl fresh water dn 3/8" chemical line w/ test pump flush line / Install BPV / remove tree / Crane in stack and removing single gate / trolley in stack and nip/up 11" 5k annular, double gate and mud cross / hook up choke and kill hoses / install flow box, flow nipple and flow line / hook up Koomey lines R/U to test BOP's, Flood stack and lines with water, M/U test jt, Attempt Shell test on components leaking, retest on small sysytem still leaking, trace back to blanking plug, R/D test equipment pull blanking plug and change BPV w/ TWC reinstall blanking plug, shell test small system good test, purge air from remaining sysyem. Test BOPS as per regulations w/ 3.5'' and 4.5'' Test jts t/ 250/3,000 psi on all components test annular t/ 250/2,500 psi, Witness was waived by Jim Regg 1 Fail Pass had to grease the inside manual the choke retest good, perform drawdown test. R/D Test Equipment, blow down lines. Torque up Landing Jt, Pull TWC, M/U landing Jt, BOLDS, Pull hanger off seat w/ 75k Hook Load 65k String Weight, Pull up to 80k Hook Load and set slips, R/U Eline. 06/26/2020 - Friday Continue R/up E-line and Build and space out slips of 2" radial torch tool string Rih t/ 4,937' wlm log jewelry and Tie in apply 400 psi t/ tbg and fire cutter and sever prk mandrel @ 4,859.5' wlm (felt cut but no pressure loss, but bled off slowly) pick up t/ 75k w/ 2' travel and lost 17k weight while being static / attempt to brk/circ but kept pressuring up / pull hanger to rig floor w/ 61k traveling weight well out balance flowing on tbg and gained 12 bbls w/ no fluid in sight on back side and unable to pump even with a crippled pump / work pipe let well balance L/dn hanger, pups, two jts of 4- 1/2" tbg, XO and rack back 5 std 3-1/2" tbg while spooling up 3/8" chemical & 1/4" control line establish circ and balance fluid, circulate surface to surface 0 psi observe slight gas on bottoms up Continue POOH w/ 3.5'' Tubing f/ 4,446' t/ 639' Change out spool on control line spooler, spool breaking from weight of control line. Continue POOH w/ 3.5'' Tubing standing back in the derrick, L/D Jewelry and removing cannon clamps f/ 639' t/ surface Clean and clear floor strap drift and tally clean out assy. RIH w/ clean out assembly on 3.5'' DP, 6'' Bit, bit sub, scrapper and cross over, t/ 1,350'. 06/27/2020 - Saturday Continue RIH w/ BHA #1 on 3.5'' TBG out of derrick ,clean out assembly 6'' Bit, bit sub, scrapper and cross over f/ 1,350 t/ 2,641' Service rig while circ btm/up Continue rih w/ 3-1/2" TBG out derrick t/ 4,674' Circ btm/ups @ @ 180 gpm @ 178 psi w/ max gas of 964 units P/up 3-1/2" tbg off walk Rabbiting and strapping same f/ 4,674' t/ 5,142' (E.T.O.C @ 4,980' ) discuss depth w/ town continue RIH and tag w/ 10k @ 5,160' (27' above perfs ) Circ btm btm up w/ some cmt in returns and dump same and w/ high gas of 3,195 units / Mointor well static Pooh l/dn excess 3-1/2" Tbg and rack back +- 4,200', L/D Bit and scraper, clear floor R/U Eline to dump bail remaining 17 gallons of cement, RIH tag up @ 5,144.7' WLM, dump bailer POOH, load second bailer and RIH, dump second bailer load, POOH, R/D ELine CIP 2,300 hrs R/U and run 3.5'' Completion as per detail, running 1/4'' control line and installing cannon clamps every other jt, @ 3,519'. RIH w/ clean out assembly on 3.5'' DP, Test BOPS as per regulations w/ 3.5'' and 4.5'' Test jts t/ 250/3,000 psi o fire cutter and sever prk mandrel @ 4,859.5' Continue Bleed tbg and annulus / Continue RIH w/ BHA #1 on 3.5'' TBG out of derrick , Rig Start Date End Date 6/20/20 7/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 06/28/2020 - Sunday Continue run 3.5'' Completion as per detail, running 1/4'' control line and installing cannon clamps every other jt, f/ 3,519' t/ 4,281' w/ calculated displacement. P/up m/up hanger and dress same w/ 1/4" continuous control line / P/up landing jut land hanger W/ re-entry guide @ 4,301.89' up/dn/wt 45/44k / RILDS (ran total 50 cannon clamps w/ two 1/2" SS bands on CIM ). R/up slick line rih #1 bar and ball set in "X" nipple @ 3,600' and pack-off line / Pump dn tbg and stage up as per Weathford hand 1,500psi 10 min, 2,500psi 10min, and 3,500psi 5 min (seen small shift @ 2,400 psi) bleed off pressure. Pooh w/ slick line and recover bar and ball / Attempt pressure up on back side had flow on tbg / discussed issue and found that old GLM had orfacie / cleaning mud pits and organization in prep for move while gathering kick over tool and dummy valve. M/up kick-over tool, rih and locate glm @ 1,616'. Latch and pull valve, pooh and recover same / Re-pin tool and load dummy valve rih. Locate GLM and set dummy valve in Top Glm @ 1,616', pooh, valve set. Test Csg/ Prk t/ 2,160 psi w/ 34.5 gals on chart for 30 min. Good. Rih, latch plug body in "X" nipple @ 3,600', pooh and recover same. R/dn Slick line / Pull landing jt and set BPV N/D riser and flow box, pull flow line, N/D BOP Stack and trolly out, crane out to BOP Craddle, N/U adaptor and tree, test void t/ 250/5,000 psi f/ 10 min. Pull BPV and set TWC, Test tree t/ 250/5,000 psi f/ 5 min no leaks, secure wellhead. R/D rig modules. R/D top drive and Lay down and prep derrick to scope down. R/D Pit and pump modules. R/D top drive house. R/D Gas buster and Lay over Scope down derrick. Prep to lay over derrick, continue rigging down modules and prepping for trucks, lay over pit roofs, disconnect mud lines, pull electric lines. R/D grasshopper, lay over derrick and un pin unspool draw works, prep to lower dog house into water tank, Continue prepping for trucks to move complexes. 06/29/2020 - Monday Trucks and cranes on location for same pad rig move/ scatter rig modules and remove needed mats / lay felt liner set rig mats / crane off choke house , derrick and dwk skid continue remove and set mats as they come available (Mats set in smallest configuration (14 total 8' wide mats deep and two wide). Set sub pony beams and HPU / spot and crane in sub and center over hole and shim for level / crane in and pin DWK skid / Crane in and pin derrick / set combo building / continue assist production w/ super sucker/ spot in remaining rig components for back yard and pits, raise derrick. Hook up interconnects and pull electrical lines, prep to scope derrick, continue hooking up interconnects to all modules, raise dog house from water tank, hook up mud lines, R/U torque tube, scope up derrick, R/U and P/U top drive, work on rig acceptance checklist. Shut down all gens, continue hooking up interconnects and equipment without power, waiting on air permits. 06/30/2020 - Tuesday Cont waiting on air quality control permit, dressed mud pumps to 5-1/2", installed Handy Berm around rig footprint, took on rig fuel and water. Received air permit at 13:00 hrs, installed Kelly hose and service loop on topdrive, cont RU rig floor, SLB coil unit on location, discussed their RU footprint to allow us to RU diverter vent line etc. Notified service Rep’s on coming out tomorrow for RU and prep to spud. Pinned topdrive to torque bushing, installed new saver sub, function tested iron roughneck, tied in gen #3 and ran same on line, flooded both mud pumps and test ran same, tested centrifugal pumps with water, prep to test mudline, standpipe and Kelly hose connections. Swapped to BRU 222-24 AFE at 18:00 hrs. l / Attempt pressure up on back side had flow on tbg / discussed load dummy valve rih. Locate GLM and set dummy valve in Top Glm @ 1,616', Test Csg/ Prk t/ 2,160 psi w/ 34.5 gals on chart for 30 min. G Rig Start Date End Date 6/20/20 7/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 07/01/2020 - Wednesday R/U coil eq. spot tanks & test pump. Test BOPE as per Hilcorp & AOGCC requirements, Witness was waived by AOGCC rep Jim Regg @09:52 6-3-2020, Tested 1.75" coil, 250/4,000 good. Install BOPE on tree, install coil connector, install blind flange on wing valve on tree, pull test coil connector 15k good. Fuel Eq. secure well, inventory YJ tools & prep for loadout. SDFN. 07/02/2020 - Thursday Stack up injector & lubricator, M/U MHA, stab onto well, P/T t/250/4,000 good RIH w/coil, start cooling down n2, tag @ 5,137', PT n2 lines t/3100psi, pressure up well t/1000psi hold for 10 min, RIH tag plug @ 5,137', good, open choke & bring N2 pump on line @ 500SCF taking returns into blow down tank, pulled off 87 bbls from return tank, increased rate & made 2 short trips to tubing tail and cont. pumping OOH, shut in annulus when we were @ 1600' and cont. pressuring up t/1660psi while POOH, tagged up in lub. shut in well & bled down coil. SITP 1660, SIAP 138 R/D coil unit, secured well, Prepped eq. for barge transport, m/o pad. 07/08/2020 - Wednesday MIRU e-line, P/U 5' gun 2-3/8" 5 SPF, 60 Deg Phasing, , wt bar, Gr, CCl, , m/u lubricator, PT 250/3,000 good. RIH tag @ 5,130', Log up t/4,600', send log to Engineering in town to verify correlation, good, pull gun into position to perforate 4,922'-4,927', fire same, good indication gun fired, tubing pressure prior to shooting 1,541psi, after 5 min 1,538 psi, 10 min 1,534psi, 15 min 1,525 psi. POOH, all shots fired E-line having intermitant issues with crane, l/d tools, change out crane, P/U 5' gun 2-3/8" 5 SPF, 60 Deg Phasing, RIH t/ 5,000', log up correlation pass t/4,600', send log to Engineering in town to verify correlation, good, pull gun into position to perforate 4,873'-4,878', fire same, good indication gun fired, tubing pressure prior to shooting 1,386psi, after 5 min 1,378 psi, 10 min 1,365psi, 15 min 1,356psi. POOH, all shots fired, L/D tools secure well for night. 07/09/2020 - Thursday P/U 7' gun 2-3/8" 5 SPF, 60 Deg Phasing, RIH t/ 5,000', log up correlation pass t/4,600', send log to Engineering in town to verify correlation, good, pull gun into position to perforate 4,864'-4,871', fire same, good indication gun fired, tubing pressure prior to shooting 823psi, after 5 min 819 psi, 10 min 815psi, 15 min 812psi. POOH, all shots fired, dry & clean. P/U 5' gun 2-3/8" 5 SPF, 60 Deg Phasing, RIH t/ 5,000', log up correlation pass t/4600', send log to Engineering in town to verify correlation, good, pull gun into position to perforate 4,735'-4,740', fire same, good indication gun fired, tubing pressure prior to shooting 770 psi, after 5 min 770 psi, 10 min 768psi, 15 min 766psi. POOH, all shots fired, dry clean P/U 23' gun assy. 2-3/8" 5 SPF, 60 Deg Phasing, RIH t/ 5,000', log up correlation pass t/4,600', send log to Engineering in town to verify correlation, good, pull gun into position to perforate 4,696'-4,719', fire same, good indication gun fired, tubing pressure prior to shooting 751 psi, after 5 min 769 psi, 10 min 775psi, 15 min 782psi. POOH, all shots fired, wet cap & sand on guns RDMO secure well. d RIH w/coil, start cooling down n2, tag @ pressure up well t/1000psi hold for 10 min, 4,922'-4,927', o perforate 4,696'-4,719', displace to N2 with CTU CTU o perforate 4,735'-4,740', o perforate 4,873'-4,878', f Rig Start Date End Date 6/20/20 7/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 212-24T 50-283-20136-00-00 210-050 Slickline personnel and equipment arrived in Beluga. Review and sign permit. MIRU. PT lubricator to 250 psi low / 3,000 psi high. MU 2.5" blind box, spangs, oil jars, KJ, wt stem and rope socket. RIH and tag top of perf gun at 4,289' SLMD. Jar perf gun assembly downhole. MU and RIH with 2.73" gauge ring to 4,400' SLMD. Did not encounter any tight spots. POOH and RD SL. Wait on 2" guns to arrive from Kenai. Once guns arrived, RU 9' gun assembly. Finish rigging up and PT lubricator to 250 psi low and 2,500 psi high. RIH with 2" XLS Razor x-low swell, 6.5 grams HMX, 6 spf, 60 deg phasing guns. Correlate to OH log and send data to town engineers to confirm on depth. Perforate from 4,384 - 4,393' with well shut in. Initial pressure prior to perforating = 325 psi. Just after perforating = 352 psi. 5 min = 776 psi. 10 min = 1,055 psi. 15 min 1,166 psi. POOH. POOH with perf guns. Confirmed shots fired. Guns came back wet and sandy. RDMO. 07/21/2020 - Tuesday AK E-line arrive in Beluga with perf guns. Review and approve permit. MIRU. Pressure test lubricator to 250 psi low / 3,000 psi high. RIH with drift using spent 2-3/8" perf gun. Drift to 4,515', did not tag, did not encounter any issues at restrictions. POOH with drift. MU Gun #1. 2-3/8" Geo Razor, 5 spf, 60 deg phasing, 11 gram charges and 10' long from top to bottom shot. RIH and correlate to OH log, send data to engineers and confirm on depth. Place shots on depth and perforate 4,432' - 4,442' with well flowing. Initial pressure before perforating = 162 psi. After perforating pressure = 164 psi. 5 minute pressure = 163 psi. While POOH with perf gun #1, gun stuck in tubing tail. Calculations indicate 4' of gun below tubing tail. Shut in well and pump diesel down tubing to try and dislodge. Work gun uphole ~ 15', then could not longer move. Broke weak point and pulled out of rope socket. POOH. Verify cable broke at weak point at surface. Laydown equipment for night. Fish in well. Top of fish ~ 4,262'. 07/22/2020 - Wednesday Perforate from 4,384 - 4,393' perforate 4,432' - 4,442' with well flowing. _____________________________________________________________________________________ Updated By DMA 08-13-20 SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 4,970’ TVD = 4,950’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 RA Tag @ 3,008.14’ RA Tag @ 3,506.84’ RA Tag @ 4,819.67’ 2 1 3 4 7 6 8 X 5 F1-F4 F7-F10 G2-G4 Top of Fish @ 4,262’ 7/21/20 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3-1/2" Production String 9.2# L-80 8RD EUE 4,301’ JEWELRY DETAIL ID. Depth MD (ft.) ID (in.) Description 1 1,616 Camco KBMG GLM 2 3,036 3-1/2” PSPOL-M Gas Lift Mandrel 3 3,115 3-1/2” PSPOL-Chemical Injection 4 3,580 DHL Packer 5 3,600 2.813” X-Nipple 6 4,302 WLEG 7 4,995 Tubing Plug w/ 25’ cement (TOC @ 4,970’) 6/23/20 8 6,350’ Halliburton EZ Drill Bridge plug 7/3/2010 PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga F1 4,382’ 4,393’ 4,362’ 4,373’ 11’ 7/22/2020 Open Beluga F4 4,432’ 4,442’ 4,412’ 4,422’ 10’ 7/21/2020 Open Beluga F7 4,696’ 4,719 4,676’ 4,699’ 23’ 7/9/2020 Open Beluga F10 4,735’ 4,740’ 4,715’ 4,720’ 4’ 7/9/2020 Open Beluga G2 4,864’ 4,871’ 4,844’ 4,851’ 7’ 7/9/2020 Open Beluga G3 4,873’ 4,878’ 4,853’ 4,858’ 5’ 7/8/2020 Open Beluga G4 4,922’ 4,927’ 4,902’ 4,907’ 5’ 7/8/2020 Open Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing Beluga F1 4,382’ 4,393’4,362’4,373’11’ 7/22/2020 Open Beluga F4 4,432’ 4,442’4,412’4,422’10’7/21/2020 Open Beluga F7 4,696’ 4,719 4,676’4,699’23’7/9/2020 Open Beluga F10 4,735’ 4,740’4,715’4,720’4’ 7/9/2020 Open Beluga G2 4,864’ 4,871’4,844’4,851’7’ 7/9/2020 Open Beluga G3 4,873’ 4,878’4,853’4,858’5’ 7/8/2020 Open Beluga G4 4,922’ 4,927’4,902’4,907’5’ 7/8/2020 Openg,,,,p// 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: __New Completion 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,565'6,350' Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng tkramer@hilcorp.com 6,545'6,350'6,330'~1,654psi 6,000' Camco TRMAXX-5E SSSV; Baker Premier Pkr 494' MD/TVDl; 4,855' MD/4,835' TVD Perforation Depth TVD (ft):Tubing Size: 4-1/2" COMMISSION USE ONLY Authorized Name: Tubing Grade: 12.6# / L-80 Tubing MD (ft): 83' See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0021128 210-050 50-283-20136-00-00 Beluga River Unit (BRU) 212-24T Beluga River / Undefined Gas Length Size State Wide Spacing Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 TVD Burst 4,892' 7,240psi MD 5,750psi 108' 2,832' 108' 2,851' 6,516'7" 20" 9-7/8" 108' 2,851' 6,535' Perforation Depth MD (ft): See Attached Schematic 6,536' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: June 20, 2020 3-1/2" m n P 66 t n Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:11 am, Jun 02, 2020 320-227 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.01 16:37:58 -08'00' Taylor Wellman 10-404 Plug Perforations Beluga and Sterling cannot be open at the same time without prior downhole commingling authorization. *3000 psi BOPE test (2500 psi annular) Pull Tubing X Rig 169 DLB 6/2/2020 gls 6/3/20 DSR-6/2/2020 Perforate GAS Perforate New Pool P X Comm. 6/4/2020 dts 6/4/2020 JLC 6/4/2020 RBDMS HEW 6/9/2020 Well Prognosis Well: BRU 212-24T Date: 6/1/20 Well Name: BRU 212-24T API Number: 50-283-20136-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 6/20/20 Rig: 169 Reg. Approval Req’d? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 210-050 First Call Engineer: Ted Kramer (907)777-8420 (O)(985)867-0665 (C) Second Call Engineer: Christina Twogood (907)777-8443 (O)(907)378-7323 (C) AFE Number Maximum Expected BHP: ~ 2,145 psi @ 4,907’ TVD Based on normal gradient Max. Potential Surface Pressure: ~ 1,654 psi Based on normal gradient minus 0.1 psi/ft gas Gradient Brief Well Summary: BRU 212-24T was drilled and completed in 2010 as a single I sand producer. The well IP’d @ 3 MMscfd but declined steeply (37% annual decline). In 2012 The I sands were isolated and the H sands were perforated and frac’d through tubing. The H sands ip’d at 4 MMscfd declining to 3 MMscfd where it stabilized until 2019. The well decreased to 2 MMscgd and eventually completely died in December 2019. The well cum’d 1.5 BCF from the I sand and 6 BCF from the H sands. Objective: The purpose of this workover is to use a rig to pull the current completion and re-complete the well up hole. The well will then be perforated through tubing. Pre- Sundry Work 1.RU Slick line and pressure test Lubricator to 3,000 psi. Pull DMK valve @ 4,800’ and dummy off GLM. 2.RU Pump truck and pressure test the 3-1/2” X 7” IA to 2,000 psi. Record on chart for 30 min. 3.RU E-line and Pressure test lubricator to 250 psi low/ 3,000 psi high. 4.PU RIH W/ through tubing plug and set same at 5,100’. POOH. 5.PU Bailer and Dump Bail 25’ of cement on top of plug (Est. TOC = 5,075’). POOH. Note: All perforations are isolated at this point. 6.PU pipe cutter and RIH to the mandrel of the Baker Premier Packer. Log on depth and fire cutter severing the packer mandrel. POOH. RD E-line. Rig 401 Procedure 7.MIRU 401 Work over rig. 8.ND wellhead, NU BOP and test to 250 psi low & 4,000 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre-charge pressures and chart tests. a.Perform Test. MIT casing All perforations are isolated at this point. 3000 psi min plug lower perfs well will then be perforated through tubing. Rig 169 Note: ScSSV waived in previous sundry 320-055 . Not required by AOGCC regulations. gls The purpose of this workover is to use a rig to pull the current completion and re-complete the well up hole. The w 169 Well Prognosis Well: BRU 212-24T Date: 6/1/20 b.Test rams on 3-1/2” test joint. c.Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 9.RU on 4-1/2” tubing string to relax packer rubbers. 10.Circulate well and bleed off any pressure. 11.Pull landing joint to floor and lay down tubing hanger. 12.POOH W/ 4-1/2” and 3-1/2” tubing string and Packer spooling up CIM line and SSSV Cap line. 13.PU scraper on 3-1/2” tubing string and RIH to TOC @ 5,075’. CBU. POOH W/ Scraper. Note: Halliburton CBL Ran July 3, 2010 shows very good cement bond up to 2,800’. 14.PU RIH With 3-1/2” X 7” Packer completion on 3-1/2“ tubing string. (Note: Space out to land Packer @ 3,600’(+/-) and bottom of tailpipe @ 4,500’ (+/-)). 15.Drop Ball and rod. Pressure up on tubing to set packer as per manufacturer’s setting procedure. 16. Pressure test back side to 2,000 psi on chart for 30 Min. Bleed down pressure. 17.RU Slickline. Pressure test lubricator to 3,000 psi. RIH and retrieve ball and rod. RDMO Slick line. 18.Hang off tubing. ND BOP, NU wellhead and test tree to 5,000 psi. 19.RDMO Rig 401. Coil Tubing Procedure 20.MIRU Coil tubing unit. Pressure test BOP to 4,000 psi. x RU Nitrogen. RIH W/ Coil, drop ball, and blow well dry with Nitrogen leaving 1,550 psi on well head. RDMO Nitrogen and CTU. E-line Procedure 21.MIRU E-line. Pressure test lubricator to 250 psi low, 3,000 psi. high. 22.Perforate the following Sand intervals ( CBL confirms good cement behind pipe): Sand Top, MD ft Bottom, MD ft Top (TVD) Bottom (TVD) Total ftg, MD Sterling C2 ±3,667’ ±3,690’ ±3,647 ±3,670 23 Sterling C3 ±3,710’ ±3,722’ ±3,690 ±3,702 12 Sterling C5 ±3,785’ ±3,821’ ±3,766 ±3,801 36 Beluga D6 ±4,008’ ±4,012’ ±3,988 ±3,992 4 Beluga E5 ±4,255’ ±4,267’ ±4,236 ±4,248 12 Beluga F1 ±4,384’ ±4,393’ ±4,364 ±4,373 9 Beluga F4 ±4,432’ ±4,442’ ±4,412 ±4,422 10 Beluga F7 ±4,696’ ±4,719 ±4,676 ±4,699 23 Beluga F10 ±4,735’ ±4,788’ ±4,715 ±4,769 5 Beluga G2 ±4,864’ ±4,871’ ±4,844 ±4,851 7 Beluga G3 ±4,873’ ±4,899’ ±4,853 ±4,879 26 Beluga G4 ±4,922’ ±4,927’ ±4,902 ±4,907 5 MIT-IA tailpipe at 4300 ft glsNote: Halliburton CBL Ran July 3, 2010 shows very good cement bond up to 2,800’. Displace fluid with N2 169 pull tubing ----------- Perfs tailpipe 4300' Concur with CBL assessment. Pressure test back side to 2,000 psi on chart for 30 Min. Well Prognosis Well: BRU 212-24T Date: 6/1/20 a.Proposed perfs also shown on the proposed schematic in red font. b.Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation (Ben Siks- Geologist, Trudi Hallett – Reservoir Engineer). d.Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record a tubing Surface pressure before each run and after each gun firing of 5, 10, 15 min reading intervals. e.The listed Sands are governed by State Wide Spacing Rules. f. Sand intervals may be grouped or shot one at a time and flow tested to the system. If a sand makes water, then a plug or an isolation patch may be set prior to moving up to the next sand interval. g.The tubing tail may need to be cut and dropped prior to setting isolation plugs to gain access to shallower perf intervals. h.Plugs will be set between pools if required. 23.POOH. RD e-line. 24.Turn well over to production. Attachments: 1.Current Well Schematic 2.Proposed Well Schematic 3.Rig BOP Schematic 4.Coil BOP Schematic 5.Current Well Head Drawing 6.Proposed Well Head Drawing 7.Standard Nitrogen Procedure 8.RWO Sundry Revision Change Form Note: SVS to be tested within 5 days of production _____________________________________________________________________________________ Updated By DMA 08-29-18 SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 6,350’ TVD = 6,330’ RA Tags @ 3008.14’ 3506.84’ 4819.67’ I2a I2b I1 4 5 2 3 6 8 9 A Max Angle = 10.08 deg @ 1,411.2’ Tubing Min ID = 2.75” TOC @ 2,860’ ¼” control line 3/8” Control Line S.S. Tbg 0.049” wall 7 1 Beluga H Sands H2 H3 H7 H9 H10 H13 H16 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40# L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 4.5" Production String 12.6# L-80 IBTM 3.5" 83' 3.5" Production String 9.3# L-80 EUEM 2.99" 4,893' JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description 1 17 3.958 Vetco Gray Hanger 2 83 2.99 Crossover 4.5" IBTM x 3.5" EUE XO-Reducing 3 494 2.813 Camco TRMaxx-5E SSSV 4 4,800 2.867 Camco KBMG 1" GLM w/ DMK Valve & BK Latch 8/23/2012 5 4,824 2.813 BJ BJX 1" Chem Mandrel w/ SOV Valve X Profile, double heck valves, w/ burst disc @ 6000 psi 8/23/2012 6 4,841 4.75 Alternate Bore Seal Assembly TC II, PXP PBR 7 4,855 2.88 Baker Premier Packer 8 4,880 2.75 Camco 2.813" 'XN' Nipple w/ 2.75” No GO 9 4,892 3.1 Wireline Entry Guide Plugs ID. Depth MD (ft.) ID Description A 6,350 - Halliburton EZ Drill Bridge plug 7/3/2010 Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Open FRAC Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Open Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Open Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Open Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Open FRAC Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Open Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Open FRAC Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Open Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Open FRAC Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Open Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Open FRAC Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Open Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Iso PLUG Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Iso PLUG Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Iso PLUG Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing Frac Notes: Beluga H2: Frac’d w/ 76K lbs 20/40 RCC 8/19/2012 H9: Frac’d w/ 74K lbs 20/40 RCC 8/19/2012 H10: Frac’d w/ 74K lbs 20/40 RCC 8/19/2012 H13a/b: Frac’d w/ 81K lbs 20/40 RCC 8/16/2012 I2: Frac’d w/ 61K lbs 20/40 CarboLite w/ 9K lbs 12-20 Flex Sand I1: Frac’d w/ 65K lbs 20/40 CarboLite w/ 9K lbs 12-20 Flex Sand Excellent cement over proposed perforation interval up to 2850 ft . gls _____________________________________________________________________________________ Updated By TRH 24April2020 PROPOSED SCHEMATIC Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00 20” 9-5/8” 7” RKB to MSL = 96.5’ RKB to GL = 18.3’ TD = 6,565’ TVD = 6,545’ PBTD = 6,350’ TVD = 6,330’ RA Tags @ 3008.14’ 3506.84’ 4819.67’ Max Angle = 10.08 deg @ 1,411.2’ TOC @ 2,860’ Beluga H Sands H2 H3 H7 H9 H10 H13 H16 CASING DETAIL Size Type WT Grade Conn ID Btm 20'' Conductor 154.19# X-65 WELD 19.13'' 108' 9-5/8" Surface 40#L-80 BTCM 8.835'' 2,851' 7'' Production 26# L-80 BTCM 6.276'' 6,535' TUBING DETAILS 3.5" Production String ±3,650 JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description ±3,600’ Packer ±3,650 Wireline Entry Guide Plugs ID. Depth MD (ft.) ID Description A 6,350 - Halliburton EZ Drill Bridge plug 7/3/2010 B±5100’ CIBP Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Sterling C2 ±3,667’ ±3,690’ 23’ TBD Proposed Sterling C3 ±3,710’ ±3,722’ 12’ TBD Proposed Sterling C5 ±3,785’ ±3,821’ 36’ TBD Proposed Beluga D6 ±4,008’ ±4,012’ 4’ TBD Proposed Beluga E5 ±4,255’ ±4,267’ 12’ TBD Proposed Beluga F1 ±4,384’ ±4,393’ 9’ TBD Proposed Beluga F4 ±4,432’ ±4,442’ 10’ TBD Proposed Beluga F7 ±4,696’ ±4,719 23’ TBD Proposed Beluga F10 ±4,735’ ±4,788’ 5’ TBD Proposed BelugaG2 ±4,864’ ±4,871’ 7’ TBD Proposed Beluga G3 ±4,873’ ±4,899’ 26’ TBD Proposed Beluga G4 ±4,922’ ±4,927’ 5’ TBD Proposed Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Isolated Beluga H2 5,187’ 5,200' 5,167' 5,180' 13’ 8/17/2018 Isolated Beluga H3 5,217' 5,224' 5,197' 5,204' 7’ 8/17/2018 Isolated Beluga H7 5,354’ 5,362’ 5,335’ 5,343’ 8’ 8/17/2018 Isolated Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Isolated Beluga H9 5,411’ 5,421’ 5,392’ 5,402’ 10’ 8/17/2018 Isolated Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Isolated Beluga H10 5,496’ 5,511’ 5,476’ 5,491’ 15’ 8/16/2018 Isolated Beluga H13a 5,586' 5,596' 5,566' 5,576' 10' 8/15/2012 Isolated Beluga H13 5,586’ 5,614’ 5,566’ 5,594’ 28’ 8/16/2018 Isolated Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Isolated Beluga H16 5,740’ 5,748’ 5,720’ 5,728’ 8’ 8/16/2018 Isolated Beluga I2a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Isolated Beluga I2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Isolated Beluga I1 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Isolated Note: S.S. bands used on S.S. tubing on 4.5” tubing (5 total). Cannon Clamps used On 3.5” tubing 4300 ft Sterling C5 ±3,785’±3,821’36’TBD Proposed ScSSV not required. ----------------- Sterling C3 ±3,710’±3,722’12’TBD Proposed packer thru tubing plug with cmt cap Sterling C2 ±3,667’±3,690’23’TBD Proposed PLug with 25 ft cement cap 3600 ft tubing tail 4300' Beluga River Unit BRU 212-24T 5-29-20 RIG 169 will pull single gate BOPE out due to height restrictions. MASP <3000 psi gls Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Coil Tubing BOP Beluga River 212-24T Current 05/27/2020 Valve, Master, WKM-M, 4 1/16 5M FE, HWO, DD trim Valve, Upper master, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'’ operator, DD trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, DD trim BHTA, Otis, 4 1/16 5M FE x 9 1/2 Otis quick union top Valve, Wing, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'’ operator, DD trim Valve, Wing, WKM-M, 4 1/16 5M FE, HWO, DD trim Vetco Gray, MB-230 system, 11'’ 5M top 20'’ 9 5/8'’ 7'’ 4 ½’’ Beluga River Unit 212-24T 20 x 9 5/8 x 7 x 4 ½ Tubing hanger, Vetco-230, 11 x 4 ½ IBT susp x 4.909 MCA lift threads, 4'’ type H BPV profile, 2- CCL ports, flex neck Beluga River 212-24T Proposed 05/27/2020 Valve, Master, WKM-M, 4 1/16 5M FE, HWO, DD trim Valve, Upper master, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'’ operator, DD trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, DD trim BHTA, Otis, 4 1/16 5M FE x 9 1/2 Otis quick union top Valve, Wing, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'’ operator, DD trim Valve, Wing, WKM-M, 4 1/16 5M FE, HWO, DD trim Vetco Gray, MB-230 system, 11'’ 5M top 20'’ 9 5/8'’ Beluga River Unit 212-24T 20 x 9 5/8 x 7 x 4 ½ Tubing hanger, Vetco-230, 11 x 4 ½ IBT susp x 4.909 MCA lift threads, 4'’ type H BPV profile, 2- CCL ports, flex neck 7'’ 3 ½’’ STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well BRU 212-24T (PTD 210-050) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date 1 Carlisle, Samantha J (CED) From:Ted Kramer <tkramer@hilcorp.com> Sent:Wednesday, June 3, 2020 1:22 PM To:Roby, David S (CED); Schwartz, Guy L (CED) Cc:Boyer, David L (CED); Donna Ambruz Subject:RE: [EXTERNAL] BRU 212-24T (PTD 210-050) RWO sundry David, Thanksfortheclarification.Basedonthat,itlookslikeweneedtoaddsettingaplugoverthebelugaperfintervals beforeperforatingtheSterling. TedKramer Sr.OperationsEngineer HilcorpͲAlaskaLLC Office–907Ͳ777Ͳ8420 Cell–985Ͳ867Ͳ0665 From:Roby,DavidS(CED)[mailto:dave.roby@alaska.gov] Sent:Wednesday,June3,20201:18PM To:TedKramer<tkramer@hilcorp.com>;Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:Boyer,DavidL(CED)<david.boyer2@alaska.gov>;DonnaAmbruz<dambruz@hilcorp.com> Subject:RE:[EXTERNAL]BRU212Ͳ24T(PTD210Ͳ050)RWOsundry Ted, Whentherearen’tdefinedpoolstheAOGCClooksatformationsasthedeterminingfactoronwhetherornotdownhole comminglingwouldoccur.Soifyouwanttoopenupzonesintwodifferentformations,inthisinstanceBelugaand Sterling,atthesametimeyou’dhavetohavedownholecomminglingauthorizationtodoso.However,withthe exceptionofopeninggassandsandoilsandsatthesametimewedon’tconsiderhavingmultiplesandsinsingle formationopenatthesametimetobedownholecommingling. Hopethisexplanationhelps. Regards, DaveRoby 907Ͳ793Ͳ1232 CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservation Commission(AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation. Theunauthorizedreview,useordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail, pleasedeleteit,withoutfirstsavingorforwardingit,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactDaveRobyat907Ͳ 793Ͳ1232ordave.roby@alaska.gov. From:TedKramer<tkramer@hilcorp.com> Sent:Wednesday,June3,20201:05PM 2 To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:Roby,DavidS(CED)<dave.roby@alaska.gov>;Boyer,DavidL(CED)<david.boyer2@alaska.gov>;DonnaAmbruz <dambruz@hilcorp.com> Subject:RE:[EXTERNAL]BRU212Ͳ24T(PTD210Ͳ050)RWOsundry Guy, Seenotesbelow: TedKramer Sr.OperationsEngineer HilcorpͲAlaskaLLC Office–907Ͳ777Ͳ8420 Cell–985Ͳ867Ͳ0665 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Wednesday,June3,20209:33AM To:TedKramer<tkramer@hilcorp.com> Cc:Roby,DavidS(CED)<dave.roby@alaska.gov>;Boyer,DavidL(CED)<david.boyer2@alaska.gov> Subject:[EXTERNAL]BRU212Ͳ24T(PTD210Ͳ050)RWOsundry Ted, Iwillupdatetoreflect169isRWOrig.401ismentionedintheproceduresection.Ihaveacoupleofquestions. 1) AreyouplanningonrunningaScSSV?ThoughtitwasrequiredinBeluga.Notshownonschematic. TheonlywellinBelugathatrequiresaSSSVisonGpad(AKABeachPad)212Ͳ25. 2) Thetubingtailisshownat3650ft(packerisat3600ft)ontheproposedschematic…yetyoumentionhavinga 1000fttubingtailandmayhavetocutifoffifneededtoaccessupperperfs.Itwouldonlydropafewhundred feet(550ft)ifitissetat4500ft.Canyouclarifythis?Idon’tthinkalltheperforationscouldbeaccessedby droppingtail. YouarecorrectGuy.Thetubingtailneedstobesetat4,300’inordertodropandandaccessalloftheproposed perforations. 3) Theplugperforationsboxshouldbechecked. Agreed 4) TheschematicshowsaCIBPat5100ft…shouldbeaTTPlugwithcementcap. Agreed 5) Isn’tthisanewpoolbyopeningtheSterling?Theycan’tbecommingledwithoutAOGCCauthorization. IspokewithBenSiks(Geologist)andCodyTerrell(Land)aboutthis.BoththoughtthatsincethegassandsatBeluga RiverUnitwereallundefined,thencominglingwasallowed.CodyTerrellwasgoingtocallSteveDaviesanddiscussthat point.Thereisaspacingexceptionforthiswell(DocketNumber:COͲ10Ͳ05andCO#629)butthespacingexception doesspecificallymentionBelugaGassandsandnotSterling.Ifitshouldturnoutthatwecannotcomingle,wecanseta plugbetweenthebelugaandsterlingsandswhenwegetthere. 3 IhaveattachedascannedcopyoftheSundryapplicationwiththemarkupsfromyourquestions.Ifyouwouldlikefor metomakethechangesandsubmitacleandocumentIamhappytodoso. Lastly,pleasenotethatdutotheheightofthewellhead,wewillneedtodropthesinglegateoutoftheRig169BOP stack.Ijustlearnedofthattoday. tek Regards, GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Taylor Wellman Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Gas Pool, BRU 212-24T Permit to Drill Number: 210-050 Sundry Number: 320-055 Dear Mr. Wellman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. o l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6ereir rice 9 DATED this day of February, 2020. RBDMS L'WAd FEB 0 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DrN i8/3020jzo 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ e o shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Permanent Sleeve ❑-' - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: SA S55 Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑� Service ❑ 210-050 3. Address: 3800 Centerpoint Dr, Suite 1400 P 6. API Number: Anchorage Alaska 99503 50-283-20136-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 6 x,76' Beluga River Unit 212-24T . ❑ Q ! Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0021128 Beluga River/ Undefined Gas ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,565' 6,545' 6,350' 6,330'-800psi 6,000' 6,350' Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' Surface 2,851' 9-7/8" 2,851' 2,832' 5,750 psi 3,090 psi Intermediate Production 6,535' 7" 6,535' 6,516' 7,240 psi 5,410 psi Production Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 4-1/2" Tubing Grade: 12.6# / L-80 Tubing MD (ft): 83' See Attached Schematic See Attached Schematic 3-1/2" 9.3# /L-80 4,892' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Comm TRMAXX-5E SSSV; Baker Premier Pkr 494' MDrrVDI; 4,855' MD/4,835' TVD 12. Attachments: Proposal Summary .r Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development [a' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 10, 2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Dale: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Taylor Wellman 777-8449 Contact Name: Ted Kramer Authorized Title: Operati ager Contact Email: tkramer@hilcoro.com Contact Phone: 777-8420 ./Lt Authorized Signature: Date: wzo COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ao- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS IAS FEB 0 41010 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exce tion Required? Yes ❑ No Subsequent Form Required: / f�i _ y v APPROVED BY �V�� Approved by: COMMISSIONER THE COMMISSION Date: J Form 10 e� 201r" Approved application Is I 1 t e ate of aPD royal. Attachment m Duplicate j�3t(-2.O � ��/- %2 zz- k 0 Hikom M.A.. LU Well Prognosis Well: BRU 212-24T Date: 1/23/2020 Well Name: BRU 212-24T API Number: 50-283-20136-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: January 25, 2020 Rig: Slickline Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 210-050 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Be York (907) 777-8345 (0) (907) 727-9247 (C) AFE Number: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary 2,418 psi @ 5,476' TVD (From Normal pressure gradient minus depletion) From Normal Pressure Gradient minus depletion and subtracting 0.1 psi/ft gas gradient to 5,476' TVD). BRU 212-24T is a gas producer that developed a SCSSSV issue this week (will not open). After discussing it with our regulatory person, it was determined that this well does not need a SCSSSV as per.lim Regg's e-mail dated May 22, 2017 (copy attached). Since this valve will not open on its own, Hilcorp will take steps to permanently open the flapper in this valve and lock it in the open position (Item # 3 of Mr. Regg's e- mail). Attachments: 1. Actual and Proposed Well Schematics 2. Copy of Jim Regg's E-mail dated May 22, 2017 'Sc S'5VV't� ('G JJ 7e l-3/--2--6 H HBeora Alaska, LLC 20' 3/8" Control S.S. Tbg 0.049" wall SCHEMATIC control line TOC @ 2,86V RA Tags @ 3506.84' 4819.67' 9 O ' Beluga H Sands H2 Tubing Min r H3 to 2.7S" H7 H9 H10 H13 H16 12a 12b IS A 7TD=6,565' TVD=6,545' PBTD = 6,350' TVD = 6,330' Max Angle =10.08 deg @ 1,411.2' Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00 CASING DETAIL Size Type wT Grade Conn ID Btm 20" Conductor 154.19# X-65 WELD 19.13" 108' 9-5/8" Surface 40# L-80 BTCM 8.835" 2,851' 7" Production 26# L-80 BTCM 6.276" 6,535' TUBING DETAILS 4.5" Production String 12.6# L-80 IBTM 3.5" 83' 3.5" ii Production String 9.3# li L-80 EUEM 2.99" 4,893' JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description 1 17 3.958 Vetco Gray Hanger 2 83 2.99 Crossover 4.5"IBTM x3.5"EUE XO -Reducing 3 494 2.813 Carron TRMaxx-5E SSSV 4 4,800 2.867 Camco KBMG 1" GLM w/ DMK Valve & BK Latch 8/23/2012 5 4,824 2.813 BJ BJX 1" Chem Mandrel w/ SOV Valve X Profile, double heck valves, w/ burst disc @ 6000 psi 8/23/2012 6 4,841 4.75 Alternate Bore Seal Assembly TC 11, PXP PBR 7 4,855 2.88 Baker Premier Packer 8 4,880 2.75 Camco 2.813"'XN' Nipple w/ 2.75" No GO 9 4,892 3.1 Wireline Entry Guide Plugs ID. Depth MD (ft.) ID Description A 6,350 Halliburton EZ Drill Bridge plug 7/3/2010 Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Open FRAC Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/17/2018 Open Beluga H3 5,217' 5,224' 5,197' 5,204' 7' 8/17/2018 Open Beluga H7 5,354' 5,362' 5,335' 5,343' 8' 8/17/2018 Open Beluga H9 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Open FRAC Beluga H9 5,411' 5,421' 5,392' 5,402' 10' 8/17/2018 Open Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Open FRAC Beluga H10 I 5,496' 5,511' 5,476' 5,491' 15' 8/16/2018 Open Beluga H13a 5,586' 5,596' 5,566' 1 5,576' 1 10' 1 8/15/2012 Open FRAC Beluga H13 5,586' 5,614' 5,566' 5,594' 28' 8/16/2018 Open Beluga H13b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Oen FRAC Beluga H16 5,740' 5,748' 5,720' 5,728' 8' 8/16/2018 Open Beluga 12a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Iso PLUG Beluga 12b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Iso PLUG Beluga 11 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Iso PLUG Note: S.S. bands used on S.S. tubing on 4.5" tubing (5 total). Cannon Clamps used On 3.5" tubing Frac Notes: Beluga 1-12: Frac'd w/ 76K lbs 20/40 RCC 8/19/2012 1-19: Frac'd w/ 74K lbs 20/40 RCC 8/19/2012 H10: Frac'd w/ 74K lbs 20/40 RCC 8/19/2012 H13a/b: Frac'd w/ 81K lbs 20/40 RCC 8/16/2012 12: Frac'd w/ 61K lbs 20/40 CarboLite w/ 9K Ibs 12-20 Flex Sand 11: Frac'd w/ 65K lbs 20/40 CarboLite w/ 9K lbs 12-20 Flex Sand Updated By DMA 08-29-18 K Hilce" Alaeks. LLC In 3/8" Control Line S.S. Tbg 0.049" wall PROPOSED SCHEMATIC CASING DETAIL Beluga River Unit Well: BRU 212-24T Last Completed: 7/5/2010 PTD: 210-050 API: 50-283-20136-00 TUBING DETAILS control line 4.5" Production String 12.6# L-80 1 IBTM3.5" 83' 3.5" Production String 9.3# L-80 EUEM 2.99" 4,893' TOC @ 2,86(YJEWELRY DETAIL �RA Tags @ ``3008.14' 3506.84' 4819.67' Production String ID. Size Type WT Grade Conn ID Btm 2 20" Conductor 154.19# X-65 WELD 19.13" 108' 3 9-5/8" Surface 40# L-80 BTCM 8.835" 2,851' L 7" Production 26# L-80 BTCM 6.276" 6,535' TUBING DETAILS control line 4.5" Production String 12.6# L-80 1 IBTM3.5" 83' 3.5" Production String 9.3# L-80 EUEM 2.99" 4,893' TOC @ 2,86(YJEWELRY DETAIL �RA Tags @ ``3008.14' 3506.84' 4819.67' Production String ID. Depth MD (ft.) ID (in.) Description 1 17 3.958 Vetco Gray Hanger 2 83 2.99 Crossover 4.5" IBTM x 3.5" EUE XO -Reducing 2A 13' 8/19/2012 Permanent Sleeve 3 494 2.813 Camco TRMaxx-5E SSSV 4 4,800 2.867 Camco KBMG 1" GLM w/ DMK Valve & BK Latch 8/23/2012 5 4,824 2.813 BJ BJX 1" Chem Mandrel w/ SOV Valve X Profile, double heck valves, w/ burst disc @ 6000 psi 8/23/2012 6 4,841 4.75 Alternate Bore Seal Assembly TC 11, PXP PBR 7 4,8552 '88 1 Baker Premier Packer 8 4,880 2.75 Camco 2.813"'XN' Nipple w/ 2.75" No GO 9 4,892 1 3.1 Wireline Entry Guide L I Plugs ID. Depth MD (ft.) ID Description 4', A 6,350 - Halliburton EZ Drill Bridge plug 7/3/2010 5: Tubing Min ID = 2.75" Beluga H Sands H2 H3 H7 H9 H10 H13 H16 12a 12b 7TD=6,565' TVD =6,545' PBTD = 6,350' TVD = 6,330' Max Angle =10.08 deg @ 1,411.2' Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Date Status Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/19/2012 Open FRAC Beluga H2 5,187' 5,200' 5,167' 5,180' 13' 8/17/2018 Open Beluga H3 5,217' 5,224' 5,197' 5,204' 7' 8/17/2018 Open Beluga H7 5,354' 5,362' 5,335' 5,343' 8' 8/17/2018 Open Beluga 119 5,411' 5,421' 5,391' 5,401' 10' 8/16/2012 Open FRAC Beluga H9 5,411' 5,421' 5,392' 5,402' 30' 8/17/2018 Open Beluga H10 5,496' 5,511' 5,476' 5,491' 15' 8/16/2012 Open FRAC Beluga 1-110 5,496' 5,511' 5,476' 5,491' 15' 8/16/2018 Open Beluga 1-113a 5,586' 5,596' 5,566' 5,576' 10' 1 8/15/2012 1 Open FRAC Beluga H13 5,586' 5,614' 5,566' 5,594' 28' 8/16/2018 Open Beluga 1133b 5,604' 5,614' 5,584' 5,594' 10' 8/15/2012 Open FRAC Beluga H16 5,740' 5,748' 5,720' 5,728' 8' 8/16/2018 Open Beluga 12a 5,786' 5,794' 5,766' 5,774' 8' 7/28/2010 Iso PLUG Beluga l2b 5,818' 5,830' 5,798' 5,810' 12' 7/28/2010 Iso PLUG Beluga 11 6,022' 6,036' 6,002' 6,016' 14' 7/16/2010 Iso PLUG Note: S.S. bands used on S.S. tubing on 4.5" tubing (5 total). Cannon Clamps used On 3.5" tubing Frac Notes: Beluga 1-12: Frac'd w/ 76K lbs 20/40 RCC 8/19/2012 1-19: Frac'd w/ 74K lbs 20/40 RCC 8/19/2012 H10: Frac'd w/ 74K lbs 20/40 RCC 8/19/2012 H13a/b: Frac'd w/ 81K lbs 20/40 RCC 8/16/2012 12: Frac'd w/ 61K lbs 20/40 CarboLite w/ 9K lbs 12-20 Flex Sand 11: Frac'd w/ 65K lbs 20/40 CarboLite w/ 9K lbs 12-20 Flex Sand Updated By DMA 01-23-20 Froin: Re& James B (DOA) lmailto:iim.reezpalaska.¢ov1 Sent: Monday, May 22, 20172:32 PM To: tarty Greenstein Subject: RE: Beluga River wells and SCSSSVs Based on the information provided with your 3/8/2017 ema9, and comparing to the requirements In 20 AAC 25.265(d), I concurthat only BRU 243-34 (PTD 2090790) b required to maintain a subsurface safety valve (SSSV) because the mean high water line falls within a 66D -foot radius circle drawn around the well. A few observations regarding the options available for the walk currently equipped with an operable SSSV: 1) Maintain and performance -test the SSSV as directed in 20AAC 25.2651h)—In this case, AOGCC would recognize the SSSV for calculating test performance failure rates (decisions about allowing the well to continue producing with a passing LPS/SSV; decisions about increased test frequency for greater than 10% failure rate; 2) Leave SSSV installed but not performance -tested —AOGCC will not include the 'test -as -needed" SSSV as a valid component for decisions about continued production or decisions about testing frequencies 3) Re move SSSV — request that the AOGCC be notif led 9 Hilcorp removes SSSV (so we can add appropriate remarks in our Inspection database). Jim Regg Supervisor, Inspections AOGCC 333 W.7 -Ave, Suite 100 Andmile, AK 99501 907-793-1236 CONFIDENNADTyNOTU.Thus e-mail message, including any marchmems, mmains information from the Alaska Oil and Gas Cora madon Commission (AOGCC), State ofAlasla and is forthe sole use ofthe intended redpiem(sl. it may contain confidential andfor privileged information The unauthorized resiew, use or dadonde of such information may violate state or federal law. If you are an unintended redpient of this e-mail, please delete it, without Jim saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, comae- Jim Regg at 907-7911236 or iini reeeHalasla.ew. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q Q - _0$0 Well History File Identifier Organizing (done) RESC Wrey r Items: scale Items: ❑ Poor Quality Originals: ❑ Other: NOTES: Two-sided 1111111111111111111 DIGITAL DATA ❑ Diskettes, No. ❑ Other, No/Type: o Re,canNeeded 1111111111111111111 OVERSIZED (Scannable) ❑ Maps: ❑ Other Items Scannable by a Large Scanner OVERSIZED (Non -Scannable) ❑ Logs of various kinds: ❑ Other:: BY: Maria Date: /s/ I 1 Project Proofing II I II II II I I III I LII BY: Maria Date: /s/ Scanning Preparation 15 x 30 = + = TOTAL PAGES Count does not include cover sheet) BY: Maria Date: 5 /s/ Production Scanning III II'IIIIIIII II III Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _YES NO BY: Maria Date: 1 15-1 I Lf /s/ or Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III Rescanned III IIIIIIIIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II')IIIII IIII�II 12/22/2011 Well History File Cover Paae.doc DATA SUBMITTAL COMPLIANCE REPORT 10/5/2012 Permit to Drill 2100500 Well Name/No. BELUGA RIV UNIT 212-24T Operator CONOCOPHILLIPS ALASKA INC API No. 50-283-20136-00-00 MD 6565 TVD 6545 Completion Date 8/5/2010 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Completion Status 1 -GAS Samples No Log Log Run Scale Media No Current Status 1 -GAS UIC N Directional SuryYes (data taken from Logs Portion of Master Well Data Maint Interval OHI Start Stop CH Received Comments Rpt % LIS Verification 159 6565 Open 7/28/2010 I ED 1--C Lis 19926 Induction/Resistivity 159 6565 Open 7/28/2010 RPD, RPX, FET, RPS, RPM, GR, ROP, NPHI, NCNT, FCNT, RHOB, DRHO Plus TIFF, CGM, & PDF Graphics Log LI Induction/Resistivity 25 Col 222 6565 Open 7/28/2010 MD BAT, DGR, EWR, I ALD, CTN j Log v Induction/Resistivity 25 Col 222 6565 Open 7/28/2010 TVD BAT, DGR, EWR, ALD, CTN Log (/ Induction/Resistivity 25 Col 222 6565 Open 7/28/2010 MD ROP, DGR, EWR, ` j Log v Induction/Resistivity 25 Col 222 6565 Open 7/28/2010 ALD, CTN TVD DGR, EWR, ALD, CTN Log Perforation 5 Col 5650 5900 Case 8/11/2010 MD Perf, CC:, GR stage two Logi"" Perforation 5 Col 200 6280 Case 8/11/2010 MD Perf, Stage One, CCL, GR, Jewelry Log Log Cement Evaluation 5 Col 1250 6432 Case 8/11/2010 MD Advanced Cement Evaluation Log V/ Cement Evaluation 5 Col 1400 6433 Case 8/11/2010 MD Fast Circumfer Acoustic Scan CBL field print Log ,`' Plug 5 Col 6200 6400 Case 8/11/2010 Plug Setting Record, CCL, GR Rpt �� Report: Final Well R 0 6565 Open 8/18/2010 End of Well, Morn Rep, Bit & Mud, Form Top, Sury Rep, Days vs Depth, Digital Data I i I DATA SUBMITTAL COMPLIANCE REPORT 10/5/2012 Permit to Drill 2100500 Well Name/No. BELUGA RIV UNIT 212-24T MD 656 TVD 6545 Completion Date 8/5/2010 E C Pdf 20013 Report: Final Well R Operator CONOCOPHILLIPS ALASKA INC API No. 50-283-20136-00-00 Completion Status 1 -GAS 0 Log Mud Log 2 Col 222 Log Mud Log 5 Col 222 Log Mud Log 5 Col 222 Log / Mud Log 2 Col 222 6565 Open 8/18/2010 MD Gas Ratio 6565 Log Mud Log 5 Col 222 Log Mud Log 2 Col 222 ` 6565 Open 8/18/2010 MD Formation Eval Log Mud Log 2 Col 222 Log Mud Log 5 Col 222 / TVD Formation Eval 6432 Case 8/11/2010 Log Mud Log 2 Col 222 Logue Mud Log 5 Col 222 ED Las 19982 Cement Evaluation Graphics 1250 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y q) Chips Received? Y71q- * Analysis Received? Comments: Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1 -GAS UIC N 6565 Open 8/18/2010 End of Well, Morn Rep, Bit Sample Set Number Comments E)N t/N Compliance Reviewed By —_ ___ -_ __ _ _ Date: L) ` �� & Mud, Form Top, Sury Rep, Days vs Depth, Digital Data w/3D graphics 6565 Open 8/18/2010 MD Engineering log 6565 Open 8/18/2010 MD Engineering log 6565 Open 8/18/2010 MD Gas Ratio 6565 Open 8/18/2010 TVD Gas Ratio 6565 Open 8/18/2010 TVD Gas Ratio 6565 Open 8/18/2010 MD Gas Ratio 6565 Open 8/18/2010 MD Formation Eval 6565 Open 8/18/2010 MD Formation Eval 6565 Open 8/18/2010 TVD Formation Eval 6565 Open 8/18/2010 TVD Formation Eval 6432 Case 8/11/2010 Advanced Cement Evaluation, Plug Setting, Jewelry, Perferation Plus Graphics Sample Set Number Comments E)N t/N Compliance Reviewed By —_ ___ -_ __ _ _ Date: L) ` �� DATA SUBMITTAL COMPLIANCE REPORT 10/5/2012 Permit to Drill 2100500 Well Name/No. BELUGA RIV UNIT 212-24T Operator CONOCOPHILLIPS ALASKA INC MD 6565 TVD 6545 Completion Date 8/5/2010 Completion Status 1 -GAS Current Status 1 -GAS API No. 50-283-20136-00-00 UIC N WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record : BRU 212-24T Run Date: 09/16/2012 - 09/19/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 BRU 212-24T LAS Data, Digital Log Image file 1 CD Rom 50-283-20136-00-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 SCANNED Fax: 907-273-3535 klinton.wood@halliburton.com Date: 1,0 L w Signed: dialtitt 644 STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COM. SION REPORT OF SUNDRY WELL OPERATIONS DECEIVED SEP 2 12012 A n►n^^ 1. Operations Performed: Abandon �'-` Repair w ell r Plug Perforations r Perforate W her After Casing Pull Tubing jStimulate - Frac r Waiver r Time Extension r Change Approved Program Operat. Shutdown " Stimulate - Other r Re-enter Suspended Well r- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 11 Exploratory r Stratigraphic Service r 210-050 3. Address: 6. API Number: - P. O. Box 100360, Anchorage, Alaska 99510 50-283-20136-00 7. Property Designation (Lease Number): 8. Well Name and Number:. ADL 21128 — BRU 212-24T 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Beluga River Field / Undefined Gas Pool 11. Present Well Condition Summary: Total Depth measured 6565 feet Plugs (measured) 5738, 6000, 6350 true vertical 6545 feet Junk (measured) None Effective Depth measured 5738 feet Packer (measured) 4855 true vertical 5718 feet (true vertical) 4835 Casing Length Size MD TVD Burst Collapse Conductor 91 20" 91' 91 Surface 2851 9.625" 2851' 2832 Production 6535 7" 6535' 6515 Perforation depth: Measured depth: 5187-5200, 5411-5421, 5496-5511, 5586-5596, 5604-5614, 5786-5794, 5818-5830, 6022-6036 True Vertical Depth: 5167-5180, 5391-5401, 5476-5491, 5566-5576, 5584-5594, 5766-5774, 5798-5810, 6002-6016 Tubing (size, grade, MD, and TVD) 4.5" x 3.5", L-80, 83'/ 4892' MD, 4873 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 4855 MD and 4835 TVD SSSV - CAMCO TRMAXX-5E SSSV @ 494 MD and 494 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5187-5200, 5411-5421, 5496-5511, 5586-5614 Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 1240 mscfd Subsequent to operation 1615 mscfd 336 0 145 psi 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory j Development r - Service Stratigraphic i 16. Well Status after work: Oil F Gas 1 W WDSPL j Daily Report of Well Operations XXX GSTOR WINJ WAG j" GINJ r"" SUSP �"" SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312-267 Contact Kerry Freedman (ED 265-6579 Printed Name K. Freedman Title Completions Engineer Signature Phone: 265-6579 Date Form 10-404 Revised 11/201 MDMS SEP 21 1#y7 Submit Original Only BRU 212-24T Well Work Summary DATE SUMMARY 8/6/12 RU SL, SET 2.813" PXN PLUG @ 4884' RKB, BLEED OFF TBG, SHUT DOWN FOR NIGHT, IN PROGRESS 8/7/12 LOAD TBG 6% KCL, PT 2500, SET 2 -WAY CHECK, BEGIN RD PROD TREE, SHUT DOWN FOR NIGHT, IN PROGRESS 8/8/12 Preparing to N/D production tree and N/U frac tree 8/8/12 REPLACE TBG HEAD BONNET, INSTALL FRAC TREE, PT MASTR VLV 10K, REMOVE 2 -WAY CHECK 8/9/12 N/D production tree, N/U frac tree, prepare pad for frac operations 8/10/12 Continue to prepare pad for frac operations 8/11/12 Continue to prepare location for frac operations, begin spotting tanks and frac equipment. 8/12/12 Spotting and rigging up frac equipment, loading frac tanks ad proppant. 8/13/12 Continue rigging up frac and CT equipment, loading tanks, heating fluid, loading proppant. 8/14/12 Moved slickline unit post frac sleeve install. Built Handy -Berm containment for 400 -bbl diffuser tank and 120 - bbl open -top tanks. Mobilized tanks to location and rigged -up flowback to tanks. Spotted up CT supply tank. Rigged up coiled tubing BOPE to frac tree and performed BOP test (AOGCC waived witness). Completed rigging up frac unit. Completed rigging up CT choke skid and flowback. Neutralized for reuse/recycle the gel in Class I fluids tank at C -Pad circulating citric with MI c -pumps. 8/15/12 Pressure tested frac unit pumps, treating lines, frac-tree connections, etc. Baker pumping services crew partially changed -out. Performed plug -back operations consisting of 20-40 ZG PolarProp and 20-ppt linear guar gel slurry. Rigged up slickline and tagged sand top at 5763' confirming proper fill up and isolation of the I -sand. Pressure tested sand plug with Baker Hughes combi pump to 4000 -psi. Rigged up Halliburton a -line and perforated 5604'-5614' and 5586'-5596' Zone 3 perfs using 2.5" guns loaded 6-spf with Millennium deep penetrating charges. 8/16/12 Executed fracture stimulation treatment in the Zone -3, lower H -sand interval, pumping 1138-total-bbis of linear and crosslink gel (20# Lightning 2000), and 81,549 -total -lbs of 20-40 ZG PolarProp resin coated proppant, continually increasing sand concentration from 1.0-6.0 PPA. Estimate 76,587 -lbs sand placement behind pipe, with a 4,962 -Ib proppant volume included in the final 6-ppa stage spotted in the casing to serve as the plug isolating this zone from Zone -4, the next perforation and frac treatment zone above. Rigged up slickline to tag top of proppant fill, correlating to the XN-nipple; soft set -downs indicated possible incomplete settling at top of sand plug. Performed pressure test to 4000 -psi against the plug to confirm integrity of the plug. Retagged sand top with 2-1/2" bailer and tagged sand approximately 90' high of target plug depth for the Zone -4 frac interval. 8/17/12 Attempted coiled tubing fill clean out of the plug -back proppant using standard 2-1/4" down jet nozzle (4 ea. Y4" ports, all down), pumping 6% KCI at 2.5 -bpm 4000 -psi CTP, 500 -psi WHP. Dry tagged sand at 5541' and corrected to 5534' based on slickline tag corrected to XN-nipple. Unable to penetrate resin -coated proppant setting down 8000# (surface) and jetting; multiple attempts varying weights and run-in speeds. POOH and swapped to the BHI Vortex jet -velocity tool. Ran in and cleaned -out proppant no problem to 5550' correlated- CTMD, pumping 2.5 -bpm, 7000 -psi CTP, 6%KCI water with friction reducer. Rigged up Pollard slickline and tagged sand plug at 5548' SLM corrected to XN-nipple. Rigged up HES a -line and perforated the H -sand Zone -4 at 5496-5511' using 2.5" guns loaded 5-spf with Millennium deep penetrating charges. Concurrently reloaded proppant and KCL; loaded and heated freshwater. 8/18/12 Executed fracture stimulation treatment in the Zone -4, lower H -sand interval, pumping 972-total-bbls of linear and crosslink gel (20# Lightning 2000), and 73,815 -total -lbs of 20-40 ZG PolarProp resin -coated proppant, continually increasing sand concentration from 1.0-6.0 PPA. Estimate 76,587 -lbs sand placement behind pipe, with a 996 -Ib proppant volume included in the final 6-ppa stage spotted in the casing to serve as the plug isolating this zone from Zone -6, the next perforation and frac treatment zone above. Rigged up slickline to tag top of proppant fill, correlating to the XN-nipple; tagged sand at 5,433'. Performed pressure test to 4000 -psi against the plug to confirm integrity of the plug; observed anticipated leak -off due to permeability of 56' plug. Ran in with slickline and retagged sand at 5456'. Rigged up HES a -line and perforated 5,411'- 5,421' (Zone -6) using 2.5" guns loaded 6-spf with Millennium deep penetrating charges. 8/19/12 Executed fracture stimulation treatment in the Zone -5, upper H -sand interval, pumping 933-total-bbls of linear and crosslink gel (20# Lightnir 100), and 74,154 -total -lbs of 20-40 ZG Pc rop resin -coated proppant, continually increasing sand coi_ntration from 1.0-6.0 PPA. Estimate 71,76„ .os sand placement behind pipe, with a 2,359 -Ib proppant volume included in the final 6-ppa stage spotted in the casing to serve as the plug isolating this zone from Zone -6, the next perforation and frac treatment zone above. Performed pressure test to 4000 -psi against the plug to confirm integrity of the plug; observed anticipated leak -off due to permeability of plug. Rigged up slickline to tag top of proppant fill, correlating to the XN-nipple; tagged sand at 5,291'. Rigged up HES a -line and perforated 5,187'-5,200' (Zone -6) using 2.5" guns loaded 6-spf with Millennium deep penetrating charges. Performed DFIT and frac treatment on Zone -6 pumping 903-total-bbls of linear and x -link, and 74,227 -total -lbs of proppant, continually increasing sand concentration from 1.0-6.0 8/20/12 Performed coiled tubing post -frac nitrified fill -clean-out pumping 6% KCI w/FRW16A friction reducer at 2.0 - bpm, and nitrogen gas at 750-scfm. Cleaned down to 5,745' CTMD; observed heavy concentrations of frac proppant in returns throughout cleanout. Used the BHI vortex velocity jetting tool which penetrated resin coated proppant with no set -downs encountered. Pumped total of 330 -bbl KCI water and 130,000-sfm N2 gas. Rigged up slickline and tagged proppant plug at 5,738' RKB, correlated to XN-nipple tag (-16' correction). Installed PXN plug and prong in the 3-1/2" XN profile. Pressure tested the PXN plug to 4000 -psi. 8/21/12 Began rigging down frac unit. Staged Sand King, frac pumps, chem -add van, gel transport, etc., at various other pads. Rigged down and staged a -line and re -spotted slickline. Rigged down coiled tubing BOPE and configured tree for slickline. Vetco Gray on location inspected production tree and tree for next location. Removed KCI water from frac tanks for transport. Started removal of rainwater from containment for disposal and to rig down Handy -Berm. Prepped for N/D frac tree and N/U production tree procedure. 8/22/12 Rigged up slickline and installed catcher sub above PXN plug. Pulled dummy valve from gas lift mandrel at 4,800' with 200 -psi applied on tubing. Pumped down IA, 120,000-scf N2 at 1800 -psi, taking returns through open side pocket mandrel, up tubing through flow cross and choke valve to diffuser tank. Bled down to zero (1 -hr) and monitored pressure for 30 -min to pressure test PXN plug in direction of flow; still 0 -psi after 30 - min. Rigged up GE Vetco Grey and installed two-way check valve in tubing hanger. Lined up again N2 down annulus and pressure tested two-way checks to 3000 -psi from below, in direction of flow (185,000-scf N2). Bled down IA (well) to zero (1.5 -hr), and rigged -down N2 line and 2" returns 1502 from wing valves. 8/23/12 Pressure tested production tree to 5,000 psi with 6% KCI using the combi/N2 pump; watched test for 30 -min, good test. Mobilized frac tree and 1502 integral flanges to J -Pad. Rigged up GE Vetco-Grey lubricator and pulled two-way check valve from tubing hanger. Rigged up slickline and installed 1" orifice -valve (3/8" orifice) in side pocket mandrel at 4,809. Ran in with 3-1/2" GS and pulled catcher sub. Pressure tested slickline and treating iron again to 3,500 -psi and ran in with JDS pulling tool. Pressured up tubing to 3,000 -psi and pulled equalizing prong from PXN plug at 4,880'. Ran in slickline and pulled PXN plug body from 3-1/2" XN profile at 4,880'. [SITP = 1,700 -psi]. Well ready for testing/production. 8/24/12 Began de -mob of equipment to J -Pad. 8/25/12 Rigged down flow -line off of wing and rigged back up rotated SSV 1800, and pressure tested tree to 5k -psi. Continue de -mob and began clean-up around pad. 8/26/12 Completed de -mob and all final clean-up of K -pad. BRU 212-24T As Built Rt ompletion Schematic 9 -17 - Surface Location 2633335.24 N; 1463508.87 E (NAD83). DOYON ARCTIC FOX RKB HEIGHT: 97.17 ft 1/4" 316SS Control Line to SSSV (d 493.61' MD 0.049" wall thickness 3/8" 316SS Control Line to CCIS (a) 4824.18' MD 0.049" wall thickness 3-%" TRMAXX-5E SSSV (W 493.61' MD 2.812 X Profile, 5.176" OD, 2.812" ID, 55" long. 3.5" 9.3# EUE special clearance Box X Pin. 5K psi working press. Stainless Steel Bands (on 4-'/2" tubing) Total Run: 5, see tubing tally for details. Cannon Cross Coupling Protectors Tubing clamp protector, over coupling type, w/ channel for (left to right): 0.375" bare line, 0.250" bare line. Low carbon steel. 25.25" long. Total run: 80, see tubing tally for details. Cannon Tubing Standoff Mid -joint type, run above/below SSSV w/a channel, low carbon steel, 15" long. Total run: 2, see tubing tally for details. 3'/2" x 1" Carrico KBMG GLM w/ 1" DMY (a� 4800.42' MD 2.867" drift ID, 5.39" major OD (oval shaped), 4500 psi external & 6000 psi internal test pressure. BJ 3.5" CCIS Chemical Injection Sub (cry 4824.18' MD 13 Cr, 10K psi working pressure, 2.813" BJ X profile, 2.813" ID, 5.680" OD (eccentric), 37.5" long, double check valves to control line, w/ 6000 psi burst disc. Baker 3.5" alternate bore asst/ TC II @4841.21 'MD GLM Baker Premier Packer 5.98"Odx 2.88" ID a. 4854.86'MD, center of packer element 2.4' from top of packer. 2.813" XN Nipple w/ 2.75" No -Go Q-) 4880.24' MD Wireline Entry Guide 4.5" OD x 3" ID aQ 4891.62' MD ConocoPhillips Conductor (Driven): 20", .75", API 5L GRB, Full Grvd, R3 Driven to Refusal 91' Below Pad Grade Surface Casing: 9-5/8", 40#, L-80, BTCM Set @ 2851' MD (TD@ 2861' MD) Production Casing: 7", 26.00#, L-80, BTC -Mod Set @ -6533' MD on Slips Tubing: 4'/2" 12.6#, L-80 IBTM to 83.37' MD; 3-1/2", 9.3#, L-80, EUE 8RD-Mod from 84.9'MD to 4891.62' MD RA TAG in 7" CSG Q 3008.14' MD (9.78' pup) Sterling A Sand 3286' MD / 3169' SSTVD Sterling B Sand 3465' MD / 3349' SSTVD Sterling C Sand 3616' MD / 3500' SSTVD -- RA TAG in 7" CSG (u) 3506.84' MD (9.8' pup) Beluga D Sand 3781' MD / 3664' SSTVD Beluga E Sand 4043' MD / 3926' SSTVD Beluga F Sand 4371' MD / 4253' SSTVD Beluga G Sand 4794' MD / 4677' SSTVD \ RA TAG in 7" CSG (a) 4819.67' MD (9.76' pup) Baker Inflatablel Bridge Plug (ED, 6000' MD Halliburton EZ Drill Bridge Plug Cc. 6350' MD Weatherford Float Collar (a) 6451.48' MD Beluga H Sand 5096' MD / 4979' SSTVD Float Shoe (Silver Bullet Eccentric) a, 6533.35' MD TD 0). 6565MD (6545' TVD) Zone 6 Perfs @ 5187-5200' MD (13') Zone 6 Frac'd w/ 76 K lbs 20/40 RCC -- ----- .....- = Zone 5 Perfs @ 5411-5421 MD (10') Zone 5 Frac'd w/ 74 K lbs 20/40 RCC ---`__=-------- ----- ------ Zone 4 Perfs @ 5496'-5511' MD (15) Zone 4 Frac'd w/ 74 K lbs 20/40 RCC ---`-==::::___ _._____-:--- Zone 3 Perfs @ 5586'-5596' MD (10') - -- -------') ------ 5604'-5614' MD (10 Zone 3 Frac'd w/ 81 K lbs 20/40 RCC , Beluga I Sand 5772' MD / 5655' SSTVD Top of RC Propoant Plug as 5738' MD Zone 2 Frac'd w/ 61 K lbs 20/40 Zone 2 Perfs @ 5786-5794' MD (8'), 2818 psi CarboLite w/ 9 K lbs 12-20 Flex Sand - ------------------------ -- 5818-5830' MD (12'), 2835 psi Zone 1 Frac'd w/ 65 K lbs 20/40-------- Zone 1 Perfs @ 6022-6036' MD (14'), 2995 psi CarboLite w/ 9 K lbs 12-20 Flex Sand ----- --- -----' ""--� �� Beluga 1 Base 6318' MD / 6201' SS TVD t i r d y SEAN PARNELL, GOVERNOR �) KA ALASKA OIL AND GAS333 W. 7th AVENUE, SUITE 100 MI0T CONSERTATION COISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 K. Freedman Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 212-24T Sundry Number: 312-267 Dear Mr. Freedman: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of July, 2012. Encl. STATE OF ALASKA A, CA OIL AND GAS CONSERVATION COMh_ .TION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUL 190 2 Anr4 .C: 1. Type of Request: Abandon r Rug for Redrill Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r%7 FWI Tubing j-' Time Extension Operational Shutdow n r Re-enter Susp. Well Stimulate ji" • After casing r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory Stratigraphic r Service r 210-050 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-283-20136-00 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r7 BRU 212-24T 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 21128 Beluga River Field / as 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): 6565 6545 5881' 5861' 6350' Casing Length Size MD TVD Burst Collapse Conductor 110 20" 110' 110' Surface 2851 9.625" 2851' 2832' Production 6535 7" 6535' 6516' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5786-5794, 5818-5830, 6022-6036 5766-5774, 5798-5810, 6002-6016 4.5" x 3.5" L-80 83'/ 4893' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER MD= 4855 TVD=4835 SSSV - CAMCO TRMAXX-5E SSSV MD=494 TVD=494 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r— Exploratory r Development jri Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/24/2012 Oil r Gas r WDSPL r Suspended r WINJ r GINJ r WAG r Abandoned r 16. Verbal Approval: Date: Commission Representative: GSTOR r SPLUG r- 17. 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kerry Freedman @ 265-6579 Printed Name K. Freedman Title: Completions Engineer Signature Zl� Phone: 265-6579 Date 7/ / Z Commossion Use Only Sundry Number: ✓ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test - Mechanical Integrity Test Location Clearance r Other: 17 Subsequent Form Required: 16-L10 y / APPROVED BY _ Approved by: COMMISSIONER THE COMMISSION Date:Form 10-403 Revised 1/201047-23.1 OR I G I8 1 11 ubmit in Duplicate Mr4� 7 <V BRU 212-24T Overview CPAI is planning to complete additional pay sand intervals in the Beluga River Unit (BRU) 212-24T well. The well was initially completed in July -August 2010 in the Beluga I sands. Additional pay sands encountered in the well at the time are now proposed for completion to increase production rate and ultimate recovery. These proposed completion sands are within the interval included in the original Permit to Drill, The proposed work will be performed through the existing completion tubing string. The proposed procedure includes sanding back the well across the existing completion intervals, and perforating and hydraulic fracture stimulating in the proposed Beluga H sands. These sands will be perforated and fractured in 4 stages as follows: Zone Perforation Depths (ft Proppant (20-40 20 Ib/1000 gallon MD RKB) curable resin coated guar/borate water ceramic) * based frac fluid * 1 5586'-5596'& 5604'- 75,000 —100,000 lbs 35,000 — 50,000 gals 5614' 2 5500-5506' 75,000 —100,000 lbs 35,000 — 50,000 gals 3 5411'-5421' 75,000 —100,000 lbs 35,000 — 50,000 gals 4 5187'-5200' 75,000 — 100,000 lbs 35,000 — 50,000 gals * Preliminary volumes. Volumes to be optimized on location based on diagnostic pressure testing. BRU 212-24T Operational Overview The well will be sanded back after each frac stage prior to perforating for the next stage. Upon completion of the fourth frac stage all of the sand plugs will be cleaned out and the well will be returned to production from the Beluga H and I sands. A general operational summary is as follows: 1. Rig up slickline. Drift tubing, tag bottom. Set PXN plug and prong in XN nipple at 4880'. Bleed off tubing pressure to zero. 2. Fill tubing with 6% KCI brine. 3. Pressure test tubing to 250/2500 psi. 4. With 2500 psi on tubing, pressure test tubing x casing annulus to'� 250/4000 psi 5. Bleed off tubing pressure to 500 psi. Close SCSSV, bleed off remaining pressure from tubing and monitor. 6. Bleed casing to zero. Set two way check in BPV profile in tubing hanger. 7. N/D production tree, N/U and test 10K frac tree 8. Spot equipment, fill tanks, load proppant. 9. Spot and rig up coiled tubing unit. 10. Spot and tag sand plug with coiled tubing as needed to isolate existing Beluga I sand perfs. 11. Perforate zone 1 perfs (as detailed above) with guns on electric line and install frac sleeve. 12. Frac zone 1 perfs. 13. Tag top of proppant with slickline. 14. Spot and tag plug as needed with coiled tubing to isolate zone 1 interval. 15. Repeat steps 10-13 for zones 2 and 3 (as detailed above). 16. Perforate zone 4 perfs (as detailed above) with guns on electric line and install frac sleeve. 17. Frac zone 4 perfs. 18. Pull frac sleeve and tag top of proppant with slickline. 19. RD and demob frac equipment 20. Clean out sand plugs from wellbore with coiled tubing/nitrogen lift as needed. 21. RD and demob coiled tubing unit 22. ND frac tree, NU production tree 23. RU flowback/test equipment 24. Flow well back through flowback equipment, lift with nitrogen as needed. 25. Demob flowback equipment Please refer to the attached well schematic for additional well details. The current estimated timeline for this work is as follows: 7/24/12 ND production tree, NU frac tree 8/5/12 Perf zone 1 8/6/2012 Frac zone 1 8/8/2012 Perf zone 2 8/9/2012 Frac zone 2 8/11/2012 Perf zone 3 8/12/2012 Frac zone 3 8/14/2012 Perf zone 4 8/15/2012 Frac zone 4 8/17/2012 Clean out sand plugs 8/19/2012 ND frac tree, NU production tree 8/21/2012 Start flowback 8/28/2012 Conclude flowback 8/30/2012 Demob from location L j � ( Cn /1% iss•�-�— w� BRU 212-24T Proposed Re -Completion Schematic Surface Location 2633335.24 N; 1463508.87 E (NAD83). DO YON ARCTIC FOX RKB HEIGHT: 97.17 ft 1/4" 316SS Control Line to SSSV 2) 493.61' MD 0.049" wall thickness 3/8" 316SS Control Line to CCIS rID_ 4824.18' MD 0.049" wall thickness 3-1/." TRMAXX-5E SSSV @ 493.61' MD 2.812 X Profile, 5.176" OD, 2.812" ID, 55" long. 3.5"9.3# EUE special clearance Box X Pin 5K psi working press. Stainless Steel Bands (on 4-1/2" tubing) Total Run: 5, see tubing tally for details. Cannon Cross Couolina Protectors Tubing damp protector, over coupling type, w/ channel for (left to right): 0.375" bare line, 0.250" bare line. Low carbon steel. 25.25" long. Total run: 80, see tubing tally for details. Cannon Tubina Standoff Mid -joint type, run above/below SSSV w/a channel, low carbon steel, 15" long. Total run: 2, see tubing tally for details. 3 1/a" x 1" Cameo KBMG GLM w/1" DMY 0 4800.42' MD 2.867" drift ID, 5.39" major OD (oval shaped) 4500 psi external & 6000 psi internal test pressure. BJ 3.5" CCIS Chemical Infection Sub 9b 4824.18' MD 13 Cr, 10K psi working pressure, 2.813" BJ X profile, 2.813" ID, 5.680" OD (eccentric), 37.5" long, double check valves to control line, w/ 6000 psi burst disc. Baker 3.5" alternate bore assv TC II 04841.21 'MD Baker Premier Packer 5.98"Odx 2.88" ID @ 4854.86'MD, center of packer element 2.4' from top of packer. 2.813" XN Niople w/ 2.75" No -Go 0 4880.24' MD r' - •� - � ire - �� Short Joint, 19.67' Iona, in 7" 0 5036.40' ML Snort Joint. b.i , ;—Q u, , (w b; 6, Au r.iL - 9k.5j.j back W)+l IZ? OD (V000' an.l :Q4AJ rt%3) +3 S83I r Halliburton EZ Drill Bridge Plug @ 6350' MD \ Weatherford Float Collar(& 6451.48' MD Float Shoe (Silver Bullet Eccentric) @ 6533 35' MD TD (M 6565' MD (6545' TVD) ConocoPhillips Conductor (Driven): 20-,.75". API 5L GRB, Full Grvd, R3 Driven to Refusal 91' Below Pad Grade Surface Casino: 9-5/8", 40#, L-80, BTCM Set @ 2851' MD (TD@ 2861' MD) Production Casina: 7",26.00#, L-80, BTC -Mod Set @ -6533' MD on Slips Tubina: 4-1/2" 12.6#, L-80 IBTM to 83.37' MD; 3-1/2", 9.3#, L-80, EUE 8RD-Mod from 84.9'MD to 4891.62' MD --- RA TAG in 7" CSG tD 3008.14' MD (9.78' punt Sterling A Sand 3286' MD / 3169' SSTVD - _- J Sterling B Sand 3465' MD / 3349' SSTVD Sterling C Sand 3616' MD / 3500' SSTVD RA TAG in 7" CSG (s 3506.84' MD (9.8' DUD) Beluga D Sand 3781' MD / 3664' SSTVD Beluga E Sand 4043' MD 13926' SSTVD Beluga F Sand 4371' MD / 4253' SSTVD Beluga G Sand 4794' MD 14677' SSTVD \ RA TAG in 7" CSG 0 4819.67' MD (9.76' DUD) Beluga H Sand 5098' MD / 4979' SSTVD Zone 6 Perfs @ 5187-5200' MD (13') Zone 5 Perfs @ 5411-5421 MD (10') Zone 4 Perfs @ 5500'-5506' MD (6) Zone 3 Perfs @ 5586'-5596' MD (10') Beluga I Sand 5772' MD 15655' SSTVD Zone 2 Perfs @ 5786-5794' MD (8'), -2818 psi 5818-5830' MD (12'), -2835 psi Zone 1 Perfs @ 6022-6036' MD (14'), -2995 psi Beluga I Base 6318' MD 16201' SS TVD Page 1 of 1 Schwartz, Guy L (DOA) From: Senden, R. Tyler [R.Tyler.Senden@conocophillips.com] Sent: Friday, July 20, 2012 9:13 AM To: Schwartz, Guy L (DOA) Subject: BRU 212-24T Frac Sundry Adder Guy, I'm not sure what data was missing from the original Sundry request but I believe the original cement job data wasn't included. 7" PRODUCTION CASING STRING 6/30/10: Make up BJ cement head. Estab circ pumping 7 bpm w/ 815 psi. With pumps on: PU wt 152k, SO wt 130k. Reciprocate 25' stroke from 6535' to 6510'. Held PJSM on cementing while circ & condition mud. Drop bottom plug, BJ pump 2 bbls of water, pressure test to 4500 psi. Load top plug. BJ pump 40 bbls Sealbound sweep (10.0 ppg, 38.1 bbls water), mix and pump 149.1 bbls 280 sx f 10.5 ppg class "G" cement w/ additives (2.99 cuft/sx, 12.354 gal/sx water, 4:16 hr ickening time), shut down/ shut in the head. Flush lines. Drop top plug, BJ pump 5 bbls water, the turn over to the rig. Recip 25' stroke continuous. Rig displace cement w/ rig pumps #1 and #2, pumping 6.75 bpm w/ 800 to 850 psi. Recip continuous until cement to the shoe. stopped recip f/ 5 minutes, then con't again until last 6 bbls. Slowed pumps down after 205 bbl of mud pumped to 3.84 bpm w/ 480 to 580 psi. Bumped plug with 242.23 bbls of 9.8 ppg mud at 1836 hrs w/ 1100 psi. Held press f/ 5 minutes. Bleed off to check floats. Floats not holding. Repressure to 1100 psi, bleed off, floats not holding. Repressure plugs to 1045 psi. Holding. Line up to attempt pressure test of casing to 4400 psi f/ 30 minute test. Bleed pressure down to 200 psi. BJ start pressure test, not holding. stop, shut in w/ 325 psi, monitor pressure and annulus while WOC. If we have accidentally omitted other data please don't hesitate to let me know. Thanks, Ty Senden ConocoPhillips Alaska, Inc. Wells Engineer ATO -2048 907-265-1544 (office) 907-982-3996 (cell) r.tyler.senden@conocophillips.com 7/23/2012 ConocoPhillips Alaska, Inc. September 20, 2010 Winton Aubert Reservoir Engineer SEP 2 7 2010 Alaska Oil & Gas Conservation C�om A ts►aliY�fllll�ission 333 W. 7th Ave., Ste. 100 �� Anchorage, Alaska 99501 Dear Mr. Aubert, Art E. Copoulos Senior Engineer 700 G Street, 99501 P.O. Box 100360 —Suite ATO 1412 Anchorage, Alaska 99510-0360 Phone (907) 263-4094 Cell (907) 575-8938 Fax (907) 265-1441 art.e.copoulos@conocophillips.com Enclosed is the gas well open flow potential report, form 10-421, for Beluga River Unit Well 212-24T. The well was completed in August, 2010. The absolute open flow potential for this well is estimated at 13200 mcf/d. The well is not completed with a gravel pack so only 3 test points were taken to minimize drawdown and the risk of formation collapse. Sincerely, Art Copoulos Cook Inlet Senior Engineer STATE OF ALASKA ALASKA _ AND GAS CONSERVATION COMMIS: GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1 a. Test: ✓ Initial Annual L Special 1 b. Type Test: Lj Stabilized L Non Stabilized ✓ Multipoint ❑ Constant Time ❑ Isochronal ❑ Other: 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: ConocoPhillips Alaska Inc. 8/5/2010 210-0500 3. Address: 6. Date TD Reached: 12, API Number: P.O. Box 100360 Anchorage, Alk 99501-0360 June 28, 2010 50- 283-20136-00-00 4a. Location of Well (Governmental Section): 7. KB Elevation above MSL (feet): 13. Well Name and Number: Surface: 2054' FNL & 144' FWL - Sec24, T13N, R10W, SM 96.5 feet BRU212-24T Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 1787' FNL & 98' FWL - Sec24, T13N, R10W, SM 5881 MD / 5861 TVD Beluga River Field Total Depth. Sterling - Beluga Gas Pool 9. Total Depth (MD + TVD): 1785' FNL & 97 'FWL - Sec24, T13N, R10W, SM 6565 MD / 6545 TVD 2.99 0.84 4b. Location of Well (State Base Plane Coordinates NAD 27): 10. Land Use Permit: 15. Property Designation: Surface: x- 323,481 y- 2,633,576 Zone 4 n/a ADL 21128 TPI: x- 323,751 y- 2,633,606 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 323,750 y- 2.633,605 Zone- 4 Cased, Cemented, and Perforated 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 7" 26 6.276 6535 open: 5786-5794 MD 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 3.5" 9.3 2.992 4893 5818-5830 MD 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 4855 n/a n/a 0.559 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d, Barometric Pressure (Pa): iZ Tubing ❑ Casing 102 F° 2850 psia @ Datum 5710 TVDSS 12.2 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO2: % N2: % H2S: Prover: Meter Run: Taps: 50' 5685' 0.565 0.298 0.348 0 Daniels Orifice 3.826' Flange 26. FLOW DATA TUBING DATA CASING DATA No. Prover Choke Line X Orifice Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow psig Hw F° psig F° psig F° Hr. Size (in.) Size (in.) 1. 3.826 X 2.75 75 56 70 1802 57 660 69 4 2 3.826 X 2.625 58 38 67 1909 57 700 66 4 3. 3.826 X 2.625 34 32 1 63 2002 57 680 64 4 4. X 5. X Basic Coefficient Pressure Flow Temp. Gravity Factor Super Comp. Rate of Flow No. (24 -Hour) hwPm Pm Factor F g Factor Q� Mcfd Fb or Fp Ft Fpv 1. 42.28 69.9 87.2 0.998 1.3 1.01 2165 2 37.54 51.6 70.2 0.998 1.3 1.01 3218 3. 37.54 38.4 46.2 0.998 1.3 1.01 1 4289 E. Form 10-421 RQ80MS SEP 2 8 201 INUED ON REVERSE SIDE Submit in Duplicate for Separator for Flowing Temperature No. Pr Tr z Gas Fluid T Gg G 1 1.63 530 2.99 0.84 2 1.63 527 2.99 0.84 3 1.63 523 2.99 0.84 Critical Pressure 673 673 4. Critical Temperature 342 342 5. Form 10-421 RQ80MS SEP 2 8 201 INUED ON REVERSE SIDE Submit in Duplicate Pc 2250 poz 5062500 P PfzI No. Pt Pte Pct -Piz PW Pv2 Pc2-Pv2 Ps Pse Pf2-Ps2 1. 1802 3247204 1815 1869 3493161 1569339 2. 1903 3621409 1441 1974 3896676 1165824 3. 2002 4008004 1054 2076 4309776 752724 4. 5. 25. AOF (Mcfd) 13200 Remarks: 3 points taken to minimize risk of sand production at varying rates. I hereby certi that the r goi is true and correct to the best of my knowledge. Signed Title 50%? AC DEFINITIONS OF SYMBOLS N Date AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= � dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back -pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 712009 Side 2 AOF determination 10000 1000 10000 100000 4, mcfd WCP* STATE OF ALASKA � NAD to ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas O SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August 5, 2010 N210-0500 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 June 14, 2010 "- 50-283-20136-00' 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2054' FNL, 144' FWL, Sec. 24, T13N, R10W, SM June 28, 2010 \ BRU 212-24T Top of Productive Horizon: 8. KB (ft above MSL): 97' RKB 15. Field/Pool(s): 1787' FNL, 98' FWL, Sec. 24, T13N, R10W, SM GL (ft above MSL): 78.7' AMSL Beluga River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1785' FNL, 97' FWL, Sec. 24, T13N, R10W, SM 5881' MD / 5861' TVD Sterling - Beluga Gas Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 323481 y- 2633576 Zone -4 6565' MD / 6545' TVD ADL 21128 11, SSSV Depth (MD + TVD): 17. Land Use Permit: TPI: x-323439 y- 2633843 Zone -4 Total Depth: x- 323438 - 2633845 Zone -4 494' MD / 494' TVD n/a 18. Directional Survey: Yes ❑✓ No❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) not applicable 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-drill/Lateral Top Window MD/TVD GR/Res not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT �- CEMENTING RECORD T CASING SIZE W. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 154# X-65 Surf. 109.5' Surf. 109.5' na driven to refusal 91' below pad 9.625" 40# L-80 Surf. 2851' Surf. 2832' 12.25" 948 sx 12.0 ppgLW Type 1 ' 7" 26# L-80 Surf. 6535' Surf. 6516' 8.75" 280 ....... Y ! .C.r; 4 'f.. 077 _ 0 J, 24. Open to production or injection? Yes O No ❑ If Yes, list each 25. TUBIW RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) FiACKLI*-§& fa &1VbT' "r,"(ggiOil 4.5" / 3.5" 83'/ 4893' 48as,.. MDit4835' TVD 5786'-5794' MD 5766'-5774' TVD 5818'-5830' MD 5798'-5810' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6022'-6036' MD 6002'-6016' TVD (perfs isolated with IBP DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED set @ 5994' MD-RKB) 5786'-5794', 5818'-5830' 61528# Carbolite 20/40 and 8768# Flexsand MSE 12/20 6022'-6036' 65000# Carbolite 20/40 and 9100# Flexsand MSE 12/20 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 18, 2010 flowback test from 7/18/2010 to 8/29/2010 Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO 9/7/2010 12 hours Test Period --> na 1.5 mmcf 2 bbls na na Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 1515 psi 308 psi 24 -Hour Rate -> na 3.0 mmscf/d 4 bbls na 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. _..� P NONE Q RSDMS SEP 13 10 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only N 28. GEOLOGIC MARKERS (List all formations and markers Cncountered): 29. FORMATION TESTS NAME MD TVD ground surface Well tested? ❑ Yes E] No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface Permafrost - Bottom na na needed, and submit detailed test information per 20 AAC 25.071. Sterling A 3286' 3267' Sterling B 3465' 3445' Sterling C 3616' 3596' Beluga D 3781' 3762' Beluga E 4043' 4023' Beluga F 4371' 4351' Beluga G 4794' 4774' Beluga H 5096' 5076' Beluga 1 5772' 5752' N/A Formation at total depth: Beluga 1 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 /-/# /AW"s I*Pm4s Printed Name G. Alvord Title: Alaska Drilling Manager Signature ALU _ Phone 265-6120 V(31", o Date 1107, Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 BRU 212-24T As -Run Completion Schematic (Final) Surface Location 2633335.24 N; 1463508.87 E (NAD83). DOYON ARCTIC FOX RKB HEIGHT: 97.17 ft 1/4" 316SS Control Line to SSSV Cad 493.61' MD 0.049" wall thickness 3/8" 316SS Control Line to CCIS Cad 4824.18' MD 0.049" wall thickness 3=/:" TRMAXX-5E SSSV Cad 493.61' MD 2.812 X Profile, 5.176" OD, 2.812" ID, 55" long. 3.5" 9.3# EUE special clearance Box X Pin. 5K psi working press. Stainless Steel Bands (on 4-%" tubing) Total Run: 5, see tubing tally for details. Cannon Cross Coupling Protectors Tubing clamp protector, over coupling type, w/ channel for (left to right): 0.375" bare line, 0.250" bare line. Low carbon steel. 25.25" long. Total run: 80, see tubing tally for details. Cannon ubina Standoff Mid -joint type, run above/below SSSV w/a channel, low carbon steel, 15" long. Total run: 2, see tubing tally for details. 3-1/V1 x 1" Camco KBMG GLM w/ 1" DMY 0 4800,42'M, 2.867" drift ID, 5.39" major OD (oval shaped), 4500 psi external & 6000 psi internal test pressure. BJ 3.5" CCIS Chemical Infection Sub a& 4824.18' MD 13 Cr, 10K psi working pressure, 2.813" BJ X profile, 2.813" ID, 5.680" OD (eccentric), 37.5" long, double check valves to control line, w/ 6000 psi burst disc. - Baker Premier Packer 5.98"Odx 2.88" ID Cad 4854.86 'MD center of packer element 2.4' from top of packer. Short Joint, 19.67' Iona. in 7' 0 5036.40' MD Halliburton EZ Drill Bridge Plug E& 6350' MD Weatherford Float Collar C) 6451.48' MD Float Shoe (Silver Bullet Eccentric) a- 6533.35' MD ConocoPhillips Conductor (Driven►: 20", .75", API 5L GRB, Full Grvd, R3 Driven to Refusal 91' Below Pad Grade Surface Casino: 9-5/8", 40#, L-80, BTCM Set @ 2851' MD (TD@ 2861' MD) Production Casino: 7", 26.00#, L-80, BTC -Mod Set @ -6533' MD on Slips Tubina: 4-1/2' 12.6#, L-80 IBTM to 83.37' MD; 3-1/2", 9.3#, L-80, EUE 8RD-Mod from 84.9'MD to 4891.62' MD RA TAG in 7" CSG (a) 3008.14' MD (9.78' pup) Beluga I Sand 5772' MD / 5655' SSTVD 5786-5794' MD (8'), -2818 psi 5818-5830' MD (12'), -2835 psi Beluga I Base 6318' MD / 6201' SS TVD PRODUCTION, 20-6,535 TO, 6.555 SAK BRU 212-24T ryt ConocoP t14li Well Attri4y es -- - - __ _.. _ _ _ Max Angle & MD TD . .�, Wellbore APUUWII Feld Name Well status Incl (°) MD (ftKB)Act Bt"' (ftKB) 502832013600 JBELUGA RIVER UNIT (PROD 10.08 I 1,411.20 6.565.0 C ent H2S (ppm) Date Annotation End Data KB Grd (it) Rig R ase Date SSSV. TRDP _ Last W0: I 18 50 7's 010 .- Annotation Depth(RID1) End Date AnnohNon Last Mod._ End Date Last Tag: I Rev Reason: NEW WELL Imosbor / 12:2010 _ ep- q�151a;.@R-2!...L72f�p1R4,13. bAM $tf�neLc_Afppi-�__ Casin Strin s Casing Description String 0... String ID ... Top (ftKB) SN Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Third CONDUCTOR 20 19.124 16.0 108.0 108.0 154.19 X-65 WELDED ---- Cuing Description String 0... String ID-._ Top (HKB) Sat Depth If SSR Depth (ND) String Wt... String _. String Top Third HANGER, 17 SURFACE 95/8 8.835 22.4 2,851.0 2,831.6 40.00 L-80 Casing Description String 0... String ID .. Top (NKB) Sat Depth If SN Depth (TVD) .. String Wt_. String ... String Top Thrd PRODUCTION 7 6.276 19.6 _6,535A 6,515.5 26 00 _ L-80 _ BTC -m - Tubing $trngs_ _ _ Sti9WStr .. Third Tubing Description Set4De9p2th.9(1Set D4epih g TUBING4.5x3." 31/2 2.990 17.0 ,8 ,8 .30 8g0 EUE-m 573 .0 Completion Details Top Depth To a (TVD) Top Incl Nom.. (ftKB) (") then Description Comment ID (in) 17.0 17.0 -0.01 HANGER Vetco Gray 4-1/2" hanger, 10.87" OD 3.95£ - 83.4 83.4 0.60 XO - Reducing Crossover 4-1/2" IBT-m x 3-12" EUE 2.99( ._ 493.6 _ -- ---- 4793_._102S 493.5 02 SAFETY VLV 3 12" Cameo- TRMAXX-SE SSSV wl 2 813" prof le 2.81: - ...7979_ 7979_-7979 4,803.8 0.53 COLLAR 3-112" EUE collar - 2.99: 4,T23) CONDUCTOR,- -_ 4,840.6 4,820.7 0.66 COLLAR 3-1/2" TC 11 collar 2.98( 16-1084,8412 4,8412 7979_____. ..... .7979_._ 4,821.3 0.66 PBR 312" Alternate Bore seal assembly TC II, P x P, 4.75' Polish Bare ID 4.75( 4,854.9 4,834.9 0.65 PACKER Baker Premier Packer 5.98" OD x 2.88" ID 2.88( sAI _Tr VLV. 4,859.8 0.63 COLLAR 3-12" EUE collar 7979- _ 2.99( 4,879.7 494 79..79. - -ITTOD Plug. 4,860.3 0.63 NIPPLE Campo "XN" NIPPLE OD 2.813" ID W 2.75" NoGo 8 RHC PI 2.75( 4,880.2 PxP ..7979-7979. ____.____. _- 4,871.7 0.62 WLEG WIRELINE ENTRY GUIDE CS" OD x 3" ID 3.10( 7979_ 4,891.6 Other In Hole(Wireline retrievable plugs, valves, pumps, fish etc. Top Depth (TVD) Top Incl ;i Top (ftKB) (RKB) (°) Description Comment Run Dale ID (in) 6,350 6,330.1 _ 0.42 PLUG !Bridge Plug - Permanent 7/32010 0.00( Notes: General & Safety End Data 79..79 Annotation NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE, 22.2,851 GAS UFT_-, _ 4,800 COLLAR, 4,824 CHEMICAL,__. 4,824 COLLAR, 4,841 - _d_ PBR,4,841 -.7979-.... PACKER, 4,865---- COLLAR, 4.880 - NIPPLE, 4,880 - WLEG, 4,892 j Mandrel Details +=i -- 'ToyDepth Top Pont(TVD) Incl OD V.I. Latch Ska TRO Run Sln Top.(ftKS) (ftKB) (") Make S_Yoda. (in) SType Type (in) (pen Run Date Cont ... 1 4,800.4 4,780.5 0.57 Camco KBMG 1 GAS LIFT DMY SK 0.000 0.0 7/42010 2 4,824.2 4,804.3 0.54 BJ 13 1 CHEM sOV 0.000 0.0 7/42010 PLUG, 6,950 -y -- PRODUCTION, 20-6,535 TO, 6.555 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: BRU 212-24T Rig Name: DOYON ARCTIC FOX Job Type: DRILLING ORIGINAL Rig Accept: 6/12/2010 2:00:00 PM Rig Release: 7/5/2010 9:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 6/12/2010 24 hr Summary Accept rig at 14:00. Lou Grimaldi with AOGCC witnessed diverter function test, OK. Fill pits with fresh water & mix spud mud. R/U pipe handling equipment & RIH with 1 jt 4" DP to M/U stand. Encounter fill & attempt to clean out to 60'. Diverter knife valve leaking. Repair with gel and plastic, change out ring gasket. Wash down to 60'. Resume P/U & standing back 104 jts of 4" DP. 14:00 19:00 5.00 0 0 SURFA( DRILL RURD P Accept rig at 14:00. P/U & R/U tongs, spinner, elevator, and slips. Fill mud pits with water and begin mixing spud mud. 19:00 20:30 1.50 0 0 SURFA( DRILL PULD P P/U mouse hole & cut hole in cellar grate. P/U & RIH 1 jt of 4" DP to M/U stand. Encounter hole fill at 26.5'. 20:30 21:30 1.00 0 0 SURFA( DRILL FCO P Prepare 70 bbls fresh water pill to wash down two joints of DP. Trouble shoot mud pump #1. Fill hole with fresh water. Knife valve on diverter leakingfluid into containment. 21:30 23:45 2.25 0 0 SURFA( WHDBO NUND T N/D diverter line & place gel around knife valve. N/U same. Fill riser with fresh water. Knife valve leaking. 23:45 00:00 0.25 0 0 SURFA( WHDBO NUND T N/D diverter line & knife valve to repair leak. 6/13/2010 Repair diverter knife valve. P/U & stand back 104 jts 4" DP & 20 jts 5" HWDP. Calibrate Totco & Sperry Sun equipment. P/U & M/U cleanout BHA, wait on 8" DC slips. Test mud lines to 3000 psi, OK. Hold pre-spud with drilling crew & service hands. Continue M/U cleanout BHA & RIH to 60'. 00:00 02:00 2.00 0 0 SURFA( WHDBO BOPE P Apply gel and plastic to diverter knife valve. Replace ring gasket in knife valve flange and N/U same. Continue ud mud. 02:00 02:45 0.75 0 0 SURFA( DRILL WASH —mixings P Wash down two joints of 4" open ended drill pipe at 5.5 BPM with 20 psi. No leaks in diverter system. 02:45 03:00 0.25 0 0 SURFA( DRILL PRTS P Attempt to test surface mud lines to 3000 psi. Casing test pump used for pressure test will not function. Attempt to trouble shoot, decide to test later. 03:00 08:00 5.00 0 0 SURFA( DRILL PULD P Drain diverter. Resume P/U 104 jts of 4" drill pipe & standing back. Drop 2.313" drift and strap pipe. 08:00 11:00 3.00 0 0 SURFA( DRILL PULD P C/O elevators & P/U 20 jts of 5" HWDP. Drop 2.688" drift and strap pipe. 11:00 12:00 1.00 0 0 SURFA( DRILL EQRP P Calibrate Totco & Sperry Sun block hei ht & de th. 12:00 12:30 0.50 0 0 SURFA( DRILL PULD P P/U cleanout BHA as per DD. Page 1 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:30 14:00 1.50 0 0 SURFA( DRILL EQRP P C/O draw works encoder for Totco & calibrate. 14:00 16:00 2.00 0 0 SURFA( DRILL PULD P Resume P/U cleanout BHA as per DD. M/U 12-1/4" bit and PDM. Need 8" DC slips to continue. Will be flown over once Weatherford delivers to S erniak. 16:00 18:00 2.00 0 0 SURFA( DRILL PULD T Wait on 8" DC slips. Recalibrate Totco, clean & clear rig floor. 18:00 20:00 2.00 0 0 SURFA( DRILL PRTS T R/U test pump to pressure test mud lines. Unable to start test pump, troubleshoot. 20:00 21:00 1.00 0 0 SURFA( DRILL PRTS P Pressure test mud lines against mud pumps #1 & #2 to 3000 psi & hold for 5 min, OK. Test against mud pump #3, leak off at 1500 psi. 21:00 21:30 0.50 0 0 SURFA( RIGMNT RGRP P Grease washpipe. C/O standpipe bleeder valve. Valve will not open. 21:30 22:00 0.50 0 0 SURFA( DRILL SFTY P Pre-spud/pre-job safety meeting in doghouse. Discuss operations, hazards, prevention, & diverter operations. 22:00 22:30 0.50 0 0 SURFA( DRILL RURD P R/U MWD monitor on drillers console. 22:30 00:00 1.50 0 0 SURFA( DRILL TRIP P M/U & RIH 12-1/4" conductor cleanout assembly. 12-1/4" bit, 8" PDM, float sub, stabilizer, X/O, HWDP. Function test Crown-O-Matic, OK. 6/14/2010 Clean out 20" conductor & spud well at 01:00. Drill 12-1/4" hole to 222.5' for BHA M/U then POOH. While M/U BHA #1, encounter fill at 78.5'. L/D BHA & clean out hole to 222.5'. M/U BHA #1 & drill 12-1/4" to tanned wiper trip depth of 826.2'. Circulate 1.5 BU. 00:00 01:00 1.00 0 0 SURFA( DRILL WASH P RIH with 12-1/4" conductor cleanout BHA & tag fill at 60'. Wash & rotate down to conductor shoe at 109'.5. 01:00 01:30 0.50 0 223 SURFA( DRILL DDRL P Drill T/ 222.5' to allow for BHA #1 M/U. 400 GPM, 40 RPM, 10-15 WOB, 1 k ft-lbs, & 400 SPP. 01:30 02:15 0.75 223 0 SURFA( DRILL TRIP P POOH F/ 222.5'. Standback 3 stands HWDP. 02:15 05:15 3.00 0 79 SURFA( DRILL PULD P M/U BHA #1. DM, DGR, EWR, HCIM, EM. Orient motor as per DD. 05:15 05:45 0.50 79 79 SURFA( DRILL TRIP T While M/U BHA, tag soft fill at 78.56'. Rotate & attempt to work down. Unable to pass. Discuss with DD & MWD for options to L/D BHA. 05:45 08:30 2.75 79 40 SURFA( DRILL PULD T POOH & L/D BHA #1 to 40.3'. 08:30 09:30 1.00 40 223 SURFA( DRILL REAM T M/U 5" HWDP & RIH to 78.5' Tag fill, wash & ream to bottom at 222.5. 400 GPM, 40 RPM, 10-15 WOB, 1k ft-lbs, 310 SPP. 09:30 10:00 0.50 223 40 SURFA( DRILL TRIP T POOH & stand back 3 stands HWDP. Hole pulled tight at 115'. Washed & reamed through. Page 2 of 28 lime Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:00 11:30 1.50 40 104 SURFA( DRILL PULD T Cont. M/U BHA #1. DM, DGR, EWR, HCIM, EM, & antenna sub. Orient motor as per DD. 11:30 13:30 2.00 104 104 SURFA( DRILL PULD P Upload MWD & test, OK 13:30 15:00 1.50 104 196 SURFA( DRILL PULD P M/U remainder of BHA #1 including flex drill collars & RIH to 196.1'. 15:00 15:15 0.25 196 223 SURFA( DRILL REAM P Wash and Ream to 222.5' MD 15:15 18:00 2.75 223 379 SURFA( DRILL DDRL P Drill 12-1/4" surface hole to 379'. 450 GPM, 50 RPM, 10 WOB, 2k ft -lbs, & 610 SPP. P/U 45k, S/O 45k, ROT 45k. 18:00 23:30 5.50 379 826 SURFA( DRILL DDRL P Cont. drill 12-1/4" surface hole to 826.2', planned wiper trip depth. 532 GPM, 90 RPM, 5-7 WOB, 2k ft -lbs on bottom, 1.5k ft -lbs off, & 920 SPP. P/U 65k, S/O 63k, ROT 63k. Backream each stand before connection. 23:30 00:00 0.50 826 826 SURFA( DRILL CIRC P Circulate 1.5 BU with 532 gpm, 840 psi. Reci rocate & rotate pipe. 6/15/2010 POOH for planned wiper trip F/ 862.2'T/ 192.1'. C/O saver sub & RIH back to bottom. Drill F/ 862.2'T/ 1901'. Circulate 1.5 BU & POOH for planned wiper rip to 829.3'. 00:00 02:00 2.00 826 196 SURFA( DRILL WPRT P POOH for planned wiper trip on elevators to 196.1' Monitor hole on trip tank. Work through tight spot at 678' with 10k O/P. 02:00 02:30 0.50 196 196 SURFA( DRILL SFTY P Post job review of POOH & pre job for C/O saver sub to HT 38. 02:30 04:00 1.50 196 196 SURFA( RIGMNT EQRP P C/O saver sub from 4-1/2" IF to HT 38. 04:00 05:00 1.00 196 196 SURFA( RIGMNT RGRP P Inspect derrick pins. Replace keepers. Grease washpipe & top drive. Clean rig floor. 05:00 05:15 0.25 196 196 SURFA( DRILL SFTY P PJSM on RIH. Focus on body position and operating i e spinner. 05:15 07:00 1.75 196 826 SURFA( DRILL WPRT P TIH F/ 196.1 T/ 826.2'. Monitor hole on trip tank 07:00 18:00 11.00 826 1,555 SURFA( DRILL DDRL P Drill F/ 826.2'T/ 1555'. 550 GPM, 100 RPM, 10-15 WOB, 4k ft -lbs, & 1450 SPP. P/U 78k, S/O 75k, & ROT 77k. Bit & Jar hours - 13.01, AST - 5.94, ART - 9.95, & ADT - 15.89. Backream each stand rotated & double backream on slides. 18:00 23:00 5.00 1,555 1,901 SURFA( DRILL DDRL P Drill F/ 1555 to planned wiper trip depth of 1901'. 590 GPM, 100 RPM, 10-15 WOB, 4k ft -lbs, & 1630 SPP. P/U 85k, S/O 75k, & ROT 80k. Bit & Jar hours - 14.45 AST - 0.52, ART - 2.84, & ADT - 3.34 23:00 23:30 0.50 1,901 1,901 SURFA( DRILL CIRC P Circulate 1.5 BU. Reciprocate & rotate. 550 GPM & 1480 SPP. 23:30 23:45 0.25 1,901 1,901 SURFA( DRILL OWFF P Watch well for flow, OK. R/U pipe s inner. Page 3 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 1,901 1,840 SURFA( DRILL WPRT P Begin POOH on elevators to HWDP for planned wiper trip. Monitor hole on trip tank. 6/16/2010 Wiper trip F/ 1901'T/ 862.2'. DDRL to TD of 2861' MD, 2841' TVD. Circulate 2 BU & POOH for planned wiper tri T/ 1901. 00:00 01:15 1.25 1,840 862 SURFA( DRILL WPRT P Cont. POOH on elevators F/ 1901' T/ 862.2' for planned wiper trip. Monitor hole on trip tank. 01:15 01:30 0.25 862 862 SURFA( DRILL RURD P R/U to TIH, clean rig floor, & clean suction screens on mud pumps. 01:30 03:00 1.50 862 1,901 SURFA( DRILL WPRT P TIH F/ 862.2 T/ 1901'. Monitor hole on trip tank. 03:00 06:00 3.00 1,901 2,085 SURFA( DRILL DDRL P Drill F/ 1901'T/ 2085'. 595 GPM, 100 RPM, 10-15 WOB, 4k ft -lbs, & 1800 SPP. P/U 90k, S/O 80k, & ROT 87k. Bit & Jar hours - 16.3, AST - 0. 18, ART - 1.70, & ADT - 1.88. Backream each stand rotated & double backream on slides. 06:00 18:00 12.00 2,085 2,779 SURFA( DRILL DDRL P Drill F/ 2085'T/ 2779'. 593 GPM, 100 RPM, 10-15 WOB, 4.5k ft -lbs, & 2160 SPP. P/U 100k, S/O 88k, & ROT 92k. Bit & Jar hours - 24.47, AST - 1.91, ART - 6.63, & ADT - 8.14. 18:00 21:00 3.00 2,779 2,861 SURFA( DRILL DDRL P Drill F/ 2779' to TD of 2861' picked by Geologist Rick Levinson. 600 GPM, 100 RPM, 10-15 WOB, 3.5k ft -lbs, & 2080 SPP. P/U 100k, S/O 92k, & ROT 88k. Bit & Jar hours - 26.26, AST - 0.82, ART - 0.97, & ADT - 1.79. 21:00 22:00 1.00 2,861 2,861 SURFA( DRILL CIRC P Circulate 2 BU. Reciprocate & rotate pipe. 585 GPM & 2080 psi. 22:00 22:15 0.25 2,861 2,861 SURFA( DRILL OWFF P Watch well for flow, OK. R/U pipe spinner. UD single of DP used to reciprocate pipe. 22:15 23:45 1.50 2,861 1,901 SURFA( DRILL WPRT P POOH on elevators to 1901' for planned wiper trip. Work tight spot 2705' Monitor hole on trip tank. 23:45 00:00 0.25 1,901 1,901 SURFA( DRILL RURD P R/U to TIH, clean & clear rig floor. 6/17/2010 RIH F/ 1901' to TD of 2861' to complete wiper trip. Circulate 2 BU & POOH on elevators. Dummy run 9-5/8" casing hanger. R/U Weatherford pipe handling equipment. M/U 9-5/8" surface casing shoe track & RIH. Midni ht depth of 1200'. 00:00 01:30 1.50 1,901 2,861 SURFA( DRILL WPRT P RIH F/ 1901'T/ 2861'. Wash down last stand. Monitor hole on trip tank. 01:30 02:30 1.00 2,861 2,861 SURFA( DRILL CIRC P Circulate 2 BU. Reciprocate & rotate pipe. 605 GPM & 2150 psi. 02:30 02:45 0.25 2,861 2,861 SURFA( DRILL OWFF P Watch well for flow, OK. R/U pipe spinner. UD single of DP used to reciprocate pipe. 02:45 09:00 6.25 2,861 100 SURFA( DRILL TRIP P POOH on elevators. Stand back HWDP & UD BHA #1. Record 3 check shots at 2812', 2795', & 1910'. Monitor hole on trip tank. Page 4 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 10:00 1.00 100 100 SURFA( DRILL PULD P Download MWD. 10:00 12:30 2.50 100 0 SURFA( DRILL PULD P UD remaining BHA #1. Bit Grade: 1 -1 -WT -A -E -1 -NO -TD. Clean & clear rig floor. 12:30 16:00 3.50 0 0 SURFA( CASING RURD P R/U Weatherford 9-5/8" casing handling equipment. Install long bales and side door elevators. 16:00 18:00 2.00 0 0 SURFA( CASING PULD P M/U casing hanger to landing joint as per Vetco Gray & dummy run. 18:00 18:45 0.75 0 0 SURFA( CASING SFTY P Crew change. PJSM with Weatherford . Discuss procedures for M/U & running casing along with associated hazards. 18:45 19:15 0.50 0 0 SURFA( CASING PULD P P/U casing pup joint & circulating swage. Finish R/U Weatherford tongs. 19:15 00:00 4.75 0 1,200 SURFA( CASING RNCS P M/U 9-5/8" shoe track as per procedure: Silver Bullet float shoe, 2 threadlock jts, float collar, backer-loc jt. Check floats, OK. M/U 9-5/8" casing & RIH. Midnight depth - 1200'. 6/18/2010 Cont. RIH 9-5/8" surface casing & land shoe at 2851.2'. Circulate & condition mud. R/U & pump 353 bbls Type I cement. Return 138 bbls to surface. N/D bell ipple, annular, knife valve, diverter line, & riser. 00:00 01:30 1.50 1,200 1,755 SURFA( CASING RNCS P Cont. run 9-5/8" surface casing to 1755' MD. 01:30 02:30 1.00 1,755 1,755 SURFA( CASING CIRC P R/U circulating swage & lines. Break circulation with 127 GPM & 200 psi. Circulate 1 BU. R/D circulating equipment. 02:30 05:00 2.50 1,755 2,851 SURFA( CASING RNCS P Cont. run 9-5/8" surface casing to TD. P/U casing hanger & land shoe at 2851.2'. P/U 163k & S/O 73k. 05:00 05:30 0.50 2,851 2,851 SURFA( CEMEN" RURD P R/D Weatherford pipe handling tools & R/U BJ cementing head. 05:30 08:15 2.75 2,851 2,851 SURFA( CEMEN" CIRC P Circulate & condition mud. Pump at 3 BPM with 350 psi & increase to 8 BPM with 480 psi. Reciprocate pipe. Mud properties of PV 14 & YP 23 08:15 09:00 0.75 2,851 2,851 SURFA( CEMEN" SFTY P PJSM on cementing procedure & handling of cement returns. Identified hazards associated with each process. 09:00 09:45 0.75 2,851 2,851 SURFA( CEMEN' CMNT P Mix & pump 40 bbls of viscosified water sweep with nut plug. Next mix & pump 24 bbls mud clean with red dye. Drop wiper plug. 09:45 10:00 0.25 2,851 2,851 SURFA( CEMEN" PRTS P BJ pump 2 bbls water and pressure test lines to 3000 psi. Page 5 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 2,851 2,851 SURFA( CASING CMNT P Load displacement plug into cementing head. Mix & pump 353 bbls Type 112 ppg cement. Pump cement at 6.7 BPM with 300 psi. Drop top plug & displace with rig pump at 6 BPM slowing to 3 BPM with 720 psi. Cement to surface at 1675 strokes, returned 138 bbls. Did not bump plug with 4454 strokes (displacement 4386 strokes). Bleed pressure & check floats, OK. Cement in place at 11:30. 12:00 18:00 6.00 2,851 2,851 SURFA( CEMEN' RURD P PJSM for R/D casing bales. Clear & clean rig floor. R/D casing elevators & bales. Blow down cement lines & mud lines. UD hanger running tool & landing joint. Organize cellar area in preparation to N/D diverter system. N/D splash pan & bell nipple. Begin pits. 18:00 18:30 0.50 2,851 2,851 SURFA( WHDBO SFTY —cleaningmud P PJSM on N/D diverter system. 18:30 19:30 1.00 2,851 2,851 SURFA( WHDBO OTHR P Flush & clean diverter equipment. 19:30 22:30 3.00 2,851 2,851 SURFA( WHDBO NUND P N/D annular preventer & knife valve. Back out lock down screws in riser. Unable to pull free with 15k. Begin R/D diverter line. 22:30 23:00 0.50 2,851 2,851 SURFA( WHDBO NUND T Overpull on riser to 15k & hold, no success. O/P to 17k & hold, no success. Check test seals, de -energize. Pull to 15k & hold, riser free. 23:00 00:00 1.00 2,851 2,851 SURFA( WHDBO NUND P UD riser & begin to N/D starter head. 6/19/2010 Finish N/D starter head from conductor. N/U wellhead & test to 5000 psi, fail. N/D wellhead & replace test ring seals. N/U same & test to 5000 psi, OK. N/U BOP stack & kill/choke lines. 00:00 00:30 0.50 2,851 2,851 SURFA( WHDBO NUND T Cont. N/D starter head. Back out lock down screws. Overpull to 15k & hold, no success. O/P to 20k & hold, no success. Drop out internal slips & ull free. Remove starter head. 00:30 02:30 2.00 2,851 2,851 SURFA( WHDBO NUND P Clean threads on casing hanger pin & M/U flange adaptor. P/U multibowl wellhead & orient. Test VG seal to 5000 psi, fail. 02:30 05:30 3.00 2,851 2,851 SURFA( WHDBO NUND T N/D wellhead & replace test seals. N/U wellhead & pressure test to 5000 psi for 10 min, OK. 05:30 06:00 0.50 2,851 2,851 SURFA( WHDBO NUND P Prepare equipment to N/U BOPE. 06:00 18:00 12.00 2,851 2,851 SURFA( WHDBO NUND P PJSM on N/U BOPE. Assemble & orient BOPE on wellhead. Turn inner annulus sweep on wellhead one bolt hole to allow for valve installation. Assemble & N/U bell nipple. Hook up flare line. Begin mixing 650 bbls of 6% KCI mud. Page 6 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 19:00 1.00 2,851 2,851 SURFA( WHDBO NUND P C/O ram configuration to 2-7/8" X 5" VBR in top ram & 4" DP in lower. 19:00 00:00 5.00 2,851 2,851 SURFA( WHDBO NUND P N/U kill and choke lines. Remove I-beam in cellar to allow for installation of kill line. 6/20/2010 N/U BOPE. Lou Grimaldi AOGCC Petroleum Inspector on site to witness BOPE tests. Test, repair & retest equip ment. BOPE test complete by 00:00. 00:00 02:30 2.50 2,851 2,851 SURFA( WHDBO NUND P Connect BOPE control lines. P/U & M/U full opening safety valve & dart valve on test joint with test plug. Set test plu in wellhead. 02:30 03:15 0.75 2,851 2,851 SURFA( WHDBO BOPE T Function test rams & annular. All functioning opposite direction of controls. Switch control lines. 03:15 05:30 2.25 2,851 2,851 SURFA( WHDBO BOPE T Function test rams & annular. Annular not operating. Trouble shoot. 05:30 06:00 0.50 2,851 2,851 SURFA( WHDBO BOPE P Function test Koomey. Fill stack with water. 06:00 18:00 12.00 2,851 2,851 SURFA( WHDBO BOPE P PJSM on BOPE testing. R/U BOP test pump. Pump water through choke & line for test #1. Lou Grimaldi, AOGCC Petroleum Inspector to witness tests. Test annular to 250 psi low & 3500 psi high for 5 min each, fail at low test 250 psi (retest later). Fix door seal on bottom rams. The following tests are conducted at 250 psi low & 4500 psi high for 5 min each. Test #2: top pipe rams (VBR), valve 5, 9, 14. Test #3: 4, 8, 1, kill line. Test #4: 3, 7, 13, manual kill (fix door seal on blind rams). Test #5: 2, 6, 12, manual kill. Retest #4 listed above. Test #6: Top pipe, 11, manual kill. 18:00 18:15 0.25 2,851 2,851 SURFA( WHDBO SFTY P PJSM with night crew on testing BOPE. 18:15 18:30 0.25 2,851 2,851 SURFA( WHDBO BOPE T Test #8: HCR choke, fail. Grease valve for retest. 18:30 20:30 2.00 2,851 2,851 SURFA( WHDBO BOPE P Test #9: full opening safety valve & dart valve. Retest #8: lower pipe rams (4" DP), upper pipe rams (VBR), manual kill, & HCR choke. Test #9: annular 250 psi low & 3500 psi high for 5 min each. 20:30 20:45 0.25 2,851 2,851 SURFA( WHDBO BOPE P Test accumulator drawdown. Start at 3000 psi, draw down to 1725 psi & build to 1925 psi in 24 seconds. Full pressure recovery in 160 seconds. 20:45 21:45 1.00 2,851 2,851 SURFA( WHDBO BOPE P Line up & test blind rams to 250 psi low & 4500 psi high for 5 min each. Line up to test IBOP & lower kelly valve. 21:45 23:30 1.75 2,851 2,851 SURFA( RIGMNi RGRP T Unable operate top drive. Trouble shoot electronic drive fault. Reset system. Page 7 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:30 00:00 0.50 2,851 2,851 SURFA( WHDBO BOPE P Test #10: IBOP & lower kelly valve to 250 psi low & 4500 psi high for 5 min each. BOPE test complete. 06/21/2010 R/D BOPE test equipment. Install wear bushing. P/U & stand back 32 jts DP. Cleanout flow line. P/U & M/U 8-3/4" production hole BHA. RIH BHA #2 on 4" DP from pipe shed. 00:00 01:30 1.50 2,851 2,851 SURFA( WHDBO RURD P R/D BOPE test equipment. Blow down choke/kill lines & manifold. Clean & clear rig floor. 01:30 02:45 1.25 2,851 2,851 SURFA( DRILL PULD P P/U & M/U wear bushing. Install same. P/U & install mouse hole. R/U tongs & elevators. 02:45 04:00 1.25 2,851 2,851 SURFA( DRILL PULD P PJSM for P/U DP. P/U & single in hole 32 jts 4" DP. 04:00 06:00 2.00 2,851 2,851 SURFA( DRILL PULD T After running in 18 jts of 4" DP, mud would not flow into the flow line. With investigation, flowline blocked by cement & clay. Clean out flowline with super sucker then R/D to ensure no further blockage. 06:00 08:30 2.50 2,851 2,851 SURFA( DRILL PULD P PJSM with day crew on P/U DP. Clean shakers for RIH. P/U & single in hole remaining 14 of 32 jts 4" DP. 08:30 10:00 1.50 2,851 2,851 SURFA( DRILL CIRC P Circulate out old mud F/ 1009' MD in preparation for BHA #2 M/U. 10:00 11:30 1.50 2,851 2,851 SURFA( DRILL TRIP P POOH & stand back 32 jts of 4" DP. 11:30 15:30 4.00 2,851 2,851 SURFA( DRILL PULD P PJSM on M/U BHA#2. P/U & M/U 8-3/4" pendulum as per Sperry Sun. RIH to 143' to upload MWD. 15:30 17:30 2.00 2,851 2,851 SURFA( DRILL PULD P Plug in & upload MWD 17:30 18:00 0.50 2,851 2,851 SURFA( DRILL PULD P P/U & M/U EM collar, index sub, antenna, & bat sonic. Prepare ports for source loading. 18:00 20:00 2.00 2,851 2,851 SURFA( DRILL PULD P PJSM on P/U & M/U BHA with night crew. Load sources. 20:00 21:00 1.00 2,851 2,851 SURFA( DRILL TRIP P RIH 10 stands of 5" HWDP & drilling 'ars. 21:00 23:45 2.75 2,851 2,851 SURFA( DRILL TRIP P P/U & single 4" DP into hole F/ 942' T/ 2702'. 23:45 00:00 0.25 2,851 2,851 SURFA( DRILL CIRC P Circulate & condition mud for casing test. 252 GPM with 550 psi. 6/22/2010 Attempt to pressure test casing with casing pump. Unable to pressure up, valves & seats washed out. Wait on BJ Service pump operators. Pressure test casing to 3000 psi, OK. Wash down & drill out shoe track. Drill 20' new formation & displace sud mud to 6% KCI KlaShield. 00:00 00:45 0.75 2,851 2,851 SURFA( DRILL CIRC P Cont. circulate & condition mud at 2705' MD. Pump at 340 GPM with 990 psi. 00:45 01:30 0.75 2,851 2,851 SURFA( DRILL RURD P R/U & line up casing test pump for 9-5/8" 3000 psi test. Page 8 of 28 Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment 01:30 03:30 2.00 2,851 2,851 SURFA( DRILL PRTS T Pressure up on casing down DP & kill line. Unable to pressure up past 1080 psi. Pressure test surface lines, will not exceed 550 psi. Discovered valves & seats to be washed out. No repair parts. Notify BJ Services at 03:30 to mobilize operators for cement unit on location. Will arrive on location at 07:00. 03:30 06:00 2.50 2,851 2,851 SURFA( DRILL PULD T Wait on BJ Service pump operators. Load pipe shed with 7" casing. Perform kick while tripping drill. Hold table top stripping in hole drill. 06:00 08:30 2.50 2,851 2,851 SURFA( DRILL PULD T Cont. working on 7" casing in pipe shed. Perform table top spill drill. Focus on materials & tools required. BJ Services arrive on location at 07:00 & begin rigging up. 08:30 09:30 1.00 2,851 2,851 SURFA( DRILL RURD T R/U head pin on DP w/ low torque to pressure test casing. Clear & clean rig floor. General housekeeping. BJ Services chart test truck. 09:30 10:00 0.50 2,851 2,851 SURFA( DRILL SFTY T PJSM with BJ Services on procedures & hazards with pressure testing casing. 10:00 12:00 2.00 2,851 2,851 SURFA( DRILL PRTS P Fill BJ lines & test to 3500 psi. Perform 9-5/8" casing pressure test to 3000 psi, OK. R/D test e ui ment. 12:00 12:45 0.75 2,851 2,851 SURFA( DRILL WASH P Wash in hole F/ 2656' MD to float collar at 2768' MD. 12:45 17:30 4.75 2,851 2,851 SURFA( CEMEN" DRLG P Drill out shoe track & rat hole: F/ 2768'T/ 2861'. 350 GPM, SPP 950, 2k WOB, & 50 RPM, 17:30 19:45 2.25 2,861 2,877 SURFA( DRILL DDRL P Drill 8-3/4" production hole F/ 2861' MD T/ 2877' MD. 315 GPM, SPP on bottom 980, SPP off bottom 840, WOB 15K, 5-6k ft -lbs, 70 RPM. P/U 105, S/O 85, & R/T 95. Bit hrs: 1.65, Jar hrs: 27.91, ART/ADT: 1.65. 19:45 20:15 0.50 2,877 2,877 SURFA( DRILL OTHR P Investigate out of balance mud. Clean out mud pit trough, thick contaminated spud mud overflowing into KlaShield mud. 20:15 20:45 0.50 2,877 2,877 SURFA( RIGMNT RGRP T Unable to start motor for drawworks. Trouble shoot. 20:45 21:15 0.50 2,877 2,879 SURFA( DRILL DDRL P Drill F/ 2877'T/ 2878.5'. Unable to keep spud mud from contaminating KlaShield in pits due to overflow from trou hs. 21:15 21:30 0.25 2,879 2,879 SURFA( DRILL SFTY P PJSM for displacing mud. Focus on fluid transfers & identifing leak points. 21:30 23:00 1.50 2,879 2,879 SURFA( DRILL CIRC P Displace hole to 9.6 ppg KlaShield 6% KCI. Pump at 256 GPM with 424 psi. Page 9 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:30 0.50 2,881 2,881 SURFA( DRILL DDRL P Cont drill 20' of new formation T/ 2881' MD. Circulate BU at 472 GPM with 1237 psi. 23:30 00:00 0.50 2,881 2,881 SURFA( DRILL RURD P Pull bit into casing for FIT & rack back stand. R/U testin a ui ment. 6/23/2010 Perform FIT to 16 EMW. Drill 8-3/4" hole F/ 2881' MD T/ 3881' MD. Circulate BU. Wiper trip to planned depth of 2881' MD. 00:00 01:45 1.75 2,881 2,881 SURFA( DRILL FIT P PJSM on procedure & hazards for a FIT. Fill BJ lines & test to 1500 psi. Pressure up the annulus & DP to 940 psi (EMW = 16 ppg) with 9.6 ppg mud, shut in. Pressure decreased to 811 psi after 10 min. R/D test equipment. Blow down lines. 01:45 06:00 4.25 2,881 2,992 PROD1 DRILL DDRL P Drill 8-3/4" production hole F/ 2881' MD T/ 2992' MD. 455 GPM, SPP on bottom 1200, SPP off bottom 900, WOB 8-10K, 2-3k ft -lbs, 70 RPM. P/U 100, S/O 88, & R/T 95. Bit hrs: 4.94, Jar hrs: 31.22, ART: 0.53 ADT: 2.77. 06:00 18:00 12.00 2,992 3,598 PROD1 DRILL DDRL P Drill 8-3/4" production hole F/ 2992' MD T/ 3598' MD. 575 GPM, SPP on bottom 1130, SPP off bottom 970, WOB 5-15k, torque on 3-5k ft -lbs, torque off 3k ft-Ilbs, 120 RPM. Bit hrs: 12.00, Jar hrs: 39.07, ART: 5.06 AST: 2.79, ADT: 7.85. 18:00 22:15 4.25 3,598 3,881 PROW DRILL DDRL P Drill 8-3/4" production hole F/ 3598' MD T/ 3881' MD. 575 GPM, SPP on bottom 1340, SPP off bottom 1110, WOB 2-5k, torque on 2-4k ft -lbs, torque off 3k ft -lbs, 120 RPM. P/U 112k, S/O 100k, & R/T 105k. Bit hrs: 15.66 Jar hrs: 41.94, AST: 0, ART: 2.82 ADT: 2.82. Max gas observed: 1129 units at 3759' MD - 3770' MD. 22:15 22:45 0.50 3,881 3,881 PROW DRILL CIRC P Circulate BU. Reciprocate & rotate pipe. 450 GPM & 1240 psi. 22:45 23:45 1.00 3,881 3,881 PROD1 DRILL WPRT P Wiper trip to 2861' MD. BROOH 4 stands. Pump at 450 GPM & 1240 psi. Torque off bottom: 3k ft -lbs. P/U 110k & S/O 98k. 23:45 00:00 0.25 3,881 3,881 PROW DRILL OWFF P Monitor hole. R/U pipe spinner to continue wiper trip on elevators to 2861' MD. 6/24/2010 Wiper trip to 2861' MD. Cut & slip drill line. RIH to bottom 3881' MD. Unable to communicate with MWD/LWD equipment, HCIM battery failure. POOH & L/D BHA. C/O HCIM & M/U BHA #3. 00:00 01:15 1.25 3,881 3,881 PROD1 DRILL WPRT P POOH 12 additional stands on elevators. 15k O/P at 3620' MD & 3560' MD. Monitor hole on trip tank. Hole losing 2 BPH. Pump at 450 GPM & 1240 psi. Torque off bottom: 3k ft -lbs. P/U 110k & S/O 98k. Page 10 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:15 03:15 2.00 3,881 3,881 PROW RIGMNT SLPC P PJSM for slip & cut drill line. Cut 86', 16 wraps. Slip same. Service top drive & traveling equipment. Monitor hole on trip tank. Lose 2.5 BPH. 03:15 05:00 1.75 3,881 3,881 PROD1 RIGMNT RGRP T Unable to start drawworks motor. Water in air line for starter. 05:00 06:30 1.50 3,881 3,881 PROW DRILL TRIP P TIH F/ 2861' MD T/ 3881' MD. Monitor hole on trip tank. 06:30 07:30 1.00 3,881 3,881 PROD1 DRILL CIRC T Unable to communicate with LWD. HCIM battery appears to have failed. Circulate hole clean. Max gas observed 193 units. 07:30 13:30 6.00 3,881 3,881 PROD1 DRILL TRIP T POOH on elevators F/ 3881' MD T/ 165' MD. 13:30 14:30 1.00 3,881 3,881 PROD1 DRILL PULD T PJSM for pulling sources. Pull & L/D same. 14:30 16:30 2.00 3,881 3,881 PROD1 DRILL PULD T Download MWD. 16:30 18:30 2.00 3,881 3,881 PROD1 DRILL PULD T L/D BHA #2 to stablizer. Inspect bit & motor bearings, OK. 18:30 21:15 2.75 3,881 3,881 PROD1 DRILL PULD T Prepare EM batteries & probes. Unable to communicate with tool. Troubleshoot. Monitor hole on trip tank, lost 2 bbls. 21:15 23:15 2.00 3,881 3,881 PROD1 DRILL PULD T PJSM. P/U & M/U BHA #3 to 165.7'. 23:15 00:00 0.75 3,881 3,881 PROD1 DRILL PULD T Upload MWD & BAT sonic. Hole losses: 1 BPH. 6/25/2010 Finish M/U BHA #3 & RIH T/ 2257'. Repair damaged link tilt hydraulic rams. Cont. RIH to 3881' MD. Drill 8-3/4" hole T/ 4046' MD. C/O wash pipe. Drill T/ 4384' MD. 00:00 01:00 1.00 3,881 3,881 PROW DRILL EQRP T Finish uploading MWD & BAT sonic. C/O flow deflector on antenna sub. 01:00 03:30 2.50 3,881 3,881 PROW DRILL TRIP T PJSM. Load sources. M/U & RIH remainder of BHA #3. 03:30 04:30 1.00 3,881 3,881 PROW DRILL TRIP T TIH on 4" DP to 2257'. Hydraulic rams on the top drive link tilt were damaged when picking up drill string from sli s. Monitor hole on trip tank. 04:30 05:30 1.00 3,881 3,881 PROD1 RIGMNT RGRP T Repair damaged link tilt rams. 05:30 09:00 3.50 3,881 3,881 PROD1 DRILL TRIP T Cont. TIH on 4" DP to 3848' MD. Wash to 3881' MD. Lost 20 bbls at 2841' MD. Fill hole & observe, static. 09:00 12:00 3.00 3,881 4,046 PROD1 DRILL DDRL P Drill 8-3/4" production hole F/ 3881' MD T/ 4046' MD. 450 GPM, SPP on bottom 1740, SPP off bottom 1690, WOB 10-15k, torque on 3-4k ft -lbs, torque off 2.5k ft -lbs, 130 RPM. P/U 115k, S/O 100k, & R/T 107k. ECD 10.22. Bit hrs: 17.39 Jar hrs: 43.67, AST: 0, ART: 1.73 ADT: 1.73. 12:00 15:30 3.50 4,046 4,046 PROD1 RIGMNT RGRP T Wash pipe leaking. P/U T/391 VMD to C/O. M/U head pin on DP & R/U cement hose. Establish circulation & C/O wash pipe. Monitor hole on trip tank. Page 11 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 16:30 1.00 4,046 4,046 PROD1 DRILL WASH P Wash back to bottom F/ 3911' MD T/ 4046' MD. 16:30 18:00 1.50 4,046 4,126 PROW DRILL DDRL P Continue drilling F/ 4046' MD T/ 4126' MD. 477 GPM, SPP on bottom 1860, SPP off bottom 1810, WOB 10k, torque on 3-4k ft -lbs, torque off 2-3k ft -lbs, 130 RPM. P/U 115k, S/O 100k, & R/T 107k. ECD 10.2. Bit hrs: 18.72, Jar hrs: 45.00, AST: 0, ART: 1.33 ADT: 1.33. 18:00 00:00 6.00 4,126 4,384 PROD1 DRILL DDRL P Cont. drill 8-3/4" hole F/ 4126' MD T/ 4384' MD. 480 GPM, SPP on bottom 1970, SPP off bottom 1850, WOB 6-8k, torque on 4.5k ft -lbs, torque off 3.5k ft -lbs, 130 RPM. P/U 122k, S/O 104k, & R/T 111k. ECD 10.29. 6/26/2010 Cont. drilling 8-3/4" hole to 4930' MD. Wiper trip 1000'. RIH & resume drilling to 5185' MD. 00:00 06:00 6.00 4,384 4,730 PROW DRILL DDRL P Cont. drill 8-3/4" hole F/ 4384' MD T/ 4730' MD. 550 GPM, SPP on bottom 2320, SPP off bottom 2120, WOB 5k, torque on 5k ft -lbs, torque off 3.5k ft -lbs, 130 RPM. P/U 123k, S/O 105k, & R/T 114k. ECD 10.33. Max gas 1720 units at 4397'- 4423' MD. 06:00 09:00 3.00 4,730 4,920 PROW DRILL DDRL P Cont. drill 8-3/4" hole F/ 4730' MD T/ 4920' MD. 480 GPM, SPP on bottom 1970, SPP off bottom 1850, WOB 6-8k, torque on 4.5k ft -lbs, torque off 3.5k ft -lbs, 130 RPM. P/U 122k, S/O 104k, & R/T 111 k. ECD 10.29. 09:00 09:15 0.25 4,920 4,920 PROD1 DRILL OWFF P Monitor hole, obtain SPR. 09:15 12:45 3.50 4,920 4,920 PROD1 DRILL WPRT P BROOH 3 stands for planned wiper trip. Attempt to pull on elevator. Overpull of 65k to work through tight spot. Resume BROOH T/ 3850' MD. Pump at 550 GPM & 2370 psi. 130 RPM, 3-4k ft -lbs. 12:45 13:15 0.50 4,920 4,920 PROW DRILL CIRC P Circulate BU. Rotate & reciprocate. Pump with 550 GPM & 2010 psi. 130 RPM. 13:15 14:15 1.00 4,920 4,920 PROD1 DRILL WPRT P RIH on elevators & wash down last stand. 14:15 18:00 3.75 4,920 5,076 PROD1 DRILL DDRL P Cont. drill 8-3/4" hole F/ 4920' MD T/ 5076' MD. 578 GPM, SPP on bottom 2630, SPP off bottom 2500, WOB 4-8k, torque on 4.5k ft -lbs, torque off 3.5k ft -lbs, 130 RPM. P/U 132k, S/O 110k, & R/T 120k. ECD 10.48. Bit hrs: 31.68, Jar hrs: 57.96, AST: 0, ART: 2.14, ADT: 2.14. Page 12 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 00:00 6.00 5,076 5,185 PROD1 DRILL DDRL P Cont. drill 8-3/4" hole F/ 5076' MD T/ 5185' MD. 567 GPM, SPP on bottom 2620, SPP off bottom 2510, WOB 10-15k, torque on 4.5k ft -lbs, torque off 3.5k ft -lbs, 130 RPM. P/U 138k, S/O 115k, & R/T 125k. ECD 10.41. Pumped 30 bbl bit balling sweep at 5115' MD. Consists of 4% Drill zone & 7#/bbl nut plug. 6/27/2010 Cont. drilling 8-3/4" production hole F/ 5185'T/ 5904' MD. Begin BROOH for planned wiper trip T/ 4922' MD. 00:00 06:00 6.00 5,185 5,361 PROW DRILL DDRL P Cont. drill 8-3/4" hole F/ 5185' MD T/ 5361' MD. 600 GPM, SPP on bottom 2630, SPP off bottom 2490, WOB 20-25k, torque on 5-7k ft -lbs, torque off 4k ft -lbs, 130 RPM. P/U 135k, S/O 115k, & R/T 125k. ECD 10.33. Bit hrs: 40.84, Jar hrs: 67.12, AST: 0, ART: 4.4, ADT: 4.4. Pumped 30 bbl bit balling sweep at 5315' MD. Consists of 4% Drill zone & 7#/bbl nut plug. Max gas observed 1979 units from 5217'- 5225' MD. 06:00 18:00 12.00 5,361 5,576 PROW DRILL DDRL P Drill 8-3/4" hole F/ 5361' MD T/ 5576' MD. 533 GPM, SPP on bottom 2570, SPP off bottom 2440, WOB 5-10k, torque on 4-5k ft -lbs, torque off 4k ft -lbs, 130 RPM. P/U 140k, S/O 117k, & R/T 127k. ECD 10.33. Bit hrs: 49.97, Jar hrs: 72.25, AST: 0, ART: 9.13, ADT: 9.13. Pumped 35 bbl bit balling sweep at 5405', 5490', & 5570' MD. Consists of 4% Drill zone & 5#/bbl nut plug. 18:00 23:00 5.00 5,576 5,804 PROD1 DRILL DDRL P Drill 8-3/4" hole F/ 5576' MD T/ 5804' MD. 550 GPM, SPP on bottom 2790, SPP off bottom 2610, WOB 15k, torque on 5-7k ft -lbs, torque off 4k ft -lbs, 130 RPM. P/U 141 k, S/O 120k, & R/T 130k. ECD 10.45. Active mud system contains 1.4% Drill zone for bit balling. 23:00 23:45 0.75 5,804 5,804 PROD1 DRILL WPRT P BROOH 4 stands for planned wiper trip to 4922' MD & circulate BU. Pump with 550 GPM & 2780 psi. 140 RPM, 4k ft -lbs. 23:45 00:00 0.25 5,804 5,804 PROD1 DRILL OWFF P Monitor well for flow. R/U pipe spinner to continue wiper trip on elevators. 6/28/2010 Cont. POOH for planned wiper trip F/ 5295' MD T/ 4922' MD. RIH & resume drilling 8-3/4" production hole to TD of 6565' MD, 6545' TVD. BROOH for wiper trip T/ 5740' MD. RIH to TD & circulate 2 BU. POOH on elevators to midnight depth of 4400' MD. Page 13 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:15 1.25 5,804 5,804 PROD1 DRILL WPRT P Cont. planned wiper trip F/ 5295' MD on elevators T/ 4922' MD. Pulled tight at 5280'. M/U top drive & BROOH one stand. 01:15 02:15 1.00 5,804 5,804 PROD1 DRILL WPRT P RIH to 5741' MD on elevators & wash down last stand. No obstructions in wellbore observed. Monitor hole on trip tank. 02:15 06:00 3.75 5,804 6,020 PROD1 DRILL DDRL P Cont. drill 8-3/4" hole F/ 5804' MD T/ 6020' MD. 570 GPM, SPP on bottom 3000, SPP off bottom 2850, WOB 8-10k, torque on 5-7k ft -lbs, torque off 4k ft -lbs, 130 RPM. P/U 135k, S/O 115k, & R/T 125k. ECD 10.33. Mixed 100 bbls of new mud into active system. Max gas observed 5300 units from 5820' MD. 06:00 14:15 8.25 6,020 6,565 PROD1 DRILL DDRL P Drill 8-3/4" hole F/ 6020' MD to TD of 6565' MD, 6545.05' TVD. 545 GPM, SPP on bottom 3170, SPP off bottom 3000, WOB 12k, torque on 5-6k ft -lbs, torque off 3k ft -lbs, 130 RPM. P/U 153k, S/O 132k, & R/T 143k. ECD 10.5. Bit hrs: 62.09, Jar hrs: 88.37, AST: 0, ART: 5.99, ADT: 5.99. API fluid loss reduced from 15 to 5 cc/30min. 14:15 15:45 1.50 6,565 6,565 PROW DRILL CIRC P Circulate 3 BU. Rotate & reciprocate. Pump with 550 GPM & 2800 si. 130 RPM. 15:45 19:00 3.25 6,565 6,565 PROW DRILL WPRT P Monitor well for flow, static. BROOH for planned wiper trip to 5740' MD. Attempt to POOH on elevators at 5994' MD, no success. Pump at 550 GPM with 3120 psi. 130 RPM. 19:00 19:30 0.50 6,565 6,565 PROD1 DRILL CIRC P Circulate BU. Rotate & reciprocate. Pump with 587 GPM & 3040 psi. 140 RPM & 4k ft -lbs. 19:30 20:30 1.00 6,565 6,565 PROW DRILL WPRT P RIH on elevators & wash down last stand. No obstructions in wellbore observed. Monitor hole on trip tank. 20:30 21:30 1.00 6,565 6,565 PROD1 DRILL CIRC P Circulate 2 BU. Rotate & reciprocate. Pump with 550 GPM & 2910 si. 130 RPM & 3k ft -lbs. 21:30 00:00 2.50 6,565 6,565 PROW DRILL TRIP P Observe well for flow, static. POOH on elevators T/ 4400' MD. Work through tight spots at 5535-5580'& 5450' MD. Monitor hole on trip tank. Page 14 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 6/29/2010 24 hr Summary Circulate bottom's up while rotating/reciprocating. Pumping 585 gpm w/ 2780 psi. Rotate 140 rpm w/ 3k ft lbs torque. Continue to pull out of the hole f/ 4481' to 3472'. Backream out of the hole from 3472' to 2842'. Pumping 550 gpm w/ 2040 psi. Rotate 140 rpm w/ 2k ft-lbs of torque. Circulate bottom's up. Pumping 600 gpm w/ 2140 psi. Rotate 30 rpm w/ 2k ft lbs of torque. Pumped 184 bbls. Monitor well- static. Pull out of the hole from 2842' to 889'. Lay down BHA f/ 889' to 114'. Monitor well on the trip tank. Pull out of the hole from 114' to 47'. Download Sperry Sun MWD. Run in the hole to 114'. Lay down BHA f/ 114'. Clear floor of tools and handling equipment. Shut blind rams. Drain stack. Change upper pipe rams to 7". Rig down short drilling bales. Pick up test joint. Pull wear bushing. Make up Vetco Gray lower test plug. Fill stack. Test 7" upper rams, kill HCR and choke valves 2,6, and 10, 4" TIW valve to 250 psi low and 4500 psi high. Hold each test 5 minutes. Monitor lower annulus. Rig down testing equipment. Blow down lines. Pre job safety meeting. Rig up to run 7" casing. Pre job safety meeting on running casing with Weatherford casing crew and Doyon crew. Prep joint number 1 and 3 for stop ring. Jt # one (5' above shoe), joint # three (10' above Float Collar). Split solid stop rings, wrap around pipe and weld ring back together. Run Ray oil tool silver bullet float shoe on jt #1, thread lock joint, Halliburton shure seal float collar on joint # 3, then bakerlock pin of joint #4. Circ to check out float equipment. Circulate 27 bbls total. Run 7" 26 ppf L-80 BTC-m casing f/ jt #5 to jt # 15 (164' to 612'). Checking make up torque to make up to base of diamond. Approx 10k to 10.5k ft-lbs of torque. Installing tandem rise centralizers every otherjoint on collars of even number joints. 00:00 00:30 0.50 4,481 4,481 PROD1 DRILL CIRC P Circulate bottom's up while rotating/reciprocating. Pumping 585 gpm w/ 2780 psi. Rotate 140 rpm w/ 3k ft lbs torque. 00:30 01:30 1.00 4,481 3,472 PROW DRILL TRIP P Continue to pull out of the hole f/ 4481' to 3472'. 01:30 04:00 2.50 3,472 2,842 PROD1 DRILL REAM P Backream out of the hole from 3472' to 2842'. Pumping 550 gpm w/ 2040 psi. Rotate 140 rpm w/ 2k ft-lbs of torque. 04:00 04:30 0.50 2,842 2,842 PROW DRILL CIRC P Circulate bottom's up. Pumping 600 gpm w/ 2140 psi. Rotate 30 rpm w/ 2k ft lbs of torque. Pumped 184 bbls. 04:30 04:45 0.25 2,842 2,842 PROD1 DRILL OWFF P Monitor well- static. 04:45 06:00 1.25 2,842 889 PROD1 DRILL TRIP P Pull out of the hole from 2842' to 889'. 06:00 10:45 4.75 889 114 PROW DRILL PULD P Lay down BHA f/ 889' to 114'. Monitor well on the trip tank. 10:45 12:00 1.25 114 47 PROD1 DRILL TRIP P Pull out of the hole from 114' to 47'. Download Sperry Sun MWD. 12:00 13:30 1.50 47 0 PROD1 DRILL TRIP P Run in the hole to 114'. Lay down BHA f/114'. 13:30 14:30 1.00 0 0 PROW DRILL PULD P Clear floor of tools and handling e ui ment. Shut blind rams. 14:30 15:45 1.25 0 PROW WHDBO BOPE P Drain stack. Change upper pipe rams to 7". Rig down short drilling bales. 15:45 16:15 0.50 PROD1 WHDBO BOPE P Pickup test joint. Pull wear bushing. Make u Vetco Gray lower test plug. 16:15 16:30 0.25 PROD1 WHDBO BOPE P Fill stack. Test 7" upper rams, kill HCR and choke valves 2,6, and 10, 4" TIW valve to 250 psi low and 4500 psi high. Hold each test 5 minutes. Monitor lower annulus. 16:30 17:00 0.50 PROD1 WHDBO BOPE P Rig down testing equipment. Blow down lines. 17:00 17:15 0.25 PROW CASING SFTY P Pre job safety meeting. 17:15 19:30 2.25 PROD1 CASING RURD P Rig up to run 7" casing. Page 15 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:30 20:00 0.50 PROD1 CASING SFTY P Pre job safety meeting on running casing with Weatherford casing crew and Doyon crew. 20:00 21:00 1.00 PROD1 CASING OTHR P Prep joint number 1 and 3 for stop ring. A # one (5' above shoe), joint # three (10' above Float Collar). Split solid stop rings, wrap around pipe and weld ring back together. 21:00 22:15 1.25 0 164 PROD1 CASING RNCS P Run Ray oil tool silver bullet float shoe on jt #1, thread lock joint, Weatherford float collar on joint # 3, then bakerlock pin of joint #4. 22:15 22:30 0.25 164 164 PROD1 CASING CIRC P Circulate to check out float equipment. 65 spm (3 bpm) w/ 100 psi- 47% Totco flow, 87 spm (4 bpm) w/ 140 psi- 53 to 54% Totco flow, 115 spm (5.31 bpm) w/ 230 psi -60% Totco flow, 136 spm (6.3 bpm) w/ 290 psi- 66% Totco flow. Circulate 27 bbls total. 22:30 00:00 1.50 164 612 PROD1 CASING RNCS P Run 7" 26 ppf L-80 BTC -m casing f/ jt #5 to jt # 15 (164' to 612'). Checking make up torque to make up to base of diamond. Approx 10k to 10.5k ft -lbs of torque. Installing tandem rise centralizers every other joint on collars of even number jts. Monitor displacement on pit #6. Fill each oint, top off every 5 jts. 6/30/2010 Continue to run 7" 26 ppf L-80 BTCM casing f/ 612' to 2813'. Circulate casing volume. Circ 111 bbls. Continue to run 7" f/ 2813' to 6488', tagged up at 6502' on jt # 159. PU wt 177k, SO wt 140k. Slacked off to block wt. POOH to 6486'. RU to circ. Establish circ, pumping 3 bpm w/ 858 psi. Work down from 6486' to 6526'. MU VetcoGray hanger and landing joint. Establish circ, pumping 4 bpm w/ 880 psi. Landed on hanger w/ shoe at 6552.72'. When reciprocating, hanging up on the lower rams with hanger. Decision made to lay down hanger/landing joint & PU a 10' pup joint to be able to reciprocate casing. POOH UD hanger and Ind jt. PU/MU 9.80' pup joint, RIH to 6535'. Make up BJ cement head. Estab circ pumping 7 bpm w/ 815 psi. With pumps on: PU wt 152k, SO wt 130k. Reciprocate 25' stroke from 6535' to 6510'. Held PJSM on cementing while circ & condition mud. Drop bottom plug, BJ pump 2 bbls of water, pressure test to 4500 psi. Load top plug. BJ pump 40 bbls Sealbound sweep (10.0 ppg, 38.1 bbls water), mix and pump 149.1 bbls (280 sx) of 10.5 ppg class "G" cement w/ additives (2.99 cuf /sx, 12.354 gal/sx water, 4:16 hr thickening time), shut down/ shut in the head. Flush lines. Drop top plug, BJ pump 5 bbls water, the turn over to the rig. Recip 25' stroke continuous. Rig displace cement w/ rig pumps #1 and #2, pumping 6.75 bpm w/ 800 to 850 psi. Recip continuous until cement to the shoe. stopped recip f/ 5 minutes, then con't again until last 6 bbls. Slowed pumps down after 205 bbl of mud pumped to 3.84 bpm w/ 480 to 580 psi. Bumped plug with 242.23 bbls of 9.8 ppg mud at 1836 hrs w/ 1100 psi. Held press f/ 5 minutes. Bleed off to check floats. Floats not holding. Repressure to 1100 psi, bleed off, floats not holding. Repressure plugs to 1045 psi. Holding. Line up to attempt pressure test of casing to 4400 psi f/ 30 minute test. Bleed pressure down to 200 psi. BJ start pressure test, not holding. stop, shut in w/ 325 psi, monitor pressure and annulus while WOC. Page 16 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 04:15 4.25 612 2,813 PROW CASING RNCS P Run 7" 26 ppf L-80 BTC -m casing f/ jt #16 to jt # 68 (612' to 2813'). Checking make up torque to make up to base of diamond. Approx 10k to 10.5k ft -lbs of torque. Installing tandem rise centralizers every other joint on collars of even number jts. Monitor displacement on pit #6. Fill each joint, top off every 5 jts. 04:15 05:00 0.75 2,813 2,813 PROW CASING CIRC P Circulate casing volume. Initial 3 bpm w/ 364 psi, final 4 bpm w/ 400 psi -53% Totco flow out. Circ 111 bbls. 05:00 06:00 1.00 2,813 3,317 PROD1 CASING RNCS P Run 7" 26 ppf L-80 BTC -m casing f/ jt #69 to jt # 80 (2813' to 3317'). Checking make up torque to make up to base of diamond. Approx 10k to 10.5k ft -lbs of torque. Installing tandem rise centralizers every other joint on collars of even number jts. Monitor displacement on pit #6. Fill each joint, top off every 5 its. 06:00 11:45 5.75 3,317 6,502 PROD1 CASING RNCS P Run 7" 26 ppf L-80 BTC -m casing f/ jt # 81 to jt # 158 (3317' to 6488'), tagged up at 6502' on jt # 159. PU wt 177k, SO wt 140k. Slacked off to block wt. Installing tandem rise centralizers every other joint on collars of even number jts to jt # 82, jt # 84 has tandem rise and spiroglider in middle on 2 stops, #85 through 97 has spiroglider in middle with 2 stops, then joint 157 and 158 have tandem rise over box. Monitor displacement on pit #6. Fill each joint, top off every 5 jts. 11:45 12:15 0.50 6,502 6,486 PROD1 CASING RURD P Pull out of the hole to 6486'. Rig up to circulate. 12:15 13:00 0.75 6,486 6,526 PROD1 CASING RNCS P Establish circulation, pumping 3 bpm w/ 858 psi- 57% Totco flow out. Work down from 6486' to 6526'. 13:00 14:45 1.75 6,526 6,553 PROD1 CASING RNCS P Make up VetcoGray hanger and landing joint. Establish circulation, pumping 4 bpm w/ 880 psi -55% flow out. Landed on hanger w/ shoe at 6552.72'. When reciprocating, hanging up in the rams with the hanger. Decision made to lay down hanger/landing joint and pick up a 10' pup joint to be able to reciprocate casing. 14:45 15:00 0.25 6,553 6,535 PROW CASING RNCS T Pull the hanger and landing joint out of the hole. Lay down both. Pickup/ make up 9.80' pup joint, run in the hole to 6535'. Page 17 of 28 U Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:00 15:15 0.25 6,535 6,535 PROD1 CEMEN RURD P Make up BJ cement head. 15:15 16:00 0.75 6,535 6,535 PROD1 CEMEN" CIRC P Establish circulation pumping 7 bpm w/ 815 psi. With pumps on: PU wt 152k, SO wt 130k. Reciprocate 25' stroke from 6535' to 6510'. Held PJSM on cementing while circulating and condition mud f/ cement 'ob. 16:00 16:45 0.75 6,535 6,535 PROD1 CEMEN- PRTS P Drop bottom plug, BJ pump 2 bbls of water, attempt to pressure test to 4500 psi. 2" demco valve on the cement line in the cellar leaked. Remove 2" demco valve f/ cement line. BJ pressure test to 4500 psi- ood. 16:45 18:00 1.25 6,535 6,535 PROD1 CEMEN" PUCM P Load top plug in the cement head. BJ pump 40 bbls Sealbound sweep (10.0 ppg, 38.1 bbls water)), mix and pump 149.1 bbls (280 sx) of 10.5 ppgl/ class "G" cement w/ additives (2.99 cuft/sx, 12.354 gal/sx water, 4:16 hr thickening time), shut down/ shut in the head. Flush lines of cement to the cellar. Drop top plug, BJ pump 5 bbls water, the turn over to the rig. Reci rocated 25' stroke continuous. 18:00 18:45 0.75 6,535 6,535 PROD1 CEMEN- DISP P Rig displace cement w/ rig pumps #1 and #2, pumping 6.75 bpm w/ 800 to 850 psi. Recip continuous until cement to the shoe. stopped recip f/ 5 minutes, then continued again until last 6 bbls. Slowed pumps down after 205 bbl of mud pumped to 3.84 bpm w/ 480 to 580 psi. Bumped plug with 242.23 bbls of 9.8 ppg mud at 1836 hrs w/ 1100 psi. Held pressure f/ 5 minutes. Bleed off to check floats. Floats not holding. Repressure to 1100 psi, bleed off, floats not holding. 18:45 19:00 0.25 6,535 6,535 PROW DRILL PRTS T Repressure plugs to 1045 psi. Holding. 19:00 19:30 0.50 6,535 6,535 PROD1 DRILL PRTS T Line up to attempt pressure test of casing to 4400 psi f/ 30 minute test. Bleed pressure down to 200 psi. BJ start pressure test. With 1 bbl pumped- 300 psi, 1.1 bbl -450 psi, 1.2 bbl- 600 psi, 1.4 bbl -750 psi, 1.5 bbl -850 psi, 2 bbl- 700 psi and dropping (circulating to the annulus). Shut down after 2.2 bbls. Shut in with 350 psi at 1915 hrs. Pressure bleed down to 325 psi. Page 18 of 28 Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment 19:30 00:00 4.50 6,535 6,535 PROD1 DRILL OWFF T Monitor pressure on the casing. Monitor annulus with trip tank. Initial 325 psi. At midnight pressure was 450 psi. Lost 4 bbls to the annulus. 165K to 170k on the weight indicator w/ 3.7' of pup above the rig floor. RKB to 7" load shoulder is 19.57' Note: From midnight to 2 am no more losses. D7/01/201 0 Continue to monitor 7" casing pressure and the annulus while WOC. Rig up and test casing to 1000 psi. Rig down. Rig up to lift stack and split Vetco Gray wellhead to install 7" slips. Set pipe on slips w/ 155k on the weight indicator. Cut off the casing w/ air recip saw. Install packoff. Set stack down w/ upper tubing spool. Tighten bolts. Torque lockdown screws to 400 ft lbs. Test Vetco Gray packoff to 80% collapse of 7" 26 ppf L-80 casing rating. Collapse is 5410 psi, 80% is 4328 psi. Pressure to 4400 with bleed off to 4200 over 5 minutes. Kept repeating with no change. Tightened lockdown screws to 600 ft lbs. Changed gauge and isolation valve on the test pump. Finally eliminated pressure loss. Rock solid test of 4350 psi. in 10 minutes. Testing the packoff, tests the packoff to wellhead, to the casing. Lockdown gland nuts and API ring. Finish nippling up flow line and kill line and choke line. Attatch chains to secure stack. Change lower rams f/ 4" to 2-7/8" x 5", change upper rams from 7" to 2-7/8" xx 5". Rig up to test upper and lower rams w/ 3-1/2" & 4" test joint. Will test annular w/ 3-1/2" test joint. Test with 4" test joint and upper Vetco Gray test plug. Test upper pipe rams to 250 psi low and 4500 psi high. Kill and choke HCR valves closed. Hold test 5 minutes. Chart test. 00:00 08:00 8.00 6,535 6,535 PROD1 DRILL WOC T Continue to monitor 7" casing pressure and the annulus while WOC. Initial 325 psi. At midnight pressure was 450 psi. Final 610 psi @ 0800 hrs. 165K to 170k on the weight indicator w/ 3.7' of pup above the rig floor. RKB to 7" load shoulder is 19.57'- cut off will be 13-3/4" (1.14') above load shoulder. Note: Drifted and strapped 170 jts of 3.5" 9.3 ppf L-80 EUE-m tubing while WOC. Note: Cleaning its while WOC. 08:00 08:45 0.75 6,535 6,535 PROD1 DRILL PRTS T Rig up, then test casing to 1000 psi f/ 10 minutes, chart test. Bleed off, no flow. Rig down testing equipment. Continue to clean pits. 08:45 14:15 5.50 6,535 6,535 PROD1 WHDBO NUND P Rig up to split VetcoGray wellhead for installation of emergency slips. Continue cleaning pits. Pick up BOP stack. 14:15 16:45 2.50 6,535 6,535 PROD1 WHDBO NUND P Set Vetco Gray 7" emergency slips w/ 155k on the weight indiciator (Blocks 24k of this weight). Cut 7" with air recip saw. Final dress 7" stump. Install packoff. Continue to clean pits. 16:45 19:00 2.25 PROD1 WHDBO NUND P Set stack back down w/ Vetco Gray upper wellhead. Tighten bolts. Tighten lockdown screws to 400 ft lbs of torque. Page 19 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:45 1.75 PROD1 WHDBO PRTS T Test Vetco Gray packoff to 80% collapse of 7" 26 ppf L-80 casing rating. Collapse is 5410 psi, 80% is 4328 psi. Pressure to 4400 with bleed off to 4200 over 5 minutes. Kept repeating with no change. Tightened lockdown screws to 600 ft lbs. Changed guage and isolation valve on the test pump. Finally eliminated pressure loss. Rock solid test of 4350 psi. in 10 minutes. This test, tests the packoff to wellhead, to the casing. Lockdown land nuts and API ring. 20:45 21:30 0.75 PROW WHDBO NUND P Finish nippling up flow line and kill line and choke line. Attatch chains to secure stack. 21:30 22:15 0.75 PROM WHDBO NUND P Change lower rams f/ 4" to 2-7/8" x 5", change upper rams from 7" to 2-7/8" x 5". 22:15 23:00 0.75 PROW WHDBO BOPE P Rig up to test upper and lower rams w/ 3-1/2" & 4" test joint. Will test annular w/ 3-1/2" test joint. 23:00 00:00 1.00 PROW WHDBO BOPE P Test with 4" test joint and upper Vetco Gray test plug. Test upper pipe rams to 250 psi low and 4500 psi high. Kill and choke HCR valves closed. Hold test 5 minutes. Chart test. 7/02/2010 Con't to test with 4" test joint & upper Vetco Gray test plug. Test upper pipe rams (2-7/8" x 5") to 250 psi low and 4500 psi high. Test lower pipe rams (2-7/8" x 5") high and low w/ 4" test joint. Change out test joint to 3-1/2". Test annular to 250 psi low and 3500 psi high. Test upper pipe rams to 250 psi low and 4500 psi high. Leaking on high. Test lower pipe rams to 250 psi low and 4500 psi high. Tested mud line valve on kill line, tested valves 10,6 and 2 in choke manifold. Drain stack, open top pipe rams. Clean and reinstall top seals on rams. Clean cavity. Install 3-1/2" test joint. RU to test, fill stack w/ water. Test upper pipe rams w/ 3-1/2" test joint to 250 psi low and 4500 psi high. Hold each test 5 minutes. Chart test. Rig down test equipment. Install Vetco Gray wear bushing (10.84" OD x 6-7/16" ID). Rig down casing running bales. Rig up drilling bales. and 4" elevators. PJSM on making up BHA. PU/MU 6-1/8" bit, scraper and bit sub. RIH w/ cleanout BHA to 573'(9 stands). Install inside BOPon top of stand #9 to keep mud from running over the pipe while running in the hole. Con't trip in the hole f/ 575' to 6049'.Fill pipe while running in the hole. Continue to RIH, PU singles f/ 6049' to 6450.61'. Tagged up on wiper plug. PU wt 107k, SO wt 93k. PU to 6447', circ, POOH to 6429', PJSM, RU, then test casing to 4500 psi f/ 30 minutes w/ BJ pump. Rig down, PJSM, displ 9.5 ppg mud with 8.6 ppg 6% KCL brine while recip/rotate 6450' to 6399'. Flush pump 2 & 3 w/ 5 bbls KCL, then pump 50 bbl sweep w/ pump 1, follow w/ 225 bbls 8.6 ppg 6% KCL brine. POOH UD 4" drill pipe f/ 6450' to 3256' at midnight. Page 20 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 03:30 3.50 PROM WHDBO BOPE P Continue to test with 4" test joint and upper Vetco Gray test plug. Test upper pipe rams (2-7/8" x 5") to 250 psi low and 4500 psi high. Kill and choke HCR valves closed. Hold test 5 minutes. Chart test. Test lower pipe rams (2-7/8" x 5") high and low w/ 4" test joint. Change out test joint to 3-1/2". Test annular to 250 psi low and 3500 psi high. Test upper pipe rams to 250 psi low and 4500 psi high. Leaking on high. Test lower pipe rams to 250 psi low and 4500 psi high. Tested mud line valve on kill line, tested valves 10,6 and 2 in choke manifold, tested kill and choke HCR valves to 250 psi low and 4500 psi high. 03:30 04:30 1.00 PROD1 WHDBO BOPE T Drain stack, open top pipe rams. Clean and reinstall top seals on rams. Clean cavity. Install 3-1/2" test joint. RU to test, fill stack w/ water. 04:30 05:00 0.50 PROM WHDBO BOPE T Test upper pipe rams w/ 3-1/2" test joint to 250 psi low and 4500 psi high. Hold each test 5 minutes. Chart test. 05:00 05:30 0.50 PROW WHDBO RURD P Rig down testing equipment. Install Vetco Gray wear bushing (10.84" OD x 6-7/16" ID). 05:30 07:00 1.50 PROW DRILL RURD P Rig down casing running bales from casing run. Rig up short drilling bales. and 4" elevators. 07:00 07:15 0.25 PROM DRILL SFTY P Pre job safety meeting on making up BHA. 07:15 07:45 0.50 0 6 PROM DRILL PULD P Pick up/ make up 6-1/8" bit, scraper and bit sub 07:45 08:15 0.50 6 573 PROM DRILL TRIP P Trip in the hole w/ cleanout BHA to 573' 9 stands). 08:15 08:30 0.25 573 575 PROM DRILL PULD P Install inside BOPon top of stand #9 to keep mud from running over the pipe while running in the hole. 08:30 11:45 3.25 575 6,049 PROM DRILL TRIP P Continue trip in the hole w/ cleanout BHA from 575' to 6049'. Total of 96 stands from the derrick. Fill pipe while running in the hole. 11:45 12:30 0.75 6,049 6,450 PROM DRILL TRIP P Continue to run in the hole picking up singles from 6049' to 6450.61'. Tagged up on wiper plug. PU wt 107k, SO wt 93k. 12:30 13:15 0.75 6,450 6,447 PROM DRILL CIRC P Pick up 3', then circulate and condition mud. Pumping 128 gpm w/ 325psi-54% Totco flow. 13:15 13:30 0.25 6,447 6,429 PROD1 DRILL PULD P Pull out of the hole from 6447' to 6429', lay down a single. 13:30 13:45 0.25 6,429 61429 PROM DRILL SFTY P Pre job safety meeting on testing 7" 26 ppf L-80 BTC -m casing. 13:45 14:15 0.50 6,429 6,429 PROD1 DRILL RURD P Rig up to test casing. Page 21 of 28 C- y 400dt- c r3c_ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:15 15:30 1.25 6,429 6,429 PROD1 DRILL PRTS P Test casing to 4500 psi f/ 30 minutes. 9.5 ppg mu in the hole. Chart test. BJ cement unit did the pumping. Pumping down the drill pipe and into the annulus via the kill line, with the top pipe rams (2-7/8" x 5" shut. 15:30 15:45 0.25 6,429 6,429 PROD1 DRILL RURD P Rig down testing equipment. Blow down lines. 15:45 16:00 0.25 6,429 6,429 PROD1 DRILL SFTY P Pre job safety meeting on displacing from 9.5 ppg mud to 8.6 ppg 6% KCL brine. 16:00 18:00 2.00 6,429 6,450 PROD1 DRILL CIRC P Pick up a single of 4" drill pipe. Make a top drive connection. Establish circulation. Rotate and reciprocate from 6450' to 6399'. Flush pump 2 & 3 w/ 5 bbls KCL, then pump 50 bbl sweep w/ pump 1, follow w/ 225 bbls 8.6 ppg 6% KCL brine. Pumped 5024 total strokes (.04464 bps- 92% pump efficiency). Final circulating pressure 380 psi -57% Totco flow, when pumping 216 gpm. 18:00 00:00 6.00 6,450 3,256 PROD1 DRILL PULD P Lay down 4" drill pipe f/ 6450 to 3256' at midnight. 7/03/2010 Continue to lay down 4" drill pipe f/ 3256', lay down BHA, clear floor, PJSM, rig up Halliburton wireline, pick up cement bond log tool string (54'), run in the hole log from 6430', pull out of the hole, lay down tool string, make up Halliburton E-z drill bridge plug, RIH on wireline, set at 6350', pull out of the hole. Rig down Halliburton wireline, clear floor, drain stack, pull Vetco Gray wear bushing, Rig up to run 3-1/2" completion, PJSM, finish rig up. Make up completion to 69'. While attatching 3/8" chemical line to the check valve- broke th test fitting. Wait on fitting to be flown over. Make up 3/8" control line. Test between ferries to 7500 psi f/ 2 minutes- OK. Test control line on the spool to 1550 psi f/ 10 minutes- good test. 00:00 03:00 3.00 3,256 6 PROD1 DRILL PULD P Continue to lay down 4" drill pipe f/ 3256 to 6'. 03:00 03:30 0.50 6 0 PROD1 DRILL PULD P Lay down cleanout scraper BHA, clear floor. 03:30 04:00 0.50 0 PROW EVALWE SFTY P PJSM on rigging up Halliburton wireline tools. 04:00 04:30 0.50 PROD1 EVALWE RURD P Rig up Halliburton wireline tools. 04:30 05:30 1.00 0 54 PROD1 EVALWE RURD P Pick up/make up 54.74' toolstring on .474" line w/ cable head weak point # 8 rated to 7900 to 8400 lbs. 05:30 10:15 4.75 54 PROD1 EVALWE QEVL P Run in the hole with cement bond tool string to 6430', log while POOH. Monitor on trip tank. CastScanHead, Cast Scanner (motor section), Cast Navigation (shows high side), flex joint, Cast-F Instrument (electronics), CBL (cement bond log), D4TG (Telemetry Gamma Ray), CCLD4 collar locator 10:15 11:00 0.75 COMPZ EVALWE PULD P Lay down Halliburton tool string. 11:00 13:00 2.00 COMPZ RPCOM PULD P Make up Halliburton E-Z Drill bridge rpluq on wireline. Page 22 of 28 C- y 400dt- c r3c_ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 13:00 14:30 1.50 6,350 COMPZ RPCOM MPSP P Run in the hole w/ Halliburton E -Z Drill bridge plug and set @ 6350' Wireline measurement. 14:30 16:15 1.75 6,350 0 COMPZ RPCOM MPSP P Pull out of the hole w/ Halliburton 474" wireline. 16:15 16:45 0.50 COMPZ RPCOM OTHR P Drain stack, Pull Vetco Gray wear bushin 10.84" OD x 6-7/16" ID). 16:45 17:15 0.50 COMPZ RPCOM OTHR P Clear floor. Monitor well on the trip tank. 17:15 18:45 1.50 COMPZ RPCOM RURD P Rig up to run 3-1/2" completion tubing. Monitor well on the trip tank. 18:45 19:00 0.25 COMPZ RPCOM SFTY P Pre job safety meeting on running completion. 19:00 19:30 0.50 COMPZ RPCOM RURD P Finish rigging up to run completion. 19:30 20:30 1.00 0 69 COMPZ RPCOM RCST P Run in the hole w/ completion to 69'. 20:30 20:45 0.25 69 69 COMPZ RPCOM OTHR P Install 3/8" chemical line to checmical injector 20:45 22:45 2.00 69 69 COMPZ RPCOM OTHR T Broke test fitting where the 3/8" control is to be tested, while torquing to 7 ft lbs of torque. Locate spare chemical sub, arange flight to bring fittings to Beluga. 22:45 00:00 1.25 69 69 COMPZ RPCOM PRTS P Install 3/8" Chemical injection line. Test between ferrules on the check valve to 7500 psi f/ 2 minutes- OK. Test chemical line spool to fitting to 1550 psi f/ 10 minutes- good test. 7/04/2010 Con't to run 3-1/2" 9.3 ppf L-80 EUE-m completion from 69' (chemical injection sub) to the CAMCO sub surface safety valve at # 135 in the hole), make up SSSV, connect 11/4" control line, test to 5000 psi- good. Con't RIH with both 3/8" & 1/4" control lines to 4804' (jt # 147 in the hole + 2 pup joints), change out handling tools to 4-1/2", install 4-1/2" IBT-m x 3-1/2" EUE crossover, Run 2 joints of 4-1/2" 12.6 ppf L-80 IBT-m tubing, PU/MU Vetco Gray hanger, tie in both chemical and SSSV control lines. Total jewelry in hole: 80 cannon clamps, 2 special cannon clamps, 5 stainless steel bands. Drain stack, Land tubing in Vetco Gray multibowl w/ WLEG @ 4892.87'. PU wt 65k, SO wt 62k. Test lower seals on the hanger to 5000 psi f/ 15 minutes - good. PJSM, RU, displace to corrosion inhibited 6% KCL brine 8.6 ppg, pumping 30 bbls non inhibited, 170 bbls inhibited, chase lines w/ 5 bbls non inhibited. Rig down lines. PJSM, RU to set packer, drop ball and rod (5.83' overall length). BJ Press test to 4500 psi -good, Pump down tbg to set packer w/ 2900 psi, then continue to 4040 psi and hold 8 minutes.Pumped .8 bbls. Test tubing to 4400 psi f/ 32 minutes, chart test - good test. Pumped .8 bbls. RU to test annulus w/ tbg open to atmoshere. Pressure to 4400 psi f/ 32 minutes. Chart test -good test. Pumped 2.2 bbls. Pull Vetco Gray landing joint, install Vetco Gray two way check in the hanger. Rig down the tools to run the completion. Nippling down BOPE, flushing mud lines and blow down mud lines. 00:00 07:30 7.50 69 4,381 COMPZ RPCOM RCST P Continue to PU/MU/RIH w/ 3-1/2" 9.3 ppf L-80 EUE-m completion f/ 69' to 4381' (135 jts in the hole), installing cannon clamps per detail. Monitor well on the trip tank. 07:30 08:00 0.50 4,381 4,381 COMPZ RPCOM RCST P PU/MU/Camco sub surface safety valve (TRMAXX-5E). Connect 1/4" SS line. 08:00 08:15 0.25 4,381 4,381 COMPZ RPCOM PRTS P Test 1/4" control line to 5000 psi f/ 10 minutes. Good test. Keep 5000 psi on line while running in the hole. 08:15 08:30 0.25 4,381 4,406 COMPZ RPCOM RCST P Install (2) red Cannon clamps (1.28' long) on body of pup jt above and below SSSV. Page 23 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:30 1.00 4,406 4,804 COMPZ RPCOM RCST P Continue to PU/MU/RIH w/ 3-1/2" 9.3 ppf L-80 EUE-m completion f/ 4804' to 4867', (147jts + 10.15' pup and 8.0' pup in the hole). 09:30 10:15 0.75 4,804 4,804 COMPZ RPCOM RURD P Change out handling tools from 3-1/2" to 4-1/2". Install 4-1/2" IBT-m box x 3-1/2" EUE pin crossover. 10:15 10:30 0.25 4,804 4,867 COMPZ RPCOM RCST P PU/MU/RIH w/ (2 jts) 4-1/2" 12.6 ppf L-80 EUE-m completion f/ 4406' to 4804', Running both 3/8" and 1/4" control line. Monitor well on the trip tank. Installing 5/8" stainless bands detail. 10:30 12:00 1.50 4,867 4,867 COMPZ RPCOM RCST —per P Make up Vetco Gray hanger w/ P xP pup and landing joint. Tie in the chemical injection line (3/8"), and SSSV control line (1/4"). 12:00 12:30 0.50 4,867 4,893 COMPZ RPCOM RCST P Drain stack. Run in the hole and land hanger w/ WLEG @ 4892.87'. PU wt 65k, SO wt 62k. 12:30 13:00 0.50 4,893 4,893 COMPZ RPCOM PRTS P Run in lockdow screws. Test lower seals on hanger to 5000 psi f/ 15 minutes. Good. 13:00 13:15 0.25 4,893 4,893 COMPZ RPCOM SFTY P Pre job safety -rigging up to displace. 13:15 13:45 0.50 4,893 4,893 COMPZ RPCOM RURD P Rig up to displace. 13:45 14:00 0.25 4,893 4,893 COMPZ RPCOM SFTY P Pre job safety meeting on displacing to corrosion inhibited 6%KCL, 8.6 ppg brine. Used CONQOR 303A, 1 drum per 100 bbls. 14:00 15:15 1.25 4,893 4,893 COMPZ RPCOM CIRC P Rig pump 30 bbls 6% KCL, then 170 bbls corrosion inhibited 6% KCL, then 5 bbls 6% KCL w/o corrosion inhibtor to clear pumps and lines.. Pumped down the tubing, returns through upper annulus to the degasser. Pumped 128 gpm w/ 240 psi. 15:15 15:45 0.50 4,893 4,893 COMPZ RPCOM RURD P Rig down and blow down lines. 15:45 16:00 0.25 4,893 4,893 COMPZ RPCOM SFTY P Pre job safety meeting on rig up to set packer and pressure test. 16:00 16:15 0.25 4,893 4,893 COMPZ RPCOM RURD P Rig up to set packer and perform pressure tests. 16:15 16:30 0.25 4,893 4,893 COMPZ RPCOM PACK P Drop ball and rod (5.83" long overall w/ 1.36" OD neck and 1.7" OD 1/2 ball) to set packer. Will land in RHC plug in the XN nipple. @ 4880.24'. BJ pressure test lines to 4500 psi - good. BJ pressure up on the tubing to set Baker premier 3-1/2" x 7" packer (Center of element @ 4857.26'). Packer set @ 2900 psi, continue to pressure up to 4040 psi. Hold pressure f/ 8 minutes. Bleed down to 4016 psi. Good indication. Total of .8 bbls pumped. Page 24 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:30 17:00 0.50 4,893 4,893 COMPZ RPCOM PRTS P Test tubing to 4400 psi f/ 30 minutes. Chart test. Good test. Pumped .8 bbls total. Pressured to 4489 psi, bleed down to 4419 psi after 32 minutes. 17:00 17:15 0.25 4,893 4,893 COMPZ RPCOM RURD P Rig up to test 7" x 3-1/2" annulus. 17:15 18:00 0.75 4,893 4,893 COMPZ RPCOM PRTS P Test 7" x 3-1/2" annulus to 4400 psi f/ 30 minutes with tubing open to atmosphere Chart test. Good test. Pumped 2.2 bbls total. Initial pressure 4470 psi, after 32 minutes -4415psi.__ 18:00 18:30 0.50 4,893 COMPZ RPCOM PULD P Pull the 4-1/2" landing jt. Break off the crossovers for circulating/pumping. 18:30 19:00 0.50 COMPZ WHDBO OTHR P Set Vetco Gray two way check valve in the hanger. 19:00 19:30 0.50 COMPZ RPCOM RURD P Rig down tools to run completion. 19:30 00:00 4.50 COMPZ WHDBO NUND P Nippling down BOPE. Kill and choke hoses, flow line, chains on stack. 7/05/2010 Nippling down BOPE. Flush and grease cavites of BOP's. Remove rams. Grease BOPE. Draining hot well f/ boilers. Cleaning pits. Terminate control lines. Nipple up tree per Vetco Gray service rep. Test hanger neck metal to metal seal to tubing head adapter. Testing API ring as well. Test to 5000 psi f/ 8 minutes. OK. Test tree to 250 psi low and 4400 psi high f/ 5 min each, charted test. OK. Rig down testing equipment, blow down lines. Secure cellar. Blow down water lines, rig down air and water lines. clean rockwasher. Rig released at 0900 hrs 7-5-2010. Note: 4600 psi on the 1/4" SSSV control line at 2200 hrs 7-5-2010. Rigging down the pump room and mud pits. Pick up top drive cradle, slack off the top drive and secure in the cradle. Rig down service loop f/ top drive. Spool up the service loop in the top drive house. Remove top drive from the rig floor with Peak Oilfield Services crane. Bridle up blocks to the derrick. Secure derrick to scope down. Con't to rig down pump room and mud pits. Scope down derrick. Rig down lower section of torque tube. Secure derrick for laying over. Remove roof caps over the drawworks. Pre job safety meeting. Rig down derrick board. Remove wind walls. Continue to prepare motor room for rig move. Rigging down windwalls around the rig floor, using Peak crane, and using manlift. Rig down beaver slide, secure motor room and pump rooms for moving. Continue rigging down and pulling electrical wires. Continue rigging down wind walls in the its. 00:00 03:30 3.50 COMPZ WHDBO NUND P Nippling down ROPE. Flush and grease cavites of BOP's. Remove rams. Grease BOPE. Draining hot well f/ boilers. Cleaning its. 03:30 06:00 2.50 COMPZ WHDBO NUND P Terminate control lines. Nipple up tree per Vetco Gray service rep. 06:00 07:30 1.50 COMPZ WHDBO PRTS P Test hanger neck metal to metal seal to tubing head adapter. Testing API ring as well. Test to 5000 psi f/ 8 minutes. OK. Test tree to 250 psi low and 4400 psi high f/ 5 min each, charted test. OK. 07:30 08:00 0.50 COMPZ WHDBO RURD P Rig down testing equipment, blow down lines. Secure cellar. 08:00 09:00 1.00 COMPZ MOVE RURD P Blow down water lines, rig down air and water lines. clean rockwasher. Rig released at 0900 hrs 7-5-2010. Note: 4600 psi on the 1/4" SSSV control line at 2200 hrs 7-5-2010. Page 25 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 12:30 3.50 DEMOB MOVE RURD P Rigging down the pump room, and mud pits. Pick up top drive cradle, slack off the top drive and secure in the cradle. Rig down service loop f/ top drive. Sppol up the service loop in the top drive house. Remove top drive from the rig floor with Peak Oilfield Services crane. 12:30 15:00 2.50 DEMOB MOVE RURD P Bridle up block to the derrick. Secure derrick to scope down. Continue to riq down pump room and mud pits. 15:00 16:30 1.50 DEMOB MOVE RURD P Scope down derrick. Rig down lower section of torque tube. 16:30 18:00 1.50 DEMOB MOVE RURD P Secure derrick for laying over. Remove roof caps over the drawworks. 18:00 18:15 0.25 DEMOB MOVE RURD P Pre job safety meeting. 18:15 20:00 1.75 DEMOB MOVE RURD P Rig down derrick board. Remove wind walls. Continue to prepare ower pack for rig move. 20:00 00:00 4.00 DEMOB MOVE RURD P Rigging down windwalls around the rig floor, using Peak crane, and using manlift. Rig down beaver slide, secure motor room and pump rooms for moving. Continue rigging down and pulling electrical wires. Continue riggingdown wind walls in the pits. 7/06/2010 Continue to rig down lines in the pits, wind walls in the pits. Secure derrick to lay over. Pre job safety meeting on laying derrick over. Lay derrick over with hydraulic cylinders. Continue to prepare for moving rig. Pull, then spool communication cable to the camp/office. Pull and store hoses for interconnect from sub base to power pack. Pull hand rails from pits to pump room on top of modules. Rig down standpipe manifold, stack windwalls, rig down floor tools and equipment. Unstring blocks. Slip drilling lineback onto the wireline spool with peak crane. Con't to prepare complexes to load out. Pre job safety meeting on moving pieces to CottonWood camp. Peak Oilfield Services move shop, matting boards, windwalls, rockwasher, poor boy degasser, derrick board, motors, boiler, MCC, pumps, pipe sheds, top drive, centrifuge, misc pieces to CottonWood camp. Move center section of pipe shed (catwalk), move water tank, move top drive power unit. Seperate pits, pulled shakers and haul to cottonwood.. Moved BOP dolly out of sub. Load out mats and misc loads. 00:00 00:15 0.25 DEMOB MOVE RURD P Continue to rig down lines in the pits, wind walls in the pits. Secure derrick to la over. 00:15 00:30 0.25 DEMOB MOVE SFTY P Pre job safety meeting on laying derrick over. 00:30 01:00 0.50 DEMOB MOVE RURD P Lay derrick over with hydraulic c linders. 01:00 06:00 5.00 DEMOB MOVE RURD P Con"t to prepare for moving rig. Pull, then spool communication cable to the camp/office. Pull and store hoses for interconnect from sub base to power pack. Pull hand rails from pits to pump oom on top of modules. Page 26 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:00 10:30 4.50 DEMOB MOVE RURD P Rig down standpipe manifold, stack windwalls, rig down floor tools and equipment. Unstring blocks. Slip drilling lineback onto the wireline spool with peak crane. Con't to prepare complexes to load out. 10:30 10:45 0.25 DEMOB MOVE RURD P Pre job safety meeting on moving feces to CottonWood camp. 10:45 18:00 7.25 DEMOB MOVE RURD P Peak Oilfield Services move shop, matting boards, windwalls, rockwasher, poor boy degasser, derrick board, motors, boiler, MCC, pumps, pipe sheds, top drive, centrifuge, misc pieces to CottonWood camp. 18:00 00:00 6.00 DEMOB MOVE RURD P Move center section of pipe shed (catwalk), move water tank/dog house, move top drive power unit. Seperate pits, pulled shakers and haul to cottonwood. Moved BOP dolly out of sub. Load out mats and misc loads. 7/07/2010 Continue to rig down the pits: Pull possum belly, lower roof cap on pit #1. Load out mats and misc loads. Organize loads to be moved. Rid down and move two pit complexes. Move Top drive power connex. Remove derrick from sub, set on trailer, then secure load. Pick drawworks skid and load on truck, then secure load. Pick sub structure, then load and secure. Move all loads to CottonWood pad and stack. Pick up herculite, clean pad. Load out mats to Cottonwood. Break down pumps for stack out. Secure loads at Cottonwood for stack out. Move misc. equipment from BRU 212 pad to CottonWood. Vetco Gray loosened tbg head adapter bolts, rotated tree to align with plan. 011ie observed and was OK with alignment. Tightened bolts. Tested tbg Head void to 5000 psi- OK. Vetco Gray set VR plug, then rotated upper annulus to upright position, tightened back up and tested to 5000 psi. Vetco Gray installed cross and wing valve. Vetco ray tested tree to 5000 psi above u per master valve. Good test. 00:00 06:00 6.00 DEMOB MOVE RURD P Continue to rig down the pits: Pull possum belly, lower roof cap on pit #1. Load out mats and misc loads. Or anize loads to be moved. 06:00 12:00 6.00 DEMOB MOVE RURD P Rid down and move two pit complexes. Move Top drive power connex. Remove derrick from sub, set on trailer, then secure load. Pick drawworks skid and load on truck, then secure load. Pick sub structure, then load and secure. Move all loads to CottonWood pad and stack. 12:00 18:00 6.00 DEMOB MOVE RURD P Pick up herculite, clean pad. Load out mats to Cottonwood. Break down pumps for stack out. Secure loads at Cottonwood for stackout. Page 27 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 DEMOB MOVE RURD P Move misc. equipment from BRU 212 pad to CottonWood. Note: Vetco Gray loosened tbg head adapter bolts, rotated tree to align with plan. 011ie observed and was OK with alignment. Tightened bolts. Tested tbg Head void to 5000 psi- OK. Vetco Gray set VR plug, then rotated upper annulus to upright position, tightened back up and tested to 5000 psi. Vetco Gray installed cross and wing valve. Vetco Gray tested tree to 5000 psi. Good test. Page 28 of 28 ConocoPhillips Time Log &Summary WelNiew Web Reporting Report Well Name: BRU 212-24T Rig Name: BJS CTU J158 Job Type: INITIAL COMPLETION Rig Accept: 7/12/2010 6:00:00 AM Rig Release: 8/20/2010 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 7/08/2010 24 hr Summary VETCO COMPLETED TREE TEST TO 5,000 PSI, GOOD TEST. SITE INSPECTION COMPLETED AFTER DRILLING PROGRAM. OPERATIONS WORKING ON WELLHEAD, IN PROGRESS. 06:00 12:00 6.00 COMPZ WHDBO DHEQ P VETCO COMPLETES TREE TEST TO 5,000 PSI. PULLED TWO WAY CHECK, RDMO VETCO. 12:00 14:00 2.00 COMPZ MOVE RURD P REMOVE REMAINING DRILLING EQUIPMENT. 14:00 15:00 1.00 COMPZ MOVE OTHR P SITE INSPECTION COMPLETE. 15:00 18:00 3.00 COMPZ WHDBO NUND P OPERATIONS SPENT REST OF DAY WORKING ON WELLHEAD, GRATING FOR CELLAR, INSTALL SSV AND SPOOL EQUIPMENT. 7/09/2010 OPERATIONS COMPLETED TIE-IN WORK. CONTINUE TO BUILD CONTAINMENT AND SPOT PTS SURFACE EQUIPMENT. 06:00 22:00 16.00 COMPZ MOVE RURD P OPERATIONS COMPLETED TIE-IN WORK. CONTINUE TO BUILD CONTAINMENT AND SPOT PTS SURFACE EQUIPMENT. 7/10/2010 CONTINUE WITH CONTAINMENT SET-UP AND RIG -UP PTS SURFACE EQUIPMENT. LAY OUT AND BUILD TANK FARM. 06:00 22:00 16.00 COMPZ MOVE RURD P CONTINUE WITH CONTAINMENT SET-UP AND RIG -UP PTS SURFACE EQUIPMENT. LAY OUT AND BUILD TANK FARM. 07/11/2010 CONTINUE WITH PTS HARDLINE RIG -UP, BUILD CONTAINMENT FOR TANK FARM, SPOT FRAC TANKS/ SUPPLY TANKS. SPOT MI SWACO SURFACE EQUIPMENT.CONTINUE WITH PTS HARDLINE RIG -UP, MAKE UP MI SWACO SURFACE EQUIPMENT. HOLD PRE COMPLETION MEETING. SPOT SAND KING AND HYDRATION UNIT, SPOT BJ COIL SURFACE EQUIPMENT. 06:00 22:00 16.00 COMPZ MOVE RURD P CONTINUE WITH PTS HARDLINE RIG -UP, BUILD CONTAINMENT FOR TANK FARM, SPOT FRAC TANKS/ SUPPLY TANKS. SPOT MI SWACO SURFACE EQUIPMENT. 7/12/2010 CONTINUE WITH PTS HARDLINE RIG -UP, MAKE UP MI SWACO SURFACE EQUIPMENT. HOLD PRE COMPLETION MEETING. SPOT SAND KING AND HYDRATION UNIT, SPOT BJ COIL SURFACE EQUIPMENT. 06:00 06:30 0.50 COMPZ MOVE SFTY P OPERATIONS MEETING 00:30 01:00 0.50 COMPZ MOVE SFTY P PRE TOUR MEETING 01:00 06:30 5.50 COMPZ MOVE RURD P MAKE UP MI SWACO SURFACE EQUIPMENT, LOAD SUPPLY TANK WITH 400 BBLS FRESH WATER. 06:30 08:30 2.00 COMPZ MOVE SFTY P PRE COMPLETION MEETING Page 1 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 7/12/2010 24 hr summary CONTINUE WITH PTS HARDLINE RIG -UP, MAKE UP MI SWACO SURFACE EQUIPMENT. HOLD PRE COMPLETION MEETING. SPOT SAND KING AND HYDRATION UNIT, SPOT BJ COIL SURFACE EQUIPMENT. 08:30 11:30 3.00 COMPZ MOVE RURD P MAKE UP MI SWACO SURFACE EQUIPMENT, LOAD SUPPLY TANK WITH 400 BBLS FRESH WATER. 11:30 16:00 4.50 COMPZ MOVE RURD P SPOT SAND KING AND HYDRATION UNIT WITH PEAK CRANE. SPOT BJ COIL SURFACE EQUIPMENT. 7/13/2010 CONTINUE WITH PTS HARDLINE RIG -UP, MAKE UP TO WELLHEAD. MAKE UP MI SWACO SURFACE EQUIPMENT, ELECTRICIAN INSTALL BREAKER PANEL, CLEAN TANKS AND TEST MANIFOLD SYSTEMS ON FRAC TANKS, BATCH FIRST LOAD OF 6% KCL. SPOT BJ COIL SURFACE EQUIPMENT AND RIG UP HARDLINE, SPOT FRAC EQUIPMENT. 06:00 06:30 0.50 COMPZ MOVE SFTY P OPS MEETING 00:30 01:00 0.50 COMPZ MOVE SFTY P DAILY PRE TOUR MEETING 01:00 14:00 13.00 COMPZ MOVE RURD P CONTINUE WITH PTS HARDLINE RIG -UP, MAKE UP TO WELLHEAD. MAKE UP MI SWACO SURFACE EQUIPMENT, ELECTRICIAN INSTALL BREAKER PANEL, CLEAN TANKS AND TEST MANIFOLD SYSTEMS ON FRAC TANKS, BATCH FIRST LOAD OF 6% KCL. SPOT BJ COIL SURFACE EQUIPMENT AND RIG UP HARDLINE, SPOT FRAC EQUIPMENT. 7/14/2010 COMPLETE PTS RIG UP AND LOAD SURFACE EQUIPMENT WITH WATER. MIRU POLLARD W/L, PERFORM INITIAL POST RIG SLICKLINE. MI SWACO CONTINUE TO MIX AND LOAD KCL. SPOT HES E -LINE UNIT. 06:00 06:30 0.50 COMPZ MOVE SFTY P OPS MEETING 00:30 01:00 0.50 COMPZ MOVE SFTY P DAILY PRE TOUR MEETING 01:00 11:00 10.00 COMPZ RPEQPI SLKL P CONTINUE MIXING AND LOADING 6% KCL. MIRU POLLARD S/L WITH PEAK 65 TON CRANE, VERIFY FUILD TO SURFACE ON TBG & IA. MAKE UP LUBRICATOR AND TOOLSTRING, LUBRICATOR TO WELLHEAD. RIH W/ 2.75" CENT & 2" RB TO 4,880'WLM, POOH W/O BALL & ROD, RIH W/ 2" RB TO 4,880'WLM, LATCH & PULL BALL & ROD, POOH. RIH W/ 3" GS TO 4,885'WLM, LATCH & PULL RHC PLUG BODY, POOH. RIH W/ 2.679" G -RING TO 6,356'WLM, NO PROBLEMS, RIH W/ 20'x 2.65" SPENT PERF GUN TO 6,356'WLM, POOH. RDMO POLLARD. ASSIST PTS WITH FLARE EXTENSION (MAN LIFT) Page 2 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:00 13:00 2.00 COMPZ MOVE RURD P HES ARRIVED ON LOCATION, CHECK EQUIPMENT ON TRIPLE NORTH. PTS COMPLETED SURFACE EQUIPMENT TEST. MI SWACO MIXED 1000 BBLS 12% KCL, WILL ADD WATER AND DILUTE TO 6 % TOMORROW. 13:00 16:00 3.00 COMPZ MOVE ELNE P SPOT HES E -LINE EQUIPMENT 7/15/2010 DURING PTS SURFACE EQUIPMENT TEST FOUND LEAK AT VETCO SSV, UNABLE TO REPAIR, INSTALL REPLACEMENT SSV, WILL RETEST SURFACE EQUIPMENT IN AM. MIX AND LOAD REMAINING KCL FOR TOTAL OF 2,000 BBLS. HES E -LINE EQUIPMENT SPOTTED READY FOR PERF GUN RUN. 06:00 06:30 0.50 COMPZ FLOWT SFTY P OPS MEETING 00:30 01:00 0.50 COMPZ FLOWT SFTY P DAILY PRE TOUR MEETING 01:00 02:30 1.50 COMPZ FLOWT ELOG P START RIGGING UP HES E -LINE EQUIPMENT. CONTINUE TO MIX AND LOAD KCL. PTS START WITH PT OF SURFACE EQUIPMENT. 02:30 03:30 1.00 COMPZ FLOWT SFTY P FLOW BACK HAZARD OBSERVATION MEETING WITH PTS AND BJ COIL CREWS. 03:30 06:30 3.00 COMPZ FLOWT ELOG P CONTINUE WITH HES RIG -UP. MIX AND LOAD KCL. DURING PTS PT DISCOVERED FLANGE LEAKING ON SSV, CALL OUT VETCO GRAY. 06:30 12:00 5.50 COMPZ FLOWT ELOG T VETCO GRAY ARRIVED ON LOCATION, TROUBLESHOOT SSV, STROKE SSV SEVERAL TIMES AND RETEST, SSV STILL LEAKING, TEAR DOWN UPPER BONNET ON SSV, FOUND ROLLED INTERNAL SEAL. CALL VETCO FOR REPLACEMENT SSV OR NEW SEAL. REPLACEMENT SSV COMING. 12:00 16:00 4.00 COMPZ FLOWT ELOG T VETCO REMOVED AND INSTALLED REPLACEMENT SSV. WILL TEST SSV IN MORNING. 7/16/2010 COMPLETE PT OF PTS SURFACE EQUIPMENT, MAKE UP METHANOL HIGH POINT INJECTION PUMP SYSTEM. RIG UP HES E -LINE LUBRICATOR TO SHOOT PERF INTERVAL @ 6,022' - 6,036'MD, ALL SHOTS FIRED. ATTEMPT INJECTIVITY TEST, FUILD LEVEL APPROXIMATELY 2501, PUMPED 2.2 BBLS AWAY, TBG PRESSURE 3,000 PSI, BLEED OFF TBG, RDMO HALLIBURTON. 06:00 06:30 0.50 COMPZ FLOWT SFTY P OPS MEETING 00:30 01:00 0.50 COMPZ FLOWT SFTY P DAILY PRE TOUR MEETING 01:00 04:00 3.00 COMPZ FLOWT PRTS P PT FUILD SIDE SURFACE EQUIPMENT TO 3,500 PSI, LEAK AT SAND CATCHER @ 1,500 PSI, MAKE REPAIRS, RETEST TO 3,500 PSI, GOOD TEST, RIG UP FOR METHANOL INJECTION AT HIGH POINT OF FLOW PATH. MAG TEC RIG UP EQUIPMENT FOR HEATING FRAC TANKS. Page 3 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 04:00 11:00 7.00 COMPZ FLOWT ELOG P MAKE UP E -LINE JARS/CCUGAMMA AND 2.5" TITAN PROSPECTOR CHARGES, 60 DEGREE PHASING, 6 SPF, STAB ON LUBRICATOR, PT LUB. 3,000 PSI, OPEN WELL, START IN HOLE, MAKE TWO LOGGING PASSES TO VERIFY CORRELATION, STOP GAMMA @ 6,007'MD, TOP SHOT 15' BELOW GAMMA, PERF INTERVAL 6,022'- 6,036'MD, FIRE GUNS, GOOD INDICATE INSIDE OF SHOTS FIRE, HOWEVER NO INDICATES OUTSIDE, NOTHING FELT ON CABLE AND NO PRESSURE CHANGE, LOG OUT OF HOLE. LAY DOWN SPENT GUNS, ALL SHOTS FIRED. 11:00 12:00 1.00 COMPZ FLOWT PRTS P BJ PUMPED 1.9 BBLS TO FILL TBG, ATTEMPT INJECTIVITY TEST, 2.2 BBLS AWAY TOTAL, TBG PRESSURED UP TO 3000 PSI, BLEED TBG OFF. 12:00 14:00 2.00 COMPZ FLOWT RURD P RIG DOWN HES E -LINE EQUIPMENT. 7/17/2010 PERFORM INITIAL BJ COIL BOPE TEST. LINE UP TO TAKE RETURNS THROUGH PTS EQUIPMENT, START IN WITH COIL TO TUBING TAIL @ 4,880'CTM, PUMPING N2 @ 350 SCF/M, RECOVERED 45 BBLS OF WATER FROM TUBING, WITH NO INDICATION OF FLOW. POOH WITH COIL, RACK BACK INJECTOR, LEAVE BOPE EQUIPMENT ON WELLHEAD FOR NIGHT. SHOT FUILD LEVEL WITH POLLARD ECHOMETER @ 3,850'MD, PTS WILL MONITOR WELL FOR FLOW THROUGHOUT NIGHT, WILL CHECK FUILD LEVEL IN AM. BJ FRAC CREW CONTINUES TO RIG UP FRAC EQUIPMENT. 06:00 06:30 0.50 COMPZ FLOWT SFTY P OPS MEETING 00:30 01:00 0.50 COMPZ FLOWT SFTY P PRE TOUR MEETING 01:00 06:00 5.00 COMPZ FLOWT BOPE P PERFORM INITIAL BJ COIL BOPE TEST, MI SWACO CONTINUE TO ROLL 6% KCL, MAGTEC STILL STRUGGLING WITH STEAM TRUCK OPERATION, CALL OUT PEAK MECHANIC, CONTINUE WORKING ON STEAM TRUCK. Page 4 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 COMPZ FLOWT CTOP P LINE UP TO TAKE RETURN THROUGH PTS SEPARATOR, RIH W/ 2.00" NOZZLE @ 1,265 -CTM STOP COIL, START N2 AT 350 SCF/M, AFTER 30 MINS PUMPING HAD N2 TO SURFACE. RIH W/ COIL WEIGHT CHECK @ 2,500'CTM 5,500#, CONTINUE IN HOLE TO 3,000'CTM, CONTINUE PUMPING N2 AT 350 SCF/M, WATER & N2 TO SURFACE, PARK COIL @ 3,050'CTM FOR 30 MINS, APPROXIMATELY 30 BBLS WATER RECOVERED. TAKE 200' BITES TO 4,880'CTM, PARK COIL 30 MINS, INCREASE N2 TO 400 SCF/M FOR 30 MINS, TOTAL OF 45 BBLS WATER RECOVERED, JUST CIRCULATING N2 TO SURFACE, SHUT DOWN N2, POOH W/ COIL. ON SURFACE WITH COIL, RACK BACK INJECTOR, LEAVE BOP'S ON WELLHEAD FOR NIGHT. PTS WILL CONTINUE MONITORING WELL FOR FLOW THROUGH NIGHT. FRAC CREW ARRIVE ON LOCATION. 12:00 16:00 4.00 COMPZ FLOWT OPNW P BJ FRAC CREW CONTINUE TO RIG UP FRAC EQUIPMENT, POLLARD ARRIVED ON LOCATION TO SHOOT FUILD LEVEL IN TUBING, SHOT LEVEL FOUR TIMES, FUILD LEVEL @ 3,850' MD WITH ECHOMETER, WILL SHOOT FUILD LEVEL IN AM. 7/18/2010 POLLARD SHOT FUILD LEVEL @ 2,850'MD WITH 60 PSI ON WHP. PTS CONTINUES TO MONITOR WELL DURING FLOWBACK OPERATIONS, CURRENTLY FLOWING @.011 MMSCFD WITH 60 PSI WELLHEAD, NO WATER. MAGTEC CONTINUES TO HEAT THREE FRAC TANK FOR UPCOMING FRAC. BJ FRAC CREW CONTINUES TO SPOT EQUIPMENT, LOAD SAND KING, HAMMER UP SURFACE LINES. 06:00 07:00 1.00 COMPZ FLOWT SFTY P WEEKLY OPS SAFETY MEETING 01:00 02:00 1.00 COMPZ FLOWT SFTY P PRE TOUR MEETING 02:00 04:00 2.00 COMPZ FLOWT CTOP P POLLARD SHOT FUILD LEVEL @ 2,850' MD WITH 60 PSI WHP. DECISION MADE TO FLOWBACK THROUGH PTS TO MONITOR WELL OVER NEXT 24 HOURS. RIG DOWN BJ BOPE EQUIPMENT FROM WELLHEAD, SECURE WELLHEAD. MAGTEC CONTINUES TO HEAT TANKS @ 14:00 TODAY THREE TANKS WERE +/- 80 DEGEES, WILL START ON ADDITIONAL TANK. Page 5 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 04:00 15:00 11.00 COMPZ FLOWT RURD P BJ FRAC CREW SPOTS REMAINING EQUIPMENT, HAMMER UP HARD LINE, LOAD SAND KING WITH FRAC SAND. 7/19/2010 SHUT DOWN FLOW BACK OPERATIONS THROUGH PTS. BJ FRAC CREW COMPLETED PREPPING SURFACE EQUIPMENT FOR FRAC. MAGTEC HEATED ADDITIONAL TANK TO 80 DEGREES FOR TOTAL OF FOUR. MIRU POLLARD FOR PRE-FRAC S/L OPERATIONS. HAD DIFFICULTY WITH TBG PT AFTER SETTING 1"SPARTEK 4,808'WLM, WILL CONTINUE S/L OPERATIONS THROUGHOUT NIGHT. 06:00 06:30 0.50 COMPZ STIM SFTY P OPS MEETING 00:30 01:00 0.50 COMPZ STIM SFTY P DAILY PER TOUR MEETING 01:00 06:00 5.00 COMPZ STIM SLKL T WAITING ON POLLARD CREW DUE TO LOW VISIBILITY. 06:00 07:00 1.00 COMPZ STIM SLKL P MIRU POLLARD EQUIPMENT, PT LUB 3,000 PSI. 07:00 18:00 11.00 COMPZ SLKL T BJ FRAC CREW CONTINUES READY EQUIPMENT FOR FRAC IN AM. MAGTEC HEATED ADDITIONAL TANK TO 80 DEGREES, FOUR TANK IN ALL HEATED AND READY. RIH W/ 2.25" BAILER TO 6,356'WLM TAG BTM, POOH. RIHW/ 3.5" X -LINE & 2.81" PXN PLUG BODY TO 4,887'WLM SET PLUG, POOH, FLUID LEVEL @ 3,275'WLM. RIH W/ 2" SB & 3' P PRONG TO 4,886'WLM SET PRONG, POOH. RIH W/ 3" GS & CATCHER SUB TO 4,882'WLM SET CATCHER, POOH. RIH W/ 3.5" DANIELS KOT & 1.25" JDS TO 4,808'WLM, LATCH DMY VALVE, PT BJ LINES 3,500 PSI, LOAD TUBING WITH 25.4 BBLS KCL, PRESSURE TBG TO 800 PSI, PULL 1" DV, POOH W/DMY. START SPARTEK GAUGE 19:30 ON 7/19/10. RIH W/ 3.5" DANIELS KOT & 1" SPARTEK ON BK LATCH TO 4,808'WLM, LOCATE BUT UNABLE TO SET DOWN, POOH. RIH W/ 3.5" OK -1 & SPARTEK TO 4,808'WLM, SET VALVE, POOH. BLED CASING FROM 680 TO 200 PSI, SHUT IN IA, BLEEDS BACK TO TBG PRESSURE, ATTEMPT TWICE WITH SAME RESULTS, IA TRACKING TBG. RIH W/ 3.5" OK -1 & 1.25" JDS TO 4,808'WLM, LATCH & PULL SPARTEK, POOH, PACKING NOT DAMAGED. CHANGE PACKING ON SPARTEK FROM VITON TO REGULAR V PACKING. CONTINUE WITH PRE-FRAC IN PROGRESS. Page 6 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 7/20/2010 24 hr Summary Continiue w/ Pollard pre-frac S/L operations. Set 1" SPG @ 4800' MD, set start time on Spartek gauge 19:30 on 7/19/2010. PT tbg to 3500 psi (good test). Set 2.81" OD frac sleeve @ 494' MD. Tested lower MV to 3350 psi. PT IA to 3100 psi (good test). Set tree saver, pumped data frac, pumped mini-frac. will analize data and speak with partners and Houstion in the AM. LDFN 00:00 02:00 2.00 COMPZ STIM SLKL P CONTINUE WITH POLLARD S/L FROM PREVIOUS DAY. RIH W/ 3.5" OK -1 & 1" SPARTEK (STANDARD V -PACKING) WITH BK LATCH TO 4,808'WLM SET SPG, POOH. PT TBG TO 3,500 PSI, ONLY TOOK 2.5 BBLS TO PRESSURE UP TO 3,500 PSI, IA PRESSURE 625 PSI, MONITOR 30 MINS, TBG 3,375 PSI IA 625 PSI, GOOD TEST. SHUT LOWER MOST MASTER VALVE WITH 3,350 PSI ON TBG, TEST MASTER BY BLEEDING LUBRICATOR ABOVE TO 0 PSI, MADE TOOL CHANGE, MASTER HOLDING GOOD. 02:00 06:00 4.00 COMPZ STIM SLKL P RIH W/ 3" GS TO 4,882'WLM LATCH & PULL CATCHER SUB, POOH W/ CATCHER. RIH W/ 2" SB TO 4,885'WLM, LATCH & PULL EQUALIZING PRONG, PRESSURE FELL FROM 500 TO 400 PSI, POOH W/ PRONG. RIH W/ 3" GS TO 4,887'WLM LATCH & PULL PLUG BODY, POOH. RIH W/ 3" GS & 2.81" FRAC SLEEVE WITH 2.31" ID (TL 80") TO 498'WLM, SET SLEEVE ACROSS SSSV, POOH. RDMO POLLARD W/L. 06:00 10:00 4.00 COMPZ STIM RURD P WAITING ON CRANE OPERATOR WHO WAS HOURED OUT TO WAKE UP. 10:00 16:00 6.00 COMPZ STIM RURD P RU STINGER TREE SAVER. 16:00 16:30 0.50 COMPZ STIM SFTY P PERFORM PJSM FOR DATA FRAC. 16:30 17:30 1.00 COMPZ STIM STIM P PT LINES TO 6258 PSI, TEST POP OFF'S 17:30 18:00 0.50 COMPZ STIM STIM P Start pumping DFIT at 3.1 BPM (first gear). Pumping straight 6%KCI with Claymaster5C & Flowback-30, Pumping 6.6 bpm @ 3683 psi. Hard shut down at 50 bbl pumped. JM time — 60. 50 bbls through perfs for DFIT. 18:00 20:00 2.00 COMPZ STIM STIM P Completed DFIT analysis. Closure at 16.9 minutes after pump shut down. Radial flow period not observed. DFIT calculated permeability = 0.11 mD. Page 7 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:00 21:00 1.00 COMPZ STIM STIM P Shift to stage 3 in Jobmaster. Start pumping mini-frac. Max rate 7.7 bpm @ 3950 psi wellhead pressure. Shut down pumping after pumping for 3.5 minutes due to high pressure/low rate. 20.7 bbls through perfs for mini-frac attempt. Decide to pump linear gel. Start witness of bucket test. 21:00 21:30 0.50 COMPZ STIM STIM T Hose ruptured on XLW-32 line. Estimating 0.5 gallons into secondary containment. Notified Kuparuk security. Called for vac truck to suck out secondary containment to be sent to Class1 disposal well. 21:30 22:00 0.50 COMPZ STIM STIM P Bucket test complete. 22:00 23:00 1.00 COMPZ STIM STIM P Start reattempt of minifrac with linear fluid. 6.2 BPM@ 3942 psi. 7.7 BPM@ 4036 psi. 7.7 BPM@ 4037 psi. 81 bbls away (85 bbl to perfs) Pump 2 down on kick off (set at 4000 psi). 6.8 BPM @ 4053 psi. 109 bbls away. Go to flush at 121 bbls away. Kill chemicals except for Flowback 30 and Claymaster 5c. Flushing at 5.6 BPM, 3925 psi. Flush complete. 85 bbls away. Shut down pumps. 295 bbls pumped total for the day. Bleed down IA to 200 psi. 23:00 00:00 1.00 COMPZ STIM STIM P Rig down and send crews home. Will continue operations at 10AM. Need to work issues with MAWP - we will need more pressure to frac. Will discuss with Houston and Anchorage team in AM. D7/21/201 0 Reset pop -offs to 4737 psi w/ pump kickouts set at 4500, 4550 & 5000 psi for modified frac. Able to pump 11.2 bpm w/ 6% Kcl @ 4060 psi. Rolled into 65 bbl Scour stage w/.5 ppa proppant @ 10.4 bpm @ 4020 psi. Well broke over allowing complete 4 stage frac of 1,2,4 & 6 ppa placing 57,326 lbs of 20/40 carbolite proppant into formation. MIRU Pollard SLunit and pulled frac sleeve, tag sand @ 5508' slm. MIRU BJ coil for AM start. 00:00 06:30 6.50 COMPZ STIM SFTY P Perform morning crew meeting. 06:30 10:30 4.00 COMPZ STIM SFTY P Talk w/ town and make plan forward w/ frac. 10:30 11:00 0.50 COMPZ STIM SFTY P Pre-frac safety meeting 11:00 11:30 0.50 COMPZ STIM P reset pop -offs to 4737 psi on N2 for treatment line, and set frac pumps to trip @ 4500, 4550 & 5000 psi. 11:30 11:45 0.25 COMPZ STIM P WHP 850 psi, open stinger valve and ready lines to pump. Page 8 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:45 12:15 0.50 COMPZ STIM P Start pumping 6% Kcl @ 2.4 bpm @ 2972 psi, increase rate to 7.2 bpm & 4127 psi, increase to 8.6 bpm & 4014 psi (break over point). Increased rate to 11.2 & 4060 psi, w/ 65 bbls away, start scour stage. 12:15 12:45 0.50 COMPZ STIM P Start pumping .5 ppa scour stage @ 10.4 bpm & 4020 psi. 12:45 13:15 0.50 COMPZ STIM P Continue pumping @ 11.2 BPM @ 3991 psi to complete scour stage, swapback to pad. 13:15 13:30 0.25 COMPZ STIM P Pad pumped @ 15.5 bpm & 4259 psi. All scour stage is to formation). 13:30 13:45 0.25 COMPZ STIM P Start 1 ppa stage @ 15.5 bpm, once at perfs start 2 ppa stage @ 15.4 bpm & 4049 psi, once 2 ppa @ perfs start 4 ppa stage @ 15.8 bpm & 3921 psi, once 4 ppa @ perfs start 6 a sta a@ 15.6 bpm & 3973 psi. 13:45 14:00 0.25 COMPZ STIM P Swap to flush and attempt to stage and drop rate to 5 bpm, try to stage sand @ -100' above perfs with 57,326 lbs of 20/40 mesh carbolite into formation. 14:00 17:00 3.00 COMPZ STIM P RDMO frac unit and tree saver. 17:00 19:00 2.00 COMPZ SLKL P MIRU Pollard slickline and pull frac sleeve @ 481' wlm, tag fill @ 5508' wlm. RDMO 19:00 22:00 3.00 COMPZ BOPE P BJ coil on location nippling up BOPE for an AM start. 7/22/2010 Perform BOP test, perform FCO to 6020' ctmd, (heavy sand returns w/ 2:1 return ratio). After bottoms up w/ final HEC gel sweep, SD coil pump for 15 minutes, performed flow check of well. Well continued to flow for 15 minutes @.5 bpm w! 10 psi +/- whp. POOH and perform another 30 minute flow check, well still flowing at .5 bpm ill allow PTS to flow over night and evaluate in the AM if N2 lift is re uired. 22:00 06:00 8.00 COMPZ STIM CTOP P Load tanks w/ water for making 6% Kcl. 08:00 12:30 4.50 COMPZ STIM BOPE P Perform BOP test. Make up BHA of 1.75" Vortex nozzle. 12:30 12:45 0.25 COMPZ STIM CTOP P PJSM for FCO 12:45 14:45 2.00 COMPZ STIM CTOP P Open WH w/ 1350 psi SIP, RIH dry to 5400'. Online w/ pump @ 1.5 bpm be in RIH 10 f m to 5550' ctmd. 14:45 15:45 1.00 COMPZ STIM CTOP P RIH to 5550' (heavy sand returns at surface, return ratio 2:1). PUH to TT and wait for a bottoms u . 15:45 16:45 1.00 COMPZ STIM CTOP P RIH to 5650'w/ 1.51b HEC at nozzle, chace gel sweep to surface w/ heavy sand returns. 16:45 17:45 1.00 COMPZ STIM CTOP P RIH w/ 6% Kcl at nozzle to 5750' ctmd, chase bottoms up to TT. 17:45 18:45 1.00 COMPZ STIM CTOP P RIH w/ 6% Kcl at nozzle to 5900', sand returns tapering off to just a trace. 18:45 19:45 1.00 COMPZ STIM CTOP P RIH w/ 6% Kcl at nozzle to 6000' ctmd, no sand in returns, PUH 50'. Page 9 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:45 20:45 1.00 COMPZ STIM CTOP P RIH w/ 1.51b HEC gel at nozzle to 6020' ctmd wait for Kcl to nozzle and chase gel sw ep back to TT. 20:45 22:45 2.00 COMPZ STIM CTOP P PUH and wash past GLM @ 4800', stop coil, SD pump and perform flowcheck of well. Well continued to flow @ 5 bpm for 15 minutes. POOH 22:45 02:00 3.25 COMPZ STIM CTOP P Once at surface, performed another flow check of well, the well continued to flow @.5 bpm w/ 15 psi +/- WHP to tanks. Hand well over to PTS to flow for the night. LDFN coil unit. 7/23/2010 Flow check well over night, well flowed 56 bbls of water (no gas) over night. MIRU BJ Coil, RIH to 1000' while pumping 325,000 scfpd N2 per day. Waited for N2 @ nozzle, start tripping in @ 50 fpm. Performed N2 lift down to 6000' ctmd, recovered 85 bbls of water during lift. Once at surface, well only producing 19,000 scfpd of gas w/ 15 psi whp (no water). MIRU slickline and tagged fill @ 5924' wlm. (Roughly 70' of fill above perfs). Gave well to PTS to flow over night LDFN. 00:00 06:00 6.00 COMPZ STIM OPNW P Flow test well through PTS, well produced 56 bbls of water. 06:00 06:30 0.50 COMPZ STIM CTOP P Held PJSM 06:30 07:30 1.00 COMPZ STIM CTOP P Make up BHA and test surface Iron. 07:30 09:00 1.50 COMPZ STIM CTOP P Open well and RIH to 1000', on-line w/ 320k nz park and wait for n2 to reach nozzle. 09:00 11:00 2.00 COMPZ STIM CTOP P Continue to RIH to below TT @ 5000' ctmd, park coil and allow well to unload. Still pumping 325,000 scfpd N2. Returns showing 400,000 as returns. 11:00 12:00 1.00 COMPZ STIM CTOP P RIH to 5200' for 30 minutes, allow well to unload. 12:00 13:00 1.00 COMPZ STIM CTOP P RIH to 5400' ctmd, allow well to unload for 30 minutes. 13:00 13:30 0.50 COMPZ STIM CTOP P RIH to 5600' ctmd, allow well to unload for 15 minutes. 13:30 14:30 1.00 COMPZ STIM CTOP P RIH to 5800' ctmd, allow well to unload for 15 minutes. Well producing water at a rate of .21 bpm no sand). 14:30 15:30 1.00 COMPZ STIM CTOP P RIH to 6000' ctmd, allow well to uload for 30 minutes. POOH 15:30 16:00 0.50 COMPZ STIM CTOP P SD N2 @ 2600' ctmd. 16:00 17:00 1.00 COMPZ STIM CTOP P At surface, hand well over to PTS, RB coil unit. After one hour, well only roducin 15-19,000 scfpd gas. 17:00 20:00 3.00 COMPZ STIM SLKL P MIRU pollard slickline, SI well and tagged sand @ 5924' wlm. (Roughly 70 of fill above perfs). Bailer full of crushed carbolite. RDMO 20:00 00:00 4.00 COMPZ STIM OPNW P Flow well through PTS for remainder of the evening. Page 10 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 7/24/2010 24 hr Summary Allow PTS to flow well over night, well died at 8:00 pm with no gas or water flow. MIRU BJ coil and performed FCO down to 6300' ctmd. Heavy frac and formation sand in returns. Performed N2 lift to kick well off pumping 325,000 SCFPD of N2 down to 6000', until well was circulating out mostly N2 with very little water in returns. Checked gas returns for LEL readin s, none found. Hand well over to PTS to flow over night. 00:00 06:00 6.00 COMPZ FLOWT OPNW P PTS flow check well through the night. No flow indicated after 8:00 Pm. WH P 0 psi. 06:00 08:00 2.00 COMPZ STIM FCO P MIRU BJ Coil w/ 1/75" Vortex nozzle. 08:00 10:00 2.00 COMPZ STIM FCO P RIH while pumping 1.5 bpm to condition well for FCO. Open to tank for returns. 10:00 11:00 1.00 COMPZ STIM FCO P Engaged fill @ 5900' ctmd, hard interface sand bridge. Jetted through brid a and continued to RIH. 11:00 13:00 2.00 COMPZ STIM FCO P RIH to 6000' PUH to TT. Heavy sand frac sand/formation sand returns. Tested for clorides, only Kcl returning . Allowed well to clean up. 13:00 14:00 1.00 COMPZ STIM FCO P RIH to 6100', heavy ssand in returns with very muddy water, made several wiper runs to clean up well. Returns increased to 2:1 during this portion of cleanout. Started getting heavy formation sand returns, choke plugged of with pieces of coal. 14:00 17:00 3.00 COMPZ STIM FCO P RIH to 6300', made several wiper runs to TT to clean out well until returns only showed trace of sand. Water is still cloudy. 17:00 21:00 4.00 COMPZ STIM FCO P PUH to above GLM and came on line w/ n2 @ 200,000 SCFPD while POOH. Once N2 was at nozzle RIH slowly to 6000' taking 100' bites every 30 minutes. ONce well mostly circulating gas, POOH and SD N2 @ 2500'. Checked gas returns for LEL's, none found. 21:00 00:00 3.00 COMPZ STIM FCO P RDMO Coil and allow PTS to flow well over ni ht. 7/25/2010 Well did not flow any gas or fluids to surface during the night PTS flow test. MIRU Pollard slickline and tagged fill at 6316' wlm. Tbg FL @ 5100'. MIRU BJ coil and lay in 7200# 20/40 river sand w/ 1000# 100 mesh beach sand cap from 6300' ctmd to TT @ 4891'. RD Coil and RU Slickline, RIH and tag at sand top @ 6100', tools falling slow w/ over pulls off of bottom. Appears that gel is not broke and sand still falling. LDFN will return in the AM to tag sand and dump cement cap. 00:00 06:00 6.00 COMPZ STIM OPNW P Flow test well, no flow detected. 06:00 09:00 3.00 COMPZ STIM SLKL X MIRU Slickline, RIH and tag top of sand @6316' WLM, RDMO. 09:00 09:30 0.50 COMPZ CEMEN' CTOP X Shot Tbg FL @ 5100' 09:30 12:30 3.00 COMPZ CEMEN' CTOP X MIRU Coil unit, make up BHA of 2.0" dump nozzle. PT lines and RIH while dis lacing well w/ 6% Kcl. Page 11 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:30 15:30 3.00 COMPZ CEMEN" CTOP P RIH to 6300' ctmd, lay in sand plug as followed. Stage #1 = 18 bbls HEC gel w/ breaker & 3200# 20/40 SS of wet surplus Carbolite. (22 bbl slurry @ 5 ppg)- Stage #2 = 18 bbls HEC gel w/ breaker & 3000# 20/40 river sand. (21 bbl slurry @ 4 ppg). Stage #3 = 12 bbls of HEC gel w/ breaker & 1000# 20/40 river sand & 1000# 100 mesh beach sand. (14 bbl slurry of 4 ppg). Calculated top of sand @ 5959' once el breaks. 15:30 19:30 4.00 COMPZ CEMEN- CTOP P Sand plug layed in from 6300' to just below TT @ 4895'. Allow gel to break for one hour and pressured well up to 500 psi. Tbg pressure slowly bled off to 403 psi in 15 minutes. POOH, flush lines and RB for Slickline. 19:30 21:30 2.00 COMPZ CEMEN' SLKL P RU SL and RIH w/ TTL & 2.25 swedge, located TT @ 4893 slmd, 4910' corrected. RIH and tagged fill @ 6117'. Tools are slow falling and had 400# over pull off of bottom. 21:30 00:00 2.50 COMPZ CEMEN" SLKL P Wait one hour and RIH and tag @ 6100', appears gel has not broke and sand still falling. LDFN. 7/26/2010 Pressure tested sand plug to 1500 psi w/ no loss to formation, Slickline tagged top of sand @ 6022' wlm. Dumpbailed 20 gallons of Class G cement on top of sand for cement ca . 00:00 07:00 7.00 COMPZ CEMEN' SLKL P Allow Slickline crew to sleep 07:00 19:00 12.00 COMPZ CEMEN" SLKL P RIH w/ TTL & 2.25 swedge, locate TT @ 4900' wlm, RIH and tag top of sand @ 6022'. Dump bail 20 gallons of class G cement @ 6021' (did not hard tag due to soft cement). RDMOL 19:00 00:00 5.00 COMPZ CEMEN" SLKL P Allow well to sit static for cement plug to cure. 7/27/2010 Allow cement plug to rest for 24 hours. Perform weekly BOP test. Pressure up IA to 2500 psi, pressure test cement plug to 4500 psi for 5 minutes (passed). Bled both back to 100 psi. RIH and tag cement top @ 5953' ctmd. Displace well out with 130 bbls of 10 micron filtered 6% Kcl. PUH to 760' and circulate out fluid with N2, POOH and left 580 si N2 cap on tubing for perforations in the AM. 00:00 08:00 8.00 1 1 COMPZ CEMEN" CMNT I P Allow cement plug to rest and cure. 08:00 17:00 9.00 COMPZ CEMEN" BOPE I P I Perform BOP test Page 12 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:00 18:00 1.00 COMPZ CEMEN" PRTS P Pressure test cement plug in 1000 psi stages up to 4500 psi, there were no losses to formation during the test. 18:00 19:00 1.00 COMPZ PERF CTOP P RIH and tag cement top @ 5953' ctmd, PUH 100' and circulate our well fluids w/ 10 micron filtered 6% Kcl until clean returns 130 bbls. 19:00 20:00 1.00 COMPZ PERF CTOP P PUH to 760' and circulate out fluid w/ N2. 20:00 21:00 1.00 COMPZ PERF CTOP P POOH leaving 580 psi N2 cap on well. 21:00 00:00 3.00 COMPZ PERF CTOP P DFN. 7/28/2010 Rigged up HES eline. Tagged top of cement at 5955'. Perforated Beluga I sand at 5818-5830', and 5786-5794', using HES 2-1/2" RTG with 2-1/2", 11-gram RDX, Titan Prospector Charges, 6-SPF, 60-deg phasinij. Prepped for flowback. 00:00 10:30 10.50 COMPZ PERF PERF P Stanby for HES Eline crerw to arrive on scheduled flight. 10:30 20:00 9.50 COMPZ PERF PERF P Safety meeting for eline operations. Rig up eline. Make up and test firing head. Pick up lubricator and tools and stab onto well. Pressure test lubricator: 500-psi low and 3500-psi high. RIH and correlate to HES CAS cement bond log dated July 3, 2010. Perforate 5818-5830'. POOH and confirm shots. Make up second gun and stab on well. Pressure test lubricator: 500-psi low and 3500-psi high. RIH and correlate to HES CAS cement bond log dated July 3, 2010. Perforate 5786-5794'. POOH and confirm shots. RDMO eline. Note: Pressures before, during, after perforating: T/IA/OA 650/100/0 20:00 00:00 4.00 COMPZ FLOWT PRDT P Safety meeting for flowback. Discuss parameters of the flowback draw down procedures. Prepped for flowback and encounter SSV not functioning. 7/29/2010 Flow tested well. Initial SIWHP: 275-psi. Bled WHP to 175-psi, observed no flow. Bled WHP to 80-psi and observed some flow to surface. Bled well to a minimum of 5-psi; 10-bbl total flow 6% KCI to tanks. Minimal gas flow observed overnight. Consulted with Anchorage team and decided to proceed with frac. Shut in well and observed WHP build-up: pressure built form 50- to 310-psi in 3.5-hrs. Closed wing and turned well to slickline. Slickline unable to determine fluid level. Tagged cement and observed small volume of formation sand in contaminated cement. Installed frac sleeve across SSSV. BJ loading ro ant into SandKin . 00:00 16:30 16.50 COMPZ FLOWT PRDT I P I PTS Flow Test. Page 13 of 28 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment SURPRI STIM SLKL P MIRU Slickline, RIH w/ 2.25" DD bailer, tag cement top @ 6022' corrected to 6039' KB. (Counter reading innacurate, depths are wrong proven by prior Coil and E -line tags). Obtain sample of contaminated cement. RIH and set frac sleeve @ 493' kb over SSSV. RDMOL. D7/30/201 0 PTS monitored WHP's over night, Tbg FL @ surface w/ 280 psi on WH. Discussed well conditions with asset, decision was made to postpone frac and continue flow test of well. Performed N2 lift w/ Coil down to 1400' ctmd, monitored well through PTS for one hour, well started producing small amounts of fluid and gas after a brekdown event noticed by PTS. (Metered 280 BWPD & 50,000 scfgpd w/425 psi WHP, w/ choke set at 80% shut). RIH w/ coiled tubing and tagged @ 6023' ctmd. (Top of abondoned perfs and roughly 70'+/ - below last tag depth of cement plug). While jetting, coil ran freely down to 6050' ctmd. Sample of 100 mesh sand captured in returns. 00:00 06:00 6.00 SURPRI FLOWT PRDT P PTS monitored WHP's. 06:00 07:00 1.00 SURPRI CEMEN' PRDT X Shot Tbg FL near surface w/ 280 psi WHP. 07:00 08:00 1.00 SURPRI CEMEN-SFTY P Have meeting with asset, decision made to flow test well for evaluation of a possible water zone before performing frac. 08:00 12:00 4.00 SURPRI CEMEN" CTOP P MIRU BJ Coil, perform BOP test. 12:00 14:00 2.00 SURPRI CEMEN" CTOP P Come online with N2 @ 300,000 scf, RIH to 200' and circulate out fluid until mostly N2 only in returns. POOH 14:00 14:30 0.50 SURPRI FLOWT PRDT P Hand well over to PTS for monitoring. Opened choke and bled well to 0 psi, in 30 minutes WHP built to 2 psi with a trickle of fluid. 14:30 15:00 0.50 SURPRI CEMEN' CTOP P RIH with coil while pumping 300,000 scf of N2 to 500' ctmd. (Started getting returns of water to surface @ 250' coil depth.) Sat at 500' until fluid returns deminished. POOH 15:00 15:30 0.50 SURPRI FLOWT PRDT P PTS opened well w/ 60 psi WHP and produced fluid, in 15 minutes well bled to 1 psi gas with LEL readings. Closed choke and well built to 3 psi in 10 minutes. 15:30 16:00 0.50 SURPRI CEMEN' CTOP P RIH w/ coil to 800' ctmd while pumping 350,000 scfpd. Allowed well to unload water and circulate out N2 while plan forward meeting was in place with co-owners. Decision was made to proceed forward with N2 bites to 1400' for further draw down. 16:00 16:30 0.50 SURPRI FLOWT PRDT P RIH to 1100' and circulate out Kcl, increased N2 rate to 500,000 scf. 16:30 17:00 0.50 SURPRI CEMEN" CTOP P RIH to 1400' and circulate out water w/ 550,000 scf until returns mostly dry. POOH and hand well over to PTS. Page 14 of 28 Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 17:00 18:30 1.50 SURPRI FISH PRDT X Hand well over to PTS w/ 125 psi WHP. PTS flowing back water and gas, well slugging but flowing on its own. Metered one slug @ 280 BWPD & 50,000 scfgpd w/425 psi WHP, w/ choke set at 80% shut. Decision made to move forward with preparing well for frac. SI PTS. 18:30 00:00 5.50 SURPRI CEMEN" CTOP X RIH w/ coil and dry tag @ 6023' ctmd. Roughly 70' deeper than prior coil and Eline tag depths. Decision made to RIH while jetting to verify if cement plug had failed. RIH to 6050' ctmd. (Obtained sample of 100 mesh sand in returns verifying plug had failed). Made two cleanout runs from 6050' to TT. POOH LDFN. D7/31/201 0 Monitor WHP's (Well built back to 280 psi), held meeting with asset folks for plan forward. Formulated plan and procedure, evaluated gel breaking options for sand plugs. RU slickline and pulled frac sleeve & tag fill @ 6062 wlm. RU CTU and RIH w/ 2.80" GR and tag XN @ 4886' ctmd. (XN @ 4880' RKB, 6' coil correction). Procedure made for la ing in sand in the AM. 00:00 02:00 2.00 SURPRI STIM CTOP P Continue RD coil, start formulating Ian forward. 02:00 08:00 6.00 SURPRI STIM PRDT P SI and monitor WHP's. 08:00 12:00 4.00 SURPRI STIM SLKL T Perform gel break test, and formulate best plan forward for sand plug. MIRU slickline unit. 12:00 14:00 2.00 SURPRI STIM �SLKL P RIH and pull frac sleeve @ 494', RIH and taq ill@6062' wlm. 14:00 21:00 7.00 SURPRI STIM CTOP T MIRU Coil, make up BHA of 1.5" MT box XO to 3/4" sucker rod, RIH and tag XN @ 4886' ctmd (6' correction to RKB. 21:00 00:00 3.00 SURPRI CTOP P POOH and LDFN. 08/01/2010 MIRU CTU, RIH and tag sand @ 6060'ctmd (6054' KB). Lay in sand slurry of 2000# 20/40 mesh river sand w/ 1.6 ppg HEC gel from 6050'-5430' ctmd. RIH and tag sand @ 6001' KB. Attempted to set IBP, plug failed to inflate due to residual sand in coil. At surface without IBP, pumped pig through coil and cleaned sand from MHA. Will resume in the AM fishing for IBP. 00:00 06:00 6.00 SURPRI OWFF P PTS monitored well. 06:00 08:00 2.00 SURPRI CTOP P MIRU Coiled tubing unit. Make up bha of 2" SJN for sand dump. 08:00 09:00 1.00 SURPRI CTOP P RIH and tag @ 6060' ctmd (6054' RKB. 09:00 10:00 1.00 SURPRI CTOP P Place nozzle @ 6050' ctmd, w/ gel @ nozzle displace slurry from 6050'-5430' ctmd. Sand slurrry was 12 bbls HEC w/ 5# breaker added, mixed w/ 2000# 20/40 mesh river sand. Top of settled sand should be @ 5967'=/-. POOH while displacing coil w/ clean fluids. Once @ surface pump two coil displacements @ 2 bpm to flush coil. Page 15 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:00 12:00 2.00 SURPRI CTOP P Make up Baker BHA of 2.5" IBP w/ 1.375" ecternal fishing neck. OAL 11', 7.12 to mid -element. 1840# to EQ & 5,500# upward force to release. Schematic in well file 12:00 13:00 1.00 SURPRI CTOP P RIH and tag sand @ 6001' KB. PUH 50' and drop ball, wait two hours for coil fluid to thermally stabilize. 13:00 17:00 4.00 SURPRI CTOP X RIH and tag sand @ 6012' RKB (11' deeper than prior tag). Attempt to pressure up on IBP to inflate w/ no success. Appears that BHA is sanded off. POOH 17:00 20:00 3.00 SURPRI CTOP X At surface w/ out IBP, MHA & screens are packed off w/ sand. Appears that tool disconnected. Will retrieve with slickline in the AM. 20:00 00:00 4.00 SURPRI CTOP X Cleaned MHA, and ran turbo pig through coil followed by two coil displacements. 8/02/2010 MIRU Slickline, attempted to retrieve lost IBP w/ out success. LIB impression of top of fishing neck perfectly centered in well, but not able to latch due to possible sand around fishing neck. MIRU BJ Coil and set 2.5" Baker IBP 6000' ctmd 5994' KB). 00:00 06:00 6.00 SURPRI SLKL X MIRU slickline 06:00 07:00 1.00 SURPRI SLKL X Make up BHA of JDC & Bell guide, RIH and tag fish @ 6010' slm, unable to latch fish. 07:00 07:30 0.50 SURPRI SLKL X RIH w/ LIB tag up on XN nipple. POOH 07:30 08:00 0.50 SURPRI SLKL X RIH w/ correct size 2.5" LIB w/ centrilizer above and tag top of fish @ 6010' wlm. OOH w/ impression of top of fishing neck. Dead center of LIB. 08:00 08:30 0.50 SURPRI SLKL X RIH w/ KJ,2.5" cent, BG & JDC, unable to latch fish. 08:30 09:30 1.00 SURPRI SLKL X RIH w/ KJ, 2.25" cent & JDC, unable to latch, tool coming back with sand inside. Decision made to move forward with sand plug. RDMO 09:30 10:30 1.00 SURPRI SFTY X Meeting with asset folks about plan forward. 10:30 14:30 4.00 SURPRI CTOP P MIRU BJ coil, perform shell test, make up Baker BHA of 2.5" IBP w/ 1.375" ecternal fishing neck. OAL 11', 7.12 to mid -element. 1840# to EQ & 5,500# upward force to release. Schematic in well file 14:30 18:30 4.00 SURPRI CTOP P RIH and tag top of fish @ 6010' ctmd. PUH 10' to 6000'. On-line w/ pump @ 1.5 bpm. Drop 1/2" steel ball, wait three hours for plug & fluid to thermally stabilize. Page 16 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:30 22:00 3.50 SURPRI CTOP P Pressure up against IBP in 500 psi stages until bladder was inflated and IBP relesed from setting tool @ 2550 psi. IBP appears to be set. POOH 22:00 00:00 2.00 SURPRI CTOP P LDFN 8/03/2010 MIRU CTU, RIH and tag IBP @ 5994'ctmd (6000' KB). Lay in sand slurry of 3000# 20/40 mesh river sand w/ 1.6 ppg HEC gel from 5990'-5050' ctmd. RIH and tag sand with Pollard S/L @ 5846'wlm, set frac sleeve @ 493' KB. Make up Sting er tech tree saver and test seals. Will test casing in AM. 06:00 06:30 0.50 SURPRI CTOP P OPS meeting 00:30 01:00 0.50 SURPRI CTOP P Daily pre tour meeting 01:00 07:00 6.00 SURPRI CTOP P MIRU CTU, RIH and tag IBP @ 5994'ctmd (6000' KB). Lay in sand slurry of 3000# 20/40 mesh river sand w/ 1.6 ppg HEC gel, overall slurry density 10.67 ppg, target plug height approximately 130', lay in from 5,990-5,050' ctmd. POOH while displacing coil with clean fluids, rack back injector head and BOPE. 07:00 10:00 3.00 SURPRI SLKL P MIRU Pollard S/L, PT lub 500 psi. RIH w/ 2.25" bailer to 5,846'wlm, POOH. RIH w/ 3" GS & 2.81" Frac Sleeve (TL 81" 2.30" ID) to 481'wlm, set sleeve, POOH. RDMO Pollard. 10:00 13:00 3.00 SURPRI RURD P RU Stinger tree saver and test. 8/04/2010 PT CASING TO 2,500 PSI, GOOD TEST. MAKE UP SURFACE EQUIPMENT TO TREESAVER. SET ANNULUS POP-OFF TO 2,910 PSI, SET TREATING LINE POP-OFF 4,750 PSI, SET KICK-OFF ON PUMPS @ 4,600/4,550/4.500 PSI.PUMPED SIX STAGE FRAC 1,2,3,4,5,&6 PPA PLACING 70,296 LBS OF 20/40 CARBO/FLEX INTO FORMATION, REMOVED TREESAVER. MIRU POLLARD, TAG FILL @ 5,800'WLM, PULLED FRAC SLEEVE 493'KB, RDMO POLLARD. 06:00 06:30 0.50 SURPRI STIM P OPS MEETING 00:30 01:00 0.50 SURPRI STIM P DAILY PER TOUR MEETING 01:00 02:00 1.00 SURPRI STIM P BJ TEST CASING TO 2,500 PSI, GGOD TEST. PREP FRAC EQUIPMENT FOR UPCOMING FRAC. 02:00 03:30 1.50 SURPRI STIM T WAITING ON FRAC CREW FROM KENAI. 03:30 05:30 2.00 SURPRI STIM P BJ FRAC CREW ARRIVED ON LOCATION. PJSM, READY SURFACE EQUIPMENT FOR FRAC. 05:30 07:00 1.50 SURPRI STIM P SET ANNULUS POP-OFF TO 2,910 PSI. PT TREATING LINE TO 6,677 PSI FOR 5 MINS. SET N2 POP-OFF AT 4,750 PSI. TRUCK 1# 4,600 TRUCK 2# 4,550 TRUCK 3# 4,500 PSI KICK-OFFS. OPEN WELLHEAD FOR DFIT, INITIAL WHP 190 PSI. Page 17 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 08:30 1.50 SURPRI STIM P START PUMPING DFIT 5.3 BPM @ 3,366 PSI 6.6 BPM @ 3,460 PSI 6.7 BPM @ 3,255 PSI WITH 18 BBLS AWAY, 30 BBLS PUMPED, HARD SHUT DOWN, SHUT GROUND VALVE. JOBMASTER TIME 89 MINS. BREAK TEST: 2 PPG GBW-18; BROKE AT 35 MINS, CLOSURE PSI 4,660 PSI, SURFACE 1,990 PSI. ADJUST PAD TO 325 BBLS, WILL RAMP DOWN DURING FLUSH, FLUSH: PUMP 35 BBLS LINEAR @ 10 BPM THEN SWAP TO KCL 37 BBLS. 08:30 10:30 2.00 SURPRI STIM P PRIME PUMPS. START PUMPING 325 BBLS PAD, 12.8 BPM @ 3,751 PSI, 15.5 BPM @ 3,683 PSI, 16.2 BPM @ 3,512 PSI, 17.4 BPM @ 3,626 PSI, 15.4 BPM @ 3,547 PSI, 15,4 BPM @ 3,533. START 1 PPA STAGE ( 100 BBL SLURRY VOLUME). START 2 PPA STAGE 100 BBL SLURRY VOLUME) 15.2 BPM @ 3,320 PSI, STAGE 2 @ PERFS. START 3 PPA STAGE (100 BBL SLURRY VOLUME) 15.2 BPM @ 3.185 PSI. START STAGE 4 PPA (100 BBL SLURRY VOLUME). START 5 PPA STAGE (100 BBL SLUURY VOLUME) STAGE 4 @ PERFS. START 6 PPA STAGE (100 BBL SLURRY VOLUME) 6 PPA @ PERFS, OUT OF SAND, STAGING FLUSH, CUT RATE TO 9.1 BPM, 97 BBLS AWAY, CUT RATE TO 5 BPM, 72 BBLS AWAY, SHUT DOWN PUMP, CLOSE GROUND VALVE, SIWHP 2,750 PSI. PUMP TOTAL OF 8,768# FLEX & 61,528# CARBO, TOTAL PUMPED 70,296#. 10:30 14:30 4.00 SURPRI STIM P FLUSH AND BLOW DOWN LINES, RIG DOWN FRAC EQUIPMENT. LAY DOWN TREESAVER. MOVE PEAK CRANE. 14:30 18:00 3.50 SURPRI SLKL P MIRU POLLARD S/L UNIT & MAST TRUCK. PT LUB TO 300 PSI (WELLHEAD PSI). RIH W/ 2.27" SWAGE TO 5,800'WLM TAG FILL, POOH. RIH W/ 3" GS TO 481'WLM (493'KB) LATCH & PULL FRAC SLEEVE, POOH. RDMO POLLARD. 8/05/2010 START FLOWING WELL TO PTS AT MIDNIGHT. RIG -UP BJ COILTECH, PERFORM WEEKLY BJ BOPE TEST. PERFORMED BJ COIL FCO TO 5,880'CTM WITH 1.75" VORTEX NOZZLE, MAINTAIN 1.5 TO 1.0 RETURNS THROUGHOUT CLEAN-OUT, HEAVY FLEX AND CARBOLITE RETURNS, NO N2 ASSIST NEEDED DURING CLEAN-OUT. PERFORMED FLOW CHECK WHILE POOH WITH COIL, ON SURFACE, RACK BACK COIL. CONTINUE TO MONITOR FLOWTHROUGH PTS FLOW BACK SYSTEM, CURRENTLY FLOWING @ 1,850 PSI WITH 4-5 MILLION GAS, MINIMAL SOLIDS OR WATER IN RETURNS. Page 18 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 SURPRI PRDT P START FLOWING WELL THROUGH PTS SURFACE EQUIPMENT AT MIDNIGHT, INITIAL SIWHP 200 PSI, AT 05:00 WHP 90 PSI, AVERAGING 7 BPH FOR TOTAL OF 35 BBLS WATER, NO GAS YET. 05:00 07:00 2.00 SURPRI BOPE P PERFORM WEEKLY BOPE TEST. GOOD TEST, TEST WAIVED BY AOGCC BOB NOBLE ON 08-04-10. 07:00 12:00 5.00 SURPRI FCO P INJECTOR HEAD TO WELLHEAD, SHELL TEST 2,500 PSI. OPEN WELL, WHP 420 PSI. START IN HOLE WITH COIL, START PUMPING MIN.RATE OF WATER @ 3,000'CTM, WEIGHT CHECK @ 5,500'CTM 11,600#. INCREASE FLUID PUMP RATE TO 1.5 BPM CTP 2,950 PSI WHP 200 PSI. MAKE 100' SWEEP TO 5,880'CTM, 50' BELOW BTM PERF'S, KEPT PUMP RATE SAME THROUGHOUT FCO, GOOD RETURNS TO SURFACE 1.5 TO 1.0 RATIO, GOOD FLEX/CARBONITE RETURNS, NO N2 REQUIRED FOR FCO, RECOVERED 350 BBLS FLUID TOTAL, SUFFICIENT AMOUNT OF SOLIDS, POOH TO TT @ 4,890'CTM, WHP 350 PSI, RETURNS CLEAR UP LAST HOUR. TURN RETURNS OVER TO PTS @ 10:30, POOH WITH COIL TO SURFACE, ON SURFACE, BLEED OFF AND RACK BACK INJECTOR. 12:00 15:00 3.00 SURPRI PRDT P CONTINUE TO MONITOR FLOW THROUGH PTS FLOW BACK SYSTEM, WHP PRESSURE UP OVER 1,150 PSI AT TIMES WITH WATER AND SOLIDS IN RETURNS. PINCH BACK WELL TO MAINTAIN 20% DRAW DOWN, STILL ABLE GET GAS RATE OF FIVE MILLION, MORE SOLIDS IN RETURNS. 15:00 19:00 4.00 SURPRI PRDT P CONTINUE TO MONITOR FLOW THROUGH PTS WHILE PUMPING MIN RATE WITH BJ PUMP THROUGH FLOW CROSS TO ASSIST WITH FLOW CUTTING SURFACE EQUIPMENT. FLOW CUT CHOKE DOWN STREAM OF SAND DUMP, WAITING ON PARTS FROM ANCHORAGE. CURRENTLY FLOWING @ 1,850 WHP 4-5 MILLION GAS, LITTLE WATER OR SAND IN RETURNS. Page 19 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 19:00 20:30 1.50 SURPRI PRDT T SHUT WELL IN. PURGE LINES WITH N2. REPLACE CHOKE DOWNSTREAM OF SAND DUMP. TEST LINES TO 1800 PSI. 20:30 00:00 3.50 SURPRI PRDT P SITP - 2245 PSI. OPEN WELL TO PTS SEPARATOR. BJ PUMPING 0.1 BPM AT FLOW CROSS. LITTLE IF ANY WATER AND SAND IN RETURNS. CURRENTLY FLOW AT 3.7 MCF GAS AT 1887 PSI TBG PRESSURE. 8/06/2010 CONTINUE FLOW BACK OPERATIONS THROUGH PTS EQUIPMENT, AS OF MIDNIGHT WHP 1,900 PSI GAS RATE AVERAGING 3.2 MCF WITH LITTLE OR NO SOLIDS OR WATER, RATES WERE STABLE THROUGHOUT DAY, SHUT IN WELL FOR S/L. MIRU POLLARD W/L, RIH W/ 2.735" SWAGE TO TAG FILL @ 5,832'WLM, JUST BELOW LOWER PERF ZONE, NO INDICATIONS OF FLUID LEVEL IN TUBING OR CASING, MADE ATTEMPT TO SHOOT FLUID LEVEL WITH POLLARD ECHOMETER WERE INCONCLUSIVE, RDFN. PLAN FORWARD WILL BE TO FLOW WELL @ 1,800, 1,900, 2,000 WHP FOR FOUR HOURS EACH THROUGHOUT NIGHT. 00:00 10:00 10.00 SURPRI PRDT P CONTINUE FLOW BACK OPERATIONS THROUGH PTS EQUIPMENT, AS OF MIDNIGHT WHP 1,900 PSI GAS RATE AVERAGING 3.2 MCF WITH LITTLE OR NO SOLIDS OR WATER. CALL -OUT POLLARD FOR TAG FILUFLUID LEVEL. 10:00 16:00 6.00 SURPRI PRTS T CONTINUE FLOW BACK WHILE WAITING ON POLLARD S/L FROM KENAI. SHUT DOWN BJ PUMP ACROSS FLOW CROSS @ 10:00. ANY FLUID RECOVERED WILL BE WELLBORE FLUIDS. ONLY MADE 2 BBLS WATER IN FOUR HOURS, HOWEVER PTS STARTED HAVING HYDRATE PROBLEMS, CALL OUT BJ TO PUMP ANOTHER 6 BBLS WARM WATER THROUGH PTS SYSTEM, SHUT DOWN FLOW BACK AT 16:00. 16:00 19:00 3.00 SURPRI SLKL P MIRU POLLARD W/L, PT LUB. 1,500 PSI. RIH W/ 2.735" SWAGE TO 5,832'WLM TAG FILL, NO INDICATION OF FLUID LEVEL IN TUBING OR CASING. POOH. INSTALL POLLARD ECHOMETER AND MAKE TO ATTEMPTS TO SHOOT FLUID LEVEL, SHOTS WERE INCONCLUSIVE. RDFN. 19:00 00:00 5.00 SURPRI PRDT P CONTINUE WITH FLOW BACK THROUGH PTS EQUIPMENT. PLAN FORWARD WILL BE TO FLOW WELL @ 1,800, 1,900, 2,000 PSI FOR FOUR HOURS EACH THROUGHOUT NIGHT. Page 20 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 8/07/2010 24 hr summary CONTINUE FLOW BACK OPERATIONS THROUGH PTS EQUIPMENT, CONTINUE TO USE BJ PUMP TO CLEAR HYDRATES IN SEPARATOR PERIODICALLY. MIRU POLLARD W/L, TAG FILL @ 5,833'WLM WITH BAILER, BAILER FULL OF CARBOLITE/FLEX SAND. RUN PSI/TEMP SURVEY TO 5,830'WLM, SIWHP 2,268 PSI, PRESSURE @ 5,830'WLM 2,603 PSI TEMP 113 DEGREES, FLUID LEVEL 5,796'MD, RDFN POLLARD. CONTINUE TO FLOW BACK AT 1,900 PSI THROUGHOUT NIGHT. 00:00 02:00 2.00 SURPRI PRDT P COTINUE FLOW BACK @ 1,800 WHP FOR TWO HOURS, AVERAGE GAS RATE 4.16 MCF NO SAND AND 1 BBL WATER MADE WELL. 02:00 06:00 4.00 SURPRI PRDT P COTINUE FLOW BACK @ 1,900 WHP FOR FOUR HOURS, AVERAGE GAS RATE 3.2 MCF NO SAND AND NO WATER. 06:00 10:00 4.00 SURPRI PRDT P COTINUE FLOW BACK @ 2,000 WHP FOR FOUR HOURS, AVERAGE GAS RATE 2.1 MCF NO SAND AND NO WATER. SHUT IN FLOW BACK FOR SLICKLINE, WHP INCREASED TO 2,250 PSI. 10:00 16:00 6.00 SURPRI SLKL P MIRU POLLARD W/L, PT LUB. 1,500 PSI. RIH W/ 2.5" DD BAILER TO 5,833'WLM SAME DEPTH AS PREVIOUS DAY, BAILER FULL OF 95 % CARBOLITE 5% FLEX SAND, POOH. RIH W/ POLLARD DOWNHOLE PSI/TEMP GAUGES TO 5,000'WLM @ 120 FPM, CONTINUE IN HOLE @ 60 FPM TO 5,830'WLM. POOH W/ GAUGES @ 60 FPM, MAKING 3 MINUTE GRADIENT STOPS @ 5,500, 5,000, 4,000, 3,000, 1,500, 0'. RDFN POLLARD W/L. CHECK DATA. SIWHP 2,268 PSI, PRESSURE @ 5,830'WLM 2,603 PSI, TEMP 113 DEGREE, FLUID LEVEL @ 5, 796'M D. 16:00 00:00 8.00 SURPRI PRDT P COTINUE FLOW BACK @ 1,900 PSI THROUGHOUT NIGHT. 8/08/2010 CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP. FIRST SIX HOURS GAS RATE 3.4 MCF AVERAGE WITH LITTLE TO NO WATER AND NO SOLIDS, SECOND SIX HOURS SAME RESULTS, THIRD SIX HOURS GAS RATE 3.387 MCF NO WATER OR SOLIDS, FOURTH SIX HOURS GAS RATE 3.330 MCF NO WATER OR SOLIDS. 00:00 00:00 24.00 SURPRI PRDT P CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP. FIRST SIX HOURS GAS RATE 3.4 MCF AVERAGE WITH LITTLE TO NO WATER AND NO SOLIDS, SECOND SIX HOURS SAME RESULTS, THIRD SIX HOURS GAS RATE 3.387 MCF NO WATER OR SOLIDS, FOURTH SIX HOURS GAS RATE 3.330 MCF NO WATER OR SOLIDS. Page 21 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 8/09/2010 24 hr Summary CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP, IISCO OBTAINED GAS SAMPLE AT PTS SEPARATOR. FIRST SIX HOURS GAS RATE 3.3 MCF AVERAGE WITH LITTLE TO NO WATER AND NO SOLIDS, SECOND SIX HOURS 3.2 MCF NO WATER OR SOLIDS, THIRD SIX HOURS GAS RATE 3.2 MCF NO WATER OR SOLIDS, FOURTH SIX HOURS GAS RATE 3.2 MCF 6 BBLS WATER AND NO SOLIDS. 00:00 00:00 24.00 SURPRI PRDT P CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP, IISCO OBTAINED GAS SAMPLE AT PTS SEPARATOR. FIRST SIX HOURS GAS RATE 3.3 MCF AVERAGE WITH LITTLE TO NO WATER AND NO SOLIDS, SECOND SIX HOURS 3.2 MCF NO WATER OR SOLIDS, THIRD SIX HOURS GAS RATE 3.2 MCF NO WATER OR SOLIDS, FOURTH SIX HOURS GAS RATE 3.2 MCF 6 BBLS WATER AND NO SOLIDS. 8/10/2010 CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP FIRST SIX HOURS GAS RATE 3.181 MCF AVERAGE WITH LITTLE TO NO WATER AND NO SOLIDS, SECOND SIX HOURS 3.172 MCF NO WATER OR SOLIDS, THIRD SIX HOURS GAS RATE 3.159 MCF NO WATER OR SOLIDS, FOURTH SIX HOURS GAS RATE 3.166 MCF 2 BBLS WATER AND NO SOLIDS. 00:00 00:00 24.00 SURPRI PRDT P CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP FIRST SIX HOURS GAS RATE 3.181 MCF AVERAGE WITH LITTLE TO NO WATER AND NO SOLIDS, SECOND SIX HOURS 3.172 MCF NO WATER OR SOLIDS, THIRD SIX HOURS GAS RATE 3.159 MCF NO WATER OR SOLIDS, FOURTH SIX HOURS GAS RATE 3.166 MCF 2 BBLS WATER AND NO SOLIDS. 8/11/2010 CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP. DECISION MADE TO START DEMOB OF EQUIPMENT. RACK BACK BJ BOP EQUIPMENT, START DEMOB OF BJ FRAC EQUIPMENT. PERFORM FLOWING PSI/TEMP SURVEY TO 5,830'MD. CONTINUE FLOW BACK THROUGHOUT NIGHT. LAST 6 HRS AVG 3.06 MCF WITH 2 BBLS WATER AND NO SOLIDS. 00:00 06:00 6.00 SURPRI PRDT P CONTINUE FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 PSI. FIRST SIX HOURS GAS RATE 3.164 MCF NO WATER OR SOLIDS, SECOND SIX HOUR AVERAGE 3.142 GAS RATE NO WATER OR SAND, CONTINUE FLOW BACK THROUGHOUT DAY. 06:00 09:00 3.00 SURPRI RURD P RIG DOWN BJ BOPE FROM WELLHEAD, RIG DOWN SURFACE EQUIPMENT NOT NEEDED FOR UPCOMING FCO. 09:00 16:00 7.00 SURPRI DMOB P BJ FRAC CREW ARRIVED ON LOCATION. DEMOB FRAC EQUIPMENT. Page 22 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:00 22:00 6.00 SURPRI SLKL P MIRU POLLARD S/L, PT EQUIPMENT, PERFORM FLOWING PRESSURE SURVEY TO 5,830'WLM. POOH. PROCESS DATA, AVERAGE FBHP 2,245 PSI, FLUID LEVEL @ 5,821'MD, 22:00 00:00 2.00 SURPRI PRDT P CONTINUE FLOW BACK. LAST 6 HRS AVG 1900 PSI 3.06 MCF WITH 2 BBLS WATER AND NO SOLIDS. 8/12/2010 CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHP, GAS RATE FIRST SIX HOURS 3.082 MINIMAL WATER AND NO SOLIDS. DEMOB HALLIBURTON, MAGTEC, AND REMAINING FRAC EQUIPMENT. MIRU POLLARD S/L, PULLED 1" SPARTEK GAUGE AND SET DV, TEST TBG TO 3,000 PSI WITH N2, GOOD TEST. RDMO POLLARD. LEAVE WELL SHUT IN OVERNIGHT. 00:00 06:00 6.00 SURPRI PRDT P CONTINUE TO MONITOR FLOW BACK THROUGH PTS EQUIPMENT @ 1,900 WHIP, GAS RATE FIRST SIX HOURS 3.082 MINIMAL WATER AND NO SOLIDS. 06:00 07:00 1.00 SURPRI DMOB P CONTINUE WITH DEMOB OF EQUIPMENT. REMAINING FRAC EQUIPMENT, HALLIBURTON, MAGTEC, AND STINGERTECH. SHUT IN WELL FOR POLLARD S/L. 07:00 08:00 1.00 SURPRI SLKL P MIRU POLLARD S/L UNIT, TEST LUB. 2,500 PSI, RIH W/ 2.25" DD BAILER TAG FILL @ 5,835'WLM, POOH. 08:00 12:00 4.00 SURPRI SLKL T STAND BY FOR PLUG FROM KENAI. 12:00 20:00 8.00 SURPRI SLKL P RIH W/ X -LINE RT & 2.81" PXN PLUG BODY TO 4487'. POH. RIH W/ 2" SB AND'P' PRONG TO 4885'. SET PRONG. POH. RIH WITH 3" GS AND CATCHER SUB TO 4882'. POH. RIH W/ 31/2" OK -1 AND 1 1/4" JDS TO 4808'. BLEED IA TO 0 PSI. PRESSURE TBG TO 2380 PSI WITH N2. PULLED SPARTECH GLM MEMORY GAUGE. POH. RIH W/ OK -1. JK RUNNING TOOL AND DGLV. FLUID LEVEL AT 4860'. PICK UP TO 4808'. SET DUMMY GLV. POH. BLEED IA TO 0 PSI. PRESSURE TBG TO 3000 PSI WITH N2. OK. BLEED TBG PRESSURE TO 2300 PSI. RIH WITH 3" GS TO 4882'. PULLED CATCHER SUB. POH. RIH WITH 2" SB TO 4885'. PULLED'P' PRONG. POH. RIH W/ 3" GS TO 4887'. PULLED PXN BODY. POH. RDMO POLLARD. 20:00 00:00 4.00 SURPRI PRDT P WELL SHUT IN. TBG PRESSURE - 2211 PSI Page 23 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 8/13/2010 24 hr summary MIRU BJ COIL UNIT, PERFORM WEEKLY BOPE TEST, PERFORM FCO TO 5,880'CTM 50' BELOW BTM PERF'S. PUMPED TOTAL OF 200 BBLS KCL DURING CLEAN-OUT RETURNED 220 BBLS FLUID, WHP NOT BUILDING DURING FCO, TROUBLE MAINTAINING 1,000 PSI MINIMUM BACK PRESSURE. MAKE ADDITIONAL RUN IN HOLE TO DRY TAG DEPTH OF 5,881'CTM, POOH TO TT @ 4,880'CTM, START PUMPING N2 @ 500 SCFM WHILE PULLING OUT OF HOLE @ 60 FPM, WHP APPEAR TO BE CLIMBING. FINAL WHP 1269 PSI. SHUT WELL IN. WHP INCREASED TO 1901 PSI IN 1.5 HRS. OPEN WELL TO PTS. FLOWING AT 0.337 MCF AT 1900 PSI FOR 2 HRS. 00:00 06:00 6.00 SURPRI PRDT P I LEFT WELL SHUT-IN 06:00 07:00 1.00 SURPRI SFTY P OPS MEETING AND DAILY PER TOUR MEETING 07:00 10:00 3.00 SURPRI CTOP P MIRU BJ COIL, STAB BOPE ON WELLHEAD, PERFORM WEEKLY BOP TEST. TEST WAIVED BY AOGCC JIM REGG ON 8/11/10. Page 24 of 28 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:00 20:30 10.50 SURPRI CTOP P PICK-UP INJECTOR, MAKE UP BHA, INJECTOR TO WELLHEAD, SHELL TEST TO 3,500 PSI, START IN HOLE @ 60 FPM, CIRCULATE KCL @ MIN RATE WHILE GOING IN HOLE.BEGIN N2 COOL DOWN @ 4,000'CTM, BRING ON N2 @ 250 SCFM, RIH TO 5,800'CT, INCREASE KCL RATE TO 1.75 BPM AND N2 500 SCFM, WHP 1715 PSI CTP 4,950 PSI, AT 5,830'CTM SLOW PENETRATE RATE TO 5 FPM, WASH SAND TO 5,880'CTM. MAKE TWO WIPER PASSES TO SAME DEPTH, GETTING GO RETURNS, HEAVY SAND AT TIMES, 1:1 RETURN RATE, CIRCULATE ON BTM 10 MINS, START OUT OF HOLE @ 25 FPM TO 4,900'CTM, POOH @ 80-100 FPM, WHP PRESSURE DOWN CLOSE TO 1,000 PSI, HAD TO PINCH BACK CHOKE SEVERAL TIMES TO MAINTAIN 1,000 PSI MINIMUM. STOP KCL @ 4,880'CTM, STOP N2 @ 1,000'CTM, AT SURFACE. MONITOR WHP PRESSURE FOR BUILD UP. PRESSURE NOT BUILDING, START BACK IN HOLE TO 4,840'CTM, START PUMPING N2 @ 500 SCFM, CONTINUE IN HOLE TO 5,860'CTM, GET ADDITIONAL 25 BBLS WATER TO RETURN TANKS FOR TOTAL OF 200 BBLS RETURNED, PUMPED 210 BBLS. SHUT DOWN N2 AND DRY TAG @ 5,881'CTM. START OUT OF HOLE TO TT @ 4,880'WLM, START PUMPING N2 @ 500 SCFM, CONTINUE OUT OF HOLE @ 60 FPM, MINIMAL WATER IN RETURNS, WHP PRESSURE BUILDING COMING OUT OF HOLE. FINAL WHP - 1269 PSI. SHUT WELL IN. 20:30 22:00 1.50 SURPRI PRDT P WHP INCREASED TO 1901 PSI IN 1.5 HRS. 22:00 00:00 2.00 SURPRI PRDT P OPEN WELL TO PTS. WELL PRODUCING 0.337 MCF AT 1900 PSI WITH NO WATER OR SOLIDS. 8/14/2010 CURRENTLY MAKING .337 MCF GAS RATE @ 1,900 PSI. PERFORM TEMP/PRESSURE SURVEY TO 5,860'WLM, POOH @ 60 FPM, DATA REVEALED FLUID LEVEL @ 5,310' WLM, RDMO POLLARD. GOT OK TO DRAW WHP TO 1,650 PSI GAS RATE STABLE @.660 MCF. DECISION MADE TO RIH WITH COIL TO PERFORM N2 LIFT @ 5,810 AT MAX N2 RATE TO TT, CONTINUE OOH @ 500 MCF. MONITOR FLOW BACK THROUGHOUT NIGHT. Page 25 of 28 Time Logs Date From To Dur S. De th E. Dei3th Phase Code Subcode T Comment 00:00 06:00 6.00 SURPRI PRDT P WELL CURRENTLY MAKING .337 MCF @ 1,900 PSI, CONTINUE TO MONITOR FLOW BACK. 06:00 07:00 1.00 SURPRI SFTY P OPS MEETING AND PER TOUR MEETING. 07:00 11:00 4.00 SURPRI SLKL P MIRU POLLARD W/L, PT LUB 2,000 PSI. PERFORM TEMP/PRESSURE SURVEY TO 5,860' WLM. POOH @ 60 FPM, DOWNLOAD DATA, DATA REVEALED FLUID LEVEL 5,310' MD. RDMO POLLARD. WHP 2,110 PSI. 11:00 15:00 4.00 SURPRI PRDT P GIVE WELL BACK TO PTS FOR FLOW BACK, GOT OK TO DRAW WELL DOWN TO 1,650 PSI IN 100 PSI STEPS. GAS RATE STABLE @ .660 MCF WHP 1,650 PSI, OVER LAST HOUR. DECIDE TO RIG UP COIL. 15:00 21:00 6.00 SURPRI CTOP P PICK-UP INJECTOR HEAD, STAB ON WELLHEAD, SHELL TEST TO 2,000 PSI. START IN HOLE WITH COIL, ESTABLISH N2 (500 SCFM) TO SURFACE BEFORE EXITING TT @ 4,891'MD. CONTINUE IN HOLE TO 5,882' CTM TAG FILL, OOH TO 5,810'CTM, INCREASE N2 RATE TO 1,500 SCFM, CONTINUE OOH TO TT @ 4,891'CTM, RETURNED 20 BBLS WATER TO SURFACE, POOH WITH COIL @ 60 FPM 500 SCFM, 400'CTM SHUT DOWN N2, ON SURFACE WITH COIL, CLOSE SWAB, RACK BACK INJECTOR, SECURE WELLHEAD, GIVE WELL TO PTS. 21:00 00:00 3.00 SURPRI PRDT P PTS MONITOR FLOW BACK THROUGHOUT NIGHT. WELL FLOWING 1.713 MCF AT 1650 PSI. NO WATER OR SOLIDS IN RETURNS. 8/15/2010 CONTINUE FLOW BACK THROUGH PTS EQUIPMENT, CURRENTLY MAKING 1.9 MCF AT 1,700 WHP, RECOVERED 2 BBLS WATER OVERNIGHT. MIRU POLLARD PERFORM FBHP SURVEY FROM 5,850'WLM, FLUID LEVEL @ 5,836' MD, SURFACE WHP 1,710 PSI, 5,850'WLM 2,110 PSI. DECISION MADE TO RIG DOWN POLLARD AND BJ COIL BOP STACK, RDMO BOTH POLLARD & BJ COIL. CONTINUE TO FLOW BACK THROUGH PTS @ 1,600 WHP. DROPPED TWO SOAP STICKS AT 21:30, MONITOR FLOW BACK. 00:00 06:00 6.00 SURPRI PRDT P CONTINUE FLOW BACK THROUGH PTS EQUIPMENT, CURRENTLY MAKING 1.9 MCF AT 1,700 WHP, RECOVERED 2 BBLS WATER OVERNIGHT. 06:00 07:00 1.00 SURPRI SFTY P OPS MEETING & PER TOUR MEETING. Page 26 of 218 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 12:00 5.00 SURPRI SLKL P MIRU POLLARD S/L, TEST LUB. 2,000 PSI, PERFORM FBHP SURVEY TO 5,850'WLM, POOH. DOWNLOAD DATA, SEND TO JOHN BULTER. WHP 1,710 PSI, 5,850' 2,110 PSI, FLUID LEVEL @ 5.836'M D. 12:00 17:00 5.00 SURPRI RURD P DECISION MADE TO RDMO POLLARD & BJ COIL EQUIPMENT. MOVE BJ EQUIPMENT TO BRWD FOR FCO, MI SWACO READY EQUIPMENT FOR DEMOB. DECISION MADE AT 15:30 TO LOWER WHP FROM 1,700 TO 1,600. MONITOR FLOW THROUGH PTS. 17:00 00:00 7.00 SURPRI PRDT P CURRENTLY FLOWING AT 1,600 WHP, GAS RATE 2.6 MCF, MADE 3 BBLS WATER SINCE 15:30. DROPPED TWO SOAP STICKS AT 21:30, CONTINUE TO MONITOR FLOWBACK. CURRENT RATE IS 2.78 MCF, MADE 3 BBLS OF WATER SINCE 17:30. 8/16/2010 CONTINUE FLOW BACK THROUGH PTS EQUIPMENT, CURRENTLY MAKING 3.089 MCF AT 1,625 WHP, RECOVERED 8-10 BBLS WATER LAST 24 HOURS. OFFLOAD UNUSED 6% KCL AT BRU 232-09 CLASS 1 WELL. 00:00 06:00 6.00 SURPRI PRDT P CONTINUE FLOW BACK THROUGH PTS EQUIPMENT, CURRENTLY MAKING 2.9 MCF AT 1,625 WHP, RECOVERED 8 BBLS WATER LAST 24 HOURS. 06:00 07:00 1.00 SURPRI SFTY P OPS MEETING & PER TOUR MEETING 07:00 18:00 11.00 SURPRI PRDT P CONTINUE TO MONITOR FLOW BACK, OFFLOAD ACCESS KCL ( 700 BBLS) TO BRU 232-09 CLASS 1 WELL. CURRENTLY AT 12:00 HRS GAS RATE AVERAGE IS 2.859 MSCFD, MADE 1 BBL WATER LAST SIX HOURS. CURRENTLY AT 15:00 HRS GAS RATE 2.998 MSCFD, LITTLE OR NO WATER. 18:00 00:00 6.00 SURPRI PRDT P CONTINUE FLOWBACK, CURRENTLY @ 1,625 WHP GAS RATE 3.03 MCF WITH LITTLE OR NO RATE. AT 21:30 HRS 1,620 WHP GAS RATE 3.035 MCF NO WATER. CURRENTLY AT 1,625 WHP GAS RATE 3.089 MCF LITTLE WATER. 8/17/2010 Continue to flow test well, average gas rate of 2.98 mscfpd w/ 10 bbls of water w/ 1675 psi WHP. 00:00 00:00 24.00 SURPRI PRDT P Continue to flow test well, average gas rate of 2.98 mscfpd w/ 10 bbls of water w/ 1675 psi WHP. Page 27 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment SURPRI 8/18/2010 Continue Flow Test. Rig down and move. 00:00 00:00 24.00 SURPRI MOVE DMOB P Rig down and move out MI Equipment from Location. Production will continue to flow well until Flowline tie in is ready. Average gas rate of 3.24 mscfpd w/ Less than1 bbl of water w/ 1707 psi WHP. 8/19/2010 Rig down and move. 00:00 00:00 24.00 1 SURPRI MOVE DMOB I P 8/20/2010 00:00 00:00 24.00 1 SURPRI MOVE DMOB P Page 28 of 28 ConocoPhillips(Alaska) Inc. Beluga River Beluga River BRU 212-24T Sperry Drilling vi Definitive Survey Report 13 July, 2010 Sperry Drilling Services ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production Droject Beluga River Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well BRU 212-24T From To I Well Position +N/ -S 0.00 ft Northing: 147.07 2,633,574.84ft Latitude: 61- 12' 16.386 N', MWD + Short Collar correction + BHA SAG Co 6/15/2010 1: +E/ -W 0.00 ft Easting: MWD + Short Collar correction + BHA SAG Co 6/23/2010 1: 323,481.44 ft Longitude: 151° 0' 3.247 W Position Uncertainty 0.00 ft Wellhead Elevation: 18.50 ft Ground Level: 78.67ft Wellbore BRU 212-24T (ft) (ft) (ft) C111001) (ft) Survey Tool Name Magnetics Model Name 0.00 Sample Date Declination Dip Angle Field Strength 0.00 2,633,574.84 323,481.44 0.00 (I 147.07 (') (nT) 124.46 BGGM2009 6/20/2010 -0.76 18.57 74.03 55,736 Design BRU 212-24T -0.76 MWD+SCC+SAG (1) 204.94 1.13 132.06 204.92 Audit Notes: -1.48 2.02 2,633,573.33 323,483.44 0.29 -1.48 MWD+SCC+SAG (1) Version: 1.0 131.28 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: 2,633,572.44 Depth From (TVD) +W -S +E/ -W Direction 101.60 324.81 227.64 (ft) (ft) (ft) (°) 1.40 -2.90 MWD+SCC+SAG (1) 389.37 18.50 0.00 0.00 0.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 147.07 2,812.49 BRU 212-24T (R100) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/15/2010 1: 2,910.15 3,705.21 BRU 212-24T (R200) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/23/2010 1: 3,768.63 6,473.56 BRU 212-24T (R300) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/29/2010 1; Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) V) (`) (ft) (ft) (ft) (ft) (ft) (ft) C111001) (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -78.67 0.00 0.00 2,633,574.84 323,481.44 0.00 0.00 UNDEFINED 147.07 1.19 124.46 147.06 49.89 -0.76 1.10 2,633,574.07 323,482.53 0.93 -0.76 MWD+SCC+SAG (1) 204.94 1.13 132.06 204.92 107.75 -1.48 2.02 2,633,573.33 323,483.44 0.29 -1.48 MWD+SCC+SAG (1) 265.26 1.37 131.28 265.22 168.05 -2.35 3.00 2,633,572.44 323,484.41 0.40 -2.35 MWD+SCC+SAG (1) 324.86 0.70 101.60 324.81 227.64 -2.90 3.90 2,633,571.89 323,485.29 1.40 -2.90 MWD+SCC+SAG (1) 389.37 0.77 93.44 389.32 292.15 -3.00 4.71 2,633,571.77 323,486.11 0.19 -3.00 MWD+SCC+SAG (1) 447.80 1.08 88.76 447.74 350.57 -3.01 5.66 2,633,571.74 323,487.05 0.55 -3.01 MWD+SCC+SAG (1) 509.63 1.00 97.65 509.56 412.39 -3.07 6.77 2,633,571.67 323,488.17 0.29 -3.07 MWD+SCC+SAG(1) 569.35 1.14 97.46 569.27 472.10 -3.22 7.88 2,633,571.50 323,489.27 0.23 -3.22 MWD+SCC+SAG(1) 628.04 1.04 90.30 627.95 530.78 -3.30 8.99 2,633,571.41 323,490.38 0.29 -3.30 MWD+SCC+SAG (1) 687.56 1.29 104.20 687.46 590.29 -3.46 10.18 2,633,571.22 323,491.57 0.63 -3.46 MWD+SCC+SAG(1) 747.53 0.90 92.65 747.42 650.25 -3.65 11.31 2,633,571.02 323,492.69 0.74 -3.65 MWD+SCC+SAG(1) 7/13/2010 9:18:40AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Easting DLS Section (ft) 111 (`) (ft) (n) (ft) (n) (ft) (ft) ("1100') (ft) Survey Tool Name 777.00 0.89 93.35 776.88 679.71 -3.68 11.77 2,633,570.99 323,493.15 0.05 -3.68 MWD+SCC+SAG (1) 844.01 0.96 92.17 843.89 746.72 -3.73 12.85 2,633,570.92 323,494.23 0.11 -3.73 MWD+SCC+SAG (1) 906.41 1.25 94.73 906.27 809.10 -3.80 14.05 2,633,570.83 323,495.43 0.47 -3.80 MWD+SCC+SAG(1) 967.25 1.40 60.24 967.10 869.93 -3.49 15.35 2,633,571.12 323,496.74 1.31 -3.49 MWD+SCC+SAG (1) 1,033.48 2.66 30.44 1,033.29 936.12 -1.76 16.83 2,633,572.82 323,498.25 2.42 -1.76 MWD+SCC+SAG (1) 1,096.65 3.93 15.12 1,096.35 999.18 1.59 18.14 2,633,576.16 323,499.60 2.43 1.59 MWD+SCC+SAG (1) 1,158.72 4.68 2.34 1,158.25 1,061.08 6.18 18.80 2,633,580.73 323,500.33 1.95 6.18 MWD+SCC+SAG(1) 1,220.94 6.02 352.30 1,220.20 1,123.03 11.95 18.47 2,633,586.50 323,500.09 2.62 11.95 MWD+SCC+SAG (1) 1,284.41 7.91 353.26 1,283.20 1,186.03 19.58 17.51 2,633,594.15 323,499.25 2.98 19.58 MWD+SCC+SAG (1) 1,346.66 9.24 351.85 1,344.75 1,247.58 28.78 16.30 2,633,603.37 323,498.18 2.16 28.78 MWD+SCC+SAG (1) 1,411.20 10.08 350.31 1,408.37 1,311.20 39.48 14.61 2,633,614.09 323,496.65 1.36 39.48 MWD+SCC+SAG (1) 1,473.60 9.46 347.39 1,469.87 1,372.70 49.87 12.57 2,633,624.51 323,494.78 1.27 49.87 MWD+SCC+SAG (1) 1,537.25 9.36 345.84 1,532.66 1,435.49 59.99 10.16 2,633,634.67 323,492.52 0.43 59.99 MWD+SCC+SAG (1) 1,601.33 9.08 345.24 1,595.91 1,498.74 69.93 7.60 2,633,644.65 323,490.11 0.46 69.93 MWD+SCC+SAG (1) 1,664.24 9.28 343.87 1,658.02 1,560.85 79.61 4.93 2,633,654.36 323,487.59 0.47 79.61 MWD+SCC+SAG (1) 1,726.45 8.74 348.26 1,719.46 1,622.29 89.05 2.57 2,633,663.84 323,485.38 1.40 89.05 MWD+SCC+SAG (1) 1,789.69 8.78 351.42 1,781.96 1,684.79 98.53 0.87 2,633,673.34 323,483.82 0.76 98.53 MWD+SCC+SAG(1) 1,852.32 8.87 352.80 1,843.85 1,746.68 108.05 -0.44 2,633,682.87 323,482.65 0.37 108.05 MWD+SCC+SAG (1) 1,914.13 8.93 355.99 1,904.92 1,807.75 117.56 -1.38 2,633,692.40 323,481.86 0.80 117.56 MWD+SCC+SAG (1) 1,978.19 9.45 355.93 1,968.16 1,870.99 127.76 -2.10 2,633,702.62 323,481.30 0.81 127.76 MWD+SCC+SAG(1) 2,041.48 9.63 355.15 2,030.57 1,933.40 138.22 -2.91 2,633,713.08 323,480.64 0.35 138.22 MWD+SCC+SAG (1) 2,103.75 8.97 351.53 2,092.02 1,994.85 148.21 -4.07 2,633,723.09 323,479.64 1.42 148.21 MWD+SCC+SAG (1) 2,168.40 8.83 348.34 2,155.89 2,058.72 158.06 -5.81 2,633,732.96 323,478.05 0.79 158.06 MWD+SCC+SAG(1) 2,230.81 9.51 346.92 2,217.51 2,120.34 167.77 -7.95 2,633,742.70 323,476.06 1.15 167.77 MWD+SCC+SAG (1) 2,292.97 8.98 349.01 2,278.86 2,181.69 177.54 -10.04 2,633,752.50 323,474.12 1.01 177.54 MWD+SCC+SAG (1) 2,356.76 8.75 349.22 2,341.89 2,244.72 187.19 -11.89 2,633,762.18 323,472.42 0.36 187.19 MWD+SCC+SAG (1) 2,418.95 9.29 348.48 2,403.31 2,306.14 196.75 -13.78 2,633,771.77 323,470.68 0.89 196.75 MWD+SCC+SAG (1) 2,482.23 9.12 351.58 2,465.77 2,368.60 206.72 -15.53 2,633,781.76 323,469.07 0.83 206.72 MWD+SCC+SAG(1) 2,545.39 8.84 350.47 2,528.16 2,430.99 216.46 -17.07 2,633,791.52 323,467.69 0.52 216.46 MWD+SCC+SAG (1) 2,608.38 7.88 350.94 2,590.48 2,493.31 225.50 -18.55 2,633,800.58 323,466.34 1.53 225.50 MWD+SCC+SAG (1) 2,671.86 7.38 354.27 2,653.40 2,556.23 233.85 -19.64 2,633,808.95 323,465.38 1.05 233.85 MWD+SCC+SAG (1) 2,734.22 6.47 355.08 2,715.30 2,618.13 241.34 -20.35 2,633,816.44 323,464.79 1.47 241.34 MWD+SCC+SAG (1) 2,797.14 5.31 355.76 2,777.89 2,680.72 247.77 -20.87 2,633,822.89 323,464.37 1.85 247.77 MWD+SCC+SAG (1) 2,812.49 4.94 354.56 2,793.18 2,696.01 249.14 -20.98 2,633,824.25 323,464.28 2.51 249.14 MWD+SCC+SAG (1) 2,910.15 3.48 347.93 2,890.57 2,793.40 256.22 -22.00 2,633,831.35 323,463.37 1.57 256.22 MWD+SCC+SAG (2) 2,947.31 2.82 346.29 2,927.67 2,830.50 258.21 -22.45 2,633,833.35 323,462.95 1.79 258.21 MWD+SCC+SAG (2) 3,011.35 2.22 345.83 2,991.65 2,894.48 260.95 -23.13 2,633,836.09 323,462.31 0.94 260.95 MWD+SCC+SAG (2) 3,074.63 1.89 333.69 3,054.89 2,957.72 263.07 -23.89 2,633,838.23 323,461.58 0.86 263.07 MWD+SCC+SAG (2) 3,137.42 1.32 321.97 3,117.66 3,020.49 264.57 -24.80 2,633,839.74 323,460.70 1.04 264.57 MWD+SCC+SAG (2) 3,200.95 1.29 318.45 3,181.17 3,084.00 265.68 -25.72 2,633,840.87 323,459.79 0.13 265.68 MWD+SCC+SAG (2) 7/1312010 9:18:40AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +E/ -W Northing Easting DLS Section (ft) (I (I (ft) (ft) (ft) (ft) Oil) (ft) ('1100') (ft) Survey Tool Name 3,263.93 1.02 304.28 3,244.14 3,146.97 266.53 -26.65 2,633,841.73 323,458.87 0.62 266.53 MWD+SCC+SAG (2) 3,326.61 0.73 283.57 3,306.81 3,209.64 266.93 -27.50 2,633,842.15 323,458.03 0.68 266.93 MWD+SCC+SAG (2) 3,388.31 0.53 258.29 3,368.51 3,271.34 266.97 -28.16 2,633,842.19 323,457.37 0.55 266.97 MWD+SCC+SAG (2) 3,453.12 1.00 253.83 3,433.31 3,336.14 266.75 -29.00 2,633,841.99 323,456.53 0.73 266.75 MWD+SCC+SAG (2) 3,515.57 0.91 257.62 3,495.75 3,398.58 266.49 -30.01 2,633,841.74 323,455.52 0.18 266.49 MWD+SCC+SAG (2) 3,578.51 0.94 248.20 3,558.68 3,461.51 266.19 -30.98 2,633,841.46 323,454.55 0.25 266.19 MWD+SCC+SAG (2) 3,641.83 0.79 237.19 3,622.00 3,524.83 265.76 -31.83 2,633,841.04 323,453.69 0.35 265.76 MWD+SCC+SAG (2) 3,705.21 0.92 246.88 3,685.37 3,588.20 265.33 -32.66 2,633,840.62 323,452.85 0.31 265.33 MWD+SCC+SAG (2) 3,768.63 0.84 264.66 3,748.78 3,651.61 265.08 -33.59 2,633,840.39 323,451.91 0.45 265.08 MWD+SCC+SAG (3) 3,827.07 0.70 250.18 3,807.22 3,710.05 264.92 -34.35 2,633,840.24 323,451.15 0.41 264.92 MWD+SCC+SAG (3) 3,891.75 0.82 255.46 3,871.89 3,774.72 264.67 -35.17 2,633,840.00 323,450.33 0.21 264.67 MWD+SCC+SAG (3) 3,954.23 0.87 252.93 3,934.37 3,837.20 264.42 -36.06 2,633,839.77 323,449.44 0.10 264.42 MWD+SCC+SAG (3) 4,018.08 0.66 270.03 3,998.21 3,901.04 264.28 -36.89 2,633,839.64 323,448.60 0.48 264.28 MWD+SCC+SAG (3) 4,081.49 0.79 280.88 4,061.61 3,964.44 264.36 -37.69 2,633,839.73 323,447.81 0.30 264.36 MWD+SCC+SAG (3) 4,143.50 0.84 279.67 4,123.62 4,026.45 264.52 -38.55 2,633,839.90 323,446.94 0.09 264.52 MWD+SCC+SAG (3) 4,208.72 0.62 281.17 4,188.83 4,091.66 264.67 -39.37 2,633,840.06 323,446.13 0.34 264.67 MWD+SCC+SAG (3) 4,269.90 0.73 282.22 4,250.01 4,152.84 264.81 -40.08 2,633,840.22 323,445.43 0.18 264.81 MWD+SCC+SAG (3) 4,334.54 0.63 282.42 4,314.64 4,217.47 264.98 -40.83 2,633,840.40 323,444.68 0.15 264.98 MWD+SCC+SAG (3) 4,396.54 0.65 292.94 4,376.64 4,279.47 265.19 -41.48 2,633,840.62 323,444.03 0.19 265.19 MWD+SCC+SAG (3) 4,461.14 0.44 289.48 4,441.24 4,344.07 265.41 -42.05 2,633,840.85 323,443.46 0.33 265.41 MWD+SCC+SAG (3) 4,523.51 0.40 288.41 4,503.61 4,406.44 265.56 -42.49 2,633,841.01 323,443.03 0.07 265.56 MWD+SCC+SAG (3) 4,585.73 0.34 294.18 4,565.82 4,468.65 265.71 -42.86 2,633,841.16 323,442.66 0.11 265.71 MWD+SCC+SAG (3) 4,648.74 0.42 293.31 4,628.83 4,531.66 265.87 -43.24 2,633,841.33 323,442.28 0.13 265.87 MWD+SCC+SAG (3) 4,712.36 0.34 282.82 4,692.45 4,595.28 266.01 -43.64 2,633,841.47 323,441.88 0.17 266.01 MWD+SCC+SAG (3) 4,774.68 0.48 287.51 4,754.77 4,657.60 266.13 -44.07 2,633,841.60 323,441.45 0.23 266.13 MWD+SCC+SAG (3) 4,837.27 0.55 273.19 4,817.36 4,720.19 266.22 -44.62 2,633,841.70 323,440.90 0.23 266.22 MWD+SCC+SAG (3) 4,901.63 0.61 287.97 4,881.71 4,784.54 266.35 -45.26 2,633,841.83 323,440.27 0.25 266.35 MWD+SCC+SAG (3) 4,964.67 0.56 306.27 4,944.75 4,847.58 266.63 -45.82 2,633,842.13 323,439.71 0.31 266.63 MWD+SCC+SAG (3) 5,027.16 0.50 311.93 5,007.24 4,910.07 266.99 -46.27 2,633,842.50 323,439.27 0.13 266.99 MWD+SCC+SAG (3) 5,089.91 0.42 295.35 5,069.99 4,972.82 267.28 -46.68 2,633,842.78 323,438.86 0.25 267.28 MWD+SCC+SAG (3) 5,152.87 0.46 277.35 5,132.94 5,035.77 267.41 -47.14 2,633,842.92 323,438.40 0.23 267.41 MWD+SCC+SAG (3) 5,216.03 0.36 293.27 5,196.10 5,098.93 267.52 -47.58 2,633,843.04 323,437.97 0.24 267.52 MWD+SCC+SAG (3) 5,279.28 0.44 284.13 5,259.35 5,162.18 267.66 -47.99 2,633,843.18 323,437.55 0.16 267.66 MWD+SCC+SAG (3) 5,341.90 0.29 321.97 5,321.97 5,224.80 267.84 -48.33 2,633,843.37 323,437.23 0.44 267.84 MWD+SCC+SAG (3) 5,405.81 0.29 355.00 5,385.88 5,288.71 268.13 -48.44 2,633,843.66 323,437.12 0.26 268.13 MWD+SCC+SAG (3) 5,468.70 0.37 351.18 5,448.77 5,351.60 268.49 -48.48 2,633,844.02 323,437.08 0.13 268.49 MWD+SCC+SAG (3) 5,531.85 0.40 347.16 5,511.92 5,414.75 268.90 -48.56 2,633,844.44 323,437.00 0.06 268.90 MWD+SCC+SAG (3) 5,595.10 0.30 334.08 5,575.17 5,478.00 269.27 -48.69 2,633,844.81 323,436.89 0.20 269.27 MWD+SCC+SAG (3) 5,657.37 0.28 337.69 5,637.43 5,540.26 269.56 -48.82 2,633,845.10 323,436.76 0.04 269.56 MWD+SCC+SAG (3) 5,720.22 0.24 310.29 5,700.28 5,603.11 269.78 -48.97 2,633,845.32 323,436.61 0.21 269.78 MWD+SCC+SAG (3) 7/1312010 9:18:40AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (ft) (I (I (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,782.95 0.27 304.08 5,763.01 5,665.84 269.95 -49.20 2,633,845.50 323,436.39 0.06 269.95 MWD+SCC+SAG (3) 5,846.35 0.28 298.07 5,826.41 5,729.24 270.11 -49.46 2,633,845.66 323,436.13 0.05 270.11 MWD+SCC+SAG (3) 5,909.81 0.15 297.74 5,889.87 5,792.70 270.22 -49.67 2,633,845.77 323,435.92 0.20 270.22 MWD+SCC+SAG (3) 5,971.80 0.06 311.83 5,951.86 5,854.69 270.28 -49.76 2,633,845.83 323,435.83 0.15 270.28 MWD+SCC+SAG (3) 6,035.70 0.09 243.71 6,015.76 5,918.59 270.28 -49.83 2,633,845.83 323,435.76 0.14 270.28 MWD+SCC+SAG (3) 6,098.58 0.16 163.54 6,078.64 5,981.47 270.17 -49.85 2,633,845.73 323,435.73 0.27 270.17 MWD+SCC+SAG (3) 6,161.02 0.18 188.05 6,141.08 6,043.91 269.99 -49.84 2,633,845.55 323,435.74 0.12 269.99 MWD+SCC+SAG (3) 6,225.07 0.10 115.77 6,205.13 6,107.96 269.87 -49.81 2,633,845.42 323,435.78 0.28 269.87 MWD+SCC+SAG (3) 6,287.45 0.29 108.63 6,267.51 6,170.34 269.79 -49.61 2,633,845.35 323,435.97 0.31 269.79 MWD+SCC+SAG (3) 6,347.90 0.31 88.27 6,327.96 6,230.79 269.75 -49.30 2,633,845.30 323,436.28 0.18 269.75 MWD+SCC+SAG (3) 6,411.59 0.46 104.10 6,391.65 6,294.48 269.69 -48.88 2,633,845.23 323,436.70 0.29 269.69 MWD+SCC+SAG (3) 6,473.56 0.50 122.89 6,453.62 6,356.45 269.48 -48.41 2,633,845.02 323,437.17 0.26 269.48 MWD+SCC+SAG (3) 6,565.00 0.50 122.89 6,545.05 6,447.88 269.05 -47.74 2,633,844.58 323,437.83 0.00 269.05 PROJECTED to TO 7/13/2010 9:18:40AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips TRANSMITTAL Beluga River Unit development well data FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzer ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7`h Ave, Suite 100 Anchorage, Alaska 99501-3539 RE: BRU 212-24T Permit: 210-050 DATE: 08/11/2010 It Cook Inlet, Alaska Beluga River Unit 212-24T 502832013600 Report and CDROM End of Well Report, Mudlogging Data, BRU 212-24T; Halliburton. Well overview, morning reports, bit and mud records, formation tops, survey report, days v. depth, digital data Color log prints(10 total): Formation evaluation logs (MD) 2" and 5' Formation evaluation logs (TVD) 2" and 5" Gas ratio (MD) 2"& 5" Gas ratio (TVD) 2"& 5' Engineering Log (MD) 2"& 5' �v .2co��c3 To al/ data recipients: please s;on, scar and rewrn this transmi-fral ✓ia e-mail o the e -.nail address CC: Rick Leyinsorl. CPAI Geologist Receipt: Date: _ CiS-Technical Data Management Corcco,�hi1lips Anchcrage, Aaska ?h: 907,26.x.9 47 Sandra. D. Lemke0Con=,oh111ips com WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: Stage One: BRU #212-24T Run Date: 7/16/2010 July 30, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #212-24T Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-283-20136-00 Perforation Record 1 Color Log 50-283-20136-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3 rafael.barreto@ r Date: AUG 1 1 2010 Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: Stage Two: BRU #212-24T Run Date: 7/28/2010 July 30, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #212-24T Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-283-20136-00 Perforation Record 1 Color Log 50-283-20136-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@h V D Date: AUG 1 1 2010 05 101 ago �CO Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: CAST -CBL -Bridge Plug: BRU #212-24T Run Date: 7/3/2010 July 29, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #212-24T Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-283-20136-00 ACE Log 1 Color Log 50-283-20136-00 CAST -CBL Field print 1 Color Log 50-283-20136-00 Plug Setting Record 1 Color Log 50-283-20136-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273Y fnpg U rafael.barreto h. [E "' Date: AUG 1 1 2010 6! ls� D Signed: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Commission Attn: Christine Mahnken 333 W. 7th Ave., #100 Anchorage, AK 99501-3539 RE: MWD Formation Evaluation Logs: BRU 212-24T API #: 50-283-20136-00 BRU 212-24T 2" x 5" MD TRIPLE COMBO Logs: 2" x 5" TVD TRIPLE COMBO Logs: 2" x 5" MD TRIPLE COMBO+BAT Sonic Logs: 2" x 5" TVD TRIPLE COMBO+ BAT Sonic Logs: July 21, 2010 AK -MW -0007262432 1 Color Log 1 Color Log 1 Color Log 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 " a P Mai "Q_ i 3 Date: Signed: olv os -v /913a6 Alaska DNR, Division of Oil & Gas ore O AJAZEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Chip Alvord FAX (907) 276-7542 Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Beluga River Field, Sterling - Beluga Gas Pool, BRU212-24T ConocoPhillips Alaska, Inc. Permit No: 210-050 Surface Location: 2054' FNL & 144' FWL - Sec. 24, T13N, R10W, SM Bottomhole Location: 1800' FNL & 122' FWL - Sec.24, T13N, R10W, SM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips Alaska, Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. �2 Chair r� DATED this2Jday of April, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 20, 2009 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill BRU 212-24T Dear Sir or Madam: ConocoPhillips RECEIVED APR 2 1 2010 4alka ©il & U cons. Commission Andwage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development gas well from an existing pad in the Beluga River Field, Alaska. The well is designed to penetrate the Beluga sands, evaluate the lower Beluga H & I intervals and be completed as a non -gravel pack gas producer in the Beluga H & I sands. As indicated in the attachments, the drilling program will include drilling a 12-1/4" surface hole to approximately 3005' MD, cement 9-5/8" surface casing, followed by drilling an 8-3/4" hole through the Sterling and Beluga sands to approximately 6527' MD. Following drilling operations, the 7" casing will be run and cemented. At this time only LWD logs will be used for formation evaluation and correlation purposes. A 3-1/2" upper completion and baker premier packer will be run to approximately 5100'. The completion program will include off -rig perforating, fracturing and flowing back select zones in the lower Beluga H & I formations. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 6. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 7. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Dennis Hartwig at 265-6862 or Chip Alvord at 265-6120. Sincerely, M ennis Hartwig Drilling Engineer Attachments cc: BRU 232-23 Well File Chip Alvord ATO -1570 Mark Chambers ATO -1566 Scott Lowry ATO -1544 Art Copoulos ATO -934 John Braden ATO -932 Marta Czarneski Kenai LNG plant Tom Zelenka BLM Anchorage Field Office STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMA PERMIT TO DRILL 20 AAC 25.005 ION RECEI, ED ptil=,L =,p 10 APR 2 1 2010 1 a. Type of Work: 1 b. Proposed Well Class: Development - Oil ❑ Service - Winj ❑ Single Zone ❑ l+i jggjpn Drill 0 Redrill ❑ Stratigraphic Test ❑ Development - Gas 0 Service - Supply ❑ Multiple Zone ❑� Coalbed Gasdrates ❑ Z*Share6 Re-entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ as ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 • BRU212-24T 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360, Anchorage, AK 99510-0360 MD: 6527' TVD: 6509 Beluga River Field Sterling - Beluga Gas Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 2054' FNL & 144' FWL -Sec24, T13N, R10W, SM ADL 21128 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1800' FNL & 122' FWL - Sec24, T13N, R10W, SM N/A 6/15/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1800' FNL & 122 'FWL - Sec24, T13N, R10W, SM 489 1440'to CIRI property lease ADL58831 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 96.5 feet 15. Distance to Nearest Well O Surface: x- 323,481' • y- 2,633,576 Zone- 4 GL Elevation above MSL: 78 feet to Same Pool: BRU212-24 195' 16. Deviated wells: Kickoff depth: 1000 feet 17. Maximum Anticipated Pressures in psig (see 20 5.035) Maximum Hole Angle: 9 degrees Downhole: 3317 psig Surface: Z186,psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) na 20" 154.2 ppf X-65 Welded 85.87 22.63 22.63 108.5 108.5 Driven to refusal 12-1/2" 9-5/8" 40 ppf L-80 BTC 2982.45 22.55 22.55 3005 2981,K 803sx 12.0 ppg Lightweight slurry 8-3/4" 7" 26 ppf L-80 BTC -M 6507.26 19.74 19.74 6527 6509 259 x 10.5 ppg Lightweight slurry J) 3-1/2" 9.3 ppf L-80 EUEM -8rd 5082.34 17.66 17.66 5100 5081 production tubing and 3-1/2" x 7 premier packer 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat El BOP Sketch Q Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Contact Dennis Hartwig 265-6862 Printed Name G.L. Alvord Title Alaska Drilling Manager Signature y Phone 265-6120 Date +(L.' Q,4Lk p Commission Use Only Permit to Drill _ 2 �-'�% �� API Number:�� ' - c Q'i Permit App See cover letter for other Number: 50-1 %fj ( Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, as hydrates, or gas contained in shales: Other: Samples req'd: Yes ❑ [ Mud log req'd: Yes No L]No [� P r re S -be) C �10 `'r S O O �i.� H2S measures: Yes ❑ No [� Directional svy req'd: Yes [2"No ❑ 1 ' Pwr ,ua4A.t to 7,v AkC 2S. oss (') (Z), JtVeff4v YekAf 61te ►s a�wraVed . Ll::� APPROVED BY THE COMMISSION 4--ZZ3 C//) DATE: , COMMISSIONER Form 10-401 (Revised 7/2009) This permit 119 i RIGt r , e date of approval (20 AAC 25.005(g)) Submit in Duplicate BRU 212-24T Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12-1/4" Hole x 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Gas Hydrates Low Monitor well, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid Hole swabbing on trips Low viscosity, control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight. Offset Surface Formations drilling does not indicate abnormal pressures in Directional Control Medium the surface hole. Lost Circulation Medium Reduced pump rates, mud rheology, lost Sloughing Shale, Tight High circulation material, use of low density cement Hole slurries, port collar, controlled running seeds. 8-3/4" Hole x 7" Casing Interval Event Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring. This will be mitigated by LCM, low fluid loss mud additives and wellbore strengthening additives., Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density ECD monitoring, weighted sweeps. Directional Control Medium BHA design, geologic review and advisement of potential slump blocks. Sloughing Shale, Tight High Increased mud density to control the shales and Hole fluid composition according to plan, controlled trip seeds, sweeps, ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, offset Pressure well data does not indicate abnormal pressures in the area. Tight hole in coals Medium Control drilling, mud logs, crew awareness, documented Beluga coal drilling strategy develop from 2008 and 2009 programs. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers A copy of the Beluga Emergency action plan may be found under the ConocoPhillips Alaska shared drive or provided upon request. SA4NCILongtermV)ri11ing & Wells OpslCook InletOeluga 200916RU 212-2471Permits & RegulatorylEAP ML Beluga: BRU 212-24T General Procedure: i 1. MIRU Doyon's Arctic Fox over pre-installed 20" conductor casing with bolted landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to i test. 3. Spud well and drill 12_ 1J4" hole to the surface casing point at 3005' MD / 2986' TVD or approximately 2-75' above the Sterling A Sand. MWD/LWD logging tools (GR/RES) will be incorporated into the BHA for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. ■ Employ lightweight cement lead slurry assure cement returns to the surface in a one -stage job. Adequate excess (-70%) cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 3/4" bit and BHA and RIH to top of float equipment. ■ Pressure test casing to 3000 psi for 30 minutes ■ Record results and fax to town 8. Drill float equipment and approximately 20' of new hole ■ Perform LOT (or FIT if gradient reaches 16 ppg equivalent) ■ Record results and fax to town 9. Drill 8-3/4" hole to approximately 6527' MD / 6509' TVD or approximately 200' TVD below the Beluga I base. MWD/LWD (GR/RES/DENS/POROSITY/SONIC/PWD) logging tools will be incorporated into the BHA for directional monitoring, formation data gathering and ECD monitoring. Mud Logging services will also be used in the . production hole for total mud gas monitoring and for chromatography. POOH with drilling assembly after circulating and conditioning the well. 10. Run and cement 7" casing per program to TD (est.@ 6527' MD/ 6509' TVD). Cement casing to bring cement +/- 500' above Sterling A sand (3281'MD / 3263'TVD) . ■ If there are signs of lost circulation prior to running casing, install a Halliburton H ES stage cementing tool at +1- 3700' MD. 11. Run in hole with ing cleanup assembly on drillpipe. 12. Test casing to 40 psi. 13. Rig up Halliburton E -line and run cement bond log GR / CCL. nRIGINIAL "� % I 14. Run 3-1/2" Upper completion and Baker 3-1/2" x 7 Premier Packer per completion schematic. (Baker Premier Packer @ approximately 4817'MD) 15. Land tubing hanger and run in lock down screws. Test tubing hanger seals to 5000 psi. 16. Pump ball and rod to set Baker Premier Packer 17. Test inner annulus to 3000 psi for 30 minutes. (Note: This will test our tubing / integrity.) 18. Set BPV and ND BOP. 19. Nipple up tree and test same. 20. Rig down Doyon Arctic Fox and Move off Pad. 21. Rig up Pollard Slickline, Halliburton Eline, BJ Coil and Frac equipment and PTS Flowback equipment on pad. 22. Rig up lubricator on tree and test. 23. Run slickline and pull BPV. 24. Run slickline and pull ball and rod from packer. 25. Run slickline and pull RHC plug from XN nipple. 26. Run slickline to install frac sleeve across SSSV. 27. Rig up E -line and correlate depth to first perforation interval in Beluga H/I sand. Perforate interval #1 in Beluga H/I interval. Pull out of hole and inspect perforating guns. 28. Rig up PTS to tree and perform post pert flowback evaluation of Perf #1. Lift well with CTU and N2 unit as necessary. 29. Rig up BJ and frac zone #1 interval in the H/I sand with approximately 125,OOOlbs of proppant. 30. Rig down BJ, Rig up PTS and perform post frac flowback evaluation of Frac #1. Lift well with CTU and N2 unit as necessary. 31. Pump sand plug to sufficiently cover zone #1 perfs. RIH with E -line and tag sand plug. 32. Correlate E -line depth to #2 perforation interval in Beluga H/I sand. Perforate interval #2 in Beluga H/I interval. Pull out of hole and inspect perforating guns. 33. Rig up PTS to tree and perform post perf flowback evaluation of Perf #2. Lift well with CTU and N2 unit as necessary. 34. Rig up BJ and frac zone #2 interval in the H/I sand with approximately 125,OOOlbs of proppant. 35. Rig down BJ, Rig up PTS and perform post frac flowback evaluation of Frac #2. Lift well with CTU and N2 unit as necessary. 36. Pump sand plug to sufficiently cover zone #2 perfs. RIH with E -line and tag sand plug. ORIGINAL 37. Correlate E -line depth to #3 perforation interval in Beluga H/I sand. Perforate interval #3 in Beluga H/I interval. Pull out of hole and inspect perforating guns. 38. Rig up PTS to tree and perform post pert flowback evaluation of Perf #3. Lift well with CTU and N2 unit as necessary. 39. Rig up BJ and frac zone #3 interval in the H/I sand with approximately 125,000lbs of proppant. 40. Rig down BJ, Rig up PTS and perform post frac flowback evaluation of Frac #3. Lift well with CTU and N2 unit as necessary. 41. Pump sand plug to sufficiently cover zone #3 perfs. RIH with E -line and tag sand plug. 42. Correlate E -line depth to #4 perforation interval in Beluga H/I sand. Perforate interval #4 in Beluga H/I interval. Pull out of hole and inspect perforating guns. 43. Rig up PTS to tree and perform post pert flowback evaluation of Perf #4. Lift well with CTU and N2 unit as necessary. 44. Rig up BJ and frac zone #4 interval in the H/I sand with approximately 125,000lbs of proppant. 45. Rig down BJ, Rig up PTS and perform post frac flowback evaluation of Frac #4. Lift well with CTU and N2 unit as necessary. 46. Run in hole with coil and clean up sand to 9-5/8" float collar 47. Rig up PTS for final flowback period. Lift well with CTU and N2 unit as necessary. 48. Place well on production Well Proximity Risks: Directional drilli / collision avoidance information as required by 20 ACC 25.050 (b) is provided inf ow ng attachments. BRU 212-24 is the closest well. Minimum well separation is 96' at 6394' MD. Drilling Area Risks: The interbedded layers of the Sterling and Beluga sands may have reservoir pressure that varies from normal (water gradient) to depleted 3.3 - 4 ppg. Sufficient mud weight to control the shale and coal layers could provide very high (1700 psi +) overbalance on the depleted sand layers. Lost circulation is a risk. This will be mitigated by LCM, low fluid loss mud additives and wellbore strengthening additives. OP I G I N A I_ Drilling Fluid Program Surface Interval Fluid Properties Production Interval Fluid Properties Funnel API Fluid Drill Depth MD Depth MD Mud Wt. Viscosity Yield Point Loss Solids Solids (ppg) (ft) (Ib/gal) (cp) (Ib/100ft2) (ml/30min) pH (%) MBT 0 - 6,527' 8.8-9.6/ 200-300 40-60 NC -<10 +/-9.0 < 7% <35 Production Interval Fluid Properties Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: The Beluga Production Interval mud system will be an inhibitive water based mud system. The primary inhibitors are KCI which will be maintained at 6% by wt, and a proprietary shale inhibitor designed to enhance the inhibition of KCL as well as provide inhibition on it own. Other components of the system are Well Bore Strengthening materials designed to prevent lost circulation in low pressure depleted Zones of the upper hole section while drilling to TD for long string casing. The system also includes additives for aiding in the stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage. If well control becomes an issue, enough barite to increase the mud weight by one pound per gallon will be on location at all times, as well as the option to increase KCL concentration for added density. ORIGINAL Plastic API Fluid Depth MD Mud Wt. Viscosity Yield Point Loss Solids (ft) (ppg) (cp) (Ib/100ft2) (cc/30min) pH (%) 3,005'- 6,527' 9.6 - 0.0 1 18-20 18-20 <6 9.0-9.5 <5 Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: The Beluga Production Interval mud system will be an inhibitive water based mud system. The primary inhibitors are KCI which will be maintained at 6% by wt, and a proprietary shale inhibitor designed to enhance the inhibition of KCL as well as provide inhibition on it own. Other components of the system are Well Bore Strengthening materials designed to prevent lost circulation in low pressure depleted Zones of the upper hole section while drilling to TD for long string casing. The system also includes additives for aiding in the stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage. If well control becomes an issue, enough barite to increase the mud weight by one pound per gallon will be on location at all times, as well as the option to increase KCL concentration for added density. ORIGINAL BRU 212-24T PRESSURE INFORMATION AND CASING DESIGN: Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Casing Setting Maximum Pore Pore MASP Size Depth Pressure Pressure Drilling Gradient 20" 108.5' MD / 108.5' 8.6 ppg 51 NA TVD 9-5/8" 3005 MD / 2986' 9.0 ppg 1397 51 psi TVD 7" 6527' M D / 6509' 9.8 ppg / 3317 2186 psi TVD Expected Maximum Mud Weights: • 12-1/4" surface hole to 3005' MD / 2986' TVD: 9.6 ppg, pore pressures of up to 9.0 ppg may be present. • 8-3/4" production hole to 6527' MD / 6509' TVD: 10.0 ppg, pore pressures of up to 9.8 ppg may be present based on offset pressure data taken in 2008 and 2009. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) — 0.1 ] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.1 = Gas Gradient in psi/ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP — (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 20" Conductor Casing MASP = [(FG x 0.052) — 0.1 ] x D = [(11.0 x 0.052) — 0.1] x 108.5' = 51 psi OR MASP = FPP — (0.1 x D) = 1397 — (0.1 x 2986') =1098 psi 2. Drilling below 9-5/8" Surface Casing MASP= [(FG x 0.052) — 0.1] x D _ Ki 6,,x 0.052) — 0.1 ] x 2986' = 2186 psi OR MASP = FPP — (0.1 x D) 3 17 — (0.1 x 6509') 266.6 psi ** See the included BOP schematics, diverter layout for a minimum 3000 psi BOP configuration. It is planned to use a 5000 psi stack due to availability. Casing Design Performance Properties Size Hole Weight Grade Conn. Internal Collapse Tensile Yield Strength Joint Bod 20" NA 154.2 X-65 Welded Conductor f 9-5/8" 12.25 40 ppf L-80 BTC 5750 psi 3090 psi 916 916 kips kips 7" 8.75 26 ppf L-80 BTC -M 7240 psi 5410 psi 604 604 kips kips Casing Setting Depth Rational: 20" @ 108.5' MD RKB - Conductor casing driven to provide sufficient anchor for diverter system. 9-5/8" @ 3005' MD RKB - Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8-3/4" hole to top of reservoir. 7" @ 6527' MD RKB - Production casing shoe is below the base of the Beluga sands to provide pressure integrity and zonal isolation. Assumptions a) Use of lightweight cement slurries cement slurries for design purposes b) Temperature deration of pipe properties has not been applied to all strings c) Assume higher than expected mud weight, - conservative for most cases �\,VA L Cementing Program: ❖ 9 5/8" Surface Casing run to 3005' MD / 2986' TVD Cement from 3005' MD to surface with lightweight 12 ppg slurry. Assume 70% excess annular volume. Lead Slurry Volume Calculations: Conductor by 9-5/8" Annulus 90 ft x 1.4982 ft3/ft with 0% excess = 134.8 ft3 Open Hole by 9-5/8" Annulus 2915 ft x 0.3132 ft3/ft with 70% excess = 1552.1 ft3 9-5/8" 40 ppf Shoe Track 80 ft x 0.4257 ft3/ft with 0% excess = 34.1 ft3 Total Slurry Volume = 1721 ft3 @ 2.09 ft3/sk = 824 sacks System: 82 Sx Type I Cement + 0.05% bwoc Static Free + 25% bwoc LW -6 + 0.6% bwoc CD -32 + 0.1 % bwoc FL -52 + 1 gals/100 sack FP -61- + 0.4% bwoc Sodium Metasilicate + 0.9% bwoc BA -10A + 5% bwoc MPA -1 + 67.9% Fresh Water, Yielding 2.09 ft3/sk ❖ 7" Production, Casing run to 6527' MD / 6509' TVD Cement from 6527' MD to approximately 2781' MD (minimum 500' MD above Sterling A Formation) with lightweight cement 10.5 ppg. Assume 40% excess annular volume. Lead Slurry Volume Calculations: 9-5/8" x 7" Annulus 224 ft x 0.1585 ft3/ft with 0% excess = 35.5 ft3 Openhole x 7" Annulus 3442 ft x 0.1503 ft3/ft with 40% excess = 724.3 ft3 7" 26ppf Shoe Track 80 ft x 0.2148 ft3/ft with 0% excess = 17.2 ft3 Total Slurry Volume = 777 ft3 @ 2.99 ft3/sk = 260 sacks System: ��6sacks Class G Cement + 15% bwoc BA -90 + 0.05% bwoc Static Free + 4% bwoc R-3 + 1.4% bwoc FL -63 + 0.25 lbs/sack Cello Flake + 1% bwoc CD -32 + 1 gals/100 sack FP -61- + 0.5% bwoc Sodium Metasilicate + 22% bwoc LW -7-6 + 109.3% Fresh Water, yielding 2.99 ft3/sk If there are problems with lost circulation during drilling, logging or tripping, consideration will be made to including a hydraulic opening stage tool in the casing string, to help ensure cement coverage of the Sterling formation. BRU 212-24T Proposed Completion Schematic v.6 Depths based on BRU 212-24T WP05 Planned Survey (NAD27) ConocoPhi I I i ps 1/4" 316SS Control Line to SSSV @ XXXX' 0.049" wall thickness 3/8" 316SS Control Line to CCIS (a_) XXXX' 0.049" wall thickness Cannon Cross Counlina Protectors Flat Channel, dual channel, for 3.5" tubing, 0.375" cable, at every other joint 3-%" TRMAXX-5E SSSV 0 500' MD 2.812 X Profile, 5.176" OD, 2.812" ID, 55" long. 3.5" 9.3# EUE special clearance Box X Pin. 5K psi working press. Cannon Cross Coupling Protectors Flat Channel, single channel, for 3.5" tubing, 0.375" cable, at every other joint 3-%" x 1" Camco KBMG GLM w/ 1" DMY (a)' MD 2.867" drift ID, 5.39" major OD (oval shaped) 4500 psi external & 6000 psi internal test pressure. BJ 3.5" CCIS Chemical Infection Sub 13 Cr, 10K psi working pressure, 2.813" BJ X profile, 2.813" ID, 5.680" OD (eccentric), 37.5" long, double check valves to control line Baker 3.5"x7" Premier Packer @4817 'MD with alternate bore 2.813" XN Nipple w/ 2.75" No-Got7a Float Shoe @ 6527' MD Float Collar @ 6447'MD - . , i �° t i'; 1 Conductor (Driven): 20",.75", API 5L GRB, Full Grvd, R3 Driven to Refusal 91' Below Pad Grade Surface Casing: 9-5/8", 40#, L-80, BTC Set @ 3005' MD Production CasIM. 7",26.00#, L-80, BTC -Mod Set @ 6527' MD Tubing: 3-1/2", 9.3#, L-80, EUE 8RD-modified RA TAG in 7" CSG na XXXX' MD (XX.XX' Iona I Sterling A Sand 3281' MD / 3164' SSTVD / 3263' TVD Sterling B Sand 3465' MD / 3348' SSTVD / 3447' TVD Sterling C Sand 3616' MD / 3499' SSTVD / 3598' TVD RA TAG in 7" CSG (a, XXXX' MD (XX.XX' Iona 1 Beluga D Sand 3783' MD / 3666' SSTVD / 3765' TVD Beluga E Sand 4044' MD / 3927' SSTVD / 4026' TVD Beluga F Sand 4365' MD / 4248' SSTVD / 4347' TVD —Beluga G Sand 4798' MD / 4681' SSTVD / 4780' TVD RA TAG in 7" CSG alb XXXX' MD (XX.XX' Iona ) Beluga H Sand 5097' MD / 4980' SSTVD / 5079' TVD Beluga I Sand 5773' MD / 5656' SSTVD / 5755' TVD Beluga I Base 6322' MD / 6205' SSTVD / 6304' TVD REV DATE I BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION T11 J a z J NOTES. THIS 1. GEOGRAPHIC COORDINATES ARE NAD 83. �Z SURVEY 2. COORDINATES SHOWN ARE NAD 83 21 2223 INC ALASKA STATE PLANE, ZONE 4 IN SURVEY FEET. 24 3 3 C)-cri- 3. VERTICAL BENCHMARK IS WELL 221-23 Q:: REFERENCE ASSUILT DATE, 1976. 27 26 25 nr mom 8k 4. SURVEY CONTROL POINTS 18 AND 19 cRFFk SEC r ARE 5/8' REBAR SET FLUSH WITH GRADE. SURVEY CONTROL POINT 20 IS SET V SPIKE FLUSH WITH GRAVEL PAD.BELUGA 0 3 RUNWAY SCALE: 1"=100' 34 �O'- d' T13N T12N VICINITY MAP — 1" = 1 MILE BRU 212-24T LOCATED WITHIN PROTRACTED SEC. 24, T. 13 N., R. 10 W., SEWARD MERIDIAN. --� 2,053' F.N.L., 144' F.W.L.------ LAT. = 61 '12'14.386' N LONG. = 15100'11.290" W^ BRU 212-24 Y = Z633,336 ED / \ X= 1,463,508 1 DEHYDRATOR A \ I \\ p 20 y BUILDING C 8 \ \ PROPOSED, \ \ 212-24T \ \BRU GENERATOR HEATER \ X73 BUILDING BUILDING \ BRU 2,32-23 oHu \ '-EDGE OF GRADED \ RIG PAD LEGEND: .4 a. r 019 SURVEY CONTROL EDGE OF EXISTING—�— EXISTING WELL GRAVEL PAD PROPOSED CONDUCTOR o BOLLARD -0- POWER POLE OHu OVERHEAD UTILITY LOUNSBURY ASSOCIATES, INC. R\)ORS ENGINEERS YL4NNER, I9U7) ':7+4-5451 y", AREA: MODULE: UNIT: ConocoPhillips BELUGA RIVER UNIT 212-24T AS STAKED DRAWING Alaska, Inc. CADD FILE NO. DRAWING NO: PART: REV: BRU212-24TAS STAKED.dwg I BRU -24TAS STAKED.dwq 1 1 OF 1 1 0 I RU 212-35 U 212-T� I A029%7 HENS Y, N. 0 ff' U 3-34 T1 3N* ,Rf"- ADL017599 T. BR 1 ' - 2N2 04 f 4 3 I ORIGINAL. 0 ADU ConocoPhillips Alaska Inc. Proposed BRU 212-24T Well 1-13-10 Scale: I' =2,640' 09101902001 ` ADL Q 'i 1 SCALE IN MILES BRU 12-18 SRU S 13 Wt7-1 ADLO BRU 224-13 . ADL05 L31 ADL063055 BRIJ22 -2 Proposed BF 32-23 BRU 212-24 BRU 212-24 .r ADL021128 JY ADL021126 RU 14-2J BLUGA r-- ' BRU 11, radiug 0 RIVER ADL021"71 t-26 UNIT l 0' X65 BRU ADx.021129 ' SRU 233-27 � BR 121 2 ` . BRU _ 'Bi r I RU 212-35 U 212-T� I A029%7 HENS Y, N. 0 ff' U 3-34 T1 3N* ,Rf"- ADL017599 T. BR 1 ' - 2N2 04 f 4 3 I ORIGINAL. 0 ADU ConocoPhillips Alaska Inc. Proposed BRU 212-24T Well 1-13-10 Scale: I' =2,640' 09101902001 ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River Plan: BRU 212-24T BRU 212-24T Plan: BRU 212-24T (wp05) Standard Proposal Report 18 March, 2010 r - IHALLIBURTON Am Sperry Drilling Services �6 H161� OR161N:1L HALLIBURTON Project: Beluga River Site: Beluga River Well: Plan: BRU 212-24T Wellbore: BRU 212-24T WELLDEEARS: Plan: BRU 212-24T GrowdLevel: 90.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.002633336.001463508.0061° 12' 14.386N 151° 0' 11.290 W Sperry drilling -- Plan: BRU 212-24T (wp03) REFERENCE INFORMATION Co-ordinate (WE) Reference: Well Plan: BRU 212-24T, True North vertical (TVD) Reference: Plan: BRU 212-24 (H81 North) (18.5+90) Q 108.50ft (Arctic Fox) Measured Depth Reference: Plan: BRU 212-24 (H81 North) (18.5+90) Q 108.50ft (Arctic FmQ Calculation Method: Minimum Curvature -500 - -- -0 CASING DETAILS 500 TVD TVDSS MD Size Name 3023.50 2915.00 3038.50 9-5/8 95/8" 6518.20 6409.70 6533.69 7 7" - } 1000 1500 µ, 2000 DDI c 2500 0 t3000 9 5/8" a - - - , { BRI 12-24T (wp03) Staling 3500 U - 7 i ,._i...T.;. ;..J_i.. � 4000 - - - - - BRU 212-24T (w4)03) Beluga 1) rT_ T-T-1 T_T.. — } t Il � 4500 5000 -! — - - - - BRU 212-24T (wp03) 13J u,a II 5500 6000 - BRU 212 24T (wp03) B.Belu ' -�- 6500 7" BRU 212-24T (,,p B) BRU 212-24T (w03) 7000 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 Vertical Section at 355.070 (15001R/in) 300 275 B U 212 24T (� P03) - 250---- - A BRU 212-24T (wp03) Sterlin --- I P 225 9 5/8" 200 2750 .rJ_ - — - 0175 150 0125 00 100 --- O75 750 _ T Magr etic North: 13.62 50 Ma pet field 1 Str ngth: 5705. snT i 25 --91,Dip,4r _7, 1250 Date: 12/14/2009 °IV ode]: I3GGM2007 }' -25 -375 -350 -325 -300 -275 -250 -225 -200 -175 -150 -125 -100 -75 -50 -25 0 25 50 75 100 125 150 175 200 225 250 77S znn 175 zsn West(-)/East(+) (100 Win) C mxoPhillips AlaSka. Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Expl Project: Beluga River Site: Beluga River Well: Plan: BRU 212-24T Wellbore: BRU 212-24T Design: BRU 212-24T (wp05) Halliburton Standard Proposal Report Well Plan: BRU 212-24T Plan: BRU 212-24T @ 98.50ft (Arctic Fox) Plan: BRU 212-24T @ 98.50ft (Arctic Fox) True Minimum Curvature Project Beluga River, Alaska, USA Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Beluga River Site Position: Northing: 2,630,909.88ft Latitude: 61° 11'51.001 N From: Map Easting: 329,245.55ft Longitude: 150° 58'4.800 W Position Uncertainty: 0.00 ft Slot Radius: 0.. Grid Convergence: -0.85 ° Well Plan: BRU 212-24T Well Position +N/ -S 0.00 ft Northing: 2,633,575.63 ft Latitude: 61° 12'16.394 N +E/ -W 0.00 ft Easting: 323,480.57 ft Longitude: 151° 0'3.265 W Position Uncertainty 0.00 ft Wellhead Elevation: 18.50 ft Ground Level: 80.00 It Wellbore BRU 212-24T Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°I (°) (nT) BGGM2009 6/1/2010 18.59 74.03 55,735 Design BRU 212-24T (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 18.50 Vertical Section: Depth From (TVD) +N/ -S +EI -W Direction (ft) (ft) (ft) (°) 18.50 0.00 0.00 355.07 Plan Sections Measured Vertical TVD Dogleg Build Tum Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (ft) (°) (I (ft) ft (ft) (ft) (°1100ft) (°/1o0ft) (°/100ft) (°) 18.50 0.00 0.00 18.50 -80.00 0.00 0.00 0.00 0.00 0.00 0.00 1,000.00 0.00 0.00 1,000.00 901.50 0.00 0.00 0.00 0.00 0.00 0.00 1,361.73 9.04 355.07 1,360.23 1,261.73 28.38 -2.45 2.50 2.50 0.00 355.07 2,619.40 9.04 355.07 2,602.27 2,503.77 225.33 -19.45 0.00 0.00 0.00 0.00 2,981.13 0.00 0.00 2,962.50 2,864.00 253.71 -21.90 2.50 -2.50 0.00 180.00 3,281.13 0.00 0.00 3,262.50 3,164.00 253.71 -21.90 0.00 0.00 0.00 0.00 5,097.13 0.00 0.00 5,078.50 4,980.00 253.71 -21.90 0.00 0.00 0.00 0.00 5,773.13 0.00 0.00 5,754.50 5,656.00 253.71 -21.90 0.00 0.00 0.00 0.00 6,527.13 0.00 0.00 6,508.50 6,410.00 253.71 -21.90 0.00 0.00 0.00 0.00 3/18/2010 11:00:26AM Page 2 COMPASS 2003.16 Build 69 �t pt 0 Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Expl Project: Beluga River Site: Beluga River Well: Plan: BRU 212-24T Wellbore: BRU 212-24T Design: BRU 212-24T (wp05) Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: BRU 212-24T TVD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) MD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +EI -W Northing Easting DLS Vert Section (ft) (I V) (n) ft (ft) (ft) (n) (ft) -80.00 18.50 0.00 0.00 18.50 -80.00 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 18.51 0.00 0.00 18.51 -79.99 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 SHL: 2054' FNL, 144' FWL - Sec24,T13N,R10W 100.00 0.00 0.00 100.00 1.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 200.00 0.00 0.00 200.00 101.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 300.00 0.00 0.00 300.00 201.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 400.00 0.00 0.00 400.00 301.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 500.00 0.00 0.00 500.00 401.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 600.00 0.00 0.00 600.00 501.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 700.00 0.00 0.00 700.00 601.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 800.00 0.00 0.00 800.00 701.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 900.00 0.00 0.00 900.00 801.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 1,000.00 0.00 0.00 1,000.00 901.50 0.00 0.00 2,633,575.63 323,480.57 0.00 0.00 1,100.00 2.50 355.07 1,099.97 1,001.47 2.17 -0.19 2,633,577.81 323,480.42 2.50 2.18 1,200.00 5.00 355.07 1,199.75 1,101.25 8.69 -0.75 2,633,584.33 323,479.95 2.50 8.72 1,300.00 7.50 355.07 1,299.14 1,200.64 19.53 -1.69 2,633,595.19 323,479.18 2.50 19.61 1,361.73 9.04 355.07 1,360.23 1,261.73 28.38 -2.45 2,633,604.05 323,478.56 2.50 28.49 1,400.00 9.04 355.07 1,398.02 1,299.52 34.37 -2.97 2,633,610.05 323,478.13 0.00 34.50 1,500.00 9.04 355.07 1,496.78 1,398.28 50.03 -4.32 2,633,625.72 323,477.02 0.00 50.22 1,600.00 9.04 355.07 1,595.54 1,497.04 65.69 -5.67 2,633,641.40 323,475.91 0.00 65.94 1,700.00 9.04 355.07 1,694.30 1,595.80 81.35 -7.02 2,633,657.08 323,474.80 0.00 81.66 1,800.00 9.04 355.07 1,793.05 1,694.55 97.01 -8.37 2,633,672.76 323,473.68 0.00 97.37 1,900.00 9.04 355.07 1,891.81 1,793.31 112.67 -9.73 2,633,688.43 323,472.57 0.00 113.09 2,000.00 9.04 355.07 1,990.57 1,892.07 128.33 -11.08 2,633,704.11 323,471.46 0.00 128.81 2,100.00 9.04 355.07 2,089.32 1,990.82 143.99 -12.43 2,633,719.79 323,470.35 0.00 144.53 2,200.00 9.04 355.07 2,188.08 2,089.58 159.65 -13.78 2,633,735.47 323,469.24 0.00 160.25 2,300.00 9.04 355.07 2,286.84 2,188.34 175.31 -15.13 2,633,751.15 323,468.12 0.00 175.97 2,400.00 9.04 355.07 2,385.59 2,287.09 190.97 -16.49 2,633,766.82 323,467.01 0.00 191.68 2,500.00 9.04 355.07 2,484.35 2,385.85 206.63 -17.84 2,633,782.50 323,465.90 0.00 207.40 2,600.00 9.04 355.07 2,583.11 2,484.61 222.29 -19.19 2,633,798.18 323,464.79 0.00 223.12 2,619.40 9.04 355.07 2,602.27 2,503.77 225.33 -19.45 2,633,801.22 323,464.57 0.00 226.17 2,700.00 7.03 355.07 2,682.07 2,583.57 236.56 -20.42 2,633,812.46 323,463.78 2.50 237.44 2,800.00 4.53 355.07 2,781.56 2,683.06 246.59 -21.29 2,633,822.50 323,463.06 2.50 247.50 2,900.00 2.03 355.07 2,881.38 2,782.88 252.28 -21.78 2,633,828.20 323,462.66 2.50 253.22 2,981.13 0.00 0.00 2,962.50 2,864.00 253.71 -21.90 2,633,829.63 323,462.56 2.50 254.66 3,000.00 0.00 0.00 2,981.37 2,882.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,005.00 0.00 0.00 2,986.37 2,887.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Surface Casing: 1800' FNL, 122' FWL - Sec24,T13N,R10W - 9 5/8" 3,024.13 0.00 0.00 3,005.50 2,907.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Injection Zone in BRWD1 3,100.00 0.00 0.00 3,081.37 2,982.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,200.00 0.00 0.00 3,181.37 3,082.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,281.13 0.00 0.00 3,262.50 3,164.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Sterling A - BRU 212-24T (wp03) Sterling A 3,300.00 0.00 0.00 3,281.37 3,182.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3/18/2010 11:00: 26AM Page 3 COMPASS 2003.16 Build 69 Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Expl Project: Beluga River Site: Beluga River Well: Plan: BRU 212-24T Wellbore: BRU 212-24T Design: BRU 212-24T (wp05) Halliburton Standard Proposal Report Local Coordinate Reference: Well Plan: BRU 212-24T TVD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) MD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map `Depth Inclination Azimuth Depth TVDss +N/ -S +EI -W Northing Easting DLS Vert Section (ft) (I (I (ft) ft (ft) (ft) (ft) (ft) 3,282.87 3,400.00 0.00 0.00 3,381.37 3,282.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,465.13 0.00 0.00 3,446.50 3,348.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Sterling B 3,500.00 0.00 0.00 3,481.37 3,382.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,600.00 0.00 0.00 3,581.37 3,482.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,616.13 0.00 0.00 3,597.50 3,499.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Sterling C 3,700.00 0.00 0.00 3,681.37 3,582.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,783.13 0.00 0.00 3,764.50 3,666.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Beluga D 3,800.00 0.00 0.00 3,781.37 3,682.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3,900.00 0.00 0.00 3,881.37 3,782.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,000.00 0.00 0.00 3,981.37 3,882.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,044.13 0.00 0.00 4,025.50 3,927.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Beluga E 4,100.00 0.00 0.00 4,081.37 3,982.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,200.00 0.00 0.00 4,181.37 4,082.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,300.00 0.00 0.00 4,281.37 4,182.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,365.13 0.00 0.00 4,346.50 4,248.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Beluga F 4,400.00 0.00 0.00 4,381.37 4,282.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,500.00 0.00 0.00 4,481.37 4,382.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,600.00 0.00 0.00 4,581.37 4,482.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,700.00 0.00 0.00 4,681.37 4,582.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,798.13 0.00 0.00 4,779.50 4,681.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Beluga G 4,800.00 0.00 0.00 4,781.37 4,682.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 4,900.00 0.00 0.00 4,881.37 4,782.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,000.00 0.00 0.00 4,981.37 4,882.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,097.13 0.00 0.00 5,078.50 4,980.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Beluga H - BRU 212-24T (wp03) Beluga H 5,100.00 0.00 0.00 5,081.37 4,982.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,200.00 0.00 0.00 5,181.37 5,082.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,300.00 0.00 0.00 5,281.37 5,182.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,400.00 0.00 0.00 5,381.37 5,282.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,500.00 0.00 0.00 5,481.37 5,382.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,600.00 0.00 0.00 5,581.37 5,482.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,700.00 0.00 0.00 5,681.37 5,582.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,773.13 0.00 0.00 5,754.50 5,656.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Beluga I - BRU 212-24T (wp03) Beluga I 5,800.00 0.00 0.00 5,781.37 5,682.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 5,900.00 0.00 0.00 5,881.37 5,782.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 6,000.00 0.00 0.00 5,981.37 5,882.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 6,100.00 0.00 0.00 6,081.37 5,982.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 6,200.00 0.00 0.00 6,181.37 6,082.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 3/18/2010 11:00:26AM Page 4 COMPASS 2003.16 Build 69 s a z HALLIBURTON Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Expl Project: Beluga River Site: Beluga River Well: Plan: BRU 212-24T Wellbore: BRU 212-24T Design: BRU 212-24T(wp05) Halliburton Standard Proposal Report Local Coordinate Reference: Well Plan: BRU 212-24T TVD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) MD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Casing Hole Depth Depth Target Name (ft) Measured O (11) Vertical 2,986.37 9 5/8" 9-5/8 12-1/4 6,527.13 Map Map Dip Dir. TVD Depth Inclination Azimuth -Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) V) ` V) (ft) ft (ft) (ft) (ft) (ft) 6,182.87; 323,462.56 6,300.00 0.00 0.00 6,281.37 6,182.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 6,322.13 0.00 0.00 6,303.50 6,205.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 Beluga I base -21.90 2,633,829.63 323,462.56 plan hits target center 6,400.00 0.00 0.00 6,381.37 6,282.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 6,500.00 0.00 0.00 6,481.37 6,382.87 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 6,527.13 0.00 0.00 6,508.50 6,410.00 253.71 -21.90 2,633,829.63 323,462.56 0.00 254.66 TD - 7 - BRU 212-24T (wp03) TD BRU 212-24T (wp03) Beluga 1 0.00 0.00 5,754.50 253.71 Targets Measured Vertical Casing Hole Depth Depth Target Name (ft) (ft) ' Name O (11) 3,005.00 2,986.37 9 5/8" 9-5/8 12-1/4 6,527.13 hit/miss target Dip Angle Dip Dir. TVD +Nl-S +El -W Northing Easting Shape V) 0 (ft) (ft) (n) (ft) (ft) BRU 212-24T (wp03) Sterling A 0.00 0.00 3,262.50 253.71 -21.90 2,633,829.63 323,462.56 plan hits target center Rectangle (sides W250.00 H300.00 D0.00) BRU 212-24T (wp03) TD 0.00 0.00 6,508.50 253.71 -21.90 2,633,829.63 323,462.56 plan hits target center Rectangle (sides W250.00 H300.00 D0.00) BRU 212-24T (wp03) Beluga H 0.00 0.00 5,078.50 253.71 -21.90 2,633,829.63 323,462.56 plan hits target center Rectangle (sides W250.00 H300.00 D0.00) BRU 212-24T (wp03) Beluga 1 0.00 0.00 5,754.50 253.71 -21.90 2,633,829.63 323,462.56 plan hits target center Rectangle (sides W250.00 H300.00 D0.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ' Name O (11) 3,005.00 2,986.37 9 5/8" 9-5/8 12-1/4 6,527.13 6,508.50 7" 7 8-3/4 3/18/2010 11:00:26AM Page 5 COMPASS 2003.16 Build 69 ' ;G I N -1A L Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Expl Project: Beluga River Site: Beluga River Well: Plan: BRU 212-24T Wellbore: BRU 212-24T Design: BRU 212-24T (wp05) Halliburton Standard Proposal Report Local Coordinate Reference: Well Plan: BRU 212-24T TVD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) MD Reference: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Vertical Dip Depth Depth Depth SS Depth Dip Direction (ft) (ft) ft Name Llthology (6) 6,322.13 6,303.50 Beluga I base 0.00 3,024.13 3,005.50 Injection Zone in BRWD1 0.00 5,097.13 5,078.50 Beluga H 0.00 5,773.13 5,754.50 Beluga 1 0.00 4,044.13 4,025.50 Beluga E 0.00 4,798.13 4,779.50 Beluga G 0.00 3,465.13 3,446.50 Sterling B 0.00 3,783.13 3,764.50 Beluga D 0.00 3,281.13 3,262.50 Sterling A 0.00 3,616.13 3,597.50 Sterling C 0.00 4,365.13 4,346.50 Beluga F 0.00 6,527.13 6,508.50 TD 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (ft) (ft) (ft) (ft) Comment 18.51 18.51 0.00 0.00 SHL: 2054' FNL, 144' FWL - Sec24,T13N,R10W 3,005.00 2,986.37 253.71 -21.90 Surface Casing: 1800' FNL, 122' FWL - Sec24,T13N,R10W 3/18/2010 11:00: 26AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River Plan: BRU 212-24T BRU 212-24T BRU 212-24T (wp05) CD G--) Sperry Drilling :Services Clearance Summary r— Anticollision Report 11 February, 2010 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Beluga River - Plan: BRU 212-24T - BRU 212-24T - BRU 212-24T (wp05) Well Coordinates: 2,633,336.00 N, 1,463,508.00 E (61° 12' 14.39" N, 151° 00' 11.29" W) Datum Height: Plan: BRU 212-24T @ 98.50ft (Arctic Fox) Scan Range: 0.00 to 6,527.13 ft. Measured Depth. Scan Radius is 850.86 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM Date: 2010-02-11T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.50 3005.00 BRU 212-24T (wp05) (BRU 212-24T) MWD+SCC+SAG 3005.00 6.527.13 BRU 212-24T (wp05) (BRU 212-24T) MWD+SCC+SAG GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 270 BRU 212- 160 ConocoPhillips (Alaska) Inc. -Expl Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 90 Travelling Cylinder Azimuth (TFO+AZI) [°[ vs Centre to Centre Separation [200 ft/in[ Details: Plan: BRU 212-24T North American Datum 1983 Alaska Zone 4 Ground Level: 80.00 +NAS +E/ -W Northing Easting Latittude Longitude Slot 0.00 0.00 2633336.00 1463508.00 61° 12' 14.386 N 151" 0' 11.290 W From Colour To MD 18 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 2000 2000 3000 3000 4000 4000 5000 5000 5250 5250 5500 5500 5750 5750 6000 6000 6250 6250 6527 ANTI -COLLISION SETTINGS Interpolation Method: MD + Stations, interval: 50.00 Depth Range From: 18.50 To 6527.13 Centre Distance: 850.86 Reference: Plan: BRU 212-24T (wp05) (Plan: BRU 212-24TBRU 21 Travelling Cylinder Azimuth (TFO+AZI) (°I vs Centre to Centre Separation 150 ft/in) SECTION DETAILS Sec MD Inc Aa TVD +N/ -S +E/ -W DLeg TFace VSec Target 1 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 0.0D 2 1000.00 No 0.00 1000.00 0.00 0.00 0.00 0.00 0.0D 3 1361.73 9.04 355.07 1360.23 28.38 -2.45 2.50 355.07 28.49 4 2619.41 9.04 355.07 2602.27 225.33 -19.45 0.00 0.00 226.17 5 2981.13 0.00 0.00 2962.50 253.71 -21.90 2.50 180.00 254.65 6 3281.13 0.00 0.00 3262.50 253.71-21.90 0.00 0.00 254.65 BRU 212-24T (wp03) Sterling A 7 5097.13 0.00 0.00 5078.50 253.71 -21.90 0.00 0.00 254.65 BRU 212-24T (wp03) Beluga H 8 5773.13 0.00 0.00 5754.50 253.71 -21.90 0.00 0.00 254.65 BRU 212-24T (wp03) Beluga 1 9 6527.13 0.00 0.00 6508.50 253.71 -21.90 0.00 0.00 254.65 BRU 212-24T (wp03) TO ConocoPhillips (Alaska) Inc. -Expl 11 February. 2010 - 7:58 Page 2 of 4 COMPASS HALLlBURT _ N Beluga River Anticollision Report for Plan: BRU 212-24T - BRU 212-24T (wp05) Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Beluga River - Plan: BRU 212-24T - BRU 212-24T - BRU 212-24T (wp05) Scan Range: 0.00 to 6,527.13 ft. Measured Depth. Scan Radius is 850.86 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Beluga River BRU 212-24 - BRU 212-24 - BRU 212-24 1,529.26 91.81 1,529.26 67.61 1,525.00 3.794 Centre Distance Pass - Major Risk BRU 212-24 - BRU 212-24 - BRU 212-24 6,393.94 195.62 6,393.94 38.42 6,375.00 1.244 Clearance Factor Pass - Major Risk DBRU BRU 232-23 - BRU 232-23 - BRU 232-23 276.991 03.84 276.99 90.37 275.00 7.706 Centre Distance Pass - Major Risk 232-23 - BRU 232-23 - BRU 232-23 301.99 103.87 301.99 90.10 300.00 7.544 Clearance Factor Pass - Major Risk /V SurveV tool program tea.. From To Survey/Plan Survey Tool (ft) (ft) 18.50 3,005.00 BRU 212-24T (wp05) MWD+SCC+SAG 3,005.00 6,527.13 BRU 212-24T (wp05) MWD+SCC+SAG Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 11 February. 2010 - 7:58 Page 2 of 4 COMPASS ,or CmaiP ,hillips Akska ConocoPhillips Alaska, Inc. I Cook Inlet Beluga River Unit �::D Plan: BRU 212-24T (wp05) 1/4 Mile Pool Scan ' Sperry Drilling Services r March 18, 2010 HAL.LIBURTON Sperry Drilling Closest in POOL Closest Approach: Reference Well: BRU 212-24T (w 05) Plan Offset Well: BRU 212-24 3-D ctrctr Horizontal Subsea Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. Distance Difference Depth Incl. Angle TRUE Azi. TVD N(+)/S(-) E(+)AN - 355.07°) Comments Depth Incl. Angle TRUE Azi. TVD N(+)/S(-) E(+)/W(_) (355.07°) Comments P -Min Distance- -POOL Min Distance 195 ) in POOL (195.5 ft) in POOL (3164 - 6410.01 (3164 - 6410.01 TVDss) to BRU 212- TVDss) to BRU 212- 24T (wp05) Plan 24 (3164 - 6281.8 (3164 - 6281.8 195.5 -195.49 1.7937306 6397.13 0.001 0.001 6280.01 2633589.95 1463490.02 254.59 TVDss) 6380.001 0.751 0.001 6281.80 2633410.55 1463412.361 81.11 TVDss) Closest Approach: Reference Well: BRU 212-24T w 05 Plan Offset Well: BRU 232-23 3-D ctrctr Horizontal Subsea Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. Distance Difference Depth Incl. An le TRUE Azi. TVD N + /S - E + AN _ (355.07°) Comments Depth Incl. An le TRUE Azi. TVD N + /S - E + AN - 355.07° Comments POOL Min Distance POOL Min Distance (2237.36 ft) in POOL (2237.36 ft) in POOL (3164 - 6410.01 (3164 - 6410.01 TVDss) to BRU 212- TVDss) to BRU 232- 24T (wp05) Plan 23 (3162 - 6571.91 (3162 - 6571.91 2237.36 -2137-29 -17,11 82 3281.13 0.00 0.00 3164.01 2633589.95 1463490.02 254.59 TVDss) 4103.49 30.35 269.61 3146.44 2633372.56 1461263.32 195.00 TVDss) POOL Summary Templatel 3/17/2010 4:43 PM 3' CHOK 3 1/8' i BOP STACK ELEVATION 12' 150 PSI HPDR. OPERATED KNIFE GATE VALVE 12' FLG'D VENT LINE SURFACE DIVERTER CONFIGURATION 11 •. 5000 PSI. HroRIL ANNULAR BOP STUDDED TDP/FLANGED BOTTOM RANGE BOTTOM/FLANGE TOP 8X 160 11•, 5000 PSI SHAFFER LXT DOUBLE PIPE RAY STUOD�O BOTTOM FLANGE TOP BX 160 3 1/8 5000 HCR VALVE 2' KILL UNE 3 1/8' 5000 P51 GATE VALVE FLANGE BOTTOM/STUDDED TOP BX 160 I1', 5000 PSI SHAFFER LXT PIPE RAM STUDDED BOTTOM/FLANGE TOP BX 160 ADAPTER SPOOL FLANGE/RANGE 21 1/1. 2000 PSI. MSP HYDWL BOP/DIVERTER STUDDED TOP/FLANGEO BOTTOM DIVERTER SPOOL ACCUMULATOR: OILCO, 6 STATION TRIPLEX PUMP: 2/575 VAC, 25 HP AIR PUMP: 2/40 : 1, 8GPM, 3,000 PSI FLUID RESERVOIR: 450 GALLON ACCUMULATOR MANIFOLD 12 BOTTLES, 15 GALLONS EACH NITROGEN BACKUP BOTTLES 6 BOTTLES. 337 CU. FT. oxrall 10 MIT - VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 ANNULAR 0 0 0 REMOTE PANEL IN DOGHOUSE AND UTILITY MODULE BOP SYSTEM AND CONTROL DIVERTER M70yolml ARCTIC FOX 1ea. 3-1/8' 5K Manual & Hydraulic Valve Programed to open when Annual or Rams are closed 11" 5K Shaffer Single Gate Lower Pipe Rams BOP STACK lea. 3-1/8" Check Valve lea. 2" Kill Line DIVERTER LINE RUN 100'+ BYOND SUBSTRUCTURE. DIVERTER LINE - 8 @ 21' EA. TOTAL DIVERTER LINE 168' voyo\ DRILLING IAMMM LTOL The Infonnatlon—telned In this drawing Is the joint Property of Doyon AKITA JV. Any reproduction In whole or part wllhout the express wdnen .....nt of Doyon AKITA JV Is prohibited. r 422/09 NTS r.. Dol 20indwo h,, Anti, Fox - 6e1uga 21}' 2000 psi Diverter Assembly General Layout 1j)OPM0 AKITA JV T4 FSE PITS CD :Z7 — TO FlAFZE PITS MATERIAL LIST Item Description A 3-1/16" 10M Remote Operated Choke B 3-1/8" 5M Adjustable Choke 1 2-1/16" 5M Manual Gate Valve 2-14 3-1/8" 5M Manual Gate Valve ciLEDGEND White Handle Valves Normally Open Red Handle Valves Normally Closed IcROM SO STACK ■ OSPNERIG T4 AT rjEaAS SER T! , UNDERFLOW FROM SHAKERS TO FLOW NIPPLE TO WEIR BOX MUD GUN 1001 Barrels NET TOTAL TANK CAPACITY = 1145 Barrels GROS: 6" 8" 8" 8" 8" 172 Barrels NET 214 Barrels NET 70 Barrels NET TO MUD PUMPS LAYERS 'RESSURE SYS. ION OUTLINE GH IDOYON DRILLING ANWA 11n sty h - urn:, The Information contalned In thls drawing Is the sole property of Doyon AK TA JV. Any reproductlon In whole or part without the express wdtlen consent of Doyon AKITA JV. Is prohibited. 3(7/09 I NTS r DDI F Mud Bchemati Beluga Project Mud Tank - Simplified Schematic 144--l- (43.92mj TWO TANK MUD SYSTEM THREE SHAKERS, TWO MIX -= PUMPS, TWO MIX HOPPERS, r DETROIT 60 SERIES 180 gal 6 STATION I FOUR AGITATORS, DEGASSER, 400 kW 600 V GENS ACCUMULATOR t (T 10 CONE MUD CLEANER jTJ-C, � r D WATER TANK ` - in 490 BBLS i I } .. - .. l 4 N 0 to DOGHOUSE wt SLIDE OUT LUNCH ROOM AND J 1 iii 111 t\ TONG ROOM ON END 1 FUELTANK 6500 gal. FUEL & WATER m —PUMP ROOM HOT WELL TANK 60 Bartels IluutJ — TWO 100 HP BOILERS BOP HANDLING i ®® M WORK BENCH, AIR COMPRESSORS TROLLEY AND PARTS STORAGE I CREW CHANGE ROOM THREE GARDNER DENVER PZ -8 RIGMASTER P-750 MUD PUMPS POWERED ONE PIECE SUB W1 BY 3412 E CAT MOTORS, TELESCOPIC DOUBLE MAST AND S 000H NOV CASING TEST PUMP `AIR HEATER SKATE TYPE POWER CATWALK WITH TWO ENCLOSED CASING SHEDS AND ONE ENCLOSED PIPE TUB. PROPOSED CENTRIFUGE HOUSE ON TOP OF CUTTINGS PROCESSOR CUTTINGS PROCESSOR ,ioilk0YON DRILLING ANOMrA The information contained In this drawing Is the joint property of Doyon AKITA JV. Anyreproduction n whole or part without the exproas wrinen conga nt of Doyon AKITA JV Ie prohibited. r 3/rlpg NTS DDI I AF GA r_ 9eluga Praect General Arrangement CD C),:-,* C) TRANSMITTAL LETTER CHECKLIST WELL NAME / r PTD# Development Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: L�',�/,� L � � POOL:Lzlbb, � Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to f pliance with 20 AAC EXCEP'T'ION 25.055. Approval to perforate d rodu , / in'ect is contingent 7 upon issuanc f a con atiy . order p _roving a spacing exception. , cz)u assumes the liability of any protest to the spacin exception thlit may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through tar et zones. Non -Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/ 11/2008 WELL PERMIT CHECKLIST Field & Pool BELUGA RIVER, UNDEFINED GAS - 92500 Well Name: BELUGA RIV UNIT 212-24T Program DEV Well bore seg ❑ PTD#:2100500 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV/1-GAS GeoArea 820 Unit 50220 On/Off Shore On Annular Disposal ❑ Administration 1 PErmitfee_attached ---------------------------------------------- NA---------------------------------------------------------------------------- 2 Lease number appropriate- ---------------------------------------- Yes-------Entier-well in -ADL 21t28------------------------------------------------ 3 Unique well name on-dnumber------------------------------- -------- Yes WellJocatedinadefirnedp-ool---------------------------------------- Yes ------- BELUGA RIVER, UNDEFINEDGAS_-92500 ------------------------- ----------------- 5 Well Jocated proper distance from drUling unit -boundary - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ Conforms with -20 AAC 25.055(9)(2) _ - _ - _ -------------------------- -------------- 6 WellJocated proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ - - _ _ $PACING EXCEPTION REQULRED: hearing vacated March- 22, 2010; draft order -at legal for review. ------- 7 7 Sufficient acreage eyeiJable Actrilling unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - - _ _ $PACING EXCEPTION REQULRED: hearing vacated_ March -22, 2010; draft order -at Legal for review. _SFp- - _ _ _ 8 If deviated, is wellbore plat included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ ---------------- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operstoronlyaffectedparty-------------------- ----- ------ ---- - -- - -- Yes --------------------------------------------------------------------------- 10 Operator has appropriate bond in_force--------------------------------- Yes--------------------------------------------------------------------------- 11 Permitcanbeissuectwithoutconseryationorder-------- --------------- - - - - -- No------------------ ---------------------------------------------------------- Appr Date 12 Permitcanbeissuedwithoutadministrativeapproval--------------------------- Yes----.-----------------------.._....--------------------_-----.------------- OFD 4/21/2010 13 Can permit beapprovedbeforel5-day-waft--------------------------------- Yes ----------------------------------------- .--------------------------------- 14 WellJocatedwithin -area and strata authorized_byinjection -Order # (put 10#in-comments).(For____NA ---------------------------------------- ____________________________________ 15 AMwelts -within 1/4mile area, ofreview identifled- (For servicewellonly) ------------------NA--------.-----------------------.--.----.----------------------------------- 16 Pre -produced -injector:. duration of pre-pro-dWionless-than 3months(For service well- only). ---- NA_ ___________________________________________________________________________ 17 _Konconven.-gas conforms toAS31,05,030(L1_A),0,ZA-Dl----------------------- NA---------------------------------------------------------------------- 18 Conductor string proyidad------------------------------------ - - - - -- Yes - - - - - -- Driven to 109, ------------------------------------------------------------- Engineering 19 Surface casing protects all known U$DWs-------------------------------- Yes --------------------_-------_-----_--------------------------.-------_.---- 20 CMT-vol_adequateto-circulate onconductor_&surfcsg_________________________ Yes -,-----Adequate excess cement, -____--------_--_-._-----------___------------------- 21 CMT-voladequatetotie-Jrt long stringtosurfcsg--------- ---- ------ ---- - -- - -- Yes--------------------------------------------------------------------------- 22 CMT_willeoyerallknownproductivehorizons---- ------ ---- ---- ------ -- - - - - Yes ----------------------------------------------------------- -------------- 23 Casing designs -adequate for 0. T, B_& permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Adequate safety -factors. - _ _ _ _ _ _ - - - - _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ - _ _ _ 24 Adequate tankageorreservepit------- --- ----- ---------- ---- --- - - - - -- Yes -------Doyon Arctic- Fox .---------------------------------------------------------- 25 Ifa_re-drill,has al0-403for-abandonment been approyed------- --------- --- - - - -- NA -------- New well -------------------------------------------------------------- 26 Adequatewellboreseparation_Proposed--------------- ------------- - - - - -- No -------- Spacing exceptiortrequlred.-------.-----------------.-----------------------_-- 27 Ifdiverterrequired. does_ It- meetregulations--------------------------------No--_----- Vent line variance required -------...---_--------------------------.------------ Appr Date 28 Drilling. fluLd_program_schematir.&equiplist-adequate --------------------------Yes.----._ Max MW10.0ppg.---------------.-.---------------------------.-.--------- WGA 4/22/2010 29 BOPEs,dotheymeetregulation--------------- - - - - ------------ - - - - -- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- ------------------------------------------ 30 BOPEpress rating_appropriate*,test to_(put psig in comments) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . - . _ . MASP 2186 psi;-csg test -4-40Q psi; SOPE test -to 4500 psi ._ _ - - _ . _ _ _ _ _ _ _ _ _ _ - . - _ - . _ _ _ _ _ _ . _ - - - _ - 31 Choke manifoldcompliesw/API RP-53(May 84)-----------------------------Yes-------5Kpsl rated. -.----------------------------------------------------------- 32 Work will occur_withoutoperatlon-shutdown-------------------------------- Yes ----------------------------.-_..-.-------------------------.---.___------- 33 Is presence -of H2$ gas probable ---------------------------------------N-o--------Not anH2Sarea .---------------------------------------------------------- 34 Mechanical conditiortofwelts withlnAORverifed(ForseryiceweJlonly) -----------------NA------------------------------------------_--------------------------------- 35 Permit can be. issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ -- ate ~'� �— --- Production Interval will be mudlogged.- Sensors will be employed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ - _ _ _ . Geology 36 Datapresented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Zi 'fir' Yes _ - _ _ _ _ . Y Offset drilling data indicate 9,8_ppg gradient; will -be drilled using_10.0ppg mud. - - - - - - - - - - - _ - - - - - - - - - - - Appr Date 37 Seismic analysis of shallow gas zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ - _ _ Offset well BRU 212-24 was_driUed nearby, and one other well -has been drilled with[n-1-mile.- - - - - - - - - - - - - - - - SFD 4/21/2010 38 Seabed condition_survey-(ifoff-shore)------------- -------------------NA---------- -- ----------------------------------------------- 39 Contaetnamelphone-forweekly-progress reportsjexplwatoryonly]------------------ --NA---------------------------------------------------------------------------- Geologic Date Engineering Pu Date Public hearing notice published 3-3-2010; hearing vacated 3-22-2010. Draft order in legal review. SFD 4/21/2010 Date: Commissioner: Commissioner: om loner _-, �- zZ to 0- Z--1"16 Well History File • 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. Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jul 19 09:57:26 2010 Reel Header Service name.............LISTPE Date .....................10/07/19 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Tape Header Service name.............LISTPE Date .....................10/07/19 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. Physical EOF Scientific Technical Services. Scientific Technical Services Comment Record OPEN HOLE CASING TAPE HEADER BIT SIZE Beluga River Field DEPTH (FT) IST STRING MWD/MAD LOGS 20.000 110.0 2ND STRING 8.750 9_625 WELL NAME: 3RD STRING PRODUCTION STRING BRU 212-24T API NUMBER: # 502832013600 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 19-JUL-10 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: -MW-0007262432 -MW-0007262432 -MW-0007262432 LOGGING ENGINEER: B. SCHULZE B. SCHULZE B. SCHULZE OPERATOR WITNESS: D.LUTRICK L. HILL L. HILL SURFACE LOCATION SECTION: 24 TOWNSHIP: 13N RANGE: low FNL: 2054 FSL: FEL: FWL: 144 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 97.17 GROUND LEVEL: 78.67 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) IST STRING 12.250 20.000 110.0 2ND STRING 8.750 9_625 2851.0 3RD STRING PRODUCTION STRING C� q # 1 0, 6 REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER -MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR-P4), DRILLSTRING DYNAMICS SENSOR (DDSr), AND EM GMS TELEMETRY. MWD RUNS 2,3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO -DENSITY (ALD), BI -MODAL ACOUSTIC TOOL (BAT), AND PRESSURE WHILE DRILLING (PWD). 4. DEPTH SHIFTING WAS WAIVED PER E-MAIL FROM WAYNE CAMPAIGN (CPAI) TO BUSTER BRYANT (SD), DATED 14 JULY 2010. THE SPERRY DRILLING LWD LOGS PROVIDE PRIMARY DEPTH CONTROL. 5. MWD RUNS 1-3 REPRESENT WELL BRU 212-24T WITH API #50-283-20136-00. THIS WELL REACHED A TOTAL DEPTH OF 6565'MD/6545'TVD. SROP = RATE OF PENETRATION WHILE DRILLING SGRC = DUAL GAMMA RAY COMBINED SEXP = EWR PHASE -4 9" 2 MHZ PHASE SHIFT RESISTIVITY SESP = EWR PHASE -4 15" 2 MHZ PHASE SHIFT RESISTIVITY SEMP = EWR PHASE -4 27" 2 MHZ PHASE SHIFT RESISTIVITY SEDP = EWR PHASE -4 39" 1 MHZ PHASE SHIFT RESISTIVITY SFXE = FORMATION EXPOSURE TIME EWR-PHASE-4 TNPS = THERMAL NEUTRON POROSITY -SS MATRIX CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = BULK DENSITY COMPENSATED (RAPID SAMPLE)- LOW COUNT BIN SCO2 = DELTA -RHO (RAPID SAMPLE)- LOW COUNT BIN SNP2 = NEAR DETECTOR PE FACTOR (RAPID SAMPLE)- LOW COUNT BIN DTCP = COMPRESSIONAL SLOWNESS DTSP = SHEAR SLOWNESS VP/VS = RATIO OF COMPRESSIONAL TO SHEAR VELOCITY ALRPM = ALD RPM REFLECTING BIT -TO -SENSOR DISTANCE PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED, 8.75" BIT MUD WEIGHT: 9.6 - 9.7 PPG WHOLE MUD CHLORIDES: 35000-48000 PPM FORMATION WATER SALINITY 6250 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. s File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record DEPTH 4 FILE HEADER 68-, 0 1 FILE NUMBER: 1 4 EDITED MERGED MWD 68 4 2 Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 8 3 DTC MWD UPSF PBU TOOL FILE SUMMARY BIT RUN NO MERGE TOP PBU TOOL CODE START DEPTH STOP DEPTH RPD 159.0 6504.5 RPX 159.0 6504.5 FET 159.0 6504.5 RPS 159.0 6504.5 RPM 159.0 6504.5 GR 167.0 6512.5 ROP 222.5 6565.0 NPHI 2749.5 6454.5 NCNT 2749.5 6454.5 FCNT 2749.5 6454.5 RHOB 2762.5 6468.5 DRHO 2762.5 6468.5 PEF 2762.5 6468.5 DTC 2850.5 6412.5 DTSH 2851.0 6407.5 SCRA 2851.0 6407.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 4 1 68-, 0 1 FCNT MWD C230 4 1 68 4 2 NCNT MWD CP30 4 MERGED DATA SOURCE 8 3 DTC MWD UPSF PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 159.0 2861.0 MWD 2 2861.0 3883.0 MWB 3 3883.0 6565.0 REMARKS: MERGED MAIN PASS., Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction ............... .Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68-, 0 1 FCNT MWD C230 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 DTC MWD UPSF 4 1 68 12 4 DTSH MWD UPSF 4 1 68 16 5 RHOB MWD G/CC 4 1 68 20 6 DRHO MWD G/CC 4 1 68 24 7 RPD MWD OHMM 4 1 68 28 8 RPM MWD OHMM 4 1 68 32 9 RPS MWD OHMM 4 1 68 36 10 RPX MWD OHMM 4 1 68 40 11 FET MWD HR 4 1 68 44 12 GR MWD API 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 ROP MWD FPH 4 1 68 56 15 NPHI MWD PU 4 1 68 60 16 SCRA MWD 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 159 6565 3362 12813 159 6565 - FCNT MWD CP30 474.17 2464.43 1018.71 7411 2749.5 6454.5 NCNT MWD CP30 107731 184556 138787 7411 2749.5 6454.5 DTC MWD UPSF 66.3231 185.615 126.366 7083 2850.5 6412.5 DTSH MWD UPSF 132.963 436.825 255.254 7104 2851 6407.5 RHOB MWD G/CC 0.651 3.096 2.21187 7413 2762.5 6468.5 DRHO MWD G/CC -4.097 0.389 0.0926998 7413 2762.5 6468.5 RPD MWD OHMM 1.44 2000 87.5975 12692 159 6504.5 RPM MWD OHMM 0.28 1999.27 66.8042 12692 159 6504.5 - RPS MWD OHMM 0.25 1878.06 46.6913 12692 159 6504.5 RPX MWD OHMM 0.19 1684.39 28.1298 12692 159 6504.5 FET MWD HR 0.42 150.76 3.43379 12692 159 6504.5 GR MWD API 15.74 117.72 65.0604 12692 167 6512.5 PEF MWD B/E 0.4 13.8 3.18721 7413 2762.5 6468.5 ROP MWD FPH 0.08 551.47 114.732 12686 222.5 6565 NPHI MWD PU 18.63 .109.14 38.7756 7411 2749.5 6454.5 SCRA MWD 1.3686 3.2056 2.02501 7068 2851 6407.5 First Reading For Entire File.......... 159 Last Reading For Entire File ........... 6565 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SFXE 159.0 SEDP 159.0 SEXP 159.0 SESP 159.0 SEMP 159.0 SGRC 167.0 SROP 222.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 2798.5 2798.5 2798.5 2798.5 2798.5 2807.0 2861.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): ---RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0,,, Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined 16 -JUN -10 Insite 88.20 Memory 2861.0 222.0 2861.0 .0 10.1 TOOL NUMBER 132477 129431 12.250 110.0 Native/Spud Mud 9.60 205.0 8.0 350 7.4 5.000 55.0 2.570 113.3 4.500 55.0 4.500 55.0 Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HR 4 1 68 20 6 GR MWD010 API 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 159 2861 1510 5405 159 2861 RPD MWD010 OHMM 7.53 2000 167.57 5280 159 2798.5 RPM MWD010 OHMM 7.08 1999.27 139.424 5280 159 2798.5 RPS MWD010 OHMM 6.69 704.73 88.4254 5280 159 2798.5 RPX MWD010 OHMM 6.01 175.06 49.9171 5280 159 2798.5 FET MWD010 HR 0.42 14.03 1.5592 5280 159 2798.5 GR MWD010 API 21.29 81.71 48.0112 5281 167 2807 ROP MWD010 FPH 7.24 551.47 141.48.4 5278 222.5 2861 First Reading For Entire File.......... 159 Last Reading For Entire File ........... 2861 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physi-eal EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTNA 2749.5 3771.0 TNPS 2749.5 3771.0 CTFA 2749.5 3771.0 SBD2 2762.5 3784.5 SNP2 2762.5 3784.5 SCO2 2762.5 3784.5 SESP 2799.0 3822.5 SEDP 2799.0 3822.5 SEMP 2799.0 3822.5 SEXP 2799.0 3822.5 SFXE 2799.0 3822.5 SGRC 2807.5 3830.5 DTCP 2850.5 3727.5 DTSP 2851.0 3727.5 VPVS 2851.0 3727.5 SROP 2861.5 3883.0 LOG HEADER DATA DATE LOGGED: 23 -JUN -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): ' 3883.0 TOP LOG INTERVAL (FT): 2861.0 BOTTOM LOG INTERVAL (FT): 3883.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .5 MAXIMUM ANGLE: 3.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 275518 EWR4 ELECTROMAG. RESIS. 4 228269 CTN COMP THERMAL NEUTRON 11292220 BAT Bi -modal Acoustic 190320 ALD Azimuthal Litho -Dens 241899 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2851.0 BOREHOLE CONDITIONS MUD TYPE: Polymer ---MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 49.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 48000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .300 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .230 96.1 MUD FILTRATE AT MT: .150 75.0 MUD CAKE AT MT: .350 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CP30 4 1 68 4 2 NCNT MWD020 CP30 4 1 68 8 3 DTC MWD020 USPF 4 1 68 12 4 DTSH MWD020 USPF 4 1 68 16 5 RHOB MWD020 G/CC 4 1 68 20 6 DRHO MWD020 G/CC 4 1 68 24 7 RPD MWD020 OHMM 4 1 68 28 8 RPM MWD020 OHMM 4 1 68 32 9 RPS MWD020 OHMM 4 1 68 36 10 RPX MWD020 OHMM 4 1 68 40 11 FET MWD020 HR 4 1 68 44 12 GR MWD020 API 4 1 68 48 13 PEF MWD020 B/E 4 1 68 52 14 ROP MWD020 FPH 4 1 68 56 15 NPHI MWD020 PU 4 1 68 60 16 SCRA MWD020 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2749.5 3883 3316.25 2268 2749.5 3883 FCNT MWD020 CP30 474.17 1911.34 873.131 2044 2749.5 3771 NCNT MWD020 CP30 107731 159681 132158 2044 2749.5 3771 DTC MWD020 USPF 118.134 185.615 148.691 1755 2850.5 3727.5 DTSH MWD020 USPF 207.295 436.825 303.706 1754 2851 3727.5 RHOB MWD020 G/CC 0.651 2.823 2.03292 2045 2762.5 3784.5 DRHO MWD020 G/CC -4.097 0.294 -0.0214866 2045 2762.5 3784.5 RPD MWD020 OHMM 3.35 2000 79.8505 2048 2799 3822.5 RPM MWD020 OHMM 0.28 1878.15 23.8935 2048 2799 3822.5 RPS MWD020 OHMM 0.25 1878.06 26.0401 2048 2799 3822.5 RPX MWD020 OHMM 0.19 1550.39 16.5295 2048 2799 3822.5 FET--MWD020 HR 0.42 150.76 10.5821 2048 2799 3822.5 GR MWD020 API 15.99 100.31 72.3542 2047 2807.5 3830.5 PEF MWD020 B/E 0.53 13.8 3.13655 2045 2762.5 3784.5 ROP MWD020 FPH 0.08 316.58 109.291 2044 2861.5 3883 NPHI MWD020 PU 18.63 109.14 42.3584 2044 2749.5 3771 SCRA MWD020 1.4155 3.1218 2.05228 1754 2851 3727.5 First Reading For Entire File.......... 2749 Last Reading For Entire File ........... 3883 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004.�- Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 SOFTWARE RAW MWD SURFACE SOFTWARE VERSION: Insite Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 6565.0 DEPTH INCREMENT: .5000 BOTTOM LOG INTERVAL (FT): 6565.0 BIT ROTATING SPEED (RPM): FILE SUMMARY MINIMUM ANGLE: VENDOR TOOL CODE START DEPTH STOP DEPTH VPVS 3731.0 6407.5 DTSP 3731.0 6407.5 DTCP 3731.0 6412.5 TNPS 3771.5 6454.5 CTNA 3771.5 6454.5 CTFA 3771.5 6454.5 SBD2 3785.0 6468.5 SNP2 3785.0 6468.5 SCO2 3785.0 6468.5 SEMP 3823.0 6504.5 SEDP 3823.0 6504.5 SESP 3823.0 6504.5 SFXE 3823.0 6504.5 SEXP 3823.0 6504.5 SGRC 3831.0 6512.5 SROP 3883.5 6565.0 LOG HEADER DATA DATE LOGGED: 28 -JUN -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME): Memory TB -DRILLER (FT): 6565.0 TOP LOG INTERVAL (FT): 3883.0 BOTTOM LOG INTERVAL (FT): 6565.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: .9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 279516 EWR4 ELECTROMAG. RESIS. 4 230203 CTN COMP THERMAL NEUTRON 11328345 BAT Bi -modal Acoustic 190320 ALD Azimuthal Litho -Dens 126973 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): ,• 2851.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 55.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .125 105.0 MUD AT MAX CIRCULATING TERMPERATURE: .090 141.4 MUD FILTRATE AT MT: .120 105.0 MUD CAKE AT MT: .240 105.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 DTC MWD030 USPF 4 1 68 12 4 DTSH MWD030 USPF 4 1 68 16 5 RHOB MWD030 G/CC 4 1 68 20 6 DRHO MWD030 G/CC 4 1 68 24 7 RPD MWD030 OHMM 4 1 68 28 8 RPM MWD030 OHMM 4 1 68 32 9 RPS MWD030 OHMM 4 1 68 36 10 RPX _MWD030 OHMM 4 1 68 40 11 FET MWD030 HR 4 1 68 44 12 GR MWD030 API 4 1 68 48 13 PEF MWD030 B/E 4 1 68 52 14 ROP MWD030 FPH 4 1 68 56 15 NPHI MWD030 PU 4 1 68 60 16 SCRA MWD030 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3731 6565 5148 5669 3731 6565 FCNT MWD030 CP30 544.51 2464.43 1074.16 5367 3771.5 6454.5 NCNT MWD030 CP30 115484 184556 141312 5367 3771.5 6454.5 DTC MWD030 USPF 66.3231 177.647 119.012 5328 3731 6412.5 DTSH MWD030 USPF 132.963 399.143 239.37 5350 3731 6407.5 RHOB MWD030 G/CC 1.265 3.096 2.28005 5368 3785 6468.5 DRHO MWD030 G/CC -0.098 0.389 0.1362 5368 3785 6468.5 RPD MWD030 OHMM 1.44 669.7; 11.8352 5364 3823 6504.5 RPM MWD030 OHMM 1.28 998.37 11.7053 5364 3823 6504.5 RPS MWD030 OHMM 1.26 1564.99 13.4956 5364 3823 6504.5 RPX MWD030 OHMM 1.17 1684.39 11.1126 5364 3823 6504.5 FET MWD030 HR 0.54 36.22 2.54978 5364 3823 6504.5 GR MWD030 API 15.74 117.72 79.0623 5364 3831 6512.5 PEF MWD030 B/E 0.4 9.47 3.20651 5368 3785 6468.5 ROP MWD030 FPH 0.13 347.46 90.4826 5364 3883.5 6565 NPHI MWD030 PU 18.97 84.68 37.4111 5367 3771.5 6454.5 SCRA MWD030 1.3686 3.2056 2.01601 5314 3731 6407.5 First Reading For Entire File.......... 3731 Last Reading For Entire File ........... 6565 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 10/07/19 Maximum Physical Record..65535 File Type...... ........LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Date .....................10/07/19 Origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS,Writing Library. Reel Trailer Service name.............LISTPE Date .....................10/07/19 Origin........... ......STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical Services Scientific Technical Services HALLIBURTON Sperry Drilling CP -1'0 -dam END OF WELL REPORT BRU 212-24T ConocoPhillips Alaska, Inc. Surface Data Logging Services ConocoPhillips Alaska, Inc. HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Formation Evaluation Logs Drilling Evaluation Logs Gas Ratio Logs LAS Files Halliburton Log Viewer EMF Log Viewer EOW Report PDF Version ADI Backup ComcoPhillips Alaska, Inc. 1 1 1 1 1 1 HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION Company: Conoco Phillips Alaska, Inc. Rig: Arctic Fox Well: BRU 212-24T Field: Beluga River Unit Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-283-20136-00-00 Sperry Job Number: AK -AM -7262432 Job Start Date: 17 Jun 2010 Spud Date: 13 -Jun -2010 TD Date: 28 -Jun -2010 Total Depth: 6565' MD, 6548' SSTVD Rig Release Date: 30 June 2010 North Reference: True Declination: 18.5700 Dip Angle: 74.0820 Total Field Strength: 55737 nT Date Of Magnetic Data: 20 Jun 2010 Wellhead Coordinates N: North 700 12' 14.38" Wellhead Coordinates W: West 151 ° 0' 11.27" Drill Floor Elevation 97.17 Ground Elevation: 78.67' Permanent Datum: Mean Sea Level SDL Engineers: Mark Lindloff, Ryan Massey SDL Sample Catchers: Chris Woolley, Leonard Grove, Dave McKechnie Company Geologist: Rick Levinson Company Representatives: Donnie Lutrick, Elmo Cecchetti, Larry Hill SSDS Unit Number: 115 ConocoMillip5 Alaska. Inc. F �__, HALLIBURTON I Sperry Drilling DAILY SUMMARY ' Begin BRU 212-24T ' 06/17/2010 — 06/20/2010 SDL Engineers arrive in Beluga to rig up mudlogging unit. 06/21/2010 Pick up BHA # 2 and started running in hole. 06/22/2010 Attempted to pressure test casing to 3000 psi when the pressure test from their cement unit. Drilled float plug and cement plug with no issues. Drilled to 2877' MD and noticed an increase in flow out. Found that the mud weight had dropped from 9.6 ppg to 9.1 ppg and was ' contaminated. Gas increased to 11 units before falling out. Displaced to KlaShield then drilled to 2881'MD. Performed leak off test to 16 ppg. Begin drilling production hole. Background gas was averaging 9 units after drilling cement. Background gas increased to 25 units during the last 30' of drilling. Drilling ahead at time of report. 06/23/2010 ' Drilled from 2945' MD to 3883' MD. ROP was variable between 40 and 280 ft/hr sustained throughout the past 24 hours of drilling. In the Sterling A, ROPs averaged 125 ft/hr with max ROP at 210 ft/hr. Drilling gas averaged 231 units and max gas was 715 units. Drilling in Sterling B, average drilling ROP was 114 ft/hr with a max ROP of 194 ft/hr. Gas while drilling averaging 214 units, max gas was 702 units. The Sterling C formation drilled with an average ROP of 121 ft/hr and sustained max ROP of 174 ft/hr. Average drilling gas was 343 units and max gas was 1129 units. No connection gas was seen. Backreamed 4 stands out of hole and ' pulled back to the shoe for wiper trip. Repaired draw works starter and cut & slip drill line. Ran back into hole to drill ahead. General Descriptions: For the interval drilled in the previous 24 hours; the Injection Zone had sequences of Claystones, Siltstones, and Sands. The upper Sterling A formation was predominately unconsolidated Sands, varying from Claystone to Siltstone with intermittent Sand and Coal stringers interbedded throughout. The Sterling B was a Clayey Siltstone with minor ' Sandstone interval at its base. The Sterling C was Silty Claystone with several quality Sandstone shows. Also interbedded with Coal stringers throughout section. 1 1 1 1 1 ■ Claystone: light gray, light brown to buff, light blue in part, soft to firm, sub platy, large blocky pieces, no swelling, trace calcareous, carbonaceous in part. ■ Siltstone: gray to light gray, light brown, light blue in part, fine low sand grading to silt, sub spherical to moderately sorted, argillaceous cement, firm to soft, blocky, rarely calcareous. ■ Sandstone: light gray to gray, medium upper to fine lower grains, occasional lower coarse and some small pebbles. Grains are predominately quartz, clear to white, buff and occasional green, poorly to moderately sorted, sub rounded to sub angular, clay matrix, unconsolidated to poorly cemented, moderately calcareous. ConocOPhillip5 Alaska, Inc. HALLIBURTON I Sperry Drilling ■ Coal: black to dark brown, hard to brittle, blocky, waxy to slightly silty, earthy to occasionally shiny, angular to sub conchoidal cuttings. 06/24/2010 Ran in hole to 3850' MD with no tight spots. Circulated and conditioned hole with bottoms up gas at 193 units. MWD tool failed; pulled out of the hole. Unloaded sources and downloaded MWD tool. Replaced tools, uploaded MWD, and sources. Made up the rest of BHA #3. 06/25/2010 Finish making up BHA #3 and began running in the hole. r06/26/2010 Tripped in hole, lost 23 bbls. Broke circulation at the shoe; experienced no losses in static. ' Tripped in the hole at 90 seconds per stand. Circulated up 277 units of trip gas. Began drilling from 3883' to 4628' MD. The Beluga E formation drilled at an average of 91 fuhr. Drilling gas averaged 233 Formation was dominantly Tuffaceous Sandstone, Tuffaceous Claystone, ' Tuffaceous Siltstone, and Coal. ROP appeared to units with several gas peaks noted in the gas breakdown. Background gas averaged160 units increase through Coal stringers. The Beluga F is currently being drilled at an average of 102 ft/hr. Average drilling gas has been Volcanic Tuff, and organic rich Carbonaceous Shale. The trend of faster drilling through the Coals and Sands continues with slower drilling in the Tuffaceous Claystones and Siltstones. General Descriptions: For the interval drilled in the previous 24 hours; the Sterling Beluga D through mostly Tuffaceous Claystone, with intermittent layers of Coal and Sand and Tuff. ■ Claystone: Gray to light gray, light brown in places, silty, soft to firm, sub blocky to blocky, tuffaceous clay, rare carbonaceous specks, non hydrophilic, slightly calcareous. ■ Siltstone: Light gray to gray, sub spherical, moderately sorted, tuffaceous clay matrix, firm, sub blocky, common carbonaceous specks, slightly calcareous. ■ Coal: Black to dark brown, very hard, occasionally firm, blocky, fissile in ' places, uneven fractures. ■ Tuff: Light gray to white, cream, soft, friable in places, sub rounded, blocky. 06/27/2010 Drilled ahead from 4628' MD to 4919' MD entering the Beluga G; average ROP was 103 ft/hr with an average drilling gas of 367 units. Backreamed out of hole 4 stands with tight spots. Pulled out 6 stands without pumping and rotating and saw a few tight spots. Backreamed 6 additional stands to 3883' MD with no tight spots. Ran in the hole with no problems and had 411 units of trip gas. Pumped up a Calcium Carbide pill to determine lag and washout, ' inconclusive results. Drilled an additional stand through a sticky Claystone which most likely gummed up the bit. ROP slowed to an average of 47 ft/hr with sustained drilling rates as low as 24 ft/hr. Drilling gas dropped to 54 units. Pumped 35 bbl balling sweep at 5110' MD, no ' significant increase of ROP or Clay cuttings seen at shaker. Pumped another Calcium Carbide pill to determine true bottoms up. The resulting gas spike appeared at 7472 strokes. Continued drilling into the Beluga H and have experienced an average ROP of 46 ft/hr. Average drilling Conoc03liiiip5 Alaska, Inc. i El HALLIBURTON ( Sperry Drilling gas has been 244 units with gas peaks up to 1591 and 1979 units. Geology continues to be a sticky Claystone but an increasing amount of Sandstone has been logged in recent depths. General Descriptions: For the interval drilled in the previous 24 hours; the Beluga F was capped by a significant Coal bed and continued to have intermittent Coal stringers throughout section. Dominantly Claystone with several Sandstone sections throughout. The upper Beluga G was also capped by a Coal bed. The rest of the section drilled was a slightly Clayey Siltstone with another Coal bed. ■ Claystone: Gray to light gray, light brown to medium brown, friable -slightly gummy, slightly silty, sub tabular cuttings, earthy, very tuffaceous, and carbonaceous laminations interbedded, slightly hydrophilic, rarely calcareous. ■ Siltstone: gray, brown to light brown, soft to firm, occasionally hard, , poorly sorted, rare sandy, tuffaceous material, sub blocky, common carbonaceous specs, occasionally volcanic lithographic, non calcareous. ■ Sandstone: very light gray to gray, soft, medium low to fine low, occasionally medium upper, sub angular to sub round sub elongated to sub spherical, moderately to well sorted, poorly tuffaceous material, multicolored volcanic, occasional carbonaceous laminations interbedded, sub nodule cuttings„ rarely calcareous. ■ Coal: Black to dark brown, very hard, occasionally firm, blocky, fissile in places, uneven fractures. ■ Tuff: Light gray to white, cream, soft, friable in places, sub rounded, blocky. ■ Shale: dark brown, hard to firm, earthy to sub blocky texture, carbonaceous, rarely laminated, occasionally banded. 06/28/2010 Drilled ahead from 4919' MD to 5903' MD. Drilled through the remaining Beluga G and into the Beluga H at an average ROP of 79 ft/hr with an average drilling gas of 121 units. Max gas of 1053 units occurred near the Beluga I marker. The bottom section of the Beluga H consisted mostly of Claystones and Siltstones. Drilling breaks occurred in the few Sandstone sections and background gas was consistently 30-40 units during the bottom 250'. Pumped 5 ppb Nut Plug sweeps with 4% Drillzone as need to enhance ROP while drilling sticky Claystones. Planned short trip from 5803' MD to approximately 4850' MD. Backreamed 4 stands, pulled out 4 stands on elevators. The 5th stand pulled tight, rotated and pumped through tight spot. Continued to pull out 13 stands on elevators with no problems. Ran back in hole. Circulated up 340 units of trip gas. Began drilling in the Beluga I at and average ROP of 97 ft/hr. Average drilling gas was 731 units with 3 substantial peaks noted above. The bottom two peaks appear to be associated with a finely grained Sandstone of the upper Beluga I. Currently drilling ahead at the time of report. General Descriptions: For the interval drilled in the previous 24 hours; lower Beluga G was a Silty Claystone with a few Sandstone and Tuffaceous Claystone sections. The upper Beluga I was Sandstone with a friable Tuffaceous Claystone matrix, high gas recorded within Sandstones. Conoc(Whiiiips Alaska, Inc. ' HALLIBURTON I Sperry Drilling ■ Claystone: gray to light gray, firm to soft, very silty to gummy, amorphous to ' nodule cuttings, earthy, hydrophilic, and slightly calcareous. ■ Siltstone: gray to light gray, some brown pieces, soft to firm, occasionally hard, poorly sorted, sandy, tuffaceous material, sub blocky, common ' carbonaceous specs occasionally volcanic lithographic, non calcareous. ' • Sandstone: light gray to gray, soft to hard in part, fine upper to very fine upper, occasionally medium low grading to coarse, sub round to round spheres, well to moderately sorted, soft tuffaceous clay matrix, hard silty cement in part, common multi colored lithics, calcareous. I n 1 r r ■ Shale: dark brown, hard to firm, earthy to sub blocky texture, carbonaceous, rarely laminated, occasionally banded. 06/29/2010 Drilled from 5903' MD to 6565' MD, TD called. Drilled at an average ROP of 122 ft/hr with an average drilling gas of 147 units. The bottom half of the Belgua I consisted of Silty Claystones, Coal stingers, and a few Sandstone sections. Circulated for 2 hours to clean up the hole. Backreamed 4 stands, pulled out on elevators 3 stands and the 3rd stand pulled tight at 6140' MD. Backreamed the next 2 stands back. Pulled 2 more stands on elevators, pulled tight at 5896' MD and 5876' MD. Backreamed the next 4 stands back to 5662' MD. Circulated for 30 minutes, Silty Claystones, and bits of Coal coming over shakers. Ran back in hole to clean out. Circulate for 1 hour, with bottoms up gas at 123 units. Pull out of hole on elevators, Pulled tight at 5585' MD. Flow check for 25 minutes - OK. Pulled tight again at 4780' MD, circulated bottoms up with max gas of 147 units. Pull out on elevators, pulled tight 3701' MD, circulated hole. Backreamed out to approximately 2772' MD at time of report. General Descriptions: For the interval drilled in the previous 24 hours; the lower Beluga I was dominantly Silty Claystone and Claystone, minor sections of Sandstone also present. ■ Claystone: gray to light gray, soft to firm, very silty to gummy, amorphous to nodule cuttings, earthy, hydrophilic, slightly calcareous, ■ Siltstone: light brown, soft to firm, occasionally hard, poorly sorted, sandy, tuffaceous material, some sub blocky, common carbonaceous specs occasionally volcanic lithographic, non calcareous. ■ Sandstone: light gray to gray, soft to hard in part, fine upper to very fine lower, grading to silty, sub round to round spheres, well to moderately sorted, soft tuffaceous clay matrix, hard silty cement in part, common multi colored lithics. 06/30/2010 Pulled out of hole on elevators once inside casing. Lay down BHA #3 test rams for 7" casing. Run in the hole with 7" casing with no problems. Circulate mud through casing for 30 minutes and recorded 12 units of max gas. Continued running in the hole with 7" casing. Landed casing with minor problems. Sperry SDL released from rig. COI'1 caftillips Alaska, Inc. Customer: CPAI Report #: 1 Max @ ft Current Pump & Flow Data: HALLIBURTON Well: BRU 212-24T Date: 06/22/2010-04:00 Depth On Bot Hrs Ann Corr Avg Diam DrillingMin AvgMax PWD Area: Kenai Peninsula Borough 04:00 Depth 2861' 10.30 45,000 Location: Beluga River Unit Progress 24 hrs: 0' Sperry Drilling Services Rig: Job 140.: Daily Charges Arctic Fox Rig Activity: Report For: Total Charges: Waiting on Parts Lutrick/Cecchetti $24,660.00 AK -AM -0007262432 $4,130.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr Flow In m SPP(psi) Gas (units) Flow In (spm) Gallons/stroke Hole Condition Depth On Bot Hrs Ann Corr Avg Diam DrillingMin AvgMax PWD 9.60 1 9.60 1 60.0 1 1 11 All Circ IMin I jAvg Max Mud Data: Depth ft Density (ppg) in out Viscosity MBT PV seG t b E cP Ilb/lyp 00 00ft2 API Filt ml/30min pH Chlorides m /I Cor Solids % 2881' 9.60 1 9.60 1 60.0 1 1 11 1 18 432 10.30 45,000 X BHA Run # Bit Type Sie TFA Hours Dethinuzµy yp /out Footage I WOB I RPM Condition 200 Hughes PDC 8.75 0.840 ELithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to _ to _ to to _ to _ to _ to to _ to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... 24 hr Recap: Completed BOP test, Picked up drill pipe and stood back in the derrick. Flow line was found to be plugged with cement, unplugged same. Picked up BHA #2 and singled into hole to the float plug. Pressure tested casing. One of the pumps broke down and are currently waiting on parts. Gas Analyzer and Chromatograph calibrated and tested OK. Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas In Air H Report #: EMIL 2 Customer: CPA[ 04:00 Depth HALLIBURTON Well: BRU 212-24T Rig Activity: Drilling Ahead Area: Kenai Peninsula Borough Total Charges: $28,790.00 Location: Beluga River Unit 9 Sperry Drilling Services Rig: Job No.: Daily Charges Arctic Fox AK -AM -0007262432 Hole ConditionPWD $4,130.00 On Bot Hrs Ann Corr AvgDiam DrillingMin AvgMax Report #: EMIL 2 Date: 06/23/2010-04:00 04:00 Depth 2945' Progress 24 hrs: 84' Rig Activity: Drilling Ahead Report For: Hill/Cecchetti Total Charges: $28,790.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: API Filt ml/30min R.O.P. ff/hr 20.0 43.0 116.0 2931' Flow In m 455 SPP(psi) 1106 Gas (units) 25 9 28 2945' Flow In (spm) 236 Gallons/stroke 1.9380 Hole ConditionPWD Depth On Bot Hrs Ann Corr AvgDiam DrillingMin AvgMax All Circ Min I jAvg Imax Mud Data: Depth ft Density (ppg) in out Viscosity (sed t) MBT b E PV cP jlb/1YP 00ftz 00 API Filt ml/30min pH Chlorides m /I Cor Solids 2881' 9.60 1 9.60 48.0 1 2.0 14 1 14 6.0 10.10 1 45,000 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 200 Hughes PDC 8.75 0.840 3.79 2861.00 84' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 5 20 70 5 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: JAvg: Gas (units) Chromatograph (ppm) Depth -to- to oto _ to to _ to _ to _ to _ to _ to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... 24 hr Recap: Continued to wait on parts, repair pumps. Drilled float plug and cement plug with no issues. Drilled to 2877' MD and noticed increased flow out, shut in well. Found that the mud weight had dropped from 9.6 ppg to 9.1 ppg and was contaminated. Gas increased to 11 units before falling out. Displaced to KlaShield then drilled to 2881'MD. Performed FIT/LOT to 16 ppg. Began drilling production hole. Background gas was averaging 9 units after drilling cement. Background gas increased to 25 units during the last 30' of drilling. Drilling ahead at time of report. Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas In Air 7 1 u j HALLIBURTDN Sperry Drilling Services Customer: Well: Area: Location: Rig: Job No.: Daily Charges BRU 212-24T Kenai Peninsula Borough Beluga River Unit Arctic Fox AK -AM -0007262432 $4,130.00 Report #: Date: 04:00 Depth Progress 24 hrs: Rig Activity: Report For: Total Charges: 3 06/24/2010-04:00 3883' 938' Drilling Ahead Hill/Cecchetti $32,920.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr 117 331 3046' Flow In m SPP(psi) - Gas (units) 190 1128 3787' Flow In (spm) Gallons/stroke 1.9380 Hole ConditionPWD Depth On Bot Hrs Ann Corr AvgDiam Drilling_77Min Av Max Avg: All Circ Min I lAvg IMax Mud Data: Depth ft Density (ppg) in out Viscosity (sec/ t) MBT b E PV cP 00ft2 jIb/1YP 00 API Filt ml/30min pH Chlorides m /I Cor Solids % 3883' 9.70 1 9.70 49.0 2.2 1 14 1 23 10.5 9.90 39,000 - BHA Run # I Bit Type Size ITFA Hours Depth in / out Footage I WOB RPM I Condition 200 Hughes PDC 8.75 10.840 15.67 2861.00 938' Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 3368' to 3392' 715 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) H2S Data 25 30 20 25 to Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 3368' to 3392' 715 530 89979 - - - - GP 3630' to 3649' 730 546 90114 - - - GP 3756' to 3788' 1129 637 132189 - - - GP 3819' to 3832' 725 593 92243 - - - GP to -to- ototo -to- -to- to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... I hr Recap: Drilled from 2945' MD to 3883' MD. ROP was variable between 40 and 280 ft/hr sustained throughout the past 24 hours of drilling. In the Sterling A, ROPs averaged 125 ft/hr with max ROP at 210 ft/hr. Drilling gas averaged 231 units and max gas was 715 units. . Drilling in Sterling B, averaging drilling ROP was 114 ft/hr with a max ROP of 194 ft/hr. Gas while drilling averaged 214 units, max gas was 702 units. The Sterling C formation drilled with an average ROP of 121 ft/hr and sustained max ROP of 174 ft/hr. Average drilling gas was 343 units and max gas was 1129 units. No connection gas was seen. Backreamed 4 stands out of hole and pulled out an additional 12 stands. Continue pulling back to shoe for wiper trip after cut and slip operations. Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units = 100% Gas In Air r L u n r r r�ALLIBURTDN Well: BRU 212-24T Date: 06/25/2010-04:00 Flow In (spm) Gallons/stroke 1.9380 Area: Kenai Peninsula Borough 04:00 Depth 3883' All Circ IMin I jAvg IMax Location: Beluga River Unit Progress 24 hrs: 0' Sperry Drilling Services Rig: Arctic Fox Rig Activity: Running in Hole Job No.: AK -AM -0007262432 Report For: Hill/ceccheftl Daily Charges $4,130.00 Total Charges: $37,050.00 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. fUhr - - Flow In m - SPP (psi) - Gas (units) - Flow In (spm) Gallons/stroke 1.9380 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam Drilling Min Av Max PWD 3883' All Circ IMin I jAvg IMax Mud Data: Depth ft Density (ppg) in out Viscosity seG t MBT b E PV cP YP Ib/100ft2 API Filt m1/30min pH Chlorides m /I Cor Solids % 3883' 9.70 9.70 48.0 3.0 14 22 10.5 10.00 1 40,000 1 8.5 Lithology (%):Sst PL4 Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 25 30 20 25 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... 24 hr Recap: Pulled back to shoe with no tight spots. Worked on starter on draw works and ran in the hole to 3850' MD. Began to circulate and condition hole, bottoms up gas maxed out at 193 units. MWD did not receive signal. Pulled out of hole. Unloaded sources and downloaded tool data. Replaced MWD tools and uploaded sources. Continued to make up BHA #3. Running in the hole at the time of report. Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas in Air u u 11 0 u 0 HALLIBURTON Customer: Well: CPAI BRU 212-24T 04:00 Depth Area: Kenai Peninsula Borough 745' Location: Beluga River Unit Sjxm7 Chilling Services Rig: Arctic Fox $41,180.00 Job No.: AK -AM -0007262432 304 Daily Charges $4,130.00 Report #: 5 Date: 06/26/2010-04:00 04:00 Depth 4628' Progress 24 hrs: 745' Rig Activity: Drilling Ahead Report For: Hill/Cecchetti Total Charges: $41,180.00 ROP Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: API Filt ml/30min R.O.PM=as: 106 100 220 4060' Flow In m 542 SPP(psi) 2435 Gas (units) 336 304 1720 4402' Flow In (spm) 279 Gallons/stroke 1.9380 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam Drillin Min Av PWD Max All Circ Min Avg Max Mud Data: Depth ft Density (ppg) in out(sec/ Viscosity t) MBT b E PV cP Ilb/1 YP 00ft2 API Filt ml/30min pH Chlorides m /1 Cor Solids 4290' 9.70 9.70 47.0 4.0 1 15 1 17 10.5 9.90 40,000 9.0 Llthology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 3HA Run # Bit TypeL87 TFA Hours Depth in / out Footage WOB RPM Condition 200 Hughes PDC 0.840 15.67 2861' 3883' 1022' 83-128300 rr Hughes PDC 0.840 10.37 3883' 1 745' Llthology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 25 30 20 25 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 4068' to 4082' 1192 892 142542 - - - - GP 4204' to 4218' 1158 860 139348 - - - - GP 4397' to 4423' 1720 924 202412 - - - - GP 4449' to 4467' 993 554 121110 - - - - GP to to to to -to— Gas oGas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... 24 hr Recap: Tripped in hole, lost 23 bbls. Broke circulation at the shoe; experienced no losses in static. Tripped in the hole at 90 seconds per stand. Circualated up 277 units of trip gas. Began driliing ahead. The Beluga E formation drilled at an average of 91 ft/hr. Drilling gas averaged 233 units with several gas peaks noted in the gas breakdown. Background gas averaged 160 units. Formation was dominantly Tuffaceous Sandstone, Tuffaceous Claystone, Tuffaceous Siltstone, and Coal. ROP appeared to increase through Coal stringers. The Beluga F is currently being drilled at an average of 102 ft/hr. Average drilling gas has been 358 units. Background gas has averaged 190 units. Formation is Coal, Tuffaceous Sandstone, Tuffaceous Siltstone and Claystone, Volcanic Tuff, and organic rich Carbonaceous Shale. The trend of faster driling through the Coals and Sands continues with slower drilling in the Tuffaceous Claystone and Silstones. Formations depths are approximated by mudlogger on location for accurate ROP and Gas data for morning report Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas In Air Customer: CPAI HALLIBURTON Well: BRU 212-24T 04:00 Depth Area: Kenai Peninsula Borough 670' Location: Beluga River Unit Sperry Drilling Bervices Rig: Job No.: Daily Charges Arctic Fox AK -AM -0007262432 Gas (units) $4,130.00 Report #: 6 Date: 06/27/2010-04:00 04:00 Depth 5298' Progress 24 hrs: 670' Rig Activity: Drilling Ahead Report For: Hill/Cecchetti Total Charges: $45,310.00 ROP Current Avg 24 hr Max Max@ft Current Pump & Flow Data: API Filt ml/30min Mas: R.O.Pr 45 75 308 4708' Flow In m 531 SPP (psi)2111 5.0 Gas (units) 90 296 1979 5224' Flow In (spm) 272 Gallons/stroke 1.9380 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam DrillingMin Av PWD Max All Circ Min I lAvg Max Mud Data: Depth ft Density (ppg) in out Viscosity sec/ t MBT b E PV 'F YP Ilb/100ft2 API Filt ml/30min pH Chlorides M /1 Cor Solids I % 5127' 9.80 1 9.80 1 46.0 5.0 16 1 21 13.0 1 9.70 1 37,000 11.0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff BHA Run # Bit Type Size ITFA I Hours I Depth in/ out I Footage I WOB I RPM Condition 200 Hughes PDC 8.75 10.840 1 15.67 1 2861' 1 3883' 1 1022' 83-128 300 rr Hughes PDC 8.75 10.8401 10.37 1 3883' 1 1 1415' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 30 15 30 25 Gas Breakdown 1-12S Data I Sample Line jMaX7 Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 4828' to 4846' 1519 939 180879 - - - - GP 5187' to 5199' 1598 1099 190819 - - - - GP 5217' to 5225' 1979 1241 233621 - - - - GP to to _ to _ to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... 24 hr Recap: Drilled ahead to 4628' MD to 4919' MD entering the Beluga G; average ROP was 103 ft/hr with an average drilling gas of 367 units. Backreamed out of hole 4 stands with tight spots. Pulled out 6 stands without pumping and rotating and saw a few tight spots. Backreamed 6 additional stands to 3883' MD with no tight spots. Ran in the hole with no problems and had 411 units of trip gas. Pumped up a Carbide pill to determine lag and washout, inconclusive results. Drilled an additional stand through a sticky Claystone which most likely gummed up the bit. ROP slowed to an average of 47 ft/hr with sustained drilling rates of 24 ft/hr. Drilling gas dropped to 54 units. Pumped 35 bbl balling sweep at 5110' MD, no significant increase of ROP or Clay cuttings seen at shaker. Pumped a Carbide pill and determined bottoms up pump strokes to be approximately 7472. Continued drilling into the Beluga H and have experienced an average ROP of 46 ft/hr. Average drilling gas has been 244 units with gas peaks up to 1591 and 1979 units. Geology continues to be a sticky Claystone but an increasing amount of Sandstone has been logged in recent depths. Formations depths are approximated by mudlogger on location for accurate ROP and Gas data for morning report Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas In Air 1 i Report #: Customer: CPAI HALLIBURTON Well: BRU 212-24T Progress 24 hrs: Area: Kenai Peninsula Borough Drilling Ahead Location: Beluga River Unit Sperry Drilling Services Rig: Arctic Fox Gas (units) Job No.: AK -AM -0007262432 5300 Daily Charges $4,130.00 283 Gallons/stroke 1.9380 Hole Condition Depth Report #: 7 Date: 06/28/2010-04:00 04:00 Depth 5903' Progress 24 hrs: 5298' Rig Activity: Drilling Ahead Report For: Hill/Cecchetti Total Charges: $49,440.00 2852 Gas (units) 151 ROP Current Avg 24 hr Max Max @ ft Hours Current Pump & Flow Data: Footage WOB RPM Condition Mas: R.O.Pr 104 83 283 5848' Flow In m 549 SPP(psi) 2852 Gas (units) 151 206 5300 5820' Flow In (spm) 283 Gallons/stroke 1.9380 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam DrillingMin PWD All Circ AvgMax IMin I jAvg IMax Mud Data: Depth ft Density (ppg) 7in out Viscosity sec/ t MBT b E PV CP YP Ib/100ft2 API Fill ml/30min pH Chlorides m /I Cor Solids % 5686' 1 9.80 9.80 55.0 6.0 1 19 30 5.8 9.70 40,000 11.0 SHA Run # Bit Type Size TFA Hours Depth in/ out Footage WOB RPM Condition 200 Hughes PDC 8.75 0.840 15.67 2861' 1 3883' 1022' 83-128 300 rr Hughes PDC 8.75 0,8401 48.83 1 3883' 1 1 2020' LithologySst pq� Silt Siltst 1 Cht Clyst Sh Lst Coal Gvl Tuff (current) 40 35 1 25 Gas Breakdown H2S Data I Sample Line Max: Avg: Ambient Air Pit Room Max: jAvg: Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 5742' to 5750' 1053 412 127919 - - - - GP 5783' to 5798' 3606 1511 411546 - - - - 5811' to 5832' 5300 2405 672848 - - - - to to _ to _ -to- to oto -to- Gas oGas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... 24 hr Recap: Drilled ahead from 5298' MD to 5803' MD. Drilled through the remaining Beluga Hat an average ROP of 79 fuhr with average drilling gas of 121 units. Max gas of 1053 units occurred near the Beluga I marker. The bottom section of the Beluga H consisted mostly of Claystones and Siltstones. Drilling breaks occurred in the few Sandstone sections and background gas was consistedly 30-40 units during the bottom 250'. Pumped 5 ppb Nut Plug sweeps with 4% Drillzone as need to enhance ROP while drilling sticky Claystones. Planned short tripp from 5803' MD to approximately 4850' MD. Backreamed 4 stands, pulled out 4 stands on elevators. The 5th stand pulled tight, rotated and pumped through tight spot. Continued to pull out 13 stands on elevators with no problems. Ran back in hole. Circulated up 340 units of trip gas. Began drilling in the the Beluga I at and average ROP of 97 ft/hr. Average drilling gas was 731 units with 3 substantial peaks noted above. The bottom two peaks appear to be associated with a finely grained Sandstone of the upper Beluga I. Currently drilling ahead at the time of report. Formations depths are approximated by mudlogger on location for accurate ROP and Gas data for morning report Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas In Air ROP & Gas: 2..- Report #: HALLIBURTON Customer: Well: CPAI BRU 212-24T 6565' Area: Kenai Peninsula Borough Rig Activity: Location: Beluga River Unit Sperry Drilling BerWC89 Rig: Arctic Fox 5964' Job No.: AK -AM -0007262432 De th Daily Charges $4,130.00 ROP & Gas: Current Report #: 8 Date: 06/29/2010-04:00 04:00 Depth 6565' Progress 24 hrs: 662' Rig Activity: POOH for Casing Run Report For: Hill/Cecchetti Total Charges: $53,570.00 5964' Flow In (spm) 0 Gallons/stroke 1.9380 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. fUhr 0 122 320 6319' Flow In m 0 SPP(psi) 0 Gas (units) 0 147 877 5964' Flow In (spm) 0 Gallons/stroke 1.9380 Hole Condition De th On Bot Hrs Ann Corr Av Diam DrillingMin Av Max PWD All Circ Min Avg IlMax Mud Data: Density (ppg) Depth ft in out Viscosity sec/ t MBT b E PV cP 00ft2 00 jlb/1YP API Filt ml/30min pH Chlorides m /I Cor Solids % 6545' 9.80 1 9.80 66.0 4.5 1 22 1 36 3.6 9.70 1 40,000 1 12.0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 200 Hughes PDC 8.75 0.840 15.67 2861' 3883' 1022' 83-128 300 rr Hughes PDC 8.75 0.840 49.16 3883' 6565' 2682' 6-8 130-150 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 25 25 50 Gas Breakdown H2S Data I Sample Line Max: Avg: Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 5955' to 5969' 877 514 107605 - - - - GP 6021' to 6040' 750 455 89058 - - - - GP to -to- -to- -to ototo _ to to _ to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... 24 hr Recap: Drilled from 5903' MD to 6565' MD, TD called. Drilled at an average ROP of 122 ft/hr, with average drilling gas of 147 units. The bottom half of the Belgua I consisted of Silty Claystones, Coal stingers, and a few Sandstone sections. Circulated for 2 hours to clean hole. Backreamed 4 stands, pulled out on elevators 3 stands and the 3rd stand pulled tight at 6140' MD. Backreamed the next 2 stands back. Pulled 2 more stands on elevators, pulled tight at 5896' MD and 5876' MD. Backreamed the next 4 stands back to 5662' MD. Circulated for 30 minutes, Silty Claystones and bits of Coal coming over shakers. Ran back in hole to clean out. Circulate for 1 hour, with bottoms up gas at 123 units. Pull out of hole on elevators, Pulled tight at 5585' MD. Flow check for 25 minutes - OK. Pulled tight again at 4780' MD, circulated bottoms up with max gas of 147 units. Pull out on elevators, pulled tight 3701' MD, circulated hole. Backreamed out to approximately 2772' MD at time of report. Formations depths are approximated by mudlogger on location for accurate ROP and Gas data for morning report Sample Catchers on location 6/21/2010 Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas In Air u i 0 L C C HALLIBURTON Customer: Well: CPAI BRU 212-24T 04:00 Depth Area: Kenai Peninsula Borough 0' Location: Beluga River Unit Sperry Drilling Services Rig: Arctic Fox $56,003.60 Job No.: AK -AM -0007262432 1 3.6 Daily Charges $2,900.00 Report #: 8 Date: 06/29/2010-04:00 04:00 Depth 6565' Progress 24 hrs: 0' Rig Activity: RIH w/ Casing Report For: Hill/Rizeki Total Charges: $56,003.60 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr Flow In m 0 SPP(psi) 0 Gas (units) Flow In (spm) 0 Gallons/stroke 1.9380 Hole ConditionPWD De th On Bot Hrs Ann Corr AvgDiam DrillingMin Av Max Cor Solids % 6565' All Circ IMin I jAvg Imax Mud Data: Depth ft Density (ppg) in out Viscosity sec! t MBT b E PV cP jib/lyp00ftml/30min2 API Filt pH Chlorides m /I Cor Solids % 6565' 9.90 9.90 65.0 1 5.0 1 22 1 36 1 3.6 1 9.70 1 40,000 1 12.0 Lithology (%): Sd j Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) BHA Run # Bit Type Size TFA I Hours I Depth in/ out I Footage WOB RPM I Condition 200 Hughes PDC 8.75 10.840 1 15.67 1 2861' 1 3883' 1 1022' - 83-128 300 rr Hughes PDC 8.75 10.8401 49.16 1 3883' 1 6565' 1 2682' 6-8 130-150 Lithology (%): Sd j Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 25 25 50 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth Max Avg: C1 C2 C3 C4 C5 -to- -to- -to ototo _ to _ -to- -to- -to ototo _ to --to- Gas oGas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... I 1Z 24 hr Recap: Continue to pullout of the hole on elevators inside of casing. Lay down BHA #3 and testing rams to 7". Rigged up and currently running in the hole with 7" casing at the time of report. Total charges include staging days before SDL Engineers commenced rig up. Logging Engineer: Ryan Massey / Mark Lindloff 10000 units= 100% Gas In Air HALLIBURTON Sperry Or1111ng BIT RECORD WELL NAME: BRU 212-24T OPERATOR:CPAI MUD CO: MI-Swaco RIG. Arctic Fox SPERRY JOB: AK -AM -0007262432 LOCATION: Beluga River Unit AREA: Cook Inlet STATE: Alaska SPUD: 14-1un-10 TD: 28 -Jun -10 BHA# SDL RUN # Bit # Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max) Bit Grade Remarks 1 100 1 Smithh XR+CPS 12.25 0 2861 2861 26.28 0.700 243.0 20 100 2270 535 1 -1 -WT -A -E -1 -N -TD TD 12.25" Hole Section at 2861" MD/ 2841' TVD 2 200 2 Hycalog DTX691M-D2 8.75 2861 3883 1022 15.65 0.840 65.7 7.4 136 1501 558 POOH for MWD 3 300 2rr Hycalog DTX691 M -D2 8.75 3883 6565 2682 50.46 0.840 382.0 54.7 162 3656 526 0-1-CT-G-x-1-NO-DTG TD well 6565' and m m m r m m m m m m m m m m m m m m m H^LLIBURTON Sperry Drilling Water Based Mud Record WELL NAME: BRU 212-24T OPERATOR: CPAI MUD CO: MI-Swaco RIG: Arctic Fox SPERRY JOB: AK -AM -0007104244 LOCATION: Beluga River Unit AREA: Cook Inlet STATE: Alaska SPUD: 13-1un-10 TD: 27-1un-10 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft -MD ppg sec Ib/100 VIM m/30m Rheometer 32nds % % % ml Ib/gal mg/L Ca - 17 -Jun 2861 9.60 170 63 38 16/21/24 5.8 164/101/90/62/20/16 3/n/a 7.0 1/93 0.50 2.0 3.5 .02/.60 502 2.79 Running9 5/8" Casing 18 -Jun 2861 9.60 50 14 23 10/11/12 5.8 51/37/28/21/12/9 2/- 7.0 1/93 0.50 - 7.5 20.0 -/.50 200 40.00 Nipple Up BOPs 19 -Jun 2861 9.60 51 15 22 10/11/12 5.8 52/37/28/22/12/9 2/- 7.0 1/93 0.50 - 7.5 20.0 -/.50 200 40.00 Nipple Up BOPS 20 -Jun 2861 9.60 51 15 21 10/11/11 5.8 51/36/26/20/12/9 2/- 7.0 1/93 0.50 7.0 20.0 -/.50 200 40.00 Test BOPS 21 -Jun 2861 9.60 60 11 18 8/9/10 5.5 40/29/25/18/8/5 1/- 7.0 3/90 - 1.80 10.3 - 1.4/1.7 45000 200.00 RIH to Drill Shoe 22 -Jun 2881 9.60 48 14 14 8/10/11 6.0 42/28/27/18!7/6 1/- 7.5 3/90 Tr 1.80 10.1 2.0 1.4/1.7 48000 200.00 FIT/LOT 23 -Jun 3883 9.70 49 14 23 7/8/9 10.5 51/37/31/23/8/7 1/1 8.5 3/89 Tr 3.00 9.9 2.2 3.0/5.4 39000 200.00 Short Tri to Shoe 24 -Jun 3883 9.70 48 14 22 8/10/11 10.5 50/36/30/23/8/7 1/- 8.5 3/89 Tr 3.30 10.0 3.0 3.0/5.5 40000 200.00 UploadingMWD 25 -Jun 4290 9.70 47 15 17 6/8/9 10.5 47/32/27/20/6/5 1/1 9.0 3/88 Tr 3.20 9.9 4.0 3.0/4.3 40000 200.00 Drilling Ahead 26 -Jun 5127 9.80 46 16 21 8/11/12 13.0 53/37/32/24/9/8 1/2 11.0 2/87 Tr 3.10 9.7 5.0 3.0/4.4 37000 200.001 Drilling Ahead 27 -Jun 5803 9.80 55 19 30 9/11/13 5.8 1 68/49/40/29/9/8 1/2 11.0 3/86 Tr 1 3.20 9.7 1 6.01 3.2/5.5 40000 160.001 POOH for Short Tri 28 -Jun 6565 9.80 66 22 36 8/10/11 3.6 1 80/58/47/35/9/7 1/212.0 4/84 Tr 2.80 9.7 4.5 2.8/5.8 40000 160.00 POOH CasingRun 29 -Jun 6565 9.90 65 22 36 8/10/11 3.6 80/58/47/35/9/7 1/2 12.0 4/84 Tr 2.90 9.7 5.0 2.8/5.6 40000 160.00 RIH with Casing Casing Record 16" Conductor @ 153' 9 5/8" Surface @ 4025' L u J I I J HALL_IBURTON 5p®r" Quilling BRU 212-24T Formation Tops Marker MD TVD Injection Zone 3024.0 2907.0 Sterling A 3286.0 3169.0 Sterling B 3465.0 3349.0 Sterling C 3616.0 3500.0 Beluga D 3781.0 3664.0 Beluga E 4043.0 3926.0 Beluga F 4371.0 4253.0 Beluga G 4794.0 4677.0 Beluga H 5096.0 4979.0 Beluga 1 5772.0 5655.0 Beluga I base 6318.0 6201.0 TD 6565.0 6448.0 �/ • ConocoMiII• ps Alaska, Inc. ConocoPhillips(Alaska) Inc. Beluga River Beluga River BRU 212-24T Sperry Oriiiinq Services Definitive Survey Report 13 July, 2010 HALLIBURTON Sperry Drilling Services ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.1711(Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production Project Beluga River Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well BRU 212-24T Well Position +N/ -S +E/ -W Position Uncertainty 0.00 It 0.00 It 0.00 ft Northing: Easting: Wellhead Elevation: 2,633,574.84 ft 323,481.44 it 18.50 ft Latitude: 61' 12'16.386 N Longitude: 151 ° 0'3.247 W Ground Level: 78.67 It Wellbore BRU 212-24T (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 147.07 Magnetics Model Name MWD + Short Collar correction + BHA SAG Co 6/15/2010 1: Sample Date Declination Dip Angle Field Strength MWD + Short Collar correction + BHA SAG Co 6/23/2010 1: 3,768.63 6,473.56 BRU 212-24T (R300) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/29/2010 1: (°) (nT) (ft) BGGM2009 6/20/2010 (ft) 18.57 74.03 55,736 Design BRU 212-24T 18.50 0.00 0.00 18.50 -78.67 Audit Notes: 0.00 2,633,574.84 323,481.44 0.00 0.00 UNDEFINED 147.07 Version: 1.0 147.06 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: 323,482.53 Depth From (TVD) +N/ -S +E/ -W Direction 204.92 107.75 -1.48 (ft) (ft) (ft) (I -1.48 MWD+SCC+SAG (1) 265.26 1.37 18.50 0.00 0.00 0.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 147.07 2,812.49 BRU 212-24T (R100) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/15/2010 1: 2,910.15 3,705.21 BRU 212-24T (R200) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/23/2010 1: 3,768.63 6,473.56 BRU 212-24T (R300) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/29/2010 1: Survey 7/132010 9:18:40AM Page 2 COMPASS 2003.16 Build 69 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -78.67 0.00 0.00 2,633,574.84 323,481.44 0.00 0.00 UNDEFINED 147.07 1.19 124.46 147.06 49.89 -0.76 1.10 2,633,574.07 323,482.53 0.93 -0.76 MWD+SCC+SAG (1) 204.94 1.13 132.06 204.92 107.75 -1.48 2.02 2,633,573.33 323,483.44 0.29 -1.48 MWD+SCC+SAG (1) 265.26 1.37 131.28 265.22 168.05 -2.35 3.00 2,633,572.44 323,484.41 0.40 -2.35 MWD+SCC+SAG (1) 324.86 0.70 101.60 324.81 227.64 -2.90 3.90 2,633,571.89 323,485.29 1.40 -2.90 MWD+SCC+SAG (1) 389.37 0.77 93.44 389.32 292.15 -3.00 4.71 2,633,571.77 323,486.11 0.19 -3.00 MWD+SCC+SAG (1) 447.80 1.08 88.76 447.74 350.57 -3.01 5.66 2,633,571.74 323,487.05 0.55 -3.01 MWD+SCC+SAG (1) 509.63 1.00 97.65 509.56 412.39 -3.07 6.77 2,633,571.67 323,488.17 0.29 -3.07 MWD+SCC+SAG (1) 569.35 1.14 97.46 569.27 472.10 -3.22 7.88 2,633,571.50 323,489.27 0.23 -3.22 MWD+SCC+SAG (1) 628.04 1.04 90.30 627.95 530.78 -3.30 8.99 2,633,571.41 323,490.38 0.29 -3.30 MWD+SCC+SAG (1) 687.56 1.29 104.20 687.46 590.29 -3.46 10.18 2,633,571.22 323,491.57 0.63 -3.46 MWD+SCC+SAG (1) 747.53 0.90 92.65 747.42 650.25 -3.65 11.31 2,633,571.02 323,492.69 0.74 -3.65 MWD+SCC+SAG (1) 7/132010 9:18:40AM Page 2 COMPASS 2003.16 Build 69 n Ell ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/700') (ft) Survey Tool Name 777.00 0.89 93.35 776.88 679.71 -3.68 11.77 2,633,570.99 323,493.15 0.05 -3.68 MWD+SCC+SAG (1) 844.01 0.96 92.17 843.89 746.72 -3.73 12.85 2,633,570.92 323,494.23 0.11 -3.73 MWD+SCC+SAG (1) 906.41 1.25 94.73 906.27 809.10 -3.80 14.05 2,633,570.83 323,495.43 0.47 -3.80 MWD+SCC+SAG (1) 967.25 1.40 60.24 967.10 869.93 -3.49 15.35 2,633,571.12 323,496.74 1.31 -3.49 MWD+SCC+SAG (1) 1,033.48 2.66 30.44 1,033.29 936.12 -1.76 16.83 2,633,572.82 323,498.25 2.42 -1.76 MWD+SCC+SAG (1) 1,096.65 3.93 15.12 1,096.35 999.18 1.59 18.14 2,633,576.16 323,499.60 2.43 1.59 MWD+SCC+SAG (1) 1,158.72 4.68 2.34 1,158.25 1,061.08 6.18 18.80 2,633,580.73 323,500.33 1.95 6.18 MWD+SCC+SAG (1) 1,220.94 6.02 352.30 1,220.20 1,123.03 11.95 18.47 2,633,586.50 323,500.09 2.62 11.95 MWD+SCC+SAG (1) 1,284.41 7.91 353.26 1,283.20 1,186.03 19.58 17.51 2,633,594.15 323,499.25 2.98 19.58 MWD+SCC+SAG (1) 1,346.66 9.24 351.85 1,344.75 1,247.58 28.78 16.30 2,633,603.37 323,498.18 2.16 28.78 MWD+SCC+SAG (1) 1,411.20 10.08 350.31 1,408.37 1,311.20 39.48 14.61 2,633,614.09 323,496.65 1.36 39.48 MWD+SCC+SAG (1) 1,473.60 9.46 347.39 1,469.87 1,372.70 49.87 12.57 2,633,624.51 323,494.78 1.27 49.87 MWD+SCC+SAG (1) 1,537.25 9.36 345.84 1,532.66 1,435.49 59.99 10.16 2,633,634.67 323,492.52 0.43 59.99 MWD+SCC+SAG (1) 1,601.33 9.08 345.24 1,595.91 1,498.74 69.93 7.60 2,633,644.65 323,490.11 0.46 69.93 MWD+SCC+SAG (1) 1,664.24 9.28 343.87 1,658.02 1,560.85 79.61 4.93 2,633,654.36 323,487.59 0.47 79.61 MWD+SCC+SAG (1) 1,726.45 8.74 348.26 1,719.46 1,622.29 89.05 2.57 2,633,663.84 323,485.38 1.40 89.05 MWD+SCC+SAG (1) 1,789.69 8.78 351.42 1,781.96 1,684.79 98.53 0.87 2,633,673.34 323,483.82 0.76 98.53 MWD+SCC+SAG (1) 1,852.32 8.87 352.80 1,843.85 1,746.68 108.05 -0.44 2,633,682.87 323,482.65 0.37 108.05 MWD+SCC+SAG (1) 1,914.13 8.93 355.99 1,904.92 1,807.75 117.56 -1.38 2,633,692.40 323,481.86 0.80 117.56 MWD+SCC+SAG (1) 1,978.19 9.45 355.93 1,968.16 1,870.99 127.76 -2.10 2,633,702.62 323,481.30 0.81 127.76 MWD+SCC+SAG (1) 2,041.48 9.63 355.15 2,030.57 1,933.40 138.22 -2.91 2,633,713.08 323,480.64 0.35 138.22 MWD+SCC+SAG (1) 2,103.75 8.97 351.53 2,092.02 1,994.85 148.21 -4.07 2,633,723.09 323,479.64 1.42 148.21 MWD+SCC+SAG (1) 2,168.40 8.83 348.34 2,155.89 2,058.72 158.06 -5.81 2,633,732.96 323,478.05 0.79 158.06 MWD+SCC+SAG (1) 2,230.81 9.51 346.92 2,217.51 2,120.34 167.77 -7.95 2,633,742.70 323,476.06 1.15 167.77 MWD+SCC+SAG (1) 2,292.97 8.98 349.01 2,278.86 2,181.69 177.54 -10.04 2,633,752.50 323,474.12 1.01 177.54 MWD+SCC+SAG (1) 2,356.76 8.75 349.22 2,341.89 2,244.72 187.19 -11.89 2,633,762.18 323,472.42 0.36 187.19 MWD+SCC+SAG (1) 2,418.95 9.29 348.48 2,403.31 2,306.14 196.75 -13.78 2,633,771.77 323,470.68 0.89 196.75 MWD+SCC+SAG (1) 2,482.23 9.12 351.58 2,465.77 2,368.60 206.72 -15.53 2,633,781.76 323,469.07 0.83 206.72 MWD+SCC+SAG (1) 2,545.39 8.84 350.47 2,528.16 2,430.99 216.46 -17.07 2,633,791.52 323,467.69 0.52 216.46 MWD+SCC+SAG (1) 2,608.38 7.88 350.94 2,590.48 2,493.31 225.50 -18.55 2,633,800.58 323,466.34 1.53 225.50 MWD+SCC+SAG (1) 2,671.86 7.38 354.27 2,653.40 2,556.23 233.85 -19.64 2,633,808.95 323,465.38 1.05 233.85 MWD+SCC+SAG (1) 2,734.22 6.47 355.08 2,715.30 2,618.13 241.34 -20.35 2,633,816.44 323,464.79 1.47 241.34 MWD+SCC+SAG (1) 2,797.14 5.31 355.76 2,777.89 2,680.72 247.77 -20.87 2,633,822.89 323,464.37 1.85 247.77 MWD+SCC+SAG (1) 2,812.49 4.94 354.56 2,793.18 2,696.01 249.14 -20.98 2,633,824.25 323,464.28 2.51 249.14 MWD+SCC+SAG (1) 2,910.15 3.48 347.93 2,890.57 2,793.40 256.22 -22.00 2,633,831.35 323,463.37 1.57 256.22 MWD+SCC+SAG (2) 2,947.31 2.82 346.29 2,927.67 2,830.50 258.21 -22.45 2,633,833.35 323,462.95 1.79 258.21 MWD+SCC+SAG (2) 3,011.35 2.22 345.83 2,991.65 2,894.48 260.95 -23.13 2,633,836.09 323,462.31 0.94 260.95 MWD+SCC+SAG (2) 3,074.63 1.89 333.69 3,054.89 2,957.72 263.07 -23.89 2,633,838.23 323,461.58 0.86 263.07 MWD+SCC+SAG (2) 3,137.42 1.32 321.97 3,117.66 3,020.49 264.57 -24.80 2,633,839.74 323,460.70 1.04 264.57 MWD+SCC+SAG (2) 3,200.95 1.29 318.45 3,181.17 3,084.00 265.68 -25.72 2,633,840.87 323,459.79 0.13 265.68 MWD+SCC+SAG (2) 7/132010 9:18:40AM Page 3 COMPASS 2003.16 Ba1k169 ' ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 ' Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production ' Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +E1-W Northing Easting DLS Section ' (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (*1100') (ft) Survey Tool Name 3,263.93 1.02 304.28 3,244.14 3,146.97 266.53 -26.65 2,633,841.73 323,458.87 0.62 266.53 MWD+SCC+SAG (2) 3,326.61 0.73 283.57 3,306.81 3,209.64 266.93 -27.50 2,633,842.15 323,458.03 0.68 266.93 MWD+SCC+SAG (2) 3,388.31 0.53 258.29 3,368.51 3,271.34 266.97 -28.16 2,633,842.19 323,457.37 0.55 266.97 MWD+SCC+SAG (2) 3,453.12 1.00 253.83 3,433.31 3,336.14 266.75 -29.00 2,633,841.99 323,456.53 0.73 266.75 MWD+SCC+SAG (2) 3,515.57 0.91 257.62 3,495.75 3,398.58 266.49 -30.01 2,633,841.74 323,455.52 0.18 266.49 MWD+SCC+SAG (2) ' 3,578.51 0.94 248.20 3,558.68 3,461.51 266.19 -30.98 2,633,841.46 323,454.55 0.25 266.19 MWD+SCC+SAG (2) 3,641.83 0.79 237.19 3,622.00 3,524.83 265.76 -31.83 2,633,841.04 323,453.69 0.35 265.76 MWD+SCC+SAG (2) 3,705.21 0.92 246.88 3,685.37 3,588.20 265.33 -32.66 2,633,840.62 323,452.85 0.31 265.33 MWD+SCC+SAG (2) 3,768.63 0.84 264.66 3,748.78 3,651.61 265.08 -33.59 2,633,840.39 323,451.91 0.45 265.08 MWD+SCC+SAG (3) 3,827.07 0.70 250.18 3,807.22 3,710.05 264.92 -34.35 2,633,840.24 323,451.15 0.41 264.92 MWD+SCC+SAG (3) 3,891.75 0.82 255.46 3,871.89 3,774.72 264.67 -35.17 2,633,840.00 323,450.33 0.21 264.67 MWD+SCC+SAG (3) 3,954.23 0.87 252.93 3,934.37 3,837.20 264.42 -36.06 2,633,839.77 323,449.44 0.10 264.42 MWD+SCC+SAG (3) ' 4,018.08 0.66 270.03 3,998.21 3,901.04 264.28 -36.89 2,633,839.64 323,448.60 0.48 264.28 MWD+SCC+SAG (3) 4,081.49 0.79 280.88 4,061.61 3,964.44 264.36 -37.69 2,633,839.73 323,447.81 0.30 264.36 MWD+SCC+SAG (3) 4,143.50 0.84 279.67 4,123.62 4,026.45 264.52 -38.55 2,633,839.90 323,446.94 0.09 264.52 MWD+SCC+SAG (3) ' 4,208.72 0.62 281.17 4,188.83 4,091.66 264.67 -39.37 2,633,840.06 323,446.13 0.34 264.67 MWD+SCC+SAG(3) 4,269.90 0.73 282.22 4,250.01 4,152.84 264.81 -40.08 2,633,840.22 323,445.43 0.18 264.81 MWD+SCC+SAG (3) 4,334.54 0.63 282.42 4,314.64 4,217.47 264.98 -40.83 2,633,840.40 323,444.68 0.15 264.98 MWD+SCC+SAG (3) ' 4,396.54 0.65 292.94 4,376.64 4,279.47 265.19 -41.48 2,633,840.62 323,444.03 0.19 265.19 MWD+SCC+SAG (3) 4,461.14 0.44 289.48 4,441.24 4,344.07 265.41 -42.05 2,633,840.85 323,443.46 0.33 265.41 MWD+SCC+SAG (3) 4,523.51 0.40 288.41 4,503.61 4,406.44 265.56 -42.49 2,633,841.01 323,443.03 0.07 265.56 MWD+SCC+SAG (3) ' 4,585.73 0.34 294.18 4,565.82 4,468.65 265.71 -42.86 2,633,841.16 323,442.66 0.11 265.71 MWD+SCC+SAG (3) 4,648.74 0.42 293.31 4,628.83 4,531.66 265.87 -43.24 2,633,841.33 323,442.28 0.13 265.87 MWD+SCC+SAG (3) 4,712.36 0.34 282.82 4,692.45 4,595.28 266.01 -43.64 2,633,841.47 323,441.88 0.17 266.01 MWD+SCC+SAG (3) 4,774.68 0.48 287.51 4,754.77 4,657.60 266.13 -44.07 2,633,841.60 323,441.45 0.23 266.13 MWD+SCC+SAG (3) 4,837.27 0.55 273.19 4,817.36 4,720.19 266.22 -44.62 2,633,841.70 323,440.90 0.23 266.22 MWD+SCC+SAG (3) 4,901.63 0.61 287.97 4,881.71 4,784.54 266.35 -45.26 2,633,841.83 323,440.27 0.25 266.35 MWD+SCC+SAG (3) ' 4,964.67 0.56 306.27 4,944.75 4,847.58 266.63 -45.82 2,633,842.13 323,439.71 0.31 266.63 MWD+SCC+SAG (3) 5,027.16 0.50 311.93 5,007.24 4,910.07 266.99 -46.27 2,633,842.50 323,439.27 0.13 266.99 MWD+SCC+SAG (3) 5,089.91 0.42 295.35 5,069.99 4,972.82 267.28 -46.68 2,633,842.78 323,438.86 0.25 267.28 MWD+SCC+SAG (3) 5,152.87 0.46 277.35 5,132.94 5,035.77 267.41 -47.14 2,633,842.92 323,438.40 0.23 267.41 MWD+SCC+SAG (3) 5,216.03 0.36 293.27 5,196.10 5,098.93 267.52 -47.58 2,633,843.04 323,437.97 0.24 267.52 MWD+SCC+SAG (3) 5,279.28 0.44 284.13 5,259.35 5,162.18 267.66 -47.99 2,633,843.18 323,437.55 0.16 267.66 MWD+SCC+SAG (3) ' 5,341.90 0.29 321.97 5,321.97 5,224.80 267.84 -48.33 2,633,843.37 323,437.23 0.44 267.84 MWD+SCC+SAG (3) 5,405.81 0.29 355.00 5,385.88 5,288.71 268.13 -48.44 2,633,843.66 323,437.12 0.26 268.13 MWD+SCC+SAG (3) 5,468.70 0.37 351.18 5,448.77 5,351.60 268.49 -48.48 2,633,844.02 323,437.08 0.13 268.49 MWD+SCC+SAG (3) 5,531.85 0.40 347.16 5,511.92 5,414.75 268.90 -48.56 2,633,844.44 323,437.00 0.06 268.90 MWD+SCC+SAG (3) 5,595.10 0.30 334.08 5,575.17 5,478.00 269.27 -48.69 2,633,844.81 323,436.89 0.20 269.27 MWD+SCC+SAG (3) 5,657.37 0.28 337.69 5,637.43 5,540.26 269.56 -48.82 2,633,845.10 323,436.76 0.04 269.56 MWD+SCC+SAG (3) 5,720.22 0.24 310.29 5,700.28 5,603.11 269.78 -48.97 2,633,845.32 323,436.61 0.21 269.78 MWD+SCC+SAG (3) ' 7/1311010 9:18:40AM Page 4 COMPASS 2003.16 Build 69 r C 0 u ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: ConocoPhillips(Alaska) Inc. Beluga River Beluga River BRU 212-24T BRU 212-24T BRU 212-24T Local Co-ordinate Reference: Well BRU 212-24T TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting US Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (*1100') (ft) Survey Tool Name 5,782.95 0.27 304.08 5,763.01 5,665.84 269.95 -49.20 2,633,845.50 323,436.39 0.06 269.95 MWD+SCC+SAG (3) 5,846.35 0.28 298.07 5,826.41 5,729.24 270.11 -49.46 2,633,845.66 323,436.13 0.05 270.11 MWD+SCC+SAG (3) 5,909.81 0.15 297.74 5,889.87 5,792.70 270.22 -49.67 2,633,845.77 323,435.92 0.20 270.22 MWD+SCC+SAG (3) 5,971.80 0.06 311.83 5,951.86 5,854.69 270.28 -49.76 2,633,845.83 323,435.83 0.15 270.28 MWD+SCC+SAG (3) 6,035.70 0.09 243.71 6,015.76 5,918.59 270.28 -49.83 2,633,845.83 323,435.76 0.14 270.28 MWD+SCC+SAG (3) 6,098.58 0.16 163.54 6,078.64 5,981.47 270.17 -49.85 2,633,845.73 323,435.73 0.27 270.17 MWD+SCC+SAG (3) 6,161.02 0.18 188.05 6,141.08 6,043.91 269.99 -49.84 2,633,845.55 323,435.74 0.12 269.99 MWD+SCC+SAG (3) 6,225.07 0.10 115.77 6,205.13 6,107.96 269.87 -49.81 2,633,845.42 323,435.78 0.28 269.87 MWD+SCC+SAG (3) 6,287.45 0.29 108.63 6,267.51 6,170.34 269.79 -49.61 2,633,845.35 323,435.97 0.31 269.79 MWD+SCC+SAG (3) 6,347.90 0.31 88.27 6,327.96 6,230.79 269.75 -49.30 2,633,845.30 323,436.28 0.18 269.75 MWD+SCC+SAG (3) 6,411.59 0.46 104.10 6,391.65 6,294.48 269.69 -48.88 2,633,845.23 323,436.70 0.29 269.69 MWD+SCC+SAG (3) 6,473.56 0.50 122.89 6,453.62 6,356.45 269.48 48.41 2,633,845.02 323,437.17 0.26 269.48 MWD+SCC+SAG (3) 6,565.00 0.50 122.89 6,545.05 6,447.88 269.05 -47.74 2,633,844.58 323,437.83 0.00 269.05 PROJECTED to TD 7/13/2010 9:18:40AM COMPASS 2003.16 Build 89 n L r F', ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River BRU 212-24T !ern" rw%V Drilling Rervices Definitive Survey Report 13 July, 2010 HALLIBURTON Sperry Grilling Services Company: ConocoPhillips (Alaska) Inc. -Expl Project: Beluga River Site: Beluga River Well: BRU 212-24T Wellbore: BRU 212-24T Design: BRU 212-24T ConocoPhlllips (Alaska) Inc. Definitive Survey Report Local Co-ordinate Reference: Well BRU 212-24T TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Project Beluga River, Alaska, USA Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well BRU 212-24T Well Position +N/ -S +E/ -W Position Uncertainty 0.00 ft 0.00 ft 0.00 ft Northing: Easting: Wellhead Elevation: 2,633,335.21 It 1,463,508.87 It 18.50 It Latitude: 61' 12'14.378 N Longitude: 151' 0' 11.272 W Ground Level: 78.67 ft Wellbore BRU 212-24T (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 147.07 Magnetics Model Name MWD + Short Collar correction + BHA SAG Co 6/15/2010 1: Sample Date Declination Dip Angle Field Strength MWD + Short Collar correction + BHA SAG Co 6/23/2010 1: 3,768.63 6,473.56 BRU 212-24T (R300) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/29/2010 1; (°) (°) (ft) BGGM2009 6/20/2010 (ft) 18.57 74.03 55,737 Design BRU 212-24T 18.50 0.00 0.00 18.50 -78.67 Audit Notes: 0.00 2,633,335.21 1,463,508.87 0.00 0.00 UNDEFINED 147.07 Version: 1.0 147.06 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: 1,463,509.96 Depth From (TVD) +N/ -S +E/ -W Direction 204.92 107.75 -1.48 (ft) (ft) (ft) (°) -1.48 MWD+SCC+SAG (1) 265.26 1.37 18.50 0.00 0.00 0.00 Survey Program Date 7/13/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 147.07 2,812.49 BRU 212-24T (R100) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/15/2010 1: 2,910.15 3,705.21 BRU 212-24T (R200) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/23/2010 1: 3,768.63 6,473.56 BRU 212-24T (R300) (BRU 212-24T) MWD+SCC+SAG MWD + Short Collar correction + BHA SAG Co 6/29/2010 1; Survey 7/132010 9:12.02AM Page 2 COMPASS 2003.16 Build 69 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I7oq (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -78.67 0.00 0.00 2,633,335.21 1,463,508.87 0.00 0.00 UNDEFINED 147.07 1.19 124.46 147.06 49.89 -0.76 1.10 2,633,334.44 1,463,509.96 0.93 -0.76 MWD+SCC+SAG (1) 204.94 1.13 132.06 204.92 107.75 -1.48 2.02 2,633,333.70 1,463,510.87 0.29 -1.48 MWD+SCC+SAG (1) 265.26 1.37 131.28 265.22 168.05 -2.35 3.00 2,633,332.81 1,463,511.84 0.40 -2.35 MWD+SCC+SAG (1) 324.86 0.70 101.60 324.81 227.64 -2.90 3.90 2,633,332.26 1,463,512.72 1.40 -2.90 MWD+SCC+SAG (1) 389.37 0.77 93.44 389.32 292.15 -3.00 4.71 2,633,332.14 1,463,513.54 0.19 -3.00 MWD+SCC+SAG (1) 447.80 1.08 88.76 447.74 350.57 -3.01 5.66 2,633,332.11 1,463,514.48 0.55 -3.01 MWD+SCC+SAG (1) 509.63 1.00 97.65 509.56 412.39 -3.07 6.77 2,633,332.04 1,463,515.60 0.29 -3.07 MWD+SCC+SAG (1) 569.35 1.14 97.46 569.27 472.10 -3.22 7.88 2,633,331.87 1,463,516.70 0.23 -3.22 MWD+SCC+SAG (1) 628.04 1.04 90.30 627.95 530.78 -3.30 8.99 2,633,331.78 1,463,517.81 0.29 -3.30 MWD+SCC+SAG (1) 687.56 1.29 104.20 687.46 590.29 -3.46 10.18 2,633,331.59 1,463,519.00 0.63 -3.46 MWD+SCC+SAG (1) 747.53 0.90 92.65 747.42 650.25 -3.65 11.31 2,633,331.39 1,463,520.12 0.74 -3.65 MWD+SCC+SAG (1) 7/132010 9:12.02AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Expl Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 777.00 0.89 93.35 776.88 679.71 -3.68 11.77 2,633,331.36 1,463,520.58 0.05 -3.68 MWD+SCC+SAG (1) 844.01 0.96 92.17 843.89 746.72 -3.73 12.85 2,633,331.29 1,463,521.66 0.11 -3.73 MWD+SCC+SAG (1) 906.41 1.25 94.73 906.27 809.10 -3.80 14.05 2,633,331.19 1,463,522.86 0.47 -3.80 MWD+SCC+SAG (1) 967.25 1.40 60.24 967.10 869.93 -3.49 15.35 2,633,331.49 1,463,524.17 1.31 -3.49 MWD+SCC+SAG (1) 1,033.48 2.66 30.44 1,033.29 936.12 -1.76 16.83 2,633,333.19 1,463,525.67 2.42 -1.76 MWD+SCC+SAG (1) 1,096.65 3.93 15.12 1,096.35 999.18 1.59 18.14 2,633,336.52 1,463,527.03 2.43 1.59 MWD+SCC+SAG (1) 1,158.72 4.68 2.34 1,158.25 1,061.08 6.18 18.80 2,633,341.10 1,463,527.76 1.95 6.18 MWD+SCC+SAG (1) 1,220.94 6.02 352.30 1,220.20 1,123.03 11.95 18.47 2,633,346.87 1,463,527.52 2.62 11.95 MWD+SCC+SAG (1) 1,284.41 7.91 353.26 1,283.20 1,186.03 19.58 17.51 2,633,354.52 1,463,526.67 2.98 19.58 MWD+SCC+SAG (1) 1,346.66 9.24 351.85 1,344.75 1,247.58 28.78 16.30 2,633,363.74 1,463,525.60 2.16 28.78 MWD+SCC+SAG (1) 1,411.20 10.08 350.31 1,408.37 1,311.20 39.48 14.61 2,633,374.46 1,463,524.08 1.36 39.48 MWD+SCC+SAG (1) 1,473.60 9.46 347.39 1,469.87 1,372.70 49.87 12.57 2,633,384.88 1,463,522.21 1.27 49.87 MWD+SCC+SAG (1) 1,537.25 9.36 345.84 1,532.66 1,435.49 59.99 10.16 2,633,395.03 1,463,519.95 0.43 59.99 MWD+SCC+SAG (1) 1,601.33 9.08 345.24 1,595.91 1,498.74 69.93 7.60 2,633,405.01 1,463,517.54 0.46 69.93 MWD+SCC+SAG (1) 1,664.24 9.28 343.87 1,658.02 1,560.85 79.61 4.93 2,633,414.73 1,463,515.02 0.47 79.61 MWD+SCC+SAG (1) 1,726.45 8.74 348.26 1,719.46 1,622.29 89.05 2.57 2,633,424.21 1,463,512.81 1.40 89.05 MWD+SCC+SAG (1) 1,789.69 8.78 351.42 1,781.96 1,684.79 98.53 0.87 2,633,433.71 1,463,511.26 0.76 98.53 MWD+SCC+SAG (1) 1,852.32 8.87 352.80 1,843.85 1,746.68 108.05 -0.44 2,633,443.24 1,463,510.08 0.37 108.05 MWD+SCC+SAG (1) 1,914.13 8.93 355.99 1,904.92 1,807.75 117.56 -1.38 2,633,452.77 1,463,509.30 0.80 117.56 MWD+SCC+SAG (1) 1,978.19 9.45 355.93 1,968.16 1,870.99 127.76 -2.10 2,633,462.98 1,463,508.73 0.81 127.76 MWD+SCC+SAG (1) 2,041.48 9.63 355.15 2,030.57 1,933.40 138.22 -2.91 2,633,473.45 1,463,508.08 0.35 138.22 MWD+SCC+SAG (1) 2,103.75 8.97 351.53 2,092.02 1,994.85 148.21 4.07 2,633,483.46 1,463,507.08 1.42 148.21 MWD+SCC+SAG (1) 2,168.40 8.83 348.34 2,155.89 2,058.72 158.06 -5.81 2,633,493.33 1,463,505.48 0.79 158.06 MWD+SCC+SAG (1) 2,230.81 9.51 346.92 2,217.51 2,120.34 167.77 -7.95 2,633,503.07 1,463,503.50 1.15 167.77 MWD+SCC+SAG (1) 2,292.97 8.98 349.01 2,278.86 2,181.69 177.54 -10.04 2,633,512.87 1,463,501.56 1.01 177.54 MWD+SCC+SAG (1) 2,356.76 8.75 349.22 2,341.89 2,244.72 187.19 -11.89 2,633,522.55 1,463,499.85 0.36 187.19 MWD+SCC+SAG (1) 2,418.95 9.29 348.48 2,403.31 2,306.14 196.75 -13.78 2,633,532.14 1,463,498.11 0.89 196.75 MWD+SCC+SAG (1) 2,482.23 9.12 351.58 2,465.77 2,368.60 206.72 -15.53 2,633,542.13 1,463,496.51 0.83 206.72 MWD+SCC+SAG (1) 2,545.39 8.84 350.47 2,528.16 2,430.99 216.46 -17.07 2,633,551.89 1,463,495.12 0.52 216.46 MWD+SCC+SAG (1) 2,608.38 7.88 350.94 2,590.48 2,493.31 225.50 -18.55 2,633,560.95 1,463,493.78 1.53 225.50 MWD+SCC+SAG (1) 2,671.86 7.38 354.27 2,653.40 2,556.23 233.85 -19.64 2,633,569.32 1,463,492.82 1.05 233.85 MWD+SCC+SAG (1) 2,734.22 6.47 355.08 2,715.30 2,618.13 241.34 -20.35 2,633,576.81 1,463,492.23 1.47 241.34 MWD+SCC+SAG (1) 2,797.14 5.31 355.76 2,777.89 2,680.72 247.77 -20.87 2,633,583.26 1,463,491.81 1.85 247.77 MWD+SCC+SAG (1) 2,812.49 4.94 354.56 2,793.18 2,696.01 249.14 -20.98 2,633,584.62 1,463,491.72 2.51 249.14 MWD+SCC+SAG (1) 2,910.15 3.48 347.93 2,890.57 2,793.40 256.22 -22.00 2,633,591.72 1,463,490.81 1.57 256.22 MWD+SCC+SAG (2) 2,947.31 2.82 346.29 2,927.67 2,830.50 258.21 -22.45 2,633,593.72 1,463,490.38 1.79 258.21 MWD+SCC+SAG (2) 3,011.35 2.22 345.83 2,991.65 2,894.48 260.95 -23.13 2,633,596.46 1,463,489.75 0.94 260.95 MWD+SCC+SAG (2) 3,074.63 1.89 333.69 3,054.89 2,957.72 263.07 -23.89 2,633,598.60 1,463,489.02 0.86 263.07 MWD+SCC+SAG (2) 3,137.42 1.32 321.97 3,117.66 3,020.49 264.57 -24.80 2,633,600.11 1,463,488.14 1.04 264.57 MWD+SCC+SAG (2) 3,200.95 1.29 318.45 3,181.17 3,084.00 265.68 -25.72 2,633,601.24 1,463,487.23 0.13 265.68 MWD+SCC+SAG (2) 7/13/2010 9:12:02AM Page 3 COMPASS 2003.16 Build 69 ' ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Expl Local Co-ordinate Reference: Well BRU 212-24T Project: Beluga River TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Site: Beluga River MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 Well: BRU 212-24T North Reference: True Wellbore: BRU 212-24T Survey Calculation Method: Minimum Curvature Design: BRU 212-24T Database: CPAI EDM Production ' Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section ' (ft) (0) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,263.93 1.02 304.28 3,244.14 3,146.97 266.53 -26.65 2,633,602.10 1,463,486.31 0.62 266.53 MWD+SCC+SAG (2) 3,326.61 0.73 283.57 3,306.81 3,209.64 266.93 -27.50 2,633,602.52 1,463,485.47 0.68 266.93 MWD+SCC+SAG (2) ' 3,388.31 0.53 258.29 3,368.51 3,271.34 266.97 -28.16 2,633,602.56 1,463,484.81 0.55 266.97 MWD+SCC+SAG (2) 3,453.12 1.00 253.83 3,433.31 3,336.14 266.75 -29.00 2,633,602.36 1,463,483.97 0.73 266.75 MWD+SCC+SAG (2) 3,515.57 0.91 257.62 3,495.75 3,398.58 266.49 -30.01 2,633,602.11 1,463,482.95 0.18 266.49 MWD+SCC+SAG (2) 3,578.51 0.94 248.20 3,558.68 3,461.51 266.19 -30.98 2,633,601.83 1,463,481.98 0.25 266.19 MWD+SCC+SAG (2) 3,641.83 0.79 237.19 3,622.00 3,524.83 265.76 -31.83 2,633,601.41 1,463,481.13 0.35 265.76 MWD+SCC+SAG (2) 3,705.21 0.92 246.88 3,685.37 3,588.20 265.33 -32.66 2,633,600.99 1,463,480.29 0.31 265.33 MWD+SCC+SAG (2) 3,768.63 0.84 264.66 3,748.78 3,651.61 265.08 -33.59 2,633,600.76 1,463,479.35 0.45 265.08 MWD+SCC+SAG (3) 3,827.07 0.70 250.18 3,807.22 3,710.05 264.92 -34.35 2,633,600.61 1,463,478.59 0.41 264.92 MWD+SCC+SAG (3) 3,891.75 0.82 255.46 3,871.89 3,774.72 264.67 -35.17 2,633,600.37 1,463,477.76 0.21 264.67 MWD+SCC+SAG (3) 3,954.23 0.87 252.93 3,934.37 3,837.20 264.42 -36.06 2,633,600.14 1,463,476.87 0.10 264.42 MWD+SCC+SAG (3) ' 4,018.08 0.66 270.03 3,998.21 3,901.04 264.28 -36.89 2,633,600.01 1,463,476.04 0.48 264.28 MWD+SCC+SAG (3) 4,081.49 0.79 280.88 4,061.61 3,964.44 264.36 -37.69 2,633,600.10 1,463,475.25 0.30 264.36 MWD+SCC+SAG (3) 4,143.50 0.84 279.67 4,123.62 4,026.45 264.52 -38.55 2,633,600.27 1,463,474.38 0.09 264.52 MWD+SCC+SAG (3) 4,208.72 0.62 281.17 4,188.83 4,091.66 264.67 -39.37 2,633,600.43 1,463,473.57 0.34 264.67 MWD+SCC+SAG(3) 4,269.90 0.73 282.22 4,250.01 4,152.84 264.81 -40.08 2,633,600.59 1,463,472.86 0.18 264.81 MWD+SCC+SAG (3) 4,334.54 0.63 282.42 4,314.64 4,217.47 264.98 -40.83 2,633,600.77 1,463,472.12 0.15 264.98 MWD+SCC+SAG (3) 4,396.54 0.65 292.94 4,376.64 4,279.47 265.19 -41.48 2,633,600.99 1,463,471.46 0.19 265.19 MWD+SCC+SAG (3) 4,461.14 0.44 289.48 4,441.24 4,344.07 265.41 -42.05 2,633,601.22 1,463,470.90 0.33 265.41 MWD+SCC+SAG (3) 4,523.51 0.40 288.41 4,503.61 4,406.44 265.56 -42.49 2,633,601.38 1,463,470.47 0.07 265.56 MWD+SCC+SAG (3) 4,585.73 0.34 294.18 4,565.82 4,468.65 265.71 -42.86 2,633,601.52 1,463,470.09 0.11 265.71 MWD+SCC+SAG (3) 4,648.74 0.42 293.31 4,628.83 4,531.66 265.87 -43.24 2,633,601.70 1,463,469.71 0.13 265.87 MWD+SCC+SAG (3) 4,712.36 0.34 282.82 4,692.45 4,595.28 266.01 -43.64 2,633,601.84 1,463,469.32 0.17 266.01 MWD+SCC+SAG (3) ' 4,774.68 0.48 287.51 4,754.77 4,657.60 266.13 -44.07 2,633,601.97 1,463,468.89 0.23 266.13 MWD+SCC+SAG (3) 4,837.27 0.55 273.19 4,817.36 4,720.19 266.22 -44.62 2,633,602.07 1,463,468.34 0.23 266.22 MWD+SCC+SAG (3) 4,901.63 0.61 287.97 4,881.71 4,784.54 266.35 -45.26 2,633,602.20 1,463,467.71 0.25 266.35 MWD+SCC+SAG (3) ' 4,964.67 0.56 306.27 4,944.75 4,847.58 266.63 -45.82 2,633,602.50 1,463,467.15 0.31 266.63 MWD+SCC+SAG (3) 5,027.16 0.50 311.93 5,007.24 4,910.07 266.99 -46.27 2,633,602.87 1,463,466.70 0.13 266.99 MWD+SCC+SAG (3) 5,089.91 0.42 295.35 5,069.99 4,972.82 267.28 -46.68 2,633,603.15 1,463,466.30 0.25 267.28 MWD+SCC+SAG (3) ' 5,152.87 0.46 277.35 5,132.94 5,035.77 267.41 -47.14 2,633,603.29 1,463,465.84 0.23 267.41 MWD+SCC+SAG (3) 5,216.03 0.36 293.27 5,196.10 5,098.93 267.52 -47.58 2,633,603.41 1,463,465.41 0.24 267.52 MWD+SCC+SAG (3) 5,279.28 0.44 284.13 5,259.35 5,162.18 267.66 -47.99 2,633,603.55 1,463,464.99 0.16 267.66 MWD+SCC+SAG (3) 5,341.90 0.29 321.97 5,321.97 5,224.80 267.84 -48.33 2,633,603.74 1,463,464.66 0.44 267.84 MWD+SCC+SAG (3) 5,405.81 0.29 355.00 5,385.88 5,288.71 268.13 -48.44 2,633,604.03 1,463,464.55 0.26 268.13 MWD+SCC+SAG (3) 5,468.70 0.37 351.18 5,448.77 5,351.60 268.49 -48.48 2,633,604.39 1,463,464.51 0.13 268.49 MWD+SCC+SAG (3) 5,531.85 0.40 347.16 5,511.92 5,414.75 268.90 -48.56 2,633,604.81 1,463,464.44 0.06 268.90 MWD+SCC+SAG (3) 5,595.10 0.30 334.08 5,575.17 5,478.00 269.27 -48.69 2,633,605.18 1,463,464.32 0.20 269.27 MWD+SCC+SAG (3) 5,657.37 0.28 337.69 5,637.43 5,540.26 269.56 -48.82 2,633,605.46 1,463,464.20 0.04 269.56 MWD+SCC+SAG (3) 5,720.22 0.24 310.29 5,700.28 5,603.11 269.78 -48.97 2,633,605.69 1,463,464.04 0.21 269.78 MWD+SCC+SAG (3) ' 7/13/2010 9:12:02AM Page 4 COMPASS 2003.16 Build 69 C 1 0 fl L ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: ConocoPhiilips (Alaska) Inc. -Expl Beluga River Beluga River BRU 212-24T BRU 212-24T BRU 212-24T Local Co-ordinate Reference: Well BRU 212-24T TVD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 MD Reference: Plan: BRU 212.24T @ 97.17ft (Arctic Fox (18.5+7 North Reference: True Survey Calculation Method: Minimum Curvature Database: CPA[ EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (1 (0) (ft) (ft) (ft) (ft) (ft) (ft) (°Hol)') (ft) Survey Tool Name 5,782.95 0.27 304.08 5,763.01 5,665.84 269.95 49.20 2,633,605.87 1,463,463.82 0.06 269.95 MWD+SCC+SAG (3) 5,846.35 0.28 298.07 5,826.41 5,729.24 270.11 -49.46 2,633,606.03 1,463,463.57 0.05 270.11 MWD+SCC+SAG (3) 5,909.81 0.15 297.74 5,889.87 5,792.70 270.22 -49.67 2,633,606.14 1,463,463.36 0.20 270.22 MWD+SCC+SAG (3) 5,971.80 0.06 311.83 5,951.86 5,854.69 270.28 49.76 2,633,606.20 1,463,463.26 0.15 270.28 MWD+SCC+SAG (3) 6,035.70 0.09 243.71 6,015.76 5,918.59 270.28 -49.83 2,633,606.20 1,463,463.19 0.14 270.28 MWD+SCC+SAG (3) 6,098.58 0.16 163.54 6,078.64 5,981.47 270.17 -49.85 2,633,606.10 1,463,463.17 0.27 270.17 MWD+SCC+SAG (3) 6,161.02 0.18 188.05 6,141.08 6,043.91 269.99 -49.84 2,633,605.92 1,463,463.18 0.12 269.99 MWD+SCC+SAG (3) 6,225.07 0.10 115.77 6,205.13 6,107.96 269.87 -49.81 2,633,605.79 1,463,463.21 0.28 269.87 MWD+SCC+SAG (3) 6,287.45 0.29 108.63 6,267.51 6,170.34 269.79 -49.61 2,633,605.71 1,463,463.41 0.31 269.79 MWD+SCC+SAG (3) 6,347.90 0.31 88.27 6,327.96 6,230.79 269.75 -49.30 2,633,605.67 1,463,463.72 0.18 269.75 MWD+SCC+SAG (3) 6,411.59 0.46 104.10 6,391.65 6,294.48 269.69 -48.88 2,633,605.60 1,463,464.14 0.29 269.69 MWD+SCC+SAG (3) 6,473.56 0.50 122.89 6,453.62 6,356.45 269.48 -48.41 2,633,605.39 1,463,464.60 0.26 269.48 MWD+SCC+SAG (3) 6,565.00 0.50 122.89 6,545.05 6,447.88 269.05 -47.74 2,633,604.94 1,463,465.27 0.00 269.05 PROJECTED to TD 7/13/1010 9:12:02AM Page 5 COMPASS 2003.16 Build 69 HALLIBURTON Sperry Drilling CPAI BRU 212-24T Days -vs- Depth 0OL -T 7. •- - I , Pm 13 -June -2010 **:: 10 0 0 MOMMI nocoPhilfips----�' mi i _AiaSka Inc- 1 1 1 MLIME (on Location W (09 -Jan -2010 2000 MINIM Drill 8.75" Hole, Se7tion i 3000 MINIM mm INIMMILIM MM 5/8" Casing to IMIMMIKI MID, 2840'TVD] MINIM IMPAF 4000 .0 Q. 3863'TVD IN 5000 L Short Trip f MID to 3883'75" Hole SectionNIN C 6000 SlhotTrip4ro 5803' MINE IN MINIM 7000 IN IN Prognosed MINIM MEN Run 7" Casing to IMINIMINIMINIM, 8000 9000 IMINIMININIMINIMIN MINIM 10000 0 4 8 12 16 20 24 Rig Days .lei 1 1 - 1 1 1 1 1 HALLIBURTON I OP --y mri"irag BRU 212-24T API 50-283-20136-00-00 Digital Data EMF & PDF Logs ADI LAS Files End of Well Report Halliburton Log Viewer EMF Viewer Conoc Phillips Alaska, Inc.