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207-151
1a. 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): Deep Creek Unit GL: 593' BF:N/A Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27):11. Total Depth MD/TVD: 19. DNR Approval Number: Surface:x- y- Zone- 4 TPI:x- y- Zone- 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD: Total Depth:x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 16" X-56 117' 9-5/8"L-80 1,105' 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 1,157'40# Surface N/A SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface 12-1/4" Driven Surface L - 220 sx / T - 187 sx Surface109# STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 2/14/2025 207-151 / 324-614 2189601 TOP HOLE SIZE 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 223690 2190972 50-231-20032-00-00December 4, 2007 N/A HVB-13December 22, 20072920' FNL, 337' FEL, Sec 21, T2S, R13W, SM, AK 611' Beluga/Tyonek Gas Pool C061589 7,747' MD / 6,913' TVD 1,200' MD / 1,140' TVD N/A Gas-Oil Ratio: Per 20 AAC 25.283 (i)(2) attach electronic information CASING, LINER AND CEMENTING RECORD 4327' FNL, 1893' FEL, Sec 21, T2S, R13W, SM, AK 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, AMOUNT PULLED N/A 222103 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. N/A N/A 1,200' MD / 1,140' TVD N/A SETTING DEPTH TVD BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORD 117' PACKER SET (MD/TVD) Driven TUBING RECORD ACID, FRACTURE, CEMENT SQUEEZE, ETC. Sr Res EngSr Pet Geo Choke Size:Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: N/A Sr Pet Eng Oil-Bbl:Water-Bbl:Flow Tubing G s d 1 0 p dB P L s (att Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 2:01 pm, May 16, 2025 Abandoned 2/14/2025 JSB RBDMS JSB 052725 xGDSR-6/3/25BJM 11/11/25 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval N/A N/A 7,674' 6,843' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)FORMATION TESTS Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. INSTRUCTIONS Wellbore Schematic, PreDrill and P&A Reports Authorized Title: Drilling Manager Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. T 19 N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.05.16 13:43:52 - 08'00' Sean McLaughlin (4311) Updated by CJD 5-16-25 Happy Valley Well HVB-13 PTD: 207-151 API: 50-231-20032-00-00 P&A Schematic PERFORATIONS (PLUGGED) Zone Top MD Btm MD Top TVD Btm TVD Amt Status Date BLG-10 3,282’3,296’2,508’2,518’18’Isolated 4/10/2024 BLG-29 3,798'3,810 2,975'2,987'12'Isolated 5/23/2012 BLG-36 4,028'4,054'3,200'3,225'26'Isolated 5/23/2012 BLG-40 4,208'4,227'3,379'3,398'19'Isolated 5/23/2012 BLG-46 4,821’4,829’3,992’4,006’8 Isolated 4/17/2019 BLG-130 6,362'6,382'5,532'5,552'20'Isolated 3/30/2009 T-2B 6,660'6,670'5,830'5,840'10'Isolated 3/30/2009 T-5 6,715'6,725'5,885'5,895'10'Isolated 3/29/2009 T-6 6,828'6,838'5,998'6,008'10'Isolated 3/29/2009 T-7A 6,970'6,990'6,140'6,160'20'Isolated 3/29/2009 T-7B 7,010'7,030'6,180'6,200'20'Isolated 3/29/2009 T-10 7,154'7,164'6,324'6,334'10'Frac'd/ Isolated 5/28/2009 7,189'7,197'6,359'6,349'8'Isolated 3/17/2009 T-13 7,322'7,340'6,492'6,510'18'Isolated 3/15/2009 T-17 7,478'7,511'6,648'6,681'33'Isolated 4/3/2008 7,479.6'7,511'6,649'6,681'31.6'Isolated 4/5/2008 7,520'7,532'6,690'6,702'12'Isolated 4/8/2008 CASING DETAIL Size Type Wt/ Grade CONN/ID Top Btm Length TOC 16" Conductor 109#, X-56 Weld/ 14.688"Surface 117’ 117’Driven 9-5/8” Surface 40#, L-80 BTC-Mod/ 8.835”Surface 1,157’1,157' 0 7”Intermediate 26#, L-80 BTC-Mod/ 6.276”1,279’ (cut)3,645’2,366'2,766' 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”3,500'7,747'4,247’3,500' TUBING DETAIL 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”Surface 3,523'3,523’ N/A JEWELRY DETAIL No.Description Depth Length ID OD Open Hole Whipstock 1,200’ 1 7” CIBP 2,396 1a CIBP w 25’ cement cap – TOC @ 3247’3,272’ 2 Cement retainer (12/11/23)3,465’ 3 Tubing Punch (11/22/13) 3,490’-3,495’ 3,490’ 4 7" Baker ZXP packer w Flex Lock Hanger (12/2007)3,500'17' 5.25" 6" 5 10-408 Seal Assembly (set 12/2007)3,523'9.27' 4" 5" 6 CIBP w 23’ cement cap – TOC @ 3,765’ (11/22/23) 3,788’ 7 Owen X-Span patch (22')3,792'22' 2.375" 2.992" 8 Composite Bridge Plug 7,175'2.08' - - 9 Sand fill (Tagged w/ Eline on 5/23/12)7,156'--- 10 WRP 7,400'3.83' - - 11 PBTD- Top of 3-1/2" float equipment (not tagged)7,679'--- Page 1/1 Well Name: DCU HVB-013 Report Printed: 3/4/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-231-20032-00-00 Field Name:Deep Creek Unit State/Province:ALASKA Permit to Drill (PTD) #:207-151 Sundry #:324-614 Rig Name/No:401 Jobs Actual Start Date:11/18/2024 End Date:11/24/2024 Report Number 1 Report Start Date 11/18/2024 Report End Date 11/19/2024 Last 24hr Summary MIRU YJ Eline. PT Lube 250 low/2500 high- pass.RIH w/ CCL and 2.75" CIBP, sat down @ 3287'. Set CIBP @ 3272'. Tag plug and log off. POOH. Test plug per AOGCC to 1500 psi- pass. RIH w/ 25' x 2.5" cement dump bailer for 12.5' of fill, TOC = 3259.5'. RIH w/ 25' x 2.5" cement dump bailer for 12.5' of fill, TOC = 3247'. RDMO Report Number 2 Report Start Date 11/21/2024 Report End Date 11/22/2024 Last 24hr Summary RDMO CLU-10rd, move Rig & eq t/HVB-13. Prep wellhead area and pad. Layout liner, spot base beam, spot carrier. Prep carrier, raise and scope up derrick, secure. Set remaining support equipment on liner. Start getting power to units. Set BPV and nipple down tree. Prep wellhead. Install blanking sub. N/u 13-5/8" BOP. Report Number 3 Report Start Date 11/22/2024 Report End Date 11/23/2024 Last 24hr Summary Finish rigging up, picking up handling equipment, and winterizing. M/U 3 1/2" TJ, run in and m/u to test sub. Test BOPE as per Hilcorp & AOGCC expectations, witnessed waived by AOGCC's Jim Regg on 11/21/24, all tests 250/3000psi. Tested PVT & gas alarms. No fails. L/d test joint, pull BPV, and m/u landing joint. Run in landing joint and m/u. BOLD. R/u e-line. RIH w/ 2.5" jet cutter, correlate to CBL 12/16/23. P/u to 50k, cut at 2400'. Good indication of cut, weight fell off to 18k. R/d e-line. R/u to circulate. Circulate down tubing up IA w/ fresh water at 3.5 bpm, 140 psi, saw cloudy fluid, no solids at bottoms up. Circulated until returns cleaned up, 100bbls total. Spot inhibited fluid. R/u skate and spooler. Pull hanger to surface, 19k p/u. Cut and cap control line. L/d hanger and landing joint. POOH, l/d 3- 1/2" 9.2 L80 IBT-Mod tubing from 2400'-t/1950'. Cutting bands and spooling control line. Report Number 4 Report Start Date 11/23/2024 Report End Date 11/24/2024 Last 24hr Summary Continue POOH, l/d 3-1/2" 9.2 L80 IBT-Mod tubing from 1950' to surface. 74 joints, 1 cut joint, 1-chem inj. mandrel assy. P/U 5.75" GR/JB, RIH on e-line t/ 2400', recovered 1- band. RIh w/7"CIBP, set at 2396' (top of plug), RIH tag plug on depth good. POOH r/d e-line. Fill hole, test CIBP t/2500psi, start 2700psi, 15 min 2690psi, 30 min 2687psi. good. Blow down lines, R/d floor, N/D BOPE. Install well cap flange and torque up. R/d support equipment, prep for mobilization. Lower and lay over derrick, secure for travel. Continue picking up around pad. Remove berming around containment where accessible. Move carrier off liner and load base beam on trailer. Load and prioritize trailers. @gpgg pgp RIH w/ 25' x 2.5" cement dump bailer for 12.5' of fill, TOC = 3247 ,pg RIH w/ 2.5" jet cutter, correlate to CBL 12/16/23. P/u to 50k, cut at 2400 Set CIBP @ 3272@ AOGCC to 1500 psi- pass y , test CIBP t/2500psi, start 2700psi gj, RIh w/7"CIBP, set at 2396' (top of plug), RIH tag plug on depth good Page 1/2 Well Name: DCU HVB-013A Report Printed: 5/16/2025WellViewAdmin@hilcorp.com Well Operations Summary Jobs Actual Start Date:2/9/2025 End Date:3/2/2025 Report Number 1 Report Start Date 2/9/2025 Report End Date 2/10/2025 Operation CCI on location at 06:00 and warming up equipment, held PJSM, staged crane, removed windwalls from pits, scoped down doghose, removed choke house and iron roughneck from floor, L/D V door windwall, removed boiler skid and aux fuel tank, lowered pit roof tops, removed back yard modules and pit modules and staged loaded trailers for move Monday morning. Start PU and loading exposed rig mats for transport to HVB pad. Cont PU rig mats, replaced 2" cement hardline on beaver slide with freshly tested hardware, traveled to HVB pad and set felt/liner, installed tree on Kalotsa 9 with wellhead Rep. PU and stage used liner on Kalotsa pad for production to use. Inspect loads for tansport. Wait on CCI rig movers. Perfrom Housekeeping. Cont to wait on CCI rig movers. Report Number 2 Report Start Date 2/10/2025 Report End Date 2/11/2025 Operation Cont cleanup of frozen felt around sub, CCI on location at 08:00 warming up equipment, held PJSM, started transport of permitted loads at 09:00 to HVB pad, spotted cranes, lowered windwalls on derrick board, and picked derrick off carrier, picked drill line spool. (15 mile move-3 hr turnaround for trucks/trailers) Picked carrier off sub, sub off pony walls. Loaded rig mats, pony walls and rig HPU. Transported cranes, sub, carrier, derrick and pony walls to HVB pad, set pony walls and sub, centered up over well, set carrier and drill line spool, set and pinned derrick. Set doghose skid and raised doghouse, set gen skid, flew iron roughneck to rig floor and pinned. Raise mast and pin. Spot gen module. Spot mud pit mods 1 and 2 and raise pit roofs. Crane set choke house. Set jig then spot mud pump 1 and 2 mods, top drive hpu, and boiler house. Hook up eletrical, water, air, steam and mud lines. Stage up boilers. Clear liner, felt and trash from Kalotsa #10. Cont to hook up electrical, air, water and steam lines. M/U mud lines from pits to mud pump. Hook up equalizer lines between pit modules. Begin hooking up Pason lines. Spool on drill line. Report Number 3 Report Start Date 2/11/2025 Report End Date 2/12/2025 Operation RD mech and electric shop, change shack/safety shack, office trailers, cont setting pit 3, poorboy and catwalk, set centrifuge and hung windwalls, hung BOP stack in cellar, welder made some minor repairs, transport trailers to HVB pad. Pinned lower torque tube to upper section, scoped up derrick, transported office trailers to location, and set same, RU comm's, install Handy Berm around rig, took on rig water, brought boilers up to temp/pressure, start steam throughout the rig, installed choke hose to manifold, staged Top Drive on rig floor, installed hooch over centrifuge, cont RU in pits, start hanging tarps. Hung Top Drive on blocks. Install service loop, kelly hose, saver sub, and bails to Top Drive and function test - Good. Set Gen 3 into place and berm in. Begin working through rig acceptance checklist. Continue working through rig acceptance checklist. Rig up generator #3 power. Rig up manual tongs and bring pipe handling equipment to rig floor. Spot mud lab with CCI loader and rig up electrical. Continue hanging tarps/felt around rig. Remove shipping beams from cellar and rig up kill line to mezzanine hookup. Calibrate and function test rig smart and Crown-O-Matic. Function test agitators, mix pumps, and gun lines in pits. Report Number 4 Report Start Date 2/12/2025 Report End Date 2/13/2025 Operation Cont working through rig acceptance checklist, building mud docks and offload mud product, RU comm's to service shacks, troubleshoot Pason PVT sensors, checked 7" for pressure, removed dry hole cap, set test plug, set BOP stack, Wellhead Rep functioned 7" packoff LDS, ran water around pits and plumbing, installed gas sensors and alarms, dressed shakers, RU geronimo line. Witness of initial BOP test waived by AOGCC Rep Jim Regg at 10:40 am on 2-12-25. Troubleshotmud pump engine (battery), replaced 2" hydraulic hose from topdrive HPU skid to sub, installed drip pan, flow riser and flow line, rig electrician tested all audio/visual gas alarms, C/O upper rams to 7", opened lower ram door and verified test joint XO's will be below lower rams, drilled port hole in 3 1/2" test joint (test plug not ported), cont offload mud product trailers, transport 6% KCL mud to pits from Paxton pad, received YJ and WIS tools, received and shipped Sperry tools. Flooded stack for shell test. Accepted rig at 18:00 hrs on 2-12-25. Continue flooding, hook up testing equipment, and purge air from system. Work air out of valves. Witness waived by AOGCC Jim Regg. All tests performed to 250/3000psi lo/hi for 5 min each. Test 4.5" test joint in LPR and dart valve. Rig down 4.5" test joint and P/U M/U 7" Test joint with pump in sub and TIW. Test 7" test joint in UPR with TIW, Mezz kill, UPR IBOP, and CMV#11-14. Witness waived by AOGCC Jim Regg. All tests performed to 250/3000psi lo/hi for 5 min each. Test LWR IBOP and CMV #1-10/15. Test inside/HCR kill, inside/HCR choke, and blinds. Test 3.5" test joint in Annular and LPR. Perform step down test on super choke and manual super choke to 1600psi. One fail/pass (Test #8-Manual Kill). Perform Koomey drawdown test Initial- 3050psi, After-1700psi 200psi recharge- 23sec Full recovery- 90sec 4 Backup NO2 bottles at 2487psi average. Report Number 5 Report Start Date 2/13/2025 Report End Date 2/14/2025 Operation RD test equipment. Primed mud pumps then pressured up mud line from pumps to Top Drive and tested at 2000 psi, set popoff's at 4000 psi, blew down Top Drive, started centrifuging mud weight from 9.2 to 9.0 ppg, obtained RKB's, racked and tallied DP, PU first stand and centered up torque tube/Top Drive over hole. Field: Deep Creek Unit Sundry #: State: ALASKA Rig/Service: HEC 169Permit to Drill (PTD) #:224-160 Wellbore API/UWI:50-231-20032-01-00 Page 2/2 Well Name: DCU HVB-013A Report Printed: 5/16/2025WellViewAdmin@hilcorp.com Well Operations Summary Operation PU singled in hole to 1257', POOH racked back 20 stands, PU singled in hole 1283', POOH racked back 20 stands. Floor motor battery ruptured, shut down and cleaned up/replaced battery. No personnel were near battery when it ruptured. PU singledin hole 16 jnts HWDP and 10 more jnts DP to 1037', POOH racked back last of pipe. 55 stands DP total and 8 stands HWDP total. During trip RU 2" HP hose from OA to flow line for circulating out the IA after casing cut. CCI RD HandyBerm for one of two empty mud storage tanks on Paxton pad. M/U Mechanical cutter and RIH T/ 1279'. P/U 42K, S/O 37K. Calculated displacement observed. Put 10 wraps to the right into string and slack off slowly engaging cutter at ~1279'. Slack off from 42K to 12K with TQ swings between 3.5-7.5KFt-lbs TQ. Let cutter work for 21 minutes total per YJ rep until TQ leveled off to a smooth 6.5K. P/U and disengaged cutter. Shut annular and break circulation at 721psi taking returns up the OA. Shut down and line up on spacer. Pump 21bbl hi-vis spacer followed by 9.0ppg 6%Kcl until clean returns observed at shakers. Open annular and displace the remaining 7" volume, FCP - 400psi at 112gpm. Total over boarded - 104bbls. Monitored well for 10 min - Static. POOH Racking back F/ 1260' - T/ Surf. Calculated displacement observed. L/D Cutter assy per YJ reps. Blade inspection confirmed good cut. C/O Hyd hose fitting on Iron Roughneck. M/U YJ spear and function test - Good. RIH to No-Go and set 5K down with Top Drive. With Annulus open BOLDS. Pull hanger to rig floor observing break over at 73K and free travel at 52K. Remove packoff. Hanger and packoff in good condition. Rig up Parker TRS power tongs. L/D 7" Casing F/ 1258' - T/ 620'. P/U 50K, S/O 47K. Calculated holefill observed. Report Number 6 Report Start Date 2/14/2025 Report End Date 2/15/2025 Operation Cont POOH L/D 7" casing. L/D hanger, 20' pup, 30 full jnts, one 8.75' cutoff section. RD casing tongs/elevators, cleaned up floor, PU single off catwalk and broke down YJ spear assembly, staged tools for cleanout BHA. PU WIS dual string mills, float sub and 8 1/2" tri-cone bit, RIH on 4 1/2" HWDP to 496'. Cont RIH on 4 1/2" DP from 496' to 1262' (9 5/8" shoe at 1157', 7" casing stub at 1279'), pulled back up into surface casing and parked at 1150'. MU topdrive and circulated surface to surface at 250 gpm-163 psi, shut down and flow checked 5 min = static. Blew down topdrive. POOH on elevators from 1150' to surface and L/D WIS string mills and bit. CCI drifted new 7" casing. PU Sperry TM and DM collars, MU float sub on bottom, RIH one stand, MU topdrive, warmed up tools then shallow pulse tested at 418gpm. Blew down topdrive, pulled OOH and L/D Sperry assembly in one piece. PU and MU WIS open hole whipstock assembly, followed with one jnt 6 5/8" HWDP, MCBPV, Sperry tools and 8 stands HWDP to 596'. RFO = 305.16° Cont TIH at 1-2 min per stand to 1220'. P/U 48K, S/O 42K. Calculated displacement observed. Top off drill string with fill up hose. Obtain parameters, P/U 48K, S/O 42K. RIH to set depth at 1230'. Come on with pumps staging up from 112gpm (75psi) to 405gpm (780psi). Orient Whipstock per directional plan to 159 ROHS. Cycle pumps 6 times to close bypass valve attempting multiple times to close bypass with 112gpm - No success. Walk pumps up to 250gpm observing valve close. Shut down pumps immediately and observe pressure increase to 4200. P/U to 90K confirming set. S/O to 50K then pick back up to 110K observing mill assy shear from whipstock at 62K over. TOW- 1200' BOW- 1214' Turn on rotary and ease down to TOW at 1200' observing TQ increase and psi decrease, confirming shear on plugs. Mill window F/ 1200' - T/ 1214' and rat hole T/ 1221'. 350/395gpm = 1395/1188psi, 60RPM = 7-9KFt-lbs TQ with 10K WOB. Ream through multiple times with pump/rotary. Dry drift with no pump/rotary observing no drag in/out of window. Monitor well for 10 min - Static. POOH F/ 1200' - T/ Surf. Calculated holefill observed. L/D TM/DM together and mill assy per WIS rep. Starter mill was 1/8" undergage and string mill was 1/16" undergage. Clean/clear rig floor. M/U and install wear ring. ID = 9", Length = 34". RILDS (x2). P/U 1.5° bend motor and M/U to Tricone. M/U TM, DM, and flex collar (x2) RIH T/ 110'. Perform RFO (280°). RIH F/ 110' - T/ 1170'. Fill pipe and shallow pulse test MWD tools - Good. P/U 50K, S/O 45K. Calculated displacement observed. Orient to 162° ROHS. Shut down pumps and trip through window observing no drag at the top, start taking wt at BOW (15-20K). P/U to ensure free with no drag pulling out of the window. Come back down observing a 20K bobble entering window. Still stacking 15-20K trying to exit the BOW at 1214'. P/U to check/verify depth and parameters with no drag exiting window. Attempt to trip back through the window stacking 20K with no entry. Orient tool to each quadrant and attempt entry multiple times in each zone with no success. Field: Deep Creek Unit Sundry #: State: ALASKA Rig/Service: HEC 169 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 21 Township: 2S Range: 13W Meridian: Seward Drilling Rig: n/a Rig Elevation: n/a Total Depth: 7,747 ft MD Lease No.: Fee - CIRI Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 117 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 1157 Feet Csg Cut@ Feet Intermediate: 7" O.D. Shoe@ 3645 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 3.5" O.D. Shoe@ 7747 Feet Csg Cut@ Feet Tubing: 3.5" O.D. Tail@ 3523 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 1659 ft 1650 ft 8.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1675 1659 1650 IA 148 150 150 OA 22 22 22 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Scott Warner Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): CIRI Lease C061589. Plug back for redrill. Tagged top of cast iron bridge plug. Cement to be added later. Witnessed a passing MIT. November 18, 2024 Bob Noble Well Bore Plug & Abandonment Happy Valley B-13 Hilcorp Alaska LLC PTD 2071510; Sundry 324-614 none Test Data: P Casing Removal: rev. 3-24-2022 2024-1118_Plug_Verification_HappyValley_B-13_bn 9 9 9 9 9 9 99 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.22 14:48:44 -09'00' 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 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,747'N/A Casing Collapse Structural Conductor Surface 3,909psi Intermediate 5,410psi Production Liner 10,540psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE CIRI 207-151 50-231-20032-00-00 Hilcorp Alaska, LLC Proposed Pools: 9.2# / L-80 TVD Burst 3,523' 1,105' Size 117' 7"3,645' 1,157' MD 3,645' Length 3-1/2" See Attached Schematic 7,240psi 5,750psi 117' 2,831' 117' 1,157' November 13, 2024 7,747'4,247' 3-1/2" 6,917' Perforation Depth MD (ft): See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Happy Valley B-13N/A Same 852psi See schematic Other: __________ 7" Baker ZXP; N/A 3,500' MD/2,698' TVD; N/A, N/A 6,913' 3,765' 2,944' Deep Creek HV Beluga/Tyonek Gas 16" 9-5/8" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:23 am, Oct 25, 2024 Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.10.24 14:57:11 -08'00' 324-614 X SFD 10/26/2024 Plug for Redrill X Provide 24 hrs notice for AOGCC witness of CIBP at 3272' pressure test and tag. 10-407 BJM 11/14/24 BOP test to 3000 psi. Annular test to 2500 psi. X DSR-10/29/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.15 11:16:45 -09'00'11/15/24 RBDMS JSB 111824 Well Prognosis Well: HVB-13 Well Name:HVB-13 API Number:50-231-20032-00-00 Current Status:Shut in Gas Well Permit to Drill Number:207-151 Regulatory Contact:Donna Ambruz (907) 777-8305 First Call Engineer:Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer:Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP:1103 psi @ 2508’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:852 psi Based on 0.1 psi/ft gas gradient to surface Well Status: Shut in gas producer Brief Well Summary HVB-13 was drilled in 2008 and IP’d at ~900 mscfd. Multiple Tyonek sands were produced from 2008 – 2012 before Beluga sands were added which initial increased production but quickly declined after water production increased. Multiple patches were set which ultimately shut off the water and production stayed around 150- 200 mscfd until water production increased again and gas rates couldn’t over come the water gradient. An IA cement packer job was completed in December 2023 to access upper Beluga sands which ended up being wet and was unsuccessful. The purpose of this sundry is to prepare the well for sidetrack now that the well has no further utility in its current state. Notes Regarding Wellbore Condition x Inclination o Max deviation of 55° @ 1788’ MD o Max DLS of 6.6°/100’ @ 391’ MD x Recent Tags o 4/11/24: Eline tagged with CCL/GPT @ 3442’. Fluid level at 1550’ Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH with 3-1/2” CIBP and set at ~3272’ 4. Dump bail minimum of 25’ cement on top of CIBP, estimated TOC at 3247’ a. Tag CIBP and pressure test to 1500 psi prior to dump bailing cement b. Provide 24 hrs notice to AOGCC for opportunity to witness tag and pressure test 5. RDMO EL 6. MIRU 401 workover rig 7. Install TWC, ND tree, NU BOP 8. Test BOPE ¾Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 24 hours in advance of test to allow them to witness test). ¾If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised,ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. ¾BOPs will be closed as needed to circulate the well during this workover. Well Prognosis Well: HVB-13 9. Pull TWC 10. RU Eline 11. RIH and cut tubing at ~2400’, while pulling in tension a. If tubing does not pull, repeat cut higher up in 100’ increments until tubing pulls free. Est TOC is ~2400’ based on CBL run in December 2023 12. RDMO EL 13. Pull and lay down tubing 14. Circulate well over to all source/lease water and clean water returns in prep of leaving source/lease water in between plugs 15. RU Eline 16. RIH and set 7” CIBP at ~1200’, 50’ below estimated KOP for sidetrack 17. RDMO Eline 18. MIT casing and plug to 2500 psi 19. ND BOP, NU dry hole tree 20. RDMO Rig 401 Attachments: 1) Actual Schematic. 2) Proposed Schematic 3) Rig 401 BOP Diagram 13-5/8” 4) AOGCC RWO Change Form Updated by DMA 04-24-24 Happy Valley Well HVB-13 Last Completed: 12/10/04 PTD: 207-151 API: 50-231-20032-00-00 SCHEMATIC PERFORATIONS Zone Top MD Btm MD Top TVD Btm TVD Amt Status Date BLG-10 3,282’3,296’2,508’2,518’18’Open 4/10/2024 BLG-29 3,798'3,810 2,975'2,987'12'Isolated 5/23/2012 BLG-36 4,028'4,054'3,200'3,225'26'Isolated 5/23/2012 BLG-40 4,208'4,227'3,379'3,398'19'Isolated 5/23/2012 BLG-46 4,821’4,829’3,992’4,006’8 Isolated 4/17/2019 BLG-130 6,362'6,382'5,532'5,552'20'Isolated 3/30/2009 T-2B 6,660'6,670'5,830'5,840'10'Isolated 3/30/2009 T-5 6,715'6,725'5,885'5,895'10'Isolated 3/29/2009 T-6 6,828'6,838'5,998'6,008'10'Isolated 3/29/2009 T-7A 6,970'6,990'6,140'6,160'20'Isolated 3/29/2009 T-7B 7,010'7,030'6,180'6,200'20'Isolated 3/29/2009 T-10 7,154'7,164'6,324'6,334'10'Frac'd/ Isolated 5/28/2009 7,189'7,197'6,359'6,349'8'Isolated 3/17/2009 T-13 7,322'7,340'6,492'6,510'18'Isolated 3/15/2009 T-17 7,478'7,511'6,648'6,681'33'Isolated 4/3/2008 7,479.6'7,511'6,649'6,681'31.6'Isolated 4/5/2008 7,520'7,532'6,690'6,702'12'Isolated 4/8/2008 CASING DETAIL Size Type Wt/ Grade CONN/ID Top Btm Length TOC 16" Conductor 109#, X-56 Weld/ 14.688"Surface 117’ 117’Driven 9-5/8” Surface 40#, L-80 BTC-Mod/ 8.835”Surface 1,157’1,157' 0 7”Intermediate 26#, L-80 BTC-Mod/ 6.276”Surface 3,645’3,645'2,766' 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”3,500'7,747'4,247’3,500' TUBING DETAIL 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”Surface 3,523'3,523’ N/A JEWELRY DETAIL No.Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line (live valve set 3-14-08) 2,097’7.26’ 2.992” 5.50” 2 Cement retainer (12/11/23) 3,465’ 3 Tubing Punch (11/22/13) 3,490’-3,495’ 3,490’ 4 7" Baker ZXP packer w Flex Lock Hanger (12/2007)3,500'17' 5.25" 6" 5 10-408 Seal Assembly (set 12/2007)3,523'9.27' 4" 5" 6 CIBP w 23’ cement cap – TOC @ 3,765’ (11/22/23) 3,788’ 7 Owen X-Span patch (22')3,792'22' 2.375" 2.992" 8 Composite Bridge Plug 7,175'2.08' - - 9 Sand fill (Tagged w/ Eline on 5/23/12)7,156'--- 10 WRP 7,400'3.83' - - 11 PBTD- Top of 3-1/2" float equipment (not tagged)7,679'--- Updated by SRW 10-24-24 Happy Valley Well HVB-13 PTD: 207-151 API: 50-231-20032-00-00 PROPOSED PERFORATIONS Zone Top MD Btm MD Top TVD Btm TVD Amt Status Date BLG-10 3,282’3,296’2,508’2,518’18’Open 4/10/2024 BLG-29 3,798'3,810 2,975'2,987'12'Isolated 5/23/2012 BLG-36 4,028'4,054'3,200'3,225'26'Isolated 5/23/2012 BLG-40 4,208'4,227'3,379'3,398'19'Isolated 5/23/2012 BLG-46 4,821’4,829’3,992’4,006’8 Isolated 4/17/2019 BLG-130 6,362'6,382'5,532'5,552'20'Isolated 3/30/2009 T-2B 6,660'6,670'5,830'5,840'10'Isolated 3/30/2009 T-5 6,715'6,725'5,885'5,895'10'Isolated 3/29/2009 T-6 6,828'6,838'5,998'6,008'10'Isolated 3/29/2009 T-7A 6,970'6,990'6,140'6,160'20'Isolated 3/29/2009 T-7B 7,010'7,030'6,180'6,200'20'Isolated 3/29/2009 T-10 7,154'7,164'6,324'6,334'10'Frac'd/ Isolated 5/28/2009 7,189'7,197'6,359'6,349'8'Isolated 3/17/2009 T-13 7,322'7,340'6,492'6,510'18'Isolated 3/15/2009 T-17 7,478'7,511'6,648'6,681'33'Isolated 4/3/2008 7,479.6'7,511'6,649'6,681'31.6'Isolated 4/5/2008 7,520'7,532'6,690'6,702'12'Isolated 4/8/2008 CASING DETAIL Size Type Wt/ Grade CONN/ID Top Btm Length TOC 16" Conductor 109#, X-56 Weld/ 14.688"Surface 117’ 117’Driven 9-5/8” Surface 40#, L-80 BTC-Mod/ 8.835”Surface 1,157’1,157' 0 7”Intermediate 26#, L-80 BTC-Mod/ 6.276”Surface 3,645’3,645'2,766' 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”3,500'7,747'4,247’3,500' TUBING DETAIL 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”Surface 3,523'3,523’ N/A JEWELRY DETAIL No.Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line (live valve set 3-14-08) 2,097’7.26’2.992”5.50” 2 Cement retainer (12/11/23)3,465’ 3 Tubing Punch (11/22/13) 3,490’-3,495’ 3,490’ 4 7" Baker ZXP packer w Flex Lock Hanger (12/2007)3,500'17' 5.25" 6" 5 10-408 Seal Assembly (set 12/2007)3,523'9.27' 4" 5" 6 CIBP w 23’ cement cap – TOC @ 3,765’ (11/22/23) 3,788’ 7 Owen X-Span patch (22')3,792'22' 2.375" 2.992" 8 Composite Bridge Plug 7,175'2.08' - - 9 Sand fill (Tagged w/ Eline on 5/23/12)7,156'--- 10 WRP 7,400'3.83' - - 11 PBTD- Top of 3-1/2" float equipment (not tagged)7,679'--- The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8"Spherical Annular Height: 46" Weight: 12,806 13-5/8"LWS Double BOP Height: 37" Width: 93" Weight 9,900 lbs. TOP RAMS 2-7/8" TO 5-1/2" MULTI- RAMS BOTTOM RAMS BLIND RAMS 13-5/8"Mud Cross W/ 4- 1/16" outlets Height:28.5" Width 31" Dual 4-1/16" Manual Gate valves W/ DSA to 2-1/16" 4-1/16" Manual Gate valve & 4-1/16" HCR W/ DSA to 2-1/16" Full Mud Cross Assy. width w/ valves installed Width: 98.5" Weight: 2200 lbs. Kill side Choke side Height Addition for Ring Gaskets: 0" BOP Total Height: 111.5" BOP Total weight: 24,906 lbs. 13-5/8" 5m BOP Package W/ 4-1/16" Valves Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Happy Valley B-13 (PTD 207-151)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC 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 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 324-614 SFD 10/26/2024 207-151 HAPPY VALLEY B-13 SFD 10/26/2024 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Cement Annulus Development Exploratory 3. Address: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: 3,788'; Total Depth measured 7,747 feet 7,175 & 7,400 feet true vertical 6,917 feet 7,156 (fill) feet Effective Depth measured 3,765 feet 3,500 feet true vertical 2,944 feet 2,698 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,523' MD 2,719' TVD Packers and SSSV (type, measured and true vertical depth)7" Baker ZXP; N/A 3,500' MD 2,698' TVD N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 5,410psi 5,750psi 7,240psi 1,157'1,105' Burst Collapse 3,909psi Production Liner 3,645' 4,247' Casing Structural 2,831' 3-1/2" 3,645' 7,747'6,917' 117'Conductor Surface Intermediate 16" 9-5/8" 117' 1,157' measured TVD 7" 10,160psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-151 50-231-20032-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEE CIRI Deep Creek / HV Beluga/Tyonek Gas Happy Valley B-13 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 117' 0 40 0 340 0 Scott Warner, Operations Engineer 323-540 Sr Pet Eng: 10,540psi Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 12:32 pm, May 01, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.05.01 11:41:15 - 08'00' Noel Nocas (4361) RBDMS JSB 051324 DSR-5/1/24 Well Name: DCU HVB-013 API #:50-231-20032-00-00 Field:Deep Creek Unit Start Date:11/21/2023 Permit #:207-151 Sundry #:323-540 End Date:4/11/2024 11/21/2023 11/22/2023 12/10/2023 12/11/2023 1/5/2024 3/4/2024 3/11/2024 3/20/2024 3/21/2024 4/7/2024 Activity Report Last 24 hrs: Fox CTU#8 1.75" CT. Mobilize Coil Unit and equipment from Fox shop. Permit & PJSM with operator on location. Spot & RU equipment. . NU BOP's, Function & Shell test . Full BOP test per sundry 250psi/2500psi. No failures. 24 hr notice given. Witness waived by Jim Regg. RD test eqpt. Secure the well. SD for the night. Notify Operator Last 24 hrs: Fox CTU#8 1.75" CT. - PJSM with operator. Warm up equipment. Fill supply tank with water from on pad well. ~100 bbls, RU IA return line.. Fill Coil w/ warm water.. MU & RIH with YJ Cement retainer & setting tool. Set down at 3766' w/4k. PU to Set depth at 3465'. Establish Circulation thru the IA. Pump 1/2" ball & set YJ Cmt retainer. Establish circulation with retainer set. PT top of Retainer to 1500 psi. PT CMT lines. Batch 31 bbls of 15.3 class G Cement. Pump 26 bbls, Displace cement with 28 bbls of water. Un-sting & circulate well clean. POOH. Blow down reel and surface lines with N2. Break off & LD Retainer running tool. RD Inj and Lube. RDMO. Secure well. Notify Operator. Set CIBP @ 3788' Dump 25' cement on top CMT top @ 3765.5' Tbg punch 3490'-3495' 6 spf, 0 deg. phasing PWL & YJ crane op, PTW, PJSM, discuss fishing strategy. Rig PWL back on well, M/U tool string w/ wt. bars, OJ & SJ and 2.50" JDC. RIH, latch fish and straight pull up to 1450 lbs. Attempted for 1 hr. then pullled to 1800 lbs. W/T for 1 hour, 1' movement. Jar down and shear off, POOH. Redressed JDC and witnessed cement inside sleeve. M/U 2.40" blind box, RIH and beat down on fish. Worked tool down from 3223' KB (slm) to 3239' KB over 2 hour period. Discussed w/ OE to abort fishing operations with equipment at hand. Specifcally .125" wire. Plan forward: W/O .160" SL wire and /or CTU to attempt fishing tool string. PJSM, Crew traveled to location, Pick up CCL/GPT & lube, Pressure test lube 250/3000-good, Run in hole to find fluid @ 2750', Tag @ 3245', Pull out of hole & grab fluid catcher, Run in hole & grab sample. Test 7" x 3.5" annulus with triplex no positive test pressure up to 1100 psi, pressure dropped to 900 psi & showed injectivity, Test inconclusive ran out of fluid. Release Yellowjacket eline, Secure well PJSM, Crew travel to location, Spot in & rig up coil tubing, Function & test BOPE-good, Pressure test BOPE 250/3000-pass (no retests), Secure well & winterize equipment. PJSM, Check wellhead pressures, OA=12 psi, IA-12, TBG-vaccum, Bleed off of IA & install triplex lines, Pump 3.3 gal methanol into 7 x 3.5", pressure up to 1500 psi monitor over 30 min, Bleed down to 900 psi, Monitor over night, Overnight put 200 psi on production tubing. PJSM, Travel to location, Check wellhead pressures, OA-12 psi, IA-500 psi, TBG-100 psi, Bleed down IA to 0, Install gauges on IA, Pressure up to 640 psi on TBG, Monitor well pressures overnight. Daily Operations: Tagged Slick line fish at 3214.7 with .160 wire. . Perform 32 jar licks at 3000 lbs. Swabbing Bha came free. POOH to surface. Possible fluid level 1105'. Rig back Slick line unit Page 1 of 2 4/8/2024 4/9/2024 4/10/2024 4/11/2024 PJSM, Crew travel to location, Pick up injector head, Stab onto well, Load reel, Make up bha & run in hole to tag @ 3249', Clean out to 3466', Reciprocate pipe 3200' to 3466' till returns clean, Pull out of hole, Lay down clean out BHA, Pick up reverse nozzle & run in hole to bottom, Unload hole with N2 reversing, Pull out of well & secure, Lay down injector & lube PJSM, Crew travel to location, Pick up injector head and lube, Load reel, Make up coil connector, Pull & pressure test-good, Work on pumps Make up clean out BHA, Run in hole pumping, Work on Hydraulics, Pull out of hole & rig down for the night. PJSM, Crew travel to location, Spot in & rig up Eline, Pick up CCL/GR & tubing punch, Pressure test lube 250/3000-good, Run in hole to perform correlation pass, Adjust, Shoot tubing punch from 3284' to 3286', Pull out of hole, Pick up run #2 GPT & sample bailer, Run in hole, No fluid seen, Pull out of hole, Pick up run #3 CCL/GR & 12' gun (2-3/8", 5 spf, 11 gr), Run in hole & correlate, Perf Beluga 10 (3284- 3296), Pull out of hole & pick up run #4 CCL/GPT, Run in hole & test well, Draw down in stages and continuously check fluid height in TBG, Last fluid level 3114', Last tag: 3448', Pull out of hole & rig down PJSM, Crew travel to location, Pick up GPT/CCL, Stab onto well, Pressure test lube 250/3000-good, Run in hole with run #1 GPT/CCL, Fluid level @ 1550'. Tag @ 3442', Pull out of hole & lay down tools, Draw down tubing monitoring IA , no changes in psi on IA , Draw down IA to zero, Talk with town, decsion made to rig down & release coil & eline, Secure well & rig down. Page 2 of 2 Updated by DMA 04-24-24 Happy Valley Well HVB-13 Last Completed: 12/10/04 PTD: 207-151 API: 50-231-20032-00-00 SCHEMATIC PERFORATIONS Zone Top MD Btm MD Top TVD Btm TVD Amt Status Date BLG-10 3,282’3,296’2,508’2,518’18’Open 4/10/2024 BLG-29 3,798'3,810 2,975'2,987'12'Isolated 5/23/2012 BLG-36 4,028'4,054'3,200'3,225'26'Isolated 5/23/2012 BLG-40 4,208'4,227'3,379'3,398'19'Isolated 5/23/2012 BLG-46 4,821’4,829’3,992’4,006’8 Isolated 4/17/2019 BLG-130 6,362'6,382'5,532'5,552'20'Isolated 3/30/2009 T-2B 6,660'6,670'5,830'5,840'10'Isolated 3/30/2009 T-5 6,715'6,725'5,885'5,895'10'Isolated 3/29/2009 T-6 6,828'6,838'5,998'6,008'10'Isolated 3/29/2009 T-7A 6,970'6,990'6,140'6,160'20'Isolated 3/29/2009 T-7B 7,010'7,030'6,180'6,200'20'Isolated 3/29/2009 T-10 7,154'7,164'6,324'6,334'10'Frac'd/ Isolated 5/28/2009 7,189'7,197'6,359'6,349'8'Isolated 3/17/2009 T-13 7,322'7,340'6,492'6,510'18'Isolated 3/15/2009 T-17 7,478'7,511'6,648'6,681'33'Isolated 4/3/2008 7,479.6'7,511'6,649'6,681'31.6'Isolated 4/5/2008 7,520'7,532'6,690'6,702'12'Isolated 4/8/2008 CASING DETAIL Size Type Wt/ Grade CONN/ID Top Btm Length TOC 16" Conductor 109#, X-56 Weld/ 14.688"Surface 117’ 117’Driven 9-5/8” Surface 40#, L-80 BTC-Mod/ 8.835”Surface 1,157’1,157' 0 7”Intermediate 26#, L-80 BTC-Mod/ 6.276”Surface 3,645’3,645'2,766' 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”3,500'7,747'4,247’3,500' TUBING DETAIL 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”Surface 3,523'3,523’ N/A JEWELRY DETAIL No.Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line (live valve set 3-14-08) 2,097’7.26’ 2.992” 5.50” 2 Cement retainer (12/11/23) 3,465’ 3 Tubing Punch (11/22/13) 3,490’-3,495’ 3,490’ 4 7" Baker ZXP packer w Flex Lock Hanger (12/2007)3,500'17' 5.25" 6" 5 10-408 Seal Assembly (set 12/2007)3,523'9.27' 4" 5" 6 CIBP w 23’ cement cap – TOC @ 3,765’ (11/22/23) 3,788’ 7 Owen X-Span patch (22')3,792'22' 2.375" 2.992" 8 Composite Bridge Plug 7,175'2.08' - - 9 Sand fill (Tagged w/ Eline on 5/23/12)7,156'--- 10 WRP 7,400'3.83' - - 11 PBTD- Top of 3-1/2" float equipment (not tagged)7,679'--- Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/1/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240501 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-13 50231200320000 207151 4/10/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 3/27/2024 YELLOW JACKET GPT-PERF KU 13-06A 50133207160000 223112 4/1/2024 YELLOW JACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/22/2024 YELLOW JACKET GPT-PERF KU 33-08 50133207180000 224008 4/30/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/23/2024 YELLOW JACKET SCBL KU 41-08 50133207170000 224005 4/11/2024 AK E-LINE GPT/Perf/CIBP MPU F-30A 50029226230100 213188 4/12/2024 READ CaliperSurvey MPU S-13 50029230930000 202114 4/16/2024 READ Caliper Survey NCI A-17 50883201880000 223031 3/22/2024 AK E-LINE Perf Paxton 6 50133207070000 222054 4/14/2024 AK E-LINE GPT/Perf PBU PTM P1-13 50029223720000 193074 4/8/2024 YELLOW JACKET CBL SRU 232-15 50133207140000 223091 3/28/2024 YELLOW JACKET GPT-PLUG-PERF SRU 232-15 50133207140000 223091 4/22/2024 YELLOW JACKET PLUG-PERF SRU 241-33B 50133206960000 221053 4/12/2024 YELLOW JACKET GPT-PERF SRU 241-33B 50133206960000 221053 4/4/2024 YELLOW JACKET GPT-PERF Please include current contact information if different from above. T38745 T38746 T38746 T38746 T38747 T38748 T38748 T38749 T38750 T38751 T38752 T38753 T38754 T38754 T38755 T38755 HV B-13 50231200320000 207151 4/10/2024 YELLOW JACKET GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.05.13 09:32:35 -08'00' From:McLellan, Bryan J (OGC) To:Scott Warner Subject:RE: [EXTERNAL] RE: HVB-13 CBL- Sundry 323-540 Date:Monday, April 8, 2024 2:51:00 PM Scott, Hilcorp has approval to proceed with the perforations as described in the sundry and below. It’s recognized that there is a gap in cement over some of the perf intervals, but all proposed intervals are in the same pool. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Friday, April 5, 2024 1:19 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: HVB-13 CBL- Sundry 323-540 Bryan, Agree cement was overdisplaced and assuming you meant will it impact our perforating strategy? Due to the cement being overdisplaced we plan to shoot the best perf interval first which is Beluga 10 from 3284’-3296’. The other intervals are last ditch efforts and depending on the results we will evaluate from there to ensure maximum depletion of the pool. All intervals we plan to perforate are within the same pool. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 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. You don't often get email from scott.warner@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, April 5, 2024 9:40 AM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: [EXTERNAL] RE: HVB-13 CBL- Sundry 323-540 Scott, It looks like cement was overdisplaced, with cement top higher than planned and no cement for a couple hundred feet above the retainer depth. Will that impact your cementing strategy? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Thursday, April 4, 2024 4:15 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: HVB-13 CBL- Sundry 323-540 Bryan, Attached is the CBL we ran on HVB-13 after the annular cement job. We are planning to perforate HVB-13 next week with the top proposed perf being 3048’ MD if we get approval from AOGCC. If you have any questions, please let me know. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/4/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240404 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/23/2024 YELLOW JACKET GPT-PERF BRU 241-23 50283201910000 223061 11/25/2023 AK E-LINE Perf HV B-13 50231200320000 207151 3/11/2024 YELLOW JACKET GPT KALOTSA 6 50133206850000 219114 3/2/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 3/13/2024 YELLOW JACKET GPT-PERF KU 21-06RD 50133100900100 201097 3/19/2024 YELLOW JACKET GPT-PERF END MPI 2-62 50029216480000 186158 2/14/2024 YELLOW JACKET PERF MPU G-18 50029231940000 204020 3/21/2024 READ Caliper Survey MPU G-18 50029231940000 204020 3/9/2024 AK E-LINE HoistCutter MPU I-24 50029237780000 224001 3/11/2024 AK E-LINE CBL NCIU A-18 50883201890000 223033 12/20/2023 AK E-LINE Perf NCIU A-18 50883201890000 223033 12/18/2024 AK E-LINE GPT/Plug/Perf PAXTON 3 50133205880000 209168 3/6/2024 YELLOW JACKET GPT PAXTON 3 50133205880000 209168 3/8/2024 YELLOW JACKET PERF PAXTON 3 50133205880000 209168 3/12/2024 AK E-LINE PPROF PAXTON 7 50133206430000 214130 2/26/2024 YELLOW JACKET PERF PBU 09-52 50029236180000 218168 3/24/2024 HALLIBURTON PPROF SD-06 50133205820000 208160 2/20/2024 YELLOW JACKET PERF SRU 222-33 50133207150000 223100 12/19/2023 AK E-LINE Perf Please include current contact information if different from above T38683 T38684 T38685 T38686 T38689 T38687 T38690 T38691 T38691T38692 T38963 T38963 T38694 T38694 T38694 T38695 T38696 T38697 T38698 HV B-13 50231200320000 207151 3/11/2024 YELLOW JACKET GPT Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 13:48:29 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/14/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240314 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/20/2024 AK E-LINE GPT/PL BCU 13 50133205250000 203138 1/4/2023 AK E-LINE JetCut/CBL BRU 221-35 50283201930000 223077 11/18/2023 AK E-LINE Perf HV B-13 50231200320000 207151 12/22/2023 AK E-LINE CBL IRU 41-01 50283200880000 192109 11/16/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 1/16/2024 AK E-LINE GPT/Perf KTU 32-07H 50133205110000 202043 10/27/2023 AK E-LINE PPROF KU 3-06A 50133207160000 223112 1/12/2024 AK E-LINE CBL KU 21X-32 50133202040000 169100 12/8/2023 AK E-LINE JetCut MPU CFP-02 50029212580000 184242 3/9/2024 READ CaliperSurvey NCI A-18 50883201890000 223033 12/8/2023 AK E-LINE Perf/GPT NIA NK-18 50029224210000 193177 12/13/2023 AK E-LINE IPROF PTM P1-13 50029223720000 193074 12/9/2023 AK E-LINE Cement TBU M-11 50733205900000 210145 1/8/2024 AK E-LINE Perf TBU M-15 50733204220000 190109 2/7/2024 AK E-LINE GPT/Perf Please include current contact information if different from above. T38615 T38615 T38616 T38617 T38618 T38619 T38620 T38621 T38622 T38623 T38624 T38625 T38626 T38627 T38628 HV B-13 50231200320000 207151 12/22/2023 AK E-LINE CBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.15 11:38:35 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/25/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240125 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-12 50231200310000 207123 1/3/2024 Yellowjacket GPT-PERF HV B-13 50231200320000 207151 12/13/2023 Yellowjacket SCBL HV B-17 50231200490000 215189 1/4/2024 Yellowjacket GPT-PERF HV B-16A 50231200400100 222070 1/12/2024 Yellowjacket GPT-PERF KBU 22-06Y 50133206500000 215044 12/5/2023 Yellowjacket GPT-PERF KTU 43-6XRD2 50133203280200 205117 12/4/2023 YELLOWJACKET GPT-PERF KU 21X-32 50133202040000 169100 12/23/2023 AK E-Line CALIPER TBU M-11 50733205900000 210145 11/10/2023 AK E-Line PL/PERF Please include current contact information if different from above. T38451 T38452 T38453 T38454 T38455 T38456 T38457 T38458 1/31/2024 HV B-13 50231200320000 207151 12/13/2023 Yellowjacket SCBL Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.31 09:35:23 -09'00' 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:Anthony Knowles To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Subject:Hilcorp Fox CTU #8 HVB-13 10-424 Date:Tuesday, December 12, 2023 5:02:06 PM Attachments:Hilcorp Fox CTU #8 12-10-2023 .xlsx Some people who received this message don't often get email from anthony.knowles@hilcorp.com. Learn why this is important Anthony Knowles Well Site Supervisor Prudhoe Bay | Alaska Hilcorp Alaska, LLC Office: (907) 659-5580 Cellular: (907) 227-2297 Harmony: 2382 anthony.knowles@hilcorp.com alternate: Dan Scarpellla 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. 'HHS&UHHN8QLW+DSS\9DOOH\% 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:CTU DATE: 12/10/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2071510 Sundry #323-540 Operation: Drilling: Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:2500 Annular:n/a Valves:250/2500 MASP:1520 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA P Annular Preventer 0NAPit Level Indicators NA P #1 Rams 1 4-1/16' Blind/Shea P Flow Indicator NA P #2 Rams 1 1-3/4" Pipe/Slip P Meth Gas Detector NA P #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)3050 P Kill Line Valves 2 2"P Pressure After Closure (psi)P Check Valve 0NA200 psi Attained (sec)4 P BOP Misc 1PFull Pressure Attained (sec)14 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1350 psi P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4/1350 psi P No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 24 P Coiled Tubing Only:#2 Rams 27 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:2.0 HCR Choke 0 NA Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/05/2023 7:00PM Waived By Test Start Date/Time:12/10/2023 12:00 (date) (time)Witness Test Finish Date/Time:12/10/2023 14:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Test w/ freash water. Recieved waive of witness from Jim Regg via email on 12/5 at 11:03 Jeremy Hart Hilcorp Alaska LLC. Anthony Knowles HVB-13 Test Pressure (psi): jeremyhart76@gmail.com anthony.knowles@hilcorp.com Form 10-424 (Revised 08/2022) 2023-1210_BOP_Fox8_DCU_HappyValley_B-13 'HHS&UHHN8QLW+DSS\9DOOH\% 9 999 9 9 9 9 MEU MEU 9 - 5HJJ 'HHS&UHHN8QLW+DSS\9DOOH\% 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: Cement Annulus, N2 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,747'7,156' (fill) Casing Collapse Structural Conductor Surface 3,909psi Intermediate 5,410psi Production Liner 10,540psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE CIRI 207-151 50-231-20032-00-00 Hilcorp Alaska, LLC Proposed Pools: 9.2# / L-80 TVD Burst 3,523' 1,105' Size 117' 7"3,645' 1,157' MD 3-1/2" See Attached Schematic 7,240psi 5,750psi 117' 2,831' 117' 1,157' October 10, 2023 7,747'4,247' 3-1/2" 6,917' Perforation Depth MD (ft): 3,645' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Happy Valley B-13CO 553 A Same ~1520 psi 7,175' & 7,400' Length 7" Baker ZXP; N/A 3,500' MD/2,698' TVD; N/A, N/A 6,917'7,156'6,326' Deep Creek HV Beluga/Tyonek Gas 16" 9-5/8" See Attached Schematic m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:03 pm, Oct 02, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.10.02 14:05:18 - 08'00' Noel Nocas (4361) DSR-10/5/23 CO 553A and CO 553A.001 SFD Perform MITIA to 1600 psi within 30 days after return to production after final perforations. 10-404 Perforate X SFD 10/4/2023 CT BOP test to 2500 psi BJM 11/7/23*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.11.07 14:46:39 -09'00'11/07/23 RBDMS JSB 111423 Well Prognosis Well Name: HVB-13 API Number: 50-231-20032-00-00 Regulatory Contact: Donna Ambruz Permit to Drill Number: 207-151 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (M) Second Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Maximum Expected BHP: ~ 2153 psi @ 6334’ TVD (0.34 psi/ft gradient to bottom open perf) Max. Potential Surface Pressure: ~ 1520 psi (Max expected BHP minus gas to surface) Well Status: SI Gas Producer Last well test: 8 mcfd @ 40 psi (9/15/23) Brief Well Summary HVB-13 is a upper Tyonek and Beluga producer that is currently below the unload rate and unable to produce. The objective of this sundry is to isolate the existing perforations with a plug and pump an annular cement job below a retainer to isolate and test multiple Beluga sands currently above the packer. History: 12/9/21 1.75 DDB to 7039’, recover clay, swab well online Max Angle: 55 degree sail Current open gross perf interval: 4028’ – 7164’ MD (3200’ – 6334’ TVD) Procedure: 1. Review approved COAs 2. MITIA to 2000 psi 3. MIRU Eline, PT lubricator to 2500 psi. 4. Set CIBP at ~3788’, dump 25’ cement on plug, MIT to 2000 psi 5. Tubing punch at ~3495’, pump on tubing to confirm tubing holes are communicating to annulus 6. MIRU coil tubing, proved 24 hrs notice to AOGCC, BOP test to 2500 psi 7. RIH w cement retainer, tag CIBP for depth correction, set cement retainer at ~3475’ 8. Mix and pump 26 bbls 15.3# cement below retainer taking returns from annulus a. 26 bbls = 1000’ of annular cement b. Planned TOC in 3-1/2 x 7 annulus = 2500’ 9. Unsting from retainer, circulate well clean, POOH, RDMO coil 10. WOC overnight 11. Log CBL, send results to AOGCC 12. RIH with nozzle, blow well dry with nitrogen, trap 1000 psi on well 13. MIRU E-line, PT lubricator to 2500 psi 14. Perforate the below sands from the bottom up: Sand MD Top MD Btm TVD Top TVD Btm Beluga 7 3048’ 3064’ 2318’ 2330’ Beluga 8 3124’ 3133’ 2377’ 2384’ Beluga 10 3284’ 3296’ 2508’ 2518’ Beluga 13 3413’ 3427’ 2620’ 2633’ Well Prognosis a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. b. If necessary use nitrogen to pressure up well during perforating 15. Return to production Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil Tubing BOP diagram 4. Nitrogen SOP Updated by JMF 9-25-23 Happy Valley Well HVB-13 Last Completed: 12/10/04 PTD: 207-151 API: 50-231-20032-00-00 SCHEMATIC PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt Gun Size Status Date BLG-29 3,798'3,810 2,975'2,987'12'2.5"Isolated 5/23/2012 BLG-36 4,028'4,054'3,200'3,225'26'2.5"Open 5/23/2012 BLG-40 4,208'4,227'3,379'3,398'19'2.5"Open 5/23/2012 BLG-46 4,821’4,829’3,992’4,0006’8 2”Open 4/17/2019 BLG-130 6,362'6,382'5,532'5,552'20'2.5"Open 3/30/2009 T-4A 6,660'6,670'5,830'5,840'10'2.5"Open 3/30/2009 T-4 6,715'6,725'5,885'5,895'10'2.5"Open 3/29/2009 T-5 6,828'6,838'5,998'6,008'10'2.5"Open 3/29/2009 T-6B 6,970'6,990'6,140'6,160'20'2.5"Open 3/29/2009 T-7 7,010'7,030'6,180'6,200'20'2.5"Open 3/29/2009 T-10 7,154' 7,164' 6,324' 6,334'10'2.5"Frac'd/ Partially Isolated 5/28/2009 7,189'7,197'6,359'6,349'8'2.5"Isolated 3/17/2009 T-13 7,322'7,340'6,492'6,510'18'2.5"Isolated 3/15/2009 T-17 7,478'7,511'6,648'6,681'33'2"Isolated 4/3/2008 7,479.6'7,511'6,649'6,681'31.6'2"Isolated 4/5/2008 7,520'7,532'6,690'6,702'12'2.5"Isolated 4/8/2008 B B B B B CASING DETAIL Size Type Wt/ Grade CONN/ID Top Btm Length TOC 16" Conductor 109#, X-56 Weld/ 14.688"Surface 117’ 117’Driven 9-5/8” Surface 40#, L-80 BTC-Mod/ 8.835”Surface 1,157’1,157' 0 7”Intermediate 26#, L-80 BTC-Mod/ 6.276”Surface 3,645’3,645'2,766' 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”3,500'7,747'4,247’3,500' TUBING DETAIL 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”Surface 3,523'3,523’ N/A JEWELRY DETAIL No.Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line (live valve set 3-14-08) 2,097’7.26’ 2.992” 5.50” 2 7" Baker ZXP packer w Flex Lock Hanger (12/2007)3,500'17' 5.25" 6" 3 10-408 Seal Assembly (set 12/2007)3,523'9.27' 4" 5" 4 Owen X-Span patch (22')3,792'22' 2.375" 2.992" 5 Composite Bridge Plug 7,175'2.08' - - 6 Sand fill (Tagged w/ Eline on 5/23/12)7,156'--- 7 WRP 7,400'3.83' - - 8 PBTD- Top of 3-1/2" float equipment (not tagged)7,679'--- Updated by DMA 09-25-23 Happy Valley Well HVB-13 Last Completed: 12/10/04 PTD: 207-151 API: 50-231-20032-00-00 PROPOSED PERFORATIONS Zone Top(MD)Btm(MD)Top(TVD)Btm(TVD)Amt Status Date BEL 7-13 ±3,048’±3,427’±2,318’±2,633’TBD Proposed BLG-29 3,798'3,810 2,975'2,987'12'Isolated 5/23/2012 BLG-36 4,028'4,054'3,200'3,225'26'Open 5/23/2012 BLG-40 4,208'4,227'3,379'3,398'19'Open 5/23/2012 BLG-46 4,821’4,829’3,992’4,0006’8 Open 4/17/2019 BLG-130 6,362'6,382'5,532'5,552'20'Open 3/30/2009 T-4A 6,660'6,670'5,830'5,840'10'Open 3/30/2009 T-4 6,715'6,725'5,885'5,895'10'Open 3/29/2009 T-5 6,828'6,838'5,998'6,008'10'Open 3/29/2009 T-6B 6,970'6,990'6,140'6,160'20'Open 3/29/2009 T-7 7,010'7,030'6,180'6,200'20'Open 3/29/2009 T-10 7,154' 7,164' 6,324' 6,334'10'Frac'd/ Partially Isolated 5/28/2009 7,189'7,197'6,359'6,349'8'Isolated 3/17/2009 T-13 7,322'7,340'6,492'6,510'18'Isolated 3/15/2009 T-17 7,478'7,511'6,648'6,681'33'Isolated 4/3/2008 7,479.6'7,511'6,649'6,681'31.6'Isolated 4/5/2008 7,520'7,532'6,690'6,702'12'Isolated 4/8/2008 CASING DETAIL Size Type Wt/ Grade CONN/ID Top Btm Length TOC 16" Conductor 109#, X-56 Weld/ 14.688"Surface 117’ 117’Driven 9-5/8” Surface 40#, L-80 BTC-Mod/ 8.835”Surface 1,157’1,157' 0 7”Intermediate 26#, L-80 BTC-Mod/ 6.276”Surface 3,645’3,645'2,766' 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”3,500'7,747'4,247’3,500' TUBING DETAIL 3-1/2” Production 9.2#, L-80 IBT-Mod/ 2.992”Surface 3,523'3,523’ N/A JEWELRY DETAIL No.Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line (live valve set 3-14-08) 2,097’7.26’ 2.992” 5.50” 1.a Cement retainer ~3485’ 1.b Tubing Punch ~3495’ 2 7" Baker ZXP packer w Flex Lock Hanger (12/2007)3,500'17' 5.25" 6" 3 10-408 Seal Assembly (set 12/2007)3,523'9.27' 4" 5" 3.a CIBP w 25’ cement cap ~3788’ 4 Owen X-Span patch (22')3,792'22' 2.375" 2.992" 5 Composite Bridge Plug 7,175'2.08' - - 6 Sand fill (Tagged w/ Eline on 5/23/12)7,156'--- 7 WRP 7,400'3.83' - - 8 PBTD- Top of 3-1/2" float equipment (not tagged)7,679'--- 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ECENED MAY 0lZOa9 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing * Operations shutdown LJ Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 207-151 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-231-20032-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE CIRI Happy Valley B-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Deep Creek Field -Happy Valley / Beluga, Tyonek Gas Sand 11. Present Well Condition Summary: Total Depth measured 7,747 feet Plugs measured 7,175 & 7,400 feet true vertical 6,917 feet Junk measured 7,156 (fill) feet Effective Depth measured 7,156 feet Packer measured 3,500 feet true vertical 6,326 feet true vertical 2,698 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' Surface 1,157' 9-5/8" 1,157' 1,105' 5,750psi 3,909psi Intermediate 3,645' 7" 3,645' 2,831' 7,240psi 5,410psi Production Liner 4,247' 3-1/2" 7,747' 6,917' 10,160psi 10,540psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 3,523' 2,719' Packers and SSSV (type, measured and true vertical depth) 7" Baker Pkr; N/A 3,500' MD 2,698' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-McfWater-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 148 7 0 38 Subsequent to operation: 1 0 167 9 0 42 14. Attachments (required per 20 Anc 25.070, 25.071, a 25.263) 15. Well Class after work: Daily Report of Well Operations R] Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas � WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-155 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: lkramer(")a.hilcoro.com Authorized Signature: Date.7M!!. �-1 rA LOl9 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 �j/ y — S- —« RBDMS 4e -a MAY 0 8 2019 Submit Original Only GL-MSL=593' RIB-MSL�14' R L=21' 7 15' 1 i� 2 95'8 BLG-29 BLG-36 4,831' 10 Pup A 9.: k, BLG-0 5.823 1 V Pup J1. I••. BLG-130 T -4A T< T-5 6.867'mPup Jt T-10 T-13 3 4 5 T 7 8 SCHEMATIC CASING DETAIL Happy Valley Well HVB-13 Last Completed: 12/10/04 PTD: 207-151 API: 50-231-20032-00 Size Type Wt/ Grade CONN/ID Top Stm Length TOC 16" Conductor 109#, X-56 Weld/ 14.688" Surface 117' 117' Driven 9-5/8" Surface 40#,L-80 BTC-Mad/8.835" Surface 1,157' 1,157' 0 7" Intermediate 26#,L-80 BTC -Mod/ 6.276" Surface 3,645' 3,645' 2,766- 3-1/2" Production 9.2#,L-80 IBT-Mod/2.992" 3,500' 7,747' 4,247' 3,500' TUBING DETAIL 3-1/2" Production 9.2#,L-80 I IBT-Mod/ 2.992" I Surface 1 3,523' 1 3,523' 1 N/A JEWELRY DETAIL No. Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line 2,09r 7.26' 2.992" 5.50" 2 Live Valve installed in chemical injection mandrel (set 3/14/2008) 2,097' - - - 3 7" Baker ZXP packer (set 12/2007) 3,500' 17' 5.25" 6" 4 7" x 5" Baker Zflex-Lock 11 liner hanger (set 12/2007) 3,517' 6.1' 5.25" 5.91" 5 10-408 Seal Assembly (set 12/2007) 3,523' 9.27' 4" 5" 6 Owen X -Span patch (22') 3,792' 22' 2.375" 2.992" 7 Composite Bridge Plug 7,175' 2.08' - - 8 Sand fill (Tagged w/ Eline on 5/23/12) 7,156' - - - 9 WRP 7,400' 3.83' - - 10 PBTD- Top of 3-1/2" float equipment (not tagged) 7,679' - - - PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date BLG-29 3,798' 3,810 2,975' 2,987' 12' 2.5" 4 60' Isolated 5/23/2012 BLG-36 4,028' 4,054' 3,200' 3,225' 26' 2.5" 4 60' Open 5/23/2012 BLG-40 4,208' 4,227' 3,379' 3,398' 19' 2.5" 4 60' Open 5/23/2012 BLG-46 4,821' 4,829' 3,992' .4te606'N 8 2" 6 60' Open 4/17/2019 BLG-130 6,362' 1 6,382' 5,532' 5,552' 20' 2.5" 6 60' Open 3/30/2009 T -4A 6,660' 6,670' 5,830' 5,840' 10' 2.5" 6 60' Open 3/30/2009 T-4 6,715' 6,725' 5,885' 5,895' 30' 2.5" 6 60' Open 3/29/2009 T-5 6,828' 6,838' 5,998' 6,008' 10' 2.5" 6 60' Open 3/29/2009 T -6B 6,970' 6,990' 6,140' 6,160' 20' 2.5" 6 60' Open 3/29/2009 T-7 7,010' 7,030' 6,180' 6,200' 20' 2.5" 6 60' Open 3/29/2009 T-10 7,154' 7,164' 6,324' 6,334' 10' 2.5" 6 60' Frac'd/ Partially Isolated 5/28/2009 71189' 7,197' 6,359' 6,349' 8' 2.5" 6 60' Isolated 3/17/2009 T-13 7,322' 7,340' 6,492' 6,510' 18' 2.5" 6 60' Isolated 3/15/2009 7,478' 7,511' 6,648' 6,681' 33' 2" 6 60' Isolated 4/3/2008 T-17 7,479.6' 7,511' 6,649' 6,681' 31.6' 2" 6 60' Isolated 4/5/2008 7,520' 7,532' 6,690' 6,702' 12' 2.5" 6 60' Isolated 4/8/2008 svr TD=7,74T PBTD=7,679' Max Dev. 55 deg from 1,600'-2,500' Updated by DMA 05-01-19 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NVB -13 E -Line 50-231-20032-00 207-151 4/17/19 4/17/19 Daily Operations: 04/17/2019- Wednesday Sign in. PTW and JSA. Mobe to location Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. Well flow at 169K with 40 psi. RIH w/GPT tool and tie into composite log. Tag at 7,018' and FL - 6,983'. Ran log and send to town. POOH. RIH w/ 2" x 8' HC, 6 spf, 60 deg phase and tie into GPT log. Run log and send to town. Was told to pert from 4,821'to 4,829'. Spotted and fired gun with 39 psi/177K. 5 min - 41 psi/221K, 10 min - 41.8 psi/275K, 15 min - 66.6 psi/177.8K, 25 min - 47.3 psi/445.8K. Out of hole. All shots fired and gun was wet. Well was flowing at 43.5 psi/356.4K. No trouble in or out with patch. Rig down off well and turn well over to field. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w -aogcc.alaska.gov Re: Deep Creek Field, Happy Valley/Beluga, Tyonek Gas Pool, Happy Valley B-13 Permit to Drill Number: 207-151 Sundry Number: 319-155 Dear Mr. York: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner H J' DATED this2— day of April, 2019. RBWS L� APR 0 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® MAR 2 7 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate [] • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 207-151 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-231-20032-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 553A Will planned perforations require a spacing exception? Yes LJ No No Happy Valley B-13 - 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE CIRI Deep Creek Field -Happy Valley/ Beluga, Tyonek Gas Sand 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): 7,747' 6,91T 7,156' 6,326' –1,579 psi 7,175'& 7,400' 7,156' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' Surface 1,15T 9-5/8" 1,157' 1,105' 5,750pst 3,909psi Intermediate 3,645' 7" 3,645' 2,831' 7,240psi 5.410psi Production Liner 4,247' 3-1/2" 7,74T 6,917' 10,160psi 10,540psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / L-80 3,523' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" Baker ZXP; N/A 3,500' MD/2,698' TVD; N/A, N/A 12. Attachments: Proposal Summary ✓ Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 11, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 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 pdprr written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCojhilcoro.com Contact Phone: 777-8420 -13 ,� Authorized Signature: Date: n °va, Lb \ COMMISSION USE ONLY Conditions of approval: flotify Commission so that a representative may wkness Sundry Number: SIG -65 Plug Integrity ,❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDWS APR 0 21019 RB Post Initial Injection MIT Req'd? Yes E] No ❑ / Spacing Exception Required? Yes ❑ No Subsequent Form Required: L 0 — t -•J APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: V 'V(�Z 111/_x,' I 'A`I IoK Submit Form and Sir Fo 10-403 Revised 4 017 Approved 3pplicatio s a foM2 Tt3ttM/k'�ryj� date of approval. Attachments in Duplicated 3.Zii• U Hilt ra Alaska, LL. Well Prognosis Well: HVB-13 Date: 3/27/19 Well Name: HVB-13 API Number: 50-231-20032-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 4/11/19 Rig: N/A Reg. Approval Req'd? 10-403 Sundry Number: BEL 48 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 207-151 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number Estimated Bottom Hole Pressure: Current Max. Surface Pressure: Max. Potential Surface Pressure: Brief Well Summary: —1,754 psi at 4,081' TVD (Assumed 0.43 psi/ft) —500 psi (Estimated shut in pressure) —1,579 psi (Based on 0.10 psi/ft gas gradient to surface) Drilled in September of 2004 and completed in the T-17 sand. In March of 2009 the T10 Lwr and the T-13 were added which caused the well to load up. The T-10 was frac'ds in June 2009 but did not flow after the frac job. In September of 2009 a plug awas set and the T5, T6, T7A, T713, & BEL132 were added. In May of 2012, the Bel 25, 35, and 37 were added. The Bel 25 showed to be wet on a PLT and was later patched in Sept of 2012. Objective: • Perforate the BEL 46, 48, and 50 sands. Notes Regarding Wellbore Condition • The well is currently flowing = 150 mcfd @ 44 psi.. • MIRU slickline and make dummy gun run prior to performing work. • Note that there is a 22' Owens X -span patch @3,792 that we will be going through to perf. E -Line Procedure 1. MIRU a -line and pressure PT lubricator to 250 psi low/3,000 psi high. 2. Perforate the Beluga sands in the table below. Perf Intervals will be shot one at a time and flow tested prior to moving to the next interval. 3. Adjust wellhead pressure as necessary for underbalance. Note that the expected reservoir pressure is 1,200 psi. The other two intervals (46 and 48) are expected to be at normal gradient. 4. PU Perf guns, RIH and Log on depth. Perforate the following interval: Zone Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Beluga BEL46 ±4,820' ±4,835 ±3,991' ±4,006' 15 Beluga BEL 48 ±41893 ±4,910' ±4,064' ±4,081' 17 Beluga BEL 50 ±4,980 ±4,995 ±4,150' ±4,165' 15 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs will be provided in the field for exact perf intervals. c. Use Gamma/CCL/to correlate. d. Spacing allowance is based on CO 553A, no5 restrictions in Beluga Gas Pool. H Elilcurp Aluekn, LL Well Prognosis Well: HVB-13 Date:3/27/19 e. If interval is wet, it will be permanently isolated with a casing patch and/or plug. f. Record 5, 10, 15 min. pressures after firing guns. 5. RDMO a -line. 6. Turn well over to production to test. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Happy Valley Well13 SCHEMATIC Last Completed: 12/10/04 PTD: 207-151 llileom Aluakn. LLC API: 50-231-20032-00 GL-MSLS93' RI®-MSL=614' RHBGL=21' 11111111 CASING DETAIL Size Type Wt/ Grade CONN/ID Top Btm Length TOC 16" Conductor 109#,X-56 Weld/ 14.688" Surface 117' 117' Driven 9-5/8" Surface 40#,L-80 BTC -Mod/ 8.835" Surface 1,157' 1,157' 0 7" Intermediate 26#,L-80 BTC-Mod/6.276" Surface 3,645' 3,645' 2,766' 3-1/2" Production 9.2#,L-80 IBT-Mod/2.992" 3,500' 7,747' 4,247' 3,500' TUBING DETAIL 1 3-1/2" Production 9.2#,L-80 IBT-Mod/2.992" Surface 3,523' 1 3,523' 1 N/A 2 &518' JEWELRY DETAIL BLG29 F IY■,'•z+wl BLG 36 4,BD1' 10' Pup JI. 5,823 10' Pup A ` BLG130 T4A =_ T4 Er T-5 a 6,867' 10' Pup JL T-10 T13 s 10 No. Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line 2,097' 7.26' 2.992" 5.50" 2 Live Valve installed in chemical injection mandrel (set 3/14/2008) 2,097' - - - 3 7" Baker ZXP packer (set 12/2007) 3,500' 17' 5.25" 6" 4 7"x 5" Baker Zflex-Lock 11 liner hanger (set 12/2007) 3,517' 6.1' 5.25" 5.91" 5 10-408 Seal Assembly (set 12/2007) 3,523' 9.27' 4" 5" 6 Owen X -Span patch (22') 3,792' 22' 2.375" 2.992" 7 Composite Bridge Plug 7,175' 2.08' - - 8 Sand fill (Tagged w/ Eline on 5/23/12) 7,156' - - - 9 WRP 7,400' 1 3.83' - - 30 PBTD- Top of 3-1/2" float equipment (not tagged) 7,679' 1 - - - PERFORATIONS Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt Gun Size SPF Phase Status Date BLG-29 3,798' 3,810 2,975' 2,987' 12' 2.5" 4 60' Open 5/23/2012 BLG-36 4,028' 4,054' 3,200' 3,225' 26' 2.5" 4 60' Open 5/23/2012 BLG-40 4,208' 4,227' 3,379' 3,398' 19' 2.5" 4 60' Open 5/23/2012 BLG-130 6,362' 6,382' 5,532' 5,552' 20' 2.5" 6 60' Open 3/30/2009 T -4A 6,660' 6,670' 5,830' 5,840' 10' 2.5" 6 60" Open 3/30/2009 T-4 6,715 6,725' 1 5,885' 5,895' 30' 2.5" 1 6 1 60" Open 3/29/2009 T-5 6,828' 6,838' 5,998' 6,008' 10' 2.5" 6 60' Open 3/29/2009 T-613 6,970' 6,990' 6,140' 6,160' 20' 2.5" 6 60' Open 3/29/2009 T-7 7,010' 7,030' 6,180' 6,200' 20' 2.5" 6 60" Open 3/29/2009 T-10 7,154' 7,164' 6,324' 6,334' 30' 2.5" 6 60" Frac'd/ Partially Isolated 5/28/2009 7,189' 7,197' 6,359' 6,349' 8' 2.5" 6 60" Isolated 3/17/2009 T-13 7,322' 7,340' 6,492' 6,510' 18' 2.5" 6 60' Isolated 3/15/2009 7,478' 7,511' 6,648' 6,681' 33' 2" 6 60' Isolated 4/3/2008 T-17 7,479.6' 7,511' 6,649' 6,681' 31.6' 2" 6 60'Isolated 4/5/2008 7,520' 7,532' 6,690' 6,702' 12' 2.5" 6 60' Isolated 4/8/2008 3VY' TD =7,74r PBTD=7,679' Max Dev. 55 deg from 1,600-2,500' Updated by DMA 03-27-19 Happy Valley Well PROPOSED SCHEMATIC Last Completed:11 12/10/04 PTD: 207-151 itilm.e A6.lu. LLC API: 50-231-20032-00 GL -MSL -y y RK&MSL�W RKBGL=21' 4,801'19 Pup A j. BI G46 13-GA8 - BLG50 5,823 10 Pup A BLG-13J- TAA -` T T-0 I T-5 6,86,10' Pup Jt. T-10 T-17 7 311T TD=7,74T PBTD=7,679' Max Dev. 55 deg horn 1,660'-2,500' CASING DETAIL Size Type Wt/Grade CONN/ID Top Btm Length TOC 16" Conductor 109#,X-56 Weld/ 14.688" R 117' S7 4 BLG-29 i BLG36 1 BTC-Mod/8.835" Surface 1,157' 1,157' Vol 7" Intermediate 26#, L-80 BTC -Mod/ 6.276" Surface 3,645' 3,645' 2,766' 3-1/2" Production 9.2#,L-80 4,801'19 Pup A j. BI G46 13-GA8 - BLG50 5,823 10 Pup A BLG-13J- TAA -` T T-0 I T-5 6,86,10' Pup Jt. T-10 T-17 7 311T TD=7,74T PBTD=7,679' Max Dev. 55 deg horn 1,660'-2,500' CASING DETAIL Size Type Wt/Grade CONN/ID Top Btm Length TOC 16" Conductor 109#,X-56 Weld/ 14.688" R 117' 117' BLG-29 i BLG36 40#,L-80 4,801'19 Pup A j. BI G46 13-GA8 - BLG50 5,823 10 Pup A BLG-13J- TAA -` T T-0 I T-5 6,86,10' Pup Jt. T-10 T-17 7 311T TD=7,74T PBTD=7,679' Max Dev. 55 deg horn 1,660'-2,500' CASING DETAIL Size Type Wt/Grade CONN/ID Top Btm Length TOC 16" Conductor 109#,X-56 Weld/ 14.688" Surface 117' 117' Driven 9-5/8" Surface 40#,L-80 BTC-Mod/8.835" Surface 1,157' 1,157' 0 7" Intermediate 26#, L-80 BTC -Mod/ 6.276" Surface 3,645' 3,645' 2,766' 3-1/2" Production 9.2#,L-80 IBT-Mod/2.992' 3,500' 7,747' 4,247' 3,500' TUBING DETAIL 3-1/2" Production 9.2#,L-80 IBT-Mod/2.992" Surface 3,523' 1 3,523' 1 N/A JEWELRY DETAIL No. Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS Control Line 2,097' 7.26' 2.992" 5.50" 2 Live Valve installed in chemical injection mandrel (set 3/14/2008) 2,097' - - - 3 7" Baker ZXP packer (set 12/2007) 3,500' 17' 5.25" 6" 4 7"x 5" Baker ZOex-Lock 11 liner hanger (set 12/2007) 3,517' 6.1' 5.25" 5.91" 5 10-408 Seal Assembly (set 12/2007) 3,523' 9.27' 4" 5" 6 Owen X -Span patch (22') 3,792' 22' 2.375" 2.992" 7 Composite Bridge Plug 7,175' 2.08' - - 8 Sand fill (Tagged w/ Eire on 5/23/12) 7,156' - - - 9 WRP 71400'- ±4,910' ±4,064' ±4,081' 10 PBTD-Topof 3-1/2" float equipment(nottagged) 7,679' - - - PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Sze SPF Phase Status Date BLG-29 3,798' 3,810 2,975' 2,987' 12' 2.5" 4 60" Open 5/23/2012 BLG-36 4,028' 4,054' 3,200' 3,225' 26' 2.5" 4 60" Open 5/23/2012 BLG-40 4,208' 4,227' 3,379' 3,398' 19' 2.5" 4 60' Open 5/23/2012 BLG-46 ±4,820' ±4,835' ±3,991' ±4,006' ±15 TBD Proposed BLG-48 ±4,893' ±4,910' ±4,064' ±4,081' ±17 TBD Proposed BLG-50 ±4,980' ±4,995' ±4,150' ±4,165' ±15 TBD Proposed BLG-130 6,362' 6,382' 5,532' 5,552' 20' 2.5" 6 60` Open 3/30/2009 T -4A 6,660' 6,670' 5,830' 5,840' 10' 2.5" 6 60" Open 3/30/2009 T-4 6,715' 6,725' 5,885' 5,895' 10' 2.5" 6 60" Open 3/29/2009 T-5 6,828' 6,838' 5,998' 6,008' 30' 2.5" 6 60" Open 3/29/2009 T -6B 6,970' 6,990' 6,140' 6,160' 20' 2.5" 6 60° Open 3/29/2009 T-7 7,010' 7,030' 6,180' 6,200' 20' 2.5" 6 60° Open 3/29/2009 T -SO 7,154' 7,164' 6,324' 6,334' 10' 2.5" 6 60' Frac'd/ Partially Isolated 5/28/2009 7,189' 7,197' 6,359' 1 6,349' 8' 2.5" 6 60" Isolated 3/17/2009 T-13 7,322' 7,340' 6,492' 6,510' 18' 2.5" 6 60° Isolated 3/15/2009 7,478' 7,511' 6,648' 6,681' 33' 2" 6 60° Isolated 4/3/2008 T-17 7,479.6' 7,511' 6,649' 6,681' 31.6' 2" 6 60" Isolated 4/5/2008 7,520' 7,532' 6,690' 6,702' 12' 2.5" 6 60' Isolated 4/8/2008 Updated by DMA 03-27-19 100,000 L c 10,000 0 CL LL V y0 1,000 N Q� w 0 0 v LL t O 100 Z 3 U M C m 0 0 IL— 10 HILCORP ALASKA LLC, HAPPY VALLEY B-13 (207-151) DEEP CK, HV BELUGA/TYONEK GAS Monthly Production Rates Cum. Prod Water (bbis): 10,016 m. Prod Gas (m ,. �MEN ism����� Jan -2010 Jan -2015 • Produced Gas (MCFM) o GOR Produced Water (BOPM) Produced Oil (BOPM) 100,000 m d 30,000 O Ile m 0 O 3 1,000 S 1 03 100 O M m a m 10 0 0 S -- 1 Jan -2020 SPREADSH EET_Prod-I nject_Cu"es_Well_V 120_2071510_Ha ppy_Va Iley_B-13_20190328.xlsx 3/28/2019 ' � ��, STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMON 2 2 20 12 ,, eN REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 1. Operations Abandon U Repair Well U Plug Perforations U Perforate Lf Other [J Pull Capstring Performed: Alter Casing Pull Tubing Stimulate - Frac 0 Waiver 0 Time Extension 0 Add Patch Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development el Exploratory ❑ , 207 -151 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 L 50- 231 - 20032 -00 — 00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE CIRI Happly Valley B -13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Deep Creek Field -Happy Valley / Beluga, Tyonek Gas Sand 11. Present Well Condition Summary Total Depth measured 7,747 feet Plugs measured 7,175 & 7,400 feet true vertical 6,917 feet Junk measured 7,156 (fill) feet Effective Depth measured 7,156 feet Packer measured 3,500 feet true vertical 6,326 feet true vertical 2,698 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' Surface 1,157' 9 -5/8" 1,157' 1,105' 5,750 psi 3,090 psi Intermediate 3,645' 7" 3,645' 2,831' 7,240 psi 5,410 psi Production Liner 4,247' 3 -1/2" 7,747' 6,917' 10,160 psi 10,540 psi J Perforation depth Measured depth See Attached Schematic SCANNED JAN 2 8 2.O True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# / L -80 3,523' MD 2,719' TVD 3,500' MD , Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP 2,698' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 300 10 150 290 Subsequent to operation: 0 250 1 10 500 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 11 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas 0 .. WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chad Helgeson Email chelgeson(a hilcorp.com Printed Name Chad Helgeson Title Operations Engineer Signature ��. Phone 907 - 777 -8405 Date 'f -` »S OL I . 2 3 20 0... � gyp.21•l1. Form 10 -404 Revised 10/2012 ",,,,0 Original Only • • 11 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date HVB -13 50- 231 - 20032 -00 207 -151 9/27/12 9/27/12 049tfratiOnS: 09/27/2012 - Thursday MIRU ELU. RIH w/ CCL and a 2.812" setting tool to 3,900' to verify depth per log. POOH. PU a 3.5" standard Owen TBG patch (22' long). RIH to 3,900'. Tied in log and PUH to 3,781.33' (CCL Detph). Set TBG patch at 3,792'- 3,814' over preforations. POOH. RDMO ELU. Ili • • Happy Valley II Well HVB -13 SCHEMATIC Last Completed: 12/10/04 PTD: 207 -151 Hileoro Alaska. U.0 API: 50- 231 - 20032-00 CASING DETAIL GL MSL=593' RIB-MSL =14' Size Type Wt/ Grade CONN /ID Top Btm Length TOC RKl3 - GL=21' 16" Conductor 109 #, X -56 Weld/ 14.688" Surface 117' 117' Driven 9 -5/8" Surface 40 #, L -80 BTC -Mod/ 8.835" Surface 1,157' 1,157' 0 ij It. 7" Intermediate 26 #, L -80 BTC -Mod/ 6.276" Surface 3,645' 3,645' 2,766' 16" 3 -1/2" Production 9.2 #, L -80 IBT -Mod/ 2.992" 3,500' 7,747' 4,247' 3,500' TUBING DETAIL ¢' 1 3 -1/2" Production 9.2 #, L -80 IBT -Mod/ 2.992" Surface 3,523' 3,523' N/A 4 - 2 1 .Sc 95/8" JEWELRY DETAIL I No. Description Depth Length ID OD 1 Pollard Chemical Injection Mandrel w/ 2,097' 1/4" SS 2 097' 7.26' 2.992" 5.50" Control Line tit ' isi� 3 2 Live Valve installed in chemical injection mandrel (set 2,097' 6 . ' , 3/14/2008) 3 7" Baker ZXP packer (set 12/2007) 3,500' 17' 5.25" 6" �f ` 4 7" x 5" Baker Zflex -Lock II liner hanger (set 12/2007) 3,517' 6.1' 5.25" 5.91" 5 � ` 5 10 -408 Seal Assembly (set 12/2007) 3,523' 9.27' 4" 5" 6 Owen X -Span patch (22') 3,792' 22' 2.375" 2.992" BLG-29 7° 7 Composite Bridge Plug 7,175' 2.08' - - BLG 1 1 w BLG- 8 Sand fill (Tagged w/ Eline on 5/23/12) 7,156' - - - 6 cl : • �� 9 WRP 7,400' 3.83' - - 4001' 10' Pup Jt. 10 PBTD- Top of 3 -1/2" float equipment (not tagged) 7,679' - - - i R * , 5,823' 10' Pup Jt. PERFORATIONS BLG - 130 ' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Size SPF Phase Status Date T BLG -29 3,798' 3,810 2,975' 2,987' 12' 2.5" 4 60° Open 5/23/2012 T BLG -36 4,028' 4,054' 3,200' 3,225' 26' 2.5" 4 60° Open 5/23/2012 T - 5 BLG -40 4,208' 4,227' 3,379' 3,398' 19' 2.5" 4 60° Open 5/23/2012 6,867' 10' Pup Jt. BLG -130 6,362' 6,382' 5,532' 5,552' 20' 2.5" 6 60° Open 3/30/2009 T T -4A 6,660' 6,670' 5,830' 5,840' 10' 2.5" 6 60° Open 3/30/2009 T-7 7 T -4 6,715' 6,725' 5,885' 5,895' 10' 2.5" 6 60° Open 3/29/2009 _ T - 10 - 8 T -5 6,828' 6,838' 5,998' 6,008' 10' 2.5" 6 60° Open 3/29/2009 T -6B 6,970' 6,990' 6,140' 6,160' 20' 2.5" 6 60° Open 3/29/2009 T - T -7 7,010' 7,030' 6,180' 6,200' 20' 2.5" 6 60° Open 3/29/2009 9 7,154' 7,164' 6,324' 6,334' 10' 2.5" 6 60° Frac'd/ Partially 5/28/2009 T - 17 = T -10 Isolated 7,189' 7,197' 6,359' 6,349' 8' 2.5" 6 60° Isolated 3/17/2009 T -13 7,322' 7,340' 6,492' 6,510' 18' 2.5" 6 60° Isolated 3/15/2009 7,478' 7,511' 6,648' 6,681' 33' 2" 6 60° Isolated 4/3/2008 10 T -17 7,479.6' 7,511' 6,649' 6,681' 31.6' 2" 6 60° Isolated 4/5/2008 7,520' 7,532' 6,690' 6,702' 12' 2.5" 6 60° Isolated 4/8/2008 . 4 - 3-1/7' TD =7,747' PBTD = 7,67W Max Dev. 55 deg from 1,600' - 2,500' Updated by DMA 10 -22 -12 • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMM ION SEP i a 2012 REPORT OF SUNDRY WELL OPERATIONS Operations Abandon Repair /� 1.O P L] P L Plug Perforations U Perforate U Other ✓ Add Capstrings Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development IN Exploratory ❑ — 207 -151 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: e"" �� AK 99503 - 50 -231- 20032 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE CIRI Happy Valley B -13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — Deep Creek Field / Happy Valley - Beluga, Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 7,747 feet Plugs measured 7,175 & 7,400 feet true vertical 6,917 feet Junk measured 7,156 (Fill) feet Effective Depth measured 7,156 feet Packer measured 3,500 feet true vertical 6,326 feet true vertical 2,698 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' Surface 1,157' 9 -5/8" 1,157' 1,105' 5,750 psi 3,090 psi Intermediate 3,645' 7" 3,645' 2,831' 7,240 psi 5,410 psi Production Liner 4,247' 3 -1/2" 7,747' 6,917' 10,160 psi 10,540 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# / L -80 3,523' 2,719' 3,500'MD Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP 2,698' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A MAR ®1 a°3 Treatment descriptions including volumes used and final pressure: N/A SCANNED 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 600 0 220 750 Subsequent to operation: 0 300 10 150 290 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 f Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ , Gas 0 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chad Helgeson Phone 777 -8405 Printed Name Chad Helgeson Title Operations Engineer Signature (!,..,/,/,./.4/ Phone 777-8405 Date 9/7/2012 Fi eD MS EP 1 0 201 Q4 i A 0 R G N A .. l l /4 V /2— z z- Form 10-404 Revised 11/2011 Submit Original Only • • Happy Valley II Well HVB -13 SCHEMATIC Last Completed 12/10/04 PTD:207 -151 Hilc"rn Alaska, LLf. API:50- 231 - 20032 -00 GL- MSL I�- NkSL14 Casing Detail ► -z1 r . r Size Type Wt/ Grade Top Btm Length CONN /ID TOC t .sr: w^ r ,1?y 16" Conductor 109 #, X -56 Surface 117' 117' Weld/ 14.688" Driven 1 9 -5/8" Surface 40 #, L -80 Surface 1,157' 1,157' BTC -Mod/ 8.835" 0 _ 7" Intermediate 26 #, L -80 Surface 3,645' 3,645' BTC -Mod/ 6.276" 2,766' 1 „ { } L 3 Production 9.2 #, 80 3,500' 7,747' 4,247 IBT Mod/ 2.992" 3,500' 1 2 Tubing Detail al v f' 3 -1/2" Production 9.2 #, L -80 Surface 3,523' 3,523' IBT -Mod/ 2.99 2" 3/8" Cap String Surface 7,770' 7,770' N/A kipi Jewelry Detail 3 =1.1-111 ilr i No. Description Depth Length ID OD 4 1 Pollard Chemical Injection Mandrel W/ 2 1/4" SS 2,097' 7.26' 2.992" 5.50" Control Li.- _� _ � _...........n r v- 5 1a Cap String 7,770' 7,770 - - 2 roe Valve Iced in c emical injection mandre set *,d N 3/14/2008) BLG-29 3 7" BakerZXP packer (set 12 /2007) 3,500' 17' 5.25" 6" BLG-36 4 7" x 5" Baker Zflex -Lock II liner hanger (set 12/2007) 3,517' 6.1' 5.25" 5.91" BLCao 5 10 -408 Seal Assembly (set 12/2007) 3,523' 9.27' 4" 5" 4,801' 10'PupJt. 1 1 6 Composite Bridge Plug 7,175' 2.08' - - 7 Sand fill (Tagged w/ Eline on 5/23/12) 7,156' - - - 5,823 1a R,p J1. '. 1 8 W RP 7,400' 3.83' - - ��13o I 9 PBTD- Top of 3 -1/2" float equipment (not tagged) 7,679' - - - T-4A T-4 Perforations T -5 Zone Top Btm Amt Gun Size SPF Phase Status Date s,esr 1n PupJl. : 4 1 BLG -29 3,798' 3,810 12' 2.5" 4 60° Open 5/23/2012 T -68 BLG -36 4,028' 4,054' 26' 2.5" 4 60° Open 5/23/2012 T7 6 BLG -40 4,208' 4,227' 19' 2.5" 4 60° Open 5/23/2012 T -10 7 BLG -130 6,362' 6,382' 20' 2.5" 6 60° Open 3/30/2009 T -4A 6,660' 6,670' 10' 2.5" 6 60° Open 3/30/2009 T -13 T -4 6,715' 6,725' 10' 2.5" 6 60° Open 3/29/2009 8 T -5 6,828' 6,838' 10' 2.5" 6 60° Open 3/29/2009 T -n ";1:: T -6B 6 970' 6,990' 20' 2.5" 6 60° Open 3/29/2009 i T -7 7,010' 7,030' 20' 2.5" 6 60° Open 3/29/2009 T 10 7,154' 7,164' 10' 2.5" 6 60° Frac'd/ Partialy Isolated 5/28/2009 o -, 7,189' 7,197' 8' 2.5" 6 60° Isolated 3/17/2009 9 T -13 7,322' 7,340' 18' 2.5" 6 60° Isolated 3/15/2009 IV . a :4. 7 478' 7,511' 33' 2" 6 60° Isolated 4/3/2008 ° T -17 7,479.6' 7,511' 31.6' 2" 6 60° Isolated 4/5/2008 y,, . 7,520' 7,532' 12' 2.5" 6 60° Isolated 4/8/2008 TD =7,74T PBTD= 7,679' Note: The fluid control valve (FCV) for this well was set at 3,100psi on 7/2012. Updated by TDF 8 -21 -12 • ` • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date HVB -13 50- 231 - 20032 -00 207 -151 8/9/12 8/9/12 Daily Operations: 08/09/2012 - Thursday Mobe to location. RU on well. Pressure test to 250 psi low and 1,800 psi high. RIH with 3/8" capstring with control valve et at 3,150 psi. Tag at 7,139' RKB Baker capstring. Adjusted depth to 7,156' RKB per E -line tag on 5/23/12. Pick up to 7020'. Pump 24 gal of foamer to fill cap and displace a little in well (7,700' +/- on spool). Set slips and make up cap string assy. RD Baker unit and turn well over to production. STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMI ON • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 1 Repair Well U Plug Perforations ❑ Perforate U Other U Add Capstrings Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska, LLC Name: Development 0 Exploratory ❑ 207 -151 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50- 231 - 20032 -00 ^ Q 7. Property Designation (Lease Number): 8. Well Name and Number: Happy Valley Facility (C- 061590) FEE CIRI Happy Valley B -13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Deep Creek Field / Happy Valley - Beluga, Tyonek Gas Pool 11. Present Well Condition Summary: - ,, Total Depth measured 7,747 feet Plugs measured 7,175 & 7,400 feet true vertical 6,917 feet Junk measured 7,156 (Fill) feet Effective Depth measured 7,156 feet Packer measured 3,500 feet true vertical 6,326 feet ��� y ^� J U "�' �� true ve rtical 2,698 feet Casing Length Size MD 66dd TVD Burst Collapse Structural Conductor 117' 16" 117' 117' Surface 1,157' 9 -5/8" 1,157' 1,062' 5,750 psi 3,090 psi Intermediate 3,645' 7" 3,645' 2,831' 7,240 psi 5,410 psi Production Liner 4,247' 3 -1/2" 7,747' 6,917' 10,160 psi 10,540 psi 3,798'- 3,810'; 4,026- 4,054'; 4,206- 4,227'; 6,362'- 6,382'; 6,660'- 6,670; Perforation depth Measured depth 6,716- 6,725'; 6,828'- 6,838'; 6,970'- 6,990'; 7,010'- 7,030'; 7,154'- 7,164' 2,976- 2,987'; 3,200'- 3,225'; 3,379'- 3,398'; 5,532' - 5,552'; 5,830' - 5,840'; True Vertical depth 5,885' - 5,895'; 5,998'- 6,008'; 6,140'- 6,160'; 6,180' - 6,200' 6,324'- 6,334' Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# / L -80 3,523' 2,719' 3,500'MD Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP 2,698' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A RECEIVED Intervals treated (measured): N/A JUN 22 2012 Treatment descriptions including volumes used and final pressure: N/A AOGCC 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 240 1 70 270 Subsequent to operation: 0 600 0 220 750 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development El ° Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas is WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson Phone 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature „.41, - Phone 777 -8300 Date FDMS JUN 25 2012 6 .�. /� Form 10-404 Revised 11/2011 re ('mit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date HVB -13 Pull capstrings and add perfs 50- 231 - 20032 -00 207 -151 5/21/12 5/23/12 Daily Operations: 05/22/2012 - Tuesday RU on well. Pull 6,665' capstring from well. Got everything out of well (fluid control valve and sinker bar with fins). Pickled capstring with methanol. RD off well and replace tree cap with Bowen connection. SDFN. 05/23/2012- Wednesday All runs made this day incorporate the CBL log dated 3/29/08 per Final Approved Perforation Request Form dated 5/11/2012 by Dave Buthman. RU lubricator, pressure test 250 low and 2,500 high. RIH w/2 -1/2 "x19' HC, 4 spf, 60 deg phase. Tag fill at 7,156'. Spot perf gun from 4,208' to 4,227'. POOH, all shots fired. RIH w/2 -1/2 "x26' HC, 4 spf, 60 deg phase. Spot perf gun from 4,028' to 4,054'. POOH. RIH w/2 -1/2 "x12' HC, 4 spf, 60 deg phase. Spot perf gun from 3,798' to 3,810'. POOH. Secure well and move to HV -12. • • • Happy Valley II Well HVB -13 Last Completed 12/10/04 PTD: 207 -151 Ililror° Ala,ka. LLC ASBUILT API:50- 231 - 20032 -00 GL -MSL =593' RKB -MSL =614 Casing Detail RKB- GL =21' Type Wt/ Grade Top Btm Length CONN /ID 1 6" Conductor 109 #, X-56 Surface 117' 117' Weld/ 14.688" Driven 9 -5/8" Surface 40 #, L -80 Surface 1,157' 1,157' BTC -Mod/ 8.835" 0 7" Intermediate 26#, L -80 Surface 3,645' 3,645' BTC -Mod/ 6.276" 2,766' 1 -- [ / 3 -1/2" Production 9.2 #, L -80 3,500' 7,747' 4,247' IBT -Mod/ 2.992" 3,500' 1 4 z Tubing Detail 3 -1/2" Production 9.2 #, L -80 Surface 3,523' 3,523' IBT -Mod/ 2.99 2" Jewelry Detail No. Description Depth Length ID `)D Pollard Chemical Injection Mandrel W/ 2,097' 1/4" SS tltElilp 3 1 Control Line 2,097' 7.26' 2.992" 5.50" Live Valve installed in chemical injection mandrel (set \1 4 2 3/14/2008) 2,097 - - - 3 7" Baker ZXP packer (set 12/2007) 3,500' 17' 5.25" 6" 5 4 7" x 5" Baker Zflex -Lock II liner hanger (set 12/2007) 3,517' 6.1' 5.25" 5.91" 5 10 -408 Seal Assembly (set 12/2007) 3,523' 9.27' 4" 5" 'L 6 Composite Bridge Plug 7,175' 2.08' - - BLG-29 7 Sand fill 7,392' 8' - - BLG-36 8 WRP 7,400' 3.83' - - BLG-40 9 PBTD- Top of 3 -1/2" float equipment (not tagged) 7,679' - - - 4,801' 10' Pup Jt. [ [ Perforations 5,823'1e Pup Jt. I 1 Zone 1 o Btm Amt Gun Size SPF Phase Status BLG -29 3,798' 3,810 12' 2.5" 4 60° Open 5/23/2012 BLG - 130 BLG -36 4,028' 4,054' 26' 2.5" 4 60° Open 5/23/2012 T BLG -40 4,208' 4,227' 19' 2.5" 4 60° Open 5/23/2012 T-4 BLG -130 6,362' 6,382' 20' 2.5" 6 60° Open 3/30/2009 T T - 4A 6,660' 6,670' 10' 2.5" 6 60° Open 3/30/2009 6,867'10' Pup 1 1 T -4 6,715' 6,725' 10' 2.5" 6 60° Open 3/29/2009 T- T -5 6,828' 6,838' 10' 2.5" 6 60° Open 3/29/2009 T -7 6 T - 6B 6,970' 6,990' 20' 2.5" 6 60° Open 3/29/2009 T -10 - 7 T -7 7,010' 7,030' 20' 2.5" 6 60° Open 3/29/2009 T -10 7,154' 7,164' 10' 2.5" 6 60° Frac'd/ Partialy Isolated 5/28/2009 T -13 , 7,189' 7,197' 8' 2.5" 6 60° Isolated 3/17/2009 8 T -13 7,322' 7,340' 18' 2.5" 6 60° Isolated 3/15/2009 T-17= 7,478' 7,511' 33' 2" 6 60° Isolated 4/3/2008 T -17 7,479.6' 7,511' 31.6' 2" 6 60° Isolated 4/5/2008 7,520' 7,532' 12' 2.5" 6 60° Isolated 4/8/2008 9 ALL 11) =7,747' PBTD = 7,679' Updated by TDF 5 -22 -12 STATE OF ALASKA ALASKA L AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Capilary Tube Install Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 207 -151 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic El Service ❑ 6. API Number: 50- 231 -20032 P OQ' 00 7. Property Designation (Lease Number : W'' 8. Well Name and Number: C- 061590 [Happy Valley Facility] EA - G f R1 I xi t Valley B -13 ' 9. Field /Pool(s): Deep Creek Field/ Happy Valley - Beluga, Tyonek Gas Pool 10. Present Well Condition Summary: Total Depth measured 7,747 feet Plugs measured 7,175 & 7,400 feet true vertical 6,913 feet Junk measured 7,134 (Fill) feet Effective Depth measured 7,134 feet Packer measured 3,500 feet true vertical 6,304 feet qf true vertical 2,701 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 116' 4,020 psi 2,630 psi Surface 1,157' 9 -5/8" 1,157' 1,105' 5,750 psi 3,090 psi Intermediate 3,645' 7" 3,645' 2,830' 7,240 psi 5,415 psi Production Liner 4,247' 3 -1/2" 7,747' 6,917' 10,160 psi 10,540 psi Perforation depth Measured depth 6,362 - 6382', 6,660- 6.670, 6.715- 6.725. 6.828- 6,838, 6970 - 6,990, 7.010- 7,030. 7,154 -7,164 feet True Vertical depth 5.532 - 5.552. 5,830 - 5,840, 5.884- 5.894, 5,998 - 6.007. 6,139- 6,159, 6,179- 6,200, 6,323 -6.333 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2 #/ L -80 3,523' 2,723' 3,500' M Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP 2,697' TAD RE N/ 11. Stimulation or cement squeeze summary: N/A G Intervals treated (measured): N/A JAN 2 7 2012 Treatment descriptions including volumes used and final pressure: N/A Alaska Oil & Gas Cons. Commission 12. Representative Daily Average P oduction or InjectAn age Oil-Bbl Gas -Mcf Water -B — u mg Pressure Prior to well operation: 0 277 1 40 psi 258 psi Subsequent to operation: 0 269 1 40 psi 270 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development El r Service ❑ Stratigraphic ❑ Daily Report of Well Operations Y 15. Well Status after work: Oil ❑ ° Gas 0 WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -226 Contact Hilcorp Drilling Dept. at 777 -8301 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ,..W` ` ...„__ Phone 276 -7600 Date 1/25/2012 IMO 27. /L Form 10 -404 RedisSait $ JA X011 3 /4"/' �,7 j Submit Original Only • S t i Chevron HVB -13 Deep Creek Unit Permit to Drill # 207 -151 Lease &Seria/ 2-061590 Field: Happy Valley API #: 50- 231 - 20032 -00 -00 ORIGINAL RIG Surface Location: Well Classificaton. Development Gas Well ELEVATIONS 2920' FNL 8 337' FEL Total Depth: 7,747' Sec 21,T2S,R13W,SM PBTD: 7,679' RKB -GL X ASP4 223,691 Tubing: 3 -% ", 9.2 #, L -80, IBT -Mod 21 00' i f Y: ASP4 2,190,972 Prod Pkrs: 7" Baker ZXP Mechanical Set Pkr RKB -MSL - Operator: UNOCAL Ownership Union Oil Company of California 100% 614.00' GL -MSL: 593' Spud Date 12/4/07 4:00 PM RKB -MSL: 614' Other: Spud Dec 2007; Rig Release Jan 2008; Frac May 2009' Yna Coil 117' Csg 3129 psi @ 7,747' MD Tubing installed December 2011 0' TOC BHT. 131° 7,747' MD 12.2 ppg 220 sx 15.8 ppg 187 sx Description Weight Grade Conn ID Length Top Btm TOC Hrs Conductor 16" 109# X -56 Weld 14.688" 117' 0' 117' Driven 23.0 hrs 1,157' Csg Surface 95/8" 40.0# L -80 BTC -Mod 8.835" 1,157' 0' 1,157' 0' 44.0 hrs Intermediate 7" 26.08 L -80 BTC -Mod 6.276" 3,645' 0' 3,645' 2,766' 88.0 hrs _ P roduction 3 1/2" 9 2# L -80 IBT -Mod 2.992" 4,247' 3,500' 7,747' 3,500' 0.0 hrs 4 1 r,- (, j 2,766' Calc TOC 2 12.5 ppg 222 sx i�1 II Tubing 31/2" 9.2# L -80 IBT -Mod 2 992" 3,523' 0' 3,523' - "1:1 3 Dyna Coil 3/8" - SS2205 ferret .125" 6,650' 0' 6,665' ■ Jewelry & Fish 3,500' TOL T 4 Description Depth Length ID OD 3,500' Calc TOC I '! " °1 1 Pollard Chemical Injection Mandrel w/ 2097' 1/4" SS control line 2,097' 7.26' 2.992" 5.50' 12.5 ppg 353 sx 5 2 Live Valve installed in Chemical Int Mandrel (set 03- 14 -08) 2,097' - - 3,645' Csg - 3 7" Baker ZXP packer (set 12/2007) 3,500' 17.00' 5.250" 6.00' 4 7 "x5" Baker Flex -Lock III liner hanger (set 12/2007) 3,517' 6.10' 5.250" 5.91' 5 10 -408 Seal Assembly (set 12/2007) 3,523' 9.27' 4.000" 5.00' 6 Composite Bridge Plug 7,175' - - - 7 WRP 7,400' 8 PBTD - Top of 3 -1/2" Float equipment (Not Tagged) 7,679' 4,801' 10' Pup Jt • Perforations Zone Top Btm Amt Gun Size SPF Phase Status Date BLG -130 6,362' 6,382' 20' 2.5" 6 60° Open 9/30/2009 5,823' 10' Pup Jt ' T -4A 6,660' 6,670' 10' 2.5" 6 60' Open 9/30/2009 T -4 6,715' 6,725' 10' 2.5" 6 60° Open 9/29/2009 IBLG -130 I T -5 6,828' 6,838' 10' 2 5" 6 60° Open 9/29/2009 T -6B 6,970' 6,990' 20' 2.5" 6 60° Open 9/29/2009 IT -4A I ', _ 3/a - cap T -7 7,010' 7,030' 20' 2.5" 6 60° Open 9/29/2009 sr,m @6,66s' T -10 7,154' 7,164' 10' 2.5" 6 60° Covered Frac 5 /28/09 IT -4I T -10 7,189' 7,197' 8' 2.5" 6 60° Covered 3/17/2009 T -13 7,322' 7,340' 18' 2.5" 6 60° Covered 3/15/2009 IT -5 I IT Al T -17 7,478' 7,511' 33' 2" 6 60° Covered 4/3/2008 '' """j T -17 7479.6' 7,511' 31.6' 2" 6 60' Covered 4/5/2008 1' ' T -17 7,520' 7,532' 12' 2.5" 6 60° Covered 4/8/2008 6,867' 10' Pup Jt IT -6B I i r t !, I -7 I I! I Fill @ 7,134' IT -10 I 1-'6. 14Fr: 6 IT13I I I all W Fill @ 7,392' 7 IT -17I{ I Fill at 7,669.5' on 4/8/08 a Revised by TDF 1/17/2012 Proposed By: Marcus Barbee I, 7,747' Csg 7,747' TD I Actual Schematic 12 -20 -2011 I • • Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) HV -B13 HAPPY VALLEY B -13 C- 061590 5023120032 LC0002 614.00 w ,;. ;, • Primary Job T ype Job Category Objective Actual Start Date Actual End Date Artificial Lift Revision Well Services 1/18/2011 1/22/2011 Primary Wellbore Affected Wellbore UWI Well Permit Number HV -B13 502312003200 2071510 is 12/2012011 00:00 - 12/2112011 00:00 Operations Summary R/U Dyna coil unit. Stab 3/8" SS capilary into dual barrier pack -off and pressure test to 250 psi low/ 3,000 psi high. RIH w/ capstring and tag bottom @ 7,134'. Pull capstring back to target depth of 6,665'. Pressure up WPA hydraulic seals to 3,000 psi, close needle valve on WPA, bleed off hose and remove. R/D. Cap tubing with Swagelock chemical injrection manifold and connect cap to chemical feed. Leave location. • • L , W i SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 ao7" Anchorage, AK 99519 Re: Deep Creek Field, Beluga, Tyonek Gas Pool, Happy Valley B -13 Sundry Number: 311 -226 Dear Mr. Brandenburg: `' fLiU) L lv -_ 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, Daniel T. Seamount, Jr. Chair 57 DATED this 2-1 day of July, 2011. Encl. Gib' \ 't ¢ f u • STATE OF ALASKA ` �' t o k- ! IL' . , i� 0 i ,A ALASKA OIL AND GAS CONSERVATION COMMISSION . , 7a.?D 1/ APPLICATION FOR SUNDRY APPROVALS � 0. 11,1 . ;; :t ;' ,,.. ; ?; {,, . ;',, • • t fillSS - 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved'I rogram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Capillary tube install, remove plugs - El 2. Operator Name: Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Development el _ Exploratory ❑ 207 -151,- 3. A dd r es s: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 196247, Anchorage, Alaska 99519 50 -231- 20032 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ o El Happy Valley B -13 - 9. Property Designation (Lease Number): 10. Field / Pool(s): C- 061590 [Happy Valley Facility] ✓ ' /-/ T Deep Creek Field/ Happy Valley - Beluga, Tyonek Gas 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): 7,747 6,913 7,154 6,323 7,175' & 7,400' 7,154' (Fill) Casing Length Size MD % TVD Burst Collapse Structural N/A Conductor 117' 16" 117' 116' 4,020 psi 2,630 psi Surface 1,157' 9 -5/8" 1,157' 1,105' 5,750 psi 3,090 psi Intermediate 3,645' 7" 3,645' 2,830' 7,240 psi 5,410 psi Production N/A Liner 4,247' 3 -1/2" 7,747' 6,917' 10,160 psi 10,540 psi Perforation Depth MD (ft)/ Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,362 - 6,382', 6,660- 6,670, 6,715- 5,532 - 5,552, 5,830 - 5,840, 5,884- / 6,725, 6,828- 6,838, 6'970- 6,990, 5,894, 5,998- 6,007, 6,139- 6,159, 7,010- 7,030, 7,154 -7,164 6,179- 6,200, 6,323- 6,333, 3 - 1/2" 9.2 #/ L - 3,523 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" Baker ZXP / na 3,500 MD / 2,697 TVD l 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/21/ 011 Oil ❑ Gas El - WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: " N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263 -7605 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature J Phone 276 -7600 Date 7/13/2011 -� JC` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ( ( a/D co Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: T e Si TOP t0 3000 pc . . Subsequent Form Required: IV — 40 Lf, APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7 Z 1 i 1 1 Form 10 -403 Revised 1/2010 0 R 1 G 1 N itikPMS JUL 2 2 20111"A.ubmit in Duplicate • Chevron • i Deep Creek Field MOO Happy Valley B -13 %. 7/14/2011 OBJECTIVE: • Drill out python plug & recover WRP in well, run a pressure temperature log and install capillary string. Current BHP: 1,500 psi @ 5,932' TVD Max Do Boole pressure: 2,000 psi @ 6,530' TVD (Based on July 2008 SITP prior to plug bac T -10, 13 & 17 sands) MASP 1,707,psi (Based on actual reservoir conditions and dry gas (0.56 sp gr) gradient (0. 4si /ft) to surface) 2 PROCEDURE SUMMARY: 1 RU CT, pressure test BOPE to 250 psi low/ OOOii si high. 2 RIH mill python plug @ 7,145' and tag bottom a-t 7,392' + / -, POOH. 3 RU E -line, pressure test lubricator to 250 psi low/ 3,000 psi high. 4 RIH with dump bailer and place 5' +/- of cement on top of milled plug. 5 RD E -line, WOC. RIH w/ CT and mill cement plug and remainder of python plug, clean out sand on top of the WRP @ 7,400' '' 6 POOH. 7 RU Slickline, pressure test lubricator to 250 psi low/ 3,000 psi high. 8 RIH and recover WRP plug @ 7,400'. 9 RIH w/ CT blow well down with nitrogen and flow well in test separator, POOH. 10 RD CT. 11 RU Slickline, pressure test lubricator to 250 psi low/ 3,000 psi high. 11 RIH w/ pressure temperature log, RD. 12 RD Slickline. 13 RU Dyna Coil Unit. 14 Stab 3/8" SS capillary line into dual barrier pack -off. Make up BHA components. Install pack -off and pressure test same against swab valve 250 psi low /3,000 psi high. 15 RIH with 3/8" capillary string to the deepest point of gas entry as per pressure temperature survey. 16 Install slips, capillary string master valve, & chemical injection pump. 17 RD Dyna Coil Unit. 18 Turn well over to production. Happy Valley B -13 REVISED BY: TDF 07/14/2011 • • - i Chevron HVB -13 Deep Creek Unit Permit to Drill #: 207 -151 Lease & Serial #: C- 061590 Field: I Deep Creek Unit API #: 50- 231 - 20032 -00 -00 ORIGINAL RIG Surface Location: Well Classificaton: Development Gas Well ELEVATIONS 2920' FNL & 337' FEL Total Depth: 7,747 Sec 21,T2S,R13W,SM PBTD: 7,679' RKB -GL T X: ASP4 223,691 Tubing: 3 -W, 9.2 #, L -80, IBT -Mod 21.00' 1 Y: ASP4 2,190,972 Prod Pkrs: 7" Baker ZXP Mechanical Set Pkr RKB -MSL - 614.00' Operator. Union Oil of Cal Ownership: Union Oil Company of California 100% GL -MSL: 593' Spud Date: 12/4/07 4:00 PM 117' Csg RKB -MSL: 614' Other. Spud Dec 2007; Rig Release Jan 2008; Frac May 2009 0' TOC - BHP: 3129 psi @ 7,747' MD 12.2 ppg 220 sx l BHT: 131° 7,747' MD 15.8 ppg 187 sx o e Description Weight Grade Conn ID Length Top Btm TOC Hr: 1,157 Csg - Conductor 16" 109# X -56 Weld 14.688" 117' 0' 117' Driven 23.0 hrs Surface 9 5/8" 40.0# L -80 BTC -Mod 8.835" 1,157' 0' 1,157' 0' 44.0 hrs i i Intermediate 7" 26.0# L -80 BTC -Mod 6.276" 3,645' 0' 3,645' 2,766' 88.0 hrs I ' Production 31/2" 9.2# L -80 IBT -Mod 2.992" 4,24T 3,500' 7,747 3,500' 0.0 hrs 2,766' CaIc TOC bid 12.5 ppg 222 sx r • ' 1.1/1 , ] Tubing 3 1/2" 9.2# L -80 IBT -Mod 2.992" 3,523' 0' 3,523' - - 3,500' TOL tl J � , idill1111I" .-.. 3,500' CaIc TOC ( I ... I Description Depth Length ID OD 12.5 ppg 353 sx - '-I 1 Pollard Chemical Injection Mandrel w/ 2097 1/4" SS control line 2,097' 7.26' 2.992" 5.50' 3,645' Csg la Live Valve installed in Chemical Inj Mandrel (set 03- 14 -08) 2,097' - - - 2 7" Baker ZXP packer (set 12/2007) 3,500' 17.00' 5.250" 6.00' 3 7 "x5" Baker Flex -Lock III liner hanger (set 12/2007) 3,517' 6.10' 5.250" 5.91' 4 10 -408 Seal Assembly (set 12/2007) 3,523' 9.27' 4.000" 5.00' 5 Composite Bridge Plug 2.08' - - 6 Sand Fill , 7,392' 8' - - 7 WRP 3.83' - - _ 8 PBTD - Top of 3 -1/2" Float equipment (Not Tagged) 7,679' - - - 4,801' 10' Pup Jt 5,823' 10' Pup Jt .. I Perforations IBLG -130 I - Zone Top Btm Amt Gun Size SPF Phase Status Date I7-4A I ... BLG -130 6,362' 6,382' 20' 2 5" 6 60° Open 9/30/2009 r Mt T -4A 8,660' 6,670' 10' 2.5" 6 60° Open 9/30/2009 17-41 T -4 6,715' 6,725' 10' 25" 6 60° Open 9/29/2009 ' T -5 6,828' 6,838' 10' 2.5" 6 60° Open 9/29/2009 T-6B 6,970' 6,990' 20' 2.5" 6 60° Open 9/29/2009 ® I II _ T -7 7,010' 7,030' 20' 2.5" 6 60° Open 9/29/2009 V. y • " T -10 7,154' 7,164' 10' 2.5" 6 60° Frac'd Frac 5 /28/09 6,867' 10' Pup Jt , . T -10 7,189' 7,197' 8' 2.5" 6 60° Isolated 3/17/2009 T -13 7,322' 7,340' 18' 2.5" 6 60° Isolated 3/15/2009 IT-6B I I _ Tag Fill @ T -17 7,478' 7,511' 33' 2" 6 60° Isolated 4/3 /2008 7,154' WLM T -17 7479.6' 7,511' 31.6' 2" 6 60° Isolated 4/5 /2008 IT ' � T -17 7,520' 7,532' 12' 2.5" 6 80° Isolated 4/8/2008 Iii% IA IT -13 l , ICI t /J L7- .f IT-t7I �� ; I� . Fill at 7,669.5' IA on 4/8/08 j 7,747' Csg 7,747' TD 4.. .i__ Revised by TDF 7/12/2011 Prepared By: Marcus Barbee ActualSchematic 7 -9-09 • i. Chevron HVB -13 Deep Creek Unit Permit to Drill #: 207 -151 Lease &Serial #: C- 061590 Field: Happy Valley API #: 50- 231 - 20032 -00 -00 ORIGINAL RIG Surface Location: Well Classificaton: Development Gas Well ELEVATIONS 2920' FNL & 337' FEL Total Depth: 7,747' Sec 21,T25,R13W,SM PBTD: 7,679' RKB -GL X. ASP4 223,691 Tubing 3 - ", 9 2#, L -80, IBT -Mod 21.00' i V: ASP4 2,190,972 Prod Pkrs 7" Baker ZXP Mechanical Set Pkr RKB -MSL – Operator: UNOCAL Ownership: Union Oil Company of California 100% 614.00 " GL-MSL 593' Spud Date 12/4/07 4 00 PM RKB -MSL: 614' Other: Spud Dec 2007; Rig Release Jan 2008; Frac May 2009' ; Dyna 117' Csg i BHP: 3129 psi @ 7,747' MD Coil Tubing chemical injection string installation August 2011; 0' TOC BHT: _ 131° @ 7,747' MD 12.2 ppg 220 sx CASING & Tubing 15.8 ppg 187 sx Description Weight Grade Conn ID Length Top Btm TOC nrs Conductor 16" 109# X -56 Weld 14.688" 117' 0' 117' Dnven 23.0 hrs 1,157' Csg Surface 95/8" 40.09 L -80 BTC -Mod 8.835" 1,157' 0' 1,157' 0' 44.0 hrs j — Intermediate 7" 26.09 L -80 BTC -Mod 6.276" 3,645' 0' 3,645' 2,766' 88.0 hrs Production 3 1/2" 9.2# L -80 IBT -Mod 2.992" 4,247' 3,500' 7,747' 3,500' 0.0 hrs 2,766' CaIc TOC 12.5 ppg 222 sx Tubing 31/2" 9.2# L -80 IBT -Mod 2.992" 3,523' 0' 3,523' - - Dyna Coil 3/8" - SS2205 ferrel .125" 7,532' 0' 7,532' . 7- Jewelry & Fish 3,500' TOL 4-I i 7 Description Depth Length ID OD 3,500' Calc TOC 1'1 ( 1 Pollard Chemical Injection Mandrel w/ 2097' 1/4" SS control line 2,097' 7.26' 2.992" 5.50' 12.5 ppg 353 sx `■�I ' 2 Live Valve installed in Chemical In; Mandrel (set 03- 14 -08) 2,097' - - - 3,645' Csg �'i ` 3 7" Baker ZXP packer (set 12/2007) 3,500' 17.00' 5.250" 6.00' 4 7"55" Baker Flex -Lock III liner hanger (set 12/2007) 3,517' 6.10' 5.250" 5.91' 5 10 -408 Seal Assembly (set 12/2007) 3,523' 9.27' 4.000" 5.00' 6 PBTD - Top of 3 -1/2" Float equipment (Not Tagged) 7,679' - - - 1 4,801' 10' Pup Jt ' 1 1 Perforations Zone Top Btm Amt Gun Size SPF Phase Status Date BLG -130 6,362' 6,382' 20' 2.5" 6 60° Open 9/30/2009 5,823' 10' Pup Jt T -4A 6,660' 6,670' 10' 2.5" 6 60° Open 9/30/2009 AAA T -4 6,715' i 6,725' 10' 2.5" 6 60° i Open 9/29/2009 IBLG -130 I ( ',--;.`•-• T -5 6,828' 6,838' 10' 2.5" 6 60° Open 9/29/2009 T -6B 6,970' 6,990' 20' 2 5" 6 60° Open 9/29/2009 IT_4AI I LS– T -7 7,010' 7,030' 20' 2.5" 6 60° Open 9/29/2009 r T -10 7,154' 7,164' 10' 2.5" 6 60° Frac'd Frac 5/28/09 IT I I I.. � T -10 7,189' 7,197' 8' 2.5" 6 60° Open 3/17/2009 `... ' T -13 7,322' 7,340' 18' 2.5" 6 60° Open 3/15/2009 IT-5 I ' w I T -17 7,478' 7,511' 33' 2" 6 60° Open 4/3/2008 ft.. T -17 7479.6' 7,511' 31.6' 2" 6 60° Open 4/5/2008 T -17 7,520' 7,532' 12' 2.5" 6 60° Open 4/8/2008 6,867' 10' Pup Jt I T-6(31 IT -7 I ' IT -10 L I • IT -13 I { I IT-17I . »I I Fill at 7,669.5' on 4/8/08 /" Revised by MGB Proposed By. Marcus Barbee II I i ii 7,747' Csg 7,747' TD Proposed Schematic 07 -14 -2011 I Kenai Well Control Equipment 5K Conventional stripper Crossover 4 1/16" 10K BX- dressed for 1.75" Coil 155 to 7" 5K Bowen Lubricator • Thread 4 1/16" 10K Quad Blind Ram All sealing rams tested min of BOP Shear Ram 1.5 X MPWHP Dressed for 1.75" Slip Ram or 1000 psi over max treating 4 1/16" 10K lid-- —kit Pipe Seal Rarrf ressure. Flowcross with flanged 2 1/16" 10K Kill Line ED ports rigged to pump Returns Outlet to 10K rated Variable choke Crossover from wellhead Dual 2 1/16" 10K fully open flange to 4 1/16 10K BX -155 valves per side 1 Schlumberger • "~ ~. a ~~, ~ ` " ~~ _ ,a x ~,~ ~~ F OC.', ~:,=f-= ,~, ;m MICROFILMED 6/30/2010. DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc Chevron FrSsco Castro Chevron North Ana Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 low Anchorage, AK 99503 Tale: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE October 30, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 Jv DATA TRANSMITTAL .:i WELL .:LbG,T'FR -t;rt i4::�: ,..'F HV B -12 PERFORATION RECORD 5" 06- Oct -09 1 1 PDS HV B -13 PERFORATION RECORD 5" 29- Sep -09 1 1 PDS /A..'l2 ft Please acknowled receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received Date: 1 I ~ ~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Anrhnrsn~ _ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver.,0 Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~^ Re- ter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: Permit to Drill Number: Name: Development ~^ Exploratory 207-151 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service 6. API Number: 50-231-20032-00 Property Designation (Lease Number): . Well Name and Number: C-061590 [Happy Valley Facility] Happy Valley B-13 ield/Pool(s): Happy Valley Field / HV Beluga, Tyonek Gas Pool 11. Present Well Condition Summary: ~ Total Depth meas ~ 7,747 feet Plugs (measured) 7,175 & 7,400 feet true verticalf 6,913 feet Junk (measured) 7,392 (sand) feet Effective Depth measured 7,175 feet Packer (measured) 3,500 feet true vertical 6,344 feet (true vertical) 2,697 feet Casing Length Size MD ND Burst Coliapse Structural Conductor 117' 16" 117' 117' 2,560 psi 3,950 psi Surface 1,157' 9-5/8" 1,157' 1,105' 3,090 psi 5,750 psi Intermediate 3,645' 7" 3,645' 2,831' S,410 psi 7,240 psi Production 4,247' 3-1/2" 7,747' 6,913' 10,540 psi 10,160 psi Liner Perforation depth: 6,362'-6,382', 6,660'-6,670', 6,715'-6,725', 6,828'-6,838', 6,970'-6,990', 7,010'-7,030', 7,154'-7,164', 7,189'-7,197', Measured depth: 7 322'-7,340', 7,178'-7,511', 7,520'-7,532' 5,532'-5,552', 5,830'-5,840', 5,884'-5,894', 5,998'-6,007', 6,139'-6,159', 6,179'-6,200', 6,323'-6,333', 6,358'-6,366', True Vertical depth: 6,491'-6,509', 6,347'-6,680', 6,689'-6,701' Tubing (size, grade, measured and true vertical depth): 3-1/2" 9.2# L-80 3,523' MD 2,718' ND / Packers and SSSV (type, measured and true vertical depth): Baker 7" ZXP LTP 3,500'MD(2,697'TVD) N/A N/A ~r Y ~.t ~SDO' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ' ~ ~~ ~ ~ N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 340 psi Subsequent to operation: 0 300 0 0 psi 300 psi 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X . Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager f'"7 . • Signature Phone 276-7600 Date 10/13/09 / STATE OF ALASKA A~AS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~~ ~~~~ ~ ~~ ~~ 3 O~~ei~~~~nrlv.~/" ` oC~ X ~ ~~(~~5 ~t ~Dii ~ a Form 10-404 Revised 7/2009 Submit Original Only i ' Ghevron , ~ ~ Well Name Legal Well Name HV-B13 HAPPY VALLEY B-1 Jobe~ '~ ~ ~ ~ Primary Job Type Job Category Perforating - Post Production Well Services Primary Wellbore Affected HV-B13 Chevron - Alaska Daily Operations Summary Lease Surf 3 C-061590 50 ace UWI ChevNo Original RKB (R) Water Depth (ft) 23120032 LC0002 614.00 , ~°~ gi°~ ~ ~:~, ~ ~ r{ . Actual Start Date Actual End Date ~~ 9/28/2009 5023120032-00 2071510 ;t~- ~~ ~;; ~~:: -~?~.~: ~ 9/28/30Q9 00:00 - 8/29/2009 t~ ~ , _ ~ "~ ~~,~ ~~ . Operations Summary RU slickline, pressure test lubricator 250psi low/3500psi high. RIH tagged fill at 7170' SLM. Confirmed fluid level at 2950' SLM. RD slickline. ° . ~~t~ Of~,00 - 9/8012009 tZb:00 ~ ~ ~ `~, ~` ~ Operations Summary ~ Rig up Schiumberger PT 250 psi low and 3500 psi high. Perforate w/ 2.5" PJ Omega 6spf 60 deg phased guns from 7010'-7030' (T7), 6970'-6990' (T6B), 6828'-6838' (T5) and 6715'-6725' (T4) Sands. Secured well and SDFN. . . .'E~~00 ~ 70~1/2008 OQ.00 ~ ~ Operations Summary Rig up Eline. Pressure test 250psi low/3500psi high and Perforate w/ 2.5" PJ Omega 6spf 60deg guns from 6660'-6670' (T4A) and 6362'-6382' (BLG130) zones. Rig down Eline and turn well over to Production. I~ c.. n ev ro n I HVB-13 Deep Creek Unit I I Le set8 Seria #: C-061590 I I RKB-GL 21.00' RKB-MSL 614.00' ~ 117' Csg ° 0' TOC 12.2 ppg 220 sx 15.8 ppg 187 sx ~ ~,157' Csg 2,766' Calc TOC 12.5 PP9 222 sx 3,500' TOL 3,500' Calc TOC 12.5 ppg 353 sx 3,645' Csg Fill at 7,669.5' on 4/8/08 ORIGINAL RIG Surtace Location: Well Classificaton: Develo ment Gas Well ELEVATIONS 2920' FNL & 337' FEL Total De th: 7,747' Sec21,T2S,R13W,SM pBTD: 7,679' X: ASP4 223.691 Tubinp: 3-%", 9.2#, L-80, IBT-Mod STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS .. ~~C~1V1~~-~~~P3 VJ .~~~. ~ ~ ~~~~ °~ll~~Zoeq 1. Operations Abandon Repair Well Plug Perforations Stimulate ~- • Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver[] Time Extension ~~1C IOr~~~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Devetopment Q- Exploratory^ 207-151 ~ 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: 50-231-20032-00~ 7. KB Elevation (ft): 9. Well Name and Number: 21' Happy Valley B-13 ~ 8. Property Designation: 10. Field/Pool(s): , C-061590 [Happy Valley Facility] Happy Valley Field / HV Beluga, Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 7,747 ~ feet Plugs (measured) 7,175' & 7,400' ~ true vertical 6,913 feet Junk (measured) 7,392' (sand) Effective Depth measured 7,175 feet true vertical 6,344 feet Casing Length Size MD ~ ND Burst Collapse Structural Conductor 117' 16" 117' 117' 2,560 psi 3,950 psi Surface 1,157' 9-5/8" 1,157' 1,105' -. 3,090 psi 5,750 psi Intermediate 3,645' 7" 3,645' 2,831' 5,410 psi 7,240 psi Production 4,247' 3-1/2" 7,747' 6,913' 10,540 psi 10,160 psi Liner Perforation depth: Measured depth: See Attached Schematic ~ ! '' ;~ ~~~i"~ ~ ~x~~~~ ~,~ L ~ ~ True Vertical depth: See Attached Schematic " `` Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 3,523' Packers and SSSV (type and measured depth) Baker 7" ZXP LTP / N/A 3,500' / N/A 12. Stimulation or cement squeeze summary: Upper T-10 frac Intervals treated (measured): 7,154'-7,165' RKB MD Treatment descriptions including volumes used and final pressure: Frac of 65,000 Ibs 20-40 carbolite w 12.5 flexsand ms at 15 BPM 3,954 psi max rate & pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 200 0 0 psi 280 psi Subsequent to operation: 0 0 0 0 psi 800 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ ' WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-171 Contact David Ross 263-7696 Printed Name Timothy C. Brandenburg Title Drilling Manager y Signature ~ C_.~ Phone 276-7600 Date 7/9/2009 Form 10-404 Revised 04l2006 Submit Original Only ~ ~ ORIGINAL ~"~'~~~~"~~~~°°~ • • ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (R) HV-613 HAPPY VALLEY B-13 C-061590 5023120032 LC0002 614.00 JcbB t. ~t ~~~ ~ ~ s ,t. ~y Com letion - Recon~l ' t~~ ~, ~ OOt00 '~ " Primary Job Type Job Category Objective Adual Start Date Actual End Date Completion - Reconfigure Well Services 3/8/2009 3/20/2009 Primary Wellbore Aifected Wellbore UWI Well Permil Number HV-613 5023120032-00 2071510 5/~E;. ~t~~,9 i11~piF W ~~f~l'2008 00:00 ° ~ ` ~ ~ Operations Summary RU slickline. Pressure test lubricator to 250psi low/2500psi high. Ran 2.78" Gauge Ring and tagged PBTD at 7,394' RKB SLM, Fluid level @ 6800' RKB. RD slickline. _ _, 5l'~~/20 00:00 ~ ~l~~~~4~8"t~t~:00~ ., ~ ~ ~ , ,~ , ~~ Operations Summary RU Eline. Pressure test lubricator to 250psi low/ 2500psi high. RIH 8~ set BJ Python Composite BP at 7175' tie in depth, verified w/ tag. RIH & set Weathorford WRP at 3200' RKB, verified w/ tag. RD Eline & secure well. ~. . ,y ~ :- _~,: . 5f201~0,09 00:00 -~2'~t2b09~00:00 ~ ~.,.3, ,~. , ~: ~ ~ ~M ~~ ; Operations Summary Vetco changed out tree to a VG-300 3 1/16"x 10M Tree w/ Vetco-K bonnet and Pressure tested tree 250 psi low and 10 K psi high, Bonnet tested 250 psi low and 5000 psi high. ~ y. ~. ~ ~I211~1~04 00:00 •'S12ZI2008 00 I~O. ~~.~.,: . ~~~'"~` ` .~~ ~ ~~~ ~ ~ OperetionsSummary Fill tubing to 3200' w/ 28 BBLs of Diesel. RU slickline. Pressure test lubricator to 250psi low/2500psi high. RIH and pull WRP at 3,200'. RD slickline. Treatment 5/19/2009 00:00 ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~~ Prima Job T e ry yp Job Category ObjecEve . Actual Start Date Actual End Date Treatment Well Services Frac T-10 Sands 5/19/2009 6/14/2009 Primary Wellbore Affected Wellbore UWI Well Permit Number HV-B13 5023120032-00 2071510 5/19/2069 00:00~ ~ ~5/201~008 OtFrttE1., , .. =~ ~ ~ ~ ~ ~ . ~~: ~;; ; ;_, ~ , Operations Summary Mobiiized miscellaneous equipment, pit liner and dunnage to location in preperation of the HV frac campaign. 5/20/2008'00:00-.51~'t/~.OS~~1QtOQ~~ ~ ~ > , .~ ~~~ <,~~ ~;~ ~~`~ ~ Operetions Summary Preparing location , building tank containment, tree changeout operations for HV-B12 and B-13. ' Sl21/2009 00:00 - 5/22IZQQ9 Q9 df~ ,`~ '.. ,.: Operations Summary ~ Continue to rig up location. 5/22I2008 OO:oo - 51a3/26os oaoo Operafions Summary Continue to rig up location. 5/23/2009 00:00 = 5(24J2009 0(~ .~Ii~f . ~~' ~ : ~ ' ~~ `' ' ~ OperaEons Summary Continue to rig up location. S/2412008 00:00 - 5f~5l2f)09 00:00 " " ' Operations Summary Continue to rig up location. w . , . .. . Y- . ,. r , ~f~ ~,~;~ .~ ~ 5/25/2009 OO:OQ - 5l26i2009 QQ .p~ , ` Operations Summary Continue to rig up location. 5/26f2QIT9 00:00 • ~F~'C/~008 00:00 " ;~". `~:°"r,.`: Operations Summary Continue to rig up location. Transfer 51,000 gals of Jet A to frac tanks. ,, _ 5/2712U09~ 00:00 - 5128I~Q08 Ob,~d ~ ~ ~ : . • ~ ~ Operations Summary Continue Rig up location. Rigged up Schlumberger CT pump to annulus and pressure tested same to 4000 psi. Load and ready N2 tanks and pump. _ ~ ~»...- ~ ~ ,.~ ,~ .. ~ ~,,,,r, ~„ Sl28/20QS 00:00 - 5/28/Z009 ~0 ~)0 ' Operations Summary Prepared location to frac HV-613, pressure tested treating lines to 8500 psi. Pertormed fracture diagnostic tests. Pumped mini frac, started frac job on upper T-10 from 7,154'-7,164'. Half way through the frac job a packing gland on one frac pump caught on fire shut down pumps fire went out. Started remaining frac pump and overtlushed frac treatment into the perts before shutting down. 5/2~I~~10~ Q6:dQ ~.51~O1~00~"Ui~:80 ~ ~ ~ Operations Summary Finished rigging up PTS sand trap and hard lines. Assisted fiiling HV-B12 w/ diesel for e-line work. 5/3~t~~(~9 OdcOQ - ~fF3~tl20~~ Q0.04 ~ Operations Summary Waiting on frac pumps. -~J • ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (R) HV-B13 HAPPY VALLEY B-13 C-061590 5023120032 LC0002 614.00 8I31/2009 OOt00 - 8f }T~O, ~~ll~t.l~`'~~ ~ ~ ~ ~ si . ~ ~. ; : ;, .... . ,_~~' ~ Operations Summary ~ . Primed up P/T backside and treating lines. Primed frac pumps with diesel and fracture stimulated the T-10 zone as per the job design. 32,000 gals Super Allo Frac and 65,000 Ibs 20-40 carbolite with 12.5% flexsand ms. Max pressure 3954 max rate 15 BPM. ND frac tree and NU production tree and flow line and test same. Began rigging up the frac head and lines to HV-612. SI pressure 350 psi, open well and begin Flowing through sand trap to weir tank 31 bbls before pressure bled to 0 psi. Begin rigging up Schluberger CT. Notice given to AOGCC of upcoming CT BOP test. ~'11~~~t~1~kt:() *` ~f2Q09 00:Q0 ° ' ai.,,~~` N., Operations Summary Tested CT BOPs 250psi low/4000psi high, witness waived by AOGCC Jim Regg. RIH pumping diesel @ 0.5 BPM tagged plug hard @ 7,117' S8' above python plug at 7,175' WLM depth, Begin unloading well with N2, recovered 208 bbls of diesel for the day. ~. ~.. ~~ooa oo:oo - ~t~o~~a~aio' ~. Operations Summary Continue unoading well pumping N2 at 700 scfm, varying depth from 5,000' - 7,000'. Disel returns at 6-8 BPM. Shut down to wait on N2 delivery. SITP built to 170 psi in 1 hour. POOH to 1000' and transfer N2 from transport. Open well to diffuser tank 37% LEL. RIH at 500 scfm increasing to 600 scfm. Tagged at 7,156' CTM. POOH and begin pumping 500 scfm with average returns of 7 BPH at 8% LEL. Shut down N2 while transferring N2 to work tanks, minimal to no flow. Continue unloading with N2 at 7,000' varying rates to find the best returns, 4-6 bph average. Move coil periodically to check weights. Tagged bottom at 02:00 at 7,175' RKB. srat~uo~~no;ao~~ ~oo~~oo:oo ~ ~ ~ : ~~~ p~., ~~~ ~ ., .. . , r~ ,. Operations Summary Continued to lift well with N2 @ 7000' and 400 scfm, varied rate to get max fluid retums. Returns varied from 4 bph tapering off to 1 bph. Closed in choke and pressured up well with N2, surged pressure, shut well in to observe pressure build up. total fluid returned approximately 360 bbis 6/4f~009' 00:00 = 6/SI~dQ~ OO~i10 ' ; , , _ ;v .x... Operations Summary Continued to surge well by allowing it to build up and bleeding down to diffuser tank, varying choke settings in an attemp to achieve a stabilized rate. _ ~ 6/9i200~ 08:tl~ • $Mb~~009 00:00 ~ ~~ , ~ ~ r ~ , ,,; ,: Operations Summary Monitoring Production. ~ ~ ~ ~ .,~ _ z~ ,; ;~~, 6/91200& 00:00 - 6E1012~09-00:00~~ ~ Operetions Summary ~ Inactive w t ,.. ~,~: ~ ~ s.. 6/12120Q9 00:00 • 6I13/2009 00:00 A.. . r~. Operations Summary RU Schiumberger CT, performed BOP test 250psi low/ 4000psi high (witness waived by AOGCC Jim Regg. RIH to unload well pumping 300-500 scfm. recovered 42 bbls of dieseL , ~;,~.~..- ~, ~ ~ „,. 8/73/20QS 00:00 - 6/14/2008'00:00 Operations Summary Continue to RIH to unload diesel, tagged sand plug @ 7100' , circulated thru bridge and continued in hole pumpin 500 scfm at 1275 psi. Tagged python plug at 7232'. CBU and recovered an additional 34 bbis of diesel until fiuid retums stopped. Shut down N@ and monitored well for 2 hrs. re-started pumping 500 scfm N2 @ 6000'. RIH and tagged sand again @ 7100'. Circulated thru bridge and continued in hole to tag python @ 7232', 47' deeper than 1 st tag. Continued unloading for 4.5 hrs recovering an addition 38 w/ light proppant. POOH to 5000' pumping 500 scfm and 613 psi for 30 minutes until well blew dry. Ran back in hole pumping 500 scfm and tagged python @ 7232', CBU and recovered an additional 5.5 bbls of diesel in 3 hours w/ no sand. Stopped pumping and monitored well for 2.5 hours. Ran back in hole one more time, tagged python circulated 30 minutes and POOH. Stopped N2 @ 2000' recovered an additiaonl 4 bbls of diesel for a total of 500.5 bbls recovered to date. RD CT and open well to the PTS sand trap. Monitored well bleeding off. RKB-GL T 21.00' + RK&MSL1~~ 814.00' ~ ~ 117' Csg " 0' TOC 12.2 PP9 220 sx 15.8 ppg 187 sx ~ 1,157' Csg 2,766' CaIcTOC 12.5 ppg 222 sx 3,500' TOL 3,500' Calc TOC 12.5 ppg 353 sx 3,845' Csg Fill at 7,669.5' on 4/8/08 ~ HVB-13 Deep Creek Unit I I Permitto Drill#: 207-151 Lease 8 Serial#: C-067590 Dec 2007; Rig Release ORIGINAL RIG SuAace Location: Well Classificaton: Develo ment Gas Well ELEVATIONS Zg20' FNL 8 337' FEL Total De th: 7,747' Sec 21,T2S,R13W,SM PBTp: ~ g~g~ X: ASP4 223,691 Tubin : 3-'/:", 92#, L-80, IBT-Mod ., Chevron Timothy C Brandenburg Drilling Manager May 13, 2009 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Supplements to (Form 10-403) for Wells HV-612 and HV-B13 Tom, • Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7884 1~ MAY :~ ~ 1.1719 Plgeka Oi{ k#- Gas Cons. ~011`frtl(t;~I~p A~n~har~~a Attached please find hard copies of the information I sent to you via a-mail on Wednesday 5-13-09; Should you require any additional information please don' Regards, ~--, ~'- David A. Ross Completion Engineer TCB: stp . ~~~~~ ~- 's ~ tt~, ~~~ Attachments: HV-B13 Cement Bond and Fracture Cross Sections.doc HV-B12 Cement Bond and Fracture Cross Sections.doc Description of BJ services Super Rheogel System Frac Tree Schematic (Also included with the 10-403 for HV-B13) Union Oil Company of California / A Chevron Company http://www. chevron. co m HV-B12 Cement Bond and Fracture Cross Sections.doc Gamma GR Awrsp~ GAA Aillpatlia~ km AmpI1tUM Noc ~ TMbDn NS ~ f [GQPII 160 [AVNAI (~( ~~ ~DL Vart~DNDancily (YDL) ---.______..... ___ ________ N10 [LBFI 0 (uSi tZ00 :saw w:m *.wa .ssau ~~ +:ssu ~,sa» w,ww ¢x:sw :-saw Ritatfw Bidrlll$jRe SCHT(__ ___GBL Am~ftuM,[CBLI,,, __ ;:usso [DELI 300 {YV) 10 w~ ;.:.rw ::nrn .~ :•„ NJ1G0 .~...~ T.gwp T~'aw 0~4aY9 G1 iaY] rsaoa uwr. a.~« s: „w .s;:H:c CBL ampptua 1aGPIM1B tnap~ (1 • N6p f NPL'/Fj [~I cas.nrnlwtTrno rr cBLnm ua csL {usI ioe {NV) is Nummum ~Tnn4t Tn1M ~ ~ Goon Bona (LOBO) -- -- ---- is (usI 300 (NVI to -/xzlmum GR.P TranGt TNw Npnpn~nn NAP 0.mpetuW _ - - I IRXTT~ - - - _ _ ~NIN4L _ 700 (Ufi 300 (N4I 100 .............. GOOaBOna Ft0an ACBL t0 GO6O lgztmum IL1P .YmplttuaB _--1ncxNaL_-- fNVI goo i HV-B12 Cement Bond and Fracture Cross Sections.doc MD ft 10100 Happy Valley B12 At Closure Stress (psi a ~n c~ .- w. 650 0 00 800 10200 10300 T-155 100 200 300 Fracture Penetration (ft) r • HV-B12 Cement Bond and Fracture Cross Sections.doc W2111D:HappyValleyB12 T-155 Set Shift ~' 3 Layer Model ~' Multi Layer Model f' TVD ~= MD Stress Stress at Stress at MD Depth Stress Gradient Top of Stress Bottom of to Top of Difference from Surface Zone Gradient Zone Modulus Layer Zone (ft) Type (P~) (ps/ft) (g) (Pslft) (g) (MMpti) 1 10110.1 Silty 0.0 0.750 7433.0 0.500 7455.9 3.09 2 10155.9 Coal 498.1 0.799 7954.0 0.500 7956.2 0.93 3 10160.3 Silty X25.2 0.736 7331.0 0.500 7336.5 2.28 4 10171.3 Coal 12.5 0.737 7349.0 0.500 7350.6 2.32 5 10174.5 Silty 101.4 0.747 7452.0 0.500 7460.8 2.66 6 10192.1 Coal 403.2 0.787 7864.0 0.500 7865.1 2.48 7 10194.3 Silty -462.1 0.740 7403.0 0.500 7420.9 3.17 8 - A 0230.0 Gas -529.9 0.687 6891.0 0.500 6901.1 .' 2.45 9 10250.3 Silty 588.9 0.745 7490.0 0.500 7501.9 3.10 10 10274.0 Coal 398.1 0.784 7900.0 0.500 7906.6 2.10 11 10287.2 Silty -356.6 0.748 7550.0 0.500 0.0 3.00 Fluid Loss Coefficient Spurt (ft/root Loss ~-ic tmin~~ t auiuum•. 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 ~: 0.00000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 Fluid Loss High Angle Well r Transverse C' Longitudinal MD Fracture Initiation Perforations Top (ft) Bottom (ft) Top (ft) Bottom (ft) Geologic Model 10240.0 10244.0 10240.0 10244.0 r Allow Natural Fracture Fluid Loss OPTIONAL Input (Only for K1W Calculations) Spurt Time Use Detailed r Loss Controlled by "Fines" Actual v Top of Pay (ft) Bottom of Pay (ft) (min) Fluid Loss ^gase" Fines Cc c. 0.000 0.0 0.0 0 20 Cw (ft/sgrt(min )> 0.00000 i HV-B12 Cement Bond and Fracture Cross Sections.doc I11~~~~ ~. i; =~, `t .^>amllu GR AwN~ Amp~u00 tie 4mp0tutl~ Mtt TOnaon ~Nf~ [G:.PII 100 { ~ nrv loo VDLWaM6MD~edty(VDL} ...••• . ••••___. toff (LBF} 8 ~ } xa {us} uoe :~ :aaw ,~ ,~ .~ .:~, ~-~, ......., rz~ r~ .,,p, ,..w .,~ :~aam R4btIW 8iOf1_f/g jR6 SChtT}_, ___ CBL tuuptuDi_(CBL}_____ :~ -~aam (DEGE SCO (MV} 18 csxao Imam ce~mo xaam .s~no T:ooaa rxm amour az amo amour m~oe ooo~m uaam aow r.m CBL 4mpllt IYPPInO ~ [8 - t661(NPU'~! f~l CCt alt Transit Tlmi CBL Am WM CBL {Uf} 180 {I!V) 1M Mlnlmum MOP Tpltiit TYM ~~~ ~~ 60110 {~~) - - -- - - - too {usi sfe (K'/} to thexlmum MAP Tg1KItT11M tMnxnum MAP AmPftllu~ - - ~ r~xrrL _ - - - -1munw~ _ -- - tr~ lus soo {rrv} teo .............. Goo06an0 Fr0a0 AtBL m LOBO Nfaxlmum If,:.P AmplttuOB _ - -1alxtz:` _ -- (MYy 180 / 1 L_J HV-B12 Cement Bond and Fracture Cross Sections.doc Happy Valley B12 t31 Z MD ft 9600 T-140 9700 9800 • Fracture Penetration (ft) HV-B12 Cement Bond and Fracture Cross Sections.doc Well ID: Happy Valley 612 T-140 Set Shift C' 3 Layer Model o=' Multi Layer Model ~' TVD ~= MD Stn:ss Stress at Stress at MD Depth Stress Gradient Top of Stress Bottom of to Top of Difference from Surface Zone Gradient Zone Modulus Layer Zone (ft) Type (Pg) (psi/ft) (p~) (Psi/ft) (Pg) (MMps) 1 9616.5 Silty 0.0 0.757 7128.0 0.000 7128.0 3.29 2 9670.0 Coal 1222.0 0.881 8350.0 0.000 8350.0 1.71 3 9681.0 Silty -1272.0 0.746 7078.0 0.000 7078.0 3.90 4 9700.0 Gas -687.0 0.672 6391.U `: 0.000 - 6391,. - 5. 5 9745.0 Silty 1460.0 0.822 7851.0 0.000 7851.0 4.89 6 9759.1 Coal 599.0 0.884 8450.0 0.000 8450.0 1.71 7 9769.5 Silty -1115.0 0.766 7335.0 0.000 7335.0 3.68 8 9777.3 Coal X23.0 0.701 6712.0 0.000 0.0 2.22 Fluid Loss Coefficient Spurt (ft/root Loss K-Ic (min) al/100ft^2) 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 - 000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 Fluid Loss High Angle Well (~ Transverse C' Longitudinal MD Fracture Initiation Perforations Top (ft) Bottom (ft) Top (ft) Bottom (ft) Geologic Model 9740.0 9742.0 9740.0 9742.0 r Allow Natural Fracture Fluid Loss OP710NAL Input (Only for KfW Calculations) Spurt Time r Use Detailed r Loss Controlled by "Fines" Actual Top of Pay (ft) Bottom of Pay (ft) (min) Fluid Loss "gass" Fines Conc. 0.000 9700.0 9745.0 0 20 Cw (ft/sgrt(min)) 0.00000 U HV-B12 Cement Bond and Fracture Cross Sections.doc Ganmu GR Awrap~ Map ampMtuue Nin amputu~ Nax TSnpOn{TENS~ (GAPI) 100 (avhuli (~) 100 ~DL VarY6NDOnclty (VDL- --•-•- ••••___• 1000 (IBF) 0 {us+ txw :.~ ,~„ ,~ ,~ .:.,,~~ .raw w,ww raw u:w a:sw :: aw •noaw •taw .~ ibtp!o 891r116gfR8 SCNT;-- __CBL N11~[1f01i-{C6LE----_ Raw www i~~] ..s+w 1~~1 500 (K'/1 H :;, c:aw c.au c*:wo *~ww *:.ow •:aooa nyw www Oi-0w Y.J900 maw »asw umw o:aaa; raw ,w.uw CBL ampOtuo~ Nappnp [~1 0613 if TfinGlt TYni TT CBL Am uM CBL {US) 106 {NVE 160 Minimum NAP Tnnctt TqM ~~~ G000 BOntl (~~! -- ---- uo {usE sa (NV~ a Iiac.T.um M:.P Trinctt Tlme I IdXTT Minimum NAP Amp6tWs MINA ~ - - - _ - - iDG I U S1 S60 _ - - ~ ~ _ -_ (NWT 106 .............. GOOUEtOntl .~ FrdnaCBLtOGOEiO IAaximum Ii.AP ampittuoe --lisxra„~~_-- - ~ia~r~ im6 1/ 11 u HV-B12 Cement Bond and Fracture Cross Sections.doc Happy Valley 612 Fracture Penetration (ft) 0 MD ft 9300 9400 9500 9600 9700 Haoov Vallev B12 t Closure T-130 100 200 300 400 500 • HV-B12 Cement Bond and Fracture Cross Sections.doc WeIIID:HappyValley612 T-130 Set Shift C' 3 Layer Model ~' Multi Layer Model f' TVD ~= MD MD Depth Stress Stress Stress at Stress Stress at to Top of Difference Gradient Top of Gradient Bottom of Modulus from Surface Zone Zone Layer Zone (ft) Type (P~) (s/ft) (pg) (Psi/ft) (g) (MMps) 1 9424.4 Coal 0.0 0.680 6277.0 0.500 6283.8 1.59 2 9438.0 Silty 822.2 0.769 7106.0 0.500 7127.1 3.54 3 9480.2 Gas -1048.1 0.655 6079.0 0.500 6089.1 4 9500.5 Silty 1333.9 0.798 7423.0 0.500 7442.3 4.92 5 9539.1 Coal -306.3 0.764 7136.0 0.500 0.0 2.51 Fluid Loss Coefficient Spurt (ft/root Loss K-Ic (min)) (gal/100ft"2) 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 0.00400 0.00000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 Fluid LOSS High Mgle Well (•' Transverse C' Longitudinal MD Fracture Initiation Perforations Top (ft) Bottom (ft) Top (ft) Bottom (ft) Geologic Model 9485.0 9497.0 9485.0 9497.0 r Allow Natural Fracture Fluid Loss OPTIONAL Input (Only forKiWCalculations) S urtTime Use Detailed LossControlle'oy'=i-:es" p r r Actual Top of Pay (ft) Bottom of Pay (ft) (min) Fluid Loss ^gase" Fines Cor c 0.000 , 0.0 0.0 0 20 Cw (ft/sgrt(min)) 0.00000 I • HV-B12 Cement Bond and Fracture Cross Sections.doc Gamnu GR A MpPArn w~ ~~ Nfn Amputua~ Mq T~nibn ~TENS~ _ [G~:PI) 100 [ANNA) [fx~y iao VDL VIMONDnM1Nly IVDL) - -------- ...... 1000 [LBF) 0 Leo {us) uoo ;_;q,9 :;.~ ,:~; ,,.,~~;. .~,,;; •:,,,w ~~ A,0111 fzeratrveeaanrvgjrt6 acnrr[-- ---cs~wnpftua-{cs~)----- :::.>: ''"°' `:a.: :Sw.>r <,~ 111009 116110 R~ 000000 025000 ,y 050090 0T~90 tl0600 L:A99 4i 1)]9 0'1000 1000060 CBL AmpYtuW Mnpplnp IOYpO (0.1M) [I~NYVF) [~1 Cbl 3.Tt TfanGt TYM CBL AM IItl~ CBL {US) MO {Ml) 100 Mlrvlmllm MAP TrarvNt TMn ~ ~ T~ ~~ ~~ [~~) 700 - - {{-U i - - 700 ) (AN) 10 f~5rlmum fPAP TnrvcH Timr (fA7CTT Mlrvlmum MAP Ampxtnoe AE1AW , _-- ~--- ius; wee _--~ ~--- [t[v) 100 .,. ~~ .. cooneonn .... .~ FfomACBLtDG060 "`--vr.`-.1~~~ f9:as:imum ff-G.P mplttu0e 1ft xr.~ ~ _ . - - - [f~r~r) - io® 1r~ u HV-B12 Cement Bond and Fracture Cross Sections.doc Happy Valley B12 Stress u n C n c MD ft 9100 9150 9200 9250 9300 Happy Valley B12 t Closure T-105 50 100 150 200 • Fracture Penetration (ft) HV-B12 Cement Bond and Fracture Cross Sections.doc Well ID: Happy Valley 612 T-105 Set Shift ~' 3 Layer Model ~= Multi Layer Model ~' TVD ~= MD MD Depth Stress Stress Stress at Stress Stress at to Top of Difference Gradient Top of Gradient Bottom of Modulus from Surface Zone Zone Layer Zone (ft) Type (P~) (psi/ft) (pg) (Psi/ft) (g) (MMpS) 1 9149.4 Coal 0.0 0.748 6700.0 0.500 6706.5 1.15 2 9162.4 Silty 48.5 0.753 6755.0 0.500 6758.9 3.59 3 9170.2 Gas X89.9 0.698 8269.0 0.500 6291.4 3.52 ~• 4 9215.0 Silty -536.4 0.638 5755.0 0.500 5756.8 2.68 5 9218.6 Coal 1151.2 0.766 6908.0 0.500 0.0 1.42 Fluid Loss Coefficient Spurt (ft/root Loss K-Ic (min)) (gal/100ft^2) 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 0.00400 0.00000 2000.0 0.00000 0.00000 2000.0 0.00000 0.00000 Fluid Loss High Angle Well it din l C= T C' L ransverse ong u a MD Fracture Initiation Perforations Top (ft) Bottom (ft) Top (ft) Bottom (ft) Geologic Model 9184.0 9196.0 9184.0 9196.0 r Allow Natural Fracture Fluid Loss OPTIONAL Input (Only for KfW Calculations) Top of Pay (ft) Bottom of Pay (ft) Spurt Time (min) Use Detailed r Fluid Loss r LossControlleri t'Y "=r~: y' Actual 0.0 0.0 0 20 "gale" Fines Conc. 0.000 Cw (fUsgrt(min)) 0.00000 • U O N C O :_. U N O U L y-+ U (B L C M0 W C U M m 2 • • HV-B13 Cement Bond and Fracture Cross Sections.doc Happy Valley B13 7100 MD ft 7150 7200 • 7250 Fracture Penetration (ft) 40004200 46004800 HV-B13 Cement Bond and Fracture Cross Sections.doc WeIIID:HappyValley613 T_~Q Set Shift ~' 3 Layer Model ~' Multi Layer Model ~' TVD ~= MD Stress Stress at Stress at MD Depth Stress Gradient Top of Stress Bottom of to Top of Difference from Surface Zone Gradient Zone Modulus Zone ft Layer O Type (Pg) (si/ft) (g) (Psi/ft) (g) (MMpsi) 1 6800.0 Silty 0.0 0.796 4751.3 0.500 4904.5 3.68 2 7110.0 Coal -210.5 0.748 4694.0 0.500 4695.0 1.15 3 7112.0 Sand 57.0 0.757 4752.0 0.500 4760.8 3.50 4 7130.0 Coal -1 .8 0.756 4759.0 0.500 4761.0 1.25 5 7134.0 Silty -17.9 0.753 4743.1 0.500 4751.1 3.59 6 7150.0 Gas -343.2 0.698 4407.9 0.500 4432.5 3.52 7 7200.0 Coal 378.9 0.756 4811.4 0.500 4816.1 1.42 8 7210.0 Silty -131.5 0.735 4684.6 0.500 4733.3 2.68 9 7310.0 Coal 223.5 0.766 4956.8 0.500 0.0 1.42 Fluid Loss Coefficient Spurt (ft/root Loss K-Ic min al/100ft^2) 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 gOOiF 4 ~' ~.dEtl+tt'~1 0.1!0000 2000.0 0.01000 0.00000 2000.0 0.00400 0.00000 2000.0 0.01000 0.00000 Fluid Loss High Angle Well (•' Transverse C' Longitudinal MD Fracture Initiation Perforations Top (ft) Bottom (ft) Top (ft) Bottom (ft) Geologic Model 7160.0 7170.0 7154.0 7178.0 r Allow Natural Fracture Fluid Loss OPTIONAL Input (Only for KtW Calculations) Spurt Time r Use Detailed ~ Loss Controlled by "Fines" Actual Top of Pay (ft) Bottom of Pay (ft) (min) Fluid Loss "gale" Fines Co. c. 0.000 0.0 0.0 0.20 Cw (ft/sgrt(min)) 0.00000 • Super Rheogel Description.doc PRODUCT DESCRIPTIONS Carbolite, 20/40 A man-made, low density, medium strength ceramic proppant. It has a density only slightly higher than sand while providing improved conductivity. It is used in medium closure pressure situations. Registered Trademark of Carbo Ceramics. Jet A Diesel (Supplied by Customer) GBO-5L A liquid breaker for the Super Rheo Gel oil-based fluid system. GO-64 Gellant for Rheo Gel Crosslinked oil system. NE-110W An anionic surfactant used in both oil and aqueous solutions to break crude oil emulsions and water blocks. XLO-5 Crosslinker for Super Rheo Gel Crosslinked oil system. GENERAL INFORMATION The Super Rheo-Gel System is a fracturing fluid design exclusively for continuous mix hydraulic fracturing applications. This system can be applied to formations with temperatures ranging from 80°F (26.7°C) to 250°F (121.1 °C). Super Rheo-Gel is compatible with kerosene, diesel, and a wide variety of crude oils (Asphaltene content should be less than 2% by weight. Additional testing will be required if content is above 2% and it may not work depending on temperature, pump time, etc.) Each oil sample to be used for the fracturing operation should be evaluated before using at temperature. The amount of gelling agent and activator chemicals required will depend on the BHT of the well. Super Rheo-Gel may be formulated to work at higher temperatures than 250° (121.1 °C) on a per source basis. Super Rheogel Component Concentrations for HV-B12 & B13 5 gpt GO-64 Gelling Agent 5 gpt XLO-5 Crosslinker 2 gpt GBO-5L Gel Breaker 0.5 gpt NE-110W Non-Emulsifier ' ~ • ~~ Happy Valley 12 and 13 Frac Setup 05/11/2009 Happy Valley HV #12 and 13 Coil tubing BOP, 4 1/16 10M. w/ 4 ram sections 4 1/16 5M Gate Valve - Frac head assy, 4 1 /16 15M run X 2 9/16 15M Y outlets, w/ 2 9/16 15M FE X 1502 plug valves installed on Y outlets Adapter, Vetco-K shld hd flg X 3 1/ Grayloc Mud Cross, 4 1/16 10M FE ~ run x 2 1/16 10M FE wing outlets, w/ 2 1/16 10M FE X 1502 plug valves installed on wings ~I, 3 1/16 10M X 4 1/16 15M e, Vetco VG-M, i 10M FE, HWO, )D trim Qty 2 :o adapter, 3 1/16 10M yloc X 3 1/16 10M API Wellhead assy, Vetco MB-230, 5M FE top x special bottom prep for ~/8 hanger assy, w/ 4- 2 1/16 5M SSO Lubricator Adaptor, 4 1/16 10M • y_ ~ 0~ °G~ R ¢~ f~ ~ pe ~" is ~5 p ~o I! ~ g e ~~ ~ ~ 7 `~ 4 ; 4 ~ E 4 4~ f~„ ~~ r Y ~Z p~ d F lpF C k~! fie,. Y fC R ~ ~@ ~~ P k ~ ~ ALASSiA OIL AHD GA5 COHSERQATIOH COMi~IISSIOH Timothy Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 u S,. h° SARAH PALIN, GOVERNOR ~F k 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 E~~ PHONE (907) 279-1433 FAX (907) 276-7542 .,'~~~~~"-J ~~~` . 4 ZflG Re: Happy Valley Field, HV Beluga/Tyonek Gas Pool, Happy Valley B-13 Sundry Number: 309-171 Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing. has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~~ day of May, 2009 ,\ ~~~ Encl. ~o .~ ~,~'l STATE OF ALASKA ~ MQ~ ~ ~ ~~~ ,, 3 3~ ALAOIL AND GAS CONSERVATION COMMISSION ~~~ o~/i 3 LC~'~ APPLICATION FOR SUNDRY APPROVAL~ska Oil ~ Gas Cons. ICo~i~a~:;aa~~l 20 AAC 25.280 Anchnr~no 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate Q- Time Extension ^ Change approved program^ Pull Tubing^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ ~ Exploratory ^ 207-151- 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-231-20032-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property Tine where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ Ha Valle B-13 , ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): C-061590 Ha Valle Facili ~ 21' Ha Valle Field / HV Belu a, T onek Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ~ 7,747 6,913 7,392 6,561 7,400' (WRP) 7,392' (sand) Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' 2,560 psi 3,950 psi Surface 1,157' 9-5/8" 1,157' 1,105' 3,090 psi 5,750 psi Intermediate 3,645' 7" 3,645' 2,831' 5,410 psi 7,240 psi Production 4,247' 3-1/2" 7,747' 6,913' 10,540 psi 10,160 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# L-80 3,523' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 7" ZXP LTP w/10-408 seal assembly / N/A 3,500' / N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development Q " Service ^ 15. Estimated Date for 5/15/2009 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas Q- Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Ross 263-7696 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 5/12/2009 C. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~=.~C.l/ - / / Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: T~' S ~ ~j,;7 ~ C ~0 ~~~ L? .. - Subsequent Form Required: Q -' ~~ ~, APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ ` ~-~ t~ ~" - Form 10-403 Revised /2006 ~ , .~ ~~- 1 '~ .~ ~ ~~~~ Submit in Duplicate Chevron OBJECTIVE: • Frac T-10 zone. PROCEDURE SUMMARY: • Happy Valley Well #HVB-13 5/7/09 1 RU Eline, pressure test lubricator. i 2 RIH and set composite bridge plug at 7,175' (+/-) 3 RIH and set wireline retrievable plug at ~ OOA"~(+/-) 4 RD Eline. 5 Set 2-way check valve, ND tree, NU Frac tree. POOH w/ 2-way check valve. 6 RU slickline, pressure test lubricator. 7 RIH and POOH w/ wireline retrievable plug at 2,000' (+/-) 8 Rig up Frac equipment, spot CT unit and transport diesel 9 Perform injection diagnostic tests and perform frac on T-10 zone r~~~ h '~p~ P~ ~~~ 10 RDMO Frac Equipment 11 RU CT and Pressure test CT BOPE 250 psi low/ 4,000 psi high ~' 12 RIH w/ CT to clean out proppant, POOH 13 RIH w/ CT and unload well with N2 if required. 14 Set 2-way check valve, ND Frac tree, NU tree POOH w/ 2-way check valve. 15 Demobe & turn well over to production. HVB-13 REVISED BY: CVK 5/7/09 R KR1';I Happy Valley 8-13 PermlRbDrllip: 207-151 Deep Creek Unlt Lease & Serlalp: C•061590 ORIGINAL RIG - ---- --- ------ ---- - -- ELEVATIONS Surface Location: Well Classificaton: Develo ment Gas Well 2920' FNL 8 337' FEL Total De the 7,747' Sec21,T2S,R13W,SM pgTD: 7,679' Y~ ACDd ~~Z !.01 T~ihinn~ 'i_V." Q 71! I _Rn IRT_Mnr1 I ~ Chevron HVB- 3rDeep Creek Unit I ILeaset8 Serial#: C-061590 I D L(R_!_I ORIGINAL RIG ........ ...... ......... ... ... ... .... .,., ~., . -~........-..,.-.... ELEVATION Surfec~e Location: ~~, moo, Well Classificaton: Develop mentG as~Wel.^A 2920' FNL & 337' FEL Total De the 7,747' Sec21,T2S,R13W,SM pBTD: 7,679' Ha ~ alle PPY Y 12 and 13 Frac Setup 05/11/2009 Happy Valley HV #12 and 13 Coil tubing BOP, 4 1/16 10M. w/ 4 ram sections 4 1/16 5M Gate Valve - Frac head assy, 4 1/16 15M run X 2 9/16 15M Y outlets, w/ 2 9/16 15M FE X 1502 plug valves installed on Y outlets Adapter, Vetco-K shld hd flg X 3 1/ Grayloc Mud Cross, 4 1/16 10M FE ~ run x 2 1/16 10M FE wing outlets, w/ 2 1/16 10M FE X 1502 plug valves installed on wings ~I, 3 1/16 10M X 4 1/16 15M e, Vetco VG-M, i 10M FE, HWO, iD trim Qty 2 .o adapter, 3 1/16 10M yloc X 3 1/16 10M API Wellhead assy, Vetco MB-230, 5M FE top x special bottom prep for /8 hanger assy, w/ 4- 2 1/16 5M SSO Lubricator Adaptor, 4 1/16 10M ~~~~/`ED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COFbIIQI~Q~J 2QQ~ REPORT OF SUNDRY WEI,~~;T~ON~ yy t s nns. ommissio~ /N1tr A.._e_ -~ 3-~? 1. Operations Abandon Repair Well Plug Perforations Stim Other ~ Isolate T-17 - Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ - Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development^ - Exploratory^ 207-151 - 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-231-20032-00 - 7. KB Elevation (ft): 9. Well Name and Number: 21' Happy Valley B-13 - 8. Property Designation: 10. Field/Pool(s): C-061590 [Happy Valley Facility] ~E"~- C'/,~°~ Happy Valey Field / HV Beluga, Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 7,747 '" feet Plugs (measured) 7,400' (WRP) true vertical 6,913. feet Junk (measured) 7,392' (sand) Effective Depth measured 7,392 feet true vertical 6,561 feet . Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' 2,560 psi 3,950 psi Surface 1,157' 9-5/8" 1,157' 1,105' 3,090 psi 5,750 psi Intermediate 3,645' 7" 3,645' 2,831' 5,410 psi 7,240 psi Production 4,247' 3-1/2" 7,747' 6,913' 10,540 psi 10,160 psi Liner Perforation depth: Measured depth: See Attached Schematic ..~, _ , n ? ~~ True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 3-112" 9.2# L-80 3,536' Packers and SSSV (type and measured depth) Baker 7" ZXP LTP / N/A 3,500' / N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 1370 psi (shut in) Subsequent to operation: 0 200 0 0 psi 270psi (flowing) 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ - Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas^ - WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-037 Contact David Ross 263-7696 Printed Name Timothy C. Brandenburg Title Drilling Manager ~ Signature Phone 276-7600 Date 4/2/2009 ~~ Form 10-404 Revised 04/2006 ~~~< / .~~~~ r '1 ~ Submit Original Only Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChavNo Original RKB (ft) Water Depth (ft) HV-B13 HAPPY VALLEY B-13 C-061590 5023120032 L00002 614.00 Jobs ------ -- -- Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion -Reconfigure Well 3!8/2009 Services Primary Wellbore Affected Wellbore UWI Well Permit Number HV-613 5023120032-00 2071510 - - __ _ ---- -- Dail Operations -- - _ __ __ 3/8/2009 13:00 - 319/2009 OOc00 __ _ _ - _ - Operations Summary R/U Pollard wireline and run 2.74" GR tagged PBTD 7,663' RKB (SLM) and 2-1/8"x 20' dummy pert guns to drift casing to 7,500' SLM. RD wireline. 3!13/2009 00:00 - 3/14/2009 00:00 _ _ _ _ _ _ Operations Summary R/U Pollard Wireline to run Pressure/Temp. memory gauges to confirm fluid level for perforating. Wireline rams were function & pressure tested on 3-12-09. Pressure tested lubricator 250 psi low/2500 psi high. Run pressure/temp. Fluid level was confirmed @ 6727'. Decision was made to pressure well up with nitrogen in an attempt to push the fluid below 7400' prior to setting WRP. RD slickline. -- 3/14/2009 00:00 - 3/15/2009 00:00 -- - __ _ Operations Summary R/U Schlumberger N2 to push H2O back into formation. Pressured well up to 2500 psi ,pressure bled to 2400 psi in 1 hour. Increased pressure to 3500 psi ,pressure bled to 3150 psi in 15 minutes. RU Eline, pressure tested 250 psi low/2500 psi high. P/U a WRP w/ a-line and RIH to set fa'~ 7400' .RD Eline unit. RU slickline, pressure tested 250 psi low/2500 psi high, P/U a dump bailer and RIH to dump 10' of sand on plug w/ Pollard. 3/15/200900:00 - 3!16!2009 00:00 __ Operations Summary Finished dum in sand on WRP 7400', RD slickline. RU Eline Unit, pressure tested 250 psi low/2500 psi high, P/U 2" Powerjet Omega guns and RIH to shoot the T-13 sand. Correlated depths based on a pup joint @ 6617' ,tagged sand on plug @ 7392', correlated back up hole to sho ot serfs ~ ~ 7322'-7340'. Bled surface pressure to 1883 psi as per program, shot perfs, observed a 2 psi pressure increase to 1885 psi. POOH Ft~cfil-um erger, Eline unit, flowed well to 1200 psi, no gas to surface, shutin well to observe pressure overnight. 3/16/2009 00100 - 3/17/2009 00:00 - - Operations Summary - - - - Pressure increased 7 psi overnight to 1207 psi. Attempted to shoot fluid level without success. Attem ted to flow well b reducin ressure down to 1000 psi , no flow , no build-up. Decision-was made to procee wl pe ora Ing a ower T-10 zone. Pressured well up to 2000 psi with nitrogen and shut down for the night. 3/17f2009 00:00 - 3/18/2009 00:00 _ Operations Summary R/U Schlumberger a-line to perforate the Lower T-10 sand, pressure tested 250 psi low/2500 psi high. RIH and correlated off of pup joint collar @ 6866'. RIH tagged sand @ 7392' correlated back up hole and positioned guns @ 7,189'-7197, Bled well down to 1640 psi-and fired guns, 1 psi pressure increase to 1641 psi. RD Eline unit. Attempted to flow w1e I crown ~~5b~psi~ow, 3 psi gain in 2 hours, flowed well to 1000 psi, no change in 30 minutes, flowed well to 500 psi, no change in 30 minutes, flowed well to atmosphere, no gas to surface 4.5 psi gain in 30 minutes. Shut well in and monitored pressure overnight. - - - - --- 3/18/2009 00:00 - 3/19/2909 00:00 - _ - - _ Operations Summary -- - - ~ - - Bled well down to 0 psi , no gas to surface (3-17-09) shut-in well over night pressure built to 11 psi, RU Pollard, pressure tested 250 psi low/2500 psi high. RIH with P/T memory gauges logged well, results indicated fluid level CcD 7242' , T-10L perfs at (7189-97'), T-13 perfs (7322-40') WRP & sand @ 7388'. RD slickline. RU N2 and pressured up well to 1641 to perforate T-10 U --- - -- 3/19/2009 00:00 - 3/20/2009 00:00 Operations Summary Pressured well to 1641 si w/ N2. Shut in well and RU Eline unit. Pressure tested lubricator 250 psi low/2500 psi high. RIH w/ 2" Powerjet Omega guns and perforated the Upper T-10 sand (7154-64'). RD Eline unit. Drew well down to 500 psi ,pressure built to 800 psi in 2 hours. Flow tested well for 3 hours, 130-135 MSCD CcD_ 274 psi FTP. Shut well in overnight for well pressure build up. Turned well over to production. ' oka_ri Happy Valtey B-13 Perms Drill#: 207-151 Deep Creek Unit Lease & Serial#: C-061590 ORIGINAL RIG ELEVATIONS Surface location: Well Classifcaton: Dever 2920' FNL & 337' FE ~~ moo, Tonal De the 7,747' Sec21,T2S,R13W,SM pgTD: 7,679' v~ ecoe r. z v_^ i . ~ ~ ~ J r,~' Technicai Assistant ®ATE Apri9 1, 2009 To: AOGCC Mahnken, Christine R 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 ~~a~lo7~~ ~®@'~~5 s~s~°s~~ Exy~ii®ra~a®a~ an~§ Pr®~~~~ii®~ 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com - - --- ~ -~ INTERVAL ~ NOTES-LAS, ~~, bVELL LUG TYPE I SCALE LOG DATE RUN # B-LINE CD LOGGED PDS; DLIS i HAPPY PERFORATION VALLEY B-13 RECORD 5" 17-Mar-09 7189'-7197' 4 1 1 PDS HAPPY PERFORATION VALLEY B-13 RECORD 5" 15-Mar-09 7322'-7340' 3 1 1 PDS ~~ti..~~'~3~~ APB :~ ~ ~~~~~ ~~--/5 / ___---' 1~~~~-/ l ~-'~-'~-5~ ._.,, .=.... Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received ~.~ Date: • • a ~ ~ Q d SARAH PALIN, GOVERNOR ALAS~A OIIj A~D GAsS 333 W. 7th AVENUE, SUITE 100 CO1rj5ERQATIOrIT CO1~IIrII55I0IQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Unocal PD Box 196247 Anchorage AK 99519 7~ ~°= Re: Happy Valley Field, HV Beluga/Tyonek Gas, Happy Valley B-13 Sundry Number: 309-037 ,.. ~.~ ,; Dear Mr. Brandenburg: { ~ ~ ~ k' ` ~ ~ `y = ~ ~ ~' 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Sea~nount, Jr. Chair r d DATED this day of February, 2009 Encl. '~~~i1~,`cY G~ `~`l STATE OF ALASKA ~~ "' ~ ~~ ® ~~q ALA~OIL AND GAS CONSERVATION COM ION ~~~ ~ ~ ~!'~ APPLICATION FOR SUNDRY APPROVALS ~'~~ ~ -3'~'~ 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate^ - y~ iyer t er^ Af1C~1~g Alter casing^ Repair well ^ .Plug Perforations timulate ^ Time Extension Change approved program^ Pull Tubing^ Perforate New Pool ~~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development O~ Exploratory ^ 207-151 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-231-20032-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Ha Valle B-13 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): C-061590 Ha Valle Facili 21' Ha Valle Field / HV Belu a, T onek Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,747 6,917 7,679 6,849 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' 2,560 psi 3,950 psi Surface 1,157' 9-5/8" 1,157' 1,105' 3,090 psi 5,750 psi Intermediate 3,645' 7" 3,645' 2,831' 5,410 psi 7,240 psi Production 4,247' 3-1/2" 7,747' 6,917' 10,540 psi 10,160 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# L-80 3,536' Packers and SSSV Type: Packers and SSSV MD (ft): Baker 7" ZXP LTP w/10-408 seal assembly / N/A 3,500' / N/A 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ - Service ^ 15. Estimated Date for 2/15/2009 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ~, Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name //~~~ Timothy C. Brandenburg Title Drilling Manager Signature `r ~ Phone 276-7600 Date 1/28/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ - (~' ~ Q«~~~~ ~'L~C~ Plu Inte ri BOP Test g g ty ^ ^ Mechanical Integrity Test ^ Location Clearance ^ ~ r~~`O ~ ~ ~~ Other: ` ~9Sc.~~ C~~ s4~rc~v P cv~Q~~-t- ~ ~ G.CCtiJ ~ - ~ S~l ~ ~-O~j~S ~ w (~3 d -~ c~-~ . a-~`~ Subsequent Form Required: ~I (-~~ _ `v ~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ 3 v ~ Form 10-403 Revised 06/2006 ~'` ~'' ~ ~' F ~`' ~ ~` ~ ~~~ ~!~"~ ~"~, ~~1~ P ~ ~~~~ Submit in Duplicate I ~ Chevron I Deep Creek Unit3 ILeaset8 Serila p: C-061590 I aKa_r_i ORIGINAL RIG .._._. ~__ ......... ...... ....... .,., _... _,,,,.._ .... ,,.. ELEVATIONS Surtace Location: Well Classificaton: Develo ment Gas Well 2920' FNL & 337' FEL Total De the 7,747' Sec 21,T2S,R13W,SM pgTD: 7,679' Y ACDA 777 Cal T..A..... ~ t/_ ~ 7N I CIt IDT I,I..w -,~ Happy Valley B-13 Permit to Drill#: 207-151 .. ev ro n Deep Creek Unit Lease 8 Serial#: C-061590 ORIGINAL RIG ELEVATIONS Surface Location: Well Classificaton: Develo ment Gas Well ouo ^1 ~ 2920'~FNI B 33T FE^^' ~.,, To`al De the ',747 ~,. ~ o~ DoT ...... Sec 21,T2S,R13W,SM pgTD: 7,679' Chevron ~ ~ Happy Valley Well #HVB-13 1/27/09 OBJECTIVE: • Perf and test T- ~ 3, & T-10 sands. PROCEDURE SUMMARY: 1 MIRU SL. RIH w/ GR & tag. Note fluid level. RIH & gauge tbg for WRP plug. RD Slickline 2 MIRU EL. PUMU WRP Plug. RIH set same to isolate the T-17 sands. POOH. RD Eline. 3 RU slickline. RIH dump bail +/- 10' of sand on plug. RD slickline. 4 MIRU EL. NU onto well. Test Lub. 5 PUMU 2.5"x 20' HCD gun loaded w/ 18 feet PJ Omega 6spf charges. RIH with GR/CCL and perf gun and tiain. RIH Perf T-13. POOH. 6 RD Eline. 7 Flow test well for 24 hours If there is flow: a retrievable plug is to be set (contingency A) and further testing of zones will continue. If no flow: skip to step 8. CONTINGENCY A: Al MIRU EL. PUMU WRP Plug. RIH set same to isolate the T-13 sands. POOH. RD Eline. A2 RU slickline. RIH dump bail 10' of sand on plug. RD slickline. END of CONTINGENCY A 8 MIRU EL. NU onto well. Test Lub. 9 PUMU 2.5"x 10' HCD gun loaded w/ PJ Omega 6spf charges. RIH with GR/CCL and perf gun andtie-in. RIH Perf Lower T-10. POOH. 10 RD Eline. 11 Flow test well for 24 hours If T-10 zone is dry: shoot upper T10 with perfs set up for a future frac design (GO TO STEP # 12). 12 MIRU EL. NU ONTO WELL. Test Lub. 13 PUMU 2.5"x 10' HCD gun loaded w/ PJ Omega 6spf charges. RIH Perf T-10. POOH. 14 RD Eline. - MIRU slickline. RIH w/bailer. If Contingency A was done, Bail and retrieve WRP set at Al . 15 Bail sand off WRP set on Line 2. RIH w/ retrieving tool. Latch and release and POOH with WRP. If T-10 zone is wet: pull plugs, patch lower T-10, set WRP to isolate, test upper T10 designed for no future frac. (contingency B) Pull plug. Produce. CONTINGENCY B: MIRU slickline. RIH w/bailer. If Contingency A was done, Eail and retrieve WRP set at A1. B 1 Bail sand off WRP set on Line 2. RIH w/ retrieving tool. Latch and release and POOH with WRP. B2 MIRU Eline. PUMU Owens Tbg Pach. RIH set same to isolate Lower T 10 sands. B3 MIRU EL. PUMU WRP Plug. RIH set same to isolate intervals below new zone/above patch. POOH. RD Eline. B4 PUMU 2.5"x 10' HCD gun loaded w/ PJ Omega 6spf charges. RIH Perf Upper T 10. POOH. BS RD Eline. B6 MIRU slickline. RIH w/ bailer. Bail sand off WRP set on line B4. RIH w/ retrieving tool. Latch and release and POOH with WRP. B7 END of CONTINGENCY B 16 Turn well over to production. HVB-13 REVISED BY: CVK 1-27-09 $vhQi(rOn Ft'anCisCO Castro Chevron North • rica Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE 7anuary 13, 2009 To: AOGCC Mahnken, Christine R 333 W. 7t~ Ave. Ste#100 ~ ,,~ ,~, ~~_~~~ ~~~1 ~,, ~ ~~ Anchorage, AK 99501 /y. { ~ `i ~p'~' j~•~ ~:~i' ~~' tom} ~~ l~ ~ =i`-1-a '-~ (~ I N,~~L LJG TYPE ~ S.,ALE L0~ DATE =tUfJ ,. 6-LI~JE ~ ;;D INTEP.VA! LOGGED NOTES - LkS, PDS, DLIS -,~ CEMENT MAPPING TOOL SRU 312-09 SCMT-GR 5" 1-Nov-08 1 1 1 3650-6000 PDS, DLIS -:"-~~ ;.~=-','~ ~ TBU M-32RD RST -SIGMA 5" 26-Nov-08 1 1 1 50-9300 DLIS, PDS .~ ~ /:'- TBU M-32RD RST -SIGMA TVD 5" 25-Nov-08 1 1 1 50-9300 LAS, DLIS, PDS i5~ ~ i~5`( HV B-13 RST - GR -CCL 5" 12-Nov-08 1 1 1 3600-7685 LAS, DLIS, PDS - ~j ~ ~'~~ ~ HV B-12 RST - GR -CCL 5" 12-Nov-08 1 1 1 3700-10313 LAS, DLIS, PDS )1`~ HV A-8 PLUG SETTING RECORD 5" 7-Dec-08 1 1 1 6077-6301 DLIS, PDS LJ_,`6 ``-f j i ~ HV A-8 PSP -WATER ENTRY 5" 10-Dec-08 1 1 1 4836-6160 LAS, DLIS, PDS i ~~ ~ HV A-8 PSP -DEFT 5" 22-Nov-08 1 1 1 4900-7300 PDS, DLIS ,~ :~ yLj ~ IRU 13-31 USIT 5" 2-Dec-08 1 1 1 50-6250 LAS, DL1S, PDS L~~ r~C7 IRU 13-31 PRESSURE TEMPERATURE 5" 10-Dec-08 1 1 1 100-6192 LAS, DLIS, PDS J1 y~ . , Please acknowledge receipt by signing and returning one copy of thi,'tra` f~07 263 7828. ,~ Received~~y ~ _- Date: ~;'`;~~~ ~ ~ ~~~ \\~~ f'~ ~,t'; i ~~ri®.~ DATA SUBMITTAL COMPLIANCE REPORT 12/15/2008 Permit to Drill 2071510 Well Name/No. HAPPY VALLEY B-13 Operator UNION OIL CO OF CALIFORNIA MD 7747 ND 6917 Completion Date REQUIRED INFORMATION Completion Status 1-GAS Current Status 1-GAS UIC N Mud Log Yes Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: LWD (GR-Res) Wireline (Caliper-GR-Res-Den-Neu-Son-CMR) Well Log Information: Log/ Electr (data taken from Logs Portion of Master Well Data Maint Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments l~t'pt Report: Final Well R C 15907~e Notes f! g See Notes 2 Col ~og See Notes 2 Col ,t'og See Notes 2 Col tf Log See Notes 2 Col "/Log See Notes 2 Col Log See Notes 2 Col ~al ~ ~lei+tfon ~~,Qy ~~ 25 Col 1 C C •~ og ement Evaluation 5 Col 1 ' ,Q~C/og Caliper log ~ Col 1 L~D C I 15908 See Notes / 0 0 Open 2/7/2008 Final Well Report, Mud Equip & Crew, Gen Well Details, Geo Data, Drill Data, Daily Reports 0 0 Open 2/7/2008 Final Well Report, Mud Equip & Crew, Gen Well Details, Geo Data, Drill Data, Daily Reports w/BOP Reports, LAS, PDF Log Files, DML Data 100 7747 Open 2/7/2008 MD Formation Log 100 7747 Open 2/7/2008 TVD Formation Log 100 7747 Open 2/7/2008 MD LWD Combo Log 100 7747 Open 2/7/2008 ND LWD Combo Log 100 7747 Open 2/7/2008 MD Drilling Dynamincs 100 7747 Open 2/7!2008 TVD Drilling Dynamincs 216 7752 GzsQ 2/7/2008 Array Induction - Q~dh Lithodensity, Comp Nuetron, GR, Platform Express 24-Dec-2007 216 3642 Case 2/7/2008 CBL, Sonic Scanner 24- Dec-2007 3642 7752 Case 2/7/2008 Caliper Log 24-Dec-2007 0 0 2/7/2008 Multi LAS and PDF's of CMR, CAL, CBL, Openhole Scanner and Caliper logs. API No. 50-231-20032-00-00 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2008 Permit to Drill 2071510 Well Name/No. HAPPY VALLEY 6-13 Operator UNION OIL CO OF CALIFORNIA API No. 50-231-20032-00-00 MD 7747 TVD 6917 Completion Date Completion Status 1-GAS Current Status 1-GAS UIC N Well Cores/Samples Information: Name __- - --- ', Cuttings ADDITIONAL INFORMATION Well Cored? Y Chips Received? 1~t1d-~ Analysis Y...L?l•- Received? Sample Interval Set Start Stop Sent Received Number Comments 1170 7747 2/27/2008 1183 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 11/6/2007. Daily History Received? ~L N Formation Tops \'G N Comments: Compliance Reviewed By: __ Date: ~ ~~ ~~ v ~ ~,~ ~~~ STATE OF ALASKA ~O~~p ~,~; ~ ~; ~ ~~~~ ALAS~OIL AND GAS CONSERVATION COMM~ON WELL COMPLETION OR RECOMPLETION REPOF~~~P~~'~~~'~ ~~~ ~~-~:~~ 1a. Well Status: Oil ~ GasO Plugged ~ Abandoned ~ 20AAC 25.105 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other^~ Shut in d ~ 20AAC 25.110 ~jti~ No. of Completions: 1 1b. Well Class: . :' Development ^~ Exploratory^ Service ^ Stratigraphic Test^ 2. Operator Name: Union Oil Company of California 5. Date Comp., ~yrs or Aband.: ~7~008 12. Permit to Drill Number: 207-151 ~ ~'7.~C~- ~C~ 3. Address: P.O. Box 196247, Anchorage, AK 99519 6. Date Spudded: 12/4/2007 13. API Number: 50-231-20032-00 " 4a. Location of Well (Governmental Section): SurFace: 2920' FNL & 337' FEL Sec. 21, T2S, R13W, S.M. 7. Date TD Reached: 12/22/2007 14. Well Name and Number: Happy Valley B-13 - Top of Productive Horizon: 3882' FNL & 1368' FEL Sec. 21, T2S, R13W, S.M. 8. KB (ft above MSL): 614' Ground (ft MSL): 593' 15. Field/Pool(s): Deep Creek Unit Total Depth: 4327' FNL & 1893' FEL Sec. 21, T2S, R13W, S.M. 9. Plug Back Depth(MD+TVD): - 7,679' MD / 6,849' TVD - Beluga/Tyonek ~ 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 223,691 y- 2,190,972 Zone- 4 10. Total Depth (MD + ND): - . 7,747' MD / 6,917' TVD _ 16. Property Designation: ~ C-061590 {Happy Valley Prod Facility TPI: x- 222,638 y- 2,190,034 Zone- 4 Total Depth: x- 222,103 y- 2,189,601 Zone- 4 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes ~ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): LWD (GR-Res) Wireline (Caliper-GR-Res-Den-Neu-Son-CMR) 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 16 109 X-56 SurFace 117' 0 117' DRIVEN DRIVEN 0 9-5/8 40 L-80 Surface 1,157' 0 1,105' 12-1/4" 90 / 39 bbl (220 / 187 sx) 0 7 26 L-80 SurFace 3,645' 0 2,830' 8-1/2" 88 bbl (222 sx) 0 3-1/2 9.2 L-80 3500 7,747' 2,702' 6,917' 6-1/8" 142 bbl (353 sx) 0 23. Open to production or injection? Yes~ No~ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) T-17 7,478' - 7,~11' (6,647' - 6,680' TVD), ~Sp~,~ ~~S~ ~'~~ 3-1/2 3500 3500 T-17 7,520' - 7,532' (6,689' - 6,701' TVD), 6spf ~~ j~~ ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~ !; ~~~3P '.~ '~ ~~ '~~:~~~t ~ ~~ 1{ , ~ , .r . a; 26. PRODUCTION TEST Date First Production: 4/4/2008 Method of Operation (Flowing, gas lift, etc.): Flowin currentl shut in Date of Test: 4/22/2008 Hours Tested: 24 Production for Test Period Oil-Bbl: 0 Gas-MCF: 530 Water-Bbl: 0 Choke Size: N/A Gas-Oil Ratio: N/A Flow Tubing Press. 595 SI Casing Press: 0 psi Calculated 24-Hour Rate ~ Oil-Bbl: 0 Gas-MCF: 530 Water-Bbl: 0 Oil Gravity - API (corr): N/A 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^~ Sidewall Cores Acquired? Yes ^ No ^~ If Yes to either question, list formations and intervals cored (MD+ND 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. GGP~PLtT10~d a ' ~ ,~: •~. `~~~~~~ ~~~ i:~~,~ ~ ~ ZQD6 ~~ l~ '\\ Form 10-407 Revised 2/2007 ~~'~~qNTINUED ON REVERSE 1~i- L~ ~~ /' ` /-~' U • - 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested , briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A N/A Beluga - Top 2654 2041 BLG-31 3945 3117 BLG-40 4188 3358 BLG-45 4598 3768 Tyonek-Top 6561 5731 T-1 6594 5764 T-5 6787 5957 T-7 6993 6162 T-8 7055 6225 T-10 7150 6320 T-17 7464 6633 Formation at total depth: T-19 Coal 7674 6843 30. List of Attachments: Operations Summary, Directional Survey, Wellbore Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola 263-7640 Printed Name: Timothv C. Brandenburp Title: Drilling Manager ` . _.~ = r `"~ ~'~6 .~u-_~- Signature: ~ ~ _ - Phone: ~-7600 Date: 8/5/2008 C~ ~ 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 1 njection, 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 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. Form 10-407 Revised 2/2007 I~ C h ev ro n I HD ep Creek Un t3 I ILease 8 Serila p: C-061590 I aua_ri ORIGINALRIG .._._. ___ ...__..,,....,...... ..__.,.___.._____ ELEVATIONS Surface Location: Well Classificaton: Develo ment Gas Well 2920' FNL & 337' FEL Total De th: 7,747' Sec 21,T2S,R13W,SM pBTD: 7,679' ~Chevron ~ ~ Chevron - Alaska Daily Operations Summary 18 00:00 - 3/29/2008 00:00 Summary out base oii w/ lease water Mill cement stringers to float coliar at 7677.5' CT RKB 18 00:00 - 3/30/2008 00:00 Summary Rig up Schlumberger Eline and log Cement bond log. Rig down Eline 3/30/2008 00:00 - 3/31/2008 00:00 Operations Summary RIH w/coil to 7677'. Unload 70 bbls of fluid (Baraklean & freshwater) from well with 3/31 /2008 00:00 - 4/1 /2008 00:00 Operations Summary De-mobe coil and get pit liner ready to send to Swanson. 4/1/2008 00:00 - 4/2/2008 00:00 Operations Summary Clean out tanks and heip production set up testing equipment. 4/3/2008 00:00 - 4/4/2008 00:00 Operations Summary Rig up Eline. RIH taf fill @ 7,676.5' Perforate T-17 Sand 6spf @ 7478' to 7511'. Rig 4/4/2008 00:00 - 4/5/2008 00:00 Operations Summary Purge and flow test HV-B13 4/5/2008 00:00 - 4/6/2008 00:00 Operations Summary Rig up Eline. Reperf T-17 sand w/ more under balance at 6spf. 7479.6' to 7511'. Ric 4/7/2008 00:00 - 4/8/2008 00:00 Operations Summary Ran Flowing Pressure/ Temperature survey. 4/8/2008 00:00 - 4/9/2008 00:00 Operations Summary R~up Eline. Added 12' perfs in the T-17, 6spf. 7520' to 7532'. Rig down Eline. POOH wlcoil and leave 2500 psi on well. Well Name Field Name API/UWI Lease/Serial CHEVNO License No./Prope... Orig KB Elev (ftKB) Water Depth (ft) HV-813 Deep Creek Unit 502312003200 C-061590 LC0002 2071510 614.0 0.00 Page 1 of 2 ~ Maunder, Thomas E (DOA) From: Gresnstein, Larry P [Greensteinlp@chevron.com] Sent: Wednesday, Juiy 30, 2008 12:03 PM To: Maunder, Thomas E (DOA) Subject: ~VV: Mappy Vailey B-13 (207-151) Tom, • I talked with Stan also. He understands what needs doing and getting with Marcus will make it happen to your satisfaction. Good seeing you at the meeting. Take care. Larry From: PORHOLA, STAN T Sent: Wednesday, July 30, 2008 11:57 AM To: 'Maunder, Thomas E (DOA)' CC: Greenstein, Larry P Subject: RE: Happy Valley B-13 (207-151) Tom, I will get with Marcus Barbee who submitted the 404 and get back with you. Stan Porhola Drilling Engineer MidContinent/Alaska Bu~iness Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 764p Fax 907 263 7884 Cell 907 229 1769 stan. porhola@chevron. com Mai1 Conftderztial Footee Privi/eged/Confidentia/ information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should dest~oy this message after notifying me immediately by rep(ying to the message or contacting me at (907) 263-7640. 12/11/2008 Page 2 of 2 ~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July 30, 2008 11:41 AM To: PORHOLA, STAN T Cc: Greenstein, Larry P Subject: Happy Valley B-13 (207-151) ~b~ ~ SvbM'~~~ ~l~°~~ Stan, I am reviewing a 404 submitted for the cleanout and perforating work done on this well in early April. The work was done according to Sundry 308-091. I need to request a form 407 documenting the completion. There was a 407 submitted in mid January, however since there were no perforations in the well at that time the well status was entered as suspended. My instructions on the 403 may have been a little confusing. What is needed is just the 2 sheet 407 with the completion date noted as 4/6/08. I will add the attachments that you provided with the 404. I have copied Larry since I am not sure you are in the office right now and if necessary he can get this request to someone else to handle. Call or message with any questions. Tom Maunder, PE AOGCC 12/11/2008 STATE OF ALASKA ~: '~ "" AL~ OIL AND GAS CONSERVATIO COf~SI GAS WELL OPEN FLOW P~TEN~~L~ ~T REPORT 1a. Test: ~ Initial Annual Special 1b. Type Test: ! . ~~k~ized Non Stabilized ~ Multipoint ~„ ~ •, ^ ~,~~pchro ~t GO/~~t•;~ Other Constant Time `~~ ~` 2. Operator Name: 5. Date Completed: -"~ 11. Permit to Drill Number: Union Oil Company of California 6/11/2008 207-151 3. Address: 6. Date TD Reached: 12. API Number: PO Box 196247, Anchorage, AK 99519 December 27, 2007 50- 231-20032-00-00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 2920' FNL 337' FEL, SEC 21 T2S, R13W, SM 614' Happy Valley #13 Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 3882' FNL, 1368' FEL, Sec 21, T2S, R13W, SM 7679-6879' Deep Creek Unit Total Depth: 9. Total Depth (MD + TVD): 4327' FNL, 1893' FEL, Sec 21, T2S, R13W, SM 7747'/6917' 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 223691 y- 2190972 Zone- 4 C-061590 TPI: x- 22263$ y- 2190034 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 222103 y- 2189601 Zone- 4 perforated casing 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 3-12" 9.2 2.992 7747' 7478-7511' 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 7520-7532 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): NA NA NA 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): ^ Tubing ^~ Casing 126 F° 1900 psia @ Datum 6060 TVDSS 14.7 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO2: % N2: % HZS: Prover: Meter Run: Taps: NA NA 0.565 0 0 0 26. FLOW DATA TUBING DATA CASING DATA N Prover Choke ifi Li X O pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow o. r ne ce psig Hw F° psig F° psig F° Hr. Size (in.) Size (in.) 1 • X 1417 NA 0 2. X 800 94 3 3• X 750 96 3 4• X 700 96 3 5. X 650 97 3 N Basic Coefficient 24 H ~ Pressure Flow Temp. F Gravity Factor Super Comp. F Rate of Flow o. - our) ( h Pm actor F 9 actor Qi Mcfd Fb or Fp Ft Fpv 1. 0 2. 712 3. 719 4. 730 5. 740 for Separator for Flowing No. Pr Temperature Tr z Gas Fluid T Gg G 1 ~ 585.8 1.707872 0.879 2. 1.396 586.8 1.710787 0.89 3. 1.31 587.8 1.713703 0.891 Critical Pressure 666.4 4. 1.223 588.8 1.716618 0.893 Critical Temperature 343 5. 1.137 589.8 1.719534 0.895 Form 10-421 Revised 1/2004 CONTII~y41E ~~2~~ESIDE (~~~_ ~~~~ Submit in Duplicate ^ r PC 1431.7 pcz 2049764. ~f 1643 p{~ 2699449 No. Pt Pte PcZ-PtZ ~ Pv~ PcZ-Pv~ Ps Ps2 Pf2-Ps2 1. 2. 815 664225 1385539.9 115 13225 2036539.89 s3o 864900 1834549 3. 765 585225 1464539.9 108 11664 2o3s1oo.s9 s73 762129 193732Q 4. 715 511225 1538539.9 100 10000 2039764.89 s15 664225 2035224 5. 665 442225 1607539.9 93 8649 2041115.89 75a 574564 212asa5 25. AOF (Mcfd) 790 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. s' Signed ~ Title Petroleum Engineer n o.26ss Date 6!23/2008 DEFINITIONS OF SYMBOLS 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 Asia Fb Basic orifice factor Mcfd/ h 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 1/2004 Side 2 L~a ~ ~~~~i~~~ STATE OF ALASKA ALAS OIL AND GAS CONSERVA710N COMMI ION REPORT OF SUNDRY WELL OPERATION~~~ o~ z008 Al,aska t'1il R ('~a~ ~;nns. C~nmmi~ainra 1. Operations Abandon Repair Well Plug Perforations Stimulate A ~~~~ Performed: Alter Casing ~ Pull Tubing ~ ~ Perforate New Pool ~ Waiver ~ Time Extension ChangeApproved Program ~ Operat. Shutdown~ Perforate Q` Re-enterSuspended Well^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q- Exploratory~ 207-151 ~ 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic~ Service^ 6. API Number: 50-231-20032-00~ 7. KB Elevation (ft): 9. Well Name and Number: 21' . HV B-13 ~ 8. Property Designation: . 10. Field/Pool(s): Happy VaVley Production Facility (C-061590) ~~ ~./,~/ ,y/d 09 _ Happy Valley Field/Beluga 11. Present Well Condition Summary: Total Depth measured 7,747' ~ feet Plugs (measured) true vertical 6 g~ 7' - feet Junk (measured) Effective Depth measured 7669.5' feet true vertical 6840' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' 2,560 psi 3,950 psi Surface 1,157' 9-5/8" 1,157' 1,111' 3.090 psi 5,750 psi Intermediate 3,645' 7" 3,645' 2,830' 5,410 psi 7,240 psi Production 4,247' 3-1/2" 7,747' 6,917' 10,540 psi 10,160 psi Liner .. ,. .. » -. i~ '~ ~-~ .!4.1i;.`i ~ `~~~~~~~'~' ~' ~ ~ ~ Perforation depth: Measured depth: 7478 -7511 and 75 , > ~ ,~ ;,;, 20 -7532 True Vertica~ depth: 6647'-6680' and 6689'-6701' Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 3500' Packers and SSSV (type and measured depth) Baker 7" ZXP 3500' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 500 0 0 595 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory~ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-091 Contact Marcus Barbee / 263-7605 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~-~ C- Phone 907-276-7600 Date 6/5/2008 Form 10-404 Revised 04/2006 ~ Submit Original O~~`a ~ ~~~5 l~~~"~~ ~` \ ~Chevron ~ ~ ~ Pressure test CT BOP's and Choke 3/28/2008 00:00 - 3/29/2008 00:00 Chevron - Alaska Daily Operations Summary ~ Change out base oil w/ lease water Mill cement strinqers to float collar at 7677.5' CT RKB ~ 3/29/2008 00:00 - 3/30/2008 00:00 Rig up Schlumberger and log Cement bond log 3/30/2008 00:00 - 3/31 /2008 00:00 Operations Summary RIH w/coil to 7677'. Unload 70 bbls of fluid from well with nitrogen. POOH w/coil and leave 2500 psi on well. 3/31/2008 00:00 - 4/1/2008 00:00 De-mobe coil and get pit liner ready to send to Swanson 4/1 /2008 00:00 - 4/2/2008 00:00 Operations Summary Clean out tanks and help production set up testing equipment. aisi2anR no~no _ aiai2ona nn~on alG 1' 1/ JGI IU. I`T / V D8 00:00 - 4/5/2008 0 ns Summary and flow test HV-613 ns no~nn . aisr2aos o ~ Reperf T-17 sand w/ more under balance. 7479.6' to 7511'. ~ 4/7/2008 00:00 - 4/8/2008 00:00 -~ ~ Ran Flowing Pressure/ Tempera 4/8/2008 00:00 - 4/9/2008 00:00 12' perfs in the T-17. 7520' to 7532'. Well Name Field Name API/UWI Lease/Serial CHEVNO License No./Prope... Orig KB Elev (ftKB) Water Depth (ft) HV-613 Deep Creek Unit 502312003200 C-061590 LC0002 2071510 614.0 0.00 ~ Happy Valley B-13 Permit to Drill#: 207-151 ~ evron DeeP Creek Unit Lease 8 Serial#: C-061590 ORIGINAL RIG ELEVATIONS Surface Location: Well Classihcaton: Develo ment Gas Well ~ 2920' ~FNL & 337' FE ~ ~,,, To`al De th: 7,747~ ~.. ~ o„ ~or .._. Sec21,T2S,R13W,SM pgTD: 7,679' Page 1 of 2 Maunder, Thomas E (DOA) From: PORHOLA, STAN T [stan.porhola@chevron.com] Sent: Wednesday, Aprii 30, 2008 8:47 AM ~°~~ ~-- To: Maunder, Thomas E (DOA) Subject: RE: Happy Valley I talked to the completions engineer on Happy Valley B-13. He said he was working on the 10-404 while doing an evaluation on whether we should do additional work on the well (reperf, frac, etc.). Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Ceil 907 229 1769 sta n. porhola@chevron. com Mail Confrdentral Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 30, 2008 8:34 AM To: PORHOI.A, STAN T Subject: RE: Happy Valley Thanks Stan. Not sure when the work was completed, but I checked our incoming log and no 404 has been submitted documenting the work. Tom From: PORHOLA, STAN T [mailto:stan.porhola@chevron.com] Sent: Wednesday, April 30, 2008 8:31 AM To: Maunder, Thomas E (DOA) Subject: RE: Happy Valley Happy Valley B-13 was perforated and was put on production thru temporary facilities setup on B-pad. I'll talk with the completions engineer who was working this while I was on the Slope working the White Hills project. 4/30/2008 Page 2 of 2 Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Celt 907 229 1769 stan. porhola@chevron. com Mail Confidential Foofier Privi/eged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, Aprif 30, 2008 8:29 AM To: PORHOLA, STAN T Subject: Happy Valley Stan, I was just clearing some old messages and one concerned Happy Valley B-13. I looked at the file and the last item is the sundry to complete. Are operations completed? Any information you can provide will be appreciated. Tom Maunder, PE AOGCC 4/30/2008 • ~L117i>•L~ OII/ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5L'`RQA'1'IO1~T COAII~II551O1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 Re: Deep Creek Unit, Beluga/~ronek Gas Pool., Happy Valley B-13 Sundry Number: 308-091 Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this~~ day of March, 2008 Encl. ~~~~ STATE OF ALASKA3~2¢~~ ,~p- ALA~ OIL AND ~ " "~i(a MAR ,~ ~ ~~ GAS CONSERVATION COMMISSION ( , f , APPLICATION FOR SUNDRY APPROVALS~~~ ~ ~ Gas Corns, C `C 20 AAC 25.280 AnnF,n...__ '~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Chevron /Union Oil Company of California Development ^ . Exploratory ^ 207-151 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-231-20032-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q HV B-13 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Happy Valle Production Facility C-061590) 21' Happ Valley Field /Beluga, Tyonek ~° . s.t'' 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,747' _ 6,917' 7,679' 6,849' None None Casing Length Size MD TVD Burst Collapse Structural n/a n/a n/a n/a n/a n/a Conductor 117' 16" 109# X-56 117' 117' 2,560 3,950 Surface 1,157' 9-5/8" 40# L-80 1,157' 1,111' 3,090 5,750 Intermediate 3,645' 7" 26# L-80 3,645' 2,830' 5,410 7,240 Production 4,247' 3-1/2" 9.2# L-80 7,747' 6,917 10,540 10,160 Liner n/a n/a na/ n/a n/a n/a Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Attached Attached 3-1/2" 9.2# L-80 3,536' Packers and SSSV Type: Baker 7" ZXP LTP w/10-408 seal assembly Packers and SSSV MD (ft): 3,500' Baker 7" ZXP pkr & 10-408 SA 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ^~ - BOP Sketch ^ Exploratory ^ Development ^~ ~ Service ^ 15. Estimated Date for 3/21/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenburg Title Driling Manager Signature ,~..-- Date G~, ~ 3 - ~~-o?.~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~~ O ~ I Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: W EL~ C1~Y~0`, E~j v`L ~ 1~ tLy~~ ~ ~.1~ ~ ~C v~S ~®~ Subsequent Form Required: ~,,( `~-~'~-C~.~~~ "~`~.C~ ~"t"~`~t~~'E ~~~ ~~ ~ 1 1 APPROVED BY ~ ~~ ~j A ,lv~ d b ' COMMISSIONER THE COMMISSI N D pprove y ate: Form 10-403 Revised 06/2006 ORIGINAL it in Duplica r,5. Z, Chevron 909 West 9Th Avenue Anchorage, Alaska 99501 Lease Serial # C-061590, Deep Creek Unit Perforation Data: Happy Valley B-13 Permit to Drill # 207-151 API # 50-231-20032-00-00 DATE INTERVAL MD INTERVAL TVD INTERVA L SUBSEA Footage DESCRIPTION ONE TOP BTM TOP BTM TOP BTM Pro osed 7,478' 7,511' 6,644' 6,681' 6,030' 6,067' 33' Prima Tar et Zone ~~ T-17 Backu 7,320' 7,341' 6,490' 6,508' 5,876' 5,894' 21' Secondar tar et zone T-13 Backu 7,155' 7,175' 6,325' 6,345' 5,711' 5,731' 20' Secondar tar et zone T-10 Note: This well has not been perforated, the secondary target zones will only be perforated if primary target zone is unsuccessful • Chevron Lease Serial # C-061590, Permit to Drill # 207-151 909 West 9th Avenue Deep Creek Unit API # 50-231-20032-00-00 Anchorage, Alaska 99501 Perforation Data: Happy Valley B-13 E -Line HV B-13 Perforating Procedure MIRU E -Line Perforating Unit, MU & test perforating tool string. Open the well and RIH to PBTD. Log from PBTD and tie into Schlumberger SCMT log previously run on HV-13 and position gun to shoot interval called for by approved perf sheet for primary target. Fire Guns & POOH Once OOH verify number of shots fired /Place well in test and contact Keith Lopez for plan forwazd; if 4 necessary repeat steps 1 through 4; substituting perf sheet for secondary target # 1 & secondary tazget # 2 respectively, until successful zone has been perforated and tested, Keith will make the call. .. • a Chevron "Deep Creek Uni 3 Lease 8 Serilal#: C 061590 Field: Dee Creek Unit API#. 50-231-20032-00-00 ORIGINAL RIG ELEVATION Surface Location: Well Classificaton: Development Gas Well S 2920' FNL & 337' FEL Total Depth: 7,747' Sec 21,T2S,R13W,SM pgTD: 7,679' ovo l_i v~ econ 77'i AO~ T„1.~nn~ ZV." Q 7L I .Rn IRT_Mnri ~hevrOrl ~ncisco Castro Chevron North erica Exploration and Production -~~ Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE February 26, 2008 To: AOGCC Okland, Howard 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 HAPPY VALLEY B-13 CONTENTS: Washed and Spin-Dried Cutting Samples BOX NUMBER INTERVAL B-1 1170-2340 B-2 2340-3600 B-3 3600-4860 B-4 4860-6060 B-5 6060-7140 B-6 7140-7747 II I,~7 ~ i Please acknowledge receipt by signing anc~ returning one copy of this transmittal or FAX to 907 263 7828. Received By:(/~~-A/i.~LC ~J,~,,(~/~r'/ I Date: ~~ I_G ~f a~ ~ ~ ~s"~ Chevron Francisco Castro Chevron North America Exploration and Production ;~ Technical Assistant 909 W. 9th Avenue '~ ~' ~;w Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com c~~ - DATE February 6, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 - - i NOTES i WELL LOG TYPE SCALE LOG DATE INTERVAL RUN n ~ 6-LIL'E CD LAS, LOGGED i PDS, DLIS' HAPPY VALLEY B-13 CALIPER LOG 5" 24-Dec-07 3642 - 7752 1 1 1 PDS HAPPY CEMENT BOND LOG- VALLEY B-13 SONIC SCANNER 5" 24-Dec-07 216 - 3642 1 1 1 PDS ARRAY INDUCTIN- LITHODENSITY COMPENSATED NEUTRON-GR PLATFORM EXPRESS HAPPY TRUEVERTICAL VALLEY B-13 DEPTH 5" 24-Dec-07 216 - 7752 1 1 1 PDS ARRAY INDUCTIN- LITHODENSITY COMPENSATED HAPPY NEUTRON-GR VALLEY B-13 PLATFORM EXPRESS 5" 24-Dec-07 216 - 7752 1 1 1 PDS ~Cl+-l S! ~ (5°ib~ Please include current contact information if different from above. ,n ., .~ ~ ~_a_ _ .. ~.__ _ Received By: ~ Date: Please acknowledge receipt by signing and returning one copy of this tt~IrdCe ~ 263 7828. ~~~$~~ ilii zw ~ : ,: r~r211,~~~. • • Chevron Francisco Castro Chevron North America Exploration and Production ' -~ Technical Assistant 909 W. 9th Avenue ~Y~~, "' Anchorage, AK 99501 ~~~~`~°` ~ Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com January 15, 2008 Mahnken, Christine R 333 W. 7th Ave. Ste#100 FAR , ,~ , Anchorage, AK 99501 ~ ~~ ~ ~~~~ ~ ~ ~ ~ . I i - - - --- ~ NOTES l"JELL ~ LOG TYPE ~~ SCALE LOS DATE WTERVAL L06GED RUN ! B- ! FILti1 ~ ~ LINE ~i CD -LAS. PDS, DLIS HAPPY VALLEY FINAL WELL REPORT B-13 MUDLOGGING DATA 2" 30-Dec-07 100 - 7747 1 1 1 PDS ~~-~r5`C ~ts~o~3 Piease acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received y: Date: i ~EDE~VED FEB 0 7 2000 ~. FINAL WELL REPORT MUDLOGGING DATA HAPPY VALLEY 13 Alaska Oil & Gas Cons. Commission Anchor~le ~f ~~ Provided by: ~~ EPOCH Approved by: d~~~s.~ ~ I ~~0~ Compiled by: John Lundy Larry Resch Date: 12/30/2007 • Distribution: January 7, 2008 i ~~ _~ ~~ ' ... Chevron January 16, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7~` Avenue Anchorage, Alaska 99501 Timothy C Brandenburg Drilling Manager Re: Well Completion Report and Log (Form 10-407) Deep Creek Unit, Happy Valley B-13 (PTD 207-151) Dear Commissioner: Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7884 ~~ ~~~ ~~ 7C.lC~~ ~i~sk~ ~~~ ~ 8~ 5~ta~:;. ~;~~z~mis~iata ;An~rsor~~ Enclosed for your review is the Well Completion Report (form 10-407) for the Deep Creek Unit Happy Valley B-13 Gas Development Well. The well is currently secured with no perforations, a tree and back-pressure valve. Anticipated completion work will include coil tubing, nitrogen and necessary ancillary equipment to cleanout and displace the base oil in the wellbore. E-line will be rigged up to shoot perforations, flow the well and plugback and perforate as necessary. Approval for this work will be submitted in a separate sundry (Form 10-403) for each well. We are targeting a start date in late spring or early summer 2008, depending on the installation of facilities on Happy - Valley B-pad. Trenching and pipeline work to connect B-pad facilities to those at A-pad was started in October 2007. If additional information is required, please contact either myself or Mr. Stan Porhola at 263-7640. Sincerely, ~~ --. ~ r%~~~ Timothy C. Brandenburg Drilling Manager TCB: stp Attachments: Form 10-407 Operations Summary Directional Survey Wellbore Diagram Cc: Well File Union Oil Company of California / A Chevron Company http://www.chevron.com ~~` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ '~: _,~; WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ^ Gas 0 Plugged ^ Abandoned ^ Suspended Q 2oaaczalos 20AAC25.110 GINJ^ WINJ ^ WDSPL ^ WAG ^ Other^ No. of Completions: 0 x ~ ' development ~Ia: z=~~< Exploratory^ Service ^ Stratigraphic Test^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Sus or~~ -~Ab~a d3i ~ _,112E2998'~i• 12. Permit to Drill Number: " 207-151 " 3. Address: P.O. Box 196247, Anchorage, AK 99519 6. Date Spudded: 12/4/2007 ~ 13. API Number: 50-231-20032-00-00 - 4a. Location of Well (Governmental Section): Surface: 2920' FNL & 337' FEL Sec. 21, T2S, R13W, S.M. 7. Date TD Reached: 12/22/2007 ' 14. Well Name and Number: Happy Valley B-13 Top of Productive Horizon: 3882' FNL & 1368' FEL Sec. 21, T2S, R13W, S.M. 8. KB (ft above MSL): 614 Ground (ft MSL): 593 15. Field/Pool(s): Total Depth: 4327' FNL & 1893' FEL Sec. 21, T2S, R13W, S.M. 9. Plug Back Depth(MD+TVD): 7679' / 6849' Deep Creek Unit Beluga/Tyonek 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 223691 ~ y- 2190972 ~ Zone- 4 10. Total Depth (MD + TVD): i 774T / 6917 ~ 16. Property Designation: FEE-CIRI TPI: x- 222638 y- 2190034 Zone- 4 Total Depth: x- 2224&3 ~f~ ~~ ~;;5 y- 2189601 Zone- 4 11. SSSV Depth (MD + TvD): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes ~ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): LWD (GR-Res) Wireline (Caliper-GR-Res-Den-Neu-Son-CMR) 22. CASING, L INER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING D EPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 16 109 X-56 0 117 0 117 DRIVEN DRIVEN 0 9-5/8 40 L-80 0 1157 0 1105 12-1/4 90 / 39 bbl (220 / 187 sx) 0 7 26 L-80 0 3645 0 2831 8-1/2 88 bbl (222 sx) 0 3-1/2 9.2 L-80 3500 7747 2698 6917 6-1/8 142 bbl (353 sx) 0 23. Open to production or injection? Yes^ No0 If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1 /2 3500 3500 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. 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. ~~ 4 r c!Yw { ~+3~' ~~` ~y}g h ........ .»..w* 3 ~~ ~,,~ ~.3r°`'~3 Form 10-407 Revised 2/2007 CONTINUED ON REVERSE - '~L- Z/( /~ „/ • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ~ No If yes list intervals and formations tested , , briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base N/A N/A Beluga -Top 2654 2041 BLG-31 3945 3117 BLG-40 4188 3358 BLG-45 4598 3768 Tyonek-Top 6561 5731 T-1 6594 5764 T-5 6787 5957 T-7 6993 6162 T-8 7055 6225 T-10 7150 6320 T-17 7464 6633 Formation at total depth: T-19 Coal 7674 6843 30. List of Attachments: Operations Summary, Directional Survey, Wellbore Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Printed Name: Tim Brandenbur4 Title: Drilling Manager ~ ~ Signature: ~ ; 'f Phone: 263-7640 Date: 1/16/2008 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 / njection, 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 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. Form 10-407 Revised 2/2007 ~~ Operations Summary: 11-26-07 to 1-02-08 PTD No. 207-151 (All depths RKB unless labeled otherwise) 11/26/07: Begin rig up on Happy Valley B-13. 11/27/07: Continue rig up on Happy Valley B-13. 11/28/07: Continue rig up on Happy Valley B-13. 11/29/07: Continue rig up on Happy Valley B-13. 11/30/07: Continue rig up on Happy Valley B-13. Happy Valley B-13 Gas Development Well Deep Creek Unit, Alaska 12/01/07: Continue rig up on Happy Valley B-13. Notify AOGCC North Slope Office of anticipated spud. 12/02/07: Continue rig up on Happy Valley B-13. Begin building spud mud. 12/03/07: Continue rig up on Happy Valley B-13. PU 12-1/4" straight hole BHA. MW = 8.6 ppg. 12/04/07: Finish PU BHA #1. Service top drive, drawworks and mudline. Wash and rotate to bottom at 117'. Spud we1104:00 p.m. Drill from 117' to 300'. Circ and cond hole. MW = 9.0 ppg. 12/05/07: POOH pumping out on 1St stand only. Lay down straight hole BHA. PU 12-1/4" directional BHA. RIH washing and reaming from 264' to 300'. Directionally drill from 300' to 814'. MW = 8.9 ppg. 12/06/07: Directionally drill from 814' to 1085'. Service mud pump pop-off. Directionally drill from 1085' to 1115'. Service mud pump pop-off. Directionally drill from 1115' to 1170'. Circ and cond hole. Pump carbide marker flag and estimate 4% washout. POOH to 752'. Back ream from 752' to 508'. POOH to BHA. Lay down BHA. MW = 8.9+ppg. 12/07/07: Continue laying down BHA. PJSM on PU csg. RU to run 9-5/8" 40# csg. RIH w/ csg to 1040' tagging fill. Wash and work casing to 1157'. Circ and cond hole. RU cementers. PJSM. RU and test cement lines to 250/4000 psi. Pump 30 bbl mud push, bottom wiper plug, 90 bbl lead 12.2 ppg slurry, 39 bbl tail 15.8 ppg slurry, top wiper plug. Displace w/ spud mud._Circulated 45 bbls cement to surface._Bump plug and pressure up to 3000 psi - casing test OK. Bleed off pressure and check floats -test OK. Clean rig floor. ND riser, spacer spool and bell nipple. MW = 9.0 ppg. 12/08/07: Continue ND riser, spacer spool and bell nipple. Install multibowl wellhead. Test wellhead to 5000 psi -test OK. NU BOPE. RU to test BOPE. MW = 9.0+ ppg. Final Report Summary page 1 ~ ~ 12/09/07: Test BOPS 250/3000 psi -test OK. AOGCC witness waived by Jim Regg. Service rig to level derrick over hole. PU drillpipe. MW = 9.1 ppg. 12/10/07: Continue PU drillpipe. PU 8-1/2" rotary steerable BHA. RIH to 920'. Service rig mud pumps. Wash down from 920' to _1104'. Tag float equipment. Drill float equipment and rat hole to 1112'. MW = 9.0 ppg. 12/11/07: Continue to drill float equipment from 1112' to 1170'. Drill new formation from 1170' to 1200'. Circ and cond hole. Pressure up and perform LOT at 14.9 ppg EMW. Empty mud pits of spud mud and haul to grind and inject. MW = 9.2+ ppg. 12/12/07: Transfer oil-based mud to mud pits. Circ and cond hole w/ oil-based mud. Directionally drill from 1200' to 1281'. Service rig mud pumps. Directionally drill from 1281' to 2175'. MW = 9.2+ ppg. 12/13/07: Directionally drill from 2175' to 2270'. Service mud pump pop-off. Directionally drill from 2270' to 3108'. Hole starting to lose fluid. Circ 2 bottoms up. Shut down pumps and check losses. Static loss = 0 bbUhr. Drilling loss = 10 bbl/hr. Mix and pump BAROFIBRE LCM at 2 lb/bbl. Directionally drill from 3108' to 3250'. Service mud pump pop-off. Directionally drill from 3250' to 3591'. Drilling loss rate = 8.6 bbl/hr. MW = 9.3 ppg. 12/14/07: Directionally drill from 3591' to 3660'. Circ and cond hole. POOH to 2360', hole started swabbing. Pump out of hole to 1150'. Circ and cond hole. RIH to 3559'. Wash and ream from 3559' to 3660'. Pick up to 3600' and spot LCM pill. POOH to 920'. MW = 9.4 ppg. 12/15/07: Continue POOH. Lay down BHA. Change 4" pipe rams to 7" casing rams. Test 7" \ casing rams 250/3000 psi -Test OK. PJSM on PU csg. RU to run 7" 26# csg. RIH w/ csg to 1141. RU circ swedge and circ hole. Experiencing some losses. MW = 9.3+ppg. 12116/07: Continue RIH w/ 7" csg to 2000'. RU circ swedge and circ hole w/o full returns. RIH w/ 7" csg to 3645'. Losses continue. Circ and cond hole w/o returns. RU cementers. PJSM. RU and test cement lines to 250/4000 psi. Pump 20 bbl mud push w/ 1 ppb LCM, bottom wiper plug, 88 bbl 12.5 ppg LiteCRETE w/ 2 ppb LCM in 1St 50 bbl cement, top wiper plug. Displace w/ mud, did not bump plug. No returns thru most of job. Bleed off pressure and check floats. Floats OK. Annulus flowing at 5 bpm w/ no flow inside casing. Monitor well. Well flow slowed and eventually stopped after 2 hours. RD cementers. Install 7" packoff. Pressure test 5000 psi for 30 min. Test OK. Move HWDP to driller-side in derrick. MW = 9.2 ppg. 12/17/07: PU drillpipe. Build additional mud volume. Change mud pump liners to 4.5". PU remaining drillpipe and stand back in derrick. Test 7" casing 250/3000 psi -Test OK. Install test plug. Change out 7" casing rams to 4" pipe rams. RU to test BOPS. Test BOPs 250/3000 nsi -test OK. Bob Noble w/ AOGCC onsite for witnessing test. Perform safety meeting on Incident Free Operations (IFO). MW = 9.2 ppg. Final Report Summary page 2 12/18/07: Continue w/ safety meeting on Incident Free Operations (IFO). RD BOP test equipment. PU 6-1/8" Directional BHA w/ motor and MWD. RIH to 3385'. Ream from 3385' to 3539' tagging cement. Circ and cond hole. Drill cement from 3539' to shoe at 3645'. Continue drilling cement in open hole from 3645' to 3660'. Drill new formation from .3660' to 3680'. Circ and cond hole. Pick up into 7" casing at 3640'. MW = 9.2 ppg. 12/19/07: RU to test shoe. Perform FIT = 14.6 ppg EMW, no leak-off. RD test equipment. RIH to 3680'. Directionally drill from 3680' to 4512'. MW = 9.2 ppg. 12/20/07: Drill from 4512' to 5574'. Lost 700 psi on mud pumps. Service mud pump #1 suction screen. Drill from 5574' to 5703'. Service mud pump #2 suction screen. MW = 9.3 ppg. 12/21/07: Drill from 5703' to 5832'. Service top drive. Drill from 5832' to 6476'. Service top drive. Drill from 6476' to 6894'. MW = 9.2 ppg. 12/22/07: Drill from 6894' to 7506'. Service mud pump #2. Drill from 7505' to 7747'. Circ and cond hole 3 bottoms up. Wiper trip from 7747' to 3645'. Circ and cond hole at 7" shoe. MW = 9.2 ppg. 12/23/07: RIH from 3645' to 7698'. Wash and ream fom 7698' to 7747'. Circ and cond hole. POOH from 7747' to 7600'. Pump dry job. POOH from 7600' to 3640'. Laydown drillpipe to BHA at 937'. Stand back HWDP. MW = 9.2 ppg. 12/24/07: Laydown directional BHA. RU for Openhole Logging. PU Quad Combo (GR-Res, Den, Neu, Son) logging tools. RIH w/ Quad Combo to 7,754' WLM. Logging up from 7,754' to 3642' WLM. Run back to 4600' WLM for repeat pass. Logging up from 4,600' to 4300' WLM at 700 ftThr. Log inside 7" casing from 3642' to 300' WLM. Estimated TOC behind 7" = 2766' MD. POOH w/ Quad Combo logging tools. Lay down Quad Combo logging tools. MW = 9.3 ppg. 12/25/07: Continue lay down of Quad Combo logging tools. PU CMR logging tools. RIH w/ CMR to 7747' WLM. Logging up to 5800' WLM. Tool not working correctly. Run back to 7358' WLM. Logging up from 7358' to 3650' WLM at 600 ft/hr. POOH w/ CMR tool. Lay down logging tools. Test annular and VBR rams to 250/3000 psi. RU to run 3-1/2" liner. MW = 9.3 ppg. 12/26/07: PU and RIH 3-1/2" casing to 3642'. Circ BU. RIH w/ 3-1/2" casing and liner equipment. Tag bottom at 7757' tubing measurement. Circ and cond while reciprocating. RU cementers. Drop ball to set liner. MW = 9.3+ppg. 12/27/07: Finish RU cementers. Test cement lines to 250/4500 psi -Test OK. Pump 27 bbls 10.5 ppg mudpush, 146 bbls 12.5 ppg LiteCrete cement, and displace w/ 70 bbls 7.5 ppg Base Oil. Set liner hanger w/ 5 bbls cement away. Bump plug and hold 3050 psi for 10 min to. test casing and insure liner set -Test OK. Base of 3-1/2" liner at 7,740'. PU to release from liner hanger. Set down w/ 30k to attempt setting ZXP liner top packer. ZXP would Final Report Summary page 3 • not set w/ multiple attempts. Circ out mud push and cement off liner top until clean base oil to surface. Attempt to set ZXP w/ no success. Close annular and pressure test liner top to 2560 for 30 min. Bled to 2320 psi. Well static. RD cementers. Circ BU. POOH w/ liner running tools. Service rig pit system. Finish POOH. Lay down liner running tools. Clean and clear rig floor. PU spear collar stop and drill collars to attempt setting of ZXP packer. MW = 7.5 ppg. 12/28/07: RIH w/ spear collar stop and 4-3/4" drill collars. Tag top of liner at 3500' DPM. Set down w/ 45-SOk to attempt to set liner. Pressure test top of liner to 3200 psi for 30 min. Test - OK. Pressure test inside 3-1/2" liner to 3200 psi for 30 min. Test - OK. PU out of liner. Circ BU. POOH laying down drillpipe. MW = 7.5 ppg. 12/29/07: Continue laying down drillpipe. Lay down spear collar stop and drill collars. Pull wear bushing. RU to run 3-1 /2" completion tubing. RIH w/ 3 -1 /2" completion tubing w/ seal assembly and chemical injection mandrel. Land hanger w/ 8k. Test hanger seals to 5000 psi for 30 min. Test - OK. MW = 7.5 ppg. 12/30/07: Test 3-1/2" tubing x 7" casing annulus to 3200 psi for 30 min. Test - OK. Test 3-1/2" tubing to 3200 psi for 30 min. Test - OK. RD testing equipment. Install BPV in tubing hanger. RD tubing running tools. Clean rig pits and circulating system to remove oil- based mud. Clean and clear rig floor for rig demobe. MW = 7.5 ppg. 12/31/07: Finish flushing oil-based mud from circulating system. ND and clean BOPs. Hook up'/4" chemical line to tubing hanger. Install short tree. Test tubing hanger to 250/5000 psi for , 30 min. Test - OK. Test tree 250/5000 psi for 30 min. Test - OK. Remove TWC and install BPV. Both annuli reading 0 psi. RD Top Drive. 1/01/07: Continue clean up of rig. Lay down Top Drive rail. RD choke and gas buster. Fold over windwalls. Shovel snow and RD pipe shed. Lower Vee door hood. Begin unplugging electric lines from equipment. 1/02/07: Continue clean up of rig. Release Rig 1/02/08 12:00 p.m. to White Hills Exploration. ***FINAL REPORT HV-B13*** Final Report Summary page 4 Chevron Actual Wellpath Report NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> Page 1 of 7 ~~~~ BAKER M~16NES - INTEQ Operator .. , . Chevron Slot HV#13 Area Cook Inlet, Alaska (Kenai Penninsula) Well HV#13 Field South Kenai Gas Field Wellbore HV #13 Facility Happy Valley B Pad ~ ~ , s ~ / Projection System ~ NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Software System WellArchitect® 2.0 North Reference True ~ User Jonethoh Scale 0.999987 Report Generated 24-Dec-07 at 07:28:11 Convergence at slot 1.31° West Database/Source file WA Anchorage/HV_#13.xm1 Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[USft] Northing[USft] Latitude Longitude Slot Location -2920.22 -333.30 223690.68 ~' 2190972.28 ~ 59°59'19.587"N 151°30'32.305"W Facility Reference Pt 224090.41 2193884.11 59°59'48.347"N 151°30'25.754"W Field Reference Pt 269300.00 2597450.00 61°06'11.304"N 151°18'14.248"W ~.Jre-a,. ~ji~ f~,3~C'c5 e ~ Calculation method Minimum curvature Rig on HV #13 (RKB) to Facility Vertical Datum 614.OOft Horizontal Reference Pt Slot Rig on HV #13 (RKB) to mean sea level 614.OOft Vertical Reference Pt Rig on HV #13 (RKB) Facility Vertical Datum to Mud Line (Facility) O.OOft MD Reference Pt Rig on HV #13 (RKB) Section Origin N 0.00,E 0.00 ft Field Vertical Reference mean sea level Section Azimuth 227.30° r. Chevron Actual Wellpath Report NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> Page 2 of 7 r~~~ BAKER uriri~riri~.w - INTEQ Operator ,. ~ ~ Chevron Slot HV#13 Area Cook Inlet, Alaska (Kenai Penninsula) Well HV#13 Field South Kenai Gas Field Wellbore HV #13 Facility Happy Valley B Pad LLPAT H DATA (123 stations) MD Inclination Azimuth TVD Iftl [°1 [°1 [ftl 0.00 0.000 131.430 0.00 150.0 0 0.180 131.430 150.00 _ _ 197.00 _ 0.240 __ 128.860 ~ - 197.00 - 268.00 329 00 -- --i- I 0.220; r 1 720; --....-- 113.61 218 190 -- 268.00 328 99 . . _ _ . _. . 391.00 _ ~ 5.8 10' 228.430 390.84 451.00 _ ~ 8.280 224.890 450.39 512.00 8.620! ~ 224.670 510.72 573.00 .. _._ 00 ' 3 10.450. 12 - 224.990 _ _ ,_ _d 22 0 0 570.88 631 60 6 5. __ __ 696.00 .790 ._ ~ _.._- - ~ 15.240 7. 7 ] _ -k 229.640 -- - . - ---- 690.78 757.00 17.460, 228.410'; 749.31 _ 818.00 20.050' 228.860 807.07 __879 00 ~ _ _23.540 _ _ 229.240 _ 863.70 939.00 ! 26.6801 228.370; 918.02 1004.00 r 28.740 _ ~ 225.100 975.57 ] 069.00_ 31.0601 225.750 1031.91 ] 115.00 33.650 227.360 1070.77 1209.00 0 ~ _ 35 OSOj 11 ; 38 ' 227.410 228 400 1148.37 1200 127_4 0 . 0 _ _ ; . .57 1337.00 ~ 41.1201 228.490 1249.09 1402.00 43.240 228.820 1297.26 1466.00 45 570 228.960 1342.98 -- 1530.00 ~ _ 48.520 . 228.940 - 1386.58 1595.00 ; ~ 51.440' _ 228_530: 1428.3$ 1659.00 j 53.760 228.560 1467.25 1724.00 ~~ 55.180 __ 227.910 1505.02 1788.00 55.280 227.020 1541.52 __ 1852.00 ~ 55.210, __ 95622 0 1578.00 - - - 1917.00 --- ' 55.140 226.420: _ 1615.12 TVD from Vert Sect North East Grid East Grid North DLS Build Rate Turn Rate Fld Vert Ref [ft] [ft] [ft] [srv tt] [srv ft] [°/100ft] [°/IOOft] ]°/100ft] [ft] -614.00 0.00 0.00 0.00 ~ 223690.68 2190972.28 0.00 0.00 0.00 -464.00 -0.02 -0.16 0.18 223690.85 2190972.12 0.12 0.12 0.00 -417.00 -0.05 -0.27 0.31 223690.98 2190972.01 0.13 0.13 -5.47 -34 6.00 -0.12 -0.41 0.55 223691.22 - 2190971.85 0.09 -0.03 -- -21_48 __ 4 -285.01 ~' _ 0.73 -1.18 - _ - - -0.09 ~ r- -- 223690.74. _--- -- 2190971.10 ; - 2.93 _ _- 2.46 _ 171.44 -223.16 4.79 -4.00 -2.83 ~ 223687.76 ~ 2190968.35 6.66 6.60 16.52 -163.61 12.15 -9.07 -8.16 223682.32 2190963.40 4.18 4.12 -5.90 -103.28 21.10 -15.44 -14.47 223675.86 2190957.18 0.56 0.56 -0.36 -43.12 -- - . 31.20 -__ _ -22.60 _ _ _-- -21.59 _ 223668.58 ___ ~.. ,.2190950.18 3.00 4...._-- _ - 3.00 - -_ 0.52 ~ ,N,,; 17.60 - c 43.68 -- 31.25_ _ -30._60 223659 38 ; 2190941.74 3.83 3 77 3.35. ~ 76.78 58.44 -41.04 41.65 223648.10 ~ 21.90932.20 4.14 4.02 4.21 135.31 ~ 75.61 ; ---- 52.31 -54.61 r 223634.90 ~ 2190921.23 3.68 _ 3.64 ~ -2.02 193.07 95.2 65.27 -69.33 223619.88 2190908.61 4.25 4.25 0.74 249.70 . _ 1 117.85 .__ _ -8_0.10 . _-86.43 _ 22_3602.44 _ 2190894.17 5.73 5.72 0.62 304.02 143.24 , -96.88' ~ -105.58 I 223582.92 2190877.83 5.27 5.23 -1.45 361.57 173.51 -117.61 -127.56 223560.47 2190857.61 3.94 3.17 -5.03 417.91 205.89 -140.34 ~ -150.65 223536.87 2190835.41 3.60 3.57 1.00 456.77 230.50 -157.26 -168.53 223518.61 2190 818.91 5.93 5.63 3.50 534.37 283.54 - - -193.17 _ -207.56 223478.77_ _ 2190783.90 1.49 __ 1.49 0.05 - - 586 57 -- 322 27 219 12 - 236.31 44 ( ~ --223449 ~ 21907 60 8 4 79 -4 1 ~i-- - 52 . ; - . _ - _ . _ 5 . . .7 1. 635.09 362.42 -245.77 -266.36 223418.79 2190732.65 4.78 4.78 0.14 683.26 406.05 -274.60 ~-299.13 223385.37 ___ 2190704.58 3.28 3.26 0.51 728.98 450.82 -304.04 -332.87 223350.97 2190675.92 3.64 3.64 0.22 772.58 497.63 334.79 -368.19 223314.96 2190645.97 4.61 4.61 -0.03 _ ~- 814.38 _547.39 ; -367.63 ~ _-405.60 j 223276 8_1 j _ __ _ _ 2190614.01 ....4.52 4.49 ___._. -0.63 853.25 598.22 -401.28 -443.70 223237.95 2190581.23 3.63 3.63 0.05 891.02 651.10 -436.52 -483.15 223197.70 2190546.90 2.33 2.18 -1.00 927.52 703.68 -472.06 -521.89 223158.17 2190512.25 1.15 0.16 -1.39 964.00 -- 756.26 - -508.05 - - -560.23 --- 223119.02 -- - 2190477.15 --- - 0.56 - - -~ -0._11 -0.67 --- - 1001.12 809 61 ' -544.78 -598.93 ' ~ - 223079.49 ----r _2190441.31 i - - 0.24 - -0 I 1 ~ _ ___ _ -0.26 Chevron Actual Wellpath Report NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> Page 3 of 7 .~ ~~ BAKER MV61~IE~ INTEQ Operator ,. ~ ~ Chevron Slot HV#13 Area Cook Inlet, Alaska (Kenai Penninsula) Well HV#13 Field South Kenai Gas Field Wellbore HV #13 Facility Happy Valley B Pad ELLPATH DATA (123 stations) MD Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS Build Rate Turn Rate [ft] [°] [°] [ft] Fld Vert Ref [ft] (ft] [ft] [srv ft] [srv ft] [°/100ft] [°/100ft] [°/100ft] [ft] 1982.00 55.130 225.730 1652.28 1038.28 862.93 -581.77 -637.35 223040.24 2190405.20 0.87 -0.02 -1.06 2046.00 55.090 225.790 1688.89 1074.89 915.41 -618.40 _ -674.96 223001.81 2190369.45 0.10 -0.06 0.09 2111.00 55.120 225.700 1726.07 1112.07 968.70 -655.60 -713.14 222962.78 2190333.12 0.12 0.05 -0.14 2174.00 55.120 225.540; 1762.10 ~ 1148.10 1020.36 _ -691.75 , -750.08 222925.03 2190297.83 0.21 0.00 -0.25 ' _ 8 68 1184 68 1072 85 728 44 ' 787 65 64 222886 2190262 00 0 35 0 06 42 0 .00 2238 55160 ; 225.810 1 179 . ~ . . . ~ - - . . . . . . _ 2303.00 55.160 225.610 1835.81 1221.81 ~ 1126.18 -765.70 -825.84 222847.61 2190225.63 0.25 0.00 -0.31 2367.00 55.210 _ 225.870 1872.35 1258.35 1178.71 -802.37 -863.47 222809.15 2190189.82 0.34 0.08 0.41 2431.00 55.210 226.3901 1908.87 1294.87 1231.26 -838.79 -901.36 222770.44 2190154.27 0.67 0.00 0.81 2496.00 55.220. 226.650 1945.95 1331.95 1284.64 -875.53 940.09_ _ 222730.88 _____2190118.43 0.33 T ~ __ 0.02 0.40 3 32 1 36 9 911 1 977 $9 222692 28 2190083 66 ~ 2 95 ~ 2 95 0 09 2560.00 53.330; 226.710± 1983.32 1 69. 3 .5 . - 7 ~ . - . . . ~ - . _. _ . 2625 00 ~ 50.700 226.510 _ 2023.32 1409.32 1387.81 946.36 ~ =1015.12 222654.26 2190049.33 4 OS -4.05 -0.31 - 2689.00 ~ 49_020 226.580 2064.58 _ 1450.58 ~ 1436.73 -980.01 -1050.63 222617.99 ~ __ 2190016.50 ___ _ 2.63 _ -2.62 --- 0.11 2754 00 ~ 47 430 226.53 0 2107.88 1493.88 1485.20 1013.34 -1085.83 _ 222582 04 2189983.98 2 45 -2.45 0.08 2818 00 46 250 226.850 ~ 2151.66 1537.66 1531.88 1045.37 -1119.80 222547 35 2189952.74 1 88 -1.84 0.50 2883.00 44.940; 227.480, 2197.14 1583.14 1578.32 __-1076.94 • -1153.85 _ 222512.59 2189921.95 F 2.13 ~ ~~ -2.02 ~ 0.97 ____... _ 2947.00 _ ~ 43.550 ~ 227.980. __ 2242.98 1628.98 1622.97 -1106.98 -1186.89 222478.88 2189892.68 2.24 -2.17 0.78 3012.00 __ 41.850 228.470 _ _ 2290.75 1676.75 _ 1667.04 __ -1136.34 -1219.76 222445.34 2189864.07 2.66 -2.62 0.75 3076.00 39.860 228.540, 2339.16 1725.16 ]708.89 -1164.08 -1251.11 222413.36 2189837.05 3.11 -3.1 ] 0.11 3140.00 37.350 228.420'1 2389.17 1775.17 1748.82 -1190.55 'i -1281.01 222382.87 2189811.27 3.92 -3.92 -0.19 3204.00 ' - 34 960! _ _ 228.310; _. _-- - 2440.84 -----T- 1826.84 - - -- 1786.56 _- -- - --- ~ 1215.63 ----- 1309.23 --- 222354.09 2189786.84 ; - 3.74 -- -3.73 -0.17 3269.0 0 32.00 0227.760 2495.05 1881.05 ]822.41 1239.60 -1335.89 222326.89 2189763.49 4.58 -4.55 -0.85 _ _ 3333.00 ~ 29.700 227.530 2549.99 1935.99 1855.23 -1261.71 -1360.14 222302.14 2189741.94 3.60 -3.59 -0.36 3398.00 ' 27.930 226.720 6062 94 1992.94 1886.56 -1283.02 ~ -1383.11 222278.70 2189721.16 2.79 -2.72 -1.25 3462.00 26 390 - ~ j 227.040 66 32 88 --- ~ __ 2049 88 J 1915.77 -1302.99 -- ~__ _1404.43_ _ 222256.92_ ____ _ __ 2189701.68 ~ 2.42 _ -2.41 _0.50 __ 3527.00 24 840 v 227.310 ~ 2722.49 210%.49' ____ 1943.87 -1322.09 ~ ___-1425.44 222235.89 ~ 21$96$3.05 2.39 -2.3$ 0.42 3590.00 23.070 228.330 2780.06 2166.06 1969.45 -1339.27 -1443.98 222216.55 2189666.31 _ 2.89 -2.81 1.62 3625.00 22.250 228.550 2812.36 2198.36 1982.93 -1348.22 -1454.07 222206.26 2189657.59 2.36 -2.34 0.63 3648.00 22.200 228.340 2833.65 2219.65 1991.62 -1353.99 -1460.58 ` _. a 222199.62 _. 2189651.97 0.41 -0.22 -0.91 _ - 3712.00 19.920 y 224.860 2893.37 - ~ 2279.37 __2014.61 -.._ -1369.76 ~_ 1477.31 f 222182.54 2189636.59 4.06 -3 56 -5.44 ~ 3777.00 16.710 225.260 2955.07 ~ 2341.07 , 2035.02 4 1384.19 149L76 ; 222167 76 ~ _2189622.49 4 94 i -4 94 0.62 • Chevron Actual Wellpath Report NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> Page 4 of 7 ^ BAKER MI~IGNE~ INTEQ Operator ,. ~ Chevron Slot HV#13 Area Cook Inlet, Alaska (Kenai Penninsula) Well HV#13 Field South Kenai Gas Field Wellbore HV #13 Facility Happy Valley B Pad LLPATH DATA (123 stations) MD [ft] Inclination [°] Azimuth [°] TVD [ft] TVD from Fld Vert Ref [ft] Vert Sect [ft] North [ft[ East [ft] Grid East [srv ft] Grid North [srv ft] DLS [°/100ft] Build Rate [°/100ft] Turn Rate [°/100ft] 3841.00 14.540 229.320 3016.71 2402.71 2052.24 -1395.90 -1504.39 222154.87 2189611.07 3.79 -3.39 6.34 3905.00 12.940 234.190 3078.88 2464.88 2067.39 -1405.33 -1516.30 222142.75 2189601.91 3.08 -2.50 7.61 3970.00 10.680 235.660 3142.50 2528.50 2080.57 -1412.99 -1527.17 222131.70 2189594.51 3.51 -3.48 2.26 4034.00 8.20 __ 0 226.710: _3205.63 _ 2591.63 20 91.01 -1419.46 -1535.39 222123.34 2 189588 .22 4.49 -3.88 -13.98 0 2 ___ _ g _ 69 87 ~ 2 618 8 C _ _ 2 0 -1425.20 _ -1540.65 _ __ _ 222117.95 _ __ _ _ ~ 2189582.60 _ 4.18 __ -3.72 -15.92' 4 16 .00 4. 90 ~ 220.780 : 33 2 . 1 04.60 -1429.83 ~ -1544.33 222114.17 2189578.06 1.72 -1.61 6.66 _ 4227.00 3.530 230.570 3397.70 2783.70 2109.30 -1433.16 -1547.64 222110.78 2189574.81 2.22 -1.94 15.06 4291.00 1.810 250.450 } 3461.63 2847.63 2112.19 -1434.75 -1550.12 222108.27 2189573.28 3.01 -2.69 31.06! __ i 4420.00 _ ---- 1 650 ~~ 205.550 _ __. ~-_-I 3590.55 -- ----~ 2976.55 I -__ _.. .._ 2116.55 x ..--- --- _1438.47 ; ~ ~-- _ - 1552.61 -_.-- --- 222105.70 ------ 2189569.61 _-- __ 1.26 ' 1.03 -1.26 ~ ~_~ -72.52; ~~ 2.32' 5 1 7 0 68 ~ ! 4550.00 - 0.530 1.960 3 - 20.53 ~ 3 -- 31 06.53 - 2117.99 1439. 1553.37 222104.90 2189568.33 1.86 -0.32 225.86 4612 00 __ ~ 0 630 354.430 3782 53 - T 3168 53 ~ 2117 62 ~ 1439.15 1553 45 ~ 222104 84 2189568 95 0.17 .1 0 6 3.98 4678 00 ~ 0 620 ._..~- 35 860 ~._ _ ~ 3848 52 ._ ___- 3234 52 _ 2117 17 - -- 1438.43 ~ ~ 1553 50 ~.~~ __' 222104 81 __._._. _._ 2189569 67 .. .. . 0 06 _.,.~ ._~ ~ _--- 002 5.20 4742.00 ' ~_~ _ 0 340 ~ T 59 890 3912.52 ` 3298.52 ~ f 2116.76 1437.99. 1553.34 _ - 222104.97 m w _ 2189570.11 ~ 0.86 _____ 0.44 ' 96.92 4806.00 0.440 r 94.100, s 3976.52 3362.52 ~ 2116.41 - ]437.91 - 1552.93 222105.38 _ 2189570.18 _ 0.39 - 0.16 53.45 4870.00 0.500 67.250 4040.52 3426.52 2115.98 -1437.82 -1552.43 222105.89 _ 2189570.26 0.35 0.09 -41.95 4935.00 0.620 60.730 4105.51 3491.51 2115.37 -1437.54 -1551.86 222106.46 2189570.52 0.21 0.18 -10.03 4997.00 0.800 47.980 4167.51 3553.51 2114.61 -1437.09 -1551.25 222107.09 2189570.96 0.38 0.29 -20.56 5058.00 0.390', _ 38.230; ~ 4228.51 (~ 3614.51 2113.98 -1436.64 -1550.80 222107.54 2189571.40 _ 0.69 -0.67 -15.98? 5127.00 - 0.070 273.630 _g_ 4297.51 _ 3683.51 -- -_-. ~~. 2113.78 -1436.45 -1550.70 222107.65 2189571.59 0.63 -0.46 -180.58 5193.00 0.240 , 42.380; 4363.51 3749.51 ~ . 2113.67 -1436.35 -1550.65 222107.70 2189571.69 0.44 0.26 195.08 - 5256.00 0 210 -- 1 62.790 4426.51 3812.51 2113.42 1436.20 ~ -1550.46 222107.90 2189571.84 0.13 -0.05 32.40 ~_ 5320.00 ---.--- .5384.00 ' 0.360 _ _ -- 0.620 M _. 1 64.820 78.100 4490.50 t... _ _ 4554.50 ; ~ 3876.50 r_ _ - .. _ ___. 3940.50 2113.1_2 ___- _-- 2112.63 _ _ 1436.06 _ -1435.90 , -1550.17 __.__. _-.-_ __ _ -1549.65 __ _222108.19 _ _._ 222108.71 2189571.97 __._.~ 2189572.11' 0.23 . -._______~__._. 0.44 0.23 -_ __-_-_._____~_ 0.41 3.17 ______ 20.75 5450.00 0.440 i 69.450 1 4620.50 4006.50 21]2.09 -1435.74 -1549.06 222109.30 2189572.26 0.30 -0.27 -13.11 5509.00 0.580 76.560 4679.50 4065.50 2111.62 -1435.59 -1548.56 222109.81 2189572.40 0.26 0.24 12.05 5578.00 0.650 -- 72.390 - 4748.49 4134.49 2110.96 -1435.39 -1547.85 222110.52 2189572.58 0.12 0.10 -6.04; 5643.00 ~ ~ 0.910 -76.320 4813.49 _ I 2189572.80 0.41 0.40 6.05 5707.00 1.050 66.970 - 4877.48 . 4263.48 !~ 2109.18 1 -1434.81 -1545.96 1- 222112.42 -2189573.12 ~ - 0.33 -0.22 1 -14.61" °~ Chevron Actual Wellpath Report NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> Page 5 of 7 ri~~E BAKER HV6MES INTEQ .. ~ -- __ _ _ - ---_ __m - _ - - - __ _ _ Operator Chevron _ (Slot ~HV#13 Area Cook Inlet, Alaska (Kenai Penninsula) ~_ Well HV#l3 Field South Kenai Gas Field Wellbore HV #13 Facility Happy Valley B Pad ELLPATH DATA (123 stations) MD ]ft] Inclination [°] Azimuth [°] TVD [ft] TVD from Fld Vert Ref [ft] Vert Sect [ft] North [ft] East [ft] Grid East [srv ft] Grid North [srv ft] DLS [°/100ft] Build Rate [°/100ft] Turn Rate [°/100ft] 5767.00 0.760 136.980 4937.47 4323.47 2108.66 -1434.88 -1545.18 222113.20 2189573.03 1.78 -0.48 116.68 5836.00 1.370 194.590 5006.46 4392.46 2109.35 -1436.02 -1545.08 222113.28 2189571.89 1.68 0.88 83.49 5901.00 1.200 206.260, 5071.44 4457.44 2110.64 -1437.38 r -1545.58 222112.75 2189570.54 0.48 -0.26 17.95 5965.00 1.23 0 2 21 .0 10; 5135.43 4521.43 2111.95 -1438.50 ~ -1546.32 222111.98 2189569.44 0.49 0.0 5 23 05 . 6029.00 ; _ _ 1 390' _ . _ __ 223.730: ~ 5199.41 4585.41 2113.40 _ -1439.58 ~ _ -1547.31 222110.97 2189568.39 0.27 ! _ 0.25 _ _ _ 4.25 6093.00 _ 1.510 237.880 5263.39 4649.39 2115.01 1440.59 -1548.56 222109.69 ~ 2189567.41 0.59 0.19 22.11 6158.00 1.820 251.510 5328.37 4714.37 2116.79 -1441.37 -1550.27 222107.97 2189566.66 0.77 0.48 20.97 6222.00 2.070 260.780 5392.33 4778.33 2118.68 -1441.88 -1552.37 222105.85 2189566.20 0.63 0.39 14.48 6286.00 _ 1.870 264 .98 0- 5456.29 j 4842.29 2120.47 -1442.15 -1554.55 222103.67 2189565.98 0.39 -0.31 6.56 6351.00 _ _ 2.150_ _ __ . 276.300' _ 5521.25 4907.25 2122.11 -1442.11_ -1556.82 222101.40 2189566.07 0.75 0.43 17.42 _ _ r _ 7 7 6480.00 1.570 303.110 9 5036.19 2124.21 -1441.03 60.68 22209 .57 218956 .23 - 0.91 -0.28 30.25 6543.00 1y920 318.360 5713.16 5099.16 2124.41 -1439.77 -1562.10 222096.18 ~ 2189568.52 0.92 0.56 24.21 6608 00 6672.00 " _ r 2 290 640 ; e ~. 2 _ 326.700 331.140 5778.12 5842.06 5164.12 " ~, „ w221i,46 2124.17 2123.61 -1437.88 -1435.52 -1563.54 -1564.95 222094.78 222093.42 2189570.46 218_9572.85 0.74 0.62 0.57 0.55 12.83 _ 6.94 6737.00 _ 2.770 _ 340.590 5906.98 5292.98 2122.63 -1432.72 -1566.19 222092.24 2189575.67 0.71 0.20 _ _ 14.54 6802.00 1.800 354.070 5971.93 5357.93 2121.40 -1430.23 -1566.82 222091.67 2189578.18 1.70 -1.49 20.74 6866.00 _ 1.450 14.000 6035.91 5421.91 2120.12 _ -1428.44_ _ -1566.73 222091.81 2189579.96 1.03 -0.55 31.14 6930.00 1.520 __ 19.02 0 6099.88 5485.88 2118.70 -1426.85 -- ~ -1566.26 222092.32 2189581.54 0.23 0.11 7.84 6995.00 ~ 1 350 21.840 6164 86 -- ; ~,+ " 5550.86 ---- 2117.25 1425.33 ; 1565.69 222092.92 ` ~~~ 2189583.05 ~~ 0.28 -0 26 --- 4.34 7059.00 _._.____ 1.390 ___._~__- 25.810 _ -- 6228.85 5614.85 2115.84 -1423.93 _ -1565.07 222093.57 2189584.43 0.16 0.06 6.20 7124.00 _ 1.35 0 26.400 6293.83 5679.83 2114.40 -1422.53 -1564.39 222094.28 2189585.81 0.07 -0.06 _._ _ 0.91 7188.00 1.480 _ 29.990 6357.81 5743.81 21]2.90 -1421.14 -1563.64 222095.06 2189587.19 0.25 0.20 5.61 7252.00 1.430 28.440 , 6421.79 5807.79 2111.36 -1419.72 -1562.85 222095.89 2189588.59 0.10 -0.08 -2.42 } .; 7317.00 -_-- 1.360 -- -~- 30.080 - 6486.77 -- - 5872.77 2109.85 -1418.34 -1562.07 22209b.69 i 2189589.95 0.12 -0.11 2.52 7381.00 1.270 25.800 6550.75 5936.75 2108.47 -1417.05 -1561.38 222097.41 2189591.23 0.21 -0.14 -6.69 7445.00 1.270 24.830 6614.74 6000.74 2107.15 -1415.77 -1560.78 222098.05 2189592.50 0.03 0.00 -1.52 7509.00 1.530 28.100 . 6678.72 6064.72 2105.69 -1414.37 -1560.08 222098.78 2189593.88 0.42 0.41 5.11 7573.00 1.940 23.180 6742.69 6128.69 ~ '.61 ~ 2103.89 -1412.62 -1559.25 222099.65 218959 5.61 0.68 0.64 -7.69 _ 7637.00 ___ _ 2.12 0 29.890 _ _ 6806.65 92.651 __ .2101.78 , -1410.60 -1558.23 ~ 222100.71 _ _ 2189597.61 0.47 0.28 _ 10.48 • cne~ron Actual Wellpath Report NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> Page 6 of 7 rrr~ BAKE R M1~6MER INTEQ Operator ,. ~ ~ Chevron Slot HV#13 Area . Cook Inlet, Alaska (Kenai Penninsula) Well HV#13 Field . South Kenai Gas Field Wellbore HV #13 Facility . Happy Valley B Pad ELLPATH DATA (123 stations) MD [ft] Inclination [°] Azimuth [°] TVD [ft] TVD from Fld Vert Ref [al Vert Sect [ft] North [ft] East [tt] Grid East [srv ft] Grid North [srv ft] DLS [°/100ft] Build Rate [°/100ft] Turu Rate [°/100ft] 7670.00 2.100 32.120 6839.62 6225.62 2100.61 -1409.55 -1557.61 222101.36 2189598.63 0.26 -0.06 6.76 7690.00 2.130 31.750 6859.61 6245.61 2099.90 -1408.93 -1557.22 222101.76 2189599.25 0.16 0.15 -1.85 7747.00 2.130 31.750 6916.57 -~ 6302.57 2097.86 -1407.13 -1556.10 - 222102.92 - 2189601.03 0.00 0.00 0.00 HOLE & CASING SECTIONS Ref Wellbore: HV #13 Ref Wellpath: NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> String/Diameter Start MD [ft] End MD [ft] Interval [ft] Start TVD [ft] End TVD [ft] Start N/S [ft] Start E/W [ft] End N/S [ft] End E/W [ft] 16in Conductor 0.00 117.00 117.00 0.00. 117.00 0.00 0.00 -0.09 0.11 9.625in Casing Surface 0.00 1157.00 1157.00 0.00 1105.60 0.00 0.00 -173.15 -185.79 Tin Casing Intermediate 0.00 3645.00 3645.00 0.00 2830.87 0.00 0.00 -1353.23 -1459.74 6.125in Open Hole 0.00 7747.00 7747.00 0.00 6916.57 0.00 0.00 -1407.13. -1556.10 • Chevron Actual Wellpath Report NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> Page 7 of 7 ®~~ BAKER MY~'~rNE~i INTEQ Operator .- - i e Chevron Slot HV#13 Area Cook Inlet, Alaska (Kenai Penninsula) Well HV#13 Field South Kenai Gas Field Wellbore HV #13 Facility Happy Valley B Pad TARGETS Name MD [ft] TVD [ft) North [ft] East [ft] Grid East [srv ft] Grid North [srv ft] Latitude Longitude Shape HV #13 Tar et #1 2932.00 -1438.21 -1558.31 222100.00 2189570.00 59°59'05.422"N 151°31'02.934"W square g HV #13 Tar et #2 6664.00 -1438.21 -1558.31 222100.00 2189570.00 59°59'05.422"N 151°31'02.934"W square g HV #13 Tar et #3 6914.00 -1438.21 -1558.31 222100.00 2189570.00 59°59'05.422"N 151°31'02.934"W square g ELLPATH COMPOSITION Ref Wellbore: HV #13 Ref Wellpath: NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-774T> Start MD [ft] End MD [ft] Positional Uncertainty Model Log Name/Comment Wellbore 0.00 ~ 1115.00 NaviTrak (Magcorrl) NaviTrak MWD<150-1115'> HV #13 1115.00 3625.00 AutoTrak G3 (SAG, MagCorr) ATK G3 MWD<1209 - 3625'> ' HV #13 3625.00 7747.00 OnTrak (Magcorrl) OnTrak MWD<3648-774T> HV #13 SURVEY LOG COMMENTS • MD [h) Inclination [°) Azimuth [°] TVD [D) Comment 7747.00 2.130. 31.750 6916.57 Projected data only - NO SURVEY Chevron Location: Cook Inlet, Alaska (Kenai Penninsula) Slot: HV#13 Field: South Kenai Gas Field Well: HV#13 Facili Ha Valle B Pad Wellbore: HV #13 r~~~ BAKER Mt~6NES INTEQ Plot reference wellpath is NaviTrak MWD<150-1115'>ATK G3 MWD<1209-3625'>OnTrak MWD<3648-7747'> True vertical depths are referenced to Rig on HV #13 (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Rig on HV #13 (RKB) North Reference: True north Rig on HV #13 (RKB) to mean sea level: 614 feet Scale: True distance mean sea level to Mud line (Facility: Happy Valley B Pad): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 24-Dec07 s~ -nso -1500 -t250 -loco aso -500 -250 0 HV#13 0 . •250 Z 0 rc r n a~ m U 1= N N 7 F Vertical Section (ft) 5pM1 ^~""'0°" Azimuth 227.30° with reference 0.00 N, 0.00 E Happy Valley 8-13 Deep Creek Unit • t to Drill#: 207-151 & Serial#: C-061590 7, 747' 7,679^^.. ^^ .^T. ORIGINAL RIG ELEVATIONS Surface Location: Well Classificaton: 2920' FNL & 337' FEL ,.... Total De the Sec 21,T2S,R13W,SM pBTD: Happy Valley B-13 (PTD 207-~) 7"" Casing Cement Program Propas ~hanges Page 1 of 2 Maunder, Thomas E (DOA From: PORHOLA, STAN T [stan.porhola@chevron.com] Sent: Monday, December 17, 2007 9:44 AM To: Maunder, Thomas E (DOA) Subject: RE: Happy Valley B-13 (PTD 207-151) 7" Casing Cement Program Proposed Changes We did not experience any "breathing" while drilling Happy Valley #12. The top of cement behind the 7" casing is 2190' MD assuming a hole requiring an open hole excess of 20% (3706' MD 7" shoe depth). We mixed and pumped 93 bbls of 12.8 ppg LiteCRETE cement, had 42 bbls of losses during the cement job and tagged the top of cement in the 7" casing at 3477' MD. Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 porhost@chevron.com A/nil Confidenttal Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, December 14, 2007 3:39 PM To: PORHOLA, STAN T; Davies, Stephen F (DOA) Cc: Tim Regg Subject: RE: Happy Valley 8-13 (PTD 207-151} 7" Casing Cement Program Proposed Changes Stan, Sorry t haven't gotten back sooner. Changing the slurry as you propose should help with the pumping issues you mention. The hydrostatic change from a 0.3 ppg weight change is minimal. You mention breathing during cementing, was any experienced while drilling? I don't remember hearing of breathing on the prior wells. Do you have any estimate of the TOC for HV-612? Tom Maunder, PE AOGCC 1/15/2008 Happy Valley B-13 (PTD 207-~} 7" Casing Cement Program Prapase~ ges Page 2 of 2 From: PORHOtA, STAN T [mailto:stan.porhola@chevron.com] Sent: Tuesday, December ii, 2407 2:57 PM To: Maunder, Thaws E (DOA}; Davies, Stephen F (DOA} Subject: Happy Valtey B-13 (PTE} 207-151} 7" Casing Cement Program Proposed Changes Tom and Steve, I would tike to inform you of a proposed change to our cement pion for the 7" casing at Happy Valley 8-13 (PTD 247-151). The proposed change is to move from a 12.8 ppg LiteCrete cement to a 12.5 ppg LiteGrete. The main reason far this change is from our experience at Happy Valley B-12. During our cement job, mixing of the cement became very difficult when the density fluctuated above a 12.8 ppg. The viscosity of the cement increased the pump pressure and likely lead to the losses and subsequent "wellbore breathing" that occurred after finishing our displacement. After drilling out to perform our yak-off test below the 7" shoe, we recorded a 13.5 EMW ppg. The hydrostatic weight was approximately 12.2 Ppg (10.5 Mudpush and 12.8 ppg LiteCrete}. if an additional 1.3 ppg were added due to the viscous nature of the 12.8 ppg t_iteCrete, this may explain the losses we experienced. The chemistry of the 12.8 ppg vs. the 12.5 ppg t_iteCrete is very similar. The most significant difference is the mix water. The change would be from 6.991 gallsk to 7.866 gal/sk. No adverse affects are expected from the decreased 4.3 ppg in hydrostatic. The formation pressures are roughly 8.7 ppg EMW. Our mud weight is planned to be a 9.4 to 9.3 ppg. Our methods to gauge the open hole excess have provided inconclusive results. To deal with any washouts andlar potential lasses, we are planning to increase our excess cement volume from 24% to 44°~. The planned cement top remains the 9-5f8" surface casing shoe at 1157` MD. Attached are the pilot tests of each cement blend. «HV 8-12 LiteCRETE 7inch 12.8 Pilot Test.doc» «HV B-13 LiteCRETE 7inch 12.5 Pilot Test.pdh> Stan Porhola Drilling Engineer MidContinenttAtaska Business Unit Chevron North America Exploration and Production 949 West 9th Avenue Anchorage, AK 99541-3322 Tel 907 263 7644 Fax 947 263 7884 Ce11 947 229 1769 porhost@chevron.com Mnil Confidential Pouter Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to tare message or contacting me at (907) 263-7640. U15/2008 ~ ~ Sehlumberger Laboratory Cement Test Report-Nabors 106 HV-12 LiteGRETE 12.8 Fluid No : PAK Int07002 Client : Chevr~ Location t R~ :Nabors 108 Date : A 18-2007 Welt Name : HY-12 Fetd : Swansor- River Daniel H~nei Job Type 7" Iraterrnediate CSG Depth 3700.0 ft TVD 3622.0 R BHST 85 degF BHCT 75 degF BHP 1800 psi Starting Temp. 80 degF Tone to Temp. 00:23 hrmn Heating Rate -0.85 degFlmin Starting Pressure 341 psi Tmie to Pressure 00:23 hrmn Schedule 9.4-3 Vol. Fracdon 54.9 % Porosity 45.1 % LiteCRETE_12 Freshwater 94 tb of CEMENT 6.276 gaUsk Blend 123.17 lbJft3 Base Fluid D046 0.200 %BWOC Antffoam D500 0.700 gaUsk GASBLOK LT D174 1.000 %BW~ Expandir~ ce D065 0.800 %BYVOC DLspersant Rheotogy (Average readings) .-. .-. 300 65.0 156.0 200 56.0 120.0 100 36.5 77.0 60 31.5 57.5 30 26.5 39.0 6 20.5 19.0 3 17.5 14.5 Temperrture ~ F 70 F Pr: 44.870 cP P•: 129.960 cP Tr: 22.45 tbfl100ft2 I Tr: 30.31 1bf/10082 Thickenin T ime 30 Bc 00:45 hemp 70 Bc 03:38 hr:mn 100 Bc 04:56 hr:mn Remark : Thidceni time inGudes 1:00 hrmn batch time Free Fluid 0.0 mU250mL in 2 hts At 80 degF and 45 deg incl. Sedimentation None Fluid Loss API Fluid Loss 44 mL 22 mL in 30 min at 80 de F and 1000 Commerrts General Comment Page 1 ~ ~ Schlumberger Laboratory Cement Test Report-Nabors 106 HV-131ntermediate Pilot ~.~ Fluid No : PAK intt07099 Client :Chevron Location /Rig :Nabors 106 Date :Dec-05-2007 Well Name : HV-13 Field :Swanson River Mohamed Job Type 7" IrMermediate Casing Depth 3835.0 ft TVD 3650.0 ft BHST 76 degF BHCT 63 degF BHP 1100 psi Starting Temp. 80 degF Time to Temp. 00:23 hymn Heating Rate 0.11 degF/min Starti Pressure 341 si Time to Pressure 00:23 hr:mn Schedule 9.4-1 cam osltlon Slurry Density 12.50 Ib/gaI Yield 2.28 ft3/sk Mix Fluid 7.566 gatfsk Solid Vol. Fraction 53.9 °~ Porosi 46.1 % Slur I.iteCRETE ..- .. ° .- Crete Blend 941b of BLEND Blend 199.77 IbHt3 Fresh water 7.066 Usk Base Fluid D046 0.600 %BWOC antifoam TU5A0092A0 D065 0.450 %BWOC dispersant VF44175C21 D174 1.000 %BWOC F~cpanding ce TU6H0228A1 D500 0.700 gaUsk GASBLOK LT CY6259310 D135 0.100 aUsk GASBLOK* sta 000001057906 Rheolo Avera a readin s 600 .-. 107.0 .-. 140.0 300 51.0 84.0 200 37.0 61.5 100 22.0 37.0 60 15.0 27.0 30 10.5 19.0 6 7.5 12.5 3 5.5 10.0 Tem rature 80 F 63 d F c ~ ~:5133bf/1 00tt2 Tr: 16.36 bf/100ft Thir_kenina Timn 30 Bc 04:11 hymn 70 Bc 05•.36 hrmn 100 Bc 06:29 hr:mn Batch Mix Time : 01:00 hr:mn at 90 F Free Fluid 0.0 mU250mL in 2 hrs At 80 degF and 45 deg incl. Sedimentation None Fluid Loss API Fluid Loss 14 mL 7 mL in 30 min at 70 d F anti 1000 i Comments General Comment Page t r a ~~ ~ SARAH PALIN GOVERNOR ~.a '~,~ ~.. t..T1 ~~ OIL A1~TD GAS 333 W 7th AVENUE, SUITE 100 CO1~T5ER'QATI011T COrII-II5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Tim Brandenburg FAx (so7~ z7sasaz Drilling Manager Unocal PO Box 196247 Anchorage, Alaska 99519 Re: Deep Creek Unit, Beluga/Tyonek Gas Pool, Happy Valley B-13 Unocal Permit No: 207-151 Surface Location: 2920 FNL, 337' FEL, Sec. 21, T2S, R13W, SM Bottomhole Location: 4359' FNL, 1897' FEL, Sec. 21, T2S, R13W, SM Dear Mr. Brandenburg, Enclosed is the approved application for permit to drill the above referenced development well. 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907,y6,~59-3607 (pager). ..l ~,. DATED this V day of November, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,~ Chevron October 26, 2007 Commissioner Alaska OiI & Gas Conservation Commission 333 W. 7`" Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill Deep Creek Unit, Happy Valley # 13 Dear Commissioner: RECEIVED OCT 2 6 2007 Alaska Oil & Gas Cons, Commission Anchorage Enclosed for your approval is a completed Permit to Drill (form 10-401) for the Deep Creek Unit Happy Valley #13 Gas Development Well. Subject to AOGCC approval, it is our intention to move the new build rig, Nabors 106E, following the completion of Happy Valley #12. We plan to drill a directional well to +/- 7,747'/6,914' MD/TVD, run and cement a 3-1/2" production casing string and demobilize the rig. Completion in the Beluga and Tyonek will be done rigless. We would also like to request a variance from the requirements of 20 AAC 25.035 (C) to drill the 12-1/4" surface hole to a depth of+/-1100 MD/ 1059'VD' without a diverter. AOGCC regulation 20 AAC 25.035 (h) (2) may allow a variance if "it provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary." Based on our experience drilling 12 '/4" surface holes in Happy Valley wells #1 thru #12 it has been proven conclusively that no shallow gas hazards exist beneath A-pad and B-pad to a depth of at least 2654' TVD and 2945' TVD respectively. The 12-1/4" surface hole for Happy Valley #13 will be drilled from the same pad as Happy Valley Well #12. For the purpose of basic risk mitigation, Chevron will utilize a gel/native spud mud which is expected to weigh approximately 8.7 - 9.0 ppg when drilling at the planned surface hole TD of 1100' MD. We are targeting a spud date of November 15~`. Therefore, your earliest attention to this application will be greatly appreciated. If additional information is required, please contact either myself or Mr. Stan Porhola at 263-7640. Sincerely, Timothy C. Brandenburg Drilling Manager TCB: stp Attachments: PTD Package Cc: Well File Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Fax 907 263 7884 Union Oil Company of California / A Chevron Company http://www.chevron.com ,.~o~ I ~1 ~ STATE OF ALASKA ~ l ALAS OIL AND GAS CONSERVATION COM oION ~~ PERMIT TO DRILL c [ ~ 20 AAC 25.005 RECEIVED OCT 2 6 2007 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development Oil ^ 1 c. Specify if o Drill Q Redrill ^ Stratigraphic Test ^ Service ^ Development Gas 0 Coalbed Methane ^ A11ChQE8~6iydrates ^ Re-entry ^ Multiple Zone ^ Single Zone ^ Shale Gas ^ . Operator Name: 5. Bond: Blanket 0 Single Well 11. Well Nam and Nu er: 61~ev~roa (Union Oil Company of California) Bond No. 086S103515406B6M~ Happy Valleyl3 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 196247, Anchorage, Alaska, 99519 MD: 7747 TVD: 6914 Deep Creek Unit 4a. Location of Well (Governmental Section): 7. Property Designation: Beluga/Tyonek Pool Surface: 2920 FNL, 337' FEL, Sec 21, T2S, R13W, SM C-061590 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4295' FNL, 1825' FEL, Sec 21, T2S, R13W, SM N/A 11/15/2007 Total Depth: 9. Acres in Property: 14. Distance to Nearest 4359' FNL, 1897' FEL, Sec 21, T2S, R13W, SM 3040 Property: 5000 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 223,691 y- 2,190,972 Zone- ASP 4 (Height above GL): 21.0 feet Within Pool: 1350 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 55 degrees Downhole: 3128 Surface: 2437 18. Casing Program: Specifications To p -Setting Depth -Bottom Cement Quantity, c.f. or sacks Hoie Casing Weight Grade Coupling Length MD TVD MO TVD (including stage data) Driven 16 109 X-56 Weld 117 0 0 117 117 Driven (not cemented) 12-1/4 9-5/8 40 L-80 BTC 1100 0 0 1100 1059 108 bbls (50% excess) 8-1/2 7 26 L-80 BTC 3650 0 0 3650 2834 77 bbls (20% excess) 6-1/8 3-1/2 9.2 L-80 IBT-Mod 4247 3500 2696 7747 6914 202 bbls (20% excess) 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 ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Filing Fee ^ BOP Sketch 0 Drilling Program Q Time v. Depth Plot Q Shallow Hazard Analysis ^ Property Plat 0 Diverter Sketch 0 Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Stan Porhola Printed Name Tim Brandenburg Title Drilling Manager Signature ~ Phone 263-7640 Date 10/26/2007 Commission Use Only Permit to Drill API Numb Permit App oval See cover letter for other Number; aQ~~~'~~ 50a3f o?OO,3o?d000 Date: requirements. If box is checked, well may not be used to explore for, test, or produce c Ibed ethane, gas hydrates, or gas contained in shales: Conditions of approval : Samples req'd: Yes[ No ^ Mud log req'd: Yes[ No^ HzS measures: Yes^ No[,~ Directional svy req'd: Yes[ No^ ~,V~~~~~`wV`\i l~~ ~ScV~S~.~ d~ ~~C Othe t . r. . ~'~s~- ~~ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 U t ` (v ~ ~ v ~ ~""' V ~ `'"'~ Submit in Duplicate Chevron Deep Creek Unit Happy Valley #13 Gas Well Drilling Procedure Summary 1. Prepare location. Set cellar. Drill and drive 16" conductor casing to +/- 117'. Install unitized wellhead. 2. MIRU Nabors #106E drilling rig. 3. PU drillpipe and 12-1/4" bit and straight hole BHA. 4. RIH and clean-out 16" conductor. 5. Drill 12-1/4" hole with 8.7-9.0 ppg water-based mud to a depth of +/- 300'. 6. POOH w/ straight hole BHA. PU 12-1/4" directional BHA. 7. Directionally drill 12-1/4" hole with 8.7-9.0 ppg water-based mud to casing point at +/- 1100'. 8. Condition hole and POOH. Laydown bit and BHA. 9. RU and run 9-5/8" casing. 10. MU and test cement lines. Circulate and cement casing bringing cement to surface. Bump top plug and test casing to 2500 psi. 11. NU BOPE equipment. Test BOPE to 2500 psi/250 psi. 12. MU 8-1/2" directional BHA and RIH. Drill out float equipment, and 20' of new formation. Pull back into the casing and conduct aleak- off test or FIT test to 15.0 ppg EMW. 13. Directionally drill 8-1/2" hole to intermediate casing shoe at +/- 3,650' with 9.0-9.3 ppg oil-based mud. 14. Condition hole and POOH. Laydown bit and BHA. 15. RU and run 7" casing. 16. MU and test cement lines. Circulate and cement casing bringing cement to 9-5/8" shoe. Bump top plug and test casing to 2500 psi. 17. MU 6-1/8" directional BHA and RIH. Drill out float equipment, and 20' of new formation. Pull back into the casing and conduct aleak- off test or FIT test to 15.5 ppg EMW. 18. Directionally drill 6-1/8" hole to TD at +/- 7,747' with 9.0-9.5 ppg oil- based mud. 19. Condition hole and POOH. Laydown bit and BHA. 20. RU and run open hole logging suite from TD to 7" shoe. 21. RU and run 3-1/2" liner. Set liner top above 7" shoe. 22. MU and test cement lines. Circulate and cement casing bringing cement to liner top. Bump top plug .and test casing to 2500 psi. 23. RU and run 3-1/2" completion and land in top of liner. 24. Test tubing to 2500 psi and tubing x casing annulus to 1500 psi. 25. ND BOPE. NU and test dry tree to 5000 psi. Release Rig. 3 Drilling Procedure Summary HV-13.doc 1 10/26/2007 Chevron Surface Location: Happy Valley B-Pad 614.0' Above MSL X:223691 Y: 2190972 Sec. 21, T2S, R13W, SM Production Tubing: 3'/z', 9.2 ppf, L-80, IBT-Mod to 3500' Completion: Chemical injection sidepocket mandrel at 2100' Zones: BLG-40 3754' MD (2317' NDSS) BLG-45 4537' MD (3090' NDSS) BLG-80 5497' MD (4050' NDSS) T-17 7337' MD (5890' NDSS) 0' MD Surface 117' MD 16" Casing Point 300-1675' MD Build 4°/100 to 55° Inc 1100' MD 9-5/8" Casing Point 2500-4400' MD Drop 3°/100 to 0° Inc 3650' MD 7" Casing Point 7747' MD TD Well Well Name: Happy Valley #13 Field: Deep Creek Unit Completion: Proposed Conductor: 16", 109 ppf, X-56 to 117' Surface Casing: 9%e', 40 ppf, L-80, BTC to 1100' Cmnt with 71 bbl of 12.2 ppg lead and 24 bbl of 15.8 ppg tail "G" Production Casing: 7", 26 ppf, L-80, BTC to 3650' Cmnt with 73 bbl of 12.8 ppg LiteCrete Production Liner: 3%2', 9.2 ppf, L-80, 1BT-Mod liner from 3500' - 7747' Baker ZXP packer, HMC liner hanger & tieback sleeve at 3500' Cemented with 126 bbl of 12.8 ppg LiteCrete PBTD = 7687' MD TD = 7747' MD 4 WBD HV-13 Proposed v1.2.x1s October 26, 2007 Drawn by: STP 0 1000 2000 3000 4000 5000 w ,~ 6000 .~ a A 7000 8000 9000 10000 11000 12000 Chevron Happy Valley #13 Depth vs. Time Drilling Time 12-1 /4" Hole 9-518" Casing 8-1 /2" Hole - -- - 7" Casing 6-1/8" Hole 3-1 /2" Casing 0 5 10 15 20 25 30 Time (Days) Chevron Planned Wellpath Report HV#13 Version 4 Page 1 of 4 Cook Inlet, Alaska (Kenai Penninsula) South Kenai Gas Field Happy Valley B Pad Slot HV#l3 Well HV#13 Wellbore HV#13 ~~~ BAKER N116NES INTEQ Projection System ~NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet 'Software System ~We1lArchitectTM 1.2 _,.m__________. ._ __w___ _ _ _,_.__..._ ; North Reference ITrue User Ulricard :Scale 0.999987 Report Generated 10/17/07 at 13:11:34 .;Wellbore last revised 08/21/07 Database/Source file WA Anchorage/HV#13.xm1 e ® , . ~ __. ~ _ .. . .. . . . . . ... ..__ _ .___._.._v. __m....._. ~._ _ ~. ` ._... _... _..._..~.. Local coordinates ._.._ __ .__.~....._ _.._______. ._._._._v.._ ... _._.. ...._ ~, _.....___.~.,.._.~ _~_..._~. __._._,..._ .. e Grid coordinates Geographic coordinates ._a_~_____._ _. ._. _ North [feet] ~ East [feet] _~__~__.~._.______~.___._u_r._ __.~.. __._._.__ _,, _.._ ~. _~ Easting SUS feet] Northing [US feet Latitude [°] Longitude [°] . _._ =Slot Location -2920.22 -333.30 223690.68 2190972.28 ~9 59 19.587N 151 30 32.305W 1 . ___ .~ .~.. _ ~. e , . _. __ Facility Reference Pt ~ ~ ~ 224090.41 2193884.11 59 59 48.347N 151 30 25.754W 'Field Reference Pt 269300.00 2597450.00 61 06 11.304N 151 18 14.248 W e ', ~..,~ .._ ...._.__. _. _...........__,..__.~ __~~.__.m .~ .,... ..__...,.__..._._.~_. ECalculation method Minimum curvature .._._...__ _.___._.~. _........_._... _._.__~_.____..__~ .e._._._~._~_..__.__...e_._. .. .....__._.._._ ,_.~. 'Rig on HV #13 (RKB) to Facility Vertical 614.00 feet ;Datum _ ___.______ .__.~ _.___. ;Horizontal Reference Pt Slot ________._,__ __ __.., _.. , _.__ .__._.~._.________a_.._. __.u, _ _ _...... 3Rig on HV #13 (RKB) to mean sea level 614.00 feet ' __ _______.___________ _ __ _._____.___ ",Vertical Reference Pt 'Rig on HV #13 (RKB) .__.________.__~ __ ..__ m_... _..___._..,... w...._..._ __ ___.__ ~. _. _ ~._._____ _ . 'Facility Vertical Datum to Mud Line (Facility) 0.00 feet ___.__._.__.___._ . _ . _. _ _. __ ___. __.__. 'MD Reference Pt Rig on HV #13 (RKB) __ _____ .___ ...,..~ ._ _. _ ______ _m___..__,.. ___. _ __ ,_.. _ _. 'Section Origin Iv 0.00,E 0.00 ft ':Field Vertical Reference mean sea level Section Azimuth 227.30° Chevron Planned Wellpath Report ;,. HV#13 Version 4 Page 2 of 4 ®. ~ ® _ Operator Chevron Slot HV#13 ----- -- Area Cook Inlet, Alaska (Kenai Penninsula) Well HV#13 _.- Field South Kenai Gas Field Wellbore HV#13 _.___ Facility Happy Valley B Pad [feet] 'ATH DATA (83 stations) -~ = i Inclination Azimuth TVD [°] [°] [feet] ~ 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1675.00 1700.00 1900.00 2000.00 2100.00 2523.86 31 3300.00 3400.00 3500.00 3600.00 :erpolated/extrapolated station TVD from Vert Sect North East Fld Vert Ref [feet] [feet] [feet] [feet] -614.00 0.00 0.00 0.00 -514.00 0.00 0.00 0.00 _ _ -414.00 0.00 0.00 0.00 -314.00 ~` 214 08 0.00 49 3 0.00 2 37 0.00 2 56 - . -114.65 . 13.94 - . -9.45 - . -10.24 r~~~ BAKER I~It~GMES INTEQ Grid East _1 Grid North DLS [us survey feet] [us survey feet] [°/100ft] 223690.68 2190972.28 0.00 223690.68 2190972.28 0.00 223690.68 2190972.28 0.00 223690.68 6 2190972.28 2 90969 97 0.00 4 00 223688.0 223680.22 1 . 2190963.06 . 4.00 223667.20 2190951.58 4.00 223649.06 2190935.59 4.00 223625.88 9 9 2190915.16 2190890 39 4.00 4 00 2235 7.7 223564.91 . 2190861.41 . 4.00 223527.41 2190828.35 4.00 223485.47 2190791.38 4.00 223439.30 12 89 2190750.68 2190706 44 4.00 4 00 2233 . 223335.17 . 2190658.88 . 4.00 223277.72 2190608.23 4.00 223232.50 2190568.37 4.00 223217.14 6 2190554.83 2190 66 00 0.00 0 00 223155. 9 223094.25 5 . 2190446.49 . 0.00 223032.80 2190392.32 0.00 222971.35 2190338.15 0.00 222909.91 8 6 2190283.98 2190229 81 0.00 0 00 22284 .4 222787.01 . 2190175.64 . 0.00 222725.57 2190121.48 0.00 2227]0.91 2190108.55 0.00 222664.79 2190067.89 0016 2 35 3.00 3 00 222606.32 222550.39 19 . 2189967.05 . 3.00 222497.16 2189920.12 3.00 222446.76 2189875.69 3.00 222399.34 2189833.89 3.00 222355.03 2189794.82 222313.94 2189758.60 3.00 3.00 222276.19 2189725.33 3.00 222241.89 2189695.09 3.00 222211.13 2189667.97 3.00 • Planned Wellpath Report HV#13 Version 4 Page 3 of 4 4000.00 10.716 227.295 3169.58 4100.00 ' 7.716 227.295 3268.28 4200.00 4300.00' 4.716. 227.295 3367.68 1.716 227.295 3467.51 4357.20 0.000 227.295 3524.70 4400.00' 0.000 0.000 3567.51 4500.00 0.000 0.000 3667.51 4600.00 4700.00 4800.00 4900.00 5000.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 'ri nn nn 7496.49 0. 0. 0. 0. 0. 0. 0. 0.000 6367.51 0.000 6467.51 0.000 6567.51 227.295 6664.00 erpolated/extrapolated station TVD from Vert Sect North East Fld Vert Ref [feet] [feet] [feet] [feet] 2361.38 2039.86 -1383.48 -1499.00 2457.86 2066.10 -1401.27 -1518.29 2555.58 2087.26 -1415.62 -1533.84 2654.28 2103.27 -1426.48 -1545.60 2753.68 2114.10 -1433.83 -1553.56 2853.51 2119.71 -1437.63 -1557.68 2910.70 2120.56 -1438.21. -1558.31 -_ 2953.51 2120.56 -1438.21 ' -1558.31 3053.51 2120.56 -1438.21 -1558.31 3153.51 2120.56 3253.51 2120.56 -1438.21 -1558.31 -1438.21 -1558.31 3353.51 2120.56 -1438.21 -1558.31 3453.51 2120.56 -1438.21 -1558.31 3553.51 2120.56 51 2 6 3 20 6 -1438.21 438 21 -1558.31 1 31 8 3 5 . 1 .5 3753.51 2120.56 -1 . -1438.21 - 55 . -1558.31 3853.51 2120.56 -1438.21 -1558.31 3953.51 2120.56 -1438.21 -1558.31 4053.51 2120.56 -1438.21 -1558.31 4153.51 2120.56 4253.51 2120.56 -1438.21 -1438.21 -1558.31 -1558.31 4353.51 2120.56 4453 51 212 6 -1438.21 1438 21 -1558.31 1558 31 . 0.5 4553.51 2120.56 4653 51 2120 56 - . -1438.21 21 1438 - . -1558.31 1558 31 . . 4753.51 2120.56 - . -1438.21 - . -1558.31 4853.51 2120.56 -1438.21 -1558.31 4953.51 2120.56 -1438.21 -1558.31 5053.51 2120.56 -1438.21 -1558.31 5253.51 2120.56 -1438.21 -1558.31 5353.51 2120.56 5453.51 2120.56 -1438.21 -1438.21 -1558.31 -1558.31 5553.51 2120.56 5653.51 2120.56 5753.51 2120.56 -1438.21 -1438.21 -1438.21 -1558.31 -1558.31 -1558.31 5853.51 2120.56 -1438.21 -1558.31 5953.51 2120.56 -1438.21 -1558.31 6050.00 2120.56 -1438.21. -1558.3: rr,~~ BAKER Nt~6MES INTEQ Grid East Grid North DLS [us survey feet] [us survey feet] [°/IOOft] 222160.54 2189623.37 3.00 222140.85 2189606.01 3.00 222124.98 2189592.02 3.00 222112.97 . 2189581.43 3.00 222104.85 2189574,2$ ' 3.00 222100.64 2189570.57' 3.00 222100.00 2189570.00 3.00 222100.00 2189570.00 0.00 222100.00 2 00 00 2189570.00 0.00 2189570 00 0 00 2 21 . 222100.00 . . 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 0 2189570.00 0.00 2 8 0 00 0 00 222100.0 222100.00 1 957 . . 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 2189570.00 0.00 00 222100.00 222100.00 2189570.00 0. 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 222100 00 2189570.00 0.00 2189570 00 0 00 . 222100.00 . . 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 2189570.00 0.00 222100.00 2189570.00 0.00 Chevron - Planned Wellpath Report ,_-- HV#13 Version 4 - Page 4 of 4 r~~~ BAKER NV6MES INTEQ ELLPATH DATA (83 stations) -~ =interpolated/extrapolated station MD Inclination Azimuth TVD TVD from Vert Sect North East _ Grid East Grid North DLS Meet] [°] ~°] Meet] Fld Vert Ref ~feet~ Meet] [feet] [us survey feet] [us survey feet] [°/100ft] [feet] 7600.00 0.000 0.000 6767.51 6153.51 2120.56 7700.00 j- 0.000 0.000 6867.51 6253.51 2120.56 -1438.21 -1438.21 -1558.31 -1558.31 222100.00 2189570.00 0.00 -- -- 222100.00 2189570.00 0.00 7746.49 0.000 227.295 6914.00 6300.00 2120.56 -1438.21 -1558.31 _ _ _ 222100.00 ' 2189570.00 0.00 ] TARGETS .Name MD TVD North East Grid East Grid North Latitude Longitude Shape [feet] [feet] [feet] [feet] [us survey [us survey [°] [°] 2932.00 -1438.21 -1558.31 feet] 222100.00 feet] __ . 2189570.00 59 59 05.422N 151 31 02.934W square HV #13 Target #1 7496.49 1) HV #13 Target #2 HV #13 Target #3 --- 14.00 -1438.21 -1558.31 222100.00 2189570.00 59 59 05.422N 151 31 02.934W HV#13 Start MD End MD Positional Uncertainty Model [feet] [feet] 0.00 1000.00 NaviTrak (Magcorrl ) _ 1000.00 3654.00 AutoTrak G3 (Standard) 3654.00 7746.49NaviTrak (Maecorrll HV#13 Version 4 Log Name/Comment __ _ __. Wellbore X13 X13 X13 • Chevron Location: Cook Inlet, Alaska (Kenai Penninsula) Slot: HV#13 Field: South Kenai Gas Field Well: HV#13 Facilit : Ha Valle B Pad Wellbore: HV#13 Plot reference wellpath is HV#13 Version 4 True vertical depths ate referenced to Rig on HV #13 (RKB) Grid System: NAD27 / TM Aleake State Plane. Zone 4 (5004), US feat Measured depths are referenced io Rig on HV if13 (RKB) NorM Reference: True north RIB on HV p13 (RKB) io mean sea level: 814 (eat Scale: Truce distance ea level to Mutl line (Facilhy -Happy Valley B Patl): O feet Depths are in feet Coortlinates era in Teel reTerencetl to Blot Createtl by: uldurtl on 1 0/1 72 00 7 ,;{~. ~~~~ BAKER NuGMES INTEQ N .,~ l \1' I d5 0 to 2009.0) Dip'. ]2 e]' F 209.] nT g uc Nortn is 18 ]5 tle9reet: Eaa10l True North (at 11/15A7) To correct azimuln Irom Magneuc io True a0tl 1a ]5 eeareea Z 0 9' ro x 9calallnch-300h Easting (ft) Chevron Chevron Location: Cook Inlet, Alaska (Kenai Penninsula) Fi61d: South Kenai Gas Field ~r~ BArK^ lR Slot: HV#13 NV~I ~~~ weu: Hv#13 INTEQ Plot reference wellpath is HV#13 Version 4 True vertical tlepths are referenced to Rig on HV #13 (RKB) Gdd System: NAD27 / TM Alaska State Plane, Zone 9 (5009), US feet Measured depths are referencetl to Rig on HV #13 (RKB) North Reference: True north 1~T Rig on HV #13 (RKB) to mean sea level: 614 feet Scale: Trus distance TRUE ea level to Mud line (Facility -Happy Valley B Pad): 0 feet Dep[hs are in feet Coortlinates era in feet referenced to Slot Created by: ulricertl on 10/1)200) Well Profile Data A' f: Design Comment MD (R) Inc (°) Az (°) TVD (R) Local N (ft) Local E (ft) DLS (°/100ft) VS (ft) Tie On 0.00 0.000 227.295 0.00 0.00 0.00 0.00 0.00 End of Tangent 300.00 0.000 227.295 300.00 0.00 0.00 0.00 0.00 BGGM (1995.0 [o zWaO) Dip: M.eJ° Field: 55209.) nT Ma9nehc North is 18.]5 tlegrees East of True North (a[ t t/15pJ) End of Build 1675.00 55.000 227.295 1473.35 -014.26 -448.86 4.00 610.81 End of Tangent 2523.86 55.000 227.295 1960.24 -885.86 -959.84 0.00 1306.15 To oorrea azimuth rom Magneae m True aea 1a Js aegreee End of Drop 4357.20 0.000 227.295 3524.70 -1438.21 -1558.31 3.00 2120.56 End of Tangent 7496.49 0.000 227.295 6664.00 -1438.21 -1558.31 0.00 2120.56 End of Tangent 7746.49 0.000 227.295 6914.00 -1438.21 -1558.31 0.00 2120.56 -1500 m -750 0 Tie On :0.00° Inc, O.OOft MD, O.OOft TVD, O.OOft VS d d 16in Conductor :0.00° Inc, 100.OOft MD, t00.00ft TVD, O.OOft VS End of Tangent :0.00° Inc, 300.OOft MD, 300.OOft TVD, O.OOft VS 7~ \ 9.625in Casing Surtace :28.00° Inc, 1000.OOft MD, 972.47ft TVD, 167.67ft VS D e4.00°/100ft 1500 _ 2250 L Q O 3000 l6 U_ 1= N ~ 3750 0 3 H 4500 HV #13 Target #2 - HV #13 Target #3~ of Build :55.00° Inc, 1675.OOft MD, 1473.35ft TVD, 610.81ft VS of Tangent :55.00° Inc, 2523.86ft MD, 1960.24ft TVD, 1306.15ft VS ~100ft Tin Casing Intermediate :21.10° Inc, 3654.OOft MD, 2837.29ft TVD, 1992.56ft HV #13 Target #1 -End of Drop :0.00° Inc. 4357.20ft MD, 3524.70ft TVD, 2120.56ft VS End of Tangent :0.00° Inc, 7496.49ft MD, 6664.OOft TVD, 2120.56ft VS End of Tangent :0.00° Inc, 7746.498 MD, 6914.OOft TVD. 2120.56ft VS 3.Sin Liner :0.00° Inc, 7746.49ft MD, 6914.008 TVD, 2120.56ft VS 0 750 1500 2250 3000 3750 4500 5250 8000 8750 Vertical Section (ft) 6eale,in°h=,5008 Azimuth 227.30° with reference 0.00 N, 0.00 E from wellhead Chevron iL~ Deep Creek Unit Happy Valley #13 Gas Well Offset Well Survey Offset Well Survey (from Happy Valley #12) The conductors for Happy Valley #12 and #13 have approximately 45 feet of separation (Happy Valley #13 is roughly southwest of Happy Valley #12). The drilling of the 12-1/4" surface hole for Happy Valley #13 will be done with astraight- hole BHA to approximately 300 feet. This BHA will be pulled and a new directional BHA w/ MWD measurements will be used for directional control and angle building. These directional measurements will be used to avoid a potential collision with the offset surface hole of Happy Valley #12. The directional survey for the 12-1/4" surface hole of Happy Valley #12 is provided for reference. The survey shows the hole section to be vertical with minimal departure away from the Happy Valley #13 location. Happy Valley #12 Directional Survey (12-1/4" Hole) MD (feet) Inc (°) Azimuth (°) TVD (feet) Departure (feet) N/S (feet) E/W (feet) 275 0.34 66.16 275 0.82 0.33 0.75 335 0.40 50.61 335 1.20 0.53 1.07 389 0.31 68.86 389 1.53 0.71 1.35 449 0.55 71.69 449 1.97 0.86 1.78 516 0.46 71.39 516 2.56 1.04 2.34 575 0.58 72.23 575 3.09 1.21 2.85 634 0.58 75.03 634 3.69 1.38 3.42 694 0.68 75.75 694 4.34 1.54 4.06 756 0.59 74.17 756 5.03 1.72 4.72 816 0.59 76.27 816 5.64 1.88 5.32 876 0.52 68.03 876 6.22 2.05 5.87 939 0.68 60.38 939 6.87 2.35 6.46 6c Offset Well Survey.doc 1 10/26/2007 i • Chevron Maximum Anticipated Surface Pressure Calculation Happy Valley Well #13 Kenai Peninsula, Alaska Assumptions: 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a 0.452 psi/ft gradient from surface to planned total depth at 6,914' TVD BRT. 2. The M.A.S.P. during drilling operations will be governed by the 7" shoe frac gradient, and is calculated based on a full column of gas between the 7" shoe and the surface. The shoe for HV #13 at 2834' TVD will be between the shoe depths of offset wells on Happy Valley A-pad, ranging from 2600' to 5186' TVD. Leak-off or formation integrity tests ranged from 12.9 ppg to 19.8 ppg (0.671 psi/ft and 1.030 psi/ft). This offset LOT/FIT data from A-pad is useful for relatively accurate kick tolerance & MASP calculations. 3. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. M.A.S.P. During Production Life: Max. pore pressure at T.D. = 6,914 ft. x 0.452 psi/ft = 3128 psi M.A.S.P. (tbg leak at surface) = 3128 psi - (0.1 psi/ft * 6,914 ft) _ = 2437 psi M.A.S.P. While Drilling 6-1/8" hole at 6,914' TVD: Max. Est. Frac pressure at 7" shoe = 2834 ft. x 0.750 psi/ft - 2126 psi M.A.S.P. during drilling = 2126 psi - (0.1 psi/ft x 2834 ft.) _ = 1843 psi M.A.S.P. While Drilling 8-1 /2" hole at 2,834' TVD: Max. Est. Frac pressure at 9-5/8" shoe = 1059 ft. x 0.728 psi/ft = 771 psi M.A.S.P. during drilling = 771 psi - (0.1 psi/ft x 1059 ft.) _ = 665 psi Calculation & Casing Design Factors Chevron Happy Valley Well #13 Kenai Peninsula, Alaska WELL: Happy Valley #13 FIELD: South Kenai Gas DATE: 26-Oct-07 DESIGN BY: Stan Porhola Sect. 1 12 1/4" hole MUD WT. 9.0 PPG MASP= 665 psi** Sect. 2 8 1/2" hole MUD WT. 9.3 PPG MASP= 1,843 psi Sect. 3 6-1/8" hole MUD WT. 9.5 PPG MASP= 2,437 psi Production Mode TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS @ RESIST. MINIMUM DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM w/o TENSION WORST CASE MASP YIELD WORST CASE SECTION CASING BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI* PSI SF COLL. PSI** PSI SF BURST 1 9-5/8" 1,100 0 1100 40 L-80 BTC 44,000 44,000 916 20.82 479 3,090 6.46 665 5,750 8.65 TVD 1,059 0 2 7" 3,650 0 3650 26 L-80 BTC 94,900 94,900 604 6.36 1,281 5,410 4.22 1,843 7,240 3.93 TVD 2,834 0 3 31/2" 7,747 0 7747 9.2 L-80 IBT-mod 71,272 71,272 207 2.90 3,125 10,530 3.37 2,437 10,160 4.17 TVD 6,914 0 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.452 psi/ft) and the casing evacuated for the internal stress (0 psi/ft) ** See attached sheet for calculation of MASP • • Chevron Deep Creek Unit Happy Valley #13 Gas Well Cement Program 16" Casing (Driven to +/-117' Note: This string is only for structural support of the wellhead and diverter system. 9-5/8" Casing (12-1 /4" Hole to 1,100' MD): Cement volume based on annular volume plus 50% and shoe joint(s). The job will consist of a lead and tail and cement will be brought to surface. The estimated total volume is as follows: Lead: 850' X 0.3132 cuft/ft (12-1/4" x 9-5/8") X 1.5 = 400 cult = 204 sxs (1.97 yield) Tail: 250' X 0.3132 cuft/ft (12-1/4" x 9-5/8") X 1.5 = 235 cult = 201 sxs (1.17 yield) 40' shoe joint X 0.4110 cuft/ft TOTAL: 400 + 235 + 17 = 652 cult or 420 sxs 7" Casing (8-1/2" Hole to 3,650' MD): = 17 cult = 15 sxs (1.17 yield) Cement volume based on annular volume plus 20% and shoe joint(s). The job will consist of a lead only and cement will be brought to 1,100' MD. The estimated total volume is as follows: Lead: 2,550' X 0.1268 cuft/ft (8-1/2" x 7") X 1.2 = 389 cult = 182 sxs (2.14 yield) 80' shoe joint X 0.2148 cuft/ft = 18 tuft = 9 sxs (2.14 yield) TOTAL: 389 + 18= 407 cult or 191 sxs 3-1/2" Liner (6-1/8" Hole to 7,747' MD): Cement volume based on annular volume plus 20% and shoe joint(s). The job will consist of a lead only and cement will be brought to 3,500' MD (Top of Liner). The estimated total volume is as follows: Lead: 4,097' X 0.1378 cuft/ft (6-1/8" x 3-1/2") X 1.2 = 678 cult = 330 sxs (2.06 yield) Lead: 150' X 0.1480 cuft/ft (6.276" x 3-1 /2") X 1.2 = 27 cult = 14 sxs (2.06 yield) 60' shoe joint X 0.0488 cuft/ft TOTAL: 678 + 27 + 3 = 708 cult or 346 sxs = 3 tuft = 2 sxs (2.06 yield) 8 Cement Program HV-13.doc 1 10/26/2007 U Chevron Deep Creek Unit Happy Valley #13 Gas Well Mud Program Surface Hole Recommendations Mud Type: LSND (Low-solids, Non-dispersed) Gel Mud (Water-based) Properties: Densi Viscosi Plastic Viscosity Yield Point API FL ~H 0 - 1100' 8.7-9.0 60 - 85 6 - 16 25 - 35 < 12 8.5-9.0 System Formulation: LSND (Water-based Product Concentration Water 0.915 bbl Aquagel 20 ppb (as required 25 YP) PAC L 1 ppb (API <6) Caustic soda 0.15 ppb (9.0 pH) Aldacide G 0.1 ppb Baroid 62 b to 9.0 • Mix in order as listed • Add polymers slowly to minimize fisheyes. Intermediate Hole Recommendations Mud Type: Invermul System (Oil-based) Properties: Densi Viscosi PV YP ES HTHP WPS O/R' FL 1100' - 3650' 9.0 - 9.3 55 - 80 18 - 30 9 -18 1000- <8 290 to 320K 80/20 1100 System Formulation: Invermul System (Oil-based) Product Concentration Base Oil 0.696 bbl EZ MUL NT 4 ppb INVERMUL 4 ppb. GELTONE V 4 ppb Lime 5 ppb DURATONE 4 ppb RM 63 1 ppb Water 0.178 bbl CaCl2 24.6 ppb AK-70 4 ppb BAROID to a 9.3 9 Mud Program HV-13.doc 1 10/26/2007 Chevron Production Hole Recommendations Mud Type: Invermul System (Oil-based) Properties: Deep Creek Unit Happy Valley #13 Gas Well Mud Program Densi Viscosi PV YP ES HTHP WPS O/W FL 3650' - TD 9.0 - 9.5 55 - 80 18-29 9-18 1000-1100 <8 290 to 320K 80/20 System Formulation: Invermul S stem Oil-based) Product Concentration Base Oil 0.696 bbl EZ MUL NT 4 ppb INVERMUL 4 ppb GELTONE V 4 ppb Lime 5 ppb DURATONE 4 ppb RM 63 1 ppb Water 0.178 bbl CaCl2 24.6 ppb AK-70 4 ppb BAROID to a 9.5 9 Mud Program HV-13.doc 2 10/26/2007 Chevron \J • Deep Creek Unit Happy Valley #13 Gas Well Drilling Waste Plan Drilling Waste Plan The water-base and oil-base mud cuttings will be hauled from the Happy Valley B- pad to the NNA #1 (PTD No. 201-215) Class II disposal well located on the NNA- pad in the Deep Creek Unit. A grind and inject facility has been mobilized and is located at the disposal well location ready to accept cuttings. The cuttings will be transported from the rigsite to the disposal well by vacuum trucks. In addition to the drill cuttings, excess water-base and oil-based mud will be injected at the end of the project. The contingency plan in case the grind and inject facility would become inoperable for any reason is twofold. First, the cuttings may be loaded into tanks for storage until the grind and inject facility is operational. Second, the cuttings may be hauled to an offshore location on the Bruce Platform for injection in the Class II disposal well Br-3-87 (PTD No. 166-052). 10 Drilling Waste Plan.doc 1 10/26/2007 LEAK OFF TEST PROCEDURE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circulate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drillpipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. Anon-permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure-vs-cumulative volume pumped. Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of leak-off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank The point "B" shown in the attached graph at which the plot of drillpipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The leak-off pressure is calculated as follows: Leak-off (EMW) = Mud weight in hole + P.I.T. (PSI) (0.052) X (shoe depth in TVD ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. SURFACE PRESS_ TYPICAL PIT PLOT [psi] NOTES: Point "A" will have some variance until the system begins to pressure up. Point "B" is the leak off and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is known as the fracture closure pressure and may not stabilize if permeable formations are exposed. VOLUME PUMPED SHUT-IN-TIME [BBLS] [MIN] Chevron ESTIMATED GEOLOGIC TOPS AND CORRELATIONS HAPPY VALLEY #13 Elevation 593 RKB 614 Marker Lithology Fluid Target Depths (+/-100') MD TVD TVDSS BLG-20 Sand Gas/Water Secondary 3754 2931 2317 BLG-40 Sand Gas/Water Secondary 3910 3079 2465 BLG-45 Sand Gas/Water Secondary 4538 3705. 3090 BLG-80 Sand Gas/Water Secondary 5488 4655 4040 T-10 Coal Gas/Water N/A 7067 6234 5619 T-10 Sand Gas/Water Primary 7096 6263 5648 T-17 Sand Gas/Water Primary 7338 6505 5890 TD 7747 6914 6300 r~ L NOTES 1. BASIS OF HORIZONTAL COORDINATES IS NGS OPUS SOLUTION FOR FOR NGS BM V82 N:2240664.076 E218221.088 ALASKA STATE PLANE (ASP) ZONE d NAD27. 2. BASIS OF ELEVATION IS NGS BM V82 NAVD 88 ELEV. 288.42 FT. 3) SECTION LINE OFFSETS DERIVED FROM PROTRACTED SECTION CORNER POSITIONS. 4. SURVEY WAS PERFORMED BY MCI ON 8/14/07 ~~~~ OF q~q I-I Q, ~' S ~ .••• 'f' ~j ~ x.49 ~ ~ z ..................................., L~ .A .: .............................~ N ~ •. M. SCOTT McLANE;' c~ . rn ~I ~~F '•. 4928-S ~~ N ~j~ CFO p ~ 8/17/07 ~P~oy~~ GRAVEL DRAIN c) \~ ~T NORTH SCALE 0 10o zoo FEET HAPPY VALLEY N0. 13 AS-BUILT WELL CONDUCTOR GRID N: 2190972.281 GRID E: 223690.676 LATITUDE: 59 °59' 19.587"N LON GI TU DE:151 °30'32.305"W ELEV. 593' HAPPY VALLEY NO. 13 WELL AS-BUILT SURFACE LOCATION NINILCHIK, AK ENGINEERING -TESTING SURVEYING -MAPPING P.O. BOX 468 INCL~ri, SOLDOTNA, AK. 99669 VOICE: (907) 283-4218 FAX: (907)283-3265 Caraul~kglnc WWW.MCLANECG.COM S16 ~ S15 Project: 073039 Revisions: #3 Dwg:073039 I Date: 08/17/07 APPLICANT: T 909 W. 9th Avenue Anchoraae. AK 99519-7685 FIGURE: 1 o~"AA AS-BUILT ~~; ~ HV#13 4" PVC PIPE 2 S21 PI S22 PROTRACTED POSITION GRID N: 2193884.105 GRID E: 224090.412 LATITUDE: 59°59'48.347"N LONGITUDE: 151 °30'25.754"W ' SECTION 21 `~\ \ TOWNSHIP 2 SOUTH RANGE 13 WEST SEWARD MERIDIAN ~\ ALASKA 12"X4 CMP BELUGA PAD N 2#9 OOBL540P E 223988.270 ELEV. 597.410' i 337 FEL / • PROTRACTED POSITION GRID N: 2193884.105 GRID E: 224090.412 LATI TU DE: 59 °59' 48.347"N LONGITUDE:151°30'25.754"W `~~~~~~~~II ~~,~~ OF q~q I ~I % - % ~ ~..~ .:.............................~ r~ ~ ~ M. SCOTT McLANE:~~ - ~ ~ s '•. ~ ~F '•. 4928-S ,• ~- ~j~ CFO •'•8103/,0.7 ~•' o~ I~ I 1\~~~~~ ~~ HV #13 B.H.L. GRID N: 2189570.000 GRID E: 222100.000 LATITUDE: 59 °59' 05.422" LONGITUDE: 151 °31'02.934" NOTES 1. BASIS OF HORIZONTAL COORDINATES IS NGS OPUS SOLUTION FOR FOR NGS BM V82 N:2240864.078 E:218221.088 AL4SKA STATE PLANE (ASP)ZONE4 NAD27. 2. BASIS OF ELEVATION IS NGS BM V82 NAVD 88 ELEV. 289.42 FT. 3) SECTION LINE OFFSETS DERIVED FROM PROTRACTED SECTION CORNER POSITIONS. 4. SURVEY WAS PERFORMED BY MCI ON 6/11/07 HV #13 AS-STAKED SECTION 21 TOWNSHIP 2 SOUTH RANGE 13 WEST SEWARD MERIDIAN ALASKA 1897'FEL NORTH SCALE 0 500 1000 FEET HAPPY VALLEY NO. 13 WELL BOTTOM HOLE LOCATION NINILCHIK, AK ENGINEERING -TESTING SURVEYING -MAPPING P.O. BOX 468 M~~~., SOLDOTNA, AK. 99669 VOICE: (907) 283-4218 FAX: (907)283-3265 ~.o1L711~ I11C WWW.MCLANECG.COM Project: 073039 Revisions: N/A Dwg:073039 I Date: 08/03/07 S16 I S15 S21 I S22 S21 S22 S28 S27 APPLICANT: ~~~"' 909 W. 9th Avenue Anchorage, AK 99519-7685 FIGURE: 1 at.l4 - __ _- i .._ ' ' ~' _ i 1 - r }. .,•-.rah, t. . ~ ~ _ - t = ~ ~.. ,~; , _ ._. _ -. ---'r LANDING STRIP ~' ~,. e~ '~ -1 - - _ T// , R - OILWELL RD „ -tiNr;~,r ' _ ~ _ ~ f~. 1 t !j. .. - - _ ~ fY~ -l _ - r - F---~ - _ _ - - r ! . .n I :,I - .. _ , _~ t~ 1 .. , t. ~__.. _ __ ..~ _~~' .. ~~.'-` i ~ ~~ M1NHFPY VH'LtYB - - ~~ .`. - .ir_ '---~` _ '- I r. .~'~ ~5~!I` -.L....r owe ~,.. ,_I i ~ ~ i i .` ~'. ~ Fran '~, ~, t ~. -~ __ - ~ ~ ~ 1 DEEPCREEKUNIT a ~^i'i~''-~- r -e X 1 ~ v j ~~i ~ ` <• ``~' ~- ---- ~ Y gyn.-r c ~ I I'- a t, - ~--- K ~ _ , 3 _ - . it -. 1 ~ i t.~ P 1 ,1 ' ~ ~ 1 _ 1 1 v . ~ fi° i h- ' 1 ~ . U 4,. i . _._ ~ ,. 'i ~~ .'; ~ r i ~~~ ~ - ~-'APP. -' - `, r '. `~ S~r",R r ~a i. xl I.' 1 ~ , .rQ,c .31 y iG~ - i pr } i - - TALL TREE % 1\ ,/ 1~ n- - j _i I ~ ~- .. - ~!` RD __ , i ~ __ S i _ -- _ ~ `<. `~I- off' _ ~!,~ - - - - -~ -NIKOL~EVSKUNIT~ v Y._:.- 1 _ _~ 1 ~Q 1 .r - - -+ : I ,- Chevron _ i ,--1 t '" Union Oil Company _ _ - - _--- ~ -- ~ ~ of California .. - ~- ":, - ' Deep Creek Unit Locations t. ._. ~ - 7 - ~ os o ~ -- -- .___ .3' ~. ~ - ~' m ~ Alaska State Plane Zone 4, NAD27 - c` ~ ~ - ,l+' i ADL384380 C061588 C061589 I ADL384380 I ._ B Pad ''"` Surface Location HV-08 (BHL) HV-13 (BHL) • HV-11 (B ~HV-02 (BHL) MV~12 (BHL) HV-04 (BHL) HV-09 (BHL) r~ HV-01 (BHL) a _~ C061590 ~ HV-06 (BHL) HV-07 (BHL) HV-05 (BHL) ice/ A Pad Surface Location Legend __ __ ' HV 12 __ HV 13 ADL384380 Happy Valley PA ®Deep Creek Unit ~ 1500 ftradius- Distance to property lines O 3000 ft radius- Distance to wells drilling or capable of producing __..._ ,~,.. ~e.,,,..,.,ffi-~..,..~ ADL384380 HV-10 (BHL) HV-03 ~~ Chevron o ~,oo0 2,000 N ,~ 1° Union Oil Company Deep Creek Unit Feet of California Happy Valley 12 and 13 Well Locations State Plane Alaska4ProJe~on NorthAmerican DdWm 1927 June 27, 2007 ~ r Happy Valley #13 BOP Stack up Bottom of Rotary Table Nabors Alaska Drilling Rig - 106E From I BOP's i , ~-;; O O VIEW ~~ B ~ 11 g ~ ~ ~'11 0 ~ ~ ~ ~ `~~ _~q ~ 10 M aterials List Item Description 1 2-1/16" 5M Manual Valve 2-14 3-1/8" SM Manual Valves A 3-1/16" 5M Hydraulic Choke B 3-1/8" 5M Manual Choke To Gas Buster I VIEW of : B B _ 11 ~~ `; ~ ~~ ti \~s ~~` -~ 74 To Flare 11 b ~4'~ ~. -h, .~ ~ ~~ 13 To Flare O O 11 a 8 0 ~ ~. -~s tl r ~ - ~-o ~ i ~ ~~ O~~I • ~~ ~ ~~ - ~~I. VIEW AA To Gauges ~,~, ~~ ~~ ,~~~'> O ~~ - ~` 1 VIEW CC 12 Revised: 10-2-07 VIEW BB • • TRANSMITTAL LETTER CHECKLgST WELL NAME. ~~,o~y ,4~~~y ~,`3 PTD# oJO ~/SID / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing welt ' (If last two digits in permit No. ,API No. 50- - _ - API number are production should continue to be reported as a function of the between 60-69) original API number stated above. OT HOLE PII In accordance with 20 AAC 25.005(f), all records, data and logs , uired for the pilot hole must be clearly differentiated in both ac q well name ( PH) and API number (50- -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing the exception. , assumes liability of any protest to the spacing exception that may occur. DRY DITCH Ali 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 t0' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for jname of welll until after ~Com_par-v Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompanv N,_ame) must contact the Commission to obtain advance approval of such water welt testing ro m. 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"~- ~ N M V ~ (O I~ W O W ~ ~ N .- e- M r ~~ (O I~ ~- ~ ~ ~ 00 ~ O O ~ N ~ N N N M N V ~ N N CO I~ O O N N N N O M M M M M M M M M M O .. .. ._ - ___.__. __.._. ~' U o o i o ~ O ~ C r r+ 10 ~ ~ N ~ IC D M y O a+ N IQ ~ U O ~ ~N w C~C ~ J ° ~' c y ~ ~ E a ~ a W ~ J~ i o a c~ C~ R Q Q U Q lL Q F- ,~ `( '"~"'i ~ Q Q Well History File /1PPENDIX 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 Tending information, information of this nature is accumulated at the end of tl~e file under APPENDIX. No special effort has been made to chronologically organize this category of information. r: RECEIVED FINAL WELL REPORT MUDLOGGING DATA HAPPY VALLEY 13 .,.. ,7 ,,. ~~ FEB p 7 2004 ~Sfca Oil $ ~ Cons. Commission Anchorage Provided by: Approved by: Distribution: January 7, 2008 ~~ EPOCH Compiled by: John Lundy Larry Resch Date: 12/30/2007 ~~-iSi # ~ ~sa~ • • Ch Happy Valley 13 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ....... 1.1 Equipment Summary .............................. 1.2 Crew ....................................................... 2 WELL DETAILS ............................................ 2.1 Well Summary ................................~---.... 2.2 Hole Data ............................................... 3 GEOLOGICAL DATA .................................... 3.1 Mudlog Summary ................................... 3.2 Connection Gas Summary ..................... 3.3 Trip/Wiper Gas Summary ...................... 3.4 Sampling Program /Sample Dispatch ... 4 DRILLING DATA ........................................... 4.1 Daily Activity Summary :.......................... 4.2 Survey Data ............................................ 4.3 Bit Record .............................................. 4.4 Mud Record ............................................ 5 MORNING REPORTS ................................... Enclosures 2"/100' Formation Log (MD&TVD) 2"/100' LWD / Lithology Log (MD&TVD) 2"/100' Drilling Dynamics Log EPOCH ..........2 ..........2 ..........2 ..........3 ..........3 ..........3 ..........4 ..........4 1 Chevron Happy Valley 13 • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary .] • Parameter Equipment Type /Position Total Comments Downtime Casing Pressure Cable to 1502 transducer for BOP 0 tests onl . Com uter -Drill Floor Monitor Azonics 0 Com uter -Pit Monitor Azonics 0 Com uter for Com an Man Ri watch Remote h coma 0 Com uter for Mud En ineer Ri watch Remote h coma 0 Com uter for Tool usher Ri watch Remote h coma 0 Computers for Mudloggers (3) Data editing, Rigwatch Master, and 0 Ri watch Remote all h com a QGM Agitator (Mounted in possum Trap briefly plugged with Ditch gas belly) Flame ionization total gas & 1.5 cuttings. Clear frozen sample chromatography. lines Hook Load / Wei ht on bit Drillin Line Sensor on Ri Floor 0 Mud Flow In Derived from Strokes/Minute and 0 Pum Out ut Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 10 radar it sensors 0 Pum Pressure Stand i e Transducer 0 Pum stroke counters 2 2 roximit sensors 0 Rate of penetration Crown Fast Sheave proximity 0 sensors RPM PLC feed 0 Tor ue PLC feed 0 Wits In (LWD Data) Inteq LWD Computer to Rigwatch 0 Master Com uter 1.2 Crew Mudloggers Years Days Sample Catchers Years Days Technician Days Lees Browne, Jr. 27 9 Teresa Downe 1 12/11 Steve Forrest 2 John Lund 16 16 Josh Dubrowski 1 12/7 Lar Resch 3 12/15 Dick Hud ins 0.5 5 M. Chowdhu 1 12/15 Unit Type Arctic Unit Number ~ ML024 ' Years experience as Mudlogger .2 Days at wellsite between spud and total depth of 7747 feet. EPOCH Chevron Happy Valley 13 . 2 WELL DETAILS 2.1 Well Summary • • Well: Happy Valley #13 API Index #: 50-231-20032 Field: South Kenai Gas Field Deep Creek Unit Surface Co-Ordinates: Lat. 590 59' 19.587" N Long. 151 30' 32.305"W Borough: Kenai Primary Targets: Tyonek Sand State: Alaska Primary Target Depth: Multiple Rig Name /Type: Nabors 106E/Antic Double TD Depth: 7747'MD 6916.6'TVD Spud Date: December 4, 2007 Ground Elevation: 593.0 FT MSL TD Date: December 22, 2007 RT Elevation: 614.5 FT MSL Days Drilling: 19 TD Formation: Tyonek Completion Status: Run Production Tubing Days Testing: 2 (E-logging) Classification: Gas 2.2 Hole Data Maximum De th Mud C / Shoe De th FIT Hole Section MD ft TVD ft TD Formation Weight (ppg) Dev. o. (inc) asing Liner MD ft ~/p ft (ppg) Conductor 117 117 - - - 16" 117 117 N/A 12 %4" 1170 1116.55 Sterlin 9.0 33.65 9 5/8" 1157 1105.72 14.88 8 '/" 3660 2844.44 Belu a 9.3 23.07 7" 3645 2830.85 14.5 6 1/8" 7747 6916.6 T onek 9.2 2.12 3'h" EPOCH Chev-on Happy Valley 13 3 GEOLOGICAL DATA 3.1 Mudlog Summary 1170' to 3660' MD (1116.55' to 2844.80' TVD) Drill Rate ft/hr Total Gas (units Maximum Minimum Avera a Maximum Minimum Avera e 281 8 152 576 3 106 Tuffaceous siltstone (1230') =Light gray to yellowish gray some becoming light brownish gray in carbon clay and various hues of all; poor to very poor indurations; sectile to slightly flexible; mushy to tacky; slimy; slightly cohesive slightly adhesive; earthy fracture; sub- blocky to sub-nodular habit; dull earthy to greasy luster; clayey to ashy to over all silty texture; massive gradation of tuffaceous silt and secondary clays; occasional thin coal and carbonaceous shale interbeds. Sand/Sandstone (1310-1440') = Light to very light gray with a slight yellowish secondary hue; soft to slightly firm in the upper part of the zone grading to firm with increasing depth; sub-rounded tosub-angular very fine upper to fine upper grading to fine lower and medium lower as depth increases; primarily clear to translucent white and smokey quartz/volcanics; . trace to common angular orange jasper/volcanics in the lower section; overall very ashy above grading to slightly ashy with depth; matrix supported in off-white to slightly yellowish white ash/clay; no visible porosity; matrix is very hydrophilic and easily washes away in water; grades to associated tuffaceous siltstone; non to very slightly calcareous. Tuffaceous siltstone/Claystone (1440-1500') = Light to very light gray with a slight bluish secondary hue; slightly firm to soft; silty to clayey texture; dull earthy luster with a slight "micro sparkly" appearance due to included mica and very fine volcanic glass shards; moderately massive beds interbedded with and grading into associated sandstones; contains common thin to very thin sandy interbeds; sandy material tends to be worked into clay/silt fragments during circulation and while on shakers; moderately to very hydrophilic; moderately to slightly cohesive; slightly to non-adhesive; abundant micro- fine to fine carbonaceous inclusions; trace micro-thin carbonaceous laminations mottled appearance in part; occasional thin coal and carbonaceous shale intervals; non-calcareous. Sand/Sandstone (1470-1600') = Light to very light gray with a slight yellowish secondary hue; soft to slightly firm sub-rounded to sub-angular; very fine upper to fine upper and medium lower grain; primarily clearto translucentwhite and smokey quartz/volcanics; trace medium grain translucent yellowish white welded volcanic glass masses; trace to common angular elongated orange jasper/volcanics throughout; trace fine carbonaceous grains; no visible porosity; rare fragments display moderate to abundant yellowish white to gray white ash/clay matrix; very hydrophilic; readily disintegrates and washes away in water; occasional thin associated tuffaceous siltstone; non to very slightly calcareous. • ~~Q~~ 4 Chevron Happy Valley 13 • Tuffaceous siltstone/Claystone (1500-1710') = Light to very light gray with a slight bluish secondary hue; firm to very firm to soft; clayey to silty texture; dull earthy luster; siltstone has a "micro sparkly" appearance due to included mica and very fine volcanic glass shards; massively bedded; interbedded with occasional thin sandstones; sandy material tends to be worked into clay/silt fragments during circulation and while on shale shakers; moderately to very hydrophilic; moderately to slightly cohesive; slightly to non adhesive; abundant micro fine to fine carbonaceous inclusions; trace micro-thin carbonaceous laminations mottled appearance in part; occasional thin coal and carbonaceous shale intervals; trace thin clean bluish gray clay fragments; non-calcareous. Sand/Sandstone (1600-1800') = Light to very light gray with a slight yellowish secondary hue; soft to slightly firm sub-rounded tosub-angular; common sub-spherical volcanics; very fine upper to fine upper and medium tower grain; primarily clear to translucent white and smokey quartz/volcanics; trace medium grain translucent yellowish white welded volcanic glass masses; trace to common angular elongated orange jasper/volcanics throughout; trace fine carbonaceous grains; no visible porosity; rare fragments display moderate to abundant yellowish white to gray white ash/clay matrix; very hydrophilic; readily disintegrates and washes away in water; occasional thin associated tuffaceous siltstone; non to very slightly calcareous. Tuffaceous siltstone/Claystone (1500-1710') = Light to very light gray with a slight bluish secondary hue; firm to very firm to soft; clayey to silty texture; dull earthy luster; siltstone has a "micro sparkly" appearance due to included mica and very fine volcanic glass shards; massively bedded; interbedded with occasional thin sandstones; sandy material tends to be worked into clay/silt fragments during circulation and while on shale shakers; moderately to very hydrophilic; moderately to slightly cohesive; slightly to non-adhesive; abundant micro fine to fine carbonaceous inclusions; trace micro-thin carbonaceous laminations mottled appearance in part; occasional thin coal and carbonaceous shale intervals; trace thin clean bluish gray clay fragments; non to very slightly calcareous. Sand/Sandstone (1980-2090') =Very light gray to gray white with a slight yellowish secondary hue in part; mottled with light gray in part; firm to very firm to disconsolidated; sandy to slight clayey texture; chalky appearance overall with marked sparkly luster due to mica and volcanic glass; very fine upper to fine lower grain; primarily angular to sub- angular; trace sub-spheroidal medium lower grains; clear to translucent white quart/volcanics predominates; trace very fine mica; trace dark gray to black mafic mineral/lithics; trace to fair visible porosity in part but matrix support predominates; matrix is a very light gray white to yellowish gray ash/clay; trace to common fine white ash trace dark gray to dark gray brown lignitic coal; trace tuffaceous Claystone and tuffaceous siltstone interbeds; very slightly to slightly calcareous; no oil indicators. Tuffaceous siltstone (2080-2130') =Light to very light gray to gray white; mottled gray and white in part; firm to soft; silty to very sandy texture; sandy to micro sparkly luster; very ashy grades to sandstone as described above; common dark gray to black mafic mineral and carbonaceous inclusions; common fine mica inclusions; trace orange jasper/volcanics EPQCH Chev-on Happy Valley 13 sand; commonly contains large amounts of re-worked sand trace coal; trace thin tuffaceous claystone; very slightly calcareous. Coa! (2130-2190) =Black becoming brown black at contacts with silts; firm; resinous luster; matte texture; irregular fractures; small cuttings size composed of various grades of lignitic to sub-bituminous coals; slight visible bleeding gas from clean bituminous coal fragments. Sand (2230) =Very light gray to light gray some pinkish gray hues; clast size ranges from medium lower to fine lower; sub-round; moderate to well developed sphericity; moderate sorting; polished to pitted texture; sub-mature nature; non to very slight siliceous cement; moderate to abundant clay/ash matrix; dominant matrix support; pore filling and loosely attached; composed of predominantly quartz with minor lithic fragments; poor porosity and permeability; no oil shows. Tuffaceous Siltstone (2290-2340) =Light gray to very light gray; poor to moderate induration; sectile; mushy to pasty in parts; tacky to slimy; some stiff; slight to moderate cohesive; slight adhesive; earthy to sub-blocky fracture; sub-blocky habit; dull earthy to greasy luster; silty to ashy texture; massive gradational silts and thin fine grained sands. Sand (2350-2380) =Very light gray; clast size ranges from medium lower to fine lower; sub-rounded to rounded; moderate some well developed sphericity; moderate sorting; polished to pitted textures; sub-mature nature; non to very slight siliceous cement; unconsolidated; moderate silt/ash matrix; loosely attach hydrophilic; both grain and matrix support; composed of quartz and various lithic minor fragments; fair porosity; poor permeability; no show of oil. Tuffaceous Sandstone (2390-2430) = Yellowish gray; clayt size ranges from coarse lower to fine lower; sub-round; moderate developed sphericity; poor sorting; abundant faction medium grains; polished to pitted textures; sub-mature nature; non to slight silic cement; non-calcareous; consolidated to loosely consolidated; moderate ash/silt matrix; pore filling and loosely attached; some as a lithifying agent; both grain and matrix supported; poor to possible fair porosity; poor permeability; no oil show. Coal (2475-2490) =Black to grayish black; firm; resinous to greasy luster; matte texture; general blocky fracture some irregular fractures in smaller cuttings; composed of bituminous coal; slight visible bleedings gas from larger cuttings. Tuffaceous Siltstone (2500-2530) =Light gray; moderate induration; slightly sectile; some stiff; slight to moderate cohesive; non to very slight adhesive; sub-blocky to earthy fracture; sub-blocky habit; dull earthy luster; silty to clay texture; homogeneous silt, grading clays. Tuffaceous Sandstone (2540-2610) =Yellowish gray some salt/pepper with interbedded carbon fines; clast size range medium lower to very fine lower; sub-round; moderate to well developed sphericity; poor sorting; abundant faction: medium to fine grains; polished to pitted texture; sub-mature to immature nature @ 2570'; non to very slight silic cement; dominant silt/ash structured matrix; pore filling; loosely attached; some acting as a lithifying agent; loose consolidation; composed of >90% quartz with various minor lithic fragments; poor porosity and permeability; no show oil indicators. ~I EPOCH-I 6 Chevron Happy Valley 13 Tuffaceous Siltstone (2620-2650) =Light gray to very light gray; moderate induration; sectile; mushy in parts; slimy; overall moderate to stiff; moderate cohesiveness; slight adhesive; blocky to pdc grooved cuttings; sub-blocky habit; dull to moderate earthy luster; silty to clayey texture; gradational silts and clays. Carbonaceous Clay grading to Coal (2660-2720) =Grayish black to dark gray; firm to mushy; sectile in parts; slimy; poor cohesion; slight adhesive; sub-planarfracture and habit; earthy to resinous luster; clayey texture; massive carbon clay with thin laminae of lignitic coal; slight visible gas from carbon clay; overall organic and earthy appearance. Coal (2720-2775) =Grayish black to black; firm becoming mushy in carbon clays; resinous luster overall; matte texture; sub-blocky fracture becoming irregular in smaller cuttings; composed of lignitic coal grading to bituminous; carbonaceous clay and shale at contacts; very slight bleeding gas from larger coal fragments. Tuffaceous Siltstone (2780-2820) =Light gray to very light gray; poor to moderate induration; slightly sectile; mushy; slimy; some becoming stiff in parts; slightly cohesive; slightly adhesive; sub-blocky fracture and habit; dull to moderate earthy luster; silty to clayey texture; massive gradational beds of silt, clay and thin beds of very carbonaceous clayey, shaley and lignitic coals. Tuffaceous Siltstone (2830-2880) =Light gray to very light gray; poor to moderate induration; slightly sectile; mushy to slimy in part; slight to moderate cohesive; non to slight adhesive; sub-blocky fracture and habit; dull to moderate earthy luster; silty to clayey texture; visible pyroclastic relic shards in matrix; thin coal beds scattered throughout zone with very carbonaceous shales at contacts. Tuffaceous Claystone (2890-2940) =Light gray; soft becoming firm; slightly sectile; generally stiff; becoming mushy in parts; slight to moderate cohesive; non adhesive; sub- blocky fracture; sub-blocky habit; dull earthy luster; clayey to silty texture; massive gradational silts and clays; minor sand. Tuffaceous Siltstone (2950-2970) =Light gray; poor induration; slightly sectile; mushy to slimy; some stiff in parts; slightly cohesive to slightly adhesive; sub-blocky habit to fracture; grading to very fine grained sandstone in part becoming detrital with depth; minor carbonaceous laminae. Tuffaceous Claystone (2970-3100') =Light to very light gray green; firm to soft; silty to smooth clayey texture; dull earthy to chalky luster; thin slightly tabular to irregular fragments; thinly bedded/interbedded with associated sands and siltstones; trace thin coals and carbonaceous shales; non to very slightly calcareous. Sand/Sandstone (3030-3090') =Light to very light gray to gray brown; form to soft to disconsolidated; very fine upper fine lower predominates; from 3060 to 3090 fine lower to upper with trace med lower grain crumbly, poorly cemented with fair visible porosity); generally matrix supported in a light to very light gray ash/clay; individual grains are predominantly clear to translucent white quartz/volcanics in the finer fraction; larger grains include smokey quartz and lithics; trace mica, dark gray and black lithics; loose sand ~PQ~~ ~ Chevron Happy Valley 13 commonly worked into clay and siltstone fragments; grades to siltstone; common mottled light gray to very light gray ash/tuff intervals; non to very slightly calcareous; no oil indicators. Coal (3030-3120') =Very dark gray; firm to slightly firm; brittle; shaley to very silty; lignitic; irregular fragments display no conchoidal fracture or other characteristics of a more mature coal; trace to common carbonaceous shale/carbonaceous material; trace very carbonaceous tuffaceous siltstone with abundant brown lignite micro-laminations. Claystone/siltstone (3100-3300') =Medium to light gray to medium brownish gray and occasionally brown; very firm to hard to soft; slightly shaley to silty/sandy texture; gritty to waxy and occasionally chalky luster; irregular angular to tabular fragments predominate with occasional soft irregular lumps; generally coated with loose sand; coarsely fissile in part; some fragments display very thin sub-fissile partings; slightly to very carbonaceous in part; some fragments display common micro-thin carbonaceous laminations and micro-fine carbonaceous inclusions; common carbonaceous shale and coal interbeds; non- calcareous. Sand/Sandstone/Conglomerate (3300-3500') =Medium gray to light gray and gray pebble to cobble conglomerate moderately well rounded tosub-angular clear to translucent quartz/volcanics with about equal amounts of medium to light gray lithic sand locally very abundant light to medium reddish brown quartzite pebble/cobble fragments and fine upper to coarse sand; generally appears at surface as loose sand, primarily worked into or clinging to associated silt and Claystone fragments, or as loosely aggregated clumps in moderately cohesive clay; no visible porosity indicators possible in most samples; common small aggregations of fine upper and medium lower grains m soft, very carbonaceous ashy/silty masses; common to occasionally abundant broadly mottled light to medium gray ash; trace to abundant dark gray to dark gray brown carbonaceous shale and increasingly mature lignitic to sub-bituminous coal; appears to be generally occurring as distinct beds rather than as continuous interbeds; non-calcareous. Tuffaceous Claystone/siltstone (3300-3500') = Medium to light gray to medium brownish gray and occasionally brown; very firm to hard to soft; slightly shaley tosilty/sandy texture; gritty to waxy and occasionally chalky luster; irregular angular to tabular fragments predominate with occasional soft irregular lumps; generally coated with loose sand; coarsely fissile in part; some fragments display very thin sub-fissile partings; slightly to very carbonaceous in part; some fragments display common micro-thin carbonaceous laminations and micro-fine carbonaceous inclusions; common carbonaceous shale and coal interbeds; noncalcareous. Tuffaceous siltstone (3510-3550) =Light gray; moderate induration; some mushy predominantly stiff; moderate cohesiveness; non to slight adhesiveness sub-blocky fracture, sub-blocky habit; moderate earthy luster; silty to clayey texture; massive gradational silts and clays with minor sands; visible pyroclastic relic shards interbedded in the tuffaceous siltstone Tuffaceous siltstone (3560-3600) =Light gray; moderate induration; becoming mushy EPOCH Chevron Happy Valley 13 with depth; slight to moderate cohesive; slight adhesive; sub-blocky fracture and habit; dull earthy luster; silty texture; becoming interbedded with detrital material and having a dirty appearance; mixed with sandstone and carbon fines. 3660' to 7747' MD (2844.80' to 6916.60' TVD) Drill Rate ft/hr Total Gas units) Maximum Minimum Avera a Maximum Minimum Avera e 256.3 5.1 112.1 784 16 97.2 Coal (3680-3690) =black, dark gray to grayish black; soft tosub-fissile in part; irregular to rarely tabular cuttings habit; argillaceous to slightly silty in part; dull tosub-vitreous; pyritic. Sandstone (3690-3750) =light gray to light bluish gray, occasionally yellowish gray; very fine to fine grain, occasionally lower medium grain; sub-angular tosub-rounded; fair sorting with poor to fair sphericity; interval grades from grain supported with fair porosity to entirely tuffaceous matrix supported; often grades from a tuffaceous sand to a sandy tuff; friable; non-calcareous; no hydrocarbon indicators. Tuffaceous Claystone and siltstone (3750 -3780') =light to medium gray with slight bluish hues; dull; soft; stiff to pasty with no definite cuttings habit; air dried samples easily hydrate; occasionally firm with sub-waxy texture; generally smooth, often silty, rarely sandy. Sandstone (3780-3900') =medium gray, occasionally light to medium dark gray; very fine to fine grain with good sorting and moderate to well defined sphericity; becoming more coarse down section; sub-rounded to sub-angular with fair to poor sphericity; generally unconsolidated in sample; often with argillaceous/tuffaceous matrix; predominately quartz with abundant light to dark gray lithic fragments; 3900' sample trending to medium lower grain, and generally more angular; fair to crystalline overgrowth in part; trace coherent fragments with ashy/clayey matrix; trace to fair visible porosity; sample fluoresces dull yellow green due to oil base mud; trace muddy yellow fluorescence in 3960 sample with no change in cut from oil base mud cut; slightly to very slightly calcareous. Coal (3900-3960') = black to very dark gray; firm to hard; brittle in part; angular irregular to blocky fragments; matte to slightly resinous luster; slightly to very silty to clean coaly texture; shaley in part; grades to firm slightly fissile silty carbonaceous shale and dark to medium gray Claystone and tuffaceous siltstone; trace conchoidal fracture and cleat in harder fragments; no pyrite or amber noted. Tuffaceous Claystone/siltstone (3900-3990') =medium to dark gray to gray brown in part; firm to moderately firm; clayey to silty texture; dull earthy to silky luster; some silt fragments show trace mica & volcanic glass inclusions with attendant sucrosic luster; trace carbonaceous inclusions and micro thin laminae; slightly adhesive moderately cohesive; moderately hydrophilic; sandy in part; fragments coated with very fine and fine grain loose sand; slightly calcareous. • EPQC~-I 9 Chevron Happy Valley 13 Tuffaceous siltstone (3990-4200') =medium to light gray; very firm; fragments are irregular angular to moderately eroded by circulation; dull earthy to sucrosic luster; silty to clayey and occasionally sandy texture; slightly to moderately adhesive/cohesive moderately hydrophilic when wet with water; common micro thin carbonaceous laminations; common very fine carbonaceous inclusions; trace very fine mica and volcanic glass shards in part; occasional 1 mm of thinner coals; occurs as thick beds with numerous thinner claystone and sand beds; occasional thin coals; trace light to very light gray ash flakes; very slightly calcareous. Sand/Sandstone (4200-4260') =medium gray; firm; occurs at shaker as medium upper size sand fragments and disaggregated sand; well to moderately well sorted fine lower to very fine moderately rounded to sub-rounded smokey, clear and translucent white quartz/volcanics; trace clastic coal fines; trace dark gray to black mafic mineral/lithics; generally matrix supported; locally partly grain supported; trace visible porosity; matrix is light to medium gray to very light gray ash/clay and silt; grades to and interbedded with thin to moderate tuffaceous clay and siltstone; occasional thin coals; slightly calcareous. Tuffaceous claystone/siltstone (4260-4350') = light to medium gray to medium brownish gray at 4350'; firm to soft to very firm; irregular eroded to angular irregular fragments; dull earthy to silky to silty and occasionally sandy luster; smooth clayey to silty texture; slightly cohesive/adhesive; very hydrophilic/expansive when washed in water; siltstone fraction has a slight micro sparkly luster, common micro thin carbonaceous laminations and common micro fine clastic coal inclusions; occurs as thin to moderate thickness interbedding in apparent gradational contact; trace very thin to thin coals; slightly to moderately calcareous; Tuffaceous claystone/siltstone (4350-4440') =light to medium gray to occasionally medium brownish gray and reddish brown; locally hard to very firm but predominantly firm to moderately irregular eroded to angular irregular and some coarsely fissile fragments; dull earthy to gritty luster; slightly sandy in part; silty/slightly sandy to smooth clayey texture; slightly cohesive/adhesive; moderately to very hydrophilic;/expansive when wet; siltstone has a micro sparkly luster due to fine mica and volcanic inclusions; common micro thin carbonaceous lamina and micro fine carbonaceous inclusions; occurs as thin to moderate thickness interbeds in apparent gradational contact; trace very thin to thin coals; non to very slightly calcareous. Sand/Sandstone (4440-4500') =medium gray pepper with salt at 4470' grading to light gray salt and pepper at 4485'; hard to very hard; well sorted in the finer sands, trace bit ground pebble fragments; generally fine lower to fine upper grain; trace medium lower, medium upper and coarse lower pebble fragments; finer fraction is primarily translucent white to clear and smokey quartz/volcanics; coarser is white quartzite; all supported in white to off white to slightly yellowish ash matrix; trace thin yellowish ash/clay fragments. Tuffaceous claystone/siltstone (4500-4560') =various shades of medium to light gray; dull; very soft; very argillaceous to sandy in part grading from a silty tuff to tuffaceous sand; abundant salt and pepper grains; often with carbonaceous detritus and micro fine carbonaceous laminations; increasing occurrence of light brown to reddish brown, amber lithic fragments; traces of mica, microcrystalline pyrite. EPOCH 1 ° Chevron Happy Valley 13 Tuffaceous Claystone (4560-4650') =generally medium gray, varies light gray to medium dark gray; generally smooth; dull to sub-waxy in part; rarely platy; non to slightly gritty; occasionally carbonaceous grading to an argillaceous coal when darker; when lighter often silty to sandy with abundant clastic and carbonaceous detritus/fragments; dull to sub- sucrosic in part with very fine quartz and mica. Air dried samples easily hydrate and swell. Sand and Tuffaceous Sandstone (4650-4710') = medium to medium dark gray; very fine to fine grain, occasionally lower medium grain; moderate sorting; generally well rounded to sub-rounded with very good sphericity; often sub-rounded to sub-angular with fair to moderate sphericity; occasionally angular, conglomeratic; silty in part; generally argillaceous/tuffaceous matrix; rarely grain supported with no visible porosity; predominately frosted quartz with medium to dark gray lithic fragments; salt and pepper in part; often interbedded with thin smooth tuffaceous claystone; friable; non to slightly calcareous. Tuffaceous siltstone (4710-4770') =medium gray to slightly light olive gray; also medium dark gray; sandy grading to a silty sandstone; very argillaceous/tuffaceous grading to a silty claystone in part; abundant extremely fine to fine grain quartz and light to dark gray/grayish black lithic fragments which are predominately matrix supported; arguably a dirty sandstone except for grain size; very soft; non-calcareous; abundant very fine pale orange, grayish to reddish orange lithic fragments; occasional medium to upper coarse milky white angular quartz with fair to poor sphericity and sharp angular edges. Carbonaceous Shale (4770-4860') =medium dark gray to dark gray; generally earthy, tuffaceous; dull tosub-waxy; generally smooth with very fine layers of organic material; soft to firm, occasionally crumbly with nodular cuttings habit; often grayish black with increasing organic content; dull to matte luster; soft to firm with irregular fracture; waxy to sub-waxy; occasionally sub-platy; often interbedded with very fine grain quartz sand microlaminations. Tuffaceous Claystone/siltstone (4860-4950') =medium dark gray, occasionally light olive gray to pale yellowish brown; claystone often smooth; clean; non-gritty; generally dull to sub-waxy; occasionally sub-sucrosic with extremely fine grain sand; occasional scale-like carbonaceous material; also silty in part, grading towards a tuffaceous siltstone; very fine sandy laminations common with very fine to fine grain milky quartz, medium to medium dark gray lithic fragments; pale yellowish orange to reddish orange fragments common; non-calcareous; soft to slightly firm. Tuffaceous siltstone/Claystone (4950-5070) =medium to medium dark gray; slight brownish secondary hue in part; firm to moderately hard to soft; angularto eroded irregular fragments and soft malleable masses; silty to slightly sandy to smooth clayey texture; micro sparkly to waxy luster; occurs as distinct moderately thick beds in gradational contact; numerous thin carbonaceous shale and occasional thin coal interbeds; trace off white ash; common micro thin carbonaceous lamina; slightly adhesive; very cohesive; very hydrophilic/expansive when wet; trace to common micro thin carbonaceous lamina; trace micro fine clastic coal inclusions; occasional very thin sandy intervals; non to very slightly calcareous. r~ EPO~~ 11 Chevron Happy Valley 13 Sandstone (5000-5150') =medium gray to occasionally gray brown; soft; very silty, very ashy texture; slight gritty texture; very fine lower grain; trace loose grains of fine upper to fine lower, sub-rounded quartz sand; all in light to medium gray silty ash/clay matrix grading to above silt/claystones; occurs at shaker as soft malleable to occasionally slightly firm masses; very slightly calcareous; note trace spherical light yellow white calcium carbonate beads/mud additive. Tuffaceous Siltstone/Claystone (5070-5270') =medium to light gray; slight brownish secondary hue in part; firm to very firm to soft; becomes soft and clayey when wet with water; dull earthy to micro sparkly luster; slightly to moderately cohesive; moderately adhesive; very hydrophilic; expansive when wet; trace micro thin carbonaceous laminations; occasional trace very fine carbonaceous inclusions; grades to very silty ash matrix sandstone as previously described; non to very slightly calcareous. Sandstone (5150-5400') =medium to light gray; slight brownish secondary hue in part; greywacke; firm to moderately firm; moderately sorted; sub-angular to angular to sub- spheroidal; fine upper to medium lower predominates; trace medium upper; individual grains are predominant medium gray lithics; common white, smoke and colorless quartz/volcanics; trace orange jasper/volcanics; all matrix supported in silty ash; rare fragments display fair to trace visible porosity; non to very slightly calcareous. Tuffaceous Siltstone/Claystone (5300-5400') = medium to medium light gray to brownish gray; firm to very firm; angular irregular to slightly eroded fragments; micro sparkly to dull earthy luster; silty to sandy to clayey texture slightly adhesive/cohesive; hydrophilic; expansive in water; common to trace thin and micro thin carbonaceous lamina; common fine and micro fine carbonaceous inclusions; trace to common pale yellow ash; overall mottled appearance in part; trace to very sandy; grading to and interbedded with associated sandstone; trace to common dark gray to gray brown carbonaceous shale; occasional coal interbeds; non to very slightly calcareous; note: trace contamination by fine to coarse sand size spherical calcium carbonate beads. Coal (5400-5520') =black to very dark brownish gray; very firm to hard; brittle; angular to tabular blocky fragments; no mature coal features preserved in samples; slightly to moderately silty to shaley; trace very fine mica and ash; occurs as thin to very thin interbeds. Sandstone (5400-5600') = medium to medium light gray; trace fragments with a brownish or yellowish secondary hue; moderately firm to soft/crumbly; lithic greywacke; medium lower to fine upper and medium upper; sub-angular to sub-round, sub-spheroidal grains; primarily medium to light gray lithic sand with up to 40% mixed milky, smoky and colorless quartz/ volcanics; common mica flakes and ash blebs; primarily matrix supported with locally fair visible porosity; matrix is identical to the associated siltstone suggesting gradational contact; matrix is very hydrophilic and easily lost in water washing; non to occasionally very slight calcareous; note: locally abundant yellow white spheroidal calcium carbonate beads. EPOCx 12 Chevron Happy Valley 13 Tuffaceous Siltstone/Claystone (5500-5600') =medium to medium light gray; trace brownish gray; lithic greywacke; firm to moderately firm; silty to sandy grading to tuffaceous Claystone; Claystone becoming increasingly rare through this interval; very ashy in part; occurs as distinct moderate thick beds and as interbeds within the associated sandstone trace to occasionally common micro-thin carbonaceous lamina and very fine carbonaceous inclusions; trace to abundant and micro fine and very fine mica and volcanic glass shards impart a micro sparkly luster; slightly to very slightly calcareous; Coal (5650-5700') =very dark gray to black to very dark brownish gray; firm to very firm; brittle; hackly; very silty to occasionally clean coal; thin angular irregular slightly fissile fragments; trace very fine mica flakes; trace pyrite Tuffaceous Claystone (5700-5790') =varying shades of medium bluish gray to medium dark gray; expansive with poor adhesion and cohesion; generally soft to moderately firm in part; dull to sub-waxy when smooth; irregular cuttings habit often scalloped from pdc bit; generally smooth; non to slightly gritty; often with very fine carbonaceous scaly laminae; grading to a carbonaceous shale in part; also gritty; silty; often with random clastic and organic detritus; very thin alternating sand lenses common with very fine well rounded to sub-angular quartz, yellow orange to red orange lithic fragments; non-calcareous; air dried samples readily hydrate and swell. Tuffaceous Sandstone (5790-5880') = light to medium dark gray; bimodal; extremely fine to fine rounded grains with very good sphericity; also very fine to fine sub-angular to sub- rounded, occasionally angular grains with fair to moderate sphericity; poorly sorted; predominately medium gray and medium light gray lithic fragments with minor milky, frosted quartz; argillaceous to tuffaceous; very slightly silty in part; occasionally grain supported in very fine lenticular alternating layers; slightly calcareous to calcareous; occasionally somewhat more coarse, angular grains with a very light pale yellowish brown to yellowish gray brown ashy matrix; poorly consolidated; soft; no visible porosity. Tuffaceous Claystone (5880-5970') =medium light to medium dark gray; generally expansive with poor cohesion and adhesion; firm; dull to earthy in part; also moderately firm with sub waxy texture; blocky; irregular to scalloped cuttings habit from pdc bit; occasionally hackly when grading towards a carbonaceous shale/argillaceous coal; silty in part; very thin alternating sand lenses common with very fine to fine grain quartz and medium gray lithic fragments; often with carbonaceous detritus; scaly organic inclusions and very thin extensive carbon laminae common; generally non-calcareous; air dried samples hydrate and swell easily. Coal/Carbonaceous Shale (5970-6030') =dark gray to grayish black; brownish black in part; often earthy; silty to tuffaceous in part; predominately black with matte luster; wedge- like to occasionally tabular cuttings habit; hackly to splintery fracture; soft; brittle; out- gassing bubbles common; occasionally interbedded with very fine grain quartz sand and silt; often gradational to carbonaceous shale/ argillaceous coal. ~ EPOCH 13 Chevron Happy Valley 13 Claystone (6030-6100') =medium to medium dark gray, also brownish gray to dark yellowish brown; generally smooth, non-abrasive; dull to sub-waxy with irregular to scalloped shaped cuttings; commonly grades to a carbonaceous shale and argillaceous siltstone with abundant micro fine sand and silt lenses; scaly to very fine wedge-like organic detritus common. Tuffaceous siltstone/Claystone (6100-6200') = medium to medium dark and light gray; firm to moderately firm; irregular angular to sub tabular cuttings habit; trace to common fine to very fine grain matrix supported sandstone with trace visible porosity; local traces of bit broken light yellowish gray chert pebble fragments; trace to abundant thin hackly coal and very silty lignite; coal is slightly sandy in part and contains abundant very fine mica and pyrite; common carbonaceous shale interbeds; micro sparkly to dull earthy luster; silty to clayey to slightly sandy texture; very hydrophilic; expansive in water; moderately cohesive slightly adhesive; common to abundant fine to micro fine mica and volcanic glass shards; trace to common micro thin carbonaceous lamination trace micro fine carbonaceous inclusions; very slightly calcareous. Note: contaminated with calcium carbonate beads. Sandstone (6150-6330') =medium gray; trace fragments show brown to yellow secondary hues; soft; crumbly; silty to sandy texture; poorly sorted overall; moderately sorted in the sand range; medium lower to fine upper and medium upper; angular tosub-angular dark to medium gray lithics predominate; fine lower to very fine upper become common from 6300 to 6330' with increasing quartz greywacke; trace to common milky to smokey quartz/volcanics; trace to abundant fine to medium grain partially decomposed mica; matrix supported in very ashy silt/clay similar to the associated silt/claystones; trace to occasionally fair visible porosity; interbedded with and in gradational contact with associated clay/siltstones; occasional thin coaly interbeds; generally very slightly calcareous; trace fragments very calcareous. Sandstone (6200-6450') =medium to light gray; slight yellowish to brownish secondary hue in part; trace yellowish gray; overall mottled appearance; soft friable to firm; poorly sorted overall; angular flattened lenticular to sub-rounded and sub-spherical grains; medium lower to fine lower soft gray lithic grains predominate; common clear, smokey and milky quartz/volcanics; common mica flakes; generally matrix supported in light to medium gray to very light gray ash/silt/clay; trace visible porosity; trace very fine grain moderately hard sandstone with fair visible porosity; occurs as thin interbeds within the associated siltstone/ Claystone; occasional thin coaly intervals; trace off white calcareous tuff; generally slightly calcareous. Note: contamination by calcium carbonate beads continues. Coal (6200-6450') =black to very dark gray brown; very firm to firm; hackly; slightly to moderately silty; slightly fissile/shaley; lignitic to trace sub-bituminous; trace poorly developed conchoidal and cleat on harder fragments; trace pyrite on bedding; trace to common very fine mica inclusions; grades to carbonaceous shale. ~ EPOCH 14 [hevron Happy Valley 13 Tuffaceous Siltstone/Claystone (6500-6700') = medium to light to dark gray; firm to very firm to soft; micro sparkly luster predominates; claystone tends more dull earthy, slightly more fissile and shaley than previous samples; silty to sandy to clayey texture; slightly to moderately cohesive/adhesive when water wet; hydrophilic; expansive in water; very ashy in part; common very thin yellowish white to brownish white ash lamina; common micro thin carbonaceous lamina; trace fine to very fine and some larger carbonaceous inclusions; trace to common very thin coal lamina and interbeds; grades to associated sand very slightly to slightly calcareous; trace calcareous tuff. Coal (6530-6700') =black to very dark gray; hard to very firm to firm; hackly in part; angular tabular to blocky fragments becoming more common; sub-bituminous to lignitic; trace poorly developed conchoidal fracture on harder fragments; silty to slightly sandy in part; trace to common very fine mica inclusions; grades to carbonaceous shale. Sandstone (6450'6720') =light to medium gray to yellowish gray; mottled; soft friable to firm; becoming distinctly more ashy and is alternating locally between medium to fine grain ashy lithic dominated sand as previously seen and fine lower to very fine lower grain sub- rounded to sub-spheroidal clear to smokey and translucent white quartz/ volcanics; generally matrix supported; finer grain material displays some fragments with apparent grain support and fair visible porosity; common off white to yellowish gray hard volcanic ash/tuff laminae, blebs and interbeds; closely bedded/interbedded and grading to associated siltstones/claystones; occasional traces fine white calcareous tuff; generally very slightly calc. Sandstone/Tuffaceous Sandstone (6720-6840') = light to medium gray to light yellowish gray and gray brown; mottled; slightly firm to firm; generally medium lower to medium upper grain; becoming more predominantly translucent white, smokey and colorless quartz/volcanics; trace mica flakes, dark gray to black mafic mineral/lithics; very ashy matrix; dirty ashy salt and pepper appearance; matrix is very hydrophilic and easily washes away in water Coal/Carbonaceous Shale (6810-6870') =light brownish black to grayish black; dull; earthy; firm yet brittle; crumbly in part; planar to occasionally sub-fissile; hackly to slightly tabular cuttings habit; generally tuffaceous/ argillaceous to slightly silty in part; grades to a dark brownish black to black coal; matte to sub-vitreous; silty in part; often smooth; generally hackly with occasional birds eye fracture; wedge-like to fissile common; often pyritic; out-gassing continues after several hours at room temperature. Sand and Tuffaceous Sandstone (6870-6930') = light to medium light gray to olive gray; occasionally pale yellowish brown; bimodal extremely fine to fine well rounded grains; a siltstone in part but often grain supported; earthy to argillaceous common; also fine to medium grain; sub-rounded to angular in part with poor to occasionally fair sphericity; samples generally unconsolidated but often appear with tuffaceous matrix; coarse multi- mineral salt and pepper grains common; frosted white to light gray; trace chlorite; often interbedded with light pale yellowish brown carbonaceous tuff. ~ POCK 15 [hevron Happy Valley 13 Tuffaceous Siltstone/Sandstone (6930-7030') =brownish yellowish gray to light pale yellowish brown; very soft to slightly firm; very earthy; varies from tuffaceous to sandy; slightly gritty to very abrasive with very fine to lower medium quartz and volcanic fragments; occasionally with very well rounded to angular quartz; commonly seen with varve-like alternating layers of sandy and smooth argillaceous material; occasional carbonaceous detritus; non-calcareous. Claystone (7030-7120') =dark yellowish gray to light olive gray, very light to light gray, often medium to medium dark gray; interval varies from ashy, smooth, non-gritty; mushy to slightly firm with scalloped cuttings habit; dull to sub-waxy; also earthy, silty, gritty to abrasive, irregular cuttings; often with very thin interbedded sandy lenses with very fine to fine sub-rounded to sub-angular quartz and carbonaceous detrital fragments; also gray black to black, grading to a carbonaceous shale; dull to matte, rarely greasy with increasing carbon content; blocky tosub-waxy; non-calcareous; becoming somewhat lighter colored, cleaner, more ashy content down section. Tuffaceous Sandstone (7120-7230') light pale yellowish brown to light olive gray to brownish medium gray; generally fine grain; often upper fine to lower medium grain; sub- rounded to sub-angular with poor to marginal sphericity; rarely well rounded; occasionally angular; poorly sorted with frosted to milky quartz; light to dark gray, grayish green, dark greenish gray, dark yellowish orange clastic fragments and dark brownish black carbonaceous detritus; generally supported with waxy argillaceous/tuffaceous to ashy matrix; slightly silty in part; rarely grain supported with no visible porosity due to variety of grain shapes and sorting; often interbedded with thin layers of very pale orange to yellowish gray ash; non to slightly calcareous. Tuffaceous Claystone & Siltstone (7230-7320') =medium to medium light gray; very smooth; non-abrasive; firm to waxy in part; hydrofissle; occasionally slightly carbonaceous; also pale yellowish brown to light brownish gray very earthy; silty to sandy in part; with abundant very fine alternating sand lenses. Interval became sandier down section, becoming a very silty and tuffaceous sandstone. Occasional very thinly interbedded black to dark grayish black coal. Carbonaceous Shale & Coal (7320-7400') =black to dark gray; olive black to brown black; matte tosub-vitreous; rarely dull; tabular to hackly; occasionally sub-fissile to fissile; birds eye fracture common on true black samples; trace pyrite; slight out-gassing common; predominately earthy; argillaceous; slightly silty in part; rarely massive; striated surfaces common; interval includes interbedded very fine to fine grain sandstone; sub-rounded; bimodal very good to fair sphericity; generally unconsolidated in sample; often firm/ friable; grain supported with very light gray to light yellowish gray argillaceous matrix; non to slightly calcareous; poor visible porosity. EPOCH 16 Chevrart Happy Valley 13 Tuffaceous Sandstone (7400-7600') light to very light and occasionally medium gray; slight yellowish to brownish secondary hue; mottled appearance; firm to very firm; moderately friable in part; moderately well to well sorted; medium lower to fine upper grading to fine lower and trace very fine upper grain; sub-angular to sub-rounded to rounded clear to translucent white quartz/volcanics predominates; trace to common dark gray toblack maficmineral/ lithic grains; trace mica flakes; abundant thin yellowish white to brownish white mottled ash lenses and blebs; sandstone is primarily matrix supported in off white to yellowish to brownish white ash; local trace to fair visible porosity; trace calcareous tuff in the upper part of the zone becoming common as depth increases; trace to common thin coal and carbonaceous shale interbeds; moderately to very calcareous. Tuffaceous Siltstone (7550-7700') =medium brownish gray to medium gray; very firm to moderately hard; angular irregular cuttings habit; dull earthy to slightly micro sparkly luster; gritty silty texture; common very thin carbonaceous laminations; appears lignitic in part; common micro fine mica flakes; trace very thin coaly laminae; trace dark to medium gray claystone interbeds; trace to common moderately hard very silty sandstone with fair visible porosity; claystone is poorly fissile and grades to carbonaceous shale; occasional thin coal and tuffaceous sandstone interbeds; trace very fine pyrite; very slightly to slightly calcareous. Coal (7600-7747') =black; hard to moderately hard; brittle in part; tabular to blocky cuttings habit; trace to common mature coal character; common small scale conchoidal fracture; trace cleat; hackly in part; thinly bedded/ interbedded within associated tuffaceous sandstones and siltstones; grades to poorly fissile carbonaceous shale; trace very fine mica in hackly/silty material. Tuffaceous Sandstone/Sandstone (7680-7747') =light to medium gray; mottled; all as described above but includes up to 10 % very fine grains; well sorted; porous; brown; silty sandstone; common to abundant calcareous tuff; moderately calcareous. End of sample descriptions at 7747 ft Total Depth. ~1 EPOCH 17 Ch Happy Valley 13 3.2 -Connection Gas Summary 1 unit - 0.05% Methane Equivalent De th Gas over BGG Measured Strokes Bottoms U (feet units) pump strokes ump strokes No Connection Gases were Observed 3.3 Trip/Wiper Gas Summary U ~J 1 Unit = 0.05% Methane Equivalent De th Tri to Gas Downtime feet feet units hours 300 surface 0 12 1170 surface 3 34 run cs 1170 surface 11 drill out cement 3660 shoe 79 9 7747 shoe 348 13.33 3.4 Sampling Program /Sample Dispatch Set Type /Purpose Frequency Interval Dispatched to AOGCC A Washed, spin dried, vials 30' 1170' - 7747' MD Attn: Howard Okland 333 W 7 Avenue Anchora e, AK 99501 Fugro Data Solutions, Inc. 3311 South U.S. Hwy 77 B Washed, spin dried, vials 30' 1170' - 7747' MD P.O. Box 295 Schulenburg, TX 78956 Chevron Stora e Fugro Data Solutions, Inc. 3311 South U.S. Hwy 77 C Unwashed Whirlpak 30' 1170' - 7747' MD P.O. Box 295 Schulenburg, TX 78956 Chevron Stora e 5amp~e trequency may be a~tered according to dri~~ rate constraints and zones or interest. EPOCH 18 Chevron Happy Valley 13 4 DRILLING DATA 4.1 Daily Activity Summary: 12/04/2007: Continue rig up operations. Academy techs working with Epoch tech to tie in remaining sensor leads. Pick up drill pipe and stand back in derrick. Building spud mud. Spud the well and drill to 300'. Circulate and clean the hole. 12/05/07: Finish cleaning the hole and pull out of the hole and pick up new BHA with MWD tools and trip back to bottom. No recorded trip gas at 300'. Commence to drill and slide formation with directional tools to 813'. 12/06/07: Drill and slide from 813' to 1170'. Circulated the hole clean and pulled out of the hole to prepare to run 9 5/8" casing. 12/07/07: Rig up casing tools and run 9 5/8" casing to 1040'. Casing was halted by hitting restriction in the hole. Worked casing with no downward movement. Pump sweep through the restriction, washed down and worked through the tight spots from 1040' to 1070'. Run in the hole with casing to landing point at 1157'. Laid down the circulating head and started to cement the hole. Completed the cement job and rigged down Schlumberger. 12/08/07: Nipple down BOP's and installed the wellhead; test the wellhead to 5000 psi for 30 minutes. Nipple down BOP'S and remove riser. Nipple up BOP'S, install choke, pickup stack and stab stack. Install kill line, bell nipple and riser. Continue to nipple up on BOP's. 12/09/07: Test BOP's (Tested casing shoe to 300 psi for 30 minutes). Attempted to level the rig with no success; adjusted the top drive and installed wind walls on the rig. Picked up 40 stands of drill pipe and racked back. 12/10/07: Finished picking up drill pipe and began making up the BHA. Continued running in the hole. Possum belly packed off with cement. Shut down tripping operations to clean cement out of the lines and trough. Continued to trip in the hole and washed down from 920' to 1085' where cement was tagged. Washed down to 1104' and tagged the float. Begin to drill the float at midnight. 12/11/07: Drilled from 1104' to 1200' and tagged the shoe at 1154'. Circulated bottoms up and conducted a F.I.T. to 360 psi at MW - 14.88 ppg. Cleaned all pits, equipment and flushed all the lines in preparation for oil base mud. 12/12/07: Finished change over for oil base mud. Brought on 395 bbls of weighted mud leftover from Happy Valley #12 and 77 bbl of base mud to achieve an all around MW of 9.3 ppg. Displaced water base mud in the hole with oil base mud; circulate and condition. Started to drill formation and drilled to 2142'. CJ EPOCH 19 Chevron Happy Valley 13 12/13/07: PJSM. Service, test and calibrate rig sensors/transducers while drilling. Conduct BOP drill while drilling. Drill from 2175' to 2270'. Service rig and repair pop off on pump #2 x2. Drill from 2270' to 2575'. Repair blown pop off on pump #2. Drill to 3027'. Clean suction screens and change shaker screens. Drill to 3108', loosing some circulation. Circulate & condition mud adding Barcofiber LCM. Blew pop off on pump #2 while circulating; R&R pump #2. Drill to 3292'. Fight stick/slip. Back ream 30'; set pump output to 490 gpm. Drill to 3591'. 12/14/07: Drilled from 3591/ to 3660' intermediate casing point. Blew nails & pop offs 3 times. Cleaned #2 suction screen. Circulate & condition mud, circulate bottoms up x2 while working pipe. Pull out of hole to 2250'. Problems swabbing and surging; pump out to shoe working tight spots. Circulate & condition mud. Service rig. Pull out of hole to 920'. 12/15/07: Continue pulling out of hole to 186'. Stand back HWDP. Down load and lay down MWD. Make up test joint, remove wear bushing and set test plug. Change out rams to 7"; make up secondary annular valve. Test rams at 250 and 300 psi. Epoch records and charts same. Rig up and prepare to run 7" X 26# casing. Run same to 1141' and break circulation. 12/16/07: Continue running casing from 1141' to 2000' with no displacement or mud returns. Circulate and condition at .5 BPM due to lost returns. Stage up to 3 BPM as • returns slowly increased. Circulate 1.5 bottoms up. Continue running 7" casing to 3643' with no returns. Land hanger. Rig up Schlumberger, test lines. Pump 20 BBL mud push LCM with rig pump. Drop bottom plug and turn overto Schlumberger. Pump 83 BBL 12.5 PPG cement; drop top plug; chase with 138.25 displacement. Plug did not bump. Monitor returns out the annulus at 58 BPH. Blow out all lines, lay down cement head, rig up circ head for well control. Monitor returns from the annulus 3.7 BPH and record 12.33 BBL total returns. Install pack off and test to 5000 psi for 30 minutes. Install wear ring. Move HWDP off driller side and make up bit sub. 12/17/07: Pick up and stand back 4"drill pipe. Build mud volume. Safety stand down as a result of Nabors rig 105 falling blocks incident. Pressure test BOP's at 250 and 300 psi. Epoch records and charts same. Repeat safety stand down for morning tour. 12/18/07: Complete testing BOP's. Pick up LWD BHA and HWDP. Run in hole washing from 3385' to 3558'; tag float; drill cement and shoe. Tag shoe at 3641'. Drill 20' new hole to 3680'. Conduct FIT. 12/19/07: Run FIT at 3643': 780 psi test for 4 minutes. Blow down kill line and drain choke manifold. Drill 6 1/8" hole from 3648' to 4529'. 12/20/07: Drill ahead from 4529' to 5703'. 24 hour average ROP = 48.9 ft/hr. Circulate and condition hole while servicing rig mud pump. ~ EPOCH 20 Chevron Happy Valley 13 12/21/07: Drill ahead from 5703' to 5832'. Service rig top drive. Drill ahead from 5832' to 6894'. 24 hour average ROP = 49.6 ft/hr. 12/22/07: Drill ahead from 6894' to TD of 7747' MD, 6916.59' TVD. Circulate hole clean and condition mud. Wiper trip to shoe, pulling tight at 6775-6786': Wash and ream through section. Continue trip to shoe at 3620'. Circulate and condition. 12/23/07: Circulate and condition at 3620'. Run back in hole to 5360'; circulate and condition. Continue to bottom working tight hole from 7698-7747'. Bottoms up after wiper trip recorded wiper gas readings of 348 and 315 units from 2 zones. Clean hole and check for flow. Pull out of hole to casing shoe. Lay down HWDP to 1519'. 12/24/07: Continue to pull out of hole. Lay down BHA and Inteq tools. 12/25/07: Rig up Schlumberger and conduct wire line logging. Rig down Schlumberger. Rig up and prepare to run 3 %2" casing. 12/26/07: Run 3'/2" casing from 100' to 3642'. Circulate and condition. Continue running casing. Break circulation at 5692'; circulate and condition bottoms up twice. Continue running casing; tagged at 7752'. Circulate and condition while rigging up cement head. Recorded 16 units of gas maximum. 12/27/07: Rig up cement lines and test same. Pump mud push 27 bbls; pump cement 145 bbls; pump 12.5 slurry; flush lines with base oil. Drop dart and pressure test to 3000 psi for 10 minutes. Epoch records and charts this test. Try to set ZXP Packer. Clean out cement stinger and circulate bottoms up. Pressure test annulus to 2500 psi for 30 minutes. Epoch records and charts this test. Rig down cement lines. Circulate bottoms up. Pull out of hole from 3416'. Clean out mud system, lay down BHA; rig up setting tool. 12/28/07: Pick up Baker setting tool. Run in hole. Set 50k on packer. Pressure test annular 500 and 2500 psi. Retest. Circulate and condition hole. Rig up to pressure test down drill pipe. Test at 500 and 3000 psi. Epoch records and charts all tests. Pull out of hole from 3456'. Conduct BOP drill. Pull out of hole laying down HWDP. Run in hole with 39 stands DP on collars. Pull out of hole sideways laying down 2 stands drill pipe. 12/29/07: Lay down 16 stands of drill pipe; drill collars; float sub; Baker tool. Prepare to run 3'h" tubing. Trip in hole to 1413'. Rig up control line and run in hole with control line and tubing. Test control valve to 1000 psi for 10 minutes. Continue tripping in hole. Sting into top of liner; strap in and touched down for space out. Pick up and makeup hanger; lay down 2 joints of tubing and pickup pup joints. Pressure test control line to 3000 psi. Land hangar at 1800 hours. Pressure test hanger seats to 5000 psi for 30 minutes. Rig up to test annular and tubing. 12/30/07: Test annular and tubing. Epoch records and charts same. Epoch Well Services released at 0500 hours. ~I EP~~H 21 Chevron Happy Valley 13 • 4.2 Survey Data • • Measured ft pth Incl. (°) Azim. (°) True Vertical Depth (ft) Northings (ft) Eastings (ft) Vertical Section ft Dogleg Rate (°/100ft) 150 0.18 131.43 150.00 0.16S 0.18E -0.02 0.12 197 0.24 128.86 197.00 0.27S 0.31 E -0.05 0.13 268 0.22 113.61 268.00 0.41 S 0.55E -0.12 0.09 329 1.72 218.19 328.99 1.18S 0.09E 0.73 2.93 391 5.81 228.43 390.84 4.OOS 2.83W 4.79 6.66 451 8.28 224.89 450.39 9.07S 8.16W 12.15 4.18 512 8.62 224.67 510.72 15.44S 14.47W 21.10 0.56 573 10.45 224.99 570.88 22.60S 21.59W 31.20 3.00 635 12.79 227.07 631.60 31.25S 30.60W 43.68 3.83 696 15.24 229.64 690.78 41.04S 41.65W 58.44 4.14 757 17.46 228.41 749.31 52.31 S 54.61 W 75.61 3.68 818 20.05 228.86 807.07 65.27S 69.33W 95.21 4.25 879 23.54 229.24 863.70 80.10S 86.43W 117.85 5.73 939 26.68 228.37 918.02 96.88S 105.58W 143.29 5.27 1004 28.74 225.10 975.57 117.61 S 127.56W 173.51 3.94 1069 31.06 225.75 1031.91 140.34S 150.65W 205.89 3.60 1115 33.65 227.36 1070.77 157.26S 168.53W 230.50 5.93 1209 35.05 227.41 1148.37 193.17S 207.56W 283.54 1.49 1274 38.11 228.40 1200.57 219.12S 236.31 W 322.27 4.79 1337 41.12 228.49 1249.09 245.77S 266.36W 362.42 4.78 1402 43.24 228.82 1297.26 274.60S 299.13W 406.05 3.28 1466 45.57 228.96 1342.98 304.04S 332.87W 450.82 3.64 1530 48.52 228.94 1386.58 334.79S 368.19W 497.63 4.61 1595 51.44 228.53 1428.38 367.63S 405.60W 547.39 4.52 1659 53.76 228.56 1467.25 401.28S 443.70W 598.22 3.63 1724 55.18 227.91 1505.02 436.52S 483.15W 651.10 2.33 1788 55.28 227.02 1541.52 472.06S 521.89W 703.68 1.15 1852 55.21 226.59 1578.00 508.05S 560.23W 756.26 0.56 1917 55.14 226.42 1615.12 544.78S 598.93W 809.69 0.24 1982 55.13 225.73 1652.28 581.77S 637.35W 862.93 0.87 2046 55.09 225.79 1688.89 618.40S 674.96W 915.41 0.10 2111 55.12 225.70 1726.07 655.60S 713.14W 968.70 0.12 2174 55.12 225.54 1762.10 691.75S 750.08W 1020.36 0.21 2238 55.16 225.81 1798.68 728.44S 787.65W 1072.85 0.35 2303 55.16 225.61 1835.81 765.70S 825.84W 1126.18 0.25 2367 55.21 225.87 1872.35 802.37S 863.47W 1178.71 0.34 2431 55.21 226.39 1908.87 838.79S 901.36W 1231.26 0.67 2496 55.22 226.65 1945.95 875.53S 940.09W 1284.63 0.33 2560 53.33 226.71 1983.32 911.17S 977.89W 1336.59 2.95 2625 50.70 226.51 2023.32 946.36S 1015.12W 1387.81 4.05 EPOCH 22 {hevron Happy Valley 13 • r1 LJ Measured Depth ft Incl. ° () Azim. ° () True Vertical Depth (ft) Northings (ft) Eastings (ft) Vertical Section ft Dogleg Rate °/100ft 2689 49.02 226.58 2064.58 980.01 S 1050.63W 1436.73 2.63 2754 47.43 226.53 2107.88 1013.34S 1085.83W 1485.20 2.45 2818 46.25 226.85 2151.66 1045.37S 1119.80W 1531.88 1.88 2883 44.94 227.48 2197.14 1076.94S 1153.85W 1578.31 2.13 2947 43.55 227.98 2242.98 1106.98S 1186.89W 1622.97 2.24 3012 41.85 228.47 2290.75 1136.34S 1219.76W 1667.04 2.66 3076 39.86 228.54 2339.16 1164.08S 1251.11 W 1708.89 3.11 3140 37.35 228.42 2389.17 1190.55S 1281.01 W 1748.81 3.92 3204 34.96 228.31 2440.84 1215.63S 1309.23W 1786.56 3.74 3269 32.00 227.76 2495.05 1239.60S 1335.89W 1822.41 4.58 3333 29.70 227.53 2549.99 1261.71 S 1360.14W 1855.23 3.60 3398 27.93 226.72 2606.94 1283.02S 1383.11 W 1886.56 2.79 3462 26.39 227.04 2663.88 1302.99S 1404.43W 1915.77 2.42 3527 24.84 227.31 2722.49 1322.09S 1425.04W 1943.87 2.39 3590 23.07 228.33 2780.06 1339.27S 1443.98W 1969.44 2.89 3625 22.25 228.55 2812.36 1348.22S 1454.07W 1982.93 2.36 3648 22.20 228.34 2833.65 1353.99S 1460.58W 1991.62 0.41 3712 19.92 224.86 2893.37 1369.75S 1477.31 W 2014.61 4.06 3777 16.71 225.26 2955.07 1384.19S 1491.76W 2035.02 4.94 3841 14.54 229.32 3016.71 1395.90S 1504.39W 2052.24 3.79 3905 12.94 234.19 3078.88 1405.33S 1516.30W 2067.39 3.08 3970 10.68 235.66 3142.50 1412.99S 1527.17W 2080.57 3.51 4034 8.20 226.71 3205.63 1419.46S 1535.39W 2091.01 4.49 4098 5.82 216.52 3269.15 1425.20S 1540.65W 2098.76 4.18 4162 4.79 220.78 3332.87 1429.83S 1544.33W 2104.60 1.72 4227 3.53 230.59 3397.70 1433.16S 1547.64W 2109.30 2.22 4291 1.81 250.45 3461.63 1434.75S 1550.12W 2112.19 3.01 4355 2.47 204.04 3525.59 1436.35S 1551.63W 2114.39 2.80 4420 1.65 205.55 3590.55 1438.47S 1552.61 W 2116.55 1.26 4484 0.74 202.89 3654.53 1439.68S 1553.17W 2117.78 1.42 4550 0.53 351.96 3720.53 1439.77S 1553.37W 2117.99 1.86 4612 0.63 354.43 3782.53 1439.15S 1553.45W 2117.62 0.17 4678 0.62 357.86 3848.52 1438.43S 1553.50W 2117.17 0.06 4742 0.34 59.89 3912.52 1437.99S 1553.34W 2116.76 0.86 4806 0.44 94.10 3976.52 1437.91 S 1552.94W 2116.41 0.39 4870 0.50 67.25 4040.52 1437.82S 1552.43W 2115.98 0.35 4935 0.62 60.73 4105.51 1437.54S 1551.86W 2115.37 0.21 4997 0.80 47.98 4167.51 1437.09S 1551.25W 2114.61 0.38 5058 0.39 38.23 4228.51 1436.64S 1550.81 W 2113.98 0.69 5127 0.07 273.63 4297.51 1436.45S 1550.70W 2113.78 0.63 5193 0.24 42.38 4363.51 1436.35S 1550.65W 2113.67 0.44 5256 0.21 62.79 4426.50 1436.20S 1550.46W 2113.42 0.13 ~I EPOCH 23 Chevron Happy Valley 13 • • LJ Measured Depth ft) Incl. ° () Azim. ° () True Vertical Depth (ft) Northings 0.58(ft) Eastings (ft) Vertical Section ft Dogleg Rate (°/100ft 5320 0.36 64.82 4490.50 1436.06S 1550.17W 2113.12 0.23 5384 0.62 78.10 4554.50 1435.90S 1549.65W 2112.63 0.44 5450 0.44 69.45 4620.50 1435.74S 1549.06W 2112.09 0.30 5509 0.58 76.56 4679.50 1435.59S 1548.56W 2111.62 0.26 5578 0.65 72.39 4748.49 1435.39S 1547.85W 2110.96 0.12 5643 0.91 76.32 4813.49 1435.15S 1547.OOW 2110.17 0.41 5707 1.05 66.97 4877.48 1434.81 S 1545.96W 2109.18 0.33 5767 0.76 136.98 4937.47 1434.88S 1545.18W 2108.66 1.78 5836 1.37 194.59 5006.46 1436.01 S 1545.08W 2109.35 1.68 5901 1.20 206.26 5071.44 1437.38S 1545.58W 2110.64 0.48 5965 1.23 221.01 5135.43 1438.50S 1546.32W 2111.95 0.49 6029 1.39 223.73 5199.41 1439.57S 1547.31 W 2113.40 0.27 6093 1.51 237.88 5263.39 1440.58S 1548.56W 2115.01 0.59 6158 1.82 251.51 5328.37 1441.37S 1550.27W 2116.79 0.77 6222 2.07 260.78 5392.33 1441.87S 1552.37W 2118.68 0.63 6286 1.87 264.98 5456.29 1442.15S 1554.55W 2120.47 0.39 6351 2.15 276.30 5521.25 1442.11 S 1556.82W 2122.11 0.75 6415 1.75 283.45 5585.21 1441.75S 1558.96W 2123.44 0.73 6480 1.57 303:11 5650.19 1441.03S 1560.68W 2124.21 0.91 6543 1.92 318.36 5713.16 1439.77S 1562.10W 2124.41 0.92 6608 2.29 326.70 5778.11 1437.87S 1563.54W 2124.17 0.74 6672 2.64 331.14 5842.05 1435.51 S 1564.95W 2123.61 0.62 6737 2.77 340.59 5906.98 1432.72S 1566.19W 2122.63 0.71 6802 1.80 354.07 5971.93 1430.23S 1566.82W 2121.40 1.70 6866 1.45 14.00 6035.91 1428.44S 1566.73W 2120.12 1.03 6930 1.52 19.02 6099.88 1426.85S 1566.26W 2118.70 0.23 6995 1.35 21.84 6164.86 1425.33S 1565.69W 2117.25 0.28 7059 1.39 25.81 6228.85 1423.93S 1565.07W 2115.85 0.16 7124 1.35 26.04 6293.83 1422.53S 1564.39W 2114.40 0.06 7188 1.48 29.29 6357.81 1421.14S 1563.65W 2112.91 0.25 7252 1.43 28.44 6421.79 1419.72S 1562.86W 2111.36 0.10 7317 1.36 30.08 6486.77 1418.34S 1562.08W 2109.86 0.12 7381 1.27 25.80 6550.75 1417.04S 1561.39W 2108.47 0.21 7445 1.27 24.83 6614.73 1415.76S 1560.79W 2107.16 0.03 7509 1.53 28.10 6678.72 1414.36S 1560.09W 2105.69 0.42 7573 1.94 23.18 6742.69 1412.61 S 1559.26W 2103.90 0.68 7637 2.12 29.89 6806.65 1410.59S 1558.24W 2101.78 0.47 7670 2.10 32.12 6839.62 1409.55S 1557.62W 2100.61 0.26 7747 2.10 32.12 6916.57 1407.12S 1556.11 W 2097.86 0.00 EPOCH 24 C ~ Happy Valley 13 4.3 Bit Record Bit Make Type / S# Jets / TFA Depth MD(ft) Total Footage Bit Hrs Avg. RO (ftlh r) WOB (Klbs) ROT RPM PP (psi) Wear I,O,D,L,B,G,O Reason 1 2 1/4" Hole 1 HCC MXL-1/ 3x14, 10 100/300 200 87 2.1 75 721 1,1,WT,A,E,I,NO BHA RR1 HCC MXL-1/ 3x14, 10 300/1170 870 12:43 130 5.1 (slide) 1534 1,1,WT,A,E,I,NO Casing 8 1/2" Hol e 2 SEC FM 2465 6X12 1170/3660 2490 20:22 152 7.6 157 2014 O,O,ER,X,A,I,SD Casing 6 1/8" Hol e 3 SEC DBS 3-14, 10 3660/7747 4087 45:59 112 3.8 54.7 2357 0,1,WT,S,I,CT TD ~ EPC)CH 25 C n Happy Valley 13 4.4 Mud Record Contractor: BAROID Date Depth MW In/ Out V1S s/ t PV YP Gels FL (cc FC Sols % NAP/W Ratio Sd % MBT pH CI ml/I Ca ml/I S ud Mud -12'/4" Section 12/04/07 259 9.0 9.0 78 28 39 22/24/25 7.8 2/- 5.2 -/94.5 - 22.5 9.9 700 - 12/05/07 675 8.9 8.9 80 25 40 18/23/26 7.2 2/- 3.7 -/96.0 1.0 20.0 9.4 800 - 12/06/07 1170 8.9+ 8.9+ 100 28 47 21/30/36 6.8 2/- 4.7 -/95.1 1.0 17.5 9.1 500 20 12/07/07 1170 9.0 9.0 55 21 20 8/10/12 6.8 2/- 5.1 -/94.7 0.5 17.5 8.9 450 40 12/08/07 1170 9.0+ 9.0+ 50 19 12 6/8/10 6.8 2!- 5.5 -/94.3 0.25 15.0 8.9 500 20 12/09/07 1170 9.1 9.1 58 22 23 9/13/20 7.4 2/- 5.7 -/94.0 0.25 17.5 8.5 700 - 12/10/07 1170 9.0 9.0 46 16 17 6/8/10 8.0 2/- 5.2 -/94.6 0.25 15.0 9.5 500 80 Date Depth MW FLT °F VIS s/ t PV YP Gels HTHP FC Sols % NAP/W Ratio Sd % Alk Ag/ NO3 CaC12 Lime Invermul Oil Base Mud - 8 1 /2 "Section 12/11 /07 1200 -- -- -- -- -- -- -- -- -- -- -- 12/12/07 2005 9.25 110 93 29 21 19/29/31 5.0 -/3 6.4 84.8/15.2 0.25 5.5 1.35 13.06 7.12 12/13/07 3600 9.3 115 94 34 24 21/32/33 4.0 -/4 8.7 76.0/14.0 0.10 5.7 1.20 14.03 7.38 12/14/07 3660 9.4 -- 110 32 23 19/24/25 4.2 -/4 9.5 75.0/14.0 0.10 5.4 1.30 13.06 6.99 12/15/07 3660 9.35 -- 132 29 16 15/23/24 4.3 -/4 8.4 76.0/14.0 0.10 5.6 1.30 12.57 7.25 12/16/07 3660 9.2 -- 110 21 12 9/20/24 5.0 -/4 8.7 79.0/11.0 -- 5.2 1.00 6.26 6.73 12/17/07 3660 9.2 -- 87 25 10 9/19/21 5.8 -/4 6.7 81.5/10.5 -- 4.6 1.10 9.18 5.96 Invermul Oil Base Mud - 6 1 /8 "Section 12/18/07 3675 9.2 80 85 23 12 11/18/20 4.8 -/4 6.7 81.5/10.5 -- 5.4 1.00 8.21 6.99 12/19/07 4500 9.2 85 70 22 9 8/16/18 4.8 -/4 7.8 80.5/10.5 -- 8.4 1.00 9.18 10.88 12/20/07 5700 9.3 81 70 22 9 9/16/18 5.6 -/4 7.9 87.9/12.1 -- $.$ 1.00 12.09 11.4 12/21 /07 6290 9.2 105 71 24 12 11 /19/20 5.2 -/4 7.6 87.9/12.1 -- 8.7 1.20 11.12 11.27 12/22/07 7747 9.2 100 69 23 11 9/18/20 4.6 -/4 7.8 81.0/10.0 -- 7.0 1.1 10.63 9.07 12/23/07 7747 9.25 80 75 23 12 9/18/20 4.5 -/4 7.8 81.0/10.0 -- 6.8 1.1 10.15 8.81 12/24/07 7747 9.3 70 85 23 12 9/18/20 4.2 -/4 8.3 80.5/10.0 -- 6.1 1.1 10.44 7.9 12/25/07 7747 9.3 70 85 23 12 9/18/20 4.2 -/4 8.3 80.5/10.0 -- 6.1 1.0 10.15 7.9 12/26/07 7747 9.35 60 131 25 11 10/18/19 4.2 -/4 7.7 89.0/11.0 -- 6.3 1.1 11.12 8.16 12/27/07 7747 -- -- -- -- -- -- 12/28/07 7747 -- -- -- -- -- -- -- -- -- -- - - Abbreviations MW =Mud Weight Gels =Gel Strength Sand =Sand content WL = Water or Filtrate Loss CI =Chlorides VIS =Funnel Viscosity Ca =Hardness Calcium PV =Plastic Viscosity Sols =Solids YP =Yield Point EP©cH ECD =Effective Circulating Density FC =Filter Cake OTHERWISE =Oil to Water ratio 26 CHEVRON USA DAILY WELLSITE REPORT ~~0~~ HAPPY VALLEY #13 REPORT FOR HURT BRADFORD DATE Dec O5, 2007 DEPTH 300.00000 PRESENT OPERATION CIRC @ 300' TIME MIDNIGHT YESTERDAY 100.00000 24 HOUR FOOTAGE 200' CASING INFORMATION 16" @ 117' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 300' 300' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HCC MXl-1 5117406 3X14, 1X10 100 300 200' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 457.4 @ 116.00000 7.6 @ 240.00000 86.1 62.45600 FT/HR SURFACE TORQUE 10067 @ 251.00000 294 @ 254.00000 3969.2 4566.00000 AMPS WEIGHT ON BIT 16 @ 103.00000 0 @ 269.00000 2.1 0.00000 KLBS ROTARY RPM 107 @ 239.00000 52 @ 183.00000 74.2 94.00000 RPM PUMP PRESSURE 954 @ 292.00000 472 @ 145.00000 717.7 938.00000 PSI DRILLING MUD REPORT DEPTH 259' MW 9.0 VIS 78 PV 28 YP 39 FL 7.8 Gels 22/24/25 CL- 700 FC 2/- SOL 5.2 SD - OIL - MBL 22.5 pH 9.9 Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 122.00000 0 @ 299.00000 0.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 300.00000 0 @ 300.00000 0.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 300.00000 0 @ 300.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 300.00000 0 @ 300.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 300.00000 0 @ 300.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 300.00000 0 @ 300.00000 0.0 RBON SHOWS NO SHOWS / NO RECORDED GAS FROM 100' TO 300' I L LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLE COLLECTION COMMENCING UNDER SURFACE CASING PRESENT LITHOLOGV DAILY ACTIVITY SUMMARY RIG UP AND SPUD WELL, DRILL TO 300' AND CIRCULATE THE HOLE CLEAN EPOCH PERSONNEL ON BOARD BROWNE, BLEYS DAILY COST $2975 REPORT BY LEES F. BROWNE JR. • CHEVRON USA DAILY WELLSITE REPORT ~1 V ~ HAPPY VALLEY #13 V REPORT FOR HURT BRADFORD DATE Dec O6, 2007 DEPTH 813.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 301.00000 24 HOUR FOOTAGE 512' CASING INFORMATION 16" @ 117' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HCC MXL-1 517406 3X14 1X10 100' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 311.3 @ 313.00000 13.1 @ 440.00000 148.3 193.95506 FT/HR SURFACE TORQUE 6082 @ 755.00000 25 @ 669.00000 1054.9 0.00000 AMPS WEIGHT ON BIT t0 @ 779.00000 0 @ 449.00000 4.0 6.74091 KLBS ROTARY RPM 56 @ 515.00000 43 @ 699.00000 14.2 0.00000 RPM PUMP PRESSURE 1700 @ 795.00000 1086 @ 355.00000 1456.5 1628.00000 PSI DRILLING MUD REPORT DEPTH 675' MW 8.9 VIS SO PV 25 YP 40 FL 7.2 Gels 18/23/26 CL- 800 FC 2/- SOL 3.7 SD 1.0 OIL - MBL 20.0 pH 9.4 Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 19 @ 656.00000 0 @ 567.00000 4.4 TRIP GAS 0 @ 300' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6013 @ 796.00000 48 @ 567.00000 979.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 813.00000 0 @ 813.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 813.00000 0 @ 813.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 813.00000 0 @ 813.00000 0.0 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 0 @ 813.00000 0 @ 813.00000 0.0 HY CARBON SHOWS NO SHOWS THE LAST 24 HOURS I L LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLES COMMENCE UNDER SURFACE CASING PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY FINISH CIRCULATING THE HOLE CLEAN AT 300' AND PULL OUT OF THE HOLE, PICKUP NEW BHA AND RUN BACK TO BOTTOM, NO RECORDED TRIP GAS, DRILL AND SLIDE AHEAD. EPOCH PERSONNEL ON BOARD BROWNE, BLEYS DAILY COST $3175 MUD LOGGING $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • CHEVRON USA DAILY WELLSITE REPORT El O~~ HAPPY VALLEY #13 REPORT FOR HURT BRADFORD DATE Dec O6, 2007 DEPTH 1170.00000 PRESENT OPERATION PREP TO RUN 9 5/8" CASING TIME MIDNIGHT YESTERDAY 813.00000 24 HOUR FOOTAGE 357' CASING INFORMATION 16" @ 117' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1170' 1116.55 SURVEY DATA 1115 33.65 227.36 1070.77 1004 28.74 225.10 975.58 879 23.54 229.24 863.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HCC MXL-1 517406 3X141X10 100 1170 1070 12.43 NA TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 271.6 @ 827.00000 1.9 @ 834.00000 105.0 47.56600 FT/HR SURFACE TOROUE 7320 @ 1165.00000 37 @ 1117.00000 1702.9 0.00000 AMPS WEIGHT ON BIT 10 @ 907.00000 0 @ 874.00000 6.9 4.03100 KLBS ROTARY RPM 51 @ 817.00000 42 @ 874.00000 17.3 0.00000 RPM PUMP PRESSURE 1886 @ 1063.00000 1417 @ 1114.00000 1651.1 0.00000 PSI DRILLING MUD REPORT DEPTH 1170' MW 8.9+ VIS 100 PV 28 YP 47 FL 6.8 Gels 21/30/36 CL- 500 FC 2/- SOL 4.7 SD 1.00 OIL - MBL 17.5 pH 9.1 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 37 @ 922.00000 0 @ 934.00000 11.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7515 @ 923.00000 194 @ 835.00000 2257.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1170.00000 0 @ 1170.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 1170.00000 0 @ 1170.00000 0.0 CURRENT 0 (C-4) 0 @ 1170.00000 0 @ 1170.00000 0.0 CURRENT BACKGROUND/AVG 0 (C-5) 0 @ 1170.00000 0 @ 1170.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLES COMMENCE UNDER SURFACE CASING PRESENT LITHOLOGV DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION FROM 813' TO 1170', CIRCULATED THE HOLE CLEAN AND PULLED OUT OF THE HOLE AND PREPARE TO RUN 9 5/8" CASING. EPOCH PERSONNEL ON BOARD BROWNE, BLEYS DAILY COST $3175 MUD LOGGING $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • CHEVRON USA DAILY WELLSITE REPORT ~1 ~~~ HAPPY VALLEY #13 REPORT FOR HURT BRADFORD DATE Dec 08, 2007 DEPTH 1170.00000 PRESENT OPERATION NIPPLE UP BOP TIME MIDNIGHT YESTERDAY 1170.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1170' 1116.55' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/BIC PULLED DRILLING PARAMETERS HIGH lOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1170 MW 9.0 VIS 55 PV 21 YP 20 FL 6.8 Gels 8/10/12 CL- 450 FC 2/- SOL 5.1 SD .50 OIL - MBL 17.5 pH 8.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ TG @ TRIP GAS 3 @ 1170' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKG ROUND/AVG PENTANE (C-5) @ @ HV CARBON SHOWS NO SHOWS THE LAST 24 HOURS I LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLES COMMENCE UNDER SURFACE CASING PRESENT LITHOLOGV WORK CASING WITH NO MOVEMENT DOWN HOLE, MAKE UP SWEDGE TO PUMP THROUGH, WASHED DOWN AND WORKED RIG UP CASING TOOLS AND RUN 9 5/8" CASING TO 1040' AND HIT A BRIDGE DAILY ACTIVITY THROUGH TIGHT SPOTS FROM 1040' TO 1070' RUN , LAY DOWN CIRCULATING IN THE HOLE TO CASING LANDING POINT AT 1157' HEAD AND PICKED UP CEMENT HEAD, START CEMENTING, COMPLETE , SUMMARY CEMENTING AND RIG DOWN SCHLUMBERGER , EPOCH PERSONNEL ON BOARD BROWNE, BLEYS DAILY COST $3175 MUD LOGGING, $725 RIGWATCH REPORT BY LEES F. BROWNE JR. CHEVRON USA DAILY WELLSITE REPORT El'O~H HAPPY VALLEY #13 REPORT FOR HURT BRADFORD DATE Dec 08, 2007 DEPTH 1170.00000 PRESENT OPERATION NIPPLE UP BOP TIME MIDNIGHT YESTERDAY 1170.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1170' 1116.55' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TO ROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1170 MW 9.0 VIS 55 PV 21 YP 20 FL 6.8 Gels 8!10/12 CL- 450 FC 2/- SOL 5.1 SD .50 OIL - MBL 17.5 pH 8.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ TG @ TRIP GAS 3 @ 1170' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ H ARBON SHOWS NO SHOWS THE LAST 24 HOURS I LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLES COMMENCE UNDER SURFACE CASING PRESENT LITHOLOGY DAILV ACTIVITY RIG UP CASING TOOLS AND RUN 9 5/8" CASING 70 1040' AND H!T A BRIDGE, WORK CASING WITH NO MOVEMENT DOWN HOLE, MAKE UP SWEDGE TO PUMP THROUGH, WASHED DOWN AND WORKED SUMMARY THROUGH TIGHT SPOTS FROM 1040' TO 1070', RUN IN THE HOLE TO CASING LANDING POINT AT 1157', LAY DOWN CIRCULATING HEAD AND PICKED UP CEMENT HEAD, START CEMENTING, COMPLETE CEMENTING AND RIG DOWN SCHLUMBERGER EPOCH PERSONNEL ON BOARD BROWNE, BLEYS DAILY COST $3175 MUD LOGGING, $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • CHEVRON USA DAILY WELLSITE REPORT ~~ ~~ `!/1 !\l• HAPPY VALLEY #13 . REPORT FOR HURT BRADFORD DATE Dec 09, 2007 DEPTH 1170.00000 PRESENT OPERATION NIPPLE UP BOP TIME MIDNIGHT YESTERDAY 1170.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1170' 1116.55' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1170' MW 9.0+ VIS 50 PV 19 VP 12 FL 6.8 Gels 6/6/10 Cl- 500 FC 2/- SOL 5.5 SD 0.25 OIL - MBL 15.0 pH 8.9 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HY CARBON SHOWS NO DRILLING MUD CIRCULATED THE LAST 24 HOURS I LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGV CEMENT: SAMPLES COMMENCE UNDER SURFACE CASING PRESENT LITHOLOGY DAILY ACTIVITY NIPPLE DOWN BOP'S. INSTALL WELLHEAD AND TEST TO 5000 PSI FOR 30 MINS. NIPPLE DOWN BOP'S AND REMOVE RISER. NIPPLE UP BOP'S, INSTALL CHOKE, PICKUP THE STACK AND STAB BACK. SUMMARY INSTALL KILL LINE, BELL NIPPLE AND RISER. CONTINUE TO NIPPLE UP BOP'S. EPOCH PERSONNEL ON BOARD BROWNE, BLEYS + SAMPLE CATCHERS DAILY COST $3555 w/ SAMPLE CATCHERS, $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • CHEVRON USA DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #13 REPORT FOR HURT BRADFORD DATE Dec 10, 2007 DEPTH 1170.00000 PRESENT OPERATION PICKING UP DRILL PIPE TIME MIDNIGHT YESTERDAY 1170.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1170' 1116.55' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.5" SEC DBS FM2465 FMH-36552 6X12 1170 DRILLING PARAMETERS NIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTIHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1170' MW 9.1 VIS 56 PV 22 YP 23 FL 7.4 Gels 9/13/20 CL- 700 FC 2/- SOL 5.7 SD 0.25 OIL - MBL 17.5 pH 8.5 Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS OR MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 100% CEMENT PRESENT LITHOLOGV SAMPLES COMMENCE UNDER SURFACE CASING DAILY ACTIVITY FINISH NIPPLE UP PROCESS, TEST BOP'S, TESTED CASING SHOE TO 3000 PSI FOR 30 MINUTES, ATTEMPTED TO LEVEL RIG WITH NO SUCCESS, ADJUSTED THE TOP SUMMARY DRIVE, INSTALLED WIND WALLS ON THE RIG. BEGIN TO PICKUP 40 STANDS OF DRILL PIPE. EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2 SC DAILY COST $3555 MUD LOGGING, $725 RIGWATCH REPORT BY LEES F. BROWNE JR. r~II ~I • CHEVRON USA DAILY WELLSITE REPORT ~~ ~~ JV\ HAPPY VALLEY #13 REPORT FOR HURT BRADFORD DATE Dec 11, 2007 DEPTH 1170.00000 PRESENT OPERATION DRILLING CEMENT TIME MIDNIGHT YESTERDAY 1170.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1170' 1116.55' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 3.5" SEC DBS FM2465 FMH-36552 6X12 1170 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH N/A MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 @ DRILL CEMENT 0 @ CEMENT 0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOIOGV/REMARKS GAS DESCRIPTION LITHOLOGV CEMENT PRESENT LITHOLOGY SAMPLES COMMENCE UNDER SURFACE CASING DAILY ACTIVITY SUMMARY FINISH PICKING UP DRILL PIPE, PICKUP BHA #3 AND TRIP INTO THE HOLE, DRILLING OUT CEMENT AT REPORT TIME EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2 SC DAILY COST $$3935 MUD LOGGING, $725 RIGWATCH REPORT BY LEES F. BROWNE JR. ~II ~I CHEVRON USA DAILY WELLSITE REPORT ~~ ~T ' /U~ H HAPPY VALLEY #13 REPORT FOR HURT BRADFORD DATE Dec 11, 2007 DEPTH 1170.00000 PRESENT OPERATION DRILLING CEMENT TIME MIDNIGHT YESTERDAY 1170.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1170' 1116.55' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC DBS FM2465 FMH-36552 6X12 1170 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH N/A MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 @ DRILL CEMENT 0 @ CEMENT 0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CEMENT PRESENT LITHOLOGY SAMPLES COMMENCE UNDER SURFACE CASING DAILY ACTIVITY SUMMARY FINISH PICKING UP DRILL PIPE, PICK UP BHA #3 AND TRIP INTO THE HOLE, DRILLING OUT CEMENT AT REPORT TIME EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2 SC DAILY COST $$3935 MUD LOGGING, $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • I CHEVRON USA DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #13 REPORT FOR BRADFORD HURT DATE Dec 12, 2007 DEPTH 1200.00000 PRESENT OPERATION SWAP OUT TO OIL BASE MUD TIME 03:21:33 YESTERDAY 1170.00000 24 HOUR FOOTAGE 30 CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1200' 1141.52' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC DBS FM 2465 FMH-36552 6X12 1170 00:41 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 66.6 @ 1193.00000 10.9 @ 1182.00000 49.7 50.09532 FT/HR SURFACE TORQUE 6376 @ 1198.00000 3016 @ 1199.00000 4984.4 5199.00000 AMPS WEIGHT ON BIT 6 @ 1195.00000 1 @ 1180.00000 5.2 5.85319 KLBS ROTARY RPM 64 @ 1180.00000 63 @ 1200.00000 65.3 63.00000 RPM PUMP PRESSURE 933 @ 1170.00000 656 @ 1180.00000 924.7 895.00000 PSI DRILLING MUD REPORT DEPTH SWAP TO OBM MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 1170.00000 0 @ 1182.00000 2.4 TRIP GAS 11 @ 1170' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 1150 @ 1170.00000 97 @ 1182.00000 474.9 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 1200.00000 0 @ 1200.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 1200.00000 0 @ 1200.00000 0.0 CURRENT 0 BUTANE (C-0) 0 @ 1200.00000 0 @ 1200.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 1200.00000 0 @ 1200.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAY, COAL PRESENT LITHOLOGV 1200' = 70 % TUFFACEOUS SILTSTONE, 20 % TUFFACEOUS CLAY, 10 % COAL DAILY ACTIVITY DRILL OUT CEMENT, TAG SHOE AT 1154', DRILL FORMATION FROM 1170' TO 1200', CIRCULATE AND CONDITION THE HOLE, PULL OUT OF THE HOLE TWO STANDS TO 1109' SUMMARY WITH NO PROBLEMS AND CIRCULATE BOTTOMS UP, RUN FIT TO 360 PSI MW = 14.88, CLEAN OUT MUD SYSTEM FOR ADDING OF OIL BASE MUD. EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2 SC DAILY COST $3935 MUD LOGGING $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • CHEVRON USA DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #13 REPORT FOR HURT PURUGGANAN DATE Dec 13, 2007 DEPTH 2143.00000 PRESENT OPERATfON DRILLING TIME MIDNIGHT YESTERDAY 1200.00000 24 HOUR FOOTAGE 943' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2046 55.09 225.79 1688.89 1917 55.14 226.42 1615.12 SURVEY DATA 1788 55.28 227.02 1541.52 1659 53.76 228.56 1467.25 1530 48.52 228.94 1386.58 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B!C PULLED 2 8.5" SEC DBS FM2465 FMH-36552 6X12 1170 8:32 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 264.7 @ 1633.00000 9.2 @ 1233.00000 153.0 75.43533 FT/HR SURFACE TORQUE 13022 @ 2024.00000 2918 @ 1410.00000 8200.5 8547.00000 AMPS WEIGHT ON BIT 16 @ 1643.00000 0 @ 1574.00000 7.2 2.73241 KLBS ROTARY RPM 166 @ 1401.00000 63 @ 1200.00000 159.4 160.00000 RPM PUMP PRESSURE 2118 @ 1921.00000 515 @ 1265.00000 1847.7 2037.63867 PSI DRILLING MUD REPORT DEPTH 2005' (oil base mud) MW 9.2+ VIS 93 PV 29 YP 21 FL - Gels 19/29/31 CL- - FC -/3 SOL 6.4 SD 0.25 OIL 78 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 468 @ 2064.00000 1 @ 1200.00000 63.9 TRIP GAS CUTTING GAS @ @ WIPER GAS 0 @ 1200' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 85883 @ 2064.00000 47 @ 1237.00000 10677.0 CONNECTION GAS HIGH 60 ETHANE (C-2) 0 @ 2143.00000 0 @ 2143.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 2143.00000 0 @ 2143.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2143.00000 0 @ 2143.00000 0.0 CURRENT BACKGROUND/AVG 107 PENTANE (C-5) 0 @ 2143.00000 0 @ 2143.00000 0.0 HYDROCARBON SHOWS GAS KICK INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 2030 TO 2105 AND BLEED SANDSTONE, SAND, BEFORE 100 MAX 463 AFTER NO FLOW OR PIT GAINS, CG 60 UNITS DUR ING SHOW, CHALKY VFGR SS, MATRIX SUPPORT, POOR OFF ASH 125 POROSITY C-1 ONLY LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SANDSTONE, SAND, COAL PRESENT LITHOLOGY 2140' = 10% ASH, 40 % TUFFACEOUS SILTSTONE, 20% TUFFACEOUS CLAYSTONE, 20 % SAND, 10 % COAL BROUGHT ON 395 BBLS OF WEIGHTED MUD LEFTOVER FROM HV #12 AND 77 BBLS OF UNWEIGHTED MUD TO ACHIEVE AN FINISHED PREPPING PITS FOR OIL BASE MUD DAILY ACTIVITY AlL AROUND MW OF 9 3 PPG O , DISPLACED WATER BASE M IL BASE MUD SPACER OF 30 BBLS BROUGHT ON UD IN HOLE WITH OIL BASE MUD CIRCULATED AND BEGAN . , SUMMARY DRILLING AHEAD TO 2143' , , EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2 SC DAILY COST $4840 MUD LOGGING $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • CHEVRON USA DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #13 REPORT FOR HURT PURUGGANAN DATE Dec 13, 2007 DEPTH 2143.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 1200.00000 24 HOUR FOOTAGE 943' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2046 55.09 225.79 1688.89 1917 55.14 226.42 1615.12 SURVEY DATA 1788 55.28 227.02 1541.52 1659 53.76 228.56 1467.25 1530 48.52 228.94 1386.58 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC DBS FM2465 FMH-36552 6X12 1170 8:32 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 264.7 @ 1633.00000 9.2 @ 1233.00000 153.0 75.43533 FT/HR SURFACE TORQUE 13022 @ 2024.00000 2918 @ 1410.00000 8200.5 8547.00000 AMPS WEIGHT ON BIT 16 @ 1643.00000 0 @ 1574.00000 7.2 2.73241 KLBS ROTARY RPM 166 @ 1401.00000 63 @ 1200.00000 159.4 160.00000 RPM PUMP PRESSURE 2118 @ 1921.00000 515 @ 1265.00000 1847.7 2037.63867 PSI DRILLING MUD REPORT DEPTH 2005' (oil base mud) MW 9.2+ VIS 93 PV 29 YP 21 FL - Gels 19/29/31 CL- - FC -/3 SOL 6.4 SD 0.25 OIL 78 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 468 @ 2084.00000 1 @ 1200.00000 63.9 TRIP GAS CUTTING GAS @ @ WIPER GAS 0 @ 1200' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 85883 @ 2064.00000 47 @ 1237.00000 10677.0 CONNECTION GAS HIGH 60 ETHANE (C-2) 0 @ 2143.00000 0 @ 2143.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 2143.00000 0 @ 2143.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2143.00000 0 @ 2143.00000 0.0 CURRENT BACKGROUND/AVG 107 PENTANE (C-5) 0 @ 2143.00000 0 @ 2143.00000 0.0 HYDROCARBON SHOWS GAS KICK INTERVAL LITHOLOGV/REMARKS GAS DESCRIPTION 2030 TO 2105 AND BLEED SANDSTONE, SAND, BEFORE 100 MAX 463 AFTER NO FLOW OR PIT GAINS, CG 60 UNITS DUR ING SHOW, CHALKY VFGR SS, MATRIX SUPPORT, POOR OFF ASH 125 POROSITY C-1 ONLY LITHOLOGV TUFFACEOUS SILTSTONE, TUFFACEOUS CLAVSTONE, SANDSTONE, SAND, COAL PRESENT LITHOLOGY 2140' = 10 % ASH, 40%TUFFACEOUS SILTSTONE, 20 % TUFFACEOUS CLAYS70NE, 20 % SAND, 10 % COAL FINISHED PREPPING PITS FOR OIL BASE MUD BROUGHT ON 395 BBLS OF WEIGHTED MUD LEFTOVER FROM HV #12 AND 77 BBLS OF UNWEIGHTED MUD TO ACHIEVE AN , DAILY ACTIVITY DISPLACED WATER BASE MUD IN HOLE WITH OIL BASE MUD, CIRCULATED AND BEGAN ALL AROUND MW OF 9.3 PPG OIL BASE MUD SPACER OF 30 BBLS BROUGHT ON , SUMMARY DRILLING AHEAD TO 2143' , EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2 SC DAILY COST $4840 MUD LOGGING $725 RIGWATCH REPORT BY LEES F. BROWNE JR. `r~ L.J • • CHEVRON USA DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #13 REPORT FOR HURT PURUGGANAN DATE Dec 14, 2007 DEPTH 3560.00000 PRESENT OPERATION DRILLING TIME MIDNIGHT YESTERDAY 2143.00000 24 HOUR FOOTAGE 1417' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3269 32.00 227.76 2495.05 3140 37.35 228.42 2389.17 SURVEY DATA 3012 41.85 228.47 2290.75 2883 44.94 227.48 2197.14 2754 47.43 226.53 2107.88 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC DBS FM2465 FMH36552 6X12 1170 19:47 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 281.0 @ 2824.00000 7.6 @ 3289.00000 156.4 96.11021 FT/HR SURFACE TORQUE 13966 @ 3494.00000 3997 @ 2354.00000 10566.9 12225.00000 AMPS WEIGHT ON BIT 17 @ 3186.00000 0 @ 3043.00000 7.8 8.84219 KLBS ROTARY RPM 166 @ 2613.00000 81 @ 2274.00000 158.3 158.00000 RPM PUMP PRESSURE 2521 @ 3255.00000 1246 @ 3440.00000 2142.9 2175.16772 PSI DRILLING MUD REPORT DEPTH 3600' MW 9.3 VIS 94 PV 34 YP 24 FL - Gels 21/32/33 CL- - FC -/4 SOL 8.7 SD 0.10 OIL 76 MBL - p H - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 576 @ 2674.00000 6 @ 3379.00000 137.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 103522 @ 2674.00000 1076 @ 3379.00000 25877.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 8 @ 3059.00000 0 @ 2997.00000 0.3 AVG 0 PROPANE (C-3) 0 @ 3560.00000 0 @ 3560.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3560.00000 0 @ 3560.00000 0.0 CURRENT BACKGROUND/AVG 75 PENTANE (C-5) 0 @ 3560.00000 0 @ 3560.00000 0.0 HYDROCARBON GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 3050 TO 3067 TUFFACEOUS SANDSTO NE GRADING TO SILTSTONE BEFORE 100 MAX 376 VERY FINE TO FINE SANDSTONE GRADING TO SILTSTONE WITH ABNT ASH POSSIBLE BLG-20 AFTER 1120 AND MATRIX SUPPORT LITHOLOGY TUFFACEOUS SANDSTONE, SAND, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL AND CARBON CLAYS PRESENT LITHOLOGY 3560' = 60 % TUFFACEOUS SILTSTONE, 20% TUFFACEOUS CLAY, 20 % SAND DAILY ACTIVITY SUMMARY DRILL FORMATION WITH MUD LOSSES AT 9 TO 10 BBLS/HOUR EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2SC DAILY COST $4840 MUD LOGGING, $725 RIG WATCH REPORT BY LEES F. BROWNE JR. • • • CHEVRON USA DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #13 REPORT FOR HURT PURUGGANAN DATE Dec 15, 2007 DEPTH 3660.00000 PRESEN T OPERATION POOH /PREP TO RUN CSG TIME MIDNIGHT YESTERDAY 3560.00000 24 HOUR FOOTAGE 100' CASING INFORMATION 9.625" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3590 23.07 228.33 2780.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" SEC DBS FM2465 FMH36552 6X12 1170 3660 2490 20:22 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 140.9 @ 3644.00000 10.2 @ 3655.00000 101.7 49.72700 FT/HR SURFACE TORQUE 13917 @ 3597.00000 5800 @ 3656.00000 11965.6 8216.00000 AMPS WEIGHT ON BIT 11 @ 3605.00000 3 @ 3655.00000 8.4 5.04200 KLBS ROTARY RPM 161 @ 3601.00000 134 @ 3613.00000 156.6 160.00000 RPM PUMP PRESSURE 2340 @ 3634.00000 1803 @ 3621.00000 2135.3 1975.03400 PSI DRILLING MUD REPORT DEPTH 3660' MW 9.4 VIS 110 PV 32 YP 23 FL - Gels 19/24/25 CL- - FC -/4 SOL 9.3 SD - OIL 75 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 157 @ 3572.00000 33 @ 3654.00000 82.0 TRIP GAS CUTTING GAS @ @ WIPER GAS 79 @ 3660' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 30033 @ 3572.00000 6334 @ 3654.00000 15773.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 3660.00000 0 @ 3660.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 3660.00000 0 @ 3660.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3660.00000 0 @ 3660.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 3660.00000 0 @ 3660.00000 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGV/REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, SILTSTONE PRESENT LITHOLOGY 3660' = 70 % SILTSTONE, 20% SANDSTONE, 10 % SAND DAILY ACTIVITY DRILL FORMATION TO 3660', CIRCULATE THE HOLE CLEAN, WIPER TRIP TO THE SHOE, WIPER GAS 79 UNITS, SPOT STEEL SEAL PILL ON BOTTOM, BEGIN TO PULL OUT SUMMARY OF THE HOLE TO RUN 7" CASING. EPOCH PERSONNEL ON BOARD BROWNE, LUNDY + 2 SC DAILY COST $4080 MUD LOGGING $725 RIGWATCH REPORT BY LEES F. BROWNE JR. • • • CHEVRON USA SOUTH KENAI GAS FIE LD DAILY WELLSITE REPOR T EPOCH HAPPY VALLEY #13 REPORT FOR Floyd Hurt, Abe Purugganan DATE Dec 15, 2007 DEPTH 3660' PRESENT OPERATION Run in hole with 7" casing TIME 2359 hrs YESTERDAY 3660' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED BN 2 8 1/2" SEC DBSFM2465 FMH36552 6 X 12 1170' 3360' 2490' 20.22 CSG PT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3660' MW 9.35 VIS 132 PV 29 YP 16 FL 4.3 Gels 15/23/24 CL- 5.54/- FC -/4 SOL 8.4 SD 0.10 OIL 76.0/14.0 MBL -- pH -- Ca+ -- CCI -- MWD SUMMARY INTERVAL TO TOOLS No new footage drilled this period GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled this period. DAILY ACTIVITY SUMMARY Continue to pull out of hole. Lay down BHA. Test BOP's. Rig up to run 7" casing. Start running same. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST DML $4,080___RW $725 REPORT BY Larry Resch • • CHEVRON USA SOUTH KENAI GAS FIELD DAILY WELLSITE REPORT EPQ~~ HAPPY VALLEY #13 REPORT FOR Floyd Hurt, Abe Purugganan DATE Dec 16 2007 DEPTH 3660' PRESENT OPERATION Pick Up Drill Pipe TIME 2359 hrs YESTERDAY 3660' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @1157' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3660' MW 9.2 VIS 110 PV 21 YP 12 FL 5.0 Gels 9/20/24 CL- 7.85/- FC -/4 SOL 8.7 SD -- OIL 87.8/12.2 MBL -- pH -- Ca+ 6.26 CCI -- MWD SUMMARY INTERVAL TO TOOLS No new footage drilled this period. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY No new footage drilled this period. PRESENT LITHOLOGY Continue running 7" casing from 1141' to 2000' with no returns/displacement. Circulate and condition, work casing with poor returns. Continue to run in hole with 7" casing. Land hanger. Rig ip Schlumberger and test lines to 4000 psi. Pump DAILY 20 bbl mud push LCM with rig pump. Drop bottom plug. Schlumberger pumps 83 bbls @ 12.5 ppg cement. Drop top ACTIVITY plug and follow with 138.25 displacement. Did not bump. Check floats: OK. Monitor returns out the anulus @ 5 bph. SUMMARY Blow down all lines. Rig down Schlumberger and rig up circ head for well control. Monitor returns @ 3.7 bph with 12.33 bbl total return from the anulus. Install pack off and test for 30 minutes at 5000 psi. Install wear ring. Move HWDP to the off driller side. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST DML $4080___RW $725 REPORT BY Larry Resch • • CHEVRON USA SOUTH KENAI GAS FIELD DAILY WELLSITE REPORT ~~I~C,H HAPPY VALLEY #13 REPORT FOR Floyd Hurt, Abe Purugganan DATE Dec 17, 2007 DEPTH 3660' PRESENT OPERATION Finish BOP Tests TIME 2359 hrs YESTERDAY 3660' 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8" @ 1157' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 6 1/8" SEC DBS FM2567 10392727 3 X 9, 2 X 16 3660' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3660' MW 9.2 VIS 87 PV 25 YP 10 FL 5.8 Gels 9/1 9/21 CL- 5.29/0.94 FC -/4 SOL 6.7 SD -- OIL 81.5/10.5 MBL -- pH -- Ca+ 5.96 CCI -- MWD SUMMARY INTERVAL TO TOOLS No tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY No new footage drilled this period . PRESENT LITHOLOGY Continue to pick up drill pipe. Conduct BOP/Evacuation drill. Stand back drill pipe. Safety shut down re: Nabors DAILY ACTIVITY 105 incident. Adju st pop off valves on pumps to 4500 psi. Pressure test casing/sheo to 3000 psi for 30 minutes. SUMMARY Install new gage on the 7" anulus to 1000 psi. Test BOP's. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST DML $4080___RW $725 REPORT BY Larry Resch • • CHEVRON USA SOUTH KENAI GAS FIELD DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #13 REPORT FOR Doug Smith, Abe Purugganan DATE Dec 18 2007 DEPTH 3660' PRESENT OPERATION FIT TIME 2359 hrs YESTERDAY 3660' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NB 3 6 1/8" SEC DBS FM2567 10392727 3 X 9, 2 X 18 3643' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3675 MW 9.2 VIS 85 PV 23 YP 12 FL 4.8 Gels 11/18/20 CL- 5.8/- FC -/4 SOL 6.7 SD ---- OIL 81.5/10.5 MBL -- pH -- Ca+ 9.66 CCI -- MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Safety stand down with Chevron. Complet BOP testing. Pick up LWD BHA and HWDP. Run in hole; wash from SUMMARY 3385' to 3558'; tag float; drill cement and shoe; tag sho at 3641'. Drill 20' new hole to 3680'. Conduct FIT. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST DML $4080___RW $725 REPORT BY Larry Resch ~~ ~~ Chevron, USA South Kenai Gas Field DAILY WELLSITE REP ORT ~~~~,~ Happy Valley #13 REPORT FOR HurUPurugganan DATE Dec 19, 2007 DEPTH 4529' PRESENT OPERATION Drilling Ahead TIME 2359 hrs YESTERDAY 3660' 24 HOUR FOOTAGE 869' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3648' 22.20 228.34 2833.63' 3841' 14.45 229.32 3016.69' SURVEY DATA 4034' 8.2 226.71 3205.61' 4227' 3.53 230.59 3397.68' 4355' 2.47 204.04 3525.57' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED BN 3 6 1/8" sec dbs fm2567 10392727 3 x 9, 2 x 18 3660 869 12.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 225.2 @ 4438 9.3 @ 4076 102.4 99.3 FT/HR SURFACE TORQUE 8216 @ 3660 37 @ 4486 3355.7 5567,0 AMPS WEIGHT ON BIT 14 @ 4219 1 @ 4482 3.4 1.1 KLBS ROTARY RPM 160 @ 3660 8 @ 4078 31.9 55.7 RPM PUMP PRESSURE 2015 @ 4477 1146 @ 3895 1653.2 1736.3 PSI DRILLING MUD REPORT DEPTH 4500' MW 9.2 VIS 70 PV 22 YP 9 FL 4.8 Gels 8/16/18 CL- 4.78/- FC -/4 SOL 7.8 SD -- OIL 88.5/11.5 MBL -- pH -- Ca+ 10.88 CCI -- MWD SUMMARY INTERVAL 3660 TO 4529 TOOLS PDC bit, Autotrak with mud motor and LWD: Gamma, Resistivity, Directional and ECD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 330 @ 4042 0 @ 41.8 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 51383 @ 4042 23 @ 3864 6510.8 CONNECTION GAS HIGH neg ETHANE (C-2) 0 @ @ AVG -- PROPANE (C-3} 0 @ @ CURRENT -- BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG 10-20 U PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS Minor (< 2000nits) coal gas throughout today's drilled interval. Please refer to mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga/Tyonek PRESENT LITHOLOGY ----------Tuff, Claystone, Sand and Sandstone, Occasional Coals,Trace Conglomeratic Sand----------- DAILY ACTIVITY Run FIT @ 3643': 780 psi test for 4 minutes. Blow down kill line and drain choke manifold. Drill 6 1/8" hole from SUMMARY 3648' to 4529'. EPOCH PERSONNEL ON Lundy, Resch + 2 BOARD SC DAILY DML $4,080___RW $750 (add'I $25 for COST BOP Sensor) REPORT BY Larry Resch CJ Chevron, USA South kenai G as Field DAILY WELLSITE REPORT ~~~~, Happy Valle y #13 REPORT FOR Dave Smith/Abe Purugganan DATE Dec 20, 2007 DEPTH 5703' PRESENT OPERATION Rig Service TIME 2359 hrs YESTERDAY 4529' 24 HOUR FOOTAGE 1174' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4612' 0.63 354.43 3782.51' 4870' 0.50 67.25 4040.50' SURVEY DATA 5127' 0.07 273.63 4297.49' 5384' 0.62 78.10 4554.48' 5578' 0.65 72.39 4748.47' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TY PE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED BN 3 6 1/8" SEC DBS FM2567 10392727 3 X 9, 2 X 18 3660 2043' 24.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 256.3 @ 5352 15.3 @ 4556 122.5 176.3 FT/HR SURFACE TORQUE 8265 @ 5665 37 @ 5069 5984.4 6156 AMPS WEIGHT ON BIT 8 @ 4810.00000 1 @ 5565 3.5 4.6 KLBS ROTARY RPM 64 @ 4592 48 @ 4677 58.4 61.0 RPM PUMP PRESSURE 2834 @ 5422 654 @ 5611 2207.8 2195 PSI DRILLING MUD REPORT DEPTH 5700' MW 9.3 VIS 70 PV 22 YP 9 FL 5.6 Gels 9/16/18 CL- 1.72/- FC -/4 SOL 7.9 SD -- OIL 80.0/11.0 MBL -- pH -- Ca+ 11.40 CCI -- MWD SUMMARY INTERVA L 3660' TO 5703' TOOLS PDC bit, Autotrak with mud motor and LWD: Gamma, Resistivity, Directional and ECD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 386 @ 5663 0 @ 5339 74.7 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 64666 @ 5665 126 @ 4997 12430.4 CONNECTION GAS HIGH 4 ETHANE (C-2) 5 @ @ AVG 0 PROPANE (C-3) 0 @ @ CURRENT 0 BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG 20 Units PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 4822-4829 5650-5702 coal/carbonaceous shale coal 314U max 387U max med dk gy-gy blk, sft v dk gy-blk-dk brn gy, fm LITHOLOGY Tyonek PRESENT LITHOLOGY ----------Claystone, Siltstone, Coals, Sand---------- DAILY ACTIVITY Drill 6 1/8" hole from 4529' to 5703'. 24 hour average ROP = 48.9 FUHr. Circulate and condition hole while SUMMARY servicing rig mud pump. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST DML $4,080___RW $750 REPORT BY Larry Resch i • Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT EPOCH Happy Va lley #13 REPORT FOR Dave Smith, Abe Purugganan DATE Dec 21, 2007 DEPTH 6894' PRESENT OPERATION Drilling Ahead TIME 2359 hrs YESTERDAY 5703' 24 HOUR FOOTAGE 1191' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3643' 0.91 76.32 4813.47' 5901 1.20 206.26 5071.43' SURVEY DATA 6158' 1.82 251.51 5328.35' 6480' 1.57 303.11 5650.17' 6737' 2.77 340.59 5906.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED BN3 6 1/8" SEC DBS FM2567 10392727 3 X 9, 2 X 18 3660 3234' 37.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 194.0 @ 6617 5.1 @ 5731 108.1 138.1 FT/HR SURFACE TORQUE 9846 @ 6822 25 @ 5801.00000 7001.0 7664.1 AMPS WEIGHT ON BIT 22 @ 6232 1 @ 5708 4.8 2.7 KLBS ROTARY RPM 71 @ 6714 2 @ 5802 58.1 70.0 RPM PUMP PRESSURE 2988 @ 6828.00000 897 @ 6104.00000 2683.0 2860.13428 PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS 71 PV 24 YP 12 FL 5.2 Gels 11/19/20 CL- 4.62/1.0 FC -/4 SOL 7.6 SD -- OIL 80.0/11.0 MBL -- pH -- Ca+ 11.2 CCI -- MWD SUMMARY INTERVAL 3660' TO 6894' TOOLS PDC bit, Autotrak with mud motor and LWD: Gamma, Resistivity, Directional and ECD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 784 @ 6715 11 @ 5837 107.9 TRIP GAS n/a CUTTING GAS 0 @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 139319 @ 6713 2190 @ 5837 18147.9 CONNECTION GAS HIGH 6 ETHANE (C-2) 28 @ 6830 0 @ 1.2 AVG 4 PROPANE (C-3) 0 @ @ CURRENT 6 BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG 40 U PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS Several quality gas shows in coals and dirty sands. Please refer to mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6097-6103; 6542-6554; 6780- coal and carb. shale; coal and carb. shale; sand, 383u Max; 255u Max; dk gy-blk, fm, outgassing; dk gy,blk, 6746; 6821-6839; tuffaceous sand; sand, tuffaceous sand; 770u Max; 488u Max; hkly,outgassing; It-m gy, of-f gr, fair por; It-m gy, f gr, wl srt; LITHOLOGY Tyonek PRESENT LITHOLOGY ----------Tuffaceous Siltstone, Claystone and Sandstone, Minor Coals---------- DAILY ACTIVITY SUMMARY Drill 6 1/8" hole from 5703' to 6894'. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST DML $4,080___RW $750 REPORT BY Larry Resch r • Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT ~~~,~ Happy Valley #13 REPORT FOR Dave Smith, Abe Purugganan DATE Dec, 22, 2007 DEPTH 7747' PRESENT OPERATION Circulate at shoe TIME 2359 hrs YESTERDAY 6894' 24 HOUR FOOTAGE 853' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6737' 2.77 340.59 5906.98' 6995' 1.35 21.84 6164.86' SURVEY DATA 7252' 1.43 28.44 6421.79' 7509' 1.53 28.10 6678.72 7747 proj. 2.10 32.12 6916.57' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED BN3 6 1/8" SEC DBS FM2567 10392727 3 X 9, 2 X 18 3660' 7747' 4087' 45.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 178.0 @ 7351 13.1 @ 7726 113.6 61.3 FT/HR SURFACE TORQUE 10325 @ 7596 6916 @ 7190 8572.7 8976 AMPS WEIGHT ON BIT 14 @ 7054 1 @ 7231 3.1 3.9 KLBS ROTARY RPM 73 @ 7056 53 @ 7502 68.5 70.0 RPM PUMP PRESSURE 3195 @ 7532 2436 @ 7340 2833.7 2768.05 PSI DRILLING MUD REPORT DEPTH 7747' MW 9.2 VIS 69 PV 23 YP 11 FL 4.6 Gels 9/18/20 CL- 3.91/10.79 FC -/4 SOL 7.8 SD -- OIL 89.0/11.0 MBL -- pH -- Ca+ 9.07 CCI -- MWD SUMMARY INTERVAL 3660' TO 7747' TOOLS PDC bit, Autotrak with mud motor and LWD: Gamma, Resistivity, Directional and ECD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 557 @ 7482.00000 32 @ 7313.00000 169.8 TRIP GAS n/a CUTTING GAS 0 @ 7747.00000 0 @ 7747.00000 0.0 WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 89928 @ 7482.00000 5093 @ 7313.00000 25714.0 CONNECTION GAS HIGH 20 ETHANE (C-2) 43 @ 7348.00000 0 @ 7657.00000 7.7 AVG 8 PROPANE (C-3) 0 @ 7747.00000 0 @ 7747.00000 0.0 CURRENT -- BUTANE (C-4) 0 @ 7747.00000 0 @ 7747.00000 0.0 CURRENT BACKGROUND/AVG < 10 u PENTANE (C-5) 0 @ 7747.00000 0 @ 7747.00000 0.0 HYDROCARBON SHOWS Many quality gas shows in coals and sands. Please refer to mud log for details. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6964-7036; 7075-7092; 7109- Tyonek, sand; Tyonek, coal! shale; Tyonek, 376 u Max; 275 u tuffsd poor vis por; sft coal, dk gy carb 7213; 7270-7276; 7320-7357; sand & coals; Tyonek, sand and coal; Tyonek, Max; 508 u Max; sh; tuffsd w/ intbd coal; tuffsd w/ intb 7460-7555; sand coal; Tyonek,sd, coal, sh 284 u Max; 521 u coal; intbd coal & sd; sd, itbd coal/carb Max; 558 u Max; sh; LITHOLOGY Tyonek PRESENT LITHOLOGY ----------Tuffaceous Sand, Sandstone, Siltstone, Claystone---------- DAILY ACTIVITY Drill 6 1/8" hole from 6894' to TD of 7747' MD/6916.59'TVD. Circulate hole clean and condition mud. Wiper trip to shoe, SUMMARY pulling tight at 6775' and 6786': Wash and ream through section. Continue trip to shoe at 3620'. Circulate and condition. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST DML $4,080___RW 750 REPORT BY Larry Resch ~i • Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT EPOCK Happy Valley #13 REPORT FOR Dave Smith, Abe Purugganan DATE Dec, 23, 2007 DEPTH 7747' PRESENT OPERATION Lay Down BHA TIME 2359 hrs YESTERDAY 7747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED BN 3 6 1/8" SEC DBS FM2567 10392727 3 X 9, 2 X 18 3660' 7747' 4087' 45.9 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7747' MW 9.25 VIS 75 PV 23 YP 12 FL 4.5 Gels 10/18/19 CL- 3.64/0.54 FC -/4 SOL 7.7 SD -- OIL 89.0/11.9 MBL -- pH -- Ca+ 8.55 CCI -- MWD SUMMARY INTERVAL 3660' TO 7747' TOOLS PDC bit, Autotrak with mud motor and LWD: Gamma, Resistivity, Directional and ECD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS 348 U Max CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH 10 ETHANE (C-2) @ @ AVG 8 PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 20-40 PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY No new footage this period. Circulate and condition at the shoe @ 3602'. Run back to 5360', circulate and condition. Continue to bottom working DAILY tight spot at 7698-7747'. Bottoms up after wiper trip recorded wiper gas readings of 348 and 315 units from 2 zones. ACTIVITY Clean hole and check for flow. Pull out of hole to casing shoe. Continue POOH sideways laying downHWDP to SUMMARY 1519'. EPOCH PERSONNEL ON BOARD Lundy, Resch + 2 SC DAILY COST $4,080___RW $750 REPORT BY Larry Resch • Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT EPOCH Happy Valley #13 REPORT FOR Dave Smith, Abe Purugganan DATE Dec, 23, 2007 DEPTH 7747' PRESENT OPERATION POOH TIME 2359 hrs YESTERDAY 7747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7747' MW 9.3 VIS 85 PV 23 YP 12 FL 4.2 Gels 9/18/20 CL- 4.01/0.88 FC -/4 SOL 8.3 SD -- OIL 89.0/11.0 MBL -- pH -- Ca+ 7.9 CCI -- MWD SUMMARY INTERVAL TO TOOLS No tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY No new footage drilled this period. DAILY ACTIVITY SUMMARY Continue to pull out of hole. Lay down BHA and Baker tools. EPOCH PERSONNEL ON BOARD Lundy, Resch = 2 SC DAILY COST DML $4,080___RW $750 REPORT BY Larry Resch • • Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT EPQCH Happy Valley #13 REPORT FOR Dave Smith, Abe Purugganan DATE ,Dec 25, 2007 DEPTH 7747' PRESENT OPERATION RIH w/ 3 1/2" CSG TIME 2359 hrs YESTERDAY 7747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7747' MW 9.3 VIS 85 PV 23 YP 12 FL 4.2 Gels 9/18/20 CL- 3.76/- FC -/4 SOL 8.3 SD -- OIL 80.5/10.0 MBL -- pH -- Ca+ 7.9 CCI -- MWD SUMMARY INTERVAL TO TOOLS No tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ C URRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this periiod. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY No new footage drilled this period. DAILY ACTIVITY SUMMARY Wire line logging. Rig down Schlumber. Rig up and prepare to run 3 1/2" casing. Effect same. EPOCH PERSONNEL Resch, ON BOARD Chawdhury DAILY DML $3,215___RW $750 (NOTE: Sample COST catchers not on location) REPORT BY Larry Resch ~~ ~J Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT EPOCH Happy Valley #13 REPORT FOR Dave Smith, Abe Purugganan DATE Dec, 26, 2007 DEPTH 7747' PRESENT OPERATION Prepare to Cement Casing TIME 2359 hrs YESTERDAY 7747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 3643' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7747' MW 9.35 VIS 131 PV 25 YP 11 FL 4.2 Gels 10/18/19 CL- 11.2 FC -/4 SOL 7.7 SD -- OIL 89.0/11.0 MBL -- pH -- Ca+ 8.16 CCI -- MWD SUMMARY INTERVAL TO TOOLS No tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 16 u CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CUR RENT BACKGROUND/AVG < 5 u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY No new footage drilled this period. DAILY ACTIVITY Run 3 1/2" casing from 100.96' to 3642'. Circulate and condition. Continue running casing 5692'. Circulate and condition bottu ms up twice. Continue running casing; tagged at 7755' Circulate and condition while rigging up SUMMARY cement head. Recorded 16 units of gas maximum. EPOCH PERSONNEL ON BOARD Resch, Chowdhury DAILY COST DML $#,215___RW $750 REPORT BY Larry Resch • Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT EPOCH Happy Valley #13 REPORT FOR Dave Smith, Jason Bradford DATE Dec, 27, 2007 DEPTH 7747' PRESENT OPERATION Make Up Setting Tool TIME 2359 hrs YESTERDAY 7747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 3643' 3 1/2" @ DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH ___Empty Pits___ MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS No tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS -- CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH n/a ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY No new footage drilled this period. Rig up cement lines and test same. Pump mud push 27 bbls; pump cement 145 bbls 12.5 slurry; flush lines with DAILY base oil. Drop dart and pressure to 3000 psi for 10 minutes. Try to set ZXP Packer. Clean out cement stinger and ACTIVITY circulate bottoms up. Pressure test annulu 2500 psi for 30 minutes. Rig down cement lines. Circulate bottoms up. SUMMARY Pull out of hole from 3416'. Clean out mud system. lay down BHA; righ up setting tool. EPOCH PERSONNEL ON BOARD Resch, Chowdhury DAILY COST DML $4,215___RW $750 REPORT BY Larry Resch C~' • L~ Chevron, USA south Kenai Gas Field -DAILY WELLSITE REPORT ~PQ~~ Happy Valley #13 REPORT FOR Dave Smith, Jason Bradford DATE ,Dec. 28, 2007 DEPTH 7747' PRESENT OPERATION POOH TIME 2359 hrs YESTERDAY 7747' 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 3643-__ __3 1/2" @ DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH ---Pits Empty-- MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS No tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS Negiigable CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/an/a METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG -- PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek PRESENT LITHOLOGY No new footage drilled. Pick up Baker setting tool. Run in hole. Set 50k on packer. Pressure test annular 500 and 2500 psi for 30 minutes. DAILY Retest. Circulate and condition hole. Rig up to pressure test down drill pipe. Test at 500 and 3000 psi. Pull out of ACTIVITY hole from 3456'. Conduct BOP drill. Pull out of hole laying down HWDP. Run in hole with 39 stands DP on collars. SUMMARY Pull out of hole sideways laying down 23 stands drill pipe. EPOCH PERSONNEL ON BOARD Resch, Chowdhury DAILY COST ___DML $3,215___RW $750 REPORT BY Larry Resch • Chevron, USA South Kenai Gas Field DAILY WELLSITE REPORT EPOCH Happy Valley #13 REPORT FOR Dave Smith, Jason Bradford DATE ,Dec 29, 2007 DEPTH 7747' PRESENT OPERATION Pressure Testing TIME 2359 hrs YESTERDAY 7747' 24 HOUR FOOTAGE 0' CASING INFORMATION ___7" @ 3643'___ ___3 1/2 " @ DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH ---Pits Empty--- MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Lay down 16 stands of drill pipe; drill collars; float sub; Baker tool. Prepare to run 3 1/2" tubing. Trip in hole to 1413'. DAILY Rig up control line and run in hole with control line and tubing. Test control valve to 1000 psi for 10 minutes. Continue ACTIVITY tripping in hole. Sti ng into top of liner; strap in and touched down for space out. Pick up and make up hanger. lay SUMMARY down 2 joints of tubing and pick up pup joints. Pressure test control line to 3000 psi. Land hanger at 1800 hrs. Pressure test hanger seals to 5000 psi for 30 minutes. Rig up to test annular and tubing. EPOCH PERSONNEL ON BOARD Resch, Chowdhury DAILY COST ___DML $3,215___RW $ 750 REPORT BY Larry Resch
