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Home My WebLink About213-196Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/15/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221215 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14A 50133205390100 213196 9/22/2022 YELLOW JACKET PERF CLU 10RD 50133205530100 222113 10/24/2022 YELLOW JACKET PERF-GPT CLU 05RD 50133204740100 215160 7/15/2022 YELLOW JACKET PLUG-PERF CLU 10 50133205530000 205106 7/16/2022 YELLOW JACKET PERF KALOTSA 4 50133206650000 217063 8/24/2022 YELLOW JACKET PERF MPU K-09 50029232470000 205014 12/11/2022 READ CaliperSurvey Please include current contact information if different from above. T37376 T37377 T37378 T37379 T37380 T37381 By Meredith Guhl at 10:10 am, Dec 16, 2022 BCU 14A 50133205390100 213196 9/22/2022 YELLOW JACKET PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.16 10:11:16 -09'00' 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): Beaver Creek Unit GL:141' BF:141' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" K-55 145' 13-3/8" K-55 2,122' 9-5/8" L-80 3,548' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl:Flow Tubing N/A 3,632' MD / 3,548' TVD N/A 9,450' MD / 8,870' TVD 3,632' MD / 3,548' TVD N/A 2123' FSL, 124' FWL, Sec 34, T7N, R10W, SM, AK Choke Size: Surface Per 20 AAC 25.283 (i)(2) attach electronic information 40# Surface 133# 68# 145' Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: N/A Gas-Oil Ratio: AMOUNT PULLED 315912 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. BCU 14AFebruary 1, 2014113' FSL, 1390' FEL, Sec 33, T7N, R10W, SM, AK 159' BOTTOMCASINGWT. PER FT.GRADE CEMENTING RECORDSETTING DEPTH TVD 2432057 TOP HOLE SIZE N/A Beluga GP, Sterling GP A028083 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 314368 2430071 50-133-02539-01-00January 25, 2014 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 10/19/2022 213-196 / 322-317 N/A PACKER SET (MD/TVD) Cond 16" Driven Surface 568 sx Surface 2,122' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Surface 3,632' (TOW) Surface ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 887 sx12-1/4" N/A SIZE DEPTH SET (MD) WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:46 pm, Dec 09, 2022 Abandoned 10/19/2022 JSB RBDMS JSB 121422 20539 xGSFD 11/2/2023 DSR-1/3/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Digital Signature with Date:Contact Email:cdinger@hilcorp.com Contact Phone: 907-777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Tyonek Wellbore Schematic, P&A Reports Authorized Title: Drilling Manager Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS No NoSidewall Cores: Yes No Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov For Monty Myers Digitally signed by Cody Dinger (2323) DN: cn=Cody Dinger (2323), ou=Users Date: 2022.12.09 15:14:45 -09'00' Cody Dinger (2323) Updated by CJD 12-9-22 P&A SCHEMATIC BCU-14A Pad 1A PTD: 213-196 API: 50-133-20539-01-00 PBTD = 3,712’ / TVD = 3,612’ TD = 9,450’ / TVD = 8,870’ RKB to GL = 18.6’ 5254 PERFORATION DETAIL Sand TOP MD BTM MD TOP TVD BTM TVD FT Date Status B3B 5,501’ 5,506’ 5,095’ 5,099’ 5 9/22/22 Isolated B5 5,624’ 5,628’ 5,200’ 5,204’ 4 10/29/20 Isolated B5 5,663’ 5,668’ 5,235’ 5,240’ 5 8/23/20 Isolated B6 5,684’ 5,694’ 5,254’ 5,263’ 10 5/18/15 Isolated UBC-3 6,550’ 6,560’ 6,060’ 6,069’ 10 11/26/14 Isolated LB-27 8,477’ 8,497’ 7,905’ 7,925’ 20 5/23/14 Isolated LB-28 8,543’ 8,560’ 7,970’ 7,987’ 17 5/15/14 Isolated LB-28B 8,715’ 8,731’ 8,140’ 8,156’ 16 3/28/14 Isolated LB-30 8,868’ 8,882’ 8,292’ 8,306’ 14 3/17/14 Isolated OPEN HOLE / CEMENT DETAIL 13-3/8” 16” Hole: 265bbls of 10ppg cement pumped. Got 15bbls cement back to surface 9-5/8” 12-1/4” hole: cemented with 377bbls 12.5ppg lead class G followed by 106 bbls 15.8ppg tail (from 7594’ MD). Got 25bbls cement back to surface. 5-1/2” 8-1/2” hole: 9.6ppg mud in hole pre-cement. 34bbls 12.5ppg mud push ahead of job. Cemented with 232bbls 15.3ppg class G. 2/17/14 CBL show’s ToC at 3990’ MD. 3/3/14 USIT shows free pipe above 3940’ MD 750’ of 12.5 ppg Mud Push 9.6 ppg Mud CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 133 K-55 18.73” Surf 145' 13-3/8" Surf Casing 68 K-55 BTC 12.415” Surf 2122 9-5/8” Int Casing 40 L-80 BTC 8.835” Surf 3,632’ (TOW) 5-1/2” Prod Casing 20 P-110 XP BTC 4.778” Surf 9419 9-5/8” KOP at ~5100’ MD 5-1/2” JEWELRY DETAIL No. Depth (MD) ID Item 1 4857 4.778” Swell Packer 2 5680 CIBP (8/23/20) 3 6475 CIBP with 44’ cement 4 8270 CIBP with 35’ cement 5 8530 CIBP 6 8610 CIBP 7 8852 CIBP with 25’ cement 13-3/8” 1 2 3 4 5 6 7 3/3/14 USIT shows free pipe above 3970’ MD Cut tubing @ 3,709 MD 09/22/22 ToC @ 3,712’ 10/07/22 TOW @ 3,632’ MD Activity Date Ops Summary 9/29/2022 Load out mix water from Swanson, 165 bbls of 85 deg water. Start rigging up return tank and cementing lines to tree cap. Halliburton cementers on location. PJSM and PTW. Pressure test lines to 1100 psi and 2500 psi. Verify circulation down tubing, taking returns from the IA to a tank, returns from IA seen at 20 bbls pumped.,Shut in IA and verified injectivity into well. Pumped 30 bbls into perfs first on a vac and then slowly built to 300 psi. Shut down. Bring cement to weight. Pump 30 bbls of 15.3 ppg cement at 4 bpm. Displaced with 24 bbls of fresh water. At 20 bbls of displacement away, shut in IA valves and squeeze 4 bbls into perfs. Reached 2500 psi squeeze pressure. Bled WHP pressure back to 500 psi and shut well in. RDMO cementers. 10/3/2022 Hot oil truck on location. PJSM and PTW. AOGCC and BLM waived witness. Rigup hot oil truck. MIT-T to 3000 psi. Lost 36 and 45 psi in first test, with final pressure at 3119 psi. Bleed pressure off and retest - 3260 initial, 3190 at 15 min, 3157 at 30 min and 3131 at 45 min. Good test. Bleed pressure off tubing.,MIT-IA to 3000 psi. Initial 3230 psi,15 min - 3164 psi (lost 66 psi), 30 min - 3142 psi (lost 22 psi). Good test. Bleed IA pressure to 2000 psi.,OA pressure at 600 psi. Bleed pressure off OA, mostly gas. MIT-OA to 3000 psi. Start test at 3127 psi. Quickly dropped. Bleed off additional gas. Start test - 3224 psi initial, 15 min - 3086 psi (lost 138 psi), 30 min - 3019 psi (lost 67 psi). Good test. Bleed tbg, IA and OA off to below 50 psi. RDMO. 10/4/2022 Yellowjacket EL on location. PJSM and PTW. Move well house. of well Rig up equipment, pressure test to 250 psi / 2000 psi. MU 2.063" jet cutter w/ CCL and weight bar. OAL - 22'. RIH and tag at 3712'. Tag same spot 3 times. POOH. MU 2.062" drift ring and spang jars, OAL - 27'. RIH and tag at 3712' consistently. No progress. POOH. Call out Pollard SL.,Pollard arrive on location. PTW. MU weight bar, spangs, gauge ring. Tagged at 3712'. No progress. POOH. MU drive down bailer, with flapper - got consistent tags at 3712', recovered ~1 gallon of contaminated cement. RDMO Pollard and Yellowjacket. 10/7/2022 Obtain PTW and hold PJSM.,RU EL, Crane and PCE. MU tool string (R.S., 2 wt. bars, CCL, centralizer, shock sub and 2.063" jet cutter). Move to well head and PT 250/2000 psi. Passed. SITP = 0 psi,RIH w/ jet cutter and tag TOC at 3712' (ELM). Confirmed tag and cut depth w/ Ops engineer. Pulled into position and shot jet cutter at 3709' (ELM). POOH.,OOH. RD and move to BCU-16rd. n (LAT/LONG): evation (RKB): 50-133-20539-02-00API #: Well Name: Field: County/State: BCU 14A Beaver Creek Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00074 BCU-14B PreDrill Spud Date: Activity Date Ops Summary 10/13/2022 Remove windwalls from pits, scope down derrick, wrap up TD HPU hoses, Cover flanges on all BOPE, Lay over and remove MGS, Continue rigging down pits, Continue pressure washing throughout entire rig. Scope derrick down, Remove centrifuge from pits, lay over MGS and remove from footprint. Continue;disconnecting all modules in preparation for move. Continue moving equipment to Beaver Creek.;Remove BOPE stack from cellar and place on trailer for transport to BC-14B. Continue welding on pipe skate, Hang blocks, Unspool drilling line from draworks, Cut 84' of drilling line (18 wraps), Tie lines up in derrick, P/U service loop and hang off, Hang off drilling line. Continue pressure washing;Throughout entire rig, PJSM, lay over derrick, continue scrubbing and pressure washing in and around mud pits, pumps and derrick.;Lay felt and liner over well. Pressure wash derrick, clean and organize all buildings, Remove pins from derrick cylinders, Lower pit roofs, Cont. to blowdown and disconnect lines. Disconnect drive line and break handle;Set rig mats on well, Finish lowering pit roofs and securing lines, hoses, and electrical. Perform derrick inspection, Remove light from buildings and lower hand rails. R/D Pason and comms cables 10/14/2022 Remove choke house, Iron roughneck and V-Door wind wall with crane while bed trucks tear down backyard and position MP#1 , Mud Tanks 1 and 2 on side of location for next trip, Take Boiler, Generator skids, MP #2 skid to Beaver Creek. Come back and grab MP #1, Electrical;shop. Crane lays down derrick board windwalls. Both cranes connect to Mast and remove it from draworks skid and place on trailer, tie down and disconnect cranes, load drilling line spool on trailer and secure, transport to Beaver Creek.;Connect cranes to draworks skid, remove from subbase and set on containment and tail roll on trailer and leave location. Connect cranes to subbase and lift off of pony subs, tail roll mechanic shop and remove from location, tail roll mud tank 2 and remove from location, Cranes set subbase on drop;deck trailer, secure and take to Beaver Creek. Pick and set pony subs on trailer, secure and take to Beaver Creek. Mobe Cranes to Beaver Creek to assemble rig over well BCU-14B.;Spot pony subs over well, crane in sub base, draw works skid, derrick. Prep tp raise derrick, spot and raise dog house, Raise derrick, Spot top drive HPU, mud tanks 1-3, Mud pumps 1 and 2, boiler house. Raise roofs on mud tanks, Install stairs and hand rails, R/U electrical cables;Power up generators, R/U mud pump high pressure lines. Pick up rig mats, liner and felt on CLU 10 well, clean up location CCI rig mover released @ 2100hrs;Complete R/U of pits and mud pumps, Spot Generator #3, Spool line on draw works and prep to raise derrick. R/U Pason system and all electrical lines. Lay out liner for Catwalk 10/15/2022 Prep to scope up derrick, perform derrick inspection, Spot and R/U choke house, Scope up derrick, prep to P/U top drive. Install wind walls on mud pits, install iron roughneck. 24hr notice for BOP test given to AOGCC @ 8:04.;Cont R/U pit system and electrical lines. Install handy berm around rig. Tie back bridal lines. R/U and P/U top drive. Hook up hyd. lines to top drive and shin top drive extend frame. Lay liner for gas buster and R/U same. Update given to BLM and AOGCC @ 15:09.;Check Nitrogen pre-charge in Koomey bottles filling as needed. Change gear oil on top drive gear box/swivel, Install saver sub, bails and M/U kelly hose on top drive. Fill boilers with water, R/U rig tongs and handling equipment/Subs.;AOGCC (Jim Regg) waived witness @ 19:29.;Remove single gate from stack and install DSA, Remove tree and install test dart, N/U BOP's and tight flanges. R/U kill and choke lines Bring boiler to full pressure and circulate steam thru rig. Install lines going to gas buster. 10/16/2022 Rig accepted @ 06:00. Install tarps and turn steam on to all heaters throughout rig, Install accumulator Lines. Function test blind rams, Choke and Kill HCRs. M/U 2-7/8" test joint and install, Function test Annular and VBRs. Good function test. Shell test T/ 3000psi. good test.;Test BOPE 250/ 3000psi 5/10as per BLM and AOGCC regulations with BLM representative Quinn Sawyer witnessing test.;R/D testing equipment, Blow down choke and kill lines, Line up well control equipment, break down test joint, Pull blanking plug from hanger as per wellhead representative, Clean and clear rig floor.;Wellhead Tech Pull BPV with dry rod. R/U parker casing equipment. M/U landing jt and screw into hanger, BOLDS and pull hanger to floor. P/U 40K S/O 38K. L/D landing jt and hanger.;POOH 2 7/8" EUE tubing F/~ 3700' to surface, L/D 117 jts and 7' cut jt.;R/D casing equipment and clear rig floor.;Set BPV, bleed down accumulator, Remove Koomey lines , Remove choke and kill hoses, remove BOP from well, Install single gate on BOP's . Remove DSA and tubing head from well head. N/U BOP's . 10/17/2022 Continue assembling flow box assembly, Test run 5-1/2" test joint, open LPR door and mark pipe for hole, POOH and take to shop and drill hole in joint. Start building 300 BBLs KCL mud, Function test new top drive hpu pump, Replace air compressor motor.;Wellhead tech Install TWC with dry rod, Install 5-1/2" test joint, Close LPR with 5-1/2" fixed rams and purge system with water and test 250psi for 5 minutes and 3000psi for 10 minutes, Good test. Pull 5-1/2" test joint and install 4-1/2" test joint close UPR 2-7/8" x 5" VBRs purge system and test.;VBRs, Mezz kill valve, CV 1, 2, and 3 to 250/ 3000 psi for 5/ 10 minutes testing all components that were broke for the re-install F/ the 7-1/16" head T/ 11" head. Good test.;R/D test equipment, Blow down choke and kill lines, L/D test joint, Clear and clean rig floor.;PJSM, R/U E-Line and RIH with jet cutter and CCL. RIH and tag 2-7/8" tubing stub at 3711' WLM, Locate 5-1/2" coupling at 3689' and jet cut 5- 1/2" liner at 3700' WLM. POOH and R/D E-Line equipment.;R/U casers and equipment to pull 5-1/2" liner. P/U landing joint and pull pack-off as per wellhead tech, Pull hanger to floor with 150K to unseat hanger and 100K P/U guiding hanger through bope stack.;R/U and circulate well clean with 400 GPM and SPP of 550psi. Flow check well: Static, Blow down top drive, P/U 80K, S/O 80K.;POOH laying down 5 1/2" casing from 3700' to surface (89 jts, 10'cut jt.) recovered 5 bow spring and 17 solid centralizers.;R/D casing equipment, clean and clear rig floor, Change out bell nipple on stack.;M/U running tool and set 9" ID wear bushing.;Load BHA on rig floor, strap and tally DP.;M/U scraper BHA.;TIH picking up DP with Scraper BHA F/ surface T/3704' - worked thru tight spots from 3650 ' to 3704'. P/U 77K, S/O 72K.;CBU 400gpm@ 390 psi. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: BCU-014B Beaver Creek Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:221-00074 BCU-14B Drilling Spud Date: 10/18/2022 Flowcheck well, Static POOH with 9-5/8" scraper assembly F/ 3704' T/ 40' P/U 77K, S/O 72K.;Iron Rough Neck Ram Leaking, Change ram.;Service rig and top drive, grease crown and draw works.;RIH P/U 4.5'' DP f/ 40' t/ 2544' POOH standing Back DP in Derrick t/ Surface, P/U 18 jts of HWDP and Rack back in the derrick.;Spot in yellow Jacket Eline truck and rig up, RIH w/ CIBP t/ 3704' set down log up find collar @ 3668' set CIBP @ 3663' WLM POOH R/D Eline.;R/U and Test Casing t/ 3000 psi f/ 10 min 3.3 bbls pumped 2.8 bbls bled back.;Pull wear ring and set test plug. Open LPR's and change rams to 7". Measure test jt. X/O and check clearance on rams. X/O to long for ram closure.;Service top drive, blocks crown, draw works, and iron roughneck.;Wait on new test jt. - perform derrick inspection, clean choke house, Prep whipstock BHA.;R/U 7" test jt. and equipment. Pressure test to 3000 high/ 250 low. Test failed. Fluid leaking out of Mud seal weep hole.;Change out mud seals on LPR.;R/U 7" test jt and test equipment. Pressure test LPR to 250psi/5 min and 3000psi /10 min. R/D test equipment. pull test plug and set wear bushing.;PJSM, P/U and M/U whipstock BHA. 10/19/2022 M/U Whipstock BHA as per DD/MWD and WIS rep Shallow test MWD, M/U Slide RIH t/ 3630'.;Displace well w/ 6 % KCL Polymer mud system Orient slide 30 right of High side.;Set down on CIBP trip anchor, Shear bolt w/ 29k down weight TOW 3632' BOW 3646' Mill window and 20' of new hole to 3667'. Top of window @ 3632', bottom of window @ 3647' 400 gpm 80 rpm 3-5k WOB 880 psi, P/U 87K, S/O 85K. 204lbs total metal recovered.;Circulate and condition while working thru window multiple times (2xCBU). Shut down pumps and rotation and work thru window with no drag. MW in 9.0, MW out 9.0.;R/U and perform FIT - 9.0 ppg mud. TVD - 3576', test pressure 580 psi. EMW = 12.1. Volume pumped 27.4 gal, Volume returned 23.5 gal. R.D test equipment and blow down choke/kill/ top drive. flow check well - static.;POOH F/ 3667 T/ surface. L/D BHA. upper mill 1/16", mid mid 1/8", lower mill 1/8" under gauge.;Clean and clear rig floor, flush Stack and prep drilling BHA.;Grease and check oils on rig equipment, clean suction screens on mud pumps.;P/U drilling BHA and trip in hole T/1500'.;Hauled: 1 bbl Solids to KGF G&I Cumulative: 27 bbl Hauled: 374 bbl Fluid to KGF G&I Cumulative: 608 bbl 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Monday, November 7, 2022 4:27 PM To:Jay Murphy - (C) Cc:Regg, James B (OGC) Subject:RE: Hilcorp 169 10-16-22 Attachments:Hilcorp 169 10-16-22 Revised.xlsx Jay, I’ve attached a revised report adding 5 to the Number of Failures based on the “FPs” and remarks. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Jay Murphy ‐ (C) <Jay.Murphy@hilcorp.com> Sent: Monday, October 17, 2022 9:12 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: Hilcorp 169 10‐16‐22 Thank You and Best Regards, Jay Murphy/ DSM Hilcorp Alaska, LLC HAK Rig 169 Office: 907‐283‐1369 Cell: 907‐715‐9211 Jay.Murphy@Hilcorp.com 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. Beaver Creek Unit 14A PTD 2131960 2 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:169 DATE:10/16/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2131960 Sundry #322-547 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1834 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8'' X 5'' P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8''P Time/Pressure Test Result HCR Valves 2 3 1/8'' & 2 1/16''P System Pressure (psi)3050 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1700 P Check Valve 0 NA 200 psi Attained (sec)19 P BOP Misc 0 NA Full Pressure Attained (sec)80 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4@2450 P No. Valves 15 FP ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 FP Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:5 Test Time:5.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/15/22 08:04am Waived By Test Start Date/Time:10/16/2022 10:30 (date)(time)Witness Test Finish Date/Time:10/16/2022 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Test with 2-7/8'' test jt, Quadco tested all gas alarms, 15 Accumulator bottles @ 1050 psi. Test #4 FP on low pressure was bleeding off. Bled down greased and functioned CMV 1, 2, 3 & 15. Retest Good test. Test #7 FP, Attempting to pressure up on electric choke and could not build pressure. Re-clocked the choke actuator to fully close choke. Retest was good. Test was witnessed with BLM representative Quinn Sawyer. Trick/ Deshotel Hilcorp Murphy/ Menapace BCU-14A Test Pressure (psi): strick@hilcorp.com Jay.Murphy@hilcorp.com Form 10-424 (Revised 08/2022)2022-1016_BOP_Hilcorp169_BCU-14A Alaska LLC            J. Regg; 11/22/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Hilcorp 169 Date:Tuesday, November 22, 2022 2:08:25 PM Attachments:2022-1016_BOP_Hilcorp169_BCU-14A.pdf Beaver Creek Unit 14A (PTD 2131960) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Donna Ambruz Subject:RE: BCU-14A(PTD#213-196) Plug for Redrill Date:Friday, September 23, 2022 4:35:00 PM Ryan, Hilcorp has approval to proceed with this plan. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Friday, September 23, 2022 2:48 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BCU-14A(PTD#213-196) Plug for Redrill Bryan- Now that we have shot additional perfs on BCU-14A(PTD#213-196) the approved plug for redrill sundry (#322-317) changes slightly. I’m also planning on additional cement for additional safety factor. Just a heads up. Circ in 26 bbls balanced plug (ToC to 4200’ now) Then downsqueeze 4bbls additional to fill in below perfs at 5501’. (so 30bbls job total) Sidetrack KOP is planned for 3915’ MD, FYI Please let me know if there are any issues with this approach. Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward 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. Updated by DMA 09-23-22 SCHEMATIC BCU-14A Pad 1A PTD: 213-196 API: 50-133-20539-01-00 PBTD = 5,680’ / TVD = 5,260’ TD = 9,450’ / TVD = 8,870’ RKB to GL = 18.6’ PERFORATION DETAIL Sand TOP MD BTM MD TOP TVD BTM TVD FT Date Status B3B 5,501’ 5,506’ 5,095’ 5,099’ 5 9/22/22 Open B5 5,624’ 5,628’ 5,200’ 5,204’ 4 10/29/20 Open B5 5,663’ 5,668’ 5,235’ 5,240’ 5 8/23/20 Open B6 5,684’ 5,694’ 5,254’ 5,263’ 10 5/18/15 Isolated UBC-3 6,550’ 6,560’ 6,060’ 6,069’ 10 11/26/14 Isolated LB-27 8,477’ 8,497’ 7,905’ 7,925’ 20 5/23/14 Isolated LB-28 8,543’ 8,560’ 7,970’ 7,987’ 17 5/15/14 Isolated LB-28B 8,715’ 8,731’ 8,140’ 8,156’ 16 3/28/14 Isolated LB-30 8,868’ 8,882’ 8,292’ 8,306’ 14 3/17/14 Isolated OPEN HOLE / CEMENT DETAIL 13-3/8” 16” Hole: 265bbls of 10ppg cement pumped. Got 15bbls cement back to surface 9-5/8” 12-1/4” hole: cemented with 377bbls 12.5ppg lead class G followed by 106 bbls 15.8ppg tail (from 7594’ MD). Got 25bbls cement back to surface. 5-1/2” 8-1/2” hole: 9.6ppg mud in hole pre-cement. 34bbls 12.5ppg mud push ahead of job. Cemented with 232bbls 15.3ppg class G. 2/17/14 CBL show’s ToC at 3990’ MD. 3/3/14 USIT shows free pipe above 3940’ MD 750’ of 12.5 ppg Mud Push 9.6 ppg Mud CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 133 K-55 18.73” Surf 145' 13-3/8" Surf Casing 68 K-55 BTC 12.415” Surf 2122 9-5/8” Int Casing 40 L-80 BTC 8.835” Surf 5081 5-1/2” Prod Casing 20 P-110 XP BTC 4.778” Surf 9419 2-7/8” Velocity String 6.5 L-80 EUE 2.441” Surf 5606 9-5/8” KOP at ~5100’ MD 5-1/2” JEWELRY DETAIL No. Depth (MD) ID Item 1 4857 4.778” Swell Packer 2 5680 CIBP (8/23/20) 3 6475 CIBP with 44’ cement 4 8270 CIBP with 35’ cement 5 8530 CIBP 6 8610 CIBP 7 8852 CIBP with 25’ cement 13-3/8” 1 2 3 4 5 6 7 3/3/14 USIT shows free pipe above 3970’ MD By Samantha Carlisle at 8:16 am, Sep 26, 2022 7\SHRI5HTXHVW$EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHUBBBBBBBBBBBBBBBBBBB 2SHUDWRU1DPH&XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Velocity String Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,450 feet 5,680'; 6,475' feet true vertical 8,870 feet N/A feet Effective Depth measured 5,680 feet 4,857 feet true vertical 5,250 feet 4,556 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)V-String 2-7/8" 6.5# / L-80 5,506' MD 5,185' TVD Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 4,857' MD 4,556' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 12,640psi 144' 2,121' 5,750psi 3,450psi Collapse 1,050psi 1,950psi 3,090psi 11,080psi Casing Structural 20" 13-3/8" 9-5/8" Length 144' 2,121' 5,081' 9,450' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,478 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-437 147 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 213-196 50-133-20539-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 319380 Beaver Creek Unit (BCU) 14A N/A FEDA 028083 5,081' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Sterling Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5-1/2"9,450' 4,744' 8,870' WINJ WAG 1,196 Water-Bbl MD 144' 2,121' 203 t Fra O 6. A G L PG , R g Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 9:08 am, Oct 01, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.10.01 09:00:26 -08'00' Taylor Wellman (2143) RBDMS HEW 10/1/2021 BJM 11/8/21 Beluga Gas Pool DSR-10/5/21 SFD 10/5/2021 SFD 10/5/2021 Rig Start Date End Date 9/3/21 9/6/21 09/03/2021- Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-133-20539-01-00 213-296 Well Name BCU-14A Safety meeting with crew, emphasis on hazards from tongs, opening up to well. Open to well, 0 psi, took 3 bbls to fill. RIH with 2-7/8" 6.5# L-80 EUE pipe from 630' to 5,606'. MU tubing hanger with pup to string, land out and ROLDS. Install TWC,. Clear rig floor of all handling equipment. Remove rig floor, stairs. ND BOP, disconnect and store hydraulic hoses, begin loading trailers and organizing equipment for move. NU Seaboard 11" tree, test flange to 5k psi, good test. RU to fill tree, fill and test to 5k, good test. Assist production team in rigging up flow line equipment. Open to well, on slight vac. Secure location for evening. 09/04/2021 - Saturday PJSM on staging equipment, rigging up, emphasis on opening to well. Open up and bleed off residual pressure. Rig down flow line. Lay out felt and herculite, begin RU ops. Stage in all equipment, lay out monitoring equipment, install circulation hose to Wing Valve. Begin filling well with 8.34 ppg produced water while continuing to rig up. Monitor well, no pressure. Install BPV. ND tree in separate components. NU new tubing spool for 2-7/8" string, test flange to 5k psi, good test. Stage in BOP and begin NU. Well secure with 2 BPVs. Secure location for evening. 09/06/2021 - Monday PJSM with crew, emphasis on moving equipment around, wearing protection while powerwashing and cleaning Carrier. Trucks on location, rig down and put away hoses and gas monitoring devices, move out pits and Accumulator. Scope down and lower Derrick. Powerwash Carrier in prep for painting and welding. Release from well, turn over to Production. Safety Meeting with crew, emphasis on hand placement while torquing BOP, pressure during BOP test, loader ops. Torque BOP bolts while staging in rig floor, stairs, laying pipe out for strapping. Install rig floor, stairs, prep 2-7/8" test joint. Test BOP per Sundry and AOGCC requirements. 13-5/8" Annular, 2-7/8" x 5" Variable rams, Blind Rams, Mud Cross. Test ram and Annular to 250 psi low / 2,500 psi high. Test gas alarms, function PVT monitors. Conduct Accumulator drawdown test. Witness waived by AOGCC rep Jim Regg. Pull test plug and upper BPV. Close Blinds, roll pump, slight pressure under second BPV. Screw in with rod one turn, allow to bleed (migrated gas from kill previous day). Pull BPV with no issues. Prep for running in with tubing while pulling BPVs. Complete prep for handling equipment. RIH with 2-7/8" 6.5# L-80 EUE tubing to 630'. Hang off for evening, secure location. 09/05/2021 - Sunday NU Seaboard 11" tree, test flange to 5k psi, good tes Test ram and Annular to 250 psi low / 2,500 psi high. RIH with 2-7/8" 6.5# L-80 EUE tubing to 630'. RIH with 2-7/8" 6.5# L-80 EUE pipe from 630' to 5,606'. M NU new tubing spool for 2-7/8" string, test flange to 5k psi, good test. S Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 141' 18.6' 9/7/2021 9/7/2021Revised By:JMF Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,081'Maximum Deviation:36.5º @ 3,713' Date Completed:2/6/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #14A A - 028083 County or Parish:Kenai Peninsula Borough BC-14A Pad 1A 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M.Permit #: 213-196 API #: 50-133-20539-01-00 Property Des: A-028083 KB Elevation: 159.6' (18.6' AGL) Lat:N60°38' 51.1588' Long:W151°2' 45.491" Spud Date: 01/24/14 Rig Released: 02/09/14 Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore PBTD 5,680' MD 5,260' TVD TD 9,450' MD 8,870' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 145' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,122' TVD 0' 2,122' 16" hole Cmt w/ 568 sks (254 bbl) of Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TVD 0' 4,744' 12-1/4" hole Cmt w/ 377 sks (141 bbls) of 12.5 ppg Tail & 510 sks (106 bbls) of 13.5 Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2" hole Cmt w/ 972 sks ( 232 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK SCHEMATIC Swell Packer @ 4,857'-4,879' MD TOC (3/03/14 USIT) - 4,725' Max Dogleg: 4.86°/100' @ 3,650' Openhole Casing 31' off bottom Max Inclination: 36.5°@ 3,713' Casing Shoe @ 9,419' Perforations: Zone MD TVD Size SPF Date B5 5,624'-5,628' 5,200'-5,204' 2-7/8" 6 10/29/20 B5 5,663'- 5,668' 5,235'-5,240 2-7/8" 6 8/23/20 B6 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/15 UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 8852' CIBP w 25' cmt 8530' CIBP 8270' CIBP w/ 35' of cmt 5,680' CIBP (8/23/2020) 6,475' CIBP w/ 44' cmt B5 B5 Velocity String (installed 9/5/21) 2.875" 6.5# EUE tubing Set @ 5606' MD 8610' CIBP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Run tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2-7/8" v-string 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,450'N/A Casing Collapse Structural Conductor 1,050 psi Surface 1,950 psi Intermediate 3,090 psi Production 11,080 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 12-Sep-21 N/A 9,450' Perforation Depth MD (ft): 5,081' See Attached Schematic 9,450' 8,870'5-1/2" 20" 13-3/8" 144' 9-5/8"5,081' 2,121' 3,060 psi 3,450 psi 144' 2,121' 4,744' 144' 2,121' N/A TVD Burst N/A 12,640 psi MD 5,750 psi Length Size CO 237A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 213-196 50-133-20539-01-00 Beaver Creek Unit (BCU) 14A Beaver Creek / Sterling Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 8,870'9,335'8,756'977 psi 5,680; 6,475 Swell Packer; N/A 4,857' MD / 4,556' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:58 am, Aug 30, 2021 321-437 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.30 09:40:36 -08'00' Taylor Wellman (2143) SFD 8/30/2021 DSR-8/30/21SFD 8/30/2021 CO 237B BJM 9/1/21 X BOP test to 2500 psi, Annular test to 2000 psi. 10-404 dts 9/1/2021 JLC 9/1/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.01 17:52:20 -08'00' RBDMS HEW 9/2/2021 Well Prognosis Well: BCU-14A Date: 08/27/2020 Well Name: BCU-14A API Number: 50-133-20539-01-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 9/12/21 Rig: 401 Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Jake Flora (907) 777-8442 (O)(720)988-5375 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O)(985)632-4113 (C) AFE Number: Current Bottom Hole Pressure: ~1500 psi @ 5,235’ TVD (5,663’ MD) Based on actual reservoir conditions. Max. Potential Surface Pressure: 977 psi (Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4)) Well Status BCU-14A is an online Sterling gas producer making 1.2 MMCFD @ 320psi and 600 bwpd. Brief Well Summary BCU-14A drilled and completed in 2014 targeting the lower Beluga and Sterling formations. This well was completed as a 5-1/2” monobore to surface. In Aug. 2020, the well was cleaned out with coil and the B6 sand was isolated. 5’ of the lower Sterling B5 was perforated. Pressure built up to 1675 psi and came online making 7.5 MMCFD. The well started to load with water and has had a sharp decline, and on Oct. 29 th 2020, the 2nd lobe of the B5 sand was perforated bringing the total rate up to 9.4 MMCFD @ 650 psi. The well has been on a significant decline since and is currently making about 1.5 MMCFD and making 500-600 bwpd – loading up. This has become operationally intensive and is currently being soaped every 45 min the last several weeks. Since BCU-14A has cum’d 950 MMCF to date from the Sterling B5. The purpose of this work/sundry is to add a 2-7/8” velocity string to the well to flatten the decline and increase rate. Notes Regarding Wellbore Condition x Minimum ID is 4.992” x Last Tag: RIH w/ 3” DD Bailer to 5,686’ KB on 10/13/2020. x *CIBP set @ 5,680’MD on 8/23/20 Procedure: 1. MIRU 401. 2. Notify AOGCC 24hrs in advance of BOP test. 3. Bullhead tubing with water, Set BPV, ND Tree. 4. NU tubing head for 2-7/8 tubing. 5. NU BOP and test to 250 psi low & 2,500 psi high, annular to 250 psi low & 2,000 psi high. Record accumulator pre-charge pressures and chart tests. a. Perform Test. b. Test rams on 2-7/8” test joint. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 6. Pull BPV Pull using a lubricator pressure tested to at least 1000 psi in case gas has swapped out with water. - bjm 6a. Fill hole with Kill Weight fluid or Bullhead tubing volume if fluid level cannot be maintained at surface. Well Prognosis Well: BCU-14A Date: 08/27/2020 7. Run 2-7/8” tubing to ~5600’. 8. Set TWC. 9. NU BOP, NU Tree, test. 10. Pull TWC. 11. RU slickline, PT lubricator, swab to kick well off. 12. Turn well over to production. Attachments 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Schematic 4. Proposed Wellhead Schematic 5. Rig 401 BOP Diagram 6. Nitrogen SOP Monitor fluid level and fill hole as needed to maintain overbalance. Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 141' 18.6' 5/18/2015 11/9/2020Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,081'Maximum Deviation:36.5º @ 3,713' Date Completed:2/6/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #14A A - 028083 County or Parish:Kenai Peninsula Borough BC-14A Pad 1A 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M.Permit #: 213-196 API #: 50-133-20539-01-00 Property Des: A-028083 KB Elevation: 159.6' (18.6' AGL) Lat:N60°38' 51.1588' Long:W151°2' 45.491" Spud Date: 01/24/14 Rig Released: 02/09/14 Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore PBTD 5,680' MD 5,260' TVD TD 9,450' MD 8,870' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 145' TVD 0' 145' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,122' TVD 0' 2,122' 16" hole Cmt w/ 568 sks (254 bbl) of 12.0 ppg, Class G cmt Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TVD 0' 4,744' 12-1/4" hole Cmt w/ 377 sks (141 bbls) of 12.5 ppg Tail & 510 sks (106 bbls) of 13.5 ppg Lead Class G cmt Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2" hole Cmt w/ 972 sks ( 232 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK SCHEMATIC Swell Packer @ 4,857'-4,879' MD TOC (3/03/14 USIT) - 4,725' Max Dogleg: 4.86°/100' @ 3,650' Openhole Casing 31' off bottom Tag (sand) @ 8,658' TPM w/ 4.625" Bit (5/11/14) Max Inclination: 36.5°@ 3,713' Casing Shoe @ 9,419' Casing/Cementing Detail - 9.6 ppg Mud - 12.5 ppg Mud Push (34 bbl) - 15.3 ppg Cement (232 bbl) - 8.4 ppg Lease Water (200 bbl) LB-30 Perforations: Zone MD TVD Size SPF Date B5 5,624'-5,628' 5,200'-5,204' 2-7/8" 6 10/29/20 B5 5,663'- 5,668' 5,235'-5,240 2-7/8" 6 8/23/20 B6 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/15 UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Fluid Level 8.4 ppg Lease Water @ 9,000' CTM Short Marker Joints @ 7,901'-7,916' MD @ 8,906'-8,921' MD Cement top @ 8,836' MD Plug @ 8,852' MD LB-28B Plug @ 8,610' ELM LB-28 LB-27 Tag (sand) @ 8,305' SLM w/ 2.00" Bailer (8/30/14) Plug @ 8,530' ELM Plug @ 8,270' ELM capped w/ 35' of cement UBC-3 Tag @ 8,264' SLM w/ 4.67" GR (4/30/15) B6 Plug @ 6,475' capped w/ 44' cmt CIBP @ 5,680' 8/23/2020 B5 B5 Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 141' 18.6' 5/18/2015 8/23/2021 Well Name & Number:Beaver Creek Unit #14A A - 028083 County or Parish:Kenai Peninsula Borough Revised By:JMF Downhole Revision Date: Schematic Revision Date: Angle @KOP and Depth:34º @ 5,081'Maximum Deviation:36.5º @ 3,713' Date Completed:2/6/2014 Ground Level (above MSL): RKB (above GL): BC-14A Pad 1A 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M.Permit #: 213-196 API #: 50-133-20539-01-00 Property Des: A-028083 KB Elevation: 159.6' (18.6' AGL) Lat:N60° 38' 51.1588' Long:W151° 2' 45.491" Spud Date: 01/24/14 Rig Released: 02/09/14 Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore PBTD 5,680' MD 5,260' TVD TD 9,450' MD 8,870' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 145' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,122' TVD 0' 2,122' 16" hole Cmt w/ 568 sks (254 bbl) of Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TVD 0' 4,744' 12-1/4" hole Cmt w/ 377 sks (141 bbls) of 12.5 ppg Tail & 510 sks (106 bbls) of 13.5 Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2" hole Cmt w/ 972 sks ( 232 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK PROPOSED Swell Packer @ 4,857'-4,879' MD TOC (3/03/14 USIT) - 4,725' Max Dogleg: 4.86°/100' @ 3,650' Openhole Casing 31' off bottom Max Inclination: 36.5° @ 3,713' Casing Shoe @ 9,419' Perforations: Zone MD TVD Size SPF Date B5 5,624'-5,628' 5,200'-5,204' 2-7/8" 6 10/29/20 B5 5,663'- 5,668' 5,235'-5,240 2-7/8" 6 8/23/20 B6 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/15 UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 8852' CIBP w 25' cmt 8530' CIBP 8270' CIBP w/ 35' of cmt 5,680' CIBP (8/23/2020) 6,475' CIBP w/ 44' cmt B5 B5 Velocity String 2.875" 9.3# EUE tubing Set EOT @ ~5600' 8610' CIBP Beaver Creek BC # 14RD Current 08/28/2021 20'’ 13 3/8'’ 9.625'’ Starting head, Vetco MB-196, 13 5/8 3M X 13 3/8 VG-Loc bottom, w/ 2- 2'’ LPO Multibowl, Vetco MB-196, 13 5/8 3M stdd bottom X 13 5/8 5M FE top, w/ 2- 2 1/16 5M SSO Valve, VG-200, 2 1/16 5M FE, HWO, AA trim Valve, Master, CIW-FC, 5 1/8 10M FE, HWO, EE trim Valve, Upper Master, WKM-M, 5 1/8 5M FE, HWO, DD trim Valve, Swab, WKM-M, 5 1/8 5M FE, HWO, DD trim Valve, Wing, WKM-M, 3 1/8 5M FE, HWO, DD trim Tree cap, Otis, 5 1/8 5M FE X 9 ½ Otis Quick Union Beaver Creek BC # 14 20 X 13 3/8 X 9 5/8 X 5 ½ Grade Level Completion spool, Cactus, 13 5/8 5M X 11 5M Tubing hanger, CXS, 11 X 5 ¾ left hand stub acme lift X 5 ½ DWC-C susp, w/ 5'’ Type H BPV profile 5 ½’’ Crossover spool, 5 1/8 5M FE X 5 1/8 10M FE Beaver Creek BC # 14RD Proposed 08/28/2021 20'’ 13 3/8'’ 9.625'’ Starting head, Vetco MB-196, 13 5/8 3M X 13 3/8 VG-Loc bottom, w/ 2- 2'’ LPO Multibowl, Vetco MB-196, 13 5/8 3M stdd bottom X 13 5/8 5M FE top, w/ 2- 2 1/16 5M SSO Valve, VG-200, 2 1/16 5M FE, HWO, AA trim Beaver Creek BC # 14 20 X 13 3/8 X 9 5/8 X 5 ½ x 2 7/8 or 2 3/8 Grade Level Completion spool, Cactus, 13 5/8 5M X 11 5M Tubing hanger, CXS, 11 X 5 ¾ left hand stub acme lift X 5 ½ DWC-C susp, w/ 5'’ Type H BPV profile 5 ½’’ Valve, Master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Upper master, CIW-FLS, 3 1/8 5M FE, HWO, EE trim Valve, Swab, CIW-FLS 3 1/8 5M FE, HWO, EE trim Valve, Wing, CIW-FC, 3 1/8 5M FE, HWO, EE trim BHTA, Otis, 3 1/8 5M FE x 6.5 Otis quick union top Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator Tubing hanger, Cactus-EN- CL, 7 x 3 ½’’ EUE 8rd lift and susp, w/ 3 type H BPV profile, 1- ¼npt control line port Adapter, Cactus-EN, 7 1/16 5M Stdd x 3 1/8 5M prepped for 5 ½ extended neck hanger Optional 2 1/16 5M SSV for Velocity stringTubing head, Cactus, 11 5M x 7 1/16 5M, w/ 2- 2 1/16 5M SSO, 9 ½ BG bottom 2 7/8 or 2 3/8 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. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564- 4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Log Vendor BCU 05RD2 501332026202 218068 2/5/2021 PERF GAMMA RAY Yellowjacket BCU 05RD2 501332026202 218068 3/5/2021 PERF GAMMA RAY Yellowjacket BCU 11 501332052100 203025 6/12/2021 PERF Yellowjacket BCU 11 501332052100 203025 6/12/2021 RCBL Yellowjacket BCU 14A 501332053901 213196 6/14/2021 GPT Yellowjacket BCU 19RD 501332057901 219188 1/13/2021 PERF GAMMA RAY Yellowjacket BCU-19RD 501332057901 219188 4/24/2020 CALIPER Yellowjacket BCU-19RD 501332057901 219188 5/18/2020 PERF GAMMA RAY/GPT Yellowjacket Please include current contact information if different from above. 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WZKWK^ ^,Dd/ 6ZHOO3DFNHU# 0' 72&86,7 0D['RJOHJ # 2SHQKROH &DVLQJ RIIERWWRP 7DJVDQG# 730 Z%LW 0D[,QFOLQDWLRQ # &DVLQJ6KRH# &DVLQJ&HPHQWLQJ'HWDLO SSJ0XG SSJ0XG3XVKEEO SSJ&HPHQWEEO SSJ/HDVH:DWHUEEO /% 3HUIRUDWLRQV =RQH0'79'6L]H63)'DWH % % % 8%& /% /% /%% /% )OXLG/HYHO SSJ/HDVH:DWHU # &70 6KRUW0DUNHU-RLQWV # 0' # 0' &HPHQWWRS# 0' 3OXJ# 0'/%% 3OXJ# (/0 /% /% 7DJVDQG# 6/0 Z%DLOHU 3OXJ# (/0 3OXJ# (/0 FDSSHGZ RIFHPHQW 8%& % 3OXJ# FDSSHGZ FPW &,%3# % % ĂƉŝůůĂƌǇ^ƚƌŝŶŐǆͬǆͬϮϭ ϯͬϴΗ ϮϮϬϱ^ƚĂŝŶůĞƐƐ^ƚĞĞů;ϲϬϬϬ͛ƐƉŽŽůͿ /ŶƐƚĂůůĞĚĂƚϱ͕ϱϳϱ͛ 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,450 feet 5,680'; 6,475' feet true vertical 8,870 feet N/A feet Effective Depth measured 5,680 feet 4,857 feet true vertical 5,250 feet 4,556 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 4,857' MD 4,556' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 12,640psi 144' 2,121' 5,750psi 3,450psi Collapse 1,050psi 1,950psi 3,090psi 11,080psi Casing Structural 20" 13-3/8" 9-5/8" Length 144' 2,121' 5,081' 9,450' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 7,243 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-435 1,197 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 213-196 50-133-20539-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 200 Beaver Creek Unit (BCU) 14A N/A FEDA 028083 5,081' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Sterling Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5-1/2"9,450' 4,744' 8,870' WINJ WAG 0 Water-Bbl MD 144' 2,121' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:28 pm, Nov 18, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.18 13:39:07 -09'00' Taylor Wellman gls 11/23/20 DSR-11/19/2020 RBDMS HEW 11/20/2020 Perforate SFD 11/24/2020 Rig Start Date End Date E-Line 10/29/20 10/29/20 10/29/2020 - Thursday Sign in. Mobe to locatiom. PTW and JSA. Spot and rig up lubricator. PT lubricator to 250 psi low and 2,500 psi high. Well flowing 1,5 mil/350 psi. RIH w/ 2-7/8" x 4' HC Razor, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Town said to subtract 3'. Subtract 3' and spotted gun from 5,624' to 5,628' well flow 1.5 mil/350 psi. Fired gun and lost about 100 lb of line wt. but got it right back. After 5 min - 4.5 mil/890 psi, 10 min - 4 mil/1,275 psi with choke at 20% and 15 min - 3.7 mil/1,363 psi with choke down to 15%. POOH. All shots fired and gun was wet. Rig down lubricator and equipment. Turn well over to field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-133-20539-01-00 213-296 Well Name BCU-14A Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 141' 18.6' 5/18/2015 11/9/2020Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,081'Maximum Deviation:36.5º @ 3,713' Date Completed:2/6/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #14A A - 028083 County or Parish:Kenai Peninsula Borough BC-14A Pad 1A 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M.Permit #: 213-196 API #: 50-133-20539-01-00 Property Des: A-028083 KB Elevation: 159.6' (18.6' AGL) Lat:N60°38' 51.1588' Long:W151°2' 45.491" Spud Date: 01/24/14 Rig Released: 02/09/14 Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore PBTD 5,680' MD 5,260' TVD TD 9,450' MD 8,870' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 145' TVD 0' 145' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,122' TVD 0' 2,122' 16" hole Cmt w/ 568 sks (254 bbl) of 12.0 ppg, Class G cmt Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TVD 0' 4,744' 12-1/4" hole Cmt w/ 377 sks (141 bbls) of 12.5 ppg Tail & 510 sks (106 bbls) of 13.5 ppg Lead Class G cmt Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2" hole Cmt w/ 972 sks ( 232 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK SCHEMATIC Swell Packer @ 4,857'-4,879' MD TOC (3/03/14 USIT) - 4,725' Max Dogleg: 4.86°/100' @ 3,650' Openhole Casing 31' off bottom Tag (sand) @ 8,658' TPM w/ 4.625" Bit (5/11/14) Max Inclination: 36.5°@ 3,713' Casing Shoe @ 9,419' Casing/Cementing Detail - 9.6 ppg Mud - 12.5 ppg Mud Push (34 bbl) - 15.3 ppg Cement (232 bbl) - 8.4 ppg Lease Water (200 bbl) LB-30 Perforations: Zone MD TVD Size SPF Date B5 5,624'-5,628' 5,200'-5,204' 2-7/8" 6 10/29/20 B5 5,663'- 5,668' 5,235'-5,240 2-7/8" 6 8/23/20 B6 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/15 UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Fluid Level 8.4 ppg Lease Water @ 9,000' CTM Short Marker Joints @ 7,901'-7,916' MD @ 8,906'-8,921' MD Cement top @ 8,836' MD Plug @ 8,852' MD LB-28B Plug @ 8,610' ELM LB-28 LB-27 Tag (sand) @ 8,305' SLM w/ 2.00" Bailer (8/30/14) Plug @ 8,530' ELM Plug @ 8,270' ELM capped w/ 35' of cement UBC-3 Tag @ 8,264' SLM w/ 4.67" GR (4/30/15) B6 Plug @ 6,475' capped w/ 44' cmt CIBP @ 5,680' 8/23/2020 B5 B5 9 5/8" @ 5081 ft B5 10/29/20B5 5,624'-5,628' 5,200'-5,204' 2-7/8" 6 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,450'N/A Casing Collapse Structural Conductor 1,050 psi Surface 1,950 psi Intermediate 3,090 psi Production 11,080 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng tkramer@hilcorp.com 8,870'9,335'8,756'1,755 5,680; 6,475 Swell Packer; N/A 4,857' MD / 4,556' TVD; N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028083 213-196 50-133-20539-01-00 Beaver Creek Unit (BCU) 14A Beaver Creek / Sterling Gas Pool Length Size CO 237A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 12,640 psi MD 5,750 psi 3,060 psi 3,450 psi 144' 2,121' 4,744' 144' 2,121' 8,870'5-1/2" 20" 13-3/8" 144' 9-5/8"5,081' 2,121' 9,450' Perforation Depth MD (ft): 5,081' See Attached Schematic 9,450' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 24-Oct-20 N/A m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:36 am, Oct 12, 2020 320-435 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.10.12 07:25:06 -08'00' Taylor Wellman GAS 10-404 SFD 10/12/2020 DSR-10/12/2020gls 10/13/20 CO 237B Perforate SFD 10/12/2020 Comm 10/13/2020 dts 10/13/2020 JLC 10/13/2020 RBDMS HEW 11/12/2020 Well Prognosis Well: BCU-14A Date: 10/9/2020 Well Name: BCU-14A API Number: 50-133-20539-01-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: October 24th, 2020 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (985) 632-4113 (C) AFE Number: Max. Expected BHP: ~ 2,275 psi @ 5,204’ TVD (Based on .437 gradient) Max. Potential Surface Pressure: ~ 1,755 psi (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) Brief Well Summary BCU-14A was drilled as a sidetrack in early 2014 to target the Sterling and Lower Beluga gas sands. This well was completed as a 5-1/2” monobore to surface. The initial zone (LB-30) was perforated and tested and showed poor performance. The 2nd zone (LB-28B) was perforated and sanded up on initial tests and failed to produce after a coil tubing cleanout. The 3rd zone (LB-28) was perforated and failed to produce. No fill and minimal water was seen from this zone. The 4th zone (LB-27) was perforated and shown to be productive. However, water from the LB-28 is contributing to downhole hydrate formation. The well sanded off and was cleaned out with coiled tubing. However, this zone sanded up again. The LB-27 was plugged back and the Upper Beluga C-3 was added in November 2014. However, this zone came in wet and was unproductive. In May 2015, one more attempt to produce the well by plugging back Beluga and perforating the Sterling B6 (previously named B4) sand. It came online making 2-3 MMCFD and within the month began to make water and by October the well was making over 1000 BWPD and loaded up and died. Multiple unsuccessful attempts to swab the water and bring back online have been made. In August of 2020 the well was plugged back and the lower B5 sand was perforated in the well. The well came on line at over 7 MMscfd and 100 bwpd. Water rate has since increased and the gas rate dropped off to between 3 MM and 2.4 MMscfd. The purpose of this work/sundry is to add the upper lobe of the B5 sand to bring in more gas to help lift the water and keep the well unloaded. Notes Regarding Wellbore Condition x Minimum ID is 4.992” Safety Concerns x Ensure all crews are aware of stop job authority. The 4th zone (LB-27) was perforated and shown to be productive. The purpose of this work/sundry is to add the upper lobe of the B5 sand to bring in more gas to help lift the water and keep the well unloaded. Well Prognosis Well: BCU-14A Date: 10/9/2020 E-Line Procedure 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 2. PU perf gun. RIH and perforate the following interval: Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Sterling B5 +5,624’ +5,628' +5,200' +5,204' 4' a. Proposed perfs also shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. d. Use Gamma/CCL to correlate. e. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Sterling Gas Pool based on Conservation Order No. 237A. E-line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 3. RIH and set 5-1/2” Casing Patch or set 5-1/2” CIBP above the zone. Attachments 1. Current Well Schematic 2. Proposed Well Schematic Sterling B5 +5,624’+5,628'+5,200'+5,204'4' Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 141' 18.6' 5/18/2015 9/10/2020 Well Name & Number:Beaver Creek Unit #14A A - 028083 County or Parish:Kenai Peninsula Borough Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,081'Maximum Deviation:36.5º @ 3,713' Date Completed:2/6/2014 Ground Level (above MSL):RKB (above GL): BC-14A Pad 1A 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M.Permit #: 213-196 API #: 50-133-20539-01-00 Property Des: A-028083 KB Elevation: 159.6' (18.6' AGL) Lat:N60°38' 51.1588' Long:W151°2' 45.491" Spud Date: 01/24/14 Rig Released: 02/09/14 Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore PBTD 9,335' MD 8,756' TVD TD 9,450' MD 8,870' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 145' TVD 0' 145' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,122' TVD 0' 2,122' 16" hole Cmt w/ 568 sks (254 bbl) of 12.0 ppg, Class G cmt Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TVD 0' 4,744' 12-1/4" hole Cmt w/ 377 sks (141 bbls) of 12.5 ppg Tail & 510 sks (106 bbls) of 13.5 ppg Lead Class G cmt Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2" hole Cmt w/ 972 sks ( 232 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK SCHEMATIC Swell Packer @ 4,857'-4,879' MD TOC (3/03/14 USIT) - 4,725' Max Dogleg: 4.86°/100' @ 3,650' Openhole Casing 31' off bottom Tag (sand) @ 8,658' TPM w/ 4.625" Bit (5/11/14) Max Inclination: 36.5°@ 3,713' Casing Shoe @ 9,419' Casing/Cementing Detail - 9.6 ppg Mud - 12.5 ppg Mud Push (34 bbl) - 15.3 ppg Cement (232 bbl) - 8.4 ppg Lease Water (200 bbl) LB-30 Perforations: Zone MD TVD Size SPF Date B5 5,663'-5,668' 5,235'-5,240' 2-7/8" 6 8/23/20 B6 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/15 UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Fluid Level 8.4 ppg Lease Water @ 9,000' CTM Short Marker Joints @ 7,901'-7,916' MD @ 8,906'-8,921' MD Cement top @ 8,836' MD Plug @ 8,852' MD LB-28B Plug @ 8,610' ELM LB-28 LB-27 Tag (sand) @ 8,305' SLM w/ 2.00" Bailer (8/30/14) Plug @ 8,530' ELM Plug @ 8,270' ELM capped w/ 35' of cement UBC-3 Tag @ 8,264' SLM w/ 4.67" GR (4/30/15) B6 Plug @ 6,475' capped w/ 44' cmt CIBP @ 5,680' 8/23/20 B5 Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 141' 18.6' 5/18/2015 10/5/2020 Well Name & Number:Beaver Creek Unit #14A A - 028083 County or Parish:Kenai Peninsula Borough Revised By:Trudi Hallett Downhole Revision Date: Schematic Revision Date: Angle @KOP and Depth:34º @ 5,081'Maximum Deviation:36.5º @ 3,713' Date Completed:2/6/2014 Ground Level (above MSL): RKB (above GL): BC-14A Pad 1A 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M.Permit #: 213-196 API #: 50-133-20539-01-00 Property Des: A-028083 KB Elevation: 159.6' (18.6' AGL) Lat:N60° 38' 51.1588' Long:W151° 2' 45.491" Spud Date: 01/24/14 Rig Released: 02/09/14 Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore PBTD 9,335' MD 8,756' TVD TD 9,450' MD 8,870' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 145' TVD 0' 145' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,122' TVD 0' 2,122' 16" hole Cmt w/ 568 sks (254 bbl) of 12.0 ppg, Class G cmt Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TVD 0' 4,744' 12-1/4" hole Cmt w/ 377 sks (141 bbls) of 12.5 ppg Tail & 510 sks (106 bbls) of 13.5 ppg Lead Class G cmt Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2" hole Cmt w/ 972 sks ( 232 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK PROPOSED SCHEMATIC Swell Packer @ 4,857'-4,879' MD TOC (3/03/14 USIT) - 4,725' Max Dogleg: 4.86°/100' @ 3,650' Openhole Casing 31' off bottom Tag (sand) @ 8,658' TPM w/ 4.625" Bit (5/11/14) Max Inclination: 36.5° @ 3,713' Casing Shoe @ 9,419' Casing/Cementing Detail -9.6 ppg Mud - 12.5 ppg Mud Push (34 bbl) - 15.3 ppg Cement (232 bbl) - 8.4 ppg Lease Water (200 bbl) LB-30 Perforations: Zone MD TVD Size SPF Date B5 ±5,624'-±5,628' ±5,200'-±5,204' TBD B5 5,663'- 5,668' 5,235'-5,240 2-7/8" 6 8/23/20 B6 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/15 UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Fluid Level 8.4 ppg Lease Water @ 9,000' CTM Short Marker Joints @ 7,901'-7,916' MD @ 8,906'-8,921' MD Cement top @ 8,836' MD Plug @ 8,852' MD LB-28B Plug @ 8,610' ELM LB-28 LB-27 Tag (sand) @ 8,305' SLM w/ 2.00" Bailer (8/30/14) Plug @ 8,530' ELM Plug @ 8,270' ELM capped w/ 35' of cement UBC-3 Tag @ 8,264' SLM w/ 4.67" GR (4/30/15) B6 Plug @ 6,475' capped w/ 44' cmt CIBP @ 5,680' 8/23/2020 B5 B5 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9,450 feet 5,680'; 6,475' feet true vertical 8,870 feet N/A feet Effective Depth measured 9,335 feet 4,857 feet true vertical 8,756 feet 4,556 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 4,857' MD 4,556' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Mike Quick Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 mquick@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,060psi 12,640psi 144' 2,121' 5,750psi 3,450psi Collapse 1,050psi 1,950psi 3,090psi 11,080psi Casing Structural 20" 13-3/8" 9-5/8" Length 144' 2,121' 5,081' 9,450' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 7,243 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-243 1,197 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 213-196 50-133-20539-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 200 Beaver Creek Unit (BCU) 14A N/A FEDA 028083 5,081' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Sterling Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5-1/2"9,450' 4,744' 8,870' WINJ WAG 0 Water-Bbl MD 144' 2,121' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:42 am, Sep 23, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.22 16:48:01 -08'00' Taylor Wellman SFD 9/24/2020 7,243 RBDMS HEW 9/23/2020 gls 9/28/20 Perforate DSR-9/24/2020 N2 Rig Start Date End Date CTU 8/20/20 8/23/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-133-20539-01-00 213-296 Well Name BCU-14A Sign in. Mobe to location. PTW, JSA and SIMOPS w/AKE-Line and SLB N2. PT AKE-Line lubricator to 250 psi low and 3,500 psi. TP - 725 psi. Worked on rental crane. Tightened flange bolts. RIH w/GPT tool and tie into Yellow Jacket perf log. Run correlation log and send to town. Told log was on depth.. Could not find fluid level. Found soupy fluid. Ran log from 5,575' to 6,025' and found soapy fluid at 5,800' but found no solid fluid. POOH. RIH w/4.212" CIBP and tie into GPL log. Run corralation log and send to town. Get ok to set plug at 5,680' with 1,700 psi on tubing. Set plug at 5,680' Pick up 30' and went back down and tagged. POOH. Setting tool look good. Good set. RIH w/ 2-7/8" x 5' HC Razor, 6 spf, 60 deg phase and tied into GPT log. Told log was needed to shift log up 4'. Shifted log up and spotted gun from 5,663' to 5,668'. Fired gun with 1,667 psi. 5 min - 1,693 psi, 10 min - 1,700 psi and 15 min - 1,704 psi. POOH. All shots fired and gun was dry. Rig down equipment and turn well over to field. Previous info. E-line ran in hole and found fluid level at 500'. Tagged fill at 5,295'. Plan was to set a 5.5" CIBP at 5,680'. PTW, JSA Pick injector head and lubricator. Make up BHA. 1.9" OD roll on coil connector, 1.75" OD DFCV, 2.0" OD MBT, 1.9" OD Down jet nozzle. BHA length 5.87'. Stab on well. PT stack 250/4,000 psi. Open well. RIH. 0 psi WHP. CT pipe displacement produced returns to surface at 3,500'. Dry tag 5,320' CTMD. Pick up clean. Online down CT and fill reel. Circulate to surface and check for 1:1 returns. Max pump rate with lease water down CT is only 1.4 bbls/min. Not enough AV's to carry solids. Cool down N2. Online with N2 900 scf/min. N2 and fluid returns to surface. RIH perform nitrified foam cleanout from 5,320' To top of cement at 6,433' CTMD. Returns showing 30-40% solids. Perform 4 wiper trips while cleaning out. RIH tag 6,433' CTMD. Calcualte and determine N2/fluid rates and pressures. Fluid level at 500' with 0 psi whp puts hydrostatic pressure at perfs 2,061 psi. Well is static. Adjust N2, fluid rate, choke position to keep well balanced or slightly over balanced. N2 rate at 900 scf/min, Fluid rate at .8 bbls/min choke between 800 psi and 980 psi. Circ pressure 2,660 psi. Equivalent pump rate 1.82 bbls/min 3.74 ppg, 2,089 psi hydrostatic returns cleaning up chase last bottoms up to surface Close choke. WHP 860 psi. Offline with N2. pump 50 bbls down 5.5" casing. Online with N2 2,000 scf/min. Tagged up at surface. Shut down N2 pump. Close swab valve. SITP 2,285 psi. Total SCF pumped 336,231 . (3611 gallons). Bleed remaining N2 from coil. Pop off well. Stack down . Pollard Spotted up awaiting crane. Move SLB lubricator box. Rig up pollard slick line. Stab on well. Pressure up lubricator. O ring cut on lubricator. Stack down and replace O ring. Stab on well. PT stack. RIH with 3" dd bailer. WHP 1,838 psi. Slick line said they saw FL at 3,300'. SL tagged 6,310' RKB. POO to surface. SLB will leave N2 pump and liquid nitrogen on location. 3,200 gallons. Shut in well. Rig down SL. Rig down SLB CTU 13. 08/23/2020 - Sunday 08/20/2020 - Thursday PTW, JSA with crew MIRU SLB CTU 13 with 1.75" coil. Spot return tanks and manlift. 24 hr bope test witness notification sent 8/19/20 @ 1358. Witness waived via email from Jim Regg 8/19/2020 1653 hrs. Test BOPE. All rams and valves tested 250/4,000 psi. Accumulator draw down test complete. 08/21/2020 - Friday spotted gun from 5,663' to 5,668'. found fluid level at 500' CIBP at 5680 ft perf 5663-5668 ft SITP 2,285 psi. CTU N2 FCO Get ok to set plug at 5,680' with 1,700 psi on tubing. S Slick line said they saw FL at 3,300'. SL tagged 6,310' RKB. POO t w MIRU SLB CTU 13 with 1.75" coil. Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 141' 18.6' 5/18/2015 9/10/2020 Well Name & Number:Beaver Creek Unit #14A A - 028083 County or Parish:Kenai Peninsula Borough Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,081'Maximum Deviation:36.5º @ 3,713' Date Completed:2/6/2014 Ground Level (above MSL):RKB (above GL): BC-14A Pad 1A 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M.Permit #: 213-196 API #: 50-133-20539-01-00 Property Des: A-028083 KB Elevation: 159.6' (18.6' AGL) Lat:N60°38' 51.1588' Long:W151°2' 45.491" Spud Date: 01/24/14 Rig Released: 02/09/14 Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore PBTD 9,335' MD 8,756' TVD TD 9,450' MD 8,870' TVD Conductor 20" K-55 133 ppf Top Bottom MD 0' 145' TVD 0' 145' Surface Casing 13-3/8" K-55 68 ppf BTC Top Bottom MD 0' 2,122' TVD 0' 2,122' 16" hole Cmt w/ 568 sks (254 bbl) of 12.0 ppg, Class G cmt Intermediate Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TVD 0' 4,744' 12-1/4" hole Cmt w/ 377 sks (141 bbls) of 12.5 ppg Tail & 510 sks (106 bbls) of 13.5 ppg Lead Class G cmt Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2" hole Cmt w/ 972 sks ( 232 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK SCHEMATIC Swell Packer @ 4,857'-4,879' MD TOC (3/03/14 USIT) - 4,725' Max Dogleg: 4.86°/100' @ 3,650' Openhole Casing 31' off bottom Tag (sand) @ 8,658' TPM w/ 4.625" Bit (5/11/14) Max Inclination: 36.5°@ 3,713' Casing Shoe @ 9,419' Casing/Cementing Detail - 9.6 ppg Mud - 12.5 ppg Mud Push (34 bbl) - 15.3 ppg Cement (232 bbl) - 8.4 ppg Lease Water (200 bbl) LB-30 Perforations: Zone MD TVD Size SPF Date B5 5,663'-5,668' 5,235'-5,240' 2-7/8" 6 8/23/20 B6 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/15 UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Fluid Level 8.4 ppg Lease Water @ 9,000' CTM Short Marker Joints @ 7,901'-7,916' MD @ 8,906'-8,921' MD Cement top @ 8,836' MD Plug @ 8,852' MD LB-28B Plug @ 8,610' ELM LB-28 LB-27 Tag (sand) @ 8,305' SLM w/ 2.00" Bailer (8/30/14) Plug @ 8,530' ELM Plug @ 8,270' ELM capped w/ 35' of cement UBC-3 Tag @ 8,264' SLM w/ 4.67" GR (4/30/15) B6 Plug @ 6,475' capped w/ 44' cmt CIBP @ 5,680' 8/23/20 B5B5 CIBP @ 5,680'@, 8/23/20 6 8/23/20B5 5,663'-5,668' 5,235'-5,240' 2-7/8" 66 From: Chnstina Tw0000d - (C) To: Loeoo. Victoria T (CED) Cc: Schwartz. Guy L (CED) Subject: RE: [EXTERNAL] Re: BCU -14A Fill Clean Out Sundry Revision (PTD 213-196, Sundry 320-243) Date: Wednesday, July 8, 2020 4:34:02 PM Thank you Victoria! Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w)907-777-8443 (c) 907-378-7323 From: Loepp, Victoria T (CED) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, July 8, 20204:32 PM To: Christina Twogood - (C) <ctwogood@hilcorp.com> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: [EXTERNAL] Re: BCU -14A Fill Clean Out Sundry Revision (PTD 213-196, Sundry 320-243) Christina, Approval is granted for this Sundry revision for a CTU fill clean out prior to proceeding with perforating. Thanx, Victoria Sent from my iPhone On Jul 8, 2020, at 2:54 PM, Christina Twogood - (C) <ctwogood @hilcorp.com> wrote: Guy, As discussed, while running the GPT on BCU -14A, Hilcorp encountered fill at 5,295' that will require a coil clean out prior to proceeding with perforating as per Approved Sundry 320-243 (attached for ease of reference). As requested, here is the coil clean out procedure for this scope of work. 1. MIRU Coiled Tubing Unit onto the 5-1/2" tubing string. Pressure test BOPE to 250 psi Low / 3,500 psi High. 2. RU Nitrogen Pump. 3. PU & RIH with nozzle and BHA on Coil. 4. Clean out to approx. 5,700'. 5. Blow well dry with Nitrogen. Leave approx. 1,800 psi on tubing at surface. 6. POOH to surface and laydown BHA. 7. RDMO Coiled Tubing Unit. 8. Proceed with well operations as per Approved Sundry 320-243. Please let me know if this is an acceptable plan to the AOGCC. Sincerely, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w)907-777-8443 (c) 907-378-7323 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. <BCU -14A Al 10-403 320-243 PTD 213-196 Approved 06-11-20.pW> 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, distdbution, 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. By Samantha Carlisle at 9:45 am, Jun 05, 2020 320-243 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.04 21:15:04 -08'00' Taylor Wellman SFD 6/9/2020 10-404 gls 6/9/20 SFD 6/09/2020 dSR-6/9/2020 SFD 6/9/2020 A 6/11/2020 dts 6/11/2020 JLC 6/11/2020 RBDMS HEW 6/12/2020 (Plug Sterling B6) Nitrogen displacement if needed. SFD 6/9/2020 A Beaver Creek Sterling Gas - 80525 SFD 6/9/2020 Sterling B6 STATE OF ALASKA AL,,oKA OIL AND GAS CONSERVATION COM ..SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations ❑ Fracture Stimulate U Pull Tubing ❑ Operations shutdown U Performed: Suspend ❑ Perforate ❑� Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Cl 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 213-196 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 111 6.API Number: Anchorage,AK 99503 50-133-20539-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 Beaver Creek Unit(BCU)14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Sterling Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,450 feet Plugs measured 8,270 f E C E 1 M E D true vertical 8,870 feet Junk measured N/A feet .JUN 12 2015 Effective Depth measured 9,335 feet Packer measured N/A feet true vertical 8,756 feet true vertical N/A feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED JUL 0 2U1,, True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A;N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. , Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf - Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 1,375 305 0 664 14.Attachments(required per 20 AAC 25.070,25.071,&25 283) 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 Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR LI WINJ ❑ WAG LI GINJ ❑ SUSP❑ SPLUG❑ 1 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: 315-271 Contact Stan Porhola Email sporholaa.hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature AOry-IA_____ Phone 907-777-8412 Date /Z70-- Form 10-404 Revised 5/2015 tf >4../ J illi 74305� RBpk n'rigings lL 5 2015 11 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 5/13/15 5/18/15 Daily Operations: 05/13/2015-Wednesday PTW and JSA.Mobe to location.Spot equipment and rig up lubricator.Pressure test to 250 psi low and 3,500 psi high.TP-0 psi. RIH with 4.50"GR,tie into SLB RST log dated 13 Mar 14 and tag fill at 8,191.5'.POOH,no problems. RIH with 4.24"OD CIBP and tie into SLB RST log dated 13 Mar 14.Run correlation log and send to town.Get ok to set plug at 6,475'.Spot plug at 6,475'and set plug.Pick up 50'and slack back down and tag plug.POOH.Good set. Make 3 runs with 4"x 30'dump bailer and dump bail cement on top of plug at 6,475'.Dump 42 gals of cement.Est TOC 6,429'.Cement in place at 16:28 hrs. Rig down lubricator and turn well over to field. 05/15/2015-Friday MIRU Slickline.Rig up lubricator and test to 250 psi low and 3,500 psi high.RIH w/3.0"DD bailer and tag cement at 6,431' SLM.RIH w/swab mandrel and swab cups.Swab out fluid down to 3,000'SLM.Rig down lubricator and turn well over to field. TP-0 psi. 05/18/2015-Monday PTW and JSA.Mobe to location and spot equipment.Rig up lubricator and pressure test to 250 psi low and 3,500 pi high.TP- 30 psi. RIH w/3-3/8"x 10'HC Razor,6 spf,60 deg phase,tie into SLB RST log dated 13-Mar-14 and tagged at cement at 6428'. Found fluid level at 3,010'.Run correlation log and send to town.Get ok to pelf as soon as wel get well pressured up to 160- 200 psi.Spot gun from 5,684'to 5,694'.Wait on well to pressure up.Got the ok to perforate with TP at 156 psi. Fired gun and pressure started building to 360 psi after 5 min and 670 psi after 10 min.822 psi after out of hole and looks like fluid level was still around 3,010'. Rig down lubricator and turn well over to field.TP 860 psi and still gaining.Move to BCU 23. , H BC-14A ACTUAL Pad 1A SCHEMATIC Haeorp Alaska.LL( 113' FSL, 1,388' FEL Permit#: 213 196 Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" TToo lot ppf p Bottom Property Des: A-028083 , , MD 0' 145' KB Elevation: 159.6' (18.6'AGL) 4; ND 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 r lr , 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 T� Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt ."1 Tree cxn=9-1/2"Otis .y" 8.0"Seal Diameter ' ' Intermediate Casing 5-1/8"Modified ID Bore :*- 9-5/8" L-80 40 ppf BTC , J , Top Bottom VMD 0' 5,081' TOC(3/03/14 USIT)-4,725' ..:,. ,0- ND 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt Swell Packer @ ' .' 4,857'-4,879'MD ,v Production Casing `° 5-1/2" P-110 20 ppf XP BTC Plug @ 8,270'ELM „ r^ ' Top Bottom capped w/35'of cement .- 4 MD o' 9,419' ND 0' 8,839' 8-1/2"hole Cmt wl 972 sks(232 bbls) Tag(sand)@ 8,305 SLM of 15.3 ppg,Class G cmt w/EASYBLOK w/2.00"Bailer(8/30/14) B4 Casing/Cementing Detail Plug @ 6,475' - 9.6 ppg Mud Plug @ 8,530'ELM • ' '*',0 A.--..,---- capped w/44'cmt - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) C ,,,^ UBC-3 - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM }}:��}�f:�„ Tag @ 8,264'SLM \,.... =Ii_,��_ti:F.,., w/4.67' GR(4/30/15) Tag(sand)@ 8,658'TPMw/4.625"Bit(5/11/14) Perforations: Zone MD TVD Size SPF Date Cement top @ 8,836'MD - B4 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 5/18/14 f' Plug @ 8,852'MD -\ =Kftiftifti �'�R'. ti'_ UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,906-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 Fluid Level :-'41g.• LB-28 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 8.4 ppg Lease Water LB-30 .---- - = LB-30 8,868'-8,882' 8,29Z-8,306' 3-3/8" 12 3/17/14 @ 9,000'CTM 4fti1.1N�:lN~ Casing Shoe @ 9,419' Openhole Casing 31'off bottom -- . • Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD8,870'TVD 8,756'ND Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease:, A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/18/2015 Schematic Revision Date: 6/8/2015 V OF Tye �j,,sT THE STATE Alaska Oil and Gas — � ofAT KA, Conservation Commission ___ _ 333 West Seventh Avenue fy \TM- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 ALAS� U1 Fax 907.276 7542 sataNED MA`! 1 2U I www alaska gov Stan Porhola Operations Engineer icti? Hilcorp Alaska, LLC a 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek(BCU) 14A Sundry Number: 315-271 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /614-C-t . Cathy P. oerster Chair DATED this lay of May, 2015 Encl. • RECEIVED ' STATE OF ALASKA MAY 0 5 015 ALASKA OIL AND GAS CONSERVATION COMMISSION VAPPLICATION FOR SUNDRY APPROVALS Gam, . `� 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations Perforate E • Pull Tubing Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 213-196 • 3.Address. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El6.API Number. Anchorage,Alaska 99503 50-133-20539-01 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek Unit(BCU)14A Will planned perforations require a spacing exception? Yes ❑ No ✓ - 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 Beaver Creek/Beluga Gas Pod 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): 9,450 • 8,870 ' 9,335 . 8,756 • 8,270 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi . Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A; N/A N/A; N/A 12.Attachments: Description Summary of Proposal ❑✓ X13.Well Class after prop.sed work: Detailed Operations Program ❑ BOP Sketch n Exploratory n Stratigraphic❑ Development n Service ❑ 14.Estimated Date for 15.Well Status after propsed work: Commencing Operations: 05/14/15 Oil ❑ Gas ❑✓ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-8412 Email sporhola@hilcorp.com Printed Name Stan Porhola Title Operations Engineer / Signature pc,„/„_. Phone 907-777-8412 Date 5-1 s1 i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . 16 - 1_1k Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes I] No U Subsequent Form Required: 1 • '/ • v APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 5— 7.45--' Submit Form and Form 10-403(Revised 10/2012) GRI,GpliNAL for 2 months from the date of approval �,/ Atta ents in Duplicate RBDMS� � MAY 1 1 2015 `r�/'r1� -- -f f'• ' /'� Well Prognosis Well: BCU-14A ilnu:tiaaa.IA) Date: 5/05/2015 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: May 14th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 3,167 psi @ 6,060' TVD (Based on pressure in UBC-3) Maximum Expected BHP: — 3,167 psi @ 6,060' TVD (Based on pressure in UBC-3) Max. Allowable Surface Pressure: —2,561 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek #14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface. The initial zone (LB-30) was perforated and tested and showed poor performance. The 2nd zone (LB-28B) was perforated and sanded up on initial tests and failed to produce after a coil tubing cleanout. The 3rd zone (LB-28) was perforated and failed to produce. No fill and minimal water was seen from this zone. The 4th zone (LB-27) was perforated and shown to be productive. However, water from the LB-28 is contributing to downhole hydrate formation. The well sanded off and was cleaned out with coiled tubing. However, this zone sanded up again. The LB-27 was plugged back and the Upper Beluga C-3 was added in November 2014. However, this zone came in wet and was unproductive. - The purpose of this work/sundry is to plugback the Upper Beluga C-3 and the associated water/sand from this interval and perforate the Sterling B4. - Notes Regarding Wellbore Condition • Last tag at 8,264' SLM on 4/30/15 w/4.67" gauge ring. • Fluid level is at 130'. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP is 600 psi. 2. RU 5-1/2" CIBP. 3. RIH and set CIBP at+/-6,450' MD. 4. MU dump bailer and dump 35' of cement on plug (approx. 33 gals cement). 5. RD E-line. 6. WOC 24 hours. Slickline Procedure: 7. MIRU Slickline, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP is 600 psi. • II Well Prognosis Well: BCU-14A llileorp Alaska,LL Date:5/05/2015 8. RIH and tag cement top. 9. Bleed off tubing pressure to 100 psi. 10. RD Slickline. E-line Procedure: 11. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. c. Tree connection is 9.5" OTIS. d. SITP will be 100 psi. 12. RU 3-3/8" 6 spf ConneX HC wireline guns (will use 1 each 10' gun). 13. RIH and perforate Sterling B4 interval from 5,684'-5,694' (1 run, total of 6 spf). a. Bleed tubing pressure to 100 psi before perforating. b. BHP= 2,050 psi (based on offset wells). c. Proposed perfs shown on the proposed schematic in red font. d. Correlate using SLB Cement PNL Log dated 3/13/14. e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands= 2,524'to BCU-19. h. Spacing allowance is based on CO 237A, no spacing limitations in the Sterling. / 14. RD E-line. 15. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic , . , : ill BC-14A ACTUAL Pad 1A SCHEMATIC Hilcorp Alaska,LU 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 213-446 S6 20" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083 a MD 0' 145' KB Elevation: 159.6' (18.6'AGL) �� ,� � ' TVD 0' 145' Lat: N60° 38' 51.1588' r "+ Long: W151° 2' 45.491" ' Fluid Level Surface Casinq Spud Date: 01/24/14 - 130'SLM 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 Tom Bottom MD 0' 2,122' ND 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of R; 12.0 ppg,Class G cmt I Tree cxn=9-1/2"Otis :,444 8.0"Seal Diameter ,-s Intermediate Casing 5-1/8"Modified ID Bore 1's 9-5/8" L-80 40 ppf BTC 1 Top Bottom yi� MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ----------------.4 ki,4 ND o' 4 _ '_ 12-1/4"hole Cmt w/377 sks sks(141 bbls)of _► 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ b i ppg Lead Class G cmt 4,857'4,879'MD . ' Production Casing 5-1/2" P-110 20 ppf XP BTC Plug @ 8,270'ELM •o,^ Top Bottom capped w/35'of cement ; MD 0' 9,419' ND 0' 8,839' ') 8-1/2"hole Cmt w/972 sks(232 bbls) Tag(sand)@ 8,305'SLM of 15.3 ppg,Class G cmt w/EASYBLOK w/2.00"Bailer(8/30/14) ' l:. n Casing/Cementing Detail - 9.6 ppg Mud • Plug @ 8,530'ELM UBC-3 - 12.5 ppg Mud Push(34 bbl) :y - 15.3 ppg Cement(232 bbl) i, - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM - - rs `jYtiYj? _ + Tag @ 8,264'SLM L- 7 ti_;M± •+•tib, w/4.67"GR(4/30/15) Tag(sand)@ 8,658'TPM LB-28 - ' - w/4.625"Bit(5/11/14) Perforations: Cement top @ 8,836'MD . f Zone MD TVD Size SPF Date UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 Plug @ 8,852'MD •i:;:;:;:}:,.g...._ LB-28B i}}}}}f}}}}}p}�� LB-27 8,477'-8,497' 7,905-7,925' 3-3/8" 12 5/23/14 .c�; .....,.`� LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Fluid Level - .• LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 8.4 ppg Lease Water LB-30 @ 9,000'CTM , r-1-�-1-14JN_ '" Casing Shoe @ 9,419' "n, -*. Openhole Casing 31'off bottom Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 450 9, 'MD 9,335'MD @ 7,901'-7,916'MD g,450870'TVD 8 756'ND Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish:_ Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: _ 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed:_ 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 4/30/2015 Schematic Revision Date: 5/5/2015 . _ . H. BC-14A PROPOSED Pad 1A SCHEMATIC Hilcorp Alaska,LLC 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" TToopp Bottom Property Des: A-028083 Ij1 : :1 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ND 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 `, I ; 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 • 0' Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of • 12.0 ppg,Class G cmt e.i Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore - 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ND 0' 4,744' 12-114"hole Cmt wl 377 sks sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ ti r ppg Lead Class G cmt L . 4,857' 1,879'MD Production Casing 5-1/2" P-110 20 ppf XP BTC Plug @ 8,270'ELM Y, Top Bottom capped w/35'of cement MD 0' 9,419' t ND 0' 8,839' AI 8-1/2"hole Cmt w/972 sks(232 bbls) Tag(sand)@ 8,305'SLM of 15.3 ppg,Class G cmt w/EASYBLOK w/2.00"Bailer(8/30/14) _1 '''�� 11 B4 i Casing/Cementing Detail Plug @ 6,450' - 9.6 ppg Mud Plug @ 8,530'ELM r_ capped w/35'cmt 12.5 ppg Mud Push(34 bbl) N -,,,1UBC-3 15.3 ppg Cement(232 bbl) 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM ,,. _ `3T ?'j Tag @ 8,264'SLM L 7 --i '.�;.ti ti,., _ w/4.67"GR(4/30/15) Tag(sand)@ 8,658'TPM w/4.625"Bit(5/11/14) LB-28 Perforations: ill Zone MD ND Size SPF Date y Cement top @ 8,836'MD = 5,684'-5,694' 5,254'-5,263' 3-3/8" 6 Proposed 7r• Plug @ 8,852'MD LB-28B =J+J%J %.S.%- UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 -�r"'r`, J•gil:r' LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 Fluid Level LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 8.4 ppg Lease Water LB-30 = - LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 @ 9,000'CTM , 4•,.M�•ti.ti•M ,,,,,...,:.,e,•.,02, A)111 . . •k Casing Shoe @ 9,419' Openhole Casing 31'off bottom Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD 8,870'ND 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL). 141' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 5/5/2015 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable b direct inspection of the file. j 3 _ j e (0 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps: ayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: aria ) Date: s l 3 iS /s/ 114 P _.,,,, Project Proofing VI(BY: ( Maria Date:3 ' / S /s/ Scanning Preparation 7 x 30 = d D + 1 9 = TOTAL PAGES goa ' (Count does not include cover sheet BY: C. Date:3 13 l5' /s/ Production Scanning Stage 1 Page Count from Scanned File: r f3o (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO BY: ChActr.i,a ) Date:3/(3/1,5". /s/ vvipStage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: [1 2, Digital version appended by: Meredith Michel Date: 3iI 3//s.-- /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 3 y'a- Scanning is complete at this point unless rescanning is required. 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GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 tI,i:,,rp 1.11 Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 02/20/15 To: Alaska Oil & Gas Conservation Commission RECEIVED Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 FEB 2 0 2015 Anchorage, AK AOGCC 99501 AOGCC DATA TRANSMITTAL BCU 14A Mudlog and Pressure Report Prints: 5" Formation Log MD -72y I`I 6 5" Formation Log TVD PressureXpress Final Report- 24 5€-1 Please include current contact information if different from above. Please acknowl receipt y Qi and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: Angela K. Singh z-f 20AS STATE OF ALASKA RECEIVED ALA .OIL AND GAS CONSERVATION COMMIS—.JNV REPORT OF SUNDRY WELL OPERATIONS JAN 0 9 2015 1.Operations Abandon LJ Repair Well Lf Plug Perforations U Perforate U Other 40Gel Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension .��C 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 0 Exploratory ❑ 213-196 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20539-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 Beaver Creek Unit(BCU)14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas 11.Present Well Condition Summary: Total Depth measured 9,450 feet Plugs measured 8,530 feet true vertical 8,870 feet Junk measured N/A feet Effective Depth measured 9,335 feet Packer measured N/A feet true vertical 8,756 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A;N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 198 Subsequent to operation: 0 0 0 0 793 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Service 0 Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑� WDSPL❑ GSTOR p WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-572 ` Contact Stan Porhola Email sDorhoIa( hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature `k P�� ___ Phone 907-777-8412 Date (/6 CI'l s. ieRBDMSc JAN 1 1 1015 Form 10-404 Revised 10/2012 i•u 'I Y Submit Original Only Hilcorp Alaska, LLC 1 /yL'� Well Operations Summary ��` Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213- 11/3/14 11/26/14 Daily Operations: 11/03/2014-Monday PTW and JSA.Rig up lubricator and PT to 250 psi low and 3,000 psi high. RIH w/4.24"OD CIBP and tie into SLB RST log dated 13 Mar 2014.Set down at 8,281'.Run correlation log and send to town.Get ok to set at 8,270'.Got on depth and set plug at 8,270'.Picked up 50',went back and tagged plug.POOH. Bled well down to zero.Plug held.Ran 3"x 50'bailer of cement(16 gal)and dumped bailed cement on plug at 8,270'. Found line stranded.Re-headed line and went in hole with 3"x 50'bailer (16 gal)and dump bailed cement at 8,240'.POOH.Cement in place at 18:05.TOC est at 8,235'. NOTE:Fluid level-1,260'. Rig down lubricator and clean up work area. 11/08/2014-Saturday Hold JSA with crews. Obtain permit to work. Fire equipment and pull onto location,rig up euipment.Notify State of BOP test. Halliburton reel sump leaked. Notified management and HSE. Spill cleaned up. Rigged up CTU. Iron,BOPS,hoses,n2. BOP Test witness waived 13:55 by Jim Regg,AOGCC.Start BOP test 14:30 as per AOGCC and API regs. Pressure test to 250/4,500psi. BOP test completed at 18:00. Rig back CTU unit for the night. Secure Wellhead. Shut down light plants. Leave location. 11/09/2014-Sunday Hold safety meeting,JSA,permit to work. Remove night cap. Pick injector head and lubricator. Make up Coil connector, check valves,wash nozzle stab on well and hammer up flange. Fluid Pack coil and pressure test stack. Low pt 250 psi/High pt 4,500 psi. Blow down coil. Methanol/water mixture removed from open top tank and stored for future BOP tests. RIH.Start n2 @ 1,000 scf/min @ 3,157 ft. Starting to get fluid returns at surface. Circulating pressure increasing to 1,200 psi Indicating we are lifting fluid. Perform weight check every 4,000 ft. Light tag top of CIBP @ 8,212'CTMD. No corrected to RKB. 2,200 psi on coil. WHP 427 psi slugging n2 and fluid. Straight n2 returns at surface. POOH chasing last of fluid out. 957 PSI Coil pressure 1,000 scf/min and 273 psi WHP. POOH at 6,000 ft straight n2 at surface. Close in choke. Down on N2 pump swap valves to pump down back side of coil by 5-1/2"annulus. Pulling out of hole while pressuring up well to 1,500 psi. Swapped down back side to save N2 by not having to compress the coil volume of 33 bbls of space. At surface. 1,530 psi well head pressure from n2. Close in well. Bleed off Coil. Start rigging down. Roustabouts have BCU 24 pit liner set ready for CTU unit. CTU unit rigged down and parked on Pad 3. Crews off location. 11/26/2014-Wednesday PTW and JSA.Mobe to location.Spot equipment and rig up.Found flange leaking between swab and well head connection. Unbolt flange and clean ring gasket.Flange back up and still leaked.Called Clint and he had his men come over to location.Put new ring gasket on and pressure tested flange and lubricator to 250 psi low and 3,500 psi high. TP-1,250 psi.Arm 3-3/8"x 10' HC,6 spt,60 deg phase perf gun and tie into SLB RST log.Ran correlation log and send to town.Get ok to perf.Spot shot from 6.550'to 6,560'.TP-1,250 psi. Fired gun and tubing pressure went to 1,300 psi in 2 min and level off. POOH.Rig down lubricator and turn well over to production. . _ . 11 BC-14A ACTUAL Pad lA SCHEMATIC IHih•ari,Alaska.Ll.(: 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 213-196 20" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 ', • 13-3/8" K-55 68 ppf BTC TQQ Bottom Riq Released: 02/09/14 MD o' 2,122' TVD 0' 2,122' y 16"hole Cmtwl 568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter i,4 1' Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC /..,) 11 Top Bottom V MD 0' 5,081' TOC(3/03/14 USIT)-4,725' .. TVD 0' 4,744' ff 12-1/4"hole Cmt w/377 sks(141 bbls)of M ^ ,1,1 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt Swell Packer @ 4,857'-4,879'MD ;, Production Casing 5-1/2" P-110 20 ppf XP BTC Plug @ 8,270'ELM 1 . Top Bottom capped w/35'of cement ; ' MD o' 9,419' TVD 0' 8,83839' ' 8-1/2"hole Cmt w/972 sks(232 bbls) Tag(sand)@ 8,305'SLM of 15.3 ppg,Class G cmt w/EASYBLOK w/2.00"Bailer(8/30/14) Casing/Cementing Detail - 9.6 ppg Mud Plug @ 8,530'ELM = UBC-3 - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM L: 7 ;�y �,,,13C r 4= Perforations: Tag(sand)@ 8,658'TPM _ _ ?`5>R I Zone MD TVD Size SPF Date w/4.625"Bit ,658 14) LB-28 t= UBC-3 6,550'-6,560' 6,060'-6,069' 3-3/8" 6 11/26/14 LB-27 8,477'-8,497' 7,905-7,925' 3-3/8" 12 5/23/14 • - LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 Cement top @ 8,836'MD LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Plug @ 8,852'MD ,l , LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 \ LB-28B -:•4 ' - i f.i• .t - ,s_ Fluid Level 8,4 ppg Lease Water LB-30 @ 9,000'CTM - L 1• MK J/.JN t,fSJ-.. j,' '-:* Casing Shoe @ 9,419' i • 4 , fi.. Openhole `., Casing 31'off bottom Max Dogleg: TD PBTD 4.86°/100'@ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD 8,870'TVD 8,756'ND Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A _ Lease: A-028083 _ County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A _ Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL):I 18.6' Revised By: Stan Porhola Downhole Revision Date: 11/26/2014 Schematic Revision Date: 12/4/2014 Schwartz, Guy L (DOA) 3A \ 61(40'b From: Schwartz, Guy L(DOA) Sent: Tuesday, December 16, 2014 1:43 PM To: Donna Ambruz' Cc: Stan Porhola Subject: RE:Sundry Cancellation - Sundry#314-339 - BCU 14A - PTD 213-196 Donna, Sundry 314-339 will be cancelled as requested below. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz©alaska.gov). From: Donna Ambruz [mailto:dambruz@hilcorp.com] Sent:Tuesday, December 16, 2014 12:16 PM To: Schwartz, Guy L(DOA) Cc: Stan Porhola Subject: Sundry Cancellation - Sundry # 314-339 - BCU 14A- PTD 213-196 Guy, Please withdraw the above mentioned sundry(Install Capstring) . Thank you. liann.a LIndutuz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 907.777.8305-Direct 907.777.8310-Fax dambruz@hilcorp.com 1 X13-1,9G 7,<;CiF 71jr 0, \\ I%% ELL STATE G 1u 9,c 7\ s'' `� �`�cr /\ •r' '�7°` `n �, r•r-r- 333 Wesf Seventh Avenue ktia_ -.r\T IN - CSO\'ERNOR SEA N PARNELL Anchorage, Alaska 99501-3572 Moro 907 279 1A33 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 14A Sundry Number: 314-572 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of October, 2014. Encl. 5 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCTO 2 1 2 CT 2 2014 D51-1 (o(��/�y APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations Q ' Perforate 0 ' Pull Tubing❑ Time Extension❑ Operations Shutdovn❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casmg❑ Other: ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 2 - 213-196 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20539-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A ' Beaver Creek Unit(BCU)14A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 " Beerier Creek/Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,450 8,870 . 9,335 8,756 8,530 N/A Casing Length Size MD ND Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(It): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q '13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n r Service n 14.Estimated Date for X15.Well Status after proposed work: 10/30/14 Commencing Operations: Oil ❑ Gas Q. WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Phone: 907-777-8412 Email soorholaahilcoro.corrm Printed Name Stanta /Poorrhola Title Operations Engineer Signature �� ' �-t/(____ Phone 907-777-8412 Date 10k-t• /y-- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l`-t - 512 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No E 1 Subsequent Form Required: /0—g 0 I /'/J APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 70- Z p(�-/ Li / " ''y'`I Submd Form and 0-4 v ed.t TO ogeGiluAtd for 12 month from the date of approval. ttachmen ' DuplicateRBCS � �1 /lei c/ /0-z3,4% Well Prognosis Well: BCU-14A Hilcorp Alaska,LLi Date: 10/22/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: October 30th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: — 3,314 psi @ 7,905' TVD (Based on sample pressures from XPT pressures collected on 2/03/14 LB-27) Maximum Expected BHP: — 3,314 psi @ 7,905' TVD (Based on sample pressures from XPT pressures collected on 2/03/14 LB-27) Max. Allowable Surface Pressure: —2,523 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface. The initial zone (LB-30) was perforated and tested and showed poor performance.The 2nd zone (LB-28B) was perforated and sanded up on initial tests and failed to produce after a coil tubing cleanout.The 3rd zone (LB-28) was perforated and failed to produce. No fill and minimal water was seen from this zone. The 4th zone (LB-27) was perforated and shown to be productive. However, water from the LB-28 is contributing to downhole hydrate formation. The well sanded off and was cleaned out with coiled tubing. However, this zone sanded up again. The purpose of this work/sundry is to plugback the LB-27 and the associated water/sand from this interval and perforate the Upper Beluga C-3. Notes Regarding Wellbore Condition • Last tag at 8,305' SLM on 8/30/14 w/2.00" bailer. • Fluid level is unknown. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 165 psi. 2. RU 5-1/2" CIBP. 3. RIH and set CIBP at+/-8,300' MD. V 4. RD E-line. Coiled Tubing Procedure: 5. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 6. RU 1.75" coil cleanout BHA. 7. RIH w/coil to 8,300' MD and tag CIBP. 8. Displace well fluids with Nitrogen. Well Prognosis Well: BCU-14A Ililcorp Alaska,LL Date: 10/22/2014 a. Estimated volume of displaced 6% KCI is 185 bbl. b. Measure starting and ending fluid volumes of flowback tank. 9. Leave well with 1,500 psi Nitrogen SITP. 10. POOH w/coil. 11. RD Coiled Tubing. 12. Turn well over to production. E-line Procedure: 13. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,500 to 2,000 psi. 14. RU 3-3/8" 6 spf ConneX HC wireline guns (will use 1 each 20' gun and 1 each 5' gun). 15. RIH and perforate Upper Beluga C-3 interval from 6,545'-6,570' (2 runs,total of 6 spf). a. Bleed tubing pressure to 1,500 psi before perforating. b. BHP = 2,600 psi (based on XPT sample data). c. Proposed perfs shown on the proposed schematic in red font. d. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. e. Correlate using SLB Cement PNL Log dated 3/13/14. f. Use Gamma/CCL/to correlate. g. Record tubing pressures before and after each perforating run. h. Distance to nearest well open in same sands=3,640'to BCU-11. i. Spacing allowance is based on CO 237A, no spacing limitations in the Upper Beluga. 16. RD E-line. 17. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic Ili BC-14A ACTUAL Pad 1A SCHEMATIC Hilcorp Alaska,LLC 113' FSL, 1,388' FEL P,im 3- 196 Sec. 33, T7N, R10W, S.M. conductor API#: 50-133-20539-01-00 zo" TToopp Bottom Property Des: A-028083 MD 0' 145' • KB Elevation: 159.6' (18.6'AGL) TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface casing Spud Date: 01/24/14 `, 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 -a,p Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter t Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom I MD 0' 5,081' TOC(3103/14 USIT)-4,725JTVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of . 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ + t; ppg Lead Class G cmt 4,857-4,879'MD -------.......„.,...........A - . Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' A 8-1/2"hole Cmt w/972 sks(232 bbls) Tag(sand)@ 8,305'SLM of 15.3 ppg,Class G cmt w/EASYBLOK w/2.00"Bailer(8/30/14) \ . Casing/Cementing Detail -MI6 - 9.6 ppg Mud Plug @ 8,530'ELM - 12.5 ppg Mud Push(34 bbl) 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM N\14. • • -• t- Perforations: Tag(sand)@ 8,658'TPM _ Zone MD TVD Size SPF Date w/4.625" Bit(5J11/14) LB-28 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 -� LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD _ LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD LB-28B +,7}:i.;;}:}•}: ti 1 1 ti ti\1 � .ti•:L ..ti.ti. Fluid Level lit' 8.4 ppg Lease Water LB-30 @ 9,000'CTM • ►•T•Z•T'T• ^•T -, Casing Shoe @ 9,419' D_______t_______, G, .-•. t Openhole Casing 31'off bottom Max Dogleg: TD PBTD 4.86°/100'@ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD 8,870'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number:_ Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed:_ 2/6/2014 Ground Level(above MSL): 141' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 8/30/2014 Schematic Revision Date: 9/24/2014 BC-14A PROPOSED Pad lA SCHEMATIC Ili1'orp Alaska,LLC. 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Permit#: 213-196 Conductor API#: 50-133-20539-01-00 20" TToopo Bottom Property Des: A-028083MD 0' 145' KB Elevation: 159.6' (18.6'AGL) TVD 0' 145' Lat: N60° 38' 51.1588' Lon:: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 ', I 13-3/8" K-55 68t ppf BTC Rid Released: 02/09/14 Top Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis • 8.0"Seal Diameter 1. Intermediate Casing 5-1/8"Modified ID Bore d 9-5/8" L-80 40 ppf BTC Top Bottom y, MD 0' 5,081' TOC(3/03/14 USIT)-4,725' *. TVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ f ppg Lead Class G cmt 4,857'4,879'MD - .A.4''' Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom Plug @ 8,300'ELM t• MD 0' 9,419' TVD 0' 8,839' A 8-1/2"hole Cmt w/972 sks(232 bbls) Tag(sand)@ 8,305'SLM of 15.3 ppg,Class G cmt w/EASYBLOK w/2.00"Bailer(8/30/14) • Casinq/Cementinq Detail - 9.6 ppg Mud Plug @ 8,530'ELM ;, - 12.5 ppg Mud Push(34 bbl) " - 15.3 ppg Cement(232 bbl) UBC-3 - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM L 7 r73`}Y:::lig �.��=�=�""�- Perforations: Tag(sand)@ 8,658'TPM Zone MD ND Size SPF Date w/4.625"Bit(5J11/14) LB-28 UBC-3 6,545'-6,570' 6,055'-6,078' 3-3/8" 6 Proposec LB-27 8,477'-8,497' 7,906-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 Cement top @ 8,836'MD _ LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Plug @ 8,852'MD LB-28B _ ;;4r^:;i ;;•+,= LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 �" ';titir{tirtirti"- Fluid Level -t i 8.4 ppg Lease Water LB-30 ' @ 9,000'CTM t;.�tif;..:tiytiti '�ti 4.fti:.LrtiP:4 Casing Shoe @ 9,419' 41r, • , -,J Openhole Casing 31'off bottom Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MDg 870'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska _ Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs:I N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 10/21/2014 STATE OF ALASKA RECEIVED ALA....A OIL AND GAS CONSERVATION COMMIS ,,SON REPORT OF SUNDRY WELL OPERATIONS SEP 2 5 2014 1.Operations Abandon Li Repair Well Li Plug Perforations Li Perforate U Other L Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ AOGCv Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5 Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory ❑ 213-196 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20539-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 Beaver Creek Unit(BCU)14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas 11.Present Well Condition Summary: 8,530; Total Depth measured 9,450 feet Plugs measured 8,610;8,852 feet true vertical 8,870 feet Junk measured N/A feet Effective Depth measured 9,335 feet Packer measured 4,857 feet true vertical 8,756 feet true vertical 4,559 feet Casing Length Size MD ND Burst Collapse Structural Conductor 145' 20" 145' 144' 3,060 psi 1,050 psi Surface 2,122' 13-3/8" 2,122' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,419' 5-1/2" 9,419' 8,839' 12,640 psi 11,080 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr 4,857'MD 4,559'ND 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: 0 980 115 0 447 - Subsequent to operation: 0 0 0 0 172 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service El Stratigraphic El Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas LI WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-320 /3/y-y/3 Contact Stan Porhola Email sporholaCa�hilcorp.com Printed Name Stan Porhola Title Operations Engineer k,/,Signature Ad✓�_ �Phone 907-777-8412 Date 1 t L BBC MS SE 6 20 Form 10-404 Revised 10/2012 2x 3, Q/,��' l Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 8/22/14 8/30/14 Daily Operations: 08/22/2014-Friday Fill out work permit and JSA. Pull pit liner and dunage. Move return iron/choke skid/aux fuel cell to pad. Spot in CTU equipment. CTU rigged up. BOP Tested. low pt 250/High pt 4500. (Jim Regg,AOGCC waived witness at 1530). 08/23/2014-Saturday Morning safety meeting and JSA. Break flange from tree and make up Coil conector,back pressure valve,jars,disconnect,circ sub,motor,x overs and mill. Pull test and pressure test MHA. Hammer up BOP flange to wellhead,fluid pack to tank,audible confirmation motor is spinning,low and high pt stack. Open well to RIH. Initial WHP 614psi(24 hrs prior only 70psi). Stacked weight at 2,853'depth without pumping. Came online with pump and made it through previous tag. Came down on pump and tried to dry run back up through tag without any luck. Back down to neutral weight and came online with pump and made it back through 2,853'. Decision was made to run smaller mill. Mill was 4.653"OD. Tagged up at surface and close breaking flange/off well swapping bits. Rigged back up on wellhead fluid pack,low and high pt stack. RIH start pumping min rate fluid and N2 at 4,000 ft to establish circulation. 7,600 ft start increasing fluid rate to 1 bbl/min and N2 rate to 400 scf/min. First tag at 7,667 ft. 2,000lb weight stack and motor work from 7,776'to 7,690 ft. Wiper trip back to 7,500 ft. Cleaned to top of perfs at 8,452 ft. Vac truck was down due to blown tire. Low on fluid so sent 10 bbl gel sweep. POOH to surface while pumping 600scf/min and 1 bbl min of KCL chasing gel pill up hole. At surface well closed. Shut down equipment for the night. Well secured and all surface valves are isolated. 08/24/2014-Sunday Safety meeting and JSA. Fire euipment and prepare to RIH with Motor and Mill. RIH. Online with fluid 1 bbl/min and 400 scf at 8,400 ft. Returns to surface at 1,040'. Milling started at 8,458'.No motor work just stacking weight. Stacking weight at 8,460'300 psi motor work. Increase fluid ratre to 1.5 bbls/min 400 scf/min. Depth of 8,460 ft. Pump tripped out and overpull 20k. Came back online and were able to move up and down through interval at normal up weights of 30k. After heavy pull a short trip was made to 8,000 ft. Headed back down. Once back at 8,460'sent a 10 bbl gel sweep. Didn't make hole. Saw good motor work but weight wasn't breaking back. Called town and decision was made to POOH to surface and jet well dry. At surface wellhead secure. Pumped 325 bbls for mill run cleanout. Break tools and RU wash nozzle. Back on well for pt. RIH. Started N2 down coil at 4,500'ft. At bottom lifting well with N2. 1,000 scf/min to start. Small traces of fluid and nitrogen to surface at 1750hrs. Good fluids to surface and N2 returns. Checked LEL periodically. Once mostly N2 and gas dropped N2 rate to 600,then 400. LEL meter read 92%LEL. Assisted production to swap over to flow line. CT POOH to surface. Flow line pressure 660. WHP every five minutes climbed starting at 19:30 500PSI. 540PSI 560PSI/570P51/580. Continue to POOH. At surface swab closed. BOP blinds closed for double barrier and manual locks closed in to secure wellhead for the night. 08/25/2014-Monday Saftey meeting and JSA. Fire equipment. Open well. Initial WHP 500psi. Well would not flow following night due to line pressure at 660psi. RIH to 5,000 ft with N2 @ 600 scf/min. Fluid returns to surface. Stopped at 7,000 ft lifting well. Good returns to surface. Stopped at 8,415'blowing down well. Well is dry. Total returns for N2 lift 118bbls. Never saw more than 28%LEL on gas meter during first lift. Waiting on N2 transport. Attempted to turn well over to produciton. Turbine was back online so line pressure was dropped from 660 psi to 330 psi. Well flowed for 45 minutes at 500 MCF @ 350 psi. Cooling down N2. Well stopped flowing. Swapped back over to CTU control. Online with N2 for second lift. 1,100 scf min at 700ft. Good returns. Color has changed from grey to brown. Took samples to mud engineer at rig. 350-400 chlorites. Gettinig produced water back. Continue to lift well. Taking swab trips from 8,460 to 7,500 ft. Performed swab trips three times. Well was showing less signs of water each time. 3rd time well was blown dry no fluids to surface. 144 bbls lifted. POOH while pumping 1,100 scf/min. Shut down N2 with 1,000 psi on wellhead choke closed. At surface blowing down coil to tank. Wellhead secure. Total fluid recoverd for day 262 bbls. 2nd saw 100%LEL consistently. Shutting down equipment and securing wellsite. Well closed in with 1.162 psi. 08/30/2014-Saturday PTW and JSA. Rig up lub and PT to 250 psi low and 2,500 psi high. RIH with 3.27"GR and tag soft fill at 8,410'. POOH. RIH with 4.7"swab cups and swab from 1,350'to 1,720'. RIH with 2"bailer and tag fill at 8,305'. POOH. Bailer full sand. Gain 105' of sand. Rig down lub and secure well. n [.. BC-14A ACTUAL Pad 1A SCHEMATIC tlileorpAlaska.LI i 113' FSL, 1,388' FEL Permits 213-196 Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" TToopo Bottom Property Des: A-028083 0e MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ti. ' ND 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 'f , 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14Top Bottom MD 0' 2,122' ND 0' 2,122' i.___ 16"hole Cmt w/568 sks(254 bbl)of F,, 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 1, 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore -$. 9-5/8" L-80 40 ppf BTC 01 Tom Bottom k.' MD 0' 5,081' TOC(3/03/14 USIT)-4,725' TVD 0' 4,744'_,1 12-1/4"hole Cmt w/377 sks sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ r ,; S' r ppg Lead Class G cmt 4,857'4,879'MD -'-----_______,<441 . • Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' ND 0' 8,839' Al 8-1/2"hole Cmt w/972 sks(232 bbls) Tag(sand)@ 8,305'SLM of 15.3 ppg,Class G cmt w/EASYBLOK w/2.00"Bailer(8/30/14) \ . Casing/Cementing Detail - 9.6 ppg Mud Plug @ 8,530'ELM - 12.5 ppg Mud Push(34 bbl) 15.3 ppg Cement(232 bbl) \'..,\ . - 8.4 ppg Lease Water(200 bbl) • Plug @ 8,610'ELM 'i.. "' - Perforations: Tag(sand)@ 8,658'TPM ' itg_ Zone MD TVD Size SPF Date w/4.625"Bit(5/11/14) LB-28 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD _ LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD LB-28B ."f •"f�f'' - titi�ti11.1 ..!* -r•r•r-r. Fluid Level 8.4 ppg Lease Water LB-30 @ 9,000'CTM _ '..ti.ti.ti•�.ti:::p •r•r• •r•r•r '.Lti•ti•..•ti•ti•1•ti �r.r.r_r.ryy_ , . Casing Shoe @ 9,419' Openhole Casing 31'off bottom • Max Dogleg: TD PBTD 4.86°/100'@ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD g g70'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: • 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 8/30/2014 Schematic Revision Date: 9/24/2014 STATE OF ALASKA R E C E ED ALASKA OIL AND GAS CONSERVATION COMMIS..ON SEP 1 0 2014 r REPORT OF SUNDRY WELL OPERATIONS 1� / OGQC 1.Operations Abandon Li Repair Well Li Plug Perforations Ed Perforate Ed other" _dr f•--4.1_,,, Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ 1(4- Change Approved Program ❑ Operat.Shutdown Stimulate-Other ❑ Re-enter Suspended Well a•fy 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 213-196 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20539-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 Beaver Creek Unit(BCU)14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas 11.Present Well Condition Summary: 8,530; Total Depth measured 9,450 feet Plugs measured 8,610;8,852 feet true vertical 8,870 feet Junk measured N/A feet Effective Depth measured 9,335 feet Packer measured 4,857 feet true vertical 8,756 feet true vertical 4,559 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 145' 20" 145' 144' 3,060 psi 1,050 psi Surface 2,122' 13-3/8" 2,122' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,419' 5-1/2" 9,419' 8,839' 12,640 psi 11,080 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr 4,857'MD 4,559'ND 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 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 182 Subsequent to operation: 0 980 115 0 447 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil El Gas Q WDSPL El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-413 Contact Stan Porhola Email sDorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature leyik Phone 907-777-8412 Date VI t0 V. , .\., '/I( RBDMS SEP 1 0 20'� Form 10-404 Revised 10/2012 / j.ISubmit Original Only ?, i Hilcorp Alaska, LLC Well Operations Summary Well Name API Number •Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 7/15/14 7/19/14 Daily Operations: 07/15/2014-Tuesday Safety meeting prejob. Finish rigging up Schlumberger Coil Unit#12,Lay down pit liner,set two frac tanks and rig up lines. Mix 500 bbls.6%KCL. BOP test 250 low-4,500 high,5 min test,draw down test.Witness waived by Jim Regg,AOGCC. Valves on tree leaking,service valves. Pick up injection head,make up BHA,test. RIH pumping 700cfm N2,tag fill at 7,020',start .5bpm water with N2,Wash down to 7,050',pick up rate to.9bpm,1000cfm,POOH. fC L 07/16/2014-Wednesday Safety Meeting Pre job. Service equipment,load N2,pick up injection head,make up BHA. Run in hole start with 0.5 bpm,700 scf at 3,000 ft. Start washing fill at 7,020',pump 0.9 bpm, 1,000 scf N2,getting good returns. Tagged CIBP with coil at 8,728'. Wash clean,POOH,Rig down coil unit. Pumped 428 bbls.fluid,676,550 SCF N2. MIRU Pollard wireline,RIH with CIBP,tag at 7,321'. POOH. 07/17/2014-Thursday Pick up 2.25 gauge ring. RIH,tagged at 7,321'. POOH,Rig down Pollard. Rig up coil,make up motor head assy.and 5.65 superjoy mill. RIH to 7,318'tagged fill. Pick up and break circulation at 700 scf and 0.7 bpm,start washing down. Wash down to 8,728'. Pump 523bb1s fluid,676,550 scf N2,gained 90 bbls.fluid. 07/18/2014-Friday Pre job safety meeting. Rig down Schlumberger coil and break down motor head assy.and mud motor. Rig up Pollard wireline ,i r to run bridge plug. RIH with 3-1/8"GR/CCL#20 setting tool,4.24"bridge plug,set plug at 8,530',POOH,rig down Pollard. Rig up Schlumberger coil,make up jet nozzle,pick up injection head,tag 8,510'. Unload well to open frac tank,800-1,000 scf., pumped 596,600 scf,6500 gal.N2,recovered 276 bbls fluid. POOH with coil,well making water,open to production gas buster,well pressure decreasing,loading with water 500 psi. Shut in pressure,rig down coil. 07/19/2014-Saturday Safety Meeting JSA. Rig down coil unit,move to yard for maintenance and pump iron inspection. A, ) 11 BC-14A ACTUAL Pad 1A SCHEMATIC Hileorp Alaska,LLC 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Permit#: 213-196 Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083 MD 0' 145' • KB Elevation: 159.6' (18.6'AGL) 4, TVD 0' 145' Lat: N60° 38' 51.1588' Lona: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 `, •, 13-3/8" K-55 68 ppf BTC Rip Released: 02/09/14 Igg Bottom MD 0' 2,122' ND 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis • 8.0"Seal Diameter 4 ' Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ,., ,- TVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 • Swell Packer @ ppg Lead Class G cmt 4,857'-4,879'MD ---------____A Production Casing 5-1/2" P-110 20 ppf XP BTC r. Top Bottom • MD 0' 9,419' a ND 0' 8,839' A • / 8-1/2"hole Cmt w/972 sks(232 bbls) w' of 15.3 ppg,Class G cmt w/EASYBLOK i JJ ., Casing/Cementing Detail - 9.6 ppg Mud Plug @ 8,530'ELM - 12.5 ppg Mud Push(34 bbl) \'‘. ,• - 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM L 7 -Mk = Perforations: Tag(sand)@ 8,658'TPM _ - Zone MD TVD Size SPF Date w/4.625"Bit(5/11/14) LB-28 LB-27 8,477'-8,497' 7,905-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD , LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD +fg}-ii:f•}g-f LB 28B -R.{.icW.A{.t.ti - -SrLr�r4rti��r`rti Fluid Level ,• 8.4 ppg Lease Water LB-30 = - @ 9,000'CTM ----________ , ti„ti,,,.14. ' Casing Shoe @ 9,419' Openhole Casing 31'off bottom Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD g g70'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska _ Country: USA Angle @KOP and Depth: , 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 7/18/2014 Schematic Revision Date: 7/22/2014 L, ,n Ellison Hilcorp Alaska, LI- 3800 R,6GeoTeCh 3800 Centerpoint Drive, Suite100 a lcJ l Anchorage, AK 99503 Tele: 907 777-8339 Hilrnrp ala+ka.l.t.(. Fax: 907 777-8510 E-mail: lellison@hilcorp.com DATE 08/22/2014 To: Alaska Oil & Gas Conservation Commission 333 W 7th Ave Ste 100 Anchorage, AK A-1T1'J 99501 DATA TRANSMITTA C7uift Transmitted herewith are cuttings from BCU 14A WELL; SAMPLE IWERVAL „ BCU 14A 5120'-6540' BCU 14A 6560'-7440' BCU 14A 7460'-8660' BCU 14A 8660'-9450' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of thi t i�F t907 777.8510 Received By: Date: `� AUG 222014 ACC Angela K. Singh �w��\\I%% s� THE NATE �_ _acica ,:_ L�. i A E- - = �:., � _ � ; ,tea i�` 4:0t 333 We_t Sevcnih Avenue ' I GovL-RNo1Z SEAN PARNI;LL Anchorage, AtcAa 99501 3572 rT* main 957 27% 1433 LA 43 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 14A Sundry Number: 314-413 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this 15 day of July, 2014. Encl. -714 RECEIVED .y STATE OF ALASKA �`` R E ALASKA OIL AND GAS CONSERVATION COMMISSION J U L 1 1 2014 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations E • Perforate E • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Atter Casing❑ C7` ('C c Other: LEI 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑✓ • 213-196 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service 111 6.API Number. Anchorage,Alaska 99503 50-133-20539-01 ' 7.If perforating: 237A8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO),17ff A91 i,/ / T Beaver Creek Unit(BCU)14A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s). FEDA028083 • Beaver Creek/Beluga Gas Pod • 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): 9,450 8,870 ' 9,335 8,756 N/A WA Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic[1 Development n Service n 14.Estimated Date for 15.Well Status after pronnsed work: 07/15/14 Commencing Operations: Oil ❑ Gas ❑✓ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorholaOhilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature 0-✓"t,L/.- / Phone 907-777-8412 Date 7/c//, COMMISSION USE ONLY ` Conditions of approval. Notify Commission so that a representative may witness Sundry Number. G� Plug Integrity ElBOIL Test IZ Mechanical Integrity Test ❑ Location Clearance ❑ Other: X r--r SSU(; r s: 136 P f' ( c,Ta(_,j ) Spacing Exception Required? Yes ❑ No Subsequent Form Required: /tt •—y C,Li APPROVED BY .4,4,. Approved by: 6 p ( COMMISSIONER THE COMMISSION Date: 7.-/s----/y / 7_,1/'/lf Submit Form and ��otm_1 4031E vise }QI2L l` o Apo 4- months from the date of approval. Attachments in Duplicate MM JJ�ULL tj ( ,Y/5 ., ri.--) 78{ 41 Well Prognosis . Well: BCU-14A Hilcorp Alaska,LL Date:7/10/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: July 15th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: -3,370 psi @ 7,971'ND (Based on sample pressures from XPT pressures collected on 2/03/14 LB-28) Maximum Expected BHP: -3,370 psi @ 7,971'ND (Based on sample pressures from XPT pressures collected on 2/03/14 LB-28) Max. Allowable Surface Pressure: -2,573 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface.The initial zone (LB-30)was perforated and tested and showed poor performance.The 2nd zone (LB-28B)was perforated and sanded up on initial tests and failed • to produce after a coil tubing cleanout.The 3`d zone(LB-28)was perforated and failed to produce. No fill and . minimal water was seen from this zone.The 4th zone (LB-27)was perforated and shown to be productive. • However, water from the LB-28 is contributing to downhole hydrate formation.The well recently sanded off • and will be cleaned out with coiled tubing. The purpose of this work/sundry is to plugback the LB-28 and the associated water/sand from this interval and reperforate the LB-27. Notes Regarding Wellbore Condition • Last tag at 7,020' SLM on 7/09/14 w/2.50" bailer. Isr • Fluid level at 2,948' RKB on 7/09/14. f, SI"� • Well will be cleaned out with coil to the CIBP at 8,610' ELM. C /— Fc c, 4 152'1% z E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. 'J a. Tree connection is 9.5"OTIS. :P2(AA; 2. RU 5-1/2"CIBP. 3. RIH and set CIBP at+/-8,530' MD. V 4. RD E-line. / Coiled Tubing Procedure: 41. 5. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 6. RU 1.75" coil cleanout BHA. 7. RIH w/coil to 8,530' MD and tag CIBP. 8. Displace well fluids with Nitrogen. Well Prognosis Well: BCU-14A Hilcorp Alaska,LL) Date:7/10/2014 a. Estimated volume of displaced 6% KCI is 190 bbl. b. Measure starting and ending fluid volumes of flowback tank. 9. POOH w/coil. 10. RD Coiled Tubing. 11. Turn well over to production. E-line Procedure: 12. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5"OTIS. b. SITP will be 1,500 to 2,000 psi. 13. RU 3-3/8" 6 spf Pi Omega HC wireline guns(will use 1 each 20'gun). 14. RIH and re-perforate Lower Beluga (LB-27) interval from 8,477'-8,497' (1 run, total of 6 spf). a. Bleed tubing pressure to 1,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement PNL Log dated 3/13/14. e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands=2,600'to BCU-13. h. Spacing allowance is based on CO 237B, no spacing limitations in the Lower Beluga. • 15. RD E-line. 16. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic ..„... . n BC-14A ACTUAL Pad 1A SCHEMATIC Hilcorp Alaska,LL( 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#:- 21'3-19620" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083 •j MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ▪ I ND 0' 145' Lat: N60° 38' 51.1588' Lona: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 , ', ', 13-3/8" K-55 68 ppf BTC Riq Released: 02/09/14 Top Bottom MD 0' 2,122' ND 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt '+7 Tree cxn=9-1/2"Otis ` V •,V. 8.0"Seal Diameter • Fluid Level Intermediate Casing 5-1/8"Modified ID Bore 1k 2,948'RKB 9-5/8" L-80 40 ppf BTC •, Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' lira TVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of • 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ ppg Lead Class G cmt 4,857'4,879'MD ------------------hli Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' It ND 0' 8,839' Al 8-1/2"hole Cmt w/972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK Y. .3 Casing/Cementing Detail Tag(sand)@ 7,020'SLM • - 9.6 ppg Mud - 12.5 ppg Mud Push(34 bbl) w/2.50"Bailer(7/09/14) `i - 15.3 ppg Cement(232 bbl) L, - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM • K4-..7.'-:::.4-FP::-4 _ �•1 . M.• L= 7 �f.�r.r�fir= SiS?S $ Perforations: 0,15,=,.....8,.,„.s.:4, Zone MD TVD Size SPF Date Tag(sand)@ 8,658'TPM • .;: - LB-28 - ". {;:4 { LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 w/4.625"Bit(5/11/14) , /4-, . .•.•.•.•+•.• .• LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 tV. .V.14::::1 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD :•f•:•:•f::e,. LB-286 ti ti-t ti... Fluid Level -► 8.4 ppg Lease Water LB-30 = - - @ 9,000'CTM , • :ytiy}y~•ti•3•~•r' f-f-f-•f-e A . ILL Casing Shoe @ 9,419' Openhole ' Casing 31'off bottom �_ _� Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD8,870'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 7/9/2014 Schematic Revision Date: 7/10/2014 , n BC-14A PROPOSED Pad 1A SCHEMATIC flilcorp Alaska,LLc 113' FSL, 1,388' FEL . • .. .. r Sec. 33, T7N, R10W, S.M. PernrTt Conductor ") 20" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083 i • MD 0' 145' KB Elevation: 159.6' (18.6'AGL) TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 r ', 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 Top Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of , 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ,.. TVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ ppg Lead Class G cmt 4,85T-4,879'MD ---------_,,,........A Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2"hole Cmt w/972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK +J Casing/Cementing Detail - 9.6 ppg Mud • Plug @ 8,530'ELM I - 12.5 ppg Mud Push(34 bbl) '44 - 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM L 7 _ _ _ - Perforations: Tag(sand)@ 8,658'TPMfig Zone MD TVD Size SPF Date w/(sand)Bit(5111/14) LB-28 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" , 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 - -r LB-28B 8,715-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD _ LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD \ ,.f.,�^'�' ;7 LB-28B •••�•�•�•� r.f.f.f.f.f.r. -.1.p-.11...-..e.....-...:- Fluid 1:ti�1.1�:ti:L Fluid Level _ ,11i 8.4 ppg Lease Water LB-30 @ 9,000'CTM ,- Casing Shoe @ 9,419' A, '- - ..+. i-x 'a'•; Openhole ` Casing 31'off bottom • . .'`J Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD 7,901'-7,916'MD $870'TVD 8 756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease. A-028083 • County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 7/10/2014 Guhl, Meredith D (DOA) From: Janise Barrett (jbarrett@hilcorp.com] Sent: Tuesday, July 01, 2014 4:18 PM To: Davies, Stephen F (DOA); Monty Myers; Stan Porhola Cc: Schwartz, Guy L (DOA); Guhl, Meredith D (DOA); Bettis, Patricia K(DOA) Subject: RE: Reporting Compliance- Information Needed (Second Request) Attachments: BCU-1 B Update.zip; BCU 14A 10407 Updated 10407 with Schematic.pdf Meredith Attached are items 3 &4 Item#3 Updated BCU 14A 10-407 and updated schematic Item#4 BCU 1B Schematic and final surveys in zip for upload (gis text file included) Thank you! Janise Barrett Drilling Technician Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 100 Anchorage,Alaska 99503 Office:907-777-8389 Mobile:907-365-9856 jbarrett(i hilcorp.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.ciov] Sent: Tuesday, July 01, 2014 12:13 PM To: Monty Myers; Janise Barrett; Stan Porhola Cc: Schwartz, Guy L(DOA); Guhl, Meredith D (DOA); Bettis, Patricia K (DOA) Subject: Reporting Compliance - Information Needed (Second Request) Stan, Monty,Janise: Here are four requests for information sent by AOGCC to Hilcorp during mid-June that have not yet been filled. Please forward this information to Meredith Guhl so that she can complete her reporting compliance review of these well history files. 1. RE: SRU 11-22, PTD 213-055, Updated Well Schematic (Sent Mon 6/16/2014 9:48 AM) Please provide an updated well schematic for SRU 11-22 by 6/30/2014. 2. RE: SCU 33-05, PTD 175-039, Location of Well discrepancy (Sent Mon 6/16/2014 9:59 AM) Please provide the most recent surveyor's NAD 27 plat for this well so that the coordinates can be confirmed. Please provide the plat by 6/30/2014. 3. RE: Well Completion Report BCU-14A PTD 213-19 (Sent Mon 6/16/2014 10:26 AM) I have not received the updated 10-407 as requested, nor an updated well schematic. Please submit an updated 10-407 along with an updated well schematic by 6/30/2014. 1 4. RE: BCU-01B, PTD 214-001, Krs/GL elevations and schematic (Sent Mon 6/16/2014 9:40 AM) Can you clarify the discrepancy between the survey data and the schematic/10-407 numbers reported?Janise provided me with an updated schematic, but the discrepancy remains. Please provide the requested information by 6/30/2014. Thank you for your help. Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Guhl, Meredith D (DOA) Sent: Monday, June 16, 2014 10:26 AM To: Monty Myers; Janise Barrett; Stan Porhola Cc: Davies, Stephen F (DOA); Schwartz, Guy L(DOA) Subject: RE: Well Completion Report BCU-14A PTD 213-196 Monty and Stan, I have not received the updated 10-407 as requested, nor an updated well schematic. Please submit an updated 10-407 along with an updated well schematic by 6/30/2014. Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil[❑ Gas Q SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.WellClass: 20AAC 25.105 2OAAC 26,110 Development 2 Exploratory❑ GINJ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Hllcorp Alaska,LLC Aband.: 3/17/2014 213-196/314-195 3.Address: 8.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 1/25/2014 50-133-20539-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 113'FSL,1,388'FEL,Sec 33,17N,R10W,SM,AK 2/1/2014 Beaver Creek Unit(BCU)14A Top of Productive Horizon: 8.KB(ft above MSL): 158 15.Field/Pool(s): 1365 FSL,649 FEL,Sec 33,T7N,R10W,SM,AK GL(ft above MSL): 141 Total Depth: 9.Plug Back Depth(MD+TVD): Beaver Creek/Beluga Gas 2,123'FSL,124 FWL,Sec 34,T7N,R1OW,SM,AK 9,335'MD/8,756'TVD 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 314368.2 y-2430071.4 Zone- 4 9,450'MD/8,870'ND FEDA028083 WI: x- 315127 y-2431311 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit Total Depth: x- 315912 y-2432057 Zone- 4 N/A N/A 18.Directional Survey: Yes Q No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed Information per 20 MC 25.050) N/A (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Laterat Top Window MD/TVD: See attachment 5081'MD/4744'TVD 23. CASING,LINER AND CEMENTING RECORD Wr.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING Fl. GRADE TOP _ BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 5-1/2" 20 P-111 Surf 9,419' Surf 8,839' 8-1/2" 972 sks Class G 24.Open to production or injection? Yes Q No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A N/A Zone MD ND Size SPF Date LB-27 8,47T-8,49T 7,905'-7,925' 3-3/8" 12 5/23/14 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 Was hydraulic fracturing used during completion? Yes❑ No ❑r LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 N/A 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.). N/A Not flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period .—p Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate —0 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑✓ Sidewall Cores Acquired? Yes❑ No❑, If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,care chips,photographs and laboratory analytical results per 20 AAC 25.071. 1 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? des Do If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top and submit detailed test information per 20 MC 25.071. Permafrost-Base Sterling B2 5468 5084 Sterling B4 5682 5252 Middle Beluga 6544 6399 Beluga 617 7730 7171 Beluga 824 8381 7811 Beluga B28 8536 7963 Beluga B28B 8710 8802 Lower Beluga LB-30 Tight non productive Formation at total depth: Tyonek 9450 8870 31. List of Attachments: Schematic,Directional Survey,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email:_fpfpyerS(()h11COrD.Corn Printed Name: Monty Myers Title: Drilling Engineer Signature: '- • Phone:907-777-8431 Date: • I • Z.0 141. 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 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b:TPI(Top of Producing Interval). Item 8:The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given In other spaces on this form and In any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23:Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing Intervals for only the interval reported in Item 26. (Submit a separate form for each additional Interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of Intervals cored and the corresponding formations,and a brief description In this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 10/2012 II BC-14A ACTUAL Pad 1A SCHEMATIC Ililcorp Alaal:n,t,l.c 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 213-196 20" K-55 133 ppf API#: 50-133-20539-01-00 Too j1ottom Property Des: A-028083 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ' TVD 0' 146' Lat: N60° 38' 51.1588' I Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 , 13-318" K-56 68 ppf BTCRiq Released: 02/09/14Int Toe Bottom MD 0' 2,122' ' 2,122' L-_ 16"hole Cm w/668 sks(264 bbl)of • 12.0 ppg,Class G cmt Tree cxn=9-112"Otis +�? 8.0"Seal Diameter Intermediate Casing 6-1/8"Modified ID Bore ,)"p 9-5/8" L-80 40 ppf BTC '# ,--->i;'; Bottom �. MD 0' 5,081' TOC(3103/14 USIT)-4,725' TVD 0' 4,744' ', 12-1/4"hole Cmt w/377 eke(141 bots)of 12.6 ppg Tail&610 sks(106 bbls)of 13.5 Swell Packer @ ' t ppg Lead Class G cmt 4,857'-4,879'MD ••, Production Casing 5-1/2" P-110 20 ppf XP ETC Top Bottom MD 0' 9,419' TVD 0' 8,839' LTJ/N 1) 't..7 8-1/2"hole Cmt w/972 sks(232 bbls) i .C.6 V• of 15.3 ppg,Class G cmt w/EASYBLOK Casing/Cementing Detail - 9.6 ppg Mud Tag(sand)©8,575'ELM 12.5 ppg Mud Push(34 bbl) w/3.375"Guns(5/23/14) -.1 - 15.3 ppg Cement(232 bbl) \., - 8.4 ppg Lease Water(200 bbl)Plug @ 8,610'ELM L --.7\4 Perforations: Tag(sand)@ 8,658'TPM Zone MD ND Size SPF Date w/4.62V Bit(5!11114) LB-28 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23114 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 • ~'i•_ LB-28B 8,716-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD • ` _ , LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD \ ' • ••�-•• LB-286 `"�`�`�`"" �S#i�i;Sf��7S��'1 Fluid Level FFa.�� 8.4 ppg Lease Water LB-30 T @ 9,000'CTM 1 4 ZQ int. 1 Aie:41,. `,y1 Casing Shoe @9,419' r :''<; ',+ Openhole Casing 31'off bottom Max Dogleg: TD PBTD 4.86°/100'@ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD g g70'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' I Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/23/2014 Schematic Revision Date: 5/28/2014 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, June 16, 2014 10:26 AM To: 'Monty Myers'; 'Janise Barrett'; 'Stan Porhola' Cc: Davies, Stephen F (DOA); Schwartz, Guy L(DOA) Subject: RE: Well Completion Report BCU-14A PTD 213-196 Monty and Stan, I have not received the updated 10-407 as requested, nor an updated well schematic. Please submit an updated 10-407 along with an updated well schematic by 6/30/2014. Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 From: Guhl, Meredith D (DOA) Sent: Wednesday, May 28, 2014 1:38 PM To: 'Janise Barrett' Cc: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: RE: Well Completion Report BCU-14A PTD 213-196 Janise, Further review of the 10-407 packet has been completed. In Box 30 regarding formation tests, it was noted that the FM top for LB-30 and the top& bottom measured depths for intervals tested were not included on the form. Could you please submit an updated 10-407 with these details? Also, regarding your email below, if perfs were shot,then plugged,they must be shown on the schematic. Please submit an updated schematic that matches the operations summary. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov 1 Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Janise Barrett [mailto:jbarrett@hilcorD.com] Sent: Thursday, April 24, 2014 4:39 PM To: Guhl, Meredith D (DOA) Subject: RE: Well Completion Report BCU-14A PTD 213-196 Meredith, Regarding the BCU 14A they plugged the other perf so I think that is why Stan Porhola (operations engineer)took it off the schematic that was sent in with the 10-407. I believe they are planning to shoot another perf -I found a proposed schematic in with the actual so am including it just in case they have already done the work(they do not tell drilling their workover/completion schedule- I am strictly drilling but I apologize for all these mistakes and will do my best to get these issues straightened out) Again,thank you for your patience and willingness to work with us to get these issues corrected. Thank you! Janise Barrett I Drilling Technician Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 100 Anchorage,Alaska 99503 Office:907-777-8389 Mobile:907-365-9856 jbarrett(a!hi lcorp.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, April 24, 2014 11:32 AM To: Janise Barrett; Monty Myers Cc: Davies, Stephen F (DOA); Schwartz, Guy L(DOA) Subject: Well Completion Report BCU-14A PTD 213-196 Janise, During further review of the Well Completion Report for Beaver Creek Unit 14A, I noticed several issues with the form. In Box 22, N/A is listed for re-drill/lateral top window.According to the daily operating summary, on Jan 23 a window was milled from 5081'to 5098'. In the future please list the top of the window in this box. In Box 24,only one perforation is listed.According to the daily operating summary,on March 28 a second round of perfs were shot which are not listed on the well completion form. 2 I will update the form by hand for these two items above. We do, however, need a new well schematic that shows the two zones of perforations.The current well schematic only shows the initial perfs. Please email me an updated well schematic, I will attach it to the Well Completion Report. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,June 04, 2014 11:35 AM To: 'Stan Porhola' Cc: Hunt,Jennifer L(DOA) Subject: RE: BCU 07 (PTD 176-006) and BCU 14A(PTD 213-196) Sundry reports Stan, I checked and you are correct that the sundries were retracted... FYI in the future if a sundry is retracted then you don't need to follow up with a 10-404 report. The sundry is "dead " to us. I didn't think to look for the retraction letters until you mentioned them below. Please pass this on to your other staff also. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz©alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent:Tuesday, June 03, 2014 4:27 PM To: Schwartz, Guy L(DOA) Cc: Hunt, Jennifer L(DOA) Subject: RE: BCU 07 (PTD 176-006) and BCU 14A(PTD 213-196) Sundry reports Guy, The sundry and work scope for BCU-07 (314-177) was replaced by the sundry and work scope of(314-290). The sundry and work scope for BCU-14A (314-246) was replaced by the sundry and work scope of(314-291). We sent those 10-404's to more or less closeout or cancel the proposed sundries that were superseded. Let me know if we need to do anything else? Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz&alaska.gov] Sent:Tuesday, June 03, 2014 3:31 PM To: Stan Porhola Cc: Hunt, Jennifer L(DOA) Subject: RE: BCU 07 (PTD 176-006) and BCU 14A(PTD 213-196) Sundry reports 1 Stan, Did you have a chance to look into these? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guv.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Wednesday, May 21, 2014 9:52 AM To: Stan Porhola Cc: Hunt, Jennifer L(DOA) Subject: BCU 07 (PTD 176-006)and BCU 14A (PTD 213-196) Sundry reports Stan, We got these two sundry 10-404's(314-177 and 314-246) with the just the cover page. Can you send us complete reports. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 2 • STATE OF ALASKA RECEIVED ALA— A OIL AND GAS CONSERVATION COMMIS..,,ON REPORT OF SUNDRY WELL OPERATIONS MAY 13 Z014' 1.Operations Abandon LI Repair Well U Plug Perforations Li Perforate U Other U AOG CC 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 E Exploratory ❑ 176-006 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20284-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028118 Beaver Creek Unit(BCU)07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver C •- /Sterling Gas 11.Present Well Condition Summary: 7,830'Cmt Total Depth measured 15,476 feet Plugs meas ed 5,600'Howco BP feet true vertical 15,476 feet Junk •sured N/A feet Effective Depth measured 5,600 feet Pac er measured 4,992' feet true vertical 5,600 feet true vertical 4,992' feet Casing Length Size 4(- ND Burst Collapse Structural Conductor 40' 30" 6..4D 40' Surface 2,077' 20" 2,077' 2,077' 3,060 psi 1,500 psi Intermediate 5,625' 13-3/8" 5,6 ' 5,625' 3,450 psi 1,950 psi Production 12,526' 9-5/8" ,526' 12,526' 6,870 psi 4,750 psi Liner Perforation depth Measured depth See Attached .chematic True Vertical depth See Att• hed Schematic Tubing(size,grade,measured and true vertical depth 3-1/2" 9.2#/N-80 4,960'MD 4,960'ND 4,922'MD Packers and SSSV(type,measured and true ve ' •I depth) Baker FH Pkr 4,922'ND N/A N/A 12.Stimulation or cement squeeze summary. N/A Intervals treated(measured): N/A Treatment descriptions including volum s 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 ..eration: 0 0 0 26 0 Subsequent to .•-ration: 0 0 0 26 0 14.Attachments: 15.Well Class after work. Copies of Logs and Surveys Run N/A Exploratory❑ Development Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-177(Close Out) Contact Stan Porhola Email sporhola(c hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature _11P Phone 907-777-8412 Date5 l? ,/ Lf RBCM MA 14 201& Form 10-404 Revised 10/2012 ,41-P544 Submit Original Only V 7 333 'oves1 Seventh A venue ,,-, GCv1.R\'oK S)•,AN i'Af:;Nr:i,,. Fnchcooe, Alcsl.a 990'-3572 0 . _ ,`" i,' ,c11 907 279 1433 ALRS � , c Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 14A Sundry Number: 314-339 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CA... /3)24_1 4.,..... Cathy P Foerster Chair n Al— DATED this2 day of June, 2014. Encl. A RECEIVED STATE OF ALASKA MAY 2 9 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION 97.5 h/2//4I APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon El Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel Cl Stimulate❑ Atter Casing❑ Other. Install Cepstring Q• 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development Q 213-196 . 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service 1:16.API Number. Anchorage,Alaska 99503 50-133-20539-01 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237.001 Beaver Creek Unit(BCU)14A . Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 Beaver Creek/Beluga Gas Pod 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,450 ' 8,870 • 9,335 8,756 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigrephicn Development pi Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations. 06/03/14 Oil ❑ Gas ❑✓ • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR Cl SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email soorhola(c hilcorD.com Printed Name Stan/P//o�rhola Title Operations Engineer Signature „elle-C-1r✓�--- Phone 907-777-8412 Date 5/21/Y COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .-2 ‘Ll— 33 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 12/ Subsequent Form Required: 1 6._ 4-1 c;f-1 APPROVED BY Approved by: Pf7 COMMISSIONER THE COMMISSION Date: C-2-71' 5,3'2,.. I N T' Submit Form and orrn 10-403 R v'sed 10/2 2 Appro e I i T onths from the date of approval. Attachments in Duplicate Well Prognosis Well: BCU-14A Hilcorp Alaska,LL) Date:5/28/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: June 3`d, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —3,370 psi @ 7,971' TVD (Based on sample pressures from XPT pressures collected on 2/03/14 LB-28) Maximum Expected BHP: —3,370 psi @ 7,971'TVD (Based on sample pressures from XPT pressures collected on 2/03/14 LB-28) Max. Allowable Surface Pressure: —2,573 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface.The initial zone (LB-30)was perforated and tested and showed poor performance.The 2"d zone (LB-28B)was perforated and sanded up on initial tests and failed to produce after a coil tubing cleanout.The 3`d zone (LB-28)was perforated and failed to produce. No fill and minimal water was seen from this zone.The 4th zone (LB-27)was perforated and shown to be productive. However,water from the LB-28 is contributing to downhole hydrate formation. The purpose of this work/sundry is to install a capstring to manage hydrate formation &water production. Notes Regarding Wellbore Condition • Last tag at 8,575' ELM on 5/23/14 w/3.375" hollow carriers. Capstring Procedure: 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. 2. Install new wellhead packoff. a. Current tree connection is 9.5"OTIS. 3. PU 3/8"capillary string. RIH and set at+/-2,500'. 4. Set spool of remaining line near well. 5. Rig down Cap String Truck. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • .. ii BC-14A ACTUAL Pad 1A SCHEMATIC HiIcorp Alaska.1.1 i 113' FSL, 1,388' FEL Permit# 213 196 , Sec. 33, T7N, R10W, S.M. Conductor 133 API#: 50-133-20539-01-00 20 T p5 Bottomf Property Des: A-028083 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) I TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 , 13-3/8" K-55 68 ppf BTC Riq Released: 02/09/14 Top Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom ,,' MD 0' 5,081' TOC(3/03/14 USIT)-4,725' 14 TVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of ,. 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ +�, tr ppg Lead Class G cmt 4,857'-4,879'MD Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 4 8-1/2"hole Cmt w/972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK • Casing/Cementing Detail - 9.6 ppg Mud Tag(sand)@ 8,575'ELM - 12.5 ppg Mud Push(34 bbl) w/3.375"Guns(5/23/14) - 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM . L 7 = Perforations: Tag(sand)@ 8,658'TPM Zone MD TVD Size SPF Date w/4.625"Bit(5/11/14) LB-28 LB-27 8,477'-8,497' 7,905'-7,925' 3-3/8" 12 5/23/14 rJ• r.r.r • LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 " s""`�"" LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD - _ LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD �;:F}:i:}:}:;: LB-28B =�•+•�•+•+•+•+•+ - r•rit.54 SI: Fluid Level 8.4 ppg Lease Water LB-30 = @ 9,000'CTM _________. :::;.•::::::::::::::::% . .J.J. l }.J.J .l.l.J.J.J.J.J_ A -. •‘ Casing Shoe @ 9,419' Openhole Casing 31'off bottom �_ � Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,90V-7,916'MD 8,870'ND 8 756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/23/2014 Schematic Revision Date: 5/28/2014 .,, illi BC-14A PROPOSED Pad 1A SCHEMATIC Ltikorp Alaska.UA 113' FSL, 1,388' FEL Permit#: 213-196 Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" TToo lt ppf p BooBottom Property Des: A-028083 r MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ND 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 , ', , 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 Toe Bottom MD 0' 2,122' ND 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis : / 8.0"Seal Diameter t Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' / ND 0' 4,744'sks J 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ . + ppg Lead Class G cmt 4,857'-4,841 MD Production Casing 5-1/2" P-110 20 ppf XP BTC Capillary Jinn (Proposed Install) Top Bottom 3/8"OD 2205 0.049" MD 0' 9,419' Stainless Steel Wall Thickness ND 0' 8,839' Top Bottom A 8-1/2"hole Cmt w/972 sks(232 bbls) MD 0' 2,500' of 15.3 ppg,Class G cmt w/EASYBLOK ND 0' 2,497' Casing/Cementing Detail - 9.6 ppg Mud Tag(sand)@ 8,575'ELM - 12.5 ppg Mud Push(34 bbl) w/3.375"Guns(5/23/14) - 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM L 7 - _ Perforations: ----\ Tag(sand)@ 8,658'TPM Zone MD ND Size SPF Date w/4.625"Bit(5/11/14) LB-28 LB-27 8,477'-8,497' 7,906-7,925' 3-3/8" 12 5/23/14 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 "' "` LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 Cement top @ 8,836'MD , LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug @ 8,852'MD \ LB-288 `•f 'T }.St..r.r.r. . Fluid Level 8.4 ppg Lease Water LB-30 = @ 9,000'CTM ►itis4,1 }.7•}1*}ti . • Casing Shoe @ 9,419' .<. ,, t, .,, T, Openhole ' Casing 31'off bottom v= ' _ Max Dogleg: TD PBTD 4.86°/100'@ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD 8,870'TVD 8 756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' I Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL):_ 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 5/29/2014 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, May 28, 2014 1:38 PM To: 'Janise Barrett' Cc: Davies, Stephen F (DOA); Schwartz, Guy L(DOA) Subject: RE: Well Completion Report BCU-14A PTD 213-196 Janise, Further review of the 10-407 packet has been completed. In Box 30 regarding formation tests, it was noted that the FM top for LB-30 and the top& bottom measured depths for intervals tested were not included on the form. Could you please submit an updated 10-407 with these details? Also, regarding your email below, if perfs were shot,then plugged, they must be shown on the schematic. Please submit an updated schematic that matches the operations summary. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Janise Barrett [mailto:jbarreft hilcorp.com] Sent: Thursday, April 24, 2014 4:39 PM To: Guhl, Meredith D (DOA) Subject: RE: Well Completion Report BCU-14A PTD 213-196 Meredith, Regarding the BCU 14A they plugged the other perf so I think that is why Stan Porhola (operations engineer)took it off the schematic that was sent in with the 10-407. I believe they are planning to shoot another perf - I found a proposed schematic in with the actual so am including it just in case they have already done the work(they do not tell drilling their workover/completion schedule- I am strictly drilling but I apologize for all these mistakes and will do my best to get these issues straightened out) ) Again,thank you for your patience and willingness to work with us to get these issues corrected. 1 Thank you! Janise Barrett I Drilling Technician Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 100 Anchorage,Alaska 99503 Office:907-777-8389 Mobile:907-365-9856 jbarrctt(a?hilcorp.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.govl Sent: Thursday, April 24, 2014 11:32 AM To: Janise Barrett; Monty Myers Cc: Davies, Stephen F(DOA); Schwartz, Guy L(DOA) Subject: Well Completion Report BCU-14A PTD 213-196 Janise, During further review of the Well Completion Report for Beaver Creek Unit 14A, I noticed several issues with the form. In Box 22, N/A is listed for re-drill/lateral top window.According to the daily operating summary,on Jan 23 a window was milled from 5081'to 5098'. In the future please list the top of the window in this box. In Box 24,only one perforation is listed. According to the daily operating summary, on March 28 a second round of perfs were shot which are not listed on the well completion form. I will update the form by hand for these two items above. We do, however, need a new well schematic that shows the two zones of perforations.The current well schematic only shows the initial perfs. Please email me an updated well schematic, I will attach it to the Well Completion Report. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 - x = ,�y:j — -- – -- ---- 333 \h'c. t Sevcni;. i, e "%= :-4417/ t;s_a\' ;?1,r�71t SI=,.'ti _'`,I.�'I:I I anchorage, AlaskaaSS501-3572 \ i_'"7.'i c i. 1 Stan Porhola Operations Engineer Hilcorp Alaska, LLC I 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 O''`3 el/6 Re: Beaver Creek/Beluga Gas Pool, BCU 14A Sundry Number: 314-320 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, - 7():712 V------ , Cathy P oerster Chair DATED this 2day of May, 2014. Encl. RIED' . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 6 2014 /Z , APPLICATION FOR SUNDRY APPROVALS c1<+ 4-AD 20 AAC 25.280 C ,1' • 5-14.,/ 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑✓ • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing El Other ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 2 213-196 . 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service El6.API Number. Anchorage,Alaska 99503 50-133-20539-01 • 7.If perforating: /jO 8.Weil Name end Number. [; L 7.1 I _ What Regulation or Conservation Order governs well spacing in this pool? _ -- ❑ S •14,4/ Beaver Creek Unit(BCU)14A • Will planned perforations require a spacing exception? Yes ❑ No � 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 ' Beaver Creek/Beluga Gas Pod • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,450 ' 8,870 • 9,335 8,756 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(It): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after prolosed work: C05/17/14 7 Commencing Operations: / Oil ❑ Gas 2 • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature ,j'eCr'nPhone 907-777-8412 Date V/ofri COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 1/-(- 32c� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No NoEl Subsequent Form Required: I 0— 1a`t Approved by: 2/2P )'-"' RttN AL THE OMMISSION Date: S— 2a—/ /fir �� Submit Form and R�FgrP X03�R��i�elq�Zg1� Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: BCU-14A ' Hilcorp Alaska,LL' Date:5/16/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: May 17th, 2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907) 229-4824(M) AFE Number: 1313435 Current Bottom Hole Pressure: —3,370 psi @ 7,971' TVD (Based on sample pressures from XPT pressures collected on 2/03/14 LB-28) Maximum Expected BHP: —3,705 psi @ 7,815' ND (Based on sample pressures from XPT pressures collected on 2/03/14 LB-24) Max. Allowable Surface Pressure: —2,924 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface.The initial zone (LB-30)was perforated and tested and showed poor performance.The 2nd zone (LB-28B)was perforated and sanded up on initial tests and failed to produce after a coil tubing cleanout.The 3`d zone (LB-28)was perforated and failed to produce. No fill and minimal water was seen from this zone. The purpose of this work/sundry is to perforate a new lower Beluga sand (and contingency intervals). Notes Regarding Wellbore Condition • Last tag at 8,610' RKB on 5/15/14 w/3.375" hollow carriers. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,500 to 2,000 psi. 2. RU 3-3/8" 6 spf P1 Omega HC wireline guns (will use 1 each 20'gun). 3. RIH and perforate Lower Beluga (LB-27) interval from 8,477'-8,497' (1 run,total of 6 spf). a. Bleed tubing pressure to 1,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement PNL Log dated 3/13/14(Tie-in log depth is 8,477'-8,497'). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands=2,600'to BCU-13. h. Spacing allowance is based on CO 237, no closer than 1,320'. 4. RD E-line. 5. Turn well over to production. 6. If LB-27 is non-productive. 7. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. Well Prognosis Well: BCU-14A Hi!cora Alaska,LL Date:5/16/2014 a. Tree connection is 9.5" OTIS. b. SITP will be 1,500 to 2,000 psi. 8. RU 3-3/8" 6 spf PJ Omega HC wireline guns(will use 2 each 20'guns). 9. RIH and perforate Lower Beluga (LB-24) interval from 8,385'-8,405' (2 runs,total of 12 spf). a. Bleed tubing pressure to 1,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement PNL Log dated 3/13/14(Tie-in log depth is 8,385'-8,405'). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands=2,600'to BCU-13. h. Spacing allowance is based on CO 237, no closer than 1,320'. 10. RD E-line. 11. Turn well over to production. 12. If LB-24 is non-productive. 13. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5"OTIS. b. SITP will be 1,500 to 2,000 psi. 14. RU 3-3/8" 6 spf PJ Omega HC wireline guns(will use 2 each 13'guns, and 2 each 15'guns). 15. RIH and perforate Lower Beluga (LB-23) interval from 8,290'-8,303' (2 runs,total of 12 spf)and 8,250'-8,265' (2 runs,total of 12 spf). -----d tubing pressure to 1,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB Cement PNL Log dated 3/13/14(Tie-in log depth is 8,290'-8,303'and 8,250'-8,265'). e. Use Gamma/CCL/to correlate. f. Record tubing pressures before and after each perforating run. g. Distance to nearest well open in same sands=2,550'to BCU-16. h. Spacing allowance is based on CO 237, no closer than 1,320'. 16. RD E-line. 17. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic . .11 BC-1,1, 4A ACTUAL Pad 1A SCHEMATIC Hitcorp Alaska,LL( 113' FSL, 388' FEL Pert 213-196 Sec. 33, T7NR10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083 ' TMD 0' 145' VD 0' 145' KB Elevation: 159.6' (18.6'AGL) ;' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" +! . , Surface Casing Spud Date: 01/24/14 i 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 Top Bottom MD 0' 2,122' f • TVD 0' 2,122' l 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter ' Intermediate Casing_ 5-1/8"Modified ID Bore . 9-5/8" L-80 40 ppf BTC Top Bottom . . MD 0' 5,081' TOC(3/03/14 USIT)-4,725' TVD 0' 4,744' 12-1/4"hole Cmt wl 377 sks(141 bbls)of • 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ i . t ppg Lead Class G cmt 4,857'-4,879'MD • Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2"hole Cmt w/972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK R P-:: 0 Casing/Cementing Detail - 9.6 ppg Mud - 12.5 ppg Mud Push(34 bbl) i if - 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM + I frt b Perforations: Tag(sand)@ 8,658'TPM Zone MD TVD Size SPF Date w/ sand)Bit(5J11/14) LB-28 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 -y + LB-28B 8,715-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 , LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD _ , Plug @ 8,852'MD LB-28B ""ms..ti.1 's ti.. .ti.�.ti-.= - wf,tJlr1r1f1r1_ Fluid Level 8.4 ppg Lease Water LB-30 @ 9,000'CTM ti.ti.ti:', tiK J•J.J.J!J,J-J: - .*. Casing Shoe @ 9,419' * Openhole ' Casing 31'off bottom Max Dogleg: TD PBTD 4.86°/100'@ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD 8870'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number:_ Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/15/2014 Schematic Revision Date: 5/16/2014 11 BC-14A PROPOSED -fa Hikkora Alaska,LL(: 113' FSLPad, 1,3881A ' FEL SCHEMATIC Sec. 33, T7N, R10W, S.M. Conductor Permit#: 213-196 20" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083MD 0' 145' KB Elevation: 159.6' (18.6'AGL) TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" surface Casing Spud Date: 01/24/14 r ', 13-3/8" K-55 68 ppf BTC Rid Released: 02/09/14 • -1:e Bottom MD 0' 2,122' ND 0' 2,122' A 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt * Tree cxn=9-1/2"Otis " • 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore 'P. 9-5/8" L-80 40 ppf BTC ` f,` Top Bottom 'k* MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ,,. TVD 0' a 12-1/4"hole Cmt wl 377 sks(141 bbls)of *4, sks 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ r ppg Lead Class G cmt 4,857'-4,879'MD , -' Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' ,' x TVD 0' 8,839' A 't 8-1/2"hole Cmt wl 972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK Casing/Cementing Detail - 9.6 ppg Mud LB-23 -." "L - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) LB-23 - ! - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM LB-24 x! L' .27t7 Perforations: Tag(sand)@ 8,658'TPM ., Zone MD TVD Size SPF Date w/4.625"Bit(5J11/14) LB-2 \11, LB-23 8,250'-8,265' 7,682'-7,697' 3-3/8" 12 Proposed v' LB-23 8,290'-8,303' 7,721'-7,734' 3-3/8" 12 Proposed - ilr LB-24 8,385-8,405' 7,815-7,835' 3-3/8" 12 Proposed Cement top @ 8,836'MD - 1 LB-27 8,477'-8,497' 7,905-7,925' 3-3/8" 12 Proposed Plug @ 8,852'MD =4.::'.1:;:::::;.";::::::::::1.1= LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-286 -"cftiftiftirtirtiftir1LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306 3-3/8" 12 3/17/14 Fluid Level .• 8.4 ppg Lease Water LB-30 = - @ 9,000'CTM ;.ti.ti.ti.ti.ti...ti -i-r.r_i-•r.r_r_ . Casing Shoe @ 9,419' Openhole Casing 31'off bottom • Max Dogleg: TD PBTD 4.86°/100'@ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD 8 870'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' • Date Completed: 2/6/2014 _ Ground Level(above MSL). 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 5/16/2014 ALA .OIL AND GAS CONSERVATION COMM'. iN " REPORT OF SUNDRY WELL OPERATIONS MAY 2 9 2014 1.Operations Abandon Lf Repair Well Ll Plug Perforations Lf Perforate ❑r Other LI, OG OG C Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ 'f Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work• 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC 11 Development Q Exploratory ❑ 213-196 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 0 50-133-20539-01 7.Property Designation(Lease Number): 8.Well Name and Number: V FEDA028083 % Beaver Creek Unit(BCU)14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • N/A Beaver Creek/Beluga Gas 11.Present Well Condition Summary: Total Depth measured • 9,450 feet Plugs measured N/A feet true vertical 8,870 feet Junk measured N/A feet Effective Depth measured 9,335 feet Packer measured N/A feet true vertical 8,756 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A tBDM MAY 20 ZDV' 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 1850 Subsequent to operation: 0 0 0 0 1896 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0% Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 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: 314-291 Contact Stan Porhola Email sporho'a(a hi'corp.com Printed Name Stan Porhola Title Operations Engineer Vic1N-- Signature - /� ,PPhone 907-777-8412 Date 5--2Z -- /'7 Form 10-404 Revised 10/2012 "fr-5// l Submit Original Only y Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 5/9/14 5/15/14 Daily Operations: 05/09/2014-Friday Rig up on well 14A. Nipple down tree. Nipple up BOP. 05/10/2014-Saturday Attempt to test BOP. Wear bushing will not got through stack. Sent to machine shop to be turned down. Attempt to test what we can. Blind rams leaking. Call Knight Oil Tools to send out hand to check it out. Test manifolds. Knight on location. Repair blind rams. Good test on blind rams. Finish BOP test. (250 low-3,000 high). Witness waived by Jim Regg,AOGCC. RIH w/4-5/8"bit,10 ea. 3-1/8"drill collars and 2-7/8"PH6 work string. 73 jts of 2-7/8"in the hole fluid displacing out the tubing. Reverse circulate. Fluid stopped. RIH,after 2 joints fluid displacing again. Circulate long way. Still displacing out the tubing. No displacement on the annulus. Volume too great to continue in the hole. POOH and lay down bit and collars. RIH w/2-7/8"PH6 cut joint on end of string. No displacement issues. Tag fill at 8,511'. Rig up power swivel to wash. 05/11/2014-Sunday On bottom-8,511'. Rig up power swivel. Power pack for power swivel not working. Start washing down. Pump in sub leaking. Discover sub has a hole in it. Lay down pump in sub. Make up new one. Wash down 15'to 8,526'. Got small amount of gas back. Switch returns to gas buster. Fill became too hard. Could not make anymore progress. Rig up tubing swivel. Attempt to rotate pipe with tongs. Pipe torquing up. Not making progress with 2-7/8"PH 6 cut joint on bottom. POOH while waiting on Moncla to obtain power swivel from Knight Oil Tools. OOH. Lay down cut joint. MU 4-5/8"bit and bit sub. RIH. At 1,630'Moncla discovered the kill switch on the power swivel power pack was the reason it was not running. The night push re-wired the kill switch and the power pack worked. 1 joint short of tag depth,rig up power swivel. Tag fill at 8,526'. Start washing down. 50 rpm,2-1/2 bpm @ 400 psi. Washed to 8,658'. Reverse circulate @ 4 bpm. 120 bbls pumped. Rig down power swivel. POOH. Rig up wireline. RIH w/gauge ring. 05/12/2014-Monday RIH w/wireline gauge ring. POOH w/wireline gauge ring. Waiting on compressor to be installed on rig. Rig up and running. Pick up CIBP. RIH and set at 8,610'. POOH w/wireline. OOH w/wireline. Rig down wireline. Test CIBP to 2,200 psi for 30 minutes. RIH to 4,024'. Rig up to pump N2. Pump N2. 1st displacement finished. +/-78 bbls recovered from well. Bleed off N2. RIH to 8,595'. Pump N2. Hole displaced.+/-90 bbls recovered from 2nd displacement. Total fluid recovered from hole- +/-168 bls. Bleed off N2. Rig down N2 and circulating equipment. POOH,laying down 2-7/8"7.9 ppf PH6 workstring. Install BPV. Nipple down BOP. 05/13/2014-Tuesday Nipple down BOP,nipple up tree. Rig down and move to BCU 07. 05/15/2014-Thursday Mobe to location and rig up lubricator. PT lubricator to 250 psi low and 3,500 psi high. Open well up and TP was 1,850 psi. Baker had pressured well up to 1,300 psi a few days before. RIH w/3-3/8"x 17',6 spf,60 deg phase perf gun and tie into log sent electronic. Tagged something at 7,300'and pushed to bottom at 8,610'. Ran correlation pass and sent to town. Got ok to perf. Logged into position with gun from 8,543'to 8,560'. Fired gun with 1,900 psi on tubing. No pressure increase. POOH. RIH with same as above and perfed same zone with same results. POOH. Rig down Pollard E-Line and turn well over to field. 05/16/2014-Friday RU lubricator and PT to 250 psi low and 3,500 psi high. RIH w/4.55"swedge and tag at 8,632'. FL at 8,500'. RIH w/2.5"bailer to 8,632',get sample and POOH. Heavy formation sand in bailer. Flow well dropping TP from 1,810 psi to 1,600 psi. RIH and find FL at 8,460'. Drop psi from 1,600 to 1,400 psi. Found FL at 8,420'. Rig down slickline. . ACTUAL BC-14A Pad lA SCHEMATIC Hileori,Alaska. I.I.t: 113' FSL, 1,388' FEL Permit#: 213-196 SeC. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ND 0' 145' Lat: N60° 38' 51.1588' Lona: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 Il ', , 13-3/8" K-55 ppf BTC Riq Released: 02/09/14 - B(6)1-8tom MD 0' 2,122' ND 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing_ • 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC ' =Toy Bottom ,.: MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ., ,' ND 0' 4,744' ' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ ' ti' ppg Lead Class G cmt - 4,857'-4,879'MD -------_____..... .4 • • Production Casing 5-1/2" P-110 20 ppf XP BTC ,f. Top Bottom MD 0' 9,419' ND 0' 8,839' A ' 8-112"hole Cmt w/972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK Casing/Cementing Detail • - 9.6 ppg Mud - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) - 8.4 ppg Lease Water(200 bbl) Plug @ 8,610'ELM Perforations: • Tag(sand)@ 8,658'TPM Zone MD TVD Size SPF Date w/4.625"Bit(5111/14) LB-28 LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 5/15/14 LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD Plug @ 8,852'MD ;};.,f f;LB 286 �K ti.;.ti.ti.ti.;..- � stiryrir}rtirjiti Fluid Level -- . _ 8.4 ppg Lease Water LB-30 @ 9,000'CTM • . • • .•%• ti S�ti3ti1{fZ:titi}tii� : A Casing Shoe @ 9,419' Openhole Casing 31'off bottom Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335' MD @ 7,901'-7,916'MDg 870'TVD 8,756'ND Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/15/2014 Schematic Revision Date: 5/16/2014 74 \I%%'t �HE STATE ,-,:_� __�. .� 11'"?;-*-,=;f:-<:- ? fy. - I , ef,__=- 333 West SevcntP� /\venue -'' iP C (��'1 12\i<)R FA v' PAi2�'El L Anchoroce, PIcsko 99501-3572 Mc -, 9(,7 ;;91 <3 �� 4"L„. \°. Tic ; SG aI3 .-.- ( 9 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Bever Creek Unit, Beluga Gas Pool, BCU 14A Sundry Number: 314-291 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P _,„-/c Cathy P. ' oerster Chair )6- DATED this 6' day of May, 2014. Encl. RECEIVED STATE OF ALASKA IAY 0 5 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION MAS SI /� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑, . Perforate 0 • Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 0 213-196 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20539-01 • 7.If perforating: 18.Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? CO 2 3 �� e..--4, . F 0 Beaver Creek Unit(BCU)14A ' Will planned perforations require a spacing exception? Yes Le No IW 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 Beaver Creek I Beluga Gas Pod • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,450' 8,870 . 9,335 8,756 WA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory ❑ Stratigraphicn Development n� Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 05/07/14 Oil ❑ Gas ❑ • WDSPL ❑ Suspended 16.Verbal Approval: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhoia Phone: 907-777-8412 Email soorhola( hilcorD.com Printed Name SttaaannnPPorrhh/ola Title Operations Engineer t� Signature _. Phone 907-777-8412 Date 516 //T' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3ka--'1V— 2l \. Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: -,Y 3CCO rS: ISO(' -TT t RBDMS644,10 08 2014 Spacing Exception Required? Yes [t T No C a' Subsequent Form Required: /0 -`fOcl 9 APPROVED BY Approved by: _4.,U / COMMISSIONER THE COMMISSION Date: 51'6 — S•G /Y � AA' 4$0 n Submit Form and Form 10-403(Revised 10/2012) App^ y`y r i li 12 months from the date of approval. Attachments in Duplicate ‘ , 14 Well Prognosis Well: BCU-14A Hilcorp Alaska,LL Date:5/05/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: May 7th, 2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: 1313435 Current Bottom Hole Pressure: — 3,270 psi @ 8,140' ND (Based on well pressures after perforating the LB-28B) Maximum Expected BHP: —3,370 psi @ 7,971' ND (Based on sample pressures from XPT pressures collected on 2/03/14) Max. Allowable Surface Pressure: —2,573 psi ✓ (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface.The initial zone (LB-30)was perforated and tested and showed poor performance.The 2'd zone (LB-28B)was perforated and sanded up on initial tests and failed to produce after a coil tubing cleanout. The purpose of this work/sundry is to plugback the existing sand and perforate a new lower Beluga sand (now using Moncla#405 to cleanout the well before plugging back with E-line). / Notes Regarding Wellbore Condition • Last tag at 8,584' RKB on 4/11/14 w/a 3.50" Gauge Ring. WO Rig Procedure: 1. MIRU Moncla#405 WO Rig. 2. Set BPV. ND Tree. 3. NU BOPE. Set BPV.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. 4. Bleed any pressure off tubing. Pull BPV. 5. MU 4.5" bit and RIH on 2-7/8" PH-6 workstring. 6. Tag fill at+/-8,515' MD. 7. Circulate well clean w/produced water(8.5 ppg). 8. Cleanout fill to 8,836' MD. 9. Circulate well clean w/produced water(8.5 ppg). 10. SOOH. Rack back workstring. 11. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. MU flange to 7" 5M BOPE. 12. RU 5-1/2"CIBP. 13. RIH and set CIBP at+/-8,575' MD. 14. RD E-line. 14 Well Prognosis Well: BCU-14A Hilcorp Alaska,LLI Date:5/05/2014 15. Test casing/plug to 2,200 psi for 30 min and chart. ✓ 16. RIH w/2-7/8" workstring to 4,000' MD. V 17. MIRU Nitrogen Pumping Unit. RU flowback tank w/gas buster. 18. RU lines to workstring. PT Lines to 250 psi Low/2,500 psi High. 19. Pump Nitrogen down the workstring and displace produced water up the 5-1/2" casing into flowback tank. a. Estimated volume of displaced produced water is 88 bbl. 20. Place Nitrogen Unit on Standby. 21. Continue in hole with workstring to CIBP at+/-8,575' MD. 22. RU lines to workstring. PT Lines to 250 psi Low/2,500 psi High. 23. Pump Nitrogen down the workstring and displace produced water up the 5-1/2" casing into flowback tank. a. Estimated volume of displaced produced water is 102 bbl. 24. Rig down Nitrogen Pumping Unit. 25. POOH and lay down 2-7/8"workstring. 26. Set BPV. ND BOPE. NU Tree. Pull BPV. 27. RD Moncla#405 WO Rig. 28. Turn well over to production. 29. Replace IA x OA pressure gauge if removed (9-5/8"x 13-3/8"). 30. MIRU Nitrogen Pumping Unit. RU flowback tank w/gas buster. 31. RU lines to tree. PT Lines to 250 psi Low/2,500 psi High. 32. Pump Nitrogen down the 5-1/2"casing and build pressure up to 2,000 psi. 33. Rig down Nitrogen Pumping Unit. E-line Procedure: 34. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. b. Tree connection is 9.5"OTIS. c. SITP will be 1,500 to 2,000 psi. 35. RU 3-3/8" 6 spf PJ Omega HC wireline guns(will use 2 each 17'guns). 36. RIH and perforate Lower Beluga (LB-28) interval from 8,543'-8,560' (2 runs,total of 12 spf). d. Bleed tubing pressure to 1,125 psi before perforating. e. Proposed perfs shown on the proposed schematic in red font. f. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. g. Correlate using SLB Cement Bond Log dated 3/13/14(Tie-in log depth is 8,543'-8,560'). h. Use Gamma/CCL/to correlate. i. Record tubing pressures before and after each perforating run. j. Distance to nearest well open in same sands=2,600'to BCU-13. k. Spacing allowance is based on CO 237, no closer than 1,320'. 37. RD E-line. 38. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic • n _ BC-14A ACTUAL Pad 1A SCHEMATIC Hileorp Alaska. fit' 113' FSL, 1,388' FEL Sec. Permit#: 213-196 33, T7N, R10W, S.M. Conductor 20" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083 f MD 0' 145' KB Elevation: 159.6' (18.6'AGL) -' ti TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 13-318" K-55 68 ppf BTC Rig Released: 02/09/14 Top Bottom MD 0' 2,12T TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of ,; 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis n0 `06 8.0"Seal Diameter it 1 Intermediate Casing 5-1/8"Modified ID Bore 7.' !' 9.5/8" L-80 40 ppf BTC y Top Bottom ,, 0MD 0' 5,081' TOC(3/03/14 USIT)-4,725' '- }r* TVD 0' 4,744' o-.. 12-1/4"hole Cmt w/377 sks(141 bbls)of ( 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt 4 Production Casing Swell Packer @ +'* 5-1/2" P-110 20 ppf XP BTC 4,857'-4,879'MD - ill i i? Top Bottom MD 0' 9,419' ,4� TVD 0' 8,839' 8-1/2"hole Cmt w/972 sks(232 bbls) Max Dogleg: of 15.3 ppg,Class G cmt w/EASYBLOK 4.86°/100'@ 3,650' .'° tT Casing/Cementing Detail Max Inclination: - 9.6 ppg Mud 36.5°@ 3,713' . - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) Short Marker Joints - 8.4 ppg Lease Water(200 bbl) @ 7,901'-7,916'MD @ 8,906'-8,921'MD • Perforations: Tag(sand)@ 8,584'SLM Zone MD ND Size SPF Date IN/3.0"GR(4/11/14) a" LB-28B 8,715-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,865-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD Plug @ 8,852'MD \ :'{S LB-28B =K'+�•�•� "A"." — —tftiftii iStiiti Fluid Level _ 8.4 ppg Lease Water LB-30 = @ 9,000'CTM .♦•r•r.r•r•r•r} ' .~.~.,.~.tiff, Casing Shoe @ 9,419' " ► Openhole Casing 31'off bottom TD PBTD 9,450'MD 9,335'MD 8,870'TVD 8,756'ND Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska _ Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 _ Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 4/11/2014 Schematic Revision Date: 4/12/2014 ' INI BC-14A PROPOSED Pad 1A SCHEMATIC flilwmmp Ala;:ka. l.l.l 113' FSL, 1,388' FEL P , 2 , I Sec. 33, T7N, R10W, S.M. Conductor 20" K-55 133 ppf AP : 50-13 t.•,.-'-01-00 Too Bottom Property Des: A-028083If r MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ti} TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 MD To B2 tt22 TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC ', Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ND o' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of F 12.5 ppg Tail&510 sks(106 bbls)of 13.5 4.` 'i ppg Lead Class G cmt Swell Packer @ - 4,857'-4,879'MD i Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom {1 MD 0' 9,419' ro , A ND 0' 8,839' 8-1/2"hole Cmt w/972 sks(232 bbls) , w of 15.3 ppg,Class G cmt w/EASYBLOK ki w4 4 ,,i Casing/Cementing Detail - 9.6 ppg Mud - 12.5 ppg Mud Push(34 bbl) " - 15.3 ppg Cement(232 bbl) I" - 8.4 ppg Lease Water(200 bbl) Plug @ 8,575'MD i APerforations: Tag(sand)@ 8,584'SLM Zone MD ND Size SPF Date w/3.0"GR(4/11/14) LB-28 ' LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 Proposed 4.\44 LB-28B 8,715-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD . 44 Plug @ 8,852'MD LB-28B . i,:,',:,','...,,',..:,.; Fluid Level 8.4 ppg Lease Water LB-30 @ 9,000'CTM ire 41:4'.'4'.*:::::::::.*\•L•1•tiK•4.1 Casing Shoe @ 9,419' Openhole Casing 31'off bottom Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD 8,870'TVD 8,756'ND Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska _ Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 _ Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 4/14/2014 •in Beaver Creek ' • 2014 Moncla Rig 405 Knight Oil Tools BOP Hilmrp Utukr,1.1.1 1 0 0 I iii iii i"1 I I 2.57' \ / Shaffer 71/16 5000 11.11111 111 111 11I EDP I 11,111j1 111 III _ 2 3/8-3'A variable CAMERON 4 -=mi. "�� 3,68' : - Blind ...opium 71/16 5000 iM111' = - - o Ill l i t If ><1'I11 Ill 0.1 lir 2 1/16 10M Kill Valves 2 1/16 10M Choke Valves Manual and HCR Manual and I ICR Iii Iii ill Ill Ill 1.56' 1OL 4* 4i , .; 71/16 5000 ØP . i 1■ I■IiIdiikl 1 j1 v . Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Monday, May 05, 2014 8:49 AM To: 'Stan Porhola' Subject: RE:Verbal Request to use Moncla 405 to cleanout well on BCU-14A(Change to Sundry 314-246) I will look for it this morning. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Monday, May 05, 2014 8:40 AM To: Schwartz, Guy L(DOA) Subject: RE: Verbal Request to use Moncla 405 to cleanout well on BCU-14A(Change to Sundry 314-246) A new sundry is heading to your office. Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Sunday, May 04, 2014 4:15 PM To: Stan Porhola Subject: Re: Verbal Request to use Moncla 405 to cleanout well on BCU-14A(Change to Sundry 314-246) I didn't catch this email right away.. It is too much of a change to do a verbal. I think a new sundry will be needed. Get one to me first thing Monday morning Guy Sent from my iPhone On May 2, 2014,at 5:31 PM, "Stan Porhola"<sporhola@hilcorp.com>wrote: Guy, 1 r • Requesting verbal approval to make the following changes to the approveu sundry 314-246 for well Beaver Creek#14A(PTD 213-196). 1.) Move in Moncla#405 to cleanout fill before setting bridge plug. 2.) Utilize Nitrogen unit to displace well after setting bridge plug. We may start moving the Moncla#405 over to this well as early as late Sunday/early Monday May 4th/5th. Attached is the updated procedure(changes to the original sundry are in red)and BOPE schematic. Regards, Stan Porhola I Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC sporhola @hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 <BCU-14A Regulatory 05-02-2014 Moncla LB-28.pdf5 <BOP Schematic Moncla#405 7.pdf5 2 .y STATE OF ALASKA t ALA, ,S OIL AND GAS CONSERVATION COMM, JN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon [J Repair Well U Plug Perforations U Perforate U Other U Coiled Tubing Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Displacement Change Approved Program 0 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 0 Exploratory E - 213-196 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 ' 50-13-20539-01 7.Property Designation(Lease Number): 8.Well Name and Number: r FEDA028083' Beaver Creek Unit(BCU)14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Qas Vak 1.„ +:— -4= ,f 11.Present Well Condition Summary: Total Depth measured ' 9,450 feet Plugs measured N/A feet true vertical 8,870 feet Junk measured N/A feet A 00 0 A.,._ Effective Depth measured - 9,335 feet Packer measured N/A feet true vertical 8,756 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A RBDMS MAY 13 2014 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 2550 • Subsequent to operation:' 0 0 0 0 1978 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development% Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas x WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-095 Contact Stan Porhola Email sporhola(a�hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature ci.j__________ Phone 907-777-8412 Date 3 /lf L, /2--/t( Form 10-404 Revised 10/2012 Submit Original Only r— Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 3/10/14 3/17/14 Daily Operations: 03/10/2014- Monday Rig up 1-1/2" coil unit, tanks and support equipment. Berm liner in around tanks. SDFN. 03/11/2014-Tuesday RU hydraulic hoses to reel, injector assembly, and BOPs. Visually function test BOPs. Close Blind rams and choke. Test blinds and choke 250/4500 psi. Test good. Insert 1-1/2" test bar. Close pipe rams.Test pipes, inside reel valve, and N2 check valve. Test 250 psi. Test good. Test 4500 psi. Test good. Test accumulator. BOP test complete. Stab coil in injector. Cut mule shoe on end of coil. Finish coil rig up. Install night cap on BOP. Secure well and location for the night. Witness waived by Jim Regg,AOGCC. 250 low-4500 high 03/12/2014-Wednesday PU injector. Straighten coil. NU injector assembly. Pump 2 bbls 50/50 MEOH into BOPs. PT shell to 4000 psi. Open tree valves. RIH to 3000' pumping N2 @ 500 scf/min. Park coil at 3000'. Recover 36 bbls. Pressure breaking over. RIH to 6000'. Parked. Recovered 96 bbls. Recover 107 bbls. Pressure breaking over. RIH to 9,000'. Recovered 143 bbls. Recovered 171 bbls. Pressure rolling over. POOH. Final strap 196 bbls recovered. Close lower master valve. SIWP 3070 psi. ND Injector. ND BOPs. NU tree cap on WH. Pumped 381,250 scf N2. Secure WH and location for the night. 03/13/2014-Thursday Rig up E-line. PT lubricator to 250 Low, 3,500 psi High -test OK. RIH w/ PNL/GR/CCL logging tools. Log interval from 9,100' to 4,982'. POOH. Rig down. 03/17/2014- Monday MIRU E-line. Rig up E-line. PT lubricator to 250 Low, 3,500 psi High -test OK. RIH w/ 14'of 3-3/8" Power Jet Nova 6 spf 60 deg Hollow Carriers. Perforate interval from 8,868'to 8,882'. POOH. RIH w/ 14' of 3-3/8" Power Jet Nova 6 spf 60 deg Hollow Carriers. Perforate same interval from 8,868'to 8,882'. POOH. Rig down. ' ACTUAL BC-14A Pad 1A SCHEMATIC HilcorpAlaska,IJ.0 113' FSL, 1,388' FEL i�e1mC 213-196 `'` SeC. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083 f MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ND 0' 145' Lat: N60° 38' 51.1588' - Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 ', 13-318" K-55 68 ppf BTC Rig Released: 02/09/14 Top Bottom MD 0' 2,122' ND 0' 2,122' 1. 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt 41 Tree cxn=9-1/2"Otis k 44). 8.0"Seal Diameter I Intermediate Casing 5-1/8"Modified ID Bore ,Pr 9-5/8" L-80 40 ppf BTC ;.�y Top Bottom ff�� MD 0' 5,081' TOC(3/03/14 USIT)-4,725' i ND 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of y 12.5 ppg Tail&510 sks(106 bbls)of 13.5 It ppg Lead Class G cmt ip Production Casing Swell Packer @5-1/2" P-110 20 ppf XP BTC 4,857'-0,879'MD - I To'p Bottom .41 MD 0 9,419' ND 0' 8,839' 8-1/2"hole Cmt w/972 sks(232 bbls) L IL Max Do le + g: of 15.3 ppg,Class G cmt w/EASYBLOK 9 4.86°/100'@ 3,650' Casing/Cementing Detail Max Inclination: - 9.6 ppg Mud 36.5°@ 3,713' - 12.5 ppg Mud Push(34 bbl) __- 15.3 ppg Cement(232 bbl) Short Marker Joints 8.4 ppg Lease Water(200 bbl) @ 7,901'-7,916'MD l' 1,, @ 8,906'-8,921'MD r' 4 e. ty Perforations: 4. ie • Zone MD TVD Size SPF Date V is kyr 4 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 z 4. f' . i A Fluid Level 1,+ 8.4 ppg Lease Water LB-30 @ 9,000'CTM Tag(sticky)@ 9,196'SLM ' }3 S?.l3l3a• ' w/4.53"GR(2/27/14) :4...,:.,:.,:.,:.;•:.;•, Casing Shoe @ 9,419' ' Openhole Casing 31'off bottom TD PBTD 9,450'MD 9,335'MD 8,870'TVD 8,756'ND Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 3/17/2014 Schematic Revision Date: 3/21/2014 11 Beaver Creek 14A Drilling Procedure Rev 2 ,.1.1 p-F-0 /3-16 2.0 Management of Change Information int Hilcorp Alaska, LLC xilcorp &IRV ®Pel Changes to Approved Permit to Drill Date: January 14,2014 Subject: Changes to Approved Permit to Drill for Beaver Creek#14A File#: Beaver Creek#14A Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the AOGCC&BLM. Date Procedure Change Approved Approved By By 1.14.2014 Changed name from BCU 14ARD to BCU 14A MM PM 1.14.2014 Changed 5-112'casing connection from DWC/C to XP MM PM Buttress 1.14.2014 Sec 16.14—Test casing to 4000 psi and chart for 30 mins. MM PM 1 I Approval: 7 ra ' 0114 Drilling Manager ' Date Prepared: /. 1 y. 2 a y in g ��ineer Date Page 3 Revision 2 January 14, 2014 Guhl, Meredith D (DOA) From: Janise Barrett[jbarrett@hilcorp.com] Sent: Thursday, April 24, 2014 4:39 PM To: Guhl, Meredith D (DOA) Subject: RE: Well Completion Report BCU-14A PTD 213-196 Attachments: BCU-14A Actual Schematic 4-11-14.pdf; BCU-14A Proposed Schematic 4-14-14.pdf Meredith, Regarding the BCU 14A they plugged the other pert so I think that is why Stan Porhola (operations engineer)took it off the schematic that was sent in with the 10-407. I believe they are planning to shoot another perf - I found a proposed schematic in with the actual so am including it just in case they have already done the work (they do not tell drilling their workover/completion schedule- I am strictly drilling but I apologize for all these mistakes and will do my best to get these issues straightened out) Again,thank you for your patience and willingness to work with us to get these issues corrected. Thank you! Janise Barrett I Drilling Technician Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 100 Anchorage,Alaska 99503 Office:907-777-8389 Mobile:907-365-9856 jbarrett@-hilcorp.com From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, April 24, 2014 11:32 AM To: Janise Barrett; Monty Myers Cc: Davies, Stephen F (DOA); Schwartz, Guy L(DOA) Subject: Well Completion Report BCU-14A PTD 213-196 Janise, During further review of the Well Completion Report for Beaver Creek Unit 14A, I noticed several issues with the form. In Box 22, N/A is listed for re-drill/lateral top window.According to the daily operating summary, on Jan 23 a window was milled from 5081'to 5098'. In the future please list the top of the window in this box. In Box 24,only one perforation is listed.According to the daily operating summary, on March 28 a second round of perfs were shot which are not listed on the well completion form. I will update the form by hand for these two items above. We do, however, need a new well schematic that shows the two zones of perforations.The current well schematic only shows the initial perfs. Please email me an updated well schematic, I will attach it to the Well Completion Report. 1 If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 BC-14A ACTUAL Pad 1A SCHEMATIC Hilcorp Alaska,LLC 113' FSL, 1,388' FEL Permit#: 213-196 Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Property Des: A-028083 MD TO Bottom 4 KB Elevation: 159.6' (18.6'AGL) . 1 TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casinq Spud Date: 01/24/14 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 -1:)p Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casinq 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ;+ TVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt I Production Casinq Swell Packer @ 5-1/2" P-110 20 ppf XP BTC - 4,857'-4,879'MD Top Bottom MD 0' 9,419' TVD 0' 8,839' A 8-1/2"hole Cmt w/972 sks(232 bbls) Max Dogleg: of 15.3 ppg,Class G cmt w/EASYBLOK 4.86°/100'@ 3,650' ` Casing/Cementing Detail Max Inclination: - 9.6 ppg Mud 36.5°@ 3,713' - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) Short Marker Jointst. - 8.4 ppg Lease Water(200 bbl) @ 7,901'-7,916'MD ) @ 8,906'-8,921'MD "r+• rPerforations: Tag(sand)@ 8,584'SLM Zone MD TVD Size SPF Date w/3.0"GR(4/11/14) ''''''----..„...,,,,.„....,,._,,,A, LB-286 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD Plug @ 8,852'MD \ _ :'�"`I�"" LB-28B 't`f`'' .t`t`''_ Fluid Level _, liii . 8.4 ppg Lease Water LB-30 @ 9,000'CTM _ :47.74 ::~11f•l'.-• Casing Shoe @ 9,419' Openhole Casing 31'off bottom TD PBTD - 9,450'MD 9,335'MD 8,870'TVD 8,756'TVD Well Name&Number: Beaver Creek Unit#14A Lease:, A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth. 34°@ 5,081' Angle/Perfs:l N/A Maximum Deviation: 36.5°@ 3,713' Date Completed:_ 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 4/11/2014 Schematic Revision Date: 4/12/2014 BC-14A PROPOSED Pad 1A SCHEMATIC Hilcorp Alaska.LLC 113' FSL, 1,388' FEL Permit#: 213 196 Sec. 33, T7N, R10W, S.M. Conductor s 20" K-55 133 ppf API#: 50-133-20539-01-00 Toa Bottom Property Des: A-028083 ,, MD 0' 145' KB Elevation: 159.6' (18.6'AGL) �' TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 -Tan Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2" Otis 8.0"Seal Diameter ,, Intermediate Casing 5-1/8"Modified ID Bore • t4 9-5/8" L-80 40 ppf BTC 41 Too Bottom IA MD 0' 5,081' TOC(3/03/14 USIT)-4,725' :! TVD 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt Swell Packer @ 4,857'-4,879' MD --\___.. ..,h,I I Production Casing 5-1/2" Top 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' A MIL 8-1/2"hole Cmt w/972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK Casing/Cementinq Detail . - 9.6 ppg Mud - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement (232 bbl) t• - 8.4 ppg Lease Water(200 bbl) i, Plug @ 8,575'MD s Perforations: Tag(sand)@ 8,584' SLM - Zone MD TVD Size SPF Date -, /^2./C. wl 3.0" GR(4111114) LB-28 - -28 8.543 0' 7,97 187' 3-3 12 Pi� d t LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/i 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836' MD 31-1-f l Plug @ 8,852'MD \ 1f'f�f LB-286 :ti.~"""F;V:.% �•1ti• 1 . '1.'.K•ti. Fluid Level �. 8.4 ppg Lease Water LB-30 @ 9,000'CTM ••:1..,.1.1..,.1. j.j.l.r.f.r.l.r .7:4.::::::::..P.V1.7. Casing Shoe @ 9,419' ' Openhole .....ii.*_ Casing 31'off bottom Max Dogleg: TD PBTD 4.86°/100' @ 3,650' Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916' MD 8,870'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921' MD 36.5° @ 3,713' Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' I Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 4/14/2014 trWhialklblinDMIIIMP • OF 1 11/7, , 1 H STATE G `l e i 7- 4 1I 5? === 333 West Seventh Avenue Gov1:1t oR SEAN PAR\F;I.1. Anchorage, Alaska 99501 3572 g1^ , rAa!n gni 279 1473 Stan Porhola j 13 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit 14A Sundry Number: 314-246 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / 1r � Daniel T. Seamount, Jr. Commissioner DATED this 1 0 day of April, 2014. Encl. rt •l 6 1 \11 N\� z1� h..F , STATE OF ALASKA IF R j 5 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well Change Approved Program❑ Suspend❑ Plug Perforations ❑✓ • Perforate Q ' Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing III Other ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: �5.Permit to Drill Number Exploratory ❑ Development ❑✓ . ` 213-196 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. s. Anchorage,Alaska 99503 50-133-20539-01 . 7.If perforating: e6 L g-, e i)f 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Cpm y,671/ J jBeaver Creek Unit(BCU)14A . Will planned perforations require a spacing exception? Yes III No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 V Beaver Creek 1 Beluga Gas Pod • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,450 8,870 9,335 8,756 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic n Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 04/18/14 Commencing Operations: Oil ❑ Gas Q - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola(cahilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature .eek w✓�Iolti Phone 907-777-8412 Date /IS/Pf COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3kl--1— 216 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: REIDMe2StAAY 0 7 2014 /7 Spacing Exception Required? Yes ❑ No © Subsequent Form Required: ` 0 — Li Qq y y APPROVED BY Approved by: ! �Z COMMISSIONER THE COMMISSION Date: 414/71— Submit Form and Form 10-403(Revised 10/2012) 41:413I n a f 12 months from the date of 8ppr vel. Attachments in Duplicate Cf Ill , .: � y ici Well Prognosis Well: BCU-14A Hi!carp Alaska,LLC Date:4/12/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: April 18th, 2014 Rig: N/A(E-line) Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907) 229-4824(M) AFE Number: 1313435 Current Bottom Hole Pressure: —3,270 psi @ 8,140' ND (Based on well pressures after perforating the LB-28B) Maximum Expected BHP: — 3,370 psi @ 7,971'ND (Based on sample pressures from XPT pressures collected on 2/03/14) Max. Allowable Surface Pressure: —2,573 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface.The initial zone(LB-30)was perforated and tested and showed poor performance.The 2"d zone(LB-28B)was perforated and sanded up on initial tests and failed to produce after a coil tubing cleanout. The purpose of this work/sundry is to plugback the existing sand and perforate a new lower Beluga sand. Notes Regarding Wellbore Condition • Last tag at 8,584' RKB on 4/11/14 w/a 3.50" Gauge Ring. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,500 to 2,000 psi. 2. RU 5-1/2" CIBP. 3. RIH and set CIBP at+/-8,575' MD. 4. RD E-line. E-line Procedure: 5. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. c. Tree connection is 9.5"OTIS. d. SITP will be 1,500 to 2,000 psi.? '-18P • 6. RU 3-3/8"6 spf PJ Omega HC wireline guns(will use 2 each 17'guns). 7. RIH and perforate Lower Beluga (LB-28) interval from 8,543'-8,560' (2 runs,total of 12 spf). e. Bleed tubing pressure to 1.125 psi before perforating. f. Proposed perfs shown on the proposed schematic in red font. g. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. h. Correlate using SLB Cement Bond Log dated 3/13/14(Tie-in log depth is 8,543'-8,560'). • Well Prognosis Well: BCU-14A Hi!cora Alaska,LLC Date:4/12/2014 i. Use Gamma/CCL/to correlate. j. Record tubing pressures before and after each perforating run. k. Distance to nearest well open in same sands=2,600'to BCU-13. I. Spacing allowance is based on CO 237, no closer than 1,320'. 8. RD E-line. 9. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 0 n BC-14A ACTUAL Pad 1A SCHEMATIC Hilcorp Alaska,LLC113' FSL, 1,388' FEL „�, ,, Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) rj: ' `! TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 13-3/8" K-55 68 ppf BTC Rill Released: 02/09/14 Top Bottom MD 0' 2,12T TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter ' Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom 0_ MD 0' 5,081' TOC(3/03/14 USIT)-4,725' t! TVD 0' 4,744' j 12-1/4"hole Cmt w/377 sks(141 bbls)of ,. 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ' ppg Lead Class G cmt ji . Production Casing Swell Packer @ 5-1/2" P-110 20 ppf XP BTC - 4,857'-4,879'MD Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2"hole Cmt w/972 sks(232 bbls) Max Dogleg: of 15.3 ppg,Class G cmt w/EASYBLOK 4.86°/100'@ 3,650' ' Casing/Cementing Detail Max Inclination: - 9.6 ppg Mud 36.5°@ 3,713' - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) Short Marker Joints - 8.4 ppg Lease Water(200 bbl) @ 7,901'-7,916'MD @ 8,906'-8,921'MD Perforations: Tag(sand)@ 8,584'SLM Zone MD TVD Size SPF Date w/3.0"GR(4/11/14) y LB-28B 8,715-8, 82' 8292-8,1 6' -3/8" 12 3/28/147 • LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD r•r.r,•,i r r r Plug @ 8,852'MD \ 4•t•`'tia : LB-286 r.r.r.r.r.r.r. yr.r•r.r•r•r• �4;,•� ti ti Fluid Level .4•- 8.4 ppg Lease Water LB-30 @ 9,000'CTM } •••ti ti.v} . y y.y.r.}.r.r Lytity,,}}y,; Casing Shoe @ 9,419' . . Openhole Casing 31'off bottom TD PBTD 9,450'MD 9,335'MD 8,870'ND 8,756'TVD Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 4/11/2014 Schematic Revision Date: 4/12/2014 P .n BC-14A PROPOSED Pad lA SCHEMATIC Hikorp Alaska. LI 1 113' FSL, 1,388' FEL Perm 213-196 Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083MD 0' 145' KB Elevation: 159.6' (18.6'AGL) TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 ', 13-318" K-55 68 ppf BTC Rig Released: 02/09/14 . Top Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing_ 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC • Top Bottom MD 0' 5,081' FOC(3/03/14 USIT)-4,725' ND o' 4,744' 12-114"hole Cmt w/377 sks sks bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 Swell Packer @ ppg Lead Class G cmt • 4,857'-4,879'MD Production Casing 5-1/2" P-110 20 ppf XP BTC Top Bottom MD 0' 9,419' TVD 0' 8,839' 8-1/2"hole Cmt wl 972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK Casing/Cementing Detail • - 9.6 ppg Mud - 12.5 ppg Mud Push(34 bbl) .. - 15.3 ppg Cement(232 bbl) }; }. I - 8.4 ppg Lease Water(200 bbl) Plug @ 8,575'MD r» _ Perforations: Tag(sand)@ 8,584'SLM Zone MD TVD Size SPF Date w/3.0"GR(4/11!14) LB-28 = LB-28 8,543'-8,560' 7,971'-7,987' 3-3/8" 12 Proposed r1 LB-28B 8,715-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD Plug @ 8,852'MD LB-28B --. ` ` " J.f.?.1.h}~ Fluid Level ; 8.4 ppg Lease Water LB-30 = - - @ 9,000'CTM . •& Casing Shoe @ 9,419' `:r Openhole Casing 31'off bottom Max Dogleg: 4.86°/100'@ 3,650' TD PBTD Short Marker Joints 9,450'MD 9,335'MD @ 7,901'-7,916'MD g g70'TVD 8,756'TVD Max Inclination: @ 8,906'-8,921'MD 36.5°@ 3,713' Well Name&Number:_ Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough _ State/Prov: Alaska Country:I USA Angle @KOP and Depth: 34°@ 5,081' I Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 4/14/2014 4i ; • STATE OF ALASKA "-'''" _. f r ALA.. -r OIL AND GAS CONSERVATION COMMI. JN r i f ;,`i iY REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well LJ Plug Perforations H Perforate U Other H 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 ❑., Exploratory ❑ • 213-196 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 . 50-133-20539-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028083 - Beaver Creek Unit(BCU)14A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas 11.Present Well Condition Summary: Total Depth measured . 9,450 feet Plugs measured N/A feet true vertical 8,870 feet Junk measured N/A feet Effective Depth measured , 9,335 feet Packer measured N/A feet true vertical 8,756 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A RBDMScN MAY 1 6 2014 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 2310 Subsequent to operation: 0 0 0 0 1287 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ „ Gas ❑' WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-184 Contact Stan Porhola Email sporholaa.hilcom.com Printed Name Stan Porhola Title Operations Engineer `� Signaturej'E-19,11—._, Phone 907-777-8412 Date 9/II /JA'- Form 10-404 Revised 10/2012 Submit Original Only .07 ,4,- Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 3/25/14 3/29/14 Daily Operations: 03/25/2014-Tuesday RU Pollard E-line. PT Lubricator to 250/3,000 psi-test OK. RIH w/5-1/2"CIBP and GR/CCL and correlate bridge plug. Set cIBP at 8,852'ELM(RKB). 'OOH. MU 3"x 20'bailer. Fill bailer with 6 gals cement. RIH and tag CIBP at 8,852'ELM(RKB). PU above CIBP and dump cement. POOH. Fill bailer with 6 gals cement. RIH to 8,820'. Dump cement. POOH. Rig down. Wait on cement. 03/28/2014-Friday MIRU Schlumberger E-line. Rig up. PT Lubricator 250/3,000 psi-test OK. PU 16'of 3-3/8"PowerJet Nova @ 6 spf. RIH and correlate using GR/CCL. Correlate to Tie-in log PNL-GR-CCL dated 3-13-14. SITP=2,310 psi. Perforate 8,715'-8,731'.. No L l7j Zg 3 change in tubing pressure. POOH. PU 2nd 16'of 3-3/8"PowerJet Nova @ 6 spf. RIH and correlate using GR/CCL. SITP=2,310 03/29/2014-Saturday MIRU Pollard Slickline. Rig up. PT Lubricator 250/2,500 psi-test OK. RIH w/2.5"DD bailer to 8,799'SLM. POOH. RIH w/ press/temp gauges to 8,722'SLM. POOH. Rig down. . iii r BC-14A ACTUAL Pad 1A SCHEMATIC Hilcorp Alaska,LLC 113' FSL, 1,388' FEL SeC. 33, T7N, R10W, S.M. Conductor P �#' 2 20" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083 lii MD 0' 145' KB Elevation: 159.6' (18.6'AGL) ND 0' 145' Lat: N60° 38' 51.1588' Lonq: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 ', 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 MD To Bottom ND 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter ` Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ND 0' 4,744' 12-1/4"hole Cmt wl 377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt • • t..,` Production Casinq Swell Packer @ • 5-1/2" P-110 20 ppf XP BTC 4,857'-4,879'MD - Top Bottom MD 0' 9,419' ND 0' 8,839' 8-112"hole Cmt wl 972 sks(232 bbls) Max Dogleg:r-- of 15.3 ppg,Class G cmt wl EASYBLOK 4.86°/100'@ 3,650' Casing/Cementinq Detail Max Inclination: 71, - 9.6 ppg Mud 36.5°@ 3,713' , - 12.5 ppg Mud Push(34 bbl) 'r� - 15.3 ppg Cement(232 bbl) Short Marker Joints - 8.4 ppg Lease Water(200 bbl) @ 7,901'-7,916'MD @ 8,906'-8,921'MD Perforations: Tag(sand)@ 8,584'SLM Zone MD TVD Size SPF Date w/3.0"GR(4111/14) LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Cement top @ 8,836'MD ti Plug @ 8,852'MD —\ �'`"``"` LB-28B •''`""""'`'= ti.ti;ti};ti ti Fluid Level . ` ` .• 8.4 ppg Lease Water LB-30 - @ 9,000'CTM ' .1 O. j:!ti .:r:,:p.r.",f„ AIL Casing Shoe @ 9,419' ;,.: t. --- ' ' Openhole Casing 31'off bottom . TD PBTD 9,450'MD 9,335'MD 8,870'TVD 8,756'TVD Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 4/11/2014 Schematic Revision Date: 4/12/2014 E i vFo Hilcorp Alaska, LLC Post Office Box 244027 F; Anchorage,AK 99524-4027 162C: , 3800 Centerpoint Drive Suite 100 t/ Cjj Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 April 16, 2014 Alaska Oil and Gas Conservation Commission 333 W.7th Ave., Ste. 100 Anchorage,Alaska 99501 Re: BCU 14(A) Form 10-407 API:50-133-20539-01 PTD:213-196 Dear Commissioner: Please find enclosed the Well Completion Form 10-407 for the BCU 14A. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LLC — gumos... I' i / 4, war= 'anise Barrett Drilling Technician (907)777-8389 jbarrett@hilcorp.com STATE OF ALASKA ALA OIL AND GAS CONSERVATION COME. ION f WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil❑ Gas ❑✓ • SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20MC 25.105 20MC 25.110 Development 2- Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Hilcorp Alaska,LLC Aband.: 3/17/2014 • 213-196/314-195 • 3 Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 1/25/2014 50-133-20539-01 4a. Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number Surface. 113'FSL,1,388'FEL,Sec 33,17N,R1OW,SM,AK 2/1/2014 • Beaver Creek Unit(BCU)14A • Top of Productive Horizon: 8.KB(ft above MSL): 158 . 15.Field/Pool(s): 1365 FSL,649 FEL,Sec 33,T7N,R1OW,SM,AK GL(ft above MSL): 141 Total Depth: 9.Plug Back Depth(MD+TVD): Beaver Creek/Beluga Gas • 2,123'FSL, 124 FWL,Sec 34,T7N,R1 OW,SM,AK • 9,335'MD/8,756'TVD 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 314368.2 . y-2430071.4 . Zone- 4 • 9,450'MD/8,870'TVD • FEDA028083 • TPI: x- 315127 y-2431311 Zone- 4 11.SSSV Depth(MD+TVD). 17.Land Use Permit: Total Depth: x- 315912 y-2432057 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑✓ No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: See attachment • 5081'MD/4744'TVD • 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 5-1/2" 20 P-111 Surf 9,419' Surf 8,839' 8-1/2" 972 sks Class G 24 Open to production or injection? Yes Q No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): WA N/A Zone MD TVD Size SPF Date LB-27 8,477'-8,497' 7,905-7,925' 3-3/8" 12 5/23/14 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. LB-28 8,543'-8,560' 7,971'-7,98T 3-3/8" 12 5/15/14 Was hydraulic fracturing used during completion? Yes❑ No Q • LB-28B 8,715'-8,731' 8,140'-8,156' 3-3/8" 12 3/28/14 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 N/A 27 PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Not flowing Date of Test Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl. Choke Size. Gas-Oil Ratio: N/A Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl. Oil Gravity-API(corr): Press 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q • 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. RECEIVED JUL 14 2014 AOGCC Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 10 `1°•�y /�� y J6 7.23,14 G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? nYes ONo . If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top and submit detailed test information per 20 AAC 25.071. Permafrost-Base Sterling B2 5468 5064 Sterling B4 5682 5252 Middle Beluga 6544 6399 Beluga B17 7730 7171 Beluga B24 8381 7811 Beluga B28 8536 7963 Beluga B28B 8710 8802 Formation at total depth: Tyonek 9450 8870 31. List of Attachments: Schematic,Directional Survey,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email. mmyers hiICorp.conl Printed Name: Monty Myers Title: Drilling Engineer Signatu • "", - . Phone: 907-777-8431 Date: 7 • 1 • ZO I y 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 1 b. Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23. Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation' Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM14, ,ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil❑ Gas 0 . SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: , I 20AAc 23.105 20AAC 25.110 Development ❑., • Explorat 'ry ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphiyffest ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to DrilNumber Hilcorp Alaska,LLC Aband.: 3/17/2014• 213-196 3/K-(`15 3.Address: �6.Date Spudded: MG 4.2414 113.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 112512014 . 50-133-20539-01 4a. Location of Well(Governmental Section): 7.Date TD Reached: '14.Well Name and Number: Surface: 113'FSL,1,388'FEL,Sec 33,T7N,R1OW,SM,AK 2/12014. ' Beaver Creek Unit(BCU)14A Top of Productive Horizon: 8.KB(ft above MSL): • 15$Na 15.Field/Pool(s): 1365 FSL,649 FEL,Sec 33,T7N,R1OW,SM,AK GL(ft above MSL): '141• Total Depth: 9.Plug Back Depth(MD+TVD): Beaver Creek/Beluga Gas 2,123'FSL,124 FWL,Sec 34,T7N,R1OW,SM,AK 9,335'MD/8,756'TVD • 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 314368.2 • y- 2430071.4 • Zone- 4 '9,450'MD/8,870'TVD. FEDA028083 TPI• x- 315127 y-2431311 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 315912 y-2432057 Zone- 4 N/A N/A 18. Directional Survey: Yes Q• No ❑ 19.Water Depth,itrOffshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral T Windoyv MD/TVD: See attachment 5081 iMD rizi ms 9•l9•)y 23. CASING,LINER AND CEMENTING RECORD 7-1?-40- At• S-2L W WT.PER SETTING DEPTH MD SETTING DTH TVD AMOUNT CASING �. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 5-1/2" 20 P-111 Surf 9,419' Surf. • 8,839' 8-1/2" 972 sks Class G '(4:). 24.Open to production or injection? Yes ❑✓ • No 15) / 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and B. -o• ;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): ( N/A N/A See attached schematic 6.0i1;L'iiU#126. ACID,FRACTURE,CEMENT SQUEEZE,ETC. II rte, °" Was hydraulic fracturing used during completion? Yes❑ No ❑ 31 I DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ; VER I p ck 1 6 ,3 i N/A AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Not flowing Date of Test: ours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A / Test Period � Flow Tubing/// Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24 Hour Rate — 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E Sidewall Cores Acquired'? Yes ❑ No E. 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. RBCMS APR 21 2014 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE y.Zci•I-( Submit original only 1, / 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? E Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top and submit detailed test information per 20 AAC 25.071. Permafrost-Base Lower Beluga LB-30 Tight non productive Sterling B2 5468 5064 Sterling B4 5682 5252 Middle Beluga 6544 6399 Beluga B17 7730 7171 Beluga B24 8381 7811 Beluga B28 8536 7963 Beluga B28B 8710 8802 Formation at total depth: Tyonek 9450 8870 • 31. List of Attachments: Schematic, Directional Survey,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email. mmyers(Q7hiICorp.Com Printed Name: Monty Myers Title: Drilling Engineer Signature: • Phone: 907-777-8431 Date: 50. I V • 2,0, 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 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 _÷..._. la BC-14A ACTUAL Pad 1A SCHEMATIC trh'nrp Alaska. l.l.(. 113' FSL, 1,388' FEL Permit#: 213-196 Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) M y' TVD 0' 145' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 `$ ' 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 TOp Bottom MD 0' 2,122' TVD 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom ' MD 0' 5,081' TOC(3/03/14 USIT)-4,725' TVD 0' 4sks 12-1/4"hole Cmt w/377 sks(141 bbls)of . 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt Production Casing Swell Packer @ p 5-1/2" P-110 20 ppf XP BTC -4,857'-4,879 MD - Top Bottom MD 0' 9,419' TVD 0' 8,839' A 8-1/2"hole Cmt w/972 sks(232 bbls) Max Do le of 15.3 ppg,Class G cmt w/EASYBLOK 9 9 y, 4.86°/100'@ 3,650' ya. - — ;i 1 Casing/Cementing Detail Max Inclination: - 9.6 ppg Mud IN 36.5°@ 3,713' I - 12.5 ppg Mud Push(34 bbl) '� A - 15.3 ppg Cement(232 bbl) =': - 8.4 ppg Lease Water(200 bbl) Short Marker Joints @ 7,901'-7,916'MD @ 8,906'-8,921 MD r3 t.,t Perforations: Zone MD TVD Size SPF Date i'-e..--t- LB-30 8,862' 8,292'-830' 3-3/8" 12 3/17/14 113 t( Sty-cRc Fluid Level r L 8.4 ppg Lease Water LB-30 @ 9,000'CTM 4 Tag(sticky)@ 9,196'SLMti .R.Rrh, . ,ti:;, w/4.53"GR(2/27/14) }.j.�.r.j.r.n. x ''' . . Casing Shoe @ 9,419' illt 4 ^ s ?.; '' Openhole s = Casing 31'off bottom TD PBTD 9,450' MD 9,335' MD 8,870'TVD 8,756'TVD Well Name&Number: Beaver Creek Unit#14A Lease A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 3/17/2014 Schematic Revision Date: 3/21/2014 Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 14(A) 50-133-20539-00 204-086/213-196 1/21/14 50-133-20539-01-00 Daily Operations: Wednesday,January 22,2014 Accepted rig at 18:00 hrs on 1-21-14..Cont testing all BOPE at 250/4000 psi for 10 minutes each. Had fail/pass on CMV's 4,5 and 8,and on outer manual kill line.Greased and functioned CMV's then passed.Changed out outer manual kill line valve in mezzanine and re-tested for a fail/pass.BLM Rep Justin Miller was on location to witness full BOP test.AOGCC Rep Jim Regg waived state witness of test. 13.5 hr test time with 4 fail/pass tests. Koomey test as follows:System Pressure:2800,After Closure: 1460, 200 psi attained:33 sec,full pressure attained: 102 sec,4 bottles at 2600 psi. Lay out liner and build containment for frac tank,load pipeshed with 4 1/2" HWDP and DP,stage mill package for PU, recieve fuel,power up Canrig shack,cont building 9.0 ppg mud.Service rig.Spot frac tank and contain,dress with fittings,tally HWDP and BHA, LD test jnt and plug,install 10 1/16" ID wear ring, RD test equipment,verify annulus valve closed. Blow down topdrive,choke line and manifold. PJSM with rig crew and Baker on MU BHA and PU pipe. MU 8 1/2"window mill+8 3/8"lower milk-flex joint+8 1/2" upper mill+X0+18 jnts HWDP,single in hole to 1025'.Service rig and topdrive,strap DP.Cont single in hole from 1025'and tag plug at 5103' DPM. Ran total 146 jnts 4 1/2" DP. MU topdrive and break circ with fresh water. Pumped 20 bbl hi-vis sweep at 408 gpm-520 psi. Up wt 104K,rot wt 102K,dwn wt 98K.Very little debri on sweep to surface.Shut down pumps, RU to test casing. Thursday,January 23,2014 RU and test 9 5/8" Intermediate casing at 3000 psi for 30 minutes on chart.Good test. Bleed off and blow down surface lines. Well u-tubing.CBU and re-level sub base(settling to off side).Also slipped more drill line onto drum(line stacking on itself on drum ends rather than kicking over). POOH from 5103',racking back in derrick 73 stnds DP and 8 stnds HWDP. PJSM with Baker Rep and rig crew on PU whipstock. PU Baker 9 5/8"Gen II whipstock slide and anchor,set up with 3 shift shear bolts (20K shear),set whipstock in table.Align and install 40K shear bolt to secure ramp to window mill.Ease in hole and scribe tools,set slips on HWDP joint. MU XO,6 3/4" DM collar,6 3/4"TM collar, NM float sub with float,UBHO sub and X0.RIH one stand HWDP f/derrick.MU topdrive,shallow test MWD at 400 gpm-512 psi.Good test. PJSM with Baker rep and night crew. Cont RIH 7 more stands HWDP,followed with 4 1/2" DP at 1 minute per stand. Fill pipe every 20 stands. RIH to 5066', no tight hole encountered during trip. Up wt 102K,down wt 100K with no pump. MU topdrive and circ at 10 bpm-1059 psi,orient whipstock ramp at 30 degrees Azimuth-22 degrees right of highside,with Sperry MWD. Up wt 110K,dwn wt 102K w/pumps on.Slack off and tag top of bridgeplug at 5103',set down 25K on anchor(no tail pipe).Saw indication of anchor bolts shear. PU up to verify anchor set and had no overpull.Slack off and set down 25K numerous times again with no overpull to indicate anchor set.Set down 5K and apply right hand torque as per Baker procedure,to 10K ft/lbs. Released torque and MWD still at 22 degrees.Applied 13,500K right hand torque,released torque and again MWD still at 22 degrees indicating anchor set. Notified Drilling Engineer of no overpull indicating 40K shear bolt had sheared prematurely. Decision made to move forward with well displacement and milling,Top of ramp at 5081' md. Bottom of ramp 5098'md.Well bore inclination 34 degrees at ramp top. Held PJSM with rig crew and Peak drivers on displacing well to 9.0 ppg mud.Closed annular,displaced well to 9.0 ppg 6%KCL/PHPA mud. Hole volume with drill string 354 bbls.Pumped at 6 bpm-340 psi,taking returns to frac tank through choke manifold. Blow down choke line and manifold, Peak transporting wellbore fluids to KGF G&I from frac tank.Open annular and line up choke manifold for drilling.With good 9.0 ppg mud in/out,up wt 105K,down wt 102K, rot wt 102K while ______ pumping 10 bpm-930 psi.80 rpm-4550 ft/lbs off bottom torque.Commence milling window in 9 5/8"casing from 5081?to PcQ,� 5083'.60 minutes per foot. 1 to 2K wt on mills,5200K to 12K ft/lbs torque on bottom at 80 rpm, 11 bpm-1017 psi. Milling 1' �J per hour.Shipped 65 bbls fluid to G&I Friday,January 24,2014 Cont milling 81/2"window in 9 5/8"casing from 5083'to 5101'.5K wob,80 RPM-7300 to 9400 ft/lbs on bottom torque, ROP increased from 3 to 15 ft/hr,460 gpm-1148 psi.Service rig,topdrive and crown.Cont milling 8 1/2"window in 9 5/8"casing from 5101'to 5121',8K wob,80 rpm-6600 ft/lbs on bott torque,ROP 3 to 21 ft/hr,466 gpm-1558 psi.Circulated 20 hi-vis sweep out of hole with no increase in cuttings or metal shavings.stopped pumps and worked mill assembly in and out of window with no problems.TOW 5081',BOW 5098', ramp face length 17',open hole diameter 8 1/2",Inc 34 degrees. Pull up hole to 5065', MU topdrive and circ while RU chart recorder.Stop pump and close upper rams. Pump down drill string w/rig pump 16 strokes(1 bbl)to 500 psi to perform FIT at 11.0 ppg EMW. Held 20 minutes. PSI dropped 40 psi in first 10 minutes then held steady at 460 psi the last 10 minutes. Bled off well,opened top rams. MD=5121',TVD=4776', mud wt=9.0 ppg. Flow check well. No flow. Pump dry job and blow down surface lines. POOH with milling assembly from 5065', LD directional tools and Baker mills. Upper mill 1/16"under gauge. PU 4 1/2"test jnt, pull wear ring,install test plug,fill surface lines with water, RU test pump and manifold,AOGCC Rep on location at 03:00.Test annular at 250/2500 psi,all remaining tests at 250/4000 psi for 5 minutes each.Transfer fluid in pits to verify TPV alarms,gain/loss alarms function properly,function flow show alarms, cont testing CMV's,innner/outer manual kill valves, HCR valves,manual/hydraulic valves.Shipped 460 bbls class II fluid to KGF G&I Saturday,January 25,2014 Cont testing BOPE at 250/4000 psi for 5 minute intervals. Drawdown test as follows:System pressure: 2800,After closure: 1400,200 psi attained: 26 seconds,full psi attained:97 seconds,4 bottles at 2525 psi.There were no failures.Total test time of 8 hours. Full test was witnessed by AOGCC Rep Lou Grimaldi. RD test equipment, pull test plug,install wear ring,blow dwn all surface lines. PJSM with Sperry Reps and rig crew on PU directional BHA. PU 7"SperryDrill Lobe motor w/1.22 deg bend, MU 8 1/2" HDBS FX56 PDC bit jetted w/5 x 13's,cont PU 10 more BHA componants to MWD sub. Download MWD tool, MU topdrive and shallow test tool at 400 gpm,good test. Remove topdrive, MU BAT collar, PJSM,Sperry installed RA source. MU NMDC's, HWDP,jars,XO's and HWDP for a total BHA length of 821'. Installed corrosion ring on top of NMDC's. PJSM on PU DP and single in hole.Clean and clear rig floor.Turn elevators. PU and single in hole a total of 136 joints 4 1/2"CDS-40 DP f/821' to 5050'. Filled pipe every 40 joints. MU topdrive,break circ,orient tool face,ease down (slide)through top of window at 5081'with no problem.Commence slide drilling 8 1/2"hole f/5121'to 5151',wob 3K,482 gpm-1478 psi,diff 97 psi,75 to 100 ft/hr. Sunday,January 26,2014 Cont directional drilling 8 1/2" hole f/5151'to 5818'. Rotating:wob 9K,482 gpm-1478 psi,80 rpm-7700 to 8700 ft/lbs on bott torque,75 to 118 ft/hr.Sliding:wob 4K,489 gpm-1723 psi,diff 112 psi, 108 ft/hr. Drilling in tuffaceous claystone and sandstone. Background gas 30 to 35 units. Had a max of 198 units. B1 SB coal came in right on at 5500'. Ran centrifuge 3 hours.Current MW 9.1 ppg/vis 58.Centrifuge output of 8.8 ppg. No flow during connections. Directional drill 8 1/2"hole f/5818'to 6091'. Rotating:wob 1-2K,470 gpm-1842 psi,75 rpm-9200 ft/lbs on bott torque, 116 ft/hr.Sliding:wob 4K,489 gpm-1723 psi,diff 112 psi,108 ft/hr. Lost+/-10 bbls fairly quick at 5900'.Slightly reduced pump rate and added 5 sx of baracarb 25 to suction pit,losses slowed to little or nothing shortly thereafter. Running water at 5 bph.Circ 20 bbl hi-vis sweep around.Good increase in cuttings(sand)with sweep to surface.Cont circ hole clean. Up wt 128K.Off bott torque 8800 ft/lbs. Flow check,no flow. POOH on elevators f/6091'to 5137'with no problem. Up wt 150K. RIH on elevators f/5137'to 6091'with no problem. Down wt 105K.Cont directional drilling 8 1/2" hole f/6091'to 6315'.Rotating:wob 5K,472 gpm-1910 psi,80 rpm-9800 to 10,000 ft/lbs on bott torque,75 to 119 ft/hr.Sliding:wob 4K,472 gpm-1825 psi,diff 78 psi,91 ft/hr. ADT:12.89hrs,ART:9.04hrs,AST:3.85hrs.At 6AM we are 2' high and 1' left of the line.Will be holding the planned 20.69 deg Inc and 46.12 deg Azimuth as per directional plan.Shipped 250 bbls cuttings to KGF G&I.Total hauled to G&I: 655 bbls Monday,January 27,2014 Cont directionally drilling 8 1/2" hole f/6315'to 6587'.Sliding:wob 3K,458 gpm-1809 psi,136 diff psi,50 to 70 ft/hr. Rotating: wob 4K,459 gpm-1858 psi,80 rpm-10,000 ft/lbs on bott torque. BGG 26 units,TPV 574 bbls,43%flow, H2O at 15 bph, centrifuge on with 9.1 ppg in and 8.8 ppg discharge.Up wt 152K,dwn wt 118K,rot wt 138K.Start hi-vis sweep.Cont circ 15 bbl hi-vis sweep around to clean hole. 25%increase in cuttings to surface.Circ and work string until clean at shakers.Service rig and topdrive and crown.Welder installed drill line bumper rollers on drawworks shrouds.Cont directionally drilling 8 1/2" hole f/6587'to 6963'. Rotating:wob 7K,478 gpm-2276 psi,75 rpm-10,900 ft/lbs on bott torque,118 ft/hr.Peak delivered two SLB cement silo's and staged next to rig water tank,Weaver delivered bulk cement,SLB loaded silo's.Carlile delivered two trailers 5 1/2"XP BTC liner.Cont directionally drilling 8 1/2" hole f/6963'to 7083',Starting to see significant stick/slip in MWD tools during backreaming prior to connections.Just prior to 7083' pumped 20 bbl hi-vis sweep.Cont circ out sweep with 25% increase in cuttings(sand)to surface.Circ hole clean while rot and recip drill string.Obtain survey, break off topdrive,flow check well. No flow and no loss. POOH on elevators f/7083', up wt 180K,dwn wt 120K.At 6420' pulled 40K over.At 6392' pulled 40 over.At 6383' pulled 60 over. MU topdrive and pumped out of hole with no rotation,slow.474 gpm-1990 psi. Pumped 4 stands with no problems. Pulled last stand (#17)on elevators f/6091'to 6031'no problem.Trip in hole on elevators with no issues f/6031'to 7021' (60'off bottom), MU topdrive. Built 20 bbl hi-wt sweep during TIH. Pump 20 bbl hiwt sweep at 476 gpm-1984 psi. Rotate at 80 rpm-10,323 ft/lbs off bott torque.25%increase in fine sand/cuttings to surface.Circ until clean at shakers.Cont directionally drilling 8 1/2" hole f/7083'to 7336',wob 12K,475 gpm-2200 psi,75 rpm-13,000 ft/lbs on bott torque,water at 10 bph,centrifuge on,9.1 ppg/55 vis ADT:21.02 hrs,ART:19.92 hrs,AST:1 hrs At 6AM we are 2' low and 4.5'left of the line.Assembly is dropping 0.45 degrees/100'and walking left 0.19degrees/100'.Shipped 175 bbls cutting to KGF G&I.Total hauled to G&1:830 bbls Tuesday,January 28,2014 Cont directionally drilling 8 1/2" hole f/7336'to 7420'.Rotating:wob 5K,500 gpm-2330 psi,80 rpm-12,500 ft/lbs on bott torque. Up wt 185K,dwn wt 122K,rot wt 140K.Top drive developed a serious drilling mud leak out the bottom of the gear box. Pulled one standoff bottom, RU head pin and circ hose and circ at 6 bpm while removing upper quill clamp,sleeve and split couplers.Could find no source of leak.Lined up on topdrive and with manual IBOP closed rolled rig pump to obtain 500 psi in quill. Leak is coming from behind load collar. Re-assembled clamps and sleeve in prep to pull up hole into casing. RD head pin and hose. POOH from 7395?to 5038?.Trip went very well. Did have a tight spot at 5930 which we worked through twice on elevators and cleaned up.Saw no drag or overpull coming up through window with BHA. Up wt 195K. RU headpin and circ hose. Blew dwn topdrive.Clean and clear rig floor in prep to LD topdrive. Peak crane on location and new topdrive on location. Lay down top drive and remove from floor, Recieved 3rd trailer load of 5 1/2" liner.Set top drive on floor,attach to blocks, remove f/shipping cradle,hook up TD to skate,hook up service lines, install dies in grabber box,function test TD, pressure test mud line @ 2700 psi.Trip in hole F/5038'T/7340'TD not read torq @ low RPM'S. Encounter tight spot @ 7340', M/U TD and wash through tight spot F/7340'T/7400',wash pipe on TD started leaking.Tighten lower union on wash pipe& grease wash pipe packing,wash pipe continue to leak. POOH 3 stands T/7209', no over pull Install pump in sub and TIW valve and establish circulation.Change out swivel packing,test swivel packing,tested ok.ADT: 1.65 hrs,ART: 1.65 hrs,AST:0 hrs.At 6AM we are 4' low and 4'left of the line.Shipped 170 bbls cuttings to KGF G&I.Total hauled to G&I: 1000 bbls Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 14(A) 20539-0050-133-2053 204-086/213-196 1/21/14 Daily,Operations: Wednesday,January 29,2014 Cont drilling 8 1/2" hole f/7420'to 7456'. Rotating:wob 6K, 500 gpm-2400 psi, 80 rpm-12500 on bott torque, Up wt 183K, dwn wt 122K, rot wt 140K. Backreamed one time prior to making connection then could not break topdrive from stump. Trouble shoot topdrive issue and call out electrician. Continue troubleshooting hydraulic issue with topdrive. Call for replacement hydraulic pump from Saxon yard.Start removal of inoperable pump from power unit. Cont replacement of topdrive power unit hydraulic pump. Hilcorp Safety Manager Carl Jones on location w/Beacon to perform UA's of everyone on location. Cont replacing hydraulic pump,fill hydraulic tank,function check topdrive. Rotate and slide F/7456'T/7580', spp 2400,gpm 495, p/u 187k,s/o 120k, rot 140k,trq on bott 13.5,trq off 12K Rotate and slide F/7580'T/7690',spp 2200 on bott, 2073 off,stk/min 205,gpm 496,wob 5/10, rpm 90,trq on 13,trq off 12.5, p/u 190k,s/o 122k, rot 142k ADT: 5.80 hrs, ART: 3.58 hrs,AST: 2.22 hrs. At 6AM we are 4.95' low and 4.8' left of the line. Shipped 120 bbls cuttings and fluid to KGF G&I,total hauled to G&I: 1370 bbls. Thursday,January 30, 2014 Cont drilling 8 1/2" hole f/7690'to 7830'. Rotating:wob 5K,486 gpm-2323 psi,80 rpm-13100 ft/lbs on bott torque. Sliding: wob 5K,496 gpm-2180 psi, 125 psi diff, BGG 4 units, MW 9.1 ppg/58 vis,water on at 10 bph.Zone B17 came in at 7728' (expected 7725'). Had some fluid loss initially and then slowed to none. Cont drilling 8 1/2" hole f/7830'to 7957'. Rotating: wob 5K,496 gpm-2381 psi, 80 rpm-13380 ft/lbs on bott torque. Sliding:wob 6K,486 gpm-2073 psi, 129 psi diff, BGG 23 units, MW 9.1 ppg/53 vis. Changed screens to 170's on shakers. Load ing casing shed with 5 1/2" and strapping same. Service rig and topdrive, change grabber dies. Electrician trouble shot topdrive rpm sensor which has stopped working. Check oil in topdrive and drawworks engine. Cont drilling 8 1/2" hole f/7957'to 8000'. Rotating:wob 5K,495 gpm-2139 psi, 80 rpm- 13400 ft/lbs on bott torque. Cont rack and tally 5 1/2" liner in casing shed. Cont drilling 8 1/2" hole f/8000'to 8200',ssp 2350,gpm 495,wob 5, rpm 90,trq on 14k,trq off 13k, p/u 192k,s/o 125k, rot 150k Continue Drilling 8 1/2" hole F/8200' T/8390',spp 2337,gpm 495, diff 250,wob 8k, rpm 90,trq on 14k,trq off 13k, p/u 195k, s/o 125k, rot 150k Saw no losses to speak of in potential depleted zones B19, B20, B21 or B22. Currently have a 10' coal coming up at+/-8385' Mudloggers are just starting to see indication of coal at 8389'. ADT: 14.76 hrs,ART: 12.44 hrs,AST: 2.32 hrs. At 6AM we are 4' high and 2.2' left of the line. Shipped 170 bbl cuttings and fluid to KGF G&I,total hauled to G&I: 1540 bbls. Friday,January 31, 2014 Cont drilling 8 1/2" hole f/8390'to 8515'. Rotating wob 8K, 500 gpm-2252 psi, 80 rpm-13,700 ft/lbs on bott torque, MW 9.2 ppg/vis 52, BGG 30 units. CBU at 474 gpm-2077 psi, 80 rpm-13,800 ft/lbs off bott torque, up wt 160K and dwn wt 150K while pumping/rotating. Obtain survey and flow check. No flow. POOH on elevators f/8515', up wt 200K.At 8105', 8057', 8000', 7809' pulled 40K over. Worked string one time and pulled through no problem. At 7757' pulled 40K over. Worked string 3 times and pulled through no problem.At 7503' pulled 40K over. Attempted to work through on elevators 4 times. Still pulling tight. MU topdrive and pump at 99 spm-730 psi, attempt to pull through just pumping,4 times.Still pulling tight. Rotate at 40 rpm-10 to 12K ft/lbs and work through tight spot 3 times. Cleaned up nice. Cont pull up hole to 7456'.Tight spot at 7503' is start of drop section where a majority of sliding was started. Worked through tight spot with pump only then no pump with no problems. RIH on elevators f/7456'to 8484'with no problem. At 8484'tagged up on fill (+/-30'). MU topdrive and break circ,wash to bottom at 8515'. Make connection at 8515', pump 20 bbl hi-vis sweep and commence drilling f/8515'to 8670'. Rotating:wob 10K,486 gpm-2499 psi, 80 rpm-14,000 to 15,000 ft/lbs on bott torque, 76 to 111 ft/hr ROP. Had 50% increase in cuttings with hi-vis sweep to surface. Geology requested we drop Inc from 10 to 7 degrees. Sliding:wob 5K,482 gpm-2363 psi, 186 psi diff, 21 to 39 ft/hr ROP. Rig crew held man down drill and H2S drill. Drill F/8670'T/8950' SPP 2800, GPM 500, RPM 90,wob 10k,trq on 15.5k,trq off 14k, p/u 200k, s/o 135k, rot 160k. Drill F/8950'T/9070',spp 2750,gpm 500, rpm 90, wob 10,trq on15.5,trq off 14k, p/u 205, s/o 135k, rot 160k, pump sweep @ 9000' no increase in cuttings. Service draw works, check and grease brake linkage,grease blocks,TD, and swivel packing. Continue Drilling F/9070'T/9172',spp 2800, gpm 499, rpm 90,trq on 15.5k,trq off 14.5k,wob 10k, p/u 205k,s/o 138k, rot 163k. Current mud weight 9.3 ppg,vis 53. Lube at 1% in mud system. Currently drilling in the Beluga Formation. ADT:13.06 hrs,ART: 11.77 hrs,AST: 1.29 hrs. At 6AM we are 22' low and 2.8' left of the original plan. (at 8600' Geo requested we drop inclination from 10 to 7 degrees.) Shipped 175 bbls cutting to KGF G&I,total hauled to G&I: 1715 bbls. Saturday, February 01, 2014 Cont_drilling 8 1/2" hole f/9172'to 9450' (TD)'Rotating:wob 5K, 500 gpm-2699 psi, 80 rpm-15,700 to 16,100 ft/lbs on bott V torque, 30 to 75 ft/hr ROP. Pumped sweep 5'from TD. Circ sweep around while rotating/reciprocating. 500 gpm-2658 psi, 90 rpm-15,300 ft/lbs off bott torque. No real increase in cuttings at bottoms up. Flow check...no flow. POOH on elevators f/9450'to 8849'with no problem. Pulled 40K over at the following depths but worked through all but three on elevators with minimum effort: 8849', 8832', 8789', 8711', 8678', 8672', 8644', 8626', 8560', 8550', 8484', 8473',8402', 8335',8304', 8282', 8273', 8158'. At 8832' had to MU topdrive and attempted to wash up hole. Could not. Rotated 40 rpm and reamed up hole f/8832'to 8818'. At 8626' had to MU topdrive and ream up hole to 8572'. At 8273' had to MU topdrive and ream up hole to 8261'. MW 9.4 ppg. Cont wiper trip f/8261'T/7200' back reaming tight spots @ 7400'thru 7327', 7200'thru 7149'. Pump high vis sweep @ 7149',slight increase in cutting @ bottoms up' Continue tripping out F/7149'T/5031' (inside casing), working thru tight spots F/7003'thru 6692'. PJSM, cut and slip 123' drilling line. Trip in hole F/5031'T/7953',filling drill pipe every 20 stands. Build 80 vis mud to spot in open hole later. ADT: 5.52 hrs,ART: 5.52 hrs,AST: 0 hrs. At TD we were 39.3' below and 1.65' right of the original line. Shipped 260 bbls cuttings to KGF G&I,total hauled to G&I: 1975 bbls. Sunday, February 02, 2014 Cont RIH (wiper trip)f/7953'to 9324',filling drill string every 20 stands. Encountered fill at 9324' (2 stnds off bottom). MU topdrive and wash down to 9450'. Circ hi-vis sweep around at 487 gpm-2796 psi, rotating 90 rpm-14,700 to 18,000 ft/lbs off bott torque. Cont vis up 300 bbls to spot in open hole. Pump 300 bbls 80 vis mud and spot in open hole section. 508 gpm- 2958 psi,45 rpm-13,200 ft/lbs off bott torque. LD single, POOH on elevators 10 stands f/9450'to 8821', up wt 210K, hole in very good shape. At 8821' blew down topdrive and checked for flow. No flow. Cont POOH f/8821'to 2555'. Had no issues in open hole section at all. Hole in good shape. Did have 10K overpull when upper stab entered into window at 5098',and another 10K overpull when bit entered window. Continue tripping out F/2555'T/200',calculate hole fill= 66 bbls, actual 98.6 bbls. Retrieve corrosion ring, rack back NMDC's, remove RA source, lay down MWD subs, motor& bit. Bit graded at 3/2- CT-A-I-BU-TD. PJSM with Schlumberger crew and rig crew. Rig up e-line sheaves, MU tool string. Run in hole with quad combo logging tools to 9428' ELM, and begin to log well. Logging up hole at 7400'at 06:00. No cuttings or class II fluid hauled to KGF G&I. We drilled 4329' in 65.57 actual drilling hours,for an average of 66 ft/hr.495' or 12%was oriented with 10.69 drilling hrs. 3834' or 88%was rotated with 54.88 drilling hrs. Monday, February 03, 2014 Cont logging 8 1/2" open hole with SLB quad combo tool,f/7400'to 5098'.. POOH. Remove RA source. LD quad combo tool string. MU XPT tool string. RIH on e-line. Obtain formation pressure tests from 8757' up to 5400' as per Geo and Reservoir Engineer. No tool failures. Spotted frac tank for produce water(cement displacement), Perform rig PM's on drawworks and motor,scrub rig exterior. POOH with XPT tool string. Remove R/A source, lay down tools& rig down e-line. Clean rig floor and prep to RIH. M/U 8 1/2"tri-cone bit(no jets),float sub, xo,stab and one NMDC, lay down one NMDC. Trip in hole f/45' to 5065'. HAlliburton Rep on location to repair RPM gauge on centrifuge. Circulate bottoms up at 5065' (just above window). Continue tripping in hole F/5065'to 9406',tagged fill. M/U TD and wash F/9406'to 9450'. Up wt 192K, down wt 130K, rot wt 160K. Shipped 85 bbls cuttings to KGF G&I,total hauled to G&I: 2060 bbls Tuesday, February 04, 2014 Washed to bottom at 9450'and increased pump rate to 500 gpm-1258 psi, 80 rpm-13,100 ft/lbs off bott torque. CBU x 2. Dropped carbide bomb on 2nd circ. Max gas 246 units on initial bottoms up. POOH LD 20 singles 4 1/2" CDS-40 DP from 9450'to 8846'. Perform 15 minute flow check, no flow, pump dry job 1.5 lb over. Cont POOH LD 4 1/2" CDS-40 DP from 8846'to the BHA @ 252' Lay down BHA and Bit Pre Job on changing rams Change out top rams F/2 7[8.X_5_Tf5.5 rams Test 5.5 rams @ 250/4000 psi F/5 min each PJSM and rig up to run 5.5 casing,changed out hydrulic unit, hook up csg tong, tongs had bad hydrulic line, change out csg tongs,#2 tong having issuses gear box seased up tongs not rotating. Hauld 90 bbls cutting T/KGF G&I, Total cutting hauled 1465 bbls, hauled 5 bbls clas 2 fluid to KGF G&I, Total class II fluids hauled = 690 bbls Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 14(A) 50-133-20539-00-00 204-086/213-196 1/21/14 50-133-20539-01-00 Daily Operations: Wednesday, February 05, 2014 Rig Service, Change out hydrulic cylinder con casing tongs, Make up shoe track check float, pick up 5 1/2 XP BTC 20# P110_, casing and run in hole to 5017', circulate 2 bottoms up, blow down mud lines&TD, Continue picking up casing,filling pipe every joint and breaking circulation every 1500', Circulate and cond. mud for cement job. P/U WT. 179k S/O 130k(cementers on location @ 03:30) Thursday, February 06, 2014 Circulate and condition,Change the shorter bails to the longer bails due to the cement head, Pjsh m with cement crew, Install cement head and rig up cmt lines, Pump 5 bbls water and test cmt lines @ 4000 psi, pump 35 bbls mud push, drop bottom plug, mix and pump 12 bbls cement.,Trouble shoot cement pump., R/D cement head,circulate out cement,dumped 103 bbls of contaminated mud., circulate and waqit on Shlumberger unit, change out cement units.,Service rig, Circulate while change out and rigging up cement unit, PJSM with cement crew, pump 5 bbls water,test cement equipment @ 4000 psi, pump 34 bbls 12.5ppg mud push II @ 5bpm, drop bottom plug, mix and pump 232 bbls 15.3 ppg cement, displace cement with 200 L6`Sjy bbls water,bump plugg @ 23:35 hrs, final circ psi 2200, psi up to 2755 psi, 2 bbls back on bleed off, rig down cement equipment, Back out landing joint, install pack off&test @ 5000 psi F/30 min, Change upper rams F/5.5 T/2 7/8 X 5", Remove flow line,take down polution pan, install beam, remove kill &choke line, remove koomey line, nipple down BOP'S,0 cuttings hauled To KGF-total cuttings hauled to KGF G&I = 1465, Hauled 180 bbls class II fluids to KGF/G&I, Total Class II fluid hauled to KGF/G& 1870 bbls Friday, February 07, 2014 Nipple Down The BOP's, Install Flnge and Valve. Rig up test pump for testing casing, Rig up test pump for testing casing.Test the 5.5" liner to 4000 psi for 30 min. Rig down test equipment and set 5"TWC.,Transfer drilling mud from the mud pits to the frac tanks on pad#7. A total of 812 bbls of 9.5 ppb drilling mud is stored in two frac tanks on pad#7, Rig down topdrive and install in carrier, remove Iron roughneck from rigfloor, clean pits, rig down hydrulic lines, mud lines and high psi hoses.,0 BBLS cuttings hauled to KGF G&I -Total cuttings hauled= 1465 bbls, 395bb1s class II fluids hauled to KGF G&I, total class II fluids hauled =1265 bbls Saturday, February 08, 2014 Clean mud pits, Change out sock on the service loop. Hook up the bridle Iine.Scope down the derrick and remove cattle shoot., Remove The topdrive from the rigfloor, rig down Pason electrical lines. Lay down windwalls, prep derrick and lay it down.Tie off lines and hoses, cables,secure derrick for rig move., Rig down chain on catwalk. Secure lines and unhook hyd lines and electrical lines. Disconnect water lines, pull berms. Clean up Work areas and location. Isolate boilers and shut in blow down line. Lower doghouse into the water tank,continue rigging down service lines, Rig released @ 06:00 hrs 2/9/2014,0 BBLS cuttings hauled to KGF G&I -Total cuttings hauled = 1465 bbls, Hauled 210 bbls class II fluids hauled to KGF G&I, total class II fluids hauled=1475 bbls Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 3/10/14 Daily Operations: 03/05/2014-Wednesday No activity to report. 03/06/2014-Thursday No activity to report. 03/07/2014 - Friday No activity to report. 03/08/2014-Saturday No activity to report. 03/09/2014-Sunday No activity to report. 03/10/2014- Monday Rig up 1-1/2" coil unit,tanks and support equipment. Berm liner in around tanks. SDFN. 03/11/2014-Tuesday RU hydraulic hoses to reel, injector assembly, and BOPs. Visually function test BOPs. Close Blind rams and choke. Test blinds and choke 250/4500 psi. Test good. Insert 1-1/2" test bar. Close pipe rams. Test pipes, inside reel valve, and N2 check cr' valve. Test 250 psi. Test good. Test_4500 psi. Test good._Test accumulator. BOP test complete. Stab coil in injector. Cut mule shoe on end of coil. Finish coil rig up. Install night cap on BOP. Secure well and location for the night. Witness waived by Jim Regg,AOGCC. 250 low- 3500 high Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 3/10/14 Daily Operations: 03/11/2014-Tuesday- UPDATE RU hydraulic hoses to reel, injector assembly, and BOPs. Visually function test BOPS. Close Blind rams and choke. Test blinds and choke 250/4500 psi. Test good. Insert 1-1/2"test bar. Close pipe rams.Test pipes, inside reel valve,and N2 check valve. Test 250 psi. Test good. Test 4500 psi. Test good. Test accumulator. BOP test complete. Stab coil in injector. Cut mule shoe on end of coil. Finish coil rig up. Install night cap on BOP. Secure well and location for the night. Witness waived by Jim Regg,AOGCC. 250 low-4500 high 03/12/2014-Wednesday PU injector. Straighten coil. NU injector assembly. Pump 2 bbls 50/50 MEOH into BOPs. PT shell to 4000 psi. Open tree valves. RIH to 3000' pumping N2 @ 500 scf/min. Park coil at 3000'. Recover 36 bbls. Pressure breaking over. RIH to 6000'. % Siotr Parked. Recovered 96 bbls. Recover 107 bbls. Pressure breaking over. RIH to 9,000'. Recovered 143 bbls. Recovered 171 D' bbls. Pressure rolling over. POOH. Final strap 196 bbls recovered. Close lower master valve. 5IWP307dpsL. ND Injector. ND BOPS. NU tree cap on WH. Pumped 381,250 scf N2. Secure WH and location for the night. 03/13/2014-Thursday Rig up E-line. PT lubricator to 250 Low, 3,500 psi High -test OK. RIH w/PNL/GR/CCL logging tools. Log interval from 9,100'to 4,982'. POOH. Rig down. 03/14/2014- Friday No activity to report. 03/15/2014-Saturday No activity to report. 03/16/2014-Sunday No activity to report. 03/17/2014-Monday MIRU E-line. Rig up E-line. PT lubricator to 250 Low,3,500 psi High -test OK. RIH w/14' of 3-3/8" Power Jet Nova 6 spf 60 deg Hollow Carriers. Perforate interval from OH. RIH w/14' of 3-3/8" Power Jet Nova 6 spf 60 deg Hollow Carriers. Perforate same interval from 8,868'to 8,882'. POOH. Rig down. 03/18/2014-Tuesday ()Pt No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 3/25/14 Daily Operations: 03/19/2014-Wednesday No activity to report. 03/20/2014-Thursay No activity to report. 03/21/2014-Friday No activity to report. 03/22/2014-Saturday No activity to report. 03/23/2014-Sunday No activity to report. 03/24/2014-Monday No activity to report. 03/25/2014-Tuesday RU Pollard E-line. PT Lubricator to 250/3,000 psi-test OK. RIH w/5-1/2"CIBP and GR/CCL and correlate bridge plug. Set ��Qks CIBP at 8,852'ELM(RKB). POOH. MU 3"x 20'bailer. Fill bailer with 6 gals cement. RIH and tag CIBP at 8,852'ELM(RKB). PU above CIBP and dump cement. POOH. Fill bailer with 6 gals cement. RIH to 8,820'. Dump cement. POOH. Rig down. 1 Wait on cement. 3!`f-1 y Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-14A 50-133-20539-01 213-296 3/25/14 3/28/14 Daily Operations: 03/26/2014-Wednesday No activity to report. 03/27/2014-Thursay No activity to report. 03/28/2014-Friday MIRU Schlumberger E-line. Rig up. PT Lubricator 250/3,000 psi-test OK. PU 16'of 3-3/8"PowerJet Nova @ 6 spf. RIH and correlate using GR/CCL. Correlate to Tie-in log PNL-GR-CCL dated 3-13-14. SITP=2,310 psi. Perforate 8,715'-8,731'. No change in tubing pressure. POOH. PU 2nd 16'of 3-3/8"PowerJet Nova @ 6 spf. RIH and correlate using GR/CCL. SITP= 2,310 psi. Perforate 8,715'-8,731'. Lost 20 psi. POOH. 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E ° � rt � � �'<r <t C� - -r oo 'C CA a 0c Cc 00 r- C` l0 Vr o ,46 I ' r a o v N o Q w O N!N �n r, oo O ;' O N N M M71. CC C, C' .^. C. Ik N M V en cC rn ! M i M M M M M i f Guhl, Meredith D (DOA) From: Monty Myers [mmyers@hilcorp.com] Sent: Wednesday, April 23, 2014 2:38 PM To: Guhl, Meredith D (DOA); Janise Barrett Cc: Davies, Stephen F (DOA) Subject: RE: Hilcorp 10-407s: PTDs: 213-055, 213-196, 214-001 Attachments: BCU-1B Definitive Survey.pdf; BCU-1B EOW Plot.pdf; BCU-1B Rig Surveys.txt; BCU-14A Definitive Survey.pdf; BCU-14A EOW Plot.pdf; BCU-14A Rig Surveys.txt Here you go! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Wednesday, April 23, 2014 11:18 AM To: Janise Barrett Cc: Davies, Stephen F(DOA); Monty Myers Subject: Hilcorp 10-407s: PTDs: 213-055, 213-196, 214-001 Janise, While reviewing the Well Completion Reports submitted for SRU11-22, BCU-14A and BCU-01B yesterday, I noticed that the digital directional surveys were not provided as part of the digital data package. Also, each 10-407 report has a different print of survey data. I've attached scans of each report. I emailed Monty Myers yesterday requesting digital survey data for SRU11-22 and he responded this morning.The definitive survey report(PDF and text) he attached to his email is precisely the data, in the proper format,that should be part of the Well Completion Report and also provided in digital format. Halliburton does this for other operators so it should not be difficult for them to provide both Hilcorp and AOGCC with the survey reports when submitting other digital and paper logs. If you would like to review other operators' completed 10-407 reports you can go to our website and browse completed reports.The reports are scanned and uploaded to this location: http://aogweb.state.ak.us/WebLink8/Browse.aspx . I recommend reviewing the well history file for 213-026 as it demonstrates a complete well history that has gone through final compliance. Please provide the digital directional survey data for BCU-14A and BCU-01B in pdf and txt/excel/ascii form. If you have any questions, please contact me. Thank you, Meredith 1 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit BCU-14A 501332053901 Sperry Drilling Definitive Survey Report 23 April, 2014 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 14 Project: Beaver Creek Unit TVD Reference: BCU 14A @ 158.00usft • Site: Beaver Creek Unit MD Reference: BCU 14A @ 158.00usft Well: Beaver CK Unit 14 North Reference: True Wellbore: BCU-14A Survey Calculation Method: Minimum Curvature Design: BCU-14A Database: Sperry EDM-NORTH US+CANADA Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Well Beaver CK Unit 14 Well Position +N/-S 0.00 usft Northing: 2,430,071.36 usft . Latitude: 60.6475441 +El-W 0.00 usft Easting: 314,368.19 usft • Longitude: -151.0343614 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 141.00 usft Wellbore BCU-14A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2013 12/31/2013 17.14 73.62 55,471 Design BCU-14A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 5,031.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (0) 17.00 0.00 0.00 90.00 Survey Program Date 4/23/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 160.00 5,031.00 BCU 14(BCU 14) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 11/21/2013 5,081.00 5,428.90 BCU-14A(MWD+Interp+Azi)(BCU-14A) MWD_Interp Azi MWD v3:standard dec with interpolated azimuth 01/08/2014 5,491.21 9,398.72 BCU 14A(MWD+SC+sag)(BCU-14A) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 01/27/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (1100) (ft) Survey Tool Name 17.00 0.00 0.00 17.00 -141.00 0.00 0.00 2,430,071.36 314,368.19 0.00 0.00 UNDEFINED 160.00 0.50 95.90 160.00 2.00 -0.06 0.62 2,430,071.29 314,368.81 0.35 0.62 MWD+SC+sag(1) 191.00 0.20 184.60 191.00 33.00 -0.13 0.75 2,430,071.22 314,368.94 1.72 0.75 MWD+SC+sag(1) 281.00 0.20 206.50 281.00 123.00 -0.43 0.67 2,430,070.92 314,368.85 0.08 0.67 MWD+SC+sag(1) 403.00 0.30 186.60 403.00 245.00 -0.94 0.54 2,430,070.41 314,368.71 0.11 0.54 MWD+SC+sag(1) 552.00 0.50 188.00 551.99 393.99 -1.97 0.40 2,430,069.39 314,368.56 0.13 0.40 MWD+SC+sag(1) 672.00 0.80 187.60 671.98 513.98 -3.32 0.22 2,430,068.04 314,368.36 0.25 0.22 MWD+SC+sag(1) 795.00 0.80 193.30 794.97 636.97 -5.00 -0.09 2,430,066.36 314,368.02 0.06 -0.09 MWD+SC+sag(1) 981.00 1.40 180.60 980.94 822.94 -8.54 -0.42 2,430,062.83 314,367.64 0.35 -0.42 MWD+SC+sag(1) 1,107.00 1.60 184.40 1,106.89 948.89 -11.83 -0.57 2,430,059.54 314,367.44 0.18 -0.57 MWD+SC+sag(1) 1,233.00 1.80 182.00 1,232.84 1,074.84 -15.56 -0.77 2,430,055.81 314,367.17 0.17 -0.77 MWD+SC+sag(1) 1,356.00 0.70 185.40 1,355.81 1,197.81 -18.24 -0.91 2,430,053.13 314,366.99 0.90 -0.91 MWD+SC+sag(1) 4/23/2014 5:24::46PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 14 Project: Beaver Creek Unit TVD Reference: BCU 14A @ 158.00usft Site: Beaver Creek Unit MD Reference: BCU 14A @ 158.00usft Well: Beaver CK Unit 14 North Reference: True Wellbore: BCU-14A Survey Calculation Method: Minimum Curvature Design: BCU-14A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,482.00 0.40 281.50 1,481.80 1,323.80 -18.92 -1.41 2,430,052.46 314,366.48 0.67 -1.41 MWD+SC+sag(1) 1,608.00 1.30 354.90 1,607.79 1,449.79 -17.41 -1.97 2,430,053.98 314,365.95 0.99 -1.97 MWD+SC+sag(1) 1,733.00 1.30 1.20 1,732.76 1,574.76 -14.58 -2.07 2,430,056.81 314,365.89 0.11 -2.07 MWD+SC+sag(1) 1,858.00 1.40 3.80 1,857.72 1,699.72 -11.64 -1.94 2,430,059.75 314,366.07 0.09 -1.94 MWD+SC+sag(1) 2,071.00 1.40 8.70 2,070.66 1,912.66 -6.47 -1.37 2,430,064.91 314,366.72 0.06 -1.37 MWD+SC+sag(1) 2,144.00 1.30 4.10 2,143.64 1,985.64 -4.76 -1.18 2,430,066.62 314,366.94 0.20 -1.18 MWD+SC+sag(1) 2,206.00 1.80 5.20 2,205.62 2,047.62 -3.09 -1.04 2,430,068.29 314,367.10 0.81 -1.04 MWD+SC+sag(1) 2,269.00 3.20 8.70 2,268.56 2,110.56 -0.37 -0.68 2,430,071.00 314,367.50 2.23 -0.68 MWD+SC+sag(1) 2,333.00 5.00 13.00 2,332.39 2,174.39 4.12 0.22 2,430,075.47 314,368.47 2.85 0.22 MWD+SC+sag(1) 2,396.00 7.60 15.00 2,395.00 2,237.00 10.82 1.91 2,430,082.14 314,370.27 4.14 1.91 MWD+SC+sag(1) 2,458.00 10.40 18.90 2,456.24 2,298.24 20.07 4.79 2,430,091.35 314,373.29 4.62 4.79 MWD+SC+sag(1) 2,520.00 12.70 25.50 2,516.98 2,358.98 31.52 9.53 2,430,102.73 314,378.22 4.27 9.53 MWD+SC+sag(1) 2,582.00 13.70 34.00 2,577.35 2,419.35 43.76 16.57 2,430,114.85 314,385.45 3.52 16.57 MWD+SC+sag(1) 2,645.00 13.70 34.70 2,638.55 2,480.55 56.08 24.99 2,430,127.04 314,394.06 0.26 24.99 MWD+SC+sag(1) 2,709.00 14.00 35.20 2,700.69 2,542.69 68.64 33.77 2,430,139.46 314,403.04 0.50 33.77 MWD+SC+sag(1) 2,771.00 15.00 33.70 2,760.72 2,602.72 81.44 42.55 2,430,152.12 314,412.01 1.72 42.55 MWD+SC+sag(1) 2,834.00 16.00 32.70 2,821.42 2,663.42 95.53 51.76 2,430,166.06 314,421.45 1.64 51.76 MWD+SC+sag(1) I 2,897.00 16.30 31.50 2.881.94 2,723.94 110.37 61.07 2,430,180.76 314,430.99 0.71 61.07 MWD+SC+sag(1) 2,960.00 17.30 27.30 2,942.25 2,784.25 126.24 69.99 2,430,196.48 314,440.15 2.50 69.99 MWD+SC+sag(1) 3,023.00 18.10 25.50 3,002.27 2,844.27 143.39 78.50 2,430,213.50 314,448.93 1.54 78.50 MWD+SC+sag(1) ' 3,085.00 19.90 25.30 3,060.89 2,902.89 161.63 87.15 2,430,231.60 314,457.87 2.91 87.15 MWD+SC+sag(1) 3,147.00 21.50 26.00 3,118.88 2,960.88 181.38 96.64 2,430,251.20 314,467.67 2.61 96.64 MWD+SC+sag(1) 3,210.00 22.90 28.00 3,177.21 3,019.21 202.58 107.46 2,430,272.22 314,478.82 2.52 107.46 MWD+SC+sag(1) 3,273.00 24.40 29.10 3,234.92 3,076.92 224.77 119.54 2,430,294.23 314,491.25 2.48 119.54 MWD+SC+sag(1) 3,335.00 25.50 29.80 3,291.13 3,133.13 247.55 132.40 2,430,316.79 314,504.47 1.84 132.40 MWD+SC+sag(1) 3,398.00 27.20 29.60 3,347.59 3,189.59 271.84 146.26 2,430,340.86 314,518.71 2.70 146.26 MWD+SC+sag(1) , 3,461.00 29.90 30.80 3,402.92 3,244.92 297.85 161.41 2,430,366.63 314,534.27 4.38 161.41 MWD+SC+sag(1) 3,523.00 31.50 31.90 3,456.23 3,298.23 324.87 177.88 2,430,393.40 314,551.16 2.73 177.88 MWD+SC+sag(1) 3,587.00 33.30 31.70 3,510.27 3,352.27 354.02 195.95 2,430,422.25 314,569.69 2.82 195.95 MWD+SC+sag(1) 3,650.00 36.30 30.60 3,561.99 3,403.99 384.79 214.54 2,430,452.73 314,588.76 4.86 214.54 MWD+SC+sag(1) 3,712.00 36.50 30.00 3,611.90 3,453.90 416.56 233.10 2,430,484.20 314,607.82 0.66 233.10 MWD+SC+sag(1) 3,775.00 36.40 30.20 3,662.57 3,504.57 448.94 251.87 2,430,516.28 314,627.09 0.25 251.87 MWD+SC+sag(1) 3,839.00 36.20 30,60 3,714.15 3,556.15 481.62 271.04 2,430,548.66 314,646.78 0.48 271.04 MWD+SC+sag(1) 3,902.00 35.60 29.20 3.765.18 3,607.18 513.64 289.46 2,430,580.38 314,665.70 1.61 289.46 MWD+SC+sag(1) 3,965.00 34.60 26.70 3,816.73 3,658.73 545.63 306.44 2,430,612.10 314,683.18 2.78 306.44 MWD+SC+sag(1) 4,028.00 34.60 26.70 3,868.59 3,710.59 577.59 322.52 2,430,643.80 314,699.76 0.00 322.52 MWD+SC+sag(1) 4,090.00 34.20 26.50 3,919.74 3,761.74 608.91 338.20 2,430,674.87 314,715.93 0.67 338.20 MWD+SC+sag(1) 4,153.00 34.10 26.80 3,971.88 3,813.88 640.52 354.07 2,430,706.23 314,732.29 0.31 354.07 MWD+SC+sag(1) 4,215.00 33.80 26.40 4,023.31 3,865.31 671.48 369.57 2,430,736.94 314,748.28 0.60 369.57 MWD+SC+sag(1) 4,277.00 33.70 26.90 4,074.86 3,916.86 702.26 385.02 2,430,767.48 314,764.21 0.48 385.02 MWD+SC+sag(1) 4/23/2014 5::24.46PM Page 4 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 14 Project: Beaver Creek Unit TVD Reference: BCU 14A©158.00usft Site: Beaver Creek Unit MD Reference: BCU 14A @ 158.00usft Well: Beaver CK Unit 14 North Reference: True Wellbore: BCU-14A Survey Calculation Method: Minimum Curvature Design: BCU-14A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 4,340.00 33.50 27.10 4,127.34 3,969.34 733.33 400.85 2,430,798.29 314,780.53 0.36 400.85 MWD+SC+sag(1) 4,403.00 33.20 27.00 4,179.96 4,021.96 764.17 416.60 2,430,828.88 314,796.76 0.48 416.60 MWD+SC+sag(1) 4,463.00 33.10 27.20 4,230.20 4,072.20 793.38 431.54 2,430,857.85 314,812.17 0.25 431.54 MWD+SC+sag(1) 4,527.00 33.10 27.40 4,283.81 4,125.81 824.44 447.57 2,430,888.65 314,828.68 0.17 447.57 MWD+SC+sag(1) 4,589.00 33.50 28.90 4,335.63 4,177.63 854.45 463.63 2,430,918.41 314,845.21 1.48 463.63 MWD+SC+sag(1) 4,651.00 33.30 29.20 4,387.39 4,229.39 884.28 480.21 2,430,947.98 314,862.25 0.42 480.21 MWD+SC+sag(1) 4,714.00 33.10 29.70 4,440.11 4,282.11 914.32 497.17 2,430,977.75 314,879.68 0.54 497.17 MWD+SC+sag(1) 4,778.00 33.20 30.10 4,493.69 4,335.69 944.66 514.61 2,431,007.81 314,897.60 0.38 514.61 MWD+SC+sag(1) 4,841.00 34.80 30.10 4,545.92 4,387.92 975.14 532.28 2,431,038.00 314,915.75 2.54 532.28 MWD+SC+sag(1) 4,904.00 35.10 30.20 4,597.56 4,439.56 1,006.35 550.41 2,431,068.92 314,934.36 0.48 550.41 MWD+SC+sag(1) 4,968.00 34.20 30.40 4,650.21 4,492.21 1,037.76 568.76 2,431,100.05 314,953.21 1.42 568.76 MWD+SC+sag(1) 5,031.00 34.10 31.30 4,702.34 4,544.34 1,068.13 586.90 2,431,130.12 314,971.82 0.82 586.90 MWD+SC+sag(1) 5,081.00 34.26 30.82 4,743.71 4,585.71 1,092.19 601.39 2,431,153.95 314,986.69 0.63 601.39 MWD_Interp Azi(2) 5,120.09 34.74 33.10 4,775.92 4,617.92 1,110.97 613.11 2,431,172.54 314,998.71 3.52 613.11 MWD_InterpAzi(2) 5,181.45 34.26 36.68 4,826.50 4,668.50 1,139.47 632.98 2,431,200.73 315,019.02 3.40 632.98 MWD_InterpAzi(2) 5,241.81 34.21 40.19 4,876.40 4,718.40 1,166.06 654.08 2,431,226.98 315,040.54 3.27 654.08 MWD_InterpAzi(2) 5,304.13 33.07 44.55 4,928.29 4,770.29 1,191.56 677.32 2,431,252.12 315,064.17 4.28 677.32 MWD_InterpAzi(2) 5,366.98 32.84 46.48 4,981.03 4,823.03 1,215.52 701.70 2,431,275.69 315,088.93 1.71 701.70 MWD_InterpAzi(2) 5,428.90 32.13 45.92 5,033.26 4,875.26 1,238.54 725.71 2,431,298.32 315,113.30 1.25 725.71 MWD_InterpAzi(2) 5,491.21 31.79 46.06 5,086.13 4,928.13 1,261.45 749.43 2,431,320.86 315,137.38 0.56 749.43 MWD+SC+sag(3) 5,552.79 30.34 45.69 5,138.88 4,980.88 1,283.57 772.24 2,431,342.62 315,160.53 2.37 772.24 MWD+SC+sag(3) 5,614.80 28.97 45.15 5,192.76 5,034.76 1,305.11 794.09 2,431,363.81 315,182.72 2.25 794.09 MWD+SC+sag(3) 5,677.04 27.10 45.37 5,247.70 5,089.70 1,325.70 814.87 2,431,384.07 315,203.82 3.01 814.87 MWD+SC+sag(3) 5,739.46 25.97 43.78 5,303.54 5,145.54 1,345.55 834.45 2,431,403.62 315,223.71 2.14 834.45 MWD+SC+sag(3) 5,801.28 24.00 44.09 5,359.57 5,201.57 1,364.36 852.56 2,431,422.13 315,242.11 3.19 852.56 MWD+SC+sag(3) 5,863.14 22.50 45.12 5,416.41 5,258.41 1,381.75 869.70 2,431,439.25 315,259.53 2.51 869.70 MWD+SC+sag(3) 5,924.54 21.22 44.95 5,473.39 5,315.39 1,397.90 885.88 2,431,455.15 315,275.95 2.09 885.88 MWD+SC+sag(3) 5,985.96 20.25 45.69 5,530.83 5,372.83 1,413.19 901.34 2,431,470.20 315,291.65 1.64 901.34 MWD+SC+sag(3) 6,047.71 20.14 45.76 5,588.79 5,430.79 1,428.07 916.60 2,431,484.83 315,307.15 0.18 916.60 MWD+SC+sag(3) 6,109.61 20.18 46.30 5,646.90 5,488.90 1,442.89 931.95 2,431,499.40 315,322.73 0.31 931.95 MWD+SC+sag(3) 6,171.74 20.53 47.17 5,705.15 5,547.15 1,457.70 947.69 2,431,513.96 315,338.70 0.74 947.69 MWD+SC+sag(3) 6,234.21 20.32 47.48 5,763.69 5,605.69 1,472.47 963.72 2,431,528.49 315,354.96 0.38 963.72 MWD+SC+sag(3) 6,296.82 20.16 47.22 5,822.43 5,664.43 1,487.15 979.65 2,431,542.91 315,371.12 0.29 979.65 MWD+SC+sag(3) 6,359.20 20.61 45.32 5,880.91 5,722.91 1,502.17 995.35 2,431,557.68 315,387.05 1.28 995.35 MWD+SC+sag(3) 6,420.67 20.62 44.83 5,938.44 5,780.44 1,517.45 1,010.67 2,431,572.72 315,402.61 0.28 1,010.67 MWD+SC+sag(3) 6,483.33 20.25 44.77 5,997.16 5,839.16 1,532.98 1,026.09 2,431,588.00 315,418.27 0.59 1,026.09 MWD+SC+sag(3) 6,544.29 20.32 44.94 6,054.34 5,896.34 1,547.96 1,040.99 2,431,602.75 315,433.41 0.15 1,040.99 MWD+SC+sag(3) 6,605.86 20.96 45.25 6,111.95 5,953.95 1,563.28 1,056.36 2,431,617.82 315,449.02 1.05 1,056.36 MWD+SC+sag(3) 6,668.72 21.02 45.31 6,170.64 6,012.64 1,579.12 1,072.36 2,431,633.41 315,465.27 0.10 1,072.36 MWD+SC+sag(3) 6,729.85 20.94 45.08 6,227.72 6,069.72 1,594.55 1,087.89 2,431,648.59 315,481.04 0.19 1,087.89 MWD+SC+sag(3) 4/23/2014 5:24:46PM Page 5 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 14 Project: Beaver Creek Unit TVD Reference: BCU 14A @ 158.00usft Site: Beaver Creek Unit MD Reference: BCU 14A @ 158.00usft Well: Beaver CK Unit 14 North Reference: True Wellbore: BCU-14A Survey Calculation Method: Minimum Curvature Design: BCU-14A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 6,793.24 20.78 45.13 6,286.96 6,128.96 1,610.48 1,103.88 2,431,664.27 315,497.28 0.25 1,103.88 MWD+SC+sag(3) 6,854.38 20.76 45.03 6,344.12 6,186.12 1,625.79 1,119.24 2,431,679.33 315,512.87 0.07 1,119.24 MWD+SC+sag(3) 6,917.58 20.47 44.85 6,403.28 6,245.28 1,641.54 1,134.95 2,431,694.84 315,528.83 0.47 1,134.95 MWD+SC+sag(3) 6,979.17 20.29 44.80 6,461.01 6,303.01 1,656.75 1,150.07 2,431,709.81 315,544.19 0.29 1,150.07 MWD+SC+sag(3) 7,040.73 19.92 44.67 6,518.82 6,360.82 1,671.78 1,164.97 2,431,724.60 315,559.32 0.61 1,164.97 MWD+SC+sag(3) 7,102.97 20.18 46.30 6,577.29 6,419.29 1,686.74 1,180.18 2,431,739.32 315,574.77 0.99 1,180.18 MWD+SC+sag(3) 7,165.16 20.18 46.45 6,635.66 6,477.66 1,701.54 1,195.71 2,431,753.88 315,590.53 0.08 1,195.71 MWD+SC+sag(3) 7,227.83 19.95 46.61 6,694.53 6,536.53 1,716.33 1,211.32 2,431,768.42 315,606.36 0.38 1,211.32 MWD+SC+sag(3) 7,289.86 20.00 46.51 6,752.82 6,594.82 1,730.90 1,226.70 2,431,782.75 315,621.98 0.10 1,226.70 MWD+SC+sag(3) 7,352.04 19.79 45.92 6,811.29 6,653.29 1,745.55 1,241.98 2,431,797.15 315,637.48 0.47 1,241.98 MWD+SC+sag(3) 7,415.10 19.61 45.40 6,870.66 6,712.66 1,760.40 1,257.18 2,431,811.76 315,652.92 0.40 1,257.18 MWD+SC+sag(3) 7,476.17 19.59 45.55 6,928.19 6,770.19 1,774.77 1,271.79 2,431,825.90 315,667.75 0.09 1,271.79 MWD+SC+sag(3) 7,538.21 17.97 46.83 6,986.93 6,828.93 1,788.60 1,286.19 2,431,839.50 315,682.37 2.69 1,286.19 MWD+SC+sag(3) 7,601.90 16.92 46.32 7,047.69 6,889.69 1,801.72 1,300.06 2,431,852.40 315,696.44 1.67 1,300.06 MWD+SC+sag(3) 7,663.98 15.70 45.26 7,107.27 6,949.27 1,813.87 1,312.56 2,431,864.36 315,709.13 2.02 1,312.56 MWD+SC+sag(3) 7,724.79 14.33 44.61 7,166.00 7,008.00 1,825.02 1,323.69 2,431,875.33 315,720.44 2.27 1,323.69 MWD+SC+sag(3) 7,788.12 12.77 48.03 7,227.57 7,069.57 1,835.28 1,334.40 2,431,885.42 315,731.30 2.77 1,334.40 MWD+SC+sag(3) 7,850.07 11.01 48.73 7,288.19 7,130.19 1,843.77 1,343.94 2,431,893.75 315,740.97 2.85 1,343.94 MWD+SC+sag(3) ' 7,912.49 10.61 46.83 7,349.50 7,191.50 1,851.63 1,352.61 2,431,901.48 315,749.77 0.86 1,352.61 MWD+SC+sag(3) 7,973.41 10.37 46.54 7,409.40 7,251.40 1,859.24 1,360.68 2,431,908.96 315,757.96 0.40 1,360.68 MWD+SC+sag(3) 8,038.97 10.18 46.66 7,473.91 7,315.91 1,867.27 1,369.18 2,431,916.86 315,766.58 0.29 1,369.18 MWD+SC+sag(3) 8,099.24 10.08 46.25 7,533.24 7,375.24 1,874.57 1,376.86 2,431,924.04 315,774.38 0.20 1,376.86 MWD+SC+sag(3) 8,159.41 10.03 45.55 7,592.49 7,434.49 1,881.89 1,384.40 2,431,931.23 315,782.03 0.22 1,384.40 MWD+SC+sag(3) li 8,221.50 9.83 45.85 7,653.65 7,495.65 1,889.36 1,392.07 2,431,938.58 315,789.81 0.33 1,392.07 MWD+SC+sag(3) 8,284.89 9.84 44.87 7,716.10 7,558.10 1,896.97 1,399.77 2,431,946.07 315,797.64 0.26 1,399.77 MWD+SC+sag(3) 8,346.83 9.76 44.82 7,777.14 7,619.14 1,904.45 1,407.20 2,431,953.43 315,805.19 0.13 1,407.20 MWD+SC+sag(3) 8,409.86 9.75 43.97 7,839.26 7,681.26 1,912.08 1,414.68 2,431,960.94 315,812.78 0.23 1,414.68 MWD+SC+sag(3) 8,468.69 9.83 44.13 7,897.23 7,739.23 1,919.27 1,421.63 2,431,968.02 315,819.85 0.14 1,421.63 MWD+SC+sag(3) 8,530.38 9.54 44.45 7,958.04 7,800.04 1,926.70 1,428.88 2,431,975.33 315,827.21 0.48 1,428.88 MWD+SC+sag(3) 8,592.44 9.49 45.56 8,019.25 7,861.25 1,933.95 1,436.13 2,431,982.47 315,834.58 0.31 1,436.13 MWD+SC+sag(3) 8,654.45 8.47 43.64 8,080.50 7,922.50 1,940.83 1,442.93 2,431,989.25 315,841.49 1.71 1,442.93 MWD+SC+sag(3) 8,716.86 7.75 41.77 8,142.28 7,984.28 1,947.30 1,448.91 2,431,995.62 315,847.56 1.23 1,448.91 MWD+SC+sag(3) 8,778.89 7.51 41.80 8,203.76 8,045.76 1,953.44 1,454.40 2,432,001.67 315,853.15 0.39 1,454.40 MWD+SC+sag(3) 8,841.09 7.46 40.92 8,265.43 8,107.43 1,959.52 1,459.75 2,432,007.67 315,858.59 0.20 1,459.75 MWD+SC+sag(3) 8,903.72 7.18 45.84 8,327.55 8,169.55 1,965.32 1,465.22 2,432,013.38 315,864.16 1.10 1,465.22 MWD+SC+sag(3) 8,965.38 6.88 45.70 8,388.75 8,230.75 1,970.58 1,470.63 2,432,018.56 315,869.65 0.49 1,470.63 MWD+SC+sag(3) 9,028.53 6.82 46.54 8,451.45 8,293.45 1,975.80 1,476.06 2,432,023.69 315,875.16 0.18 1,476.06 MWD+SC+sag(3) 9,090.34 6.89 46.35 8,512.82 8,354.82 1,980.89 1,481.40 2,432,028.69 315,880.58 0.12 1,481.40 MWD+SC+sag(3) 9,152.17 6.84 47.10 8,574.21 8,416.21 1,985.95 1,486.79 2,432,033.67 315,886.04 0.17 1,486.79 MWD+SC+sag(3) 9,212.39 6.84 46.80 8,634.00 8,476.00 1,990.85 1,492.03 2,432,038.49 315,891.36 0.06 1,492.03 MWD+SC+sag(3) 4/23/2014 5:24:46PM Page 6 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 14 Project: Beaver Creek Unit TVD Reference: BCU 14A @ 158.00usft Site: Beaver Creek Unit MD Reference: BCU 14A @ 158.00usft Well: Beaver CK Unit 14 North Reference: True Wellbore: BCU-14A Survey Calculation Method: Minimum Curvature Design: BCU-14A Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 9,275.50 6.78 46.58 8,696.66 8,538.66 1,995.98 1,497.47 2,432,043.53 315,896.88 0.10 1,497.47 MWD+SC+sag(3) 9,337.05 6.76 46.51 8,757.78 8,599.78 2,000.97 1,502.74 2,432,048.44 315,902.23 0.04 1,502.74 MWD+SC+sag(3) 9,398.72 6.69 46.38 8,819.03 8,661.03 2,005.95 1,507.97 2,432,053.33 315,907.54 0.12 1,507.97 MWD+SC+sag(3) 9,450.00 6.69 46.38 8,869.96 8,711.96 2,010.07 1,512.30 2,432,057.39 315,911.93 0.00 1,512.30 PROJECTED to TD 4/23/2014 5:24:46PM Page 7 COMPASS 5000.1 Build 70 Project: Beaver Creek Unit Well: BCU-14A HALLIBURTON Site: Wellbore: BCU 14A Beaver Creek Unit Sperry Drilling Services Beaver CK 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CO 00 01 01 0 0 ri 00 00 00 00 00 00 CO CO CO 00 00 00 00 00 00 CO 61 0 61 Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln 111 ri ri r-I r1 1-i ri r 1 1--1 1--1 1--1 1-1 1-1 r 1 r-1 1--1 1--1 ri 1-1 1--1 M M M M M M M M M M M M M M M M M rn M 1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Iim.reggCcDalaska.qov AOGCC.Inspectors( alaska.gov phoebe.brooks(a alaska.gov Contractor: Saxon Rig No.: 169 DATE: 1/21/14 Rig Rep.: Jay Compton Rig Phone: 907-268-3148 Rig Fax: Operator: Hilcorp Alaska, LLC Op. Phone: 907-776-6776 Op. Fax: Rep.: Rance Pederson E-Mail rpederson@hilcorp.com Well Name: BCU 14 PTD# 2040860 Operation: DrIg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/4000 Annular: 250/2500 Valves: 250/4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11" P Pit Level Indicators P P #1 Rams 1 2 7/8 X 5" P Flow Indicator P P #2 Rams 1 11" Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8 X 5" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 2 3 1/8" P Kill Line Valves 2 2 1/16" FP Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 2800 P • CHOKE MANIFOLD: Pressure After Closure 1460 P Quantity Test Result 200 psi Attained 33 P No. Valves 13 FP Full Pressure Attained 102 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles(avg): 4 @ 2600 CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 4 Test Time: 13.5 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested annular, upper and lower rams with 4 1/2"test joint at 10 minute intervals, as per BLM. Had 3 fail/pass tests on CMV's 4,5 and 8. Greased and cycled valves and retested OK. Outer manual kill line valve failed numerous times. Replaced outer kill line valve and re-tested OK. Gas detectors were 24 HOUR NOTICE GIVEN YES NO X Waived By Jim Regg Date 1/20/14 Time 10:00 Witness Test start 10:30 (1-21) Finish 12:00 (1-22) Form 10-424 (Revised 03/2013) Saxon 169 1-21-14 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim.regqAalaska.gov AOGCC.Inspectors(a alaska.gov phoebe.brooks(a�alaska.qov Contractor: Saxon Rig No.: 169 DATE: 1/25/14 Rig Rep.: Ryan Archer Rig Phone: 907-268-3148 Rig Fax: Operator: Hilcorp Alaska, LLC Op. Phone: 907-776-6776 Op. Fax: Rep.: Rance Pederson E-Mail rpederson@hilcorp.com Well Name: BCU 14RD PTD# 2131960 Operation: Drlg: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/4000 Annular: 250/2500 Valves: 250/4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11" P Pit Level Indicators P P #1 Rams 1 2 7/8 X 5" P _ Flow Indicator P P #2 Rams 1 11" Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8 X 5" P H2S Gas Detector P P #4 Rams 0 NA MS Misc_ 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 2 3 1/8" P Kill Line Valves 2 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 2800 P CHOKE MANIFOLD: Pressure After Closure 1400 P _ Quantity Test Result 200 psi Attained 26 P No. Valves 13 P Full Pressure Attained 97 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles(avg): 4 @ 2525 CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 8.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Tested annular, upper and lower rams with 4 1/2"test joint at 5 minute intervals. Gas detectors and alarms were tested by Total Safety. Pit fluid level alarms are working properly as well as flow indicator and alarm. 24 HOUR NOTICE GIVEN YES X NO Waived By Date 1/24/14 Time 06:00 Witness Lou Grimaldi Test start 03:00 (1-25) Finish 11:00 (1-25) Form 10-424 (Revised 03/2013) Saxon 169 01-25-14 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. BCU-14A Date 6-Feb-14 County Kenai Peninsula Burough State Alaska Supv. Joe Grubb/Jimmy Greco CASING RECORD TD 9450.00 Shoe Depth: 9419.10 PBTD: MD/'TVD Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 51/2 STL Wfd 1.53 9,419.10 9,417.57 2 5 1/2 20 P-1110 XP BTC 81.97 9,417.57 9,335.60 F.Collar 5 1/2 STL Wfd 1.03 9,335.60 9,334.57 108&2 Pups 5 1/2 20 P-1110 XP BTC 4,455.44 9,334.57 4,879.13 Swell PKR 5 1/2 20 P-1110 XP BTC 22.14 4,879.13 4,856.99 117 5 1/2 20 _ P-1110 _ XP BTC 4,834.95 4,856.99 22.04 Pup 5 1/2 P-1110 XP BTC 3.71 22.04 18.33 Hanger _ 0.83 18.33 17.50 RKB 17.50 17.50 0.00 Total Csg Wt.On Hook: 181,644 Type Float Collar: Float No.Hrs to Run: 18 Csg Wt.On Slips: Type of Shoe: Bullnose Casing Crew: Wfd Fluid Description: 9.6 ppg 6%KCL/ PV=13 YP=22 HTHP=12.1 Liner hanger Info(Make/Model): Liner top Packer?. Yes X No Liner hanger test pressure: 0 Centralizer Placement: Centralizers on each joint in shoe track,then every other joint to window. Then every 4th joint to surface.Total of 87 centralizers placed on string. CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) _ 12.5 Volume pumped(BBLs) 34 Lead Slurry Type: G g72 5X Density(ppg) 15.3 Volume pumped(BBLs) 232 Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: 1 Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 1- Post Flush(Spacer) Type: Density(ppg) Rate(bpm). Volume: re I Displacement: Type. water Density(ppg) 8.3 ppg Rate(bpm): 5 bpm Volume(actual/calculated): 207.5/200 FCP(psi): 2200 Pump used for disp: Schlumberger pump Plug Bumped? x Yes No Bump press 2755 Casing Rotated? Yes X No Reciprocated? _Yes X No %Returns during job MI Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: 23:35 Date: 2/6/2014 Estimated TOC: 4,081 Method Used To Determine TOC: tit-",[1-- TO c. 0— 1{7 2.5 r Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): co Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: wDisplacement: Type Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf. Cement In Place At: Date: Estimated TOC. Method Used To Determine TOC: CASING RUN IN TALLY WELL NAME: BCU 14A DATE: 02/05/14 CASING SIZE 5.500 inches WEIGHT 20.00 ppf CASING ID 4.778 inches GRADE P-110 THREAD XP BTC CAPACITY 0.0222 bbls/ft TORQUE - OPTIMUM = 12520 MIN= 11270 DISPLACEMENT 0.0095 bbls/ft SHOE DEPTH 9419.10 feet HOLE TD 9450.00 feet Foreman: Grubb/Greco MUD WT 9.40 ppg _ Joint Running Joint Depth BOUY FACTOR 0.86 Joint# Joint# Length _ Total Bottom Top REMARKS: Bouyant Capacity Displmt on rack in hole feet feet feet feet Run 87 Centralizers weight bbls bbls Off Br '" "" Block Weight => 21,000 Weatherford Bullnose A 1.53 1.53 9419.10 9417.57 Shoe SN:488700 21,026 0.0 0.0 227 1 41 .28 42.81 9417.57 9376.29 P-110 XP BTC( -xl 1) 21,733 0.9 0.4 226 2 40.69 83.50 9376.29 9335.60 P-110 XP BTC ( ) 22,430 1.9 0.8 B 1.03 84.53 9335.60 9334.57 22,448 1.9 0.8 225 3 41 .40 125.93 9334.57 9293.17 P-110 XP BTC( ) 23,157 2.8 1.2 224 4 41 .95 167.88 9293.17 9251.22 P-110 XP BTC(red 4) 23,876 3.7 1.6 223 5 41 .40 209.28 9251.22 9209.82 P-110 XP BTC(silver 1) 24,585 4.6 2.0 222 6 40.84 250.12 9209.82 9168.98 P-110 XP BTC(red 5) 25,284 5.5 2.4 221 7 41 .22 291.34 9168.98 9127.76 P-110 XP BTC(red 6) 25,991 6.5 2.8 220 8 41 .25 332.59 9127.76 9086.51 P-110 XP BTC(silver 2) 26,697 7.4 3.2 219 9 41 .27 373.86 9086.51 9045.24 P-110 XP BTC(silver 3) 27,404 8.3 3.6 218 10 41 .28 415.14 9045.24 9003.96 P-110 XP BTC 28,111 9.2 3.9 217 11 41 .29 456.43 9003.96 8962.67 P-110 XP BTC(red 7) 28,819 10.1 4.3 216 12 41 .67 498.10 8962.67 8921.00 P-110 XP BTC 29,532 11.0 4.7 15.03 513.13 8921.00 8905.97 Pup Joint 29,790 11.4 4.9 215 13 41 .23 554.36 8905.97 8864.74 P-110 XP BTC(silver 4) 30,496 12.3 5.3 214 14 41 .28 595.64 8864.74 8823.46 P-110 XP BTC 31,203 13.2 5.7 213 15 41 .38 637.02 8823.46 8782.08 P-110 XP BTC(silver 5) 31,912 14.1 6.1 212 16 40.50 677.52 8782.08 8741.58 P-110 XP BTC 32,606 15.0 6.4 211 17 41 .25 718.77 8741.58 8700.33 P-110 XP BTC(red 8) 33,312 15.9 6.8 210 18 41 .49 760.26 8700.33 8658.84 P-110 XP BTC 34,023 16.9 7.2 209 19 41 .27 801.53 8658.84 8617.57 P-110 XP BTC(silver 6) 34,730 17.8 7.6 208 20 41 .40 842.93 8617.57 8576.17 P-110 XP BTC 35,439 18.7 8.0 207 21 41 .36 884.29 8576.17 8534.81 P-110 XP BTC(silver 7) 36,148 19.6 8.4 206 22 41 .47 925.76 8534.81 8493.34 P-110 XP BTC 36,858 20.5 8.8 205 23 41 .11 966.87 8493.34 8452.23 P-110 XP BTC(red 9) 37,562 21.4 9.2 204 24 41 .02 1007.89 8452.23 8411.21 P-110 XP BTC 38,265 22.4 9.6 203 25 41 .27 1049.16 8411.21 8369.94 P-110 XP BTC(silver 8) 38,972 23.3 10.0 202 26 41 .25 1090.41 8369.94 8328.69 P-110 XP BTC 39,678 24.2 10.4 201 27 41 .51 1131.92 8328.69 8287.18 P-110 XP BTC(silver 9) 40,390 25.1 10.8 200 28 41 .23 1173.15 8287.18 8245.95 P-110 XP BTC 41,096 26.0 11.1 199 29 41 .65 1214.80 8245.95 8204.30 P-110 XP BTC(red 10) 41,809 26.9 11.5 198 30 41 .41 1256.21 8204.30 8162.89 P-110 XP BTC 42,519 27.9 11.9 197 31 41 .84 1298.05 8162.89 8121.05 P-110 XP BTC(silver 10 43,235 28.8 12.3 196 32 41 .16 1339.21 8121.05 8079.89 P-110 XP BTC 43,940 29.7 12.7 Joint Running Joint Depth BOUY FACTOR 0.86 I Joint# Joint# Length Total Bottom Top REMARKS: Bouyant Capacity Displmt on rack in hole feet feet feet feet Run 87 Centralizers weight bbls bbls 195 33 40.93 1380.14 8079.89 8038.96 '-110 XP BTC(silver 11 44,641 30.6 13.1 194 34 41 .52 1421.66 8038.96 7997.44 P-110 XP BTC 45,353 31.5 13.5 193 35 40.60 1462.26 7997.44 7956.84 P-110 XP BTC(red II) 46,048 32.4 13.9 192 36 41 .17 1503.43 7956.84 7915.67 P-110 XP BTC 46,753 33.3 14.3 15.13 1518.56 7915.67 7900.54 Pup Joint 47,013 33.7 14.4 191 37 41 .22 1559.78 7900.54 7859.32 '-110 XP BTC(silver 12 47,719 34.6 14.8 190 38 41 .88 1601.66 7859.32 7817.44 P-110 XP BTC 48,436 35.5 15.2 189 39 41 .50 1643.16 7817.44 7775.94 '-110 XP BTC(silver 13 49,147 36.4 15.6 188 40 41 .38 1684.54 7775.94 7734.56 P-110 XP BTC 49,856 37.4 16.0 187 41 41 .47 1726.01 7734.56 7693.09 P-110 XP BTC(red 12) 50,566 38.3 16.4 186 42 41 .60 1767.61 7693.09 7651.49 P-110 XP BTC 51,279 39.2 16.8 185 43 41 .01 1808.62 7651.49 7610.48 '-110 XP BTC(silver 14 51,981 40.1 17.2 184 44 41 .59 1850.21 7610.48 7568.89 P-110 XPBTC 52,694 41.0 17.6 183 45 41 .60 1891.81 7568.89 7527.29 '-110 XP BTC(silver 15 53,406 42.0 18.0 182 46 41 .61 1933.42 7527.29 7485.68 P-110 XP BTC 54,119 42.9 18.4 181 47 41 .58 1975.00 7485.68 7444.10 P-110 XP BTC(red 13) 54,831 43.8 18.8 180 48 41 .59 2016.59 7444.10 7402.51 P-110 XP BTC 55,544 44.7 19.2 179 49 41 .49 2058.08 7402.51 7361.02 '-110 XP BTC(silver 16 56,254 45.6 19.6 178 50 41 .34 2099.42 7361.02 7319.68 P-110 XP BTC 56,963 46.6 19.9 177 51 41 .32 2140.74 7319.68 7278.36 '-110 XP BTC(silver 17 57,670 47.5 20.3 176 52 41 .25 2181.99 7278.36 7237.11 P-110 XP BTC 58,377 48.4 20.7 175 53 41 .25 2223.24 7237.11 7195.86 P-110 XP BTC(red 14) 59,084 49.3 21.1 174 54 40.93 2264.17 7195.86 7154.93 P-110 XP BTC 59,785 50.2 21.5 173 55 41 .39 2305.56 7154.93 7113.54 '-110 XP BTC(silver 18 60,494 51.1 21.9 172 56 41 .24 2346.80 7113.54 7072.30 P-110 XP BTC 61,200 52.1 22.3 171 57 41 .26 2388.06 7072.30 7031.04 '-110 XP BTC(silver 19 61,907 53.0 22.7 170 58 41 .26 2429.32 7031.04 6989.78 P-110 XP BTC 62,614 53.9 23.1 169 59 41 .89 2471.21 6989.78 6947.89 P-110 XP BTC(red 15) 63,331 54.8 23.5 168 60 41 .67 2512.88 6947.89 6906.22 P-110 XP BTC 64,045 55.7 23.9 167 61 40.21 2553.09 6906.22 6866.01 '-110 XP BTC(silver 20 64,734 56.6 24.3 166 62 41 .23 2594.32 6866.01 6824.78 P-I 10 XPBTC 65,440 57.5 24.6 165 63 41 .22 2635.54 6824.78 6783.56 '-110 XP BTC(silver 21 66,146 58.5 25.0 164 64 40.87 2676.41 6783.56 6742.69 P-110 XP BTC 66,846 59.4 25.4 163 65 41 .18 2717.59 6742.69 6701.51 P-110 XP BTC(red 16) 67,552 60.3 25.8 162 66 40.95 2758.54 6701.51 6660.56 P-110 XP BTC 68,253 61.2 26.2 161 67 40.90 2799.44 6660.56 6619.66 '-110 XP BTC(silver 22 68,954 62.1 26.6 160 68 40.90 2840.34 6619.66 6578.76 P-110 XP BTC 69,654 63.0 27.0 159 69 41 .80 2882.14 6578.76 6536.96 '-110 XP BTC(silver 23 70,370 63.9 27.4 158 70 41 .19 2923.33 6536.96 6495.77 P-110 XP BTC 71,076 64.8 27.8 157 71 40.97 2964.30 6495.77 6454.80 P-110 XP BTC(red 17) 71,778 65.7 28.2 156 72 41 .38 3005.68 6454.80 6413.42 P-110 XP BTC 72,487 66.7 28.6 155 73 41 .56 3047.24 6413.42 6371.86 '-110 XP BTC(silver 24 73,199 67.6 28.9 154 74 41 .46 3088.70 6371.86 6330.40 P-110 XP BTC 73,909 68.5 29.3 153 75 41 .25 3129.95 6330.40 6289.15 '-110 XP BTC(silver 25 74,615 69.4 29.7 152 76 41 .23 3171.18 6289.15 6247.92 P-110 XP BTC 75,322 70.3 30.1 151 77 41 .23 3212.41 6247.92 6206.69 P-110 XP BTC(red 18) 76,028 71.3 30.5 150 78 41 .27 3253.68 6206.69 6165.42 P-110 XP BTC 76,735 72.2 30.9 149 79 41 .80 3295.48 6165.42 6123.62 '-110 XP BTC(silver 26 77,451 73.1 31.3 148 80 41 .63 3337.11 6123.62 6081.99 P-110 XPBTC 78,164 74.0 31.7 Joint Running Joint Depth BOUY FACTOR 0.86 Joint# Joint# Length Total Bottom Top REMARKS: Bouyant Capacity Displmt on rack in hole feet feet feet feet Run 87 Centralizers weight bbls bbls 147 81 41 .37 3378.48 • 6081.99 6040.62 P-110 XP BTC(silver 27 78,873 74.9 32.1 146 82 41 .55 3420.03 6040.62 5999.07 P-110 XPBTC 79,584 75.9 32.5 145 83 41 .23 3461.26 5999.07 5957.84 P-110 XP BTC(red 19) 80,291 76.8 32.9 144 84 41 .41 3502.67 5957.84 5916.43 P-110 XP BTC 81,000 77.7 33.3 143 85 40.48 3543.15 5916.43 5875.95 P-110 XP BTC(silver 28 81,693 78.6 33.7 142 86 41 .87 3585.02 5875.95 5834.08 P-110 XP BTC 82,411 79.5 34.1 141 87 41 .55 3626.57 5834.08 5792.53 P-110 XP BTC(silver 29 83,122 80.4 34.5 140 88 41 .36 3667.93 5792.53 5751.17 P-110 XP BTC 83,831 81.4 34.8 139 89 41 .26 3709.19 5751.17 5709.91 P-110 XP BTC(red 20) 84,538 82.3 35.2 138 90 42.03 3751.22 5709.91 5667.88 P-110 XP BTC 85,258 83.2 35.6 137 91 41 .04 3792.26 5667.88 5626.84 P-110 XP BTC(silver 30 85,961 84.1 36.0 136 92 41 .45 3833.71 5626.84 5585.39 P-110 XP BTC 86,671 85.0 36.4 135 93 41 .75 3875.46 5585.39 5543.64 D-110 XP BTC(silver 31 87,386 86.0 36.8 134 94 41 .77 3917.23 5543.64 5501.87 P-110 XP BTC 88,101 86.9 37.2 133 95 41 .74 3958.97 5501.87 5460.13 P-110 XP BTC(red 21) 88,816 87.8 37.6 132 96 41 .72 4000.69 5460.13 5418.41 P-110 XP BTC 89,531 88.7 38.0 131 97 41 .21 4041.90 5418.41 5377.20 P-110 XP BTC(silver 32 90,237 89.6 38.4 130 98 41 .23 4083.13 5377.20 5335.97 P-110 XP BTC 90,943 90.6 38.8 129 99 41 .23 4124.36 5335.97 5294.74 °-110 XP BTC(silver 33 91,649 91.5 39.2 128 100 41 .47 4165.83 5294.74 5253.27 P-110 XP BTC 92,360 92.4 39.6 127 101 41 .95 4207.78 5253.27 5211.32 P-110 XP BTC(red 22) 93,078 93.3 40.0 126 102 41 .40 4249.18 5211.32 5169.92 P-110 XP BTC 93,787 94.2 40.4 125 103 41 .30 4290.48 5169.92 5128.62 P-110 XP BTC(silver 34 94,495 95.2 40.8 124 104 41 .60 4332.08 5128.62 5087.02 P-110 XP BTC 95,208 96.1 41.2 123 105 41 .25 4373.33 5087.02 5045.77 95,914 97.0 41.5 122 106 41 .60 4414.93 5045.77 5004.17 P-110 XP BTC 96,627 97.9 41.9 121 107 41 .75 4456.68 5004.17 4962.42 P-110 XP BTC(silver 35 97,342 98.8 42.3 120 108 41 .86 4498.54 4962.42 4920.56 P-110 XP BTC 98,059 99.8 42.7 119 109 41 .43 4539.97 4920.56 4879.13 P-110 XP BTC 98,769 100.7 43.1 118 110 22.14 4562.11 4879.13 4856.99 P-110 XP BTC(silver 36 99,148 101.2 43.3 41 .06 4603.17 4856.99 4815.93 PKR 99,851 102.1 43.7 117 111 41 .12 4644.29 4815.93 4774.81 P-110 XP BTC 99,852 102.1 43.7 116 112 41 .91 4686.20 4774.81 4732.90 P-110 XP BTC 100,570 103.0 44.1 115 113 40.75 4726.95 4732.90 4692.15 P-110 XP BTC(red 23) 101,268 103.9 44.5 114 114 40.82 4767.77 4692.15 4651.33 P-110 XP BTC 101,967 104.8 44.9 113 115 41 .72 4809.49 4651.33 4609.61 P-110 XP BTC 102,682 105.8 45.3 112 116 41 .74 4851.23 4609.61 4567.87 P-110 XP BTC 103,397 106.7 45.7 111 117 41 .74 4892.97 4567.87 4526.13 P-110 XP BTC(red 24) 104,112 107.6 46.1 110 118 41 .73 4934.70 4526.13 4484.40 P-110 XP BTC 104,827 108.5 46.5 109 119 41 .25 4975.95 4484.40 4443.15 P-110 XP BTC 105,534 109.5 46.9 108 120 41 .75 5017.70 4443.15 4401.40 P-110 xPBTC 106,249 110.4 47.3 107 121 41 .77 5059.47 4401.40 4359.63 P-110 XP BTC(red 25) 106,964 111.3 47.7 106 122 41 .77 5101.24 4359.63 4317.86 P-110 XP BTC 107,680 112.2 48.1 105 123 41 .78 5143.02 4317.86 4276.08 P-110 XP BTC 108,395 113.2 48.5 104 124 41 .86 5184.88 4276.08 4234.22 P-110 XP BTC 109,112 114.1 48.9 103 125 41 .91 5226.79 4234.22 4192.31 P-110 XP BTC(red 26) 109,830 115.0 49.3 102 126 41 .71 5268.50 4192.31 4150.60 P-110 XP BTC 110,545 115.9 49.7 101 127 41 .19 5309.69 4150.60 4109.41 P-110 XP BTC 111,250 116.9 50.1 100 128 41 .17 5350.86 4109.41 4068.24 P-110 XP BTC 111,956 117.8 50.4 Joint Running Joint Depth BOUY FACTOR 0.86 Joint# Joint# Length Total Bottom Top REMARKS: Bouyant Capacity Displmt on rack in hole feet feet feet feet Run 87 Centralizers weight bbls bbls 99 129 41 .24 5392.10 4068.24 4027.00 P-110 XP BTC(red 27) 112,662 118.7 50.8 98 130 40.91 5433.01 4027.00 3986.09 P-110 XP BTC 113,363 119.6 51.2 97 131 40.87 5473.88 3986.09 3945.22 P-110 XP BTC 114,063 120.5 51.6 96 132 41 .16 5515.04 3945.22 3904.06 P-110 XP BTC 114,768 121.4 52.0 95 133 41 .96 5557.00 3904.06 3862.10 P-110 XP BTC(red 28) 115,487 122.3 52.4 94 134 41 .29 5598.29 3862.10 3820.81 P-110 XP BTC 116,194 123.3 52.8 93 135 41 .73 5640.02 3820.81 3779.08 P-110 XP BTC 116,909 124.2 53.2 92 136 41 .28 5681.30 3779.08 3737.80 P-110 XP BTC 117,616 125.1 53.6 91 137 41.36 5722.66 3737.80 3696.44 P-110 XP BTC(red 29) 118,325 126.0 54.0 90 138 41 .85 5764.51 3696.44 3654.59 P-110 XP BTC 119,041 126.9 54.4 89 139 41 .28 5805.79 3654.59 3613.31 P-110 XP BTC 119,748 127.9 54.8 88 140 41 .30 5847.09 3613.31 3572.01 P-110 XP BTC 120,456 128.8 55.2 87 141 41 .29 5888.38 3572.01 3530.72 P-110 XP BTC(red 30) 121,163 129.7 55.5 86 142 41 .35 5929.73 3530.72 3489.37 P-110 XP BTC 121,872 130.6 55.9 85 143 41 .34 5971.07 3489.37 3448.03 P-110 XP BTC 122,580 131.5 56.3 84 144 41 .29 6012.36 3448.03 3406.74 P-110 XP BTC 123,287 132.4 56.7 83 145 41 .29 6053.65 3406.74 3365.45 P-110 XP BTC(red 31) 123,994 133.4 57.1 82 146 41 .27 6094.92 3365.45 3324.18 P-110 XP BTC 124,701 134.3 57.5 81 147 41 .26 6136.18 3324.18 3282.92 P-110 XP BTC 125,408 135.2 57.9 80 148 41 .26 6177.44 3282.92 3241.66 P-110 XP BTC 126,115 136.1 58.3 79 149 41 .30 6218.74 3241.66 3200.36 P-110 XP BTC(red 32) 126,822 137.0 58.7 78 150 41 .65 6260.39 3200.36 3158.71 P-110 XP BTC 127,536 137.9 59.1 77 151 41 .33 6301.72 3158.71 3117.38 P-110 XP BTC 128,244 138.9 59.5 76 152 41 .60 6343.32 3117.38 3075.78 P-110 XP BTC 128,956 139.8 59.9 75 153 41 .26 6384.58 3075.78 3034.52 P-110 XP BTC(red 33) 129,663 140.7 60.3 74 154 41 .63 6426.21 3034.52 2992.89 P-110 XP BTC 130,376 141.6 60.7 73 155 41 .32 6467.53 2992.89 2951.57 P-110 XP BTC 131,084 142.5 61.1 72 156 41 .27 6508.80 2951.57 2910.30 P-110 XP BTC 131,791 143.5 61.4 71 157 41 .25 6550.05 2910.30 2869.05 P-110 XP BTC(red 34) 132,498 144.4 61.8 70 158 41 .23 6591.28 2869.05 2827.82 P-110 XP BTC 133,204 145.3 62.2 69 159 41 .28 6632.56 2827.82 2786.54 P-110 XP BTC 133,911 146.2 62.6 68 160 41 .27 6673.83 2786.54 2745.27 P-110 XP BTC 134,618 147.1 63.0 67 161 41 .27 6715.10 2745.27 2704.00 P-110 XP BTC(red 35) 135,325 148.0 63.4 66 162 41 .55 6756.65 2704.00 2662.45 P-110 XP BTC 136,037 149.0 63.8 65 163 41 .28 6797.93 2662.45 2621.17 P-110 XP BTC 136,744 149.9 64.2 64 164 41 .92 6839.85 2621.17 2579.25 P-110 XP BTC 137,462 150.8 64.6 63 165 40.28 6880.13 2579.25 2538.97 P-110 XP BTC(red 36) 138,152 151.7 65.0 62 166 40.12 6920.25 2538.97 2498.85 P-110 XP BTC 138,839 152.6 65.4 61 167 40.92 6961.17 2498.85 2457.93 P-110 XP BTC 139,540 153.5 65.7 60 168 41 .38 7002.55 2457.93 2416.55 P-110 XP BTC 140,249 154.4 66.1 59 169 41 .20 7043.75 2416.55 2375.35 P-110 XP BTC(red 37) 140,954 155.3 66.5 58 170 41 .53 7085.28 2375.35 2333.82 P-110 XP BTC 141,666 156.2 66.9 57 171 41 .25 7126.53 2333.82 2292.57 P-110 XP BTC 142,372 157.2 67.3 56 172 41 .44 7167.97 2292.57 2251.13 P-110 XP BTC 143,082 158.1 67.7 55 173 41 .10 7209.07 2251.13 2210.03 P-110 XP BTC(red 38) 143,786 159.0 68.1 54 174 41 .24 7250.31 2210.03 2168.79 P-110 XP BTC 144,493 159.9 68.5 53 175 41 .85 7292.16 2168.79 2126.94 P-110 XP BTC 145,210 160.8 68.9 52 176 40.00 7332.16 2126.94 2086.94 P-110 XP BTC 145,895 161.7 69.3 51 177 41 .04 7373.20 2086.94 2045.90 P-110 XP BTC(red 39) 146,598 162.6 69.7 Joint Running Joint Depth BOUY FACTOR 0.86 Joint# Joint# Length Total Bottom Top REMARKS: Bouyant Capacity Displmt on rack in hole feet feet feet feet Run 87 Centralizers weight bbls bbls 50 178 41 .14 7414.34 2045.90 2004.76 P-110 XP BTC 147,303 163.5 70.0 49 179 41 .37 7455.71 2004.76 1963.39 P-110 XP BTC 148,011 164.5 70.4 48 180 40.03 7495.74 1963.39 1923.36 P-110 XP BTC 148,697 165.3 70.8 47 181 41 .23 7536.97 1923.36 1882.13 P-110 XP BTC(red 40) 149,403 166.3 71.2 46 182 41 .19 7578.16 1882.13 1840.94 P-110 XP BTC 150,109 167.2 71.6 45 183 41 .24 7619.40 1840.94 1799.70 P-110 XP BTC 150,815 168.1 72.0 44 184 41 .26 7660.66 1799.70 1758.44 P-110 XP BTC 151,522 169.0 72.4 43 185 41 .33 7701.99 1758.44 1717.11 P-110 XP BTC(red 41) 152,230 169.9 72.8 42 186 41 .82 7743.81 1717.11 1675.29 P-110 XP BTC 152,946 170.8 73.2 41 187 41 .24 7785.05 1675.29 1634.05 P-110 XP BTC 153,653 171.8 73.6 40 188 41 .20 7826.25 1634.05 1592.85 P-110 XP BTC 154,359 172.7 74.0 39 189 41 .24 7867.49 1592.85 1551.61 P-110 XP BTC(red 42) 155,065 173.6 74.4 38 190 41.23 7908.72 1551.61 1510.38 P-110 XP BTC 155,771 174.5 74.7 37 191 41 .22 7949.94 1510.38 1469.16 P-110 XP BTC 156,477 175.4 75.1 36 192 41 .05 7990.99 1469.16 1428.11 P-110 XP BTC 157,180 176.3 75.5 35 193 41 .35 8032.34 1428.11 1386.76 P-110 XP BTC(red 43) 157,889 177.2 75.9 34 194 41 .33 8073.67 1386.76 1345.43 P-110 XP BTC 158,597 178.2 76.3 33 195 41 .38 8115.05 1345.43 1304.05 P-110 XP BTC 159,306 179.1 76.7 32 196 41 .81 8156.86 1304.05 1262.24 P-110 XP BTC 160,022 180.0 77.1 31 197 41 .53 8198.39 1262.24 1220.71 P-110 XP BTC(red 44) 160,733 180.9 77.5 30 198 40.70 8239.09 1220.71 1180.01 P-110 XP BTC 161,430 181.8 77.9 29 199 40.22 8279.31 1180.01 1139.79 P-110 XP BTC 162,119 182.7 78.3 28 200 41 .50 8320.81 1139.79 1098.29 P-110 XP BTC 162,830 183.6 78.7 27 201 41 .20 8362.01 1098.29 1057.09 P-110 XP BTC(red 45) 163,536 184.6 79.0 26 202 41 .20 8403.21 1057.09 1015.89 P-110 XP BTC 164,242 185.5 79.4 25 203 41 .67 8444.88 1015.89 974.22 P-110 XP BTC 164,956 186.4 79.8 24 204 41 .17 8486.05 974.22 933.05 P-110 XP BTC 165,661 187.3 80.2 23 205 41 .28 8527.33 933.05 891.77 P-110 XP BTC(red 46) 166,368 188.2 80.6 22 206 41 .18 8568.51 891.77 850.59 P-110 XP BTC 167,073 189.1 81.0 21 207 41 .28 8609.79 850.59 809.31 P-110 XP BTC 167,780 190.1 81.4 20 208 41 .32 8651.11 809.31 767.99 P-110 XP BTC 168,488 191.0 81.8 19 209 41 .55 8692.66 767.99 726.44 P-110 XP BTC(red 47) 169,200 191.9 82.2 18 210 41 .08 8733.74 726.44 685.36 P-110 XP BTC 169,904 192.8 82.6 17 211 41 .50 8775.24 685.36 643.86 P-110 XP BTC 170,614 193.7 83.0 16 212 41 .30 8816.54 643.86 602.56 P-110 XP BTC 171,322 194.6 83.4 15 213 41 .95 8858.49 602.56 560.61 P-110 XP BTC(red 48) 172,041 195.6 83.8 14 214 40.35 8898.84 560.61 520.26 P-110 XP BTC 172,732 196.5 84.1 13 215 41 .40 8940.24 520.26 478.86 P-110 XP BTC 173,441 197.4 84.5 12 216 41 .35 8981.59 478.86 437.51 P-110 XP BTC 174,149 198.3 84.9 11 217 41 .95 9023.54 437.51 395.56 P-110 XP BTC(red 49) 174,868 199.2 85.3 10 218 41 .55 9065.09 395.56 354.01 P-110 XP BTC 175,580 200.2 85.7 9 219 41 .67 9106.76 354.01 312.34 P-110 XP BTC 176,293 201.1 86.1 8 220 42.05 9148.81 312.34 270.29 P-110 XP BTC 177,014 202.0 86.5 7 221 41 .20 9190.01 270.29 229.09 P-110 XP BTC(red 50) 177,719 202.9 86.9 6 222 41 .95 9231.96 229.09 187.14 P-110 XP BTC 178,438 203.9 87.3 5 223 41 .30 9273.26 187.14 145.84 P-110 XP BTC 179,145 204.8 87.7 4 224 41 .25 9314.51 145.84 104.59 P-110 XP BTC 179,852 205.7 88.1 3 225 41 .25 9355.76 104.59 63.34 P-110 XP BTC(red 51) 180,559 206.6 88.5 2 226 41 .30 9397.06 63.34 22.04 P-110 XP BTC 181,266 207.5 88.9 Joint Running Joint Depth BOUY FACTOR 0.86 Joint# Joint# Length Total Bottom Top REMARKS: Bouyant CapacityDisplmt on rack in hole feet feet feet feet Run 87 Centralizers weight bbls bbls 1 227 3.7-i 9400.77 22.04 18.33 Pup Joint 181,330 207.6 88.9 0.83 9401.60 18.33 17.50 Hanger 181,344 207.6 88.9 RKB 17.50 9419.10 17.50 0.00 RKB to Load shoulder 181,644 208.0 89.1 0.00 208.0 Extras 1 41 .30 2 41 .27 3 41 .54 4 41 .20 5 41 .92 6 41 .50 7 41 .30 _ 8 41 .33 9 41 .65 Joint Running Joint Depth BOUY FACTOR 0.86 Joint# Joint# Length Total Bottom Top REMARKS: Bouyant Capacity Displmt on rack in hole feet feet feet feet Run 87 Centralizers weight bbls bbls 10 41 .05 t3- ta1Co Landon Ellison Hilcorp Alaska, LLC 2." GeoTech 3800 Centerpoint Drive, Suite 100 ` 1. Anchorage, AK 99503 Tele: 907 777-8339 2"‘53 xslrf,rp Fax: 907 777-8510 21-{% E-mail: lellison@hilcorp.com DATA LOGGED A5/2014 M K BENDER DATE 04/15/14 APR 1 5 2014 Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician AOVIV�w CC 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 14A LWD MWD log data Schlumberger Prints: PTS SONICSCANNER MONOPOLE & DIPOLE CBL-VDL-GR-CCL 17-FEB-2014 USIT-GR-CCL 03-MAR-2014 AIT-TLD-CNL-GR combo CD: Final Well Data (4 discs) Disc 1: Wireline logs, Final report(pdf, las, dlis), USIT Disc 2: Wireline logs, Final report(pdf, las, dlis), Processed Sonic Disc 3: Wireline logs, Final report(pdf, las, dlis), CBL/VDL Disc 4: PEX: QUAD COMBO AIT-TLD-CNL-GR (pdf, las,dlis) Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: r ) &/44\61 l'i(N5104 2S3- \°1G II Landon Ellison Hilcorp Alaska, LLC 1-441, � GeoTech 3800 Centerpoint Drive, Suite 100 0 Anchorage, AK 99503 Tele: 907 777-8339 DATA LOGGED Ifuknrr:.1:1.11:.,.Ii.(, Fax: 907 777-8510 q AS/2014 E-mail: Jellison@hilcorp.com M K BENDER RECEiVED DATE 04/15/14 APR 1 5 2014 To: Alaska Oil & Gas Conservation Commission AOGVC Makana Bender �.,/l7IV Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 14A Elog data Halliburton Prints: ROP DGR EWR ALD CTN MD DGR EWR ALD CTN TVD XBAT Azim DGR EWR ALD CTN MD XBAT Azim DGR EWR ALD CTN TVD CD: Final Well Data Name Date modified Type CGM 2/612014 1:53 PM File folder DLIS+LAS 2/6120141:53 PM File folder EMF 216/2014 1:54 PM File folder PDF 2/6/2014 1:54 PM File folder TIFF 2:'6120141:55 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: 6.44441 il Date: Al I5 l4 z.\3- ter Landon Ellison Hilcorp Alaska, LLC 2." GeoTech 3800 Centerpoint Drive, Suite 100 �( Anchorage, AK 99503 Tele: 907 777-8339 1411 irae„cr MA, Fax: 907 777-8510 E-mail: lellison@hilcorp.com DATA LOGGED 4 11,55/2014 M K BENDER RECEIVED DATE 04/15/2014 APR 1 5 20'14 To: Alaska Oil & Gas Conservation Commission AOGCC Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 14A Mudlog data Prints: Final Well Report, DML Logging Data Formation Log 2in MD Formation Log 2in TVD LWD Combo Log 2in MD LWD Combo Log 2in TVD Gas Ratio Log 2in MD Gas Ratio Log 2in TVD Drilling Dynamics Log 2in MD Drilling Dynamics Log 2in TVD CD: Final Well Data DAILY REPORTS 2/18/2014 7:18 PM File folder DML DATA 2/18/2014 7:18 PM File folder FINAL WELL REPORT 2/18/2014 7:18 PM File folder LAS FILES 2/18/2014 7:18 PM File folder LOG PDFs 2/18/2014 7:18 PM File folder LOG TIFFs 2/18/2014 7:18 PM File folder SI-10W-Pixler Plots 2/18/2014 7:18 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: ty) Date: 41\4,44 w //// ks.� THE STATE F' ci Gil',• `t sirsf::=7;34;_-1_F 333 West Seventh Avenue GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 Main 907.279 1433 ®p F 7,E5�€` P,C 917 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 A,13 - I q6 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit 14A Sundry Number: 314-184 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 2`) day of March, 2014. Encl. a . ; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS . 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wel❑ Change Approved Program❑ Suspend❑ Plug Perforations 0• Perforate Q • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development E• 213-196 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20539-01 7.If perforating: 8.Well Name/ and Number. What Regulation or Conservation Order governs well spacing in this pool? / CO 237,CV I / 's, 1'` I Beaver Creek Unit(BCU)14A Wil planned perforations require a spacing exception? Yes b f,•+`4 No ,,- 1 9.Property Designation(Lease Number): 10.Field/P I(sy' v' FEDA028083 • Beaver Creek/Beluga Gas Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,450 8,870 9,335 8,756 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12,640 psi 11,080 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic n Development n Service n 14.Estimated Date for 15.Well Status after propsed work: Commencing Operations: 03/25/14 Oil ❑ Gas Q • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 3/24/2014 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Guy Schwartz(plugback only) GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-8412 Email soorhola( hilcorD.corrl Printed Name an Porhola Title Operations Engineer Signature %.! cs✓C_----- Phone 907-777-8412 Date 3/2-9//q /q COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. al1.-{-\•%1L{ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / - A(�erw r pl,`�.m.,,J- 71,,.......9 Zo ,44C-ZS'lIi(0) RBDMS9k MAY 10 2014 Spacing Exception Required? Yes [f'No ❑ S�jy��bsequent Form Required: /C - Yd .d.c., 7„A 7,oc,( ,/5-L) 3.2_5'i i / --->' APPROVED BY ") -Z S j I ---, Approved by / /' COMMISSIONER THE COMMISSION Date: .7-Z S41 � Submit Form and 1 Form 10-403(Revised 1 / 01 r! ' 1 Appro RuluiGi 114 { 7t monthsfrom the date of approveAttachmenDupscatte11uVV 1 /Ij t� ie zsi> ' 7' Well Prognosis(Rev 1) Well: BCU-14A Hilroru Alaska,LLC Date: 3/24/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: March 25th, 2014 Rig: N/A (E-line) Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824 (M) AFE Number: 1313435 Current Bottom Hole Pressure: — 3,255 psi @ 8,292'TVD (Based on well pressures after perforating the LB-30) Maximum Expected BHP: — 3,270 psi @ 8,140' TVD (Based on sample pressures from XPT pressures collected on 2/03/14) Max. Allowable Surface Pressure: — 2,456 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface.The initial zone(LB-30)was perforated and tested and showed poor performance. The purpose of this work/sundry is to plugback the existing sand and perforate a new lower Beluga sand. La-Zs e Notes Regarding Wellbore Condition • Last tag at 9,196' RKB on 2/27/14 w/a 4.53"Gauge Ring. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5"OTIS. b. SITP will be 2,600 to 2,900 psi. 2. RU 5-1/2"CIBP. 3. RIH and set CIBP at+/-8,865' MD. 4. RIH and dump bail 10'of cement on top of plug (est. 9.5 gallons). 5. RD E-line. Slickline Procedure: 6. MIRU Slickline, PT lubricator to 3,000 psi Hi 250 Low. c. Tree connection is 9.5"OTIS. d. SITP will be 2,600 to 2,900 psi. 7. RIH w/4.0" DD bailer and tag cement at+/-8,855' MD. 8. RD Slickline. E-line Procedure: 9. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 11 Well Prognosis(Rev 1) Well: BCU-14A Nikon)Alaska,LLC Date: 3/24/2014 e. Tree connection is 9.5"OTIS. f. SITP will be 2,600 to 2,900 psi. 10. RU 3-3/8"6 spf PJ Omega HC wireline guns (will use 3 each 16'guns). 11. RIH and perforate Lower Beluga (LB-28B) interval from 8,715'-8,731'(3 runs,total of 18 spf). ✓ g. Bleed tubing pressure to 2,390 psi before perforating. h. Proposed perfs shown on the proposed schematic in red font. i. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. j. Correlate using SLB Cement Bond Log dated 3/13/14(Tie-in log depth is 8,715'-8,731'). k. Use Gamma/CCL/to correlate. I. Record tubing pressures before and after each perforating run. 12. RD E-line. 13. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic Well Prognosis Well: BCU-14A Hilcorp Alaska,LLi Date:3/24/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: March 25th, 2014 Rig: N/A(E-line) Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: 1313435 Current Bottom Hole Pressure: — 3,255 psi @ 8,292' TVD (Based on well pressures after perforating the LB-30) Maximum Expected BHP: — 3,270 psi @ 810' TVD (Based on sample pressures from XPT ,1)')/k � pressures collected on 2/03/14) Max. Allowable Surface Pressure: —2,456 psi 1 (Based on actual reservoir conditions II 7', and gas gradient to surface (0.10psi/ft)) r Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in earl 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface.The initial zone (LB-30) was perforated and tested and showed poor performance. The purpose of this work/sundry is to plugb ck the existing sand and perforate a new lower Beluga sand. Notes Regarding Wellbore Condition • Last tag at 9,196' RKB on 2/27/14 w/a 4.53" Gauge Ring. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 2,300 to 2,500 psi. 2. RU 3-3/8" 6 spf PJ Omega HC wireline guns (will use 3 each 16'guns). 3. RIH and per7 rate Lower Beluga (LB-28B) interval from 8,715'-8,731' (3 runs,total of 18 spf). c. Pr posed perfs shown on the proposed schematic in red font. d. F hal Perfs tie-in sheet will be provided in the field for exact perf intervals. e. orrelate using SLB Cement Bond Log dated 3/13/14 (Tie-in log depth is 8,715'-8,731'). f. Use Gamma/CCL/to correlate. g. Record tubing pressures before and after each perforating run. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic , . s. _ :vim _ BC-14A ACTUAL Pad 1A SCHEMATIC Hilcon)Alaska,LLC 113' FSL, 1,388' FEL w "� Sec. 33, T7N, R10W, S.M. Conductor i4rfnit* '77771'3-196 '''' 20" K-55 133 ppf API#: 50-133-20539-01-00 Top Bottom Property Des: A-028083 MD 0' 145' KB Elevation: 159.6' (18.6'AGL) Y 1 ND 0' 145' Lat: N60° 38' 51.1588' Lonq: W151° 2' 45.491" Surface Casinq Spud Date: 01/24/14 13-3/8" K-55 68 ppf BTC Riq Released: 02/09/14 • Top Bottom I • MD 0' 2,122' ND 0' 2,122' 16"hole Cmt w/568 sks(254 bbl)of ,, 12.0 ppg,Class G cmt Tree cxn=9-1/2"Otis 8.0"Seal Diameter Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' .,,. ,. ND 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of 12.5 ppg Tail&510 sks(106 bbls)of 13.5 ppg Lead Class G cmt •. 4 Production Casing Swell Packer @ 5-1/2" P-110 20ppf XP BTC 4,857'4,879'MD Top Bottom MD 0' 9,419' A lit ND 0' 8,839' 8-1/2"hole Cmt w/972 sks(232 bbls) Max Dogleg: of 15.3 ppg,Class G cmt w/EASYBLOK 4.86°/100'@ 3,650' ',r ,F0 ..3 Casing/Cementing Detail Max Inclination: * - 9.6 ppg Mud 36.5°@ 3,713' ;' 0 - 12.5 ppg Mud Push(34 bbl) +t - 15.3 ppg Cement(232 bbl) '' ; - 8.4 ppg Lease Water(200 bbl) Short Marker Joints } @ 7,901'-7,916'MDi . @ 8,906'-8,921'MD , Perforations: Zone MD TVD Size SPF Date i +. LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 t. Fluid Level t', • 8.4 ppg Lease Water LB-30 = @ 9,000'CTM Tag(sticky)@ 9,196'SLM 14}};;�}?;!;} . w/4.53"GR(2/27/14) ','.7:41-",:41:::;)A •-* Casing Shoe @ 9,419' Openhole Casing 31'off bottom TD PBTD 9,450'MD 9,335'MD 8,870'ND 8,756'ND Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' I Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 3/17/2014 Schematic Revision Date: 3/21/2014 • ' BC-14A PROPOSED Pad 1A SCHEMATIC .,• _[ ffilcorp Alaska,LLC 113' FSL, 1,388' FEL ,�,�L� Sec. 33, T7N, R10W, S.M. Conductor Permit#:- 213-%6 20" K-55 133 ppf API#: 50-133-20539-01-00Top Bottom Property Des: A-028083MD 0' 145' KB Elevation: 159.6' (18.6'AGL) j ND 0' 145' Lat: N60° 38' 51.1588' !i Long: W151° 2' 45.491" f Surface Casing Spud Date: 01/24/14 II ' `r ', 13-318" K-55 68 ppf BTC Rig Released: 02/09/14 T� Bottom MD 0' 2,122' ND 0' 2,122' , 16"hole Cmt w/568 sks(254 bbl)of 12.0 ppg,Class G cmt l Tree cxn=9-1/2"Otis tlx 8.0"Seal Diameter � �, Intermediate Casing 5-1/8"Modified ID Bore 9-5/8" L-80 40 ppf BTC mToBottom MD 0' 5,081' TOC(3/03/14 USIT)-4,725' ND 0' 4,744' 12-1/4"hole Cmt w/377 sks(141 bbls)of • 12.5 ppg Tail&510 sks(106 bbls)of 13.5 1 ppg Lead Class G cmt S' • Production Casing Swell Packer41 5-1/2" P-110 20 ppf XP BTC 4,857'-4,879'MD 7 Top Bottom ' 41 MD 0' 9,419' • . ND 0' 8,839' A 8-1/2"hole Cmt w/972 sks(232 bbls) Max DO le of 15.3 ppg,Class G cmt w/EASYBLOK g g: 4.86°/100'@ 3,650' E 1 Casing/Cementing Detail Max Inclination: - 9.6 ppg Mud • 36.5°@ 3,713' - 12.5 ppg Mud Push(34 bbl) - 15.3 ppg Cement(232 bbl) Short Marker Joints - 8.4 ppg Lease Water(200 bbl) @ 7,90V-7,916'MD • @ 8,906'-8,921'MD Perforations: • Zone MD ND Size SPF Date LB-28B 8,716-8,731' 8,140'-8,156' 3-3/8" 18 Proposed LB-30 8,868'-8,882' 8,292'-8,306' 3-3/8" 12 3/17/14 Plug g 8,865'MD Capped w/10'of cement \ Fluid Level y Alii. 8.4 ppg Lease Water LB-30 = @ 9,000'CTM Tag(sticky)@ 9,196'SLM !>3}�,fly}}}jay} - w/4.53"GR(2/27/14) :;%f.,?•s'%•'•� 4 - ‘ Casing Shoe @ 9,419' Openhole Casing 31'off bottom TD PBTD 9,450'MD 9,335'MD 8,870'TVD 8,756'TVD Well Name&Number: Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A _ Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL):_ 141' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 3/21/2014 • ` �w��\\I%%%tea. THE STATE A. a� z:e C: i rC c;:;:,:i. e t fit#=_=- — — 333 West Seventh Avc nue �= CiOVI';1tN(�IZ SLAM PARNLI.1. Anchorage, Alaska 99501-3572 rY�3 Main 907 279 1 433 Stan Porhola Operations Engineer Hilcorp Alaska, LLC `q 3800 Centerpoint Drive, Suite 100 o`Z1 3` Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 14A Sundry Number: 314-095 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ," f.-- 4L' Cathy P. oerster Chair DATED this day of February, 2014. Encl. RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 20 2.0)`1,i APPLICATION FOR SUNDRY APPROVALS 2-124 << ' 20 MC 25.280 AOG�✓ 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate 0 • Pull Tubing Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Aker Casing❑ Other: Coiled Tubing Displacement0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q . 213-196 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service 1116.API Number. Anchorage,Alaska 99503 50-133-20539-01 . 7.If perforating: 8.Well Name and Number. /� What Regulation or Conservation Order governs well spacing in this pool? CO 237 ` r ❑ Beaver Creek Unit(BCU)14A. Will planned perforations require a spacing exception? Yes CI No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 • Beaver Creek/Beluga Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,450 8,870 9,335 8,756 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 144' 20" 144' 144' 3,060 psi 1,050 psi Surface 2,121' 13-3/8" 2,121' 2,121' 3,450 psi 1,950 psi Intermediate 5,081' 9-5/8" 5,081' 4,744' 5,750 psi 3,090 psi Production 9,450' 5-1/2" 9,450' 8,870' 12.640 psi 11,080P si Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;NIA 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: , Detailed Operations Program ❑ BOP Sketch n Exploratory ❑ Stratigraphic❑ Development n Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 02/24/14 Commencing Operations: Oil El Gas ❑✓ r WDSPL El Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email saorhola(cahilcorD.com Printed Name Stan Porhola _Title Operations Engineer Signature `__ ''"4— Phone 907-777-8412 Date 9---4 4fr/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ems®/ -3\1- - ©�S Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: vE 9 Soo p5; 3ii P s( RBDM MAY V 9 2014 Spacing Exception Required? Yes ❑ No L'J Subsequent Form Required: /0, Y 0 L/ V APPROVED BY Approved by: , /9 ' COMMISSIONER THE COMMISSION Date: ...2 2(,//� D Submit Form and �'''""�,Form 10-403(Revised 10/2012) Apio eRplIGal1 N,AL months from the date of approval. Attachments in Duplicate /,p- 1. ,;f„vVV ' ` 1 . Y ,. n Hilcorp Alaska, LLC RECEIFEB 2 0 2014 Post Office Box 244027 Anchorage,AK 99524-4027 AOGCC3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 Phone: 907/777-8412 February 19, 2014 Fax: 907/777 8301 Alaska Oil and Gas Conservation Commission 333 W.7th Ave., Ste. 100 Anchorage,Alaska 99501 Re: Beaver Creek Field BCU-14A (PTD 213-196) Request for Name Change and Application for Sundry Approval to Complete Dear Commissioner: This letter is to make a request to change the well name for BCU-14RD to BCU-14A. 4,y • This change is being requested to keep the same naming convention used on others �7� onshore fields such as the Swanson River Field where the 'A' would indicate the 1St , j sidetrack, a `B' would indicate the 2nd sidetrack. The naming convention using 'RD' is / more common on our offshore fields and we do not plan to continue using this naming Z' convention for our onshore wells, even though it has been used in the past (examples are BCU-3RD, SU 41-15RD, etc.). Attached is the final directional survey for this well, along with the proposed 10-403 Sundry request for the completion of this well using coiled tubing and E-line. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LLC Stan Porhola Operations Engineer stp Final Directional Survey 10-403 Form Well Prognosis Actual Well Schematic Proposed Well Schematic BOPE Schematic cc: Chad Helgeson Well Prognosis Well: BCU-14A Ililcorp Alaska,LL Date: 2/19/2014 Well Name: BCU-14A API Number: 50-133-20539-01 Current Status: New Sidetrack Leg: N/A Estimated Start Date: February 24th, 2014 Rig: N/A(Coil) Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 213-196 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: 1313435 Current Bottom Hole Pressure: — 0 psi @ 8,292' TVD (No perforations) Maximum Expected BHP: — 3,300 psi @ 8,292' TVD (Based on sample pressures from XPT pressures collected on 2/03/14) Max. Allowable Surface Pressure: —2,471 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#14A was drilled as a sidetrack in early 2014 to target the Sterling and lower Beluga gas sands. This well was completed as a 5-1/2" monobore to surface. The purpose of this work/sundry is to complete the well by displacing the well fluid with Nitrogen with coil tubing and perforate a lower Beluga sand. I� Notes Regarding Wellbore Condition C (31 • Last tag at 9,271' RKB on 2/12/14 w/a 3.50" Gauge Ring. Coiled Tubing Procedure: L-, S%05 1. MIRU Coiled Tubing, PT BOPE to 3,000 psi Hi 250 Low. a. Top tree connection is swab valve, 5-1/16" 5M FE. 2. RU 1.75" coil BHA w/jet nozzle. 3. RIH to 8,700' and displace 6% KCL with Nitrogen (est. 192 bbl). a. Leave some fluid across proposed perforated interval for perf guns. b. Leave approximately 2,700 psi on the tubing c. 100 psi fluid hydrostatic+2,700 psi N2 hydrostatic= 2,800 psi total hydrostatic = 500 psi underbalance for perforating. 4. POOH with 1.75" coil BHA w/jet nozzle. 5. RD Coiled Tubing. 6. Turn well over to production. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. 2. RU 3.5" 6 spf P1 Omega HC wireline guns (will use 2 each 14' guns). 3. RIH and perforate Lower Beluga (LB-30) interval from 8,86,882' (2 runs, total of 12 spf). b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. Well Prognosis Well: BCU-14A Ililcorp Alaska,LI, Date: 2/19/2014 d. Correlate using SLB Cement Bond Log dated 2/17/14 (Tie-in log depth is 8,868'-8,882'). e. Use Gamma/CCL/Neutron Tool to correlate. f. Record tubing pressures before and after each perforating run. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic z ' a ° I- o a0 3 mo c J ' °' a : I m v 04 0 U cip+ oo m co O N h et O N O\ N h h h h et h N 00 et 00 N O\ M h O\ h v) \O h 0\ O et '0 et O \0. 00 eC 0 O h \O et N O et v) h O\ .4 a1 O O\ M N .-1 O \O N O� h v1 v1 O\ S v) h Oet N et 00 \0v , 0 O O C O O c O O O O O N O O -. et O; -O N M N O0 vi 00 v d . -• N M v) \O \O h 00 D1 O- . M et \O h O\ N l �-' O in N 00 -. M in 00 h 0 h O1 .--• '0 O O M N h N \O O N 7 O et N 00 et 0`00 M N O M h O * -. 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O VN.CJ O M ,--- M h O N 0 �, O CV CV Vl t;,.- !00 O A y 0 V_l CV t` 0, Vl v O 0) CV M M 7 as O, Q\ 01 Q\ an on a en CV en 7 Vl ,O N M M M M en en en cc , . _ ._ int [ BC-14A ACTUAL Pad 1A SCHEMATIC Hilcorp Alaska,LLC 113' FSL, 1,388' FEL 1 Sec. 33, T7N, R10W, S.M. Conductor .213-196 -133-20539-01-00 l 20" K-55 133 ppf Top Bottom es: A-028083 MD 0' 144' on: 159' (18'AGL) TVD 0' 144' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface casing Spud Date: 01/24/14 , , 13-3/8" K-55 68 ppf BTC Rip Released: 02/09/14 Bottom 0 MD 0' 2,121' ' TVD 0' 2,121' 16"hole Cmt w/568 sks( bbl)of Tree cxn=6-1/2"Otis ,_at; 1 4-1 12.0 ppg,Class G cmt a ax p f�S, TOC(2/17/14 CBL)-4,766' A. /A f ) Intermediate Casing r 9-5/8" L-80 40 ppf BTC Top Bottom Directional Data: f MD 0' 5,081' KOP-2,200'at 1.3 deg/100'build r, a TVD 0' 4,744' EOB-4,178',28.1 deg hole angle ,, 12-1/4"hole Cmt w/377 sks(bbls)of Drop-4,240'@ 0.8 deg/100' e;'G e {� ' 12.5 ppg Tail&510 sks( bbls)of 13.5 Hold-8,550', 1.0 deg hole angle to TD ' ppg Lead Class G cmt Production Casing 5-1/2" P-110 20 ppf XP BTC Swell Packer @ 4,857'MD - f' Top Bottom ,:',i MD 0' 9,450' TVD 0' 8,870' 8-1/2"hole Cmt w/972 sks(232 bbls) Max Do le g: of 15.3 ppg,Class G cmt w/EASYBLOK 9 4.86°/100'@ 3,650' ,, r. ;l 4 V -1',--IV 1 .t ,I i F,` (f .s I . 1 TD PBTD 9,450'MD 9,335'MD 8,870'TVD 8,756'ND Well Name&Number:_ Beaver Creek Unit#14A Lease: A-028083 County or Parish:_ Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,081' Angle/Perfs: N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL):_ 141' RKB(above GL): 18' Revised By: Stan Porhola Downhole Revision Date: 2/6/2014 Schematic Revision Date! 2/19/2014 , H BC-14A PROPOSED Rad 1A Hilcorp Alaska,LLC 3' FSL, 1,388' FEL SCHEMATIC Permit#: 213-196 Sec. 33, T7N, R10W, S.M. Conductor API#: 50-133-20539-01-00 20" K-55 133 ppf Top Bottom Property Des: A-028083 ,. MD 0' 144' KB Elevation: 159' (18'AGL) .; ND 0' 144' Lat: N60° 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 01/24/14 ,t 13-3/8" K-55 68 ppf BTC Rig Released: 02/09/14 row Bottom MD 0' 2121' ND 0' 2,121' 16"hole Cmt wl 568 sks( bbl)of Tree cxn=6-1/2"Otis • 12.0 ppg,Class G cmt TOC(2/17/14 CBL)-4,766' Intermediate Casing 9-5/8" L-80 40 ppf BTC 1Top Bottom Directional Data: l+ MD 0' 5,081' KOP-2,200'at 1.3 deg/100'build ND 0' 4,744' EOB-4,178',28.1 deg hole angle 12-1/4"hole Cmt w/377 sks(bbls)of Drop-4,240'@ 0.8 deg/100' ,• . 12.5 ppg Tail&510 sks( bbls)of 13.5 Hold-8,550'0..0 deg hole angle to TD • + ppg Lead Class G cmt ,1 Production Casing _♦ ;x 5-1/2" P-110 20 ppf XP BTC Swell Packer @ 4,857'MD o.„., Top Bottom MD 0' 9,450' ND 0' 8,870' 8-1/2"hole Cmt w/972 sks(232 bbls) of 15.3 ppg,Class G cmt w/EASYBLOK i 1 iI i M Perforations: Zone MD TVD Size SPF Date LB-30 8,868'-8,882' 8,292'-8,306' 3-1/2" 6 Proposed ../r TD PBTD 9,450'MD 9,335'MD 8,870'TVD 8,756'TVD Well Name&Number:_ Beaver Creek Unit#14A Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: . 34°@ 5,081' I Angle/Perfs:_ N/A Maximum Deviation: 36.5°@ 3,713' Date Completed: 2/6/2014 Ground Level(above MSL): 141' RKB(above GL): 18' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 2/19/2014 . . Beaver Creek II BC #14A Proposed Coil BOPE Iliteorp tbs.'s.III. 2/19/2014 1111 Lubricator to injection head Il_ i IISlaMir co,..«, III 4 rl I■1 IMI 1: Davies, Stephen F (DOA) From: Stan Porhola [sporhola@hilcorp.com] Sent: Thursday, February 20, 2014 11:36 AM To: Davies, Stephen F (DOA) Subject: RE: BCU 09 and BCU 14 A Perforations Steve, Currently BCU-09 is on/off production in the Sterling Gas Pool: Other wells not on production but open to the Sterling Gas Pool: BCU-07 BCU-09 => BCU-07 is 5,250' ************************************************************************************ Currently BCU-14A is not on production (following sidetrack) but planned for producing in the Beluga Gas Pool: BCU-14A=> BCU-19 is 1,500' (closest well open to Beluga not producing but open in Beluga) / BCU-14A=> BCU-12 is 1,900' BCU-14A=> BCU-13 is 2,650' BCU-14A=> BCU-16RD is 2,600' BCU-14A=> BCU-18 is 5,000' Stan Porhola Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, February 20, 2014 11:04 AM To: Stan Porhola Subject: BCU 09 and BCU 14 A Perforations Stan, Two more wells for you: What is the distance from the planned perforation intervals in the BCU 09 and BCU 14A wells and perforations that are, or will be, open to the same gas pool in the closest wells? Thanks, Steve Davies AOGCC 907-793-1224 1 r Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Friday, February 21, 2014 12:24 PM To: Stan Porhola Subject: BCU 14A(PTD 213-196) Stan, I need to see the CBL log for BCU 14A before you perforate the BCU 14A.Also need a chart record of the IA being tested (30 min). I don't see these being done on any of the daily reports since the rig left. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 I ',Yr."2-;-, --::..1:----- -_:) i 2. ..,..)—IL .1_,Li,..) .\_,..,_,.' L‘ } 333 'v'es1 Seventh A5'cnue; "% p' '4- • GCV"} RNOR SF,SN P:\RNFF.1 [ Anchorage, Alaska 99501-3(72 V �r- 273 Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit(BCU) #14RD Hilcorp Alaska, LLC Permit No: 213-196 Surface Location: 113' FSL, 1388' FEL, SEC. 33, T7N, R1 OW, SM Bottomhole Location: 2150' FSL, 5124' FEL, SEC. 34, T7N, R10W, SM Dear Mr. Myers: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC 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 AOGCC 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, al-e Cathy P. oerster Chair DATED this /i �p d of January, 2014. RECEivhu STATE OF ALASKA Al :A OIL AND GAS CONSERVATION COMM. .ON OF C 16 2013 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone 0 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑✓ • Service-Supply 0 Multiple Zone ❑ Coalbed Gas 0 Gas Hydrates 0 Redril D• Reentry ❑ Exploratory 0 Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: D Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No.,.',Ly.i1 13`Z z(,)"3;Z'/�2 44 Beaver Creek Unit(BCU)#14RD . 3.Address: 6.Proposed Depth: 12 Field/Pool(s): 3800 Centerpoint Drive,Suite 100 Anchorage AK 99503 MD• 9,500' - TVD:8,876' • Beaver Creek 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga Gas Pool Surface. 113'FSL,1,388'FEL,Sec 33,T7N,R10W SM A-028083 • Top of Productive Horizon:2,022'FSL,5,255'FEL,Sec 34,T7N,R1 OW,SM 8.Land Use Permit: 13.Approximate Spud Date: N/A-Beaver Creek Unit 1/15/2014 Total Depth:2,150'FSL,5,124'FEL,Sec 34,T7N,R1OW,SM 9.Acres in Property: 14.Distance to Nearest Property: 2000 5,268' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation above MSL:159.6' feet 15.Distance to Nearest Well Open Surface: x-314368 • y-2430071.36 • Zor 4 GL Elevation above MSL:141' feet to Same Pool: 1,310' 16.Deviated wells: Kickoff depth: 5,100'MD feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 35.85 degrees Downhole: 3603psi • Surface: 2790psi • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 5 1/2 Production 20 P-110 DWC/C 9,500 Surface Surface 9,500 8,876' 1003 sx 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): 9361 8786 5,100' NA NA NA Casing Length Size Cement Volume MD TVD Conductor/Structural 147' 20" Driven 147' 147 Surface 2,124' 13 3/8" 568 sks 12.5 ppg Class G 2,124' 2,124' Intermediate 7594' 9 5/8" 887 sks 12.5-13.5ppg Class G 7,594' 7,023' Production 9,329' 3 1/2" 832 sks 15.8ppg Class G 9,329' 8,756' Liner Perforation Depth MD(ft):7,702'-7,712',7,763'-7,773',8,025'-8,035',8,148'•Perforation Depth TVD(ft):7,131-7,141, 7,191-7,201,7,453-7,463,7,576-7,586, 8,158',8,302'-8,312',8,424'-8,434',8,507'-8,517',8,556'-8,566 7,730-7,740, 7,852-7,862, 7,935-7,945,7,984-7,994 20. Attachments: Property Plat ❑✓ BOP Sketch Q Drilling Program ❑l Time v.Depth Plot ❑✓ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Email Printed Name Monty Myers Title Drilling Engineer Signature _ Phone 907-777-8431 Date lit/RfA3 Commission Use Only Permit to Drill C1 API Number: „ ,, Permit Approval See cover letter for other Number: 2( //c 50-/ 2 - 25_?.c,! ate: III(QI�1 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan gas hydrates,or gas contained in shales:[✓7 Other: �--/ „ - • Samples req'd: Yes❑ No 7 Mud log req'd:Yes❑ o[" dO� p� ,` � G ' 01 r H2S measures: Yes❑ o© Directional svy req'd:Yes['No❑ / y� — /J Spacing exception req'd: Yes[�No❑ Inclination-only svy req'd:Yes❑ No12 � U _ 62...,, [ en". Fes— ©p.�.- vy1-c. . I (j . ctS r) 1'•e 7.s.�-� APPROVED BY / / Approved# COMMISSIONER THE COMMISSION Date: / /�--/y' r - I-Z . 6/34thSubmit Form and 1 ,� Form 10-401(Revised 10/2012) This - t - d7O12 4s Ern the date of approval(20 AAC 25.005(g)) Attachments in Duplicate , ,, 11 Monty Myers Hilcorp Alaska, LLC Hilcorp Drilling Engineer P.O. Box 244027 c t Anchorage,AK 99524-4027 Bump Tel 907 777 8431 Email mmyers@hilcorp.com 12/16/13 /� Commissioner RECEIVED Alaska Oil &Gas Conservation Commission DEC 1 6 201 3 333 W.7th Avenue Anchorage,Alaska 99501 AOGCC Re: Beaver Creek Unit 14RD Dear Commissioner, Beaver Creek #14 RD is a sidetrack to replace the original BCU 14 lower Beluga production hole section with a new well. The asset team believes that the BCU 14 was compromised by a bad Excape completion which was the cause for lack of production from the well. The details of the directional '7, plan are not critical: our intent is to sidetrack the well to the NE and basically twin the original BCU 14 production hole.The new well will utilize the existing casing program down to 5100' MD. The base plan is a deviated wellbore reaching a maximum inclination of 35.6 deg and a 490'vertical separation at TD. Drilling operations are expected to commence approximately January 15th, 2014 with the Saxon Rig #169.This rig will be used to sidetrack the existing Beaver Creek#14 well, drill the new wellbore, run casing and cement. The Beluga formation will be perforated after the rig has moved off. 17 All waste& mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack. eneral sequence of operations pertaining to this approved drilling procedure: QD 1. MOB Saxon Rig#169 to well site. 2. N/U &test BOPE. 3. M/U 4-1/2" DP and 8-1/2" string mill and TIH to CIBP at' 5100'. POOH standing back DP. 4. Run and set whipstock,displace to drilling fluid at 9 ppg. Mill window and 20' of new formation. Conduct FITto)./2; e(S-- 5. Drill 8-1/2" production hole section to TD. POOH 6. Make wireline logging passes. 7. Run and cement 5-1/2" production casing. — 4-00- -it. "1,0°0/9"):.- 8. 1,0°0P").:8. TOOH, LDDP 9. Land tubing hanger. Set BPV. 10. N/D BOP, N/U tree, RDMO Hilcorp Alaska, LLC Page 1 of 2 A spacing exception is required for Beaver Creek Unit 14RD,Conservation order 237, Rule 3A and ✓ will be filed under separate cover. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 Hilcorp Alaska, LLC Beaver Creek 14RD Drilling Program Beaver Creek Reviewed by: � '� /Z . /Z. Za/7 r- Approved By: /21/3/20' Version 1 December 5th, 2013 Beaver Creek 14RD 11 Drilling Procedure Ililrorp Alu.+kv,LIA: Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program• 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 BOP N/U and Test 11 11.0 Mud Program and Density Selection Criteria 12 12.0 Whipstock Running Procedure 13 13.0 Whipstock Setting Procedure: 16 14.0 Drill 8-1/2"Hole Section 18 15.0 Run 5.5"Production Casing 21 16.0 Cement 5.5" Production Casing 24 17.0 RDMO 27 18.0 BOP Schematic 28 19.0 Wellhead Schematic 29 20.0 Days vs Depth 30 21.0 Geo-Prog 31 22.0 Anticipated Drilling Hazards 32 23.0 Rig Layout 33 24.0 FIT Procedure 34 25.0 Choke Manifold Schematic 35 26.0 Casing Design Information 36 27.0 8-1/2"Hole Section MASP 37 28.0 Plot(NAD 27)(Governmental Sections) 38 29.0 Surface Plat(As Built)(NAD 27) 39 30.0 Directional Program(P1) 40 Beaver Creek 14RD Drilling Procedure Il il•,,r1,:Ua.ka.LI,1: 1.0 Well Summary Well Beaver Creek#14RD Pad&Old Well Designation Sidetrack of existing well Beaver Creek 14 Planned Completion Type 5-1/2"20#P-110 Longstring Target Reservoir(s) Beluga • Planned Well TD,MD/TVD 9500' MD/8876'TVD PBTD,MD/TVD 9420' MD/8794'TVD Surface Location(Governmental) 113' FSL, 1388'FEL, Sec 33,T7N,R10W, S,AK • Surface Location(NAD 27) X=314368,Y=2430071 • Surface Location(NAD 83) Top of Productive Horizon (Governmental) 2022'FSL,5255'FEL, Sec 34, T7N, R10W, S,AK TPH Location(NAD 27) X=315809,Y=2431958 TPH Location(NAD 83) BHL(Governmental) 2150'FSL,5124'FEL,Sec 34,T7N,R10W,S,AK BHL(NAD 27) X=315943,Y=2432083 BHL(NAD 83) AFE Number 1313435 AFE Drilling Days 19 AFE Completion Days 3 AFE Drilling Amount $3.005 MM AFE Completion Amount $1.181 MM Work String 4-1/2" 16.6#S-135 CDS-40 RKB—GL 18.6' Ground Elevation 141' AMSL(geoprog) • BOP Equipment 11" 5M T3-Energy(Model 7082)Annular BOP 11" 5M T3-Energy(Model 6011i)Double Ram 11"5M T3-Energy(Model 6011i) Single Ram Page 2 Version 1 Dec,2013 Beaver Creek 14RD Drilling Procedure llilrara Alaska,11.1: 2.0 Management of Change Information H Hilcorp Alaska,LLC HiI Changes to Approved Permit to Drill Date: December 5".2013 Subject: Changes to Approved Permit to Drill for Beaver Creek#14RD File«: Beaver Creek#I4RD Drilling and Completion Program Any modifcationsto the Drilling&Completion Program will be documented and approved below. Changes to an approvedAPD will be communicated to theAOGCC&BLit. Date Procedure Change Approved Approved By By .=.pproval. Drilling Manager Date Prepared: Drilling Engineer Date L43o4r FS7ee=14.0 .:_ Page 3 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ilileorp Alaska,LU: 3.0 Tubular Program: Hole OD(in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD(in) (#/ft) (psi) (psi) (k-lbs) 8-1/2" 5-1/2" 4.778 4.653 6.050 20 - P-110 DWC/C 12410, 10670 443 4.0 Drill Pipe Information: Hole OD(in) ID(in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) w (psi) (psi) (k-lbs) 8-1/2" 4-1/2" 3.826 2-11/16" 5-1/4" 16.6 S-135 CDS-40 17693 16769 595k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ili enrp Alaska,UA: 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates i. Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com, mmyers(cihilcorp.com and jbarrett@hilcorp.com 5.3 5am Weekend Update i. Submit a short operations update each weekend and holiday to whoever is assigned weekend or vacation duty. Details will be sent before each weekend or holiday. ii. Copy pmazzolini@hilcorp.com, lkeller(a,hilcorp.com and mmyers@hilcorp.com 5.4 EHS Incident Reporting i. Notify EHS field coordinator. 1. This could be one of(3)individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston:0:(907)777-6726 C: (907)227-3189 b. Mark Tornai:0:(907)283-1372 C: (907)748-3299 c. Thad Eby: 0:(907)777-8317 C: (907)602-5178 2. Spills:Kate Kaufman: 0:907-777-8329 C:907-244-8292 ii. Notify Drlg Manager 1. Paul Mazzolini:0:907-777-8369 C:907-317-1275 iii. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally i. Send final"As-Run"Casing tally to mmyers@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report i. Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 1 Dec,2013 Beaver Creek 14RD II Drilling Procedure Meow!, tla.lea.LIT. 6.0 Planned Wellbore Schematic KB=159'(18' AGL) C SING DETAIL 'jjv1- t?°'1/5 Sue Type WV Grade/Conn 10 Toa BI- 20' Conducto- 133*/K-55/PE 15.73 Surf 147 13-3/5" Surface 6S#/K-55/BTC :2.42 Surf 9-5/B' Intermedote dolt/L-EO/BTC 5.535 Surf 7,5?4 A I y 5.1/2` Production 20e/P-110/DWCrC 4.775 Surf —9,500 OPEN MOLE/CEMENT DETAIL SOO 13-3/B` 16` hole, curbbt w1565 sks(334 s)12.5 ppg class G. Bumped plug floats held. 5.7.1.. t'( 9-5/5` 12-1/4' hole, ant w/667 sks(246 bbs)125 ppg lead and 135 ppg tail class G. e� Bumped plug,floats held. 5-1/2" Proposed to cement to inside window with 216 bbs cement(includes 20%excess o open hole volume) 1 4 "r I r CuN4TICN DETAIL 4\; t' KO P: 5100'MD/4759'TvD r✓19P SI" i Drop: 3.05/100' TT s t Mold: 22'from 5775'-7953'MD !Y!' fe#A Drop: 3.0!/100"to0!from 79S3'-B7WM- ., i ncwrnation at TO: 0! .9A:!muth: 30!to 5,500MD&45!to TD $ K A Y 1 4 1 ' v� ,* A 1. r + o.A. :Z` "j i 7D=93W7°'0=EBS VAX.0::A`1.E.36.5'g 371s Page 6 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Itileorp Alaska,LLC 7.0 Drilling Summary Beaver Creek#14 RD is a sidetrack to replace the original BCU 14 lower Beluga production hole section with a new well. The asset team believes that the BCU 14 was compromised by a bad Excape completion which was the cause for lack of production from the well. The details of the directional plan are not critical: our intent is to sidetrack the well to the NE and basically twin the original BCU 14 production hole.The new well will utilize the existing casing program down to 5100' MD. The base plan is a deviated wellbore reaching a maximum inclination of 35.6 deg and a 490' vertical separation at TD. Drilling operations are expected to commence approximately January 15th, 2014 with the Saxon Rig #169. This rig will be used to sidetrack the existing Beaver Creek#14 well, drill the new wellbore, run casing and cement. The Beluga formation will be perforated after the rig has moved off. • All waste &mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. A separate sundry notice will be submitted to cover P&A and wellborereparation or the sidetrack. �--3 ca.s:•D f->, Joc.. -pxsfa.Q ZooDe s General sequence of operations pertaining to this approved drilling procedure: 1. MOB Saxon Rig#169 to well site. _ 2. N/U&test BOPE. "Moo /o s s- oP 7 Gs 3. M/U 4-1/2"DP and 8-1/2"string mill and TIH to CIBP at 5100'. POOH standing back DP. 4. Run and set whipstock, displace to drilling fluid at 9 ppg. Mill window and 20' of new formation. Conduct FIT to . 1 Z 5. Drill 8-1/2"production hole section to TD. POOH 6. Make wireline logging passes. 7. Run and cement 5-1/2"production casing. TSI- Gcs. L(o° p5v 8. TOOH, LDDP 7;a1-. /A. Z Sao P S 9. Land tubing hanger. Set BPV. 10.N/D BOP,N/U tree, RDMO Page 7 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ilikorp Alaska,LLC 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2)week intervals during the drilling of Beaver Creek#14 RD. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4000 psi& subsequent tests of the BOP equipment will be to 250/4000 psi for 10/10 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components . utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. o No variance requests at this time. Page 8 Version 1 Dec,2013 Beaver Creek 14RD Drilling Procedure Ililcorp AIaKka, Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M 13-Energy Double Ram Initial Test:250/4000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: - • 2-1/16"x 5M Kill line 250/4000 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit. 5 station. 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running&cement operations. • Any other notifications required in APD. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Sal-'(S . Jim Regg/AOGCC Inspector/(0):907-793-1236/Email: 'im.re al.• a.l ov Guy Schwartz/Petroleum Engineer/(0):907-793-1226/(C):kt 07-276-7 42 Email:guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0):907-793-1247/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors 2iialaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone:907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Version 1 Dec,2013 Beaver Creek 14RD Drilling Procedure IIill•ori, kla.ka.1.1.1: 9.0 R/U and Preparatory Work 9.1 A separate sundry will be submitted that will include the following: • MIRU workover rig. • Set BPV,remove tree. • N/U and test BOP. • Pull existing production tubing. Plug back well with cmt. • Tag&pressure test cmt plug. • Run and set a CIBP at 5100' MD. • RDMO workover rig. L — "-rert 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Layout Herculite on pad to extend beyond footprint of rig. 9.4 R/U Saxon Rig#169, spot service company shacks, spot&R/U company man &toolpusher offices. 9.5 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.6 Mix mud for 8-1/2"hole section. 9.7 Set test Plug in wellhead prior to N/U BOP to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.8 Verify 5-1/2" liners installed in mud pumps. • HHF-1000 Pumps are rated at 3572 psi(100%) with 5-1/2" liners and can deliver 370 gpm at 120 spm. This will allow us to drill the 8-1/2"hole section with(1) mud pump. Page 10 Version 1 Dec, 2013 S Beaver Creek 14RD Drilling Procedure llikvrrp Ala.ka,hr.c 10.0 BOP N/U and Test 10.1 N/U 11"x 5M BOP as follows: • BOP configuration from Top down: 11"x 5M annular BOP/11"x 5M double ram/11"x 5M mud cross/11"x 5M single ram. • Double ram should be dressed with 2-7/8"x 5-1/2"VBR in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8"x 5-1/2"VBR. • N/U bell nipple, install flowline. 10.2 Run BOP test assy, land out test plug(if not installed previously). ✓ • Test BOP to 250/4000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! . • Test VBRs on 4-1/2" and 5-1/2"test joints. 10.3 R/D BOP test assy. 10.4 Continue mixing mud for 8-1/2"hole section. 10.5 Set wearbushing in wellhead. Ensure ID of wearbushing> 8-1/2". Page 11 Version 1 Dec,2013 Beaver Creek 14RD E4 Drilling Procedure Ililrorp Ala.ka,111; 11.0 Mud Program and Density Selection Criteria 11.1 8-1/2" Production hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system to (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6%KC1/PHPA fresh water based drilling fluid. Properties: MD Density / Viscosity Plastic Viscosity Yield Point pH HPHT 5100' —9500' 9-9.5 f 40-53 15-25 15-25 8.5-9.5 <_11.0 System Formulation: 6% KCI / EZ Mud DP Product Concentration Water 0.905 bbl Caustic 22 ppb (29K Chlorides) BARAZAN D+ 0.2 ppb (9 pH) EZ MUD DP 1.25 ppb (as required 18+YP) DEXTRID LT 0.75 ppb (initial .25 ppb) PAC-L 1-2 ppb BARACARB 5/25/50 1.0 ppb STEELSEAL 50/100/400 10 ppb (3.3 ppb each) BAROFIBER as directed BAROTROL PLUS as directed BAROID 41 as directed ALDACIDE G as required for 9.0-9.5 ppg BAROCOR 700 1 ppb BARASCAV D 0.5 ppb(maintain per dilution rate) 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be ✓ overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure flik»rp Na+ka.LLf 12.0 Whipstock Running Procedure 12.1 M/U window milling assembly and TIH w/4-1/2"DP off of pipe rack. • Use an 8-1/2"taper mill (or 8-1/2" mill tooth bit) and a 8-1/2" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (5100' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the#of joints picked up so we know where we are. 12.3 CBU &circ at least(1) hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.4 Displace to 9.0 ppg 6%KC1/PHPA fresh water based drilling fluid. 12.5 Pressure test casing to 3000 p i/30 min. Chart record casing test&keep track of the amount of fluid pumped. Stage up to 3000 psi in 500 psi increments. 12.6 TOH. 12.7 Make up mills on a joint of HWDP. 12.8 RIH & set in slips. 12.9 Make up float sub, install float. 12.10 Make up UBHO sub. 12.11 Orient UBHO to starter mill. 12.12 Leave assembly hanging in the elevators, and stand back on floor. 12.13 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.14 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws, Page 13 Version 1 Dec,2013 Beaver Creek 14RD 11 Drilling Procedure Iblenrp Alawka,GU; Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Note: Attach mills to Whipstock with (1)35k mill shear bolt 12.15 If needed, open BOP Blinds. 12.16 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.17 Release pick up system at this point, Make up mills. 12.18 With the top drive,pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up,the shear bolt then can be made up by the Baker Rep. 12.19 The assembly can now be picked up to ensure that the shear bolt is tight. 12.20 Remove the handling system. 12.21 Slowly run in the hole as per Baker Rep. run extremely slow through the BOP&wear bushing. 12.22 Run in hole at 1 V2 to 2 minutes per stand. 12.23 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.24 Call for Baker Rep. 15— 10 stands before getting to bottom. 12.25 Orient at least 30' —45' above the CIBP. Ensure to have gyro personnel and equipment as well as a wireline unit R/U and ready. Page 14 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ili •orp \Invkn.I.I.I. WindowMaster G2 System on TorqueMaster BTA 9 5/8"40#Csg—WindowMaster G2 On BTA BHA#1 Connection Length O.D. BOTTOM TRIP ANCHOR 4%2 IF-Box X Bottom Guide 3.42' 8.352" WINDOW MASTER WHIPSTOCK Shear Bolt X 4'A IF-Pin 18.54' 8.00" WINDOW MILL 4-1/2 Reg-Pin X Mill 1.3' 8.500" LOWER WATER MELON MILL 4-1/2 IF-Box X 4-1/2 Reg-Box 5.67' 8.375" FLEX JOINT 4-1/2 IF-Box X 4-1/2 IF-Pin 9.00' 6.375" UPPER WATER MELON MILL 4-1/2 IF-Box X 4-1/2 IF-Pin 6.17' 8.500" 1 JT HWDP 4-1/2 IF-Box X 4-1/2 IF-Pin 30' 6.50" MWD Survey Tool 4-1/2 IF-Box X 4-1/2 IF-Pin 6.50" UBHO 4-1/2 IF-Box X 4-1/2 IF-Pin 6.50" Bowen Lubricated 4-1/2 IF-Box X 4-1/2 IF-Pin 6.250" Bumper Jar 6 DRILL COLLARS 4-1/2 IF-Box X 4-1/2 IF-Pin 180' 6.75" 30 JTS—HWDP 4-1/2 IF-Box X 4-1/2 IF-Pin 900' 6.50" CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 15 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ililearp Alaska.I.U; 13.0 Whipstock Setting Procedure: 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. Run gyro survey to orient Whipstock face. 13.2 Orient Whipstock to desired direction by turning DP in 1/4 round increments. P/U and S/O on DP to work all torque out(Being careful not to set BTA). Whipstock Orientation Diagram: 30L 101 VP,Desired orientation of the Whipstock face is 10 to 30 degrees left of high side. Hole Angle at window interval (5100' MD) is < 34 deg. The wellbore trajectory is also . planned to the right of the existing wellbore. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9 ppg 6%KC1/P1-IPA drilling fluid (if not done previously). 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of Whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 16 Version 1 Dec, 2013 Beaver Creek 14RD 11 Drilling Procedure Ililrnrp Alawka, 13.10 Estimated metal cuttings volume from cutting window: 9-5/8"40# L-80 Cuttings Weight Window Length Casing Weight Min (lbs) Avg(lbs) Max(lbs) 17 40# 150 225 300 13.11 Drill approx. 20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in= MW out. 13.13 Conduct FIT to 12 ppg EMW. • (12—9) * 0.052 * 4760' tvd= 743 psi Note: Offset field test data predicts frac gradients at the 7"window to be between 13 ppg and 15 ppg. A ✓ 12 ppg FIT results in a 3 ppg kick margin while drilling the interval with a 9 ppg fluid density. 13.14 Slug pipe and POOH. Gauge Mills for wear. 13.15 Should a second run be required pick up the following BHA. Back Up Mills Connection Length O.D. WINDOW MILL 4 '/2 REG-P X MILL 1.30 8.50 NEW LOWER WATERMELON MILL 4 '/2 IF-B X 4 1/2 REG-B 5.67 8.50 FLEX JOINT 4 '/2 IF-B X 4 %IF-P 9.00 4.75 UPPER WATERMELON MILL 4 '/z' IF-B X 41" IF-P 6.17 8.50 FLOAT SUB 4 '/z' IF-B X 4 '/" IF-P 3.00 4.75 XO sub and 30 jts-HWDP 4 1/2" CDS40-B X 4 1/2" IF-P 900' 5.25 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY., Page 17 Version 1 Dec,2013 Beaver Creek 14RD Drilling Procedure llikorp Alaska,LLC 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2"directional drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift&caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.41 —0.51 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 275 - 350 gpm. 14.6 Motor AKO should be set at 1.2 deg. Must keep up with 3 deg/100 DLS in the build and drop sections of the wellbore. 14.7 Primary bit will be the Halliburton 8-1/2" FX55 PDC bit. Spec sheet attached on next page. Ensure to have a few mill tooth bits (IADC 117W) available on location. Page 18 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ilileorp Alaska.111: WALLIeURTON ;ma,- 8-1/2" (216mm) FX55 PRODL CT SPECIFICATIONS Cutter Type X3-Extreme Dnllmg IADC Code M424 rr ♦;`i. Body Type MATRIX Total Cutter Count 41 = Cutter Distribution 12Z1111 M1l m l m `may ik Face 0 26 k i w Gauge 5 5 Up Drill 5 0 Number of Large Norzlec 5 Number of Medium Nozzles 0 Number of Small Nozzles 0 Number of Micro Nozzles 0 Number of Potts(Size) 0 Numberof Replaceable Ports(Size) 0 4a0110 - Junk Slot Area(sq in) 12.76 Normalized Face Volume 37.06% Z API Connection 4-1/2 REG.PIN Recommended Make-Up Torque' 12.461—17.766 Ft•lbs. Nominal Dimensions•• t• Makc•Up Face to Nose 11.11 in•2112 mm Gauge Length 2 in•51 mm Slets e Length 0 in-0 mm Shank Diameter 6 in-152 mm Break Out Plate(Mat.aiLegacya) 111195444040 Approximate Shipping Weight I50Lbs.-6114 SPECIAL FEATURES Up-Drill Cutters on Gage Pads•I:32"Relieved Gage Material#687916 •nit specific recommended makeup torque is a function of the Fit I.D.and actual tut stab O.D.utitiaed is specified in API RP7G Section A.a.2. ••Design dimcmtons are nominal and may san shghtl)on manufactured product.Ilallibrttort Drill Hits and Seniors models are continuously reviewed and relined Product specifications may chance without notice C 2013 Halliburton.All rights reserved.Sales of I lalliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that as applicable to the sale. www.halliburton.com Page 19 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Iliirorp AlaKka,1.1.1 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Baker service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill (and LWD log) 8-1/2"hole to 9500' MD using above motor assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss <6. • Take MWD surveys every stand drilled. 14.11 Hilcorp Geologists will follow LWD log closely to determine exact TD. 14.12 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.13 TOH with drilling assy, handle BHA as appropriate. Page 20 Version 1 Dec,2013 Beaver Creek 14RD Drilling Procedure ❑ilrorp Aianka, 15.0 Run 5.5" Production Casing 15.1 R/U Weatherford 5.5" casing running equipment. • Ensure 5.5" DWC/C HT x 4-1/2" CDS-40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total# of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor &model info. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on &threadlocked (coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end &threadlocked(coupling also thread locked). • (1) Joint with landing collar bucked up. • Solid body centralizers will be pre-installed on shoe joint, FC joint, and LC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe & FC. 15.4 Continue running 5.5"production casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every other joint to window. Leave the centralizers free floating. • Install tandem rise bow springs every other joint thereafter to the window. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5.5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 15,100 ft-lbs 17,400 ft-lbs 19,800 ft-lbs Page 21 Version 1 Dec, 2013 Beaver Creek 14RD 11 Drilling Procedure llilrnrp Alaska,LIA: Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grads: OWCJC Casing 5-1/2 in 20.00bi#R(0.361 in) P-110 ztanCanC Material P•110 Grade 110.000 Minimum Yield Strength(psi) WISMONS/NSFU SA 125.000 Minimum Ultimate Strength(psi) vial USA 4424'A' Sam Houston Pkwy Suite'50 Pipe Dimensions Houston.TX 77041 5.500 Nominal Pipe Body 0.0.(in) Phone n11yi9 ssaa� 4.778 Nominal Pipe Body I.D.(in) >:-madvnr,tusA��rtt,{ vam.i r 0.361 Nominal Wall Thickness(in) 20.00 Nominal Weight(lbs./ft) 19.83 Plain End Weight(Ibsift) 5.828 Nominal Pipe Body Area(sq in) Pipe Body Performance Properties 641,000 Minimum Pipe Body Yield Strength(lbs) 11,100 Minimum Collapse Pressure(psi) 12,640 Minimum Internal Yield Pressure(psi) 11,600 Hydrostatic Test Pressure(psi) Connection Dimensions 6.050 Connection 0.0.(in) 4.778 Connection I.D.(in) 4.653 Connection Drift Diameter(in) 4.13 Make-up Loss(in) 5.828 Cntical Area(sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 641,000 Joint Strength(lbs) 22,890 Reference Strang Length(ft) 1A Design Factor 661,000 API Joint Strength(lbs) 641,000 Compression Rating(lbs) 11,100 API Collapse Pressure Rating(psi) 12,360 API Internal Pressure Resistance(psi) 91.7 Maximum Uniaxial Bend Rating[degrees100') • Appoximated Field End Torque Values 15,100 Minimum Final Torque(ft-lbs) 17,400 Maximum Final Torque(ft-lbs) 19,800 Connection Yield Torque(ft-lbs) For detailed information on performance properties.refer to DWC Connection Data Notes on following pagejs). Connection specifications within the control of VAM USA were cannot as of the date printed.SpecFcation%aro subinct to change without notice.Certain connection speotications are dependent on the mecharvcai properties of the pipe Mechanical properties of mill proprietary pipe grades were obtained from mill publications and are subject to change.Properties of mit proprietary grades should be confirmed with Me mil.Users are advised to obtain current connection specif cabdns and henry pee mechanical properties for each applicateon. Alt information is provided by VAM USA or its affiliates at users We risk.without liability for loss.damage or injury resulting from the use thereof:and on an'AS IS'basis without warranty re represemtabon of any kind.whether express or implied,including without limitation any warranty of merchantability,fitness for purpose or completeness.This decurrent and its contents are subject to change without notice.In no Page 22 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ililrnrp Alaska,LU: 15.7 Run in hole w/ 5-1/2" casing. 15.8 Fill the casing with fill up line and break circulation every 1,500 feet to the window or as the hole dictates. 15.9 Obtain slack off weight,PU weight, rotating weight and torque of the casing. 15.10 Circulate 2X bottoms up at window, ease casing thru window. 15.11 Continue to RIH w/casing no faster than 1 jt /minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 Set casing slowly in and out of slips. 15.13 Swedge up and wash last 5 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 15.14 Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.15 Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 23 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure ;Ivor!) Un.ka.1.1,1'. 16.0 Cement 5.5" Production Casing 16.1 Hold a pre-job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 10 bbls 12.5 ppg MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 25 bbls npg MUDPUSH II spacer. 16.6 Mix and pump 241 bbls of 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 20% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to give 500' of cement inside window in annulus between 9-5/8" casing and 5-1/2"casing. Cement Calculations 9-5/8"Casing x 5-1/2"Ann: 500' x 0.0464= 23.2 bbls 8-1/2"off x 5-1/2"Ami+ (9500' —5100')x .0408 x 1.2 = 215.4 bbls 20%excess Shoe Track: 120' x 0.02218 = 2.6 bbl Total Volume(bbls): 23.2 +215.4+2.6 = 241.2 bbls Total Volume(ft3): 241.2 bbls x 5.615 ft3/bbl = 1354 ft3 Total Volume(sx): 1354 ft3 / 1.35 ft3/sk= 0 sx Te) '� �-(SdD a M 17 Page 24 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ililrorp Alaska,LLC Slurry Information: System Easy BLOK Density 15.3 lb/gal ' Yield 1.34 ft3/sk • Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF / 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2% BWOC Additives D202 Dispersant 1.5% BWOC D400 Gas Control Agent 0.8%BWOC D154 Extender 8.0%BWOC 16.7 Drop wiper plug and displace with produced water. 16.8 If hole conditions allow—continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100%coverage around the pipe. 16.9 If elevated displacement pressures are encountered,position casing at setting depth and cease 0 V • reciprocation. Monitor returns&pressure closely while circulating. Notify Drilling Foreman immediately of any changes. ,v cd? 16.10 Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 10 Ot v minutes. elegy 16.11 Do not overdisplace by more than %2 shoe track. Shoe track volume is 2.6 bbls. 16.12 Bleed pressure to zero to check float equipment. Watch for flow.Note amount of fluid returned '�,l►� after bumping plug and releasing pressure. t 16.13 RD cementers and flush equipment. it, Page 25 Version 1 Dec,2013 Beaver Creek 14RD II Drilling Procedure IIileorp AlaKka,1.1.1; Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume, whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Note: Send Csg & crnt report + "As-Run"liner tally to mmvers(ahilcorp.corn Page 26 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ilileorp Alaska,LIA: 17.0 RDMO 17.1 Install BPV in wellhead. RILDs. 17.2 N/D BOP. 17.3 N/U temp abandonment cap. 17.4 RDMO Saxon Rig#169. Page 27 Version 1 Dec, 2013 Beaver Creek 14RD II Drilling Procedure Il ilinrp Alaska,1.1A: 18.0 BOP Schematic k1 c at rfti rffi It rfi Yal 3.;,. 24 5r��`Dtl Model 6011i `67 41 1 t"-St1DE1 . rf31 rfti rf tl iftr 3. _ ^0' alt 1 1 1 3 Enemy lip tU Model 11"5000. ..... j*.. til 111111 III Itl i 2.00' I 1111 14.. ..7.4. " • ,I 161.1111.11111111-1111 2 1,/16 IM K,II Side " 41.1"5 1/S 5M Choke Side 1:1' ...tom 11 T3 so�del li mu_ Ill 111 111 III 111 iiiiiit Grade NW 1 iii t!l Iii It1 lit t .4, :-.:740„1„, .• ,,,,c5D 0 .., $T.,,, .,5 1,3 E III, lire ,f, 11, _- wail laillili IE JP' �1 11141-81/1 2c)" Page 28 Version 1 Dec, 2013 Beaver Creek 14RD II Drilling Procedure llileorp Alaska.IAA: 19.0 Wellhead Schematic Beaver Creek Tubing hanger,CBS,11 X 511 BCg 14 LTC lift X5'A TC-2 susp,w/ 20 X 13 3/8 X 9 5/8 X 511 5"Type H BPV profile,2-3/8 CCI,Alloy material Tree cap,OtIs,5 1/8 10M FE X 9:IOUs Quick Union 3 i Valve,Swab,CIW-FC, �A • s�4t ' 04 , tTFO~ 5 1/8 IOM FE,HWO #ELi , ,,'• 40' <, %.1„._ JT P • ., Valve,Upper Master, • C' CIW-FC,5 1/8 lOM FE,HWO, O A,.Vl. * ,\Y/�(7 BB trim U , J P- Is�m,,.'I t •i V Valve,Master,CIW-FC, 5 1/8 10M FE,H WO, O •e,, BB trim P lib lit is 1 X2 � Control lines 1:,1.,_, ...Ir.—, ...,_•• Completion spool,Cactus, -.41".11 T fEi aT��l r 13 5/8 SM X11 SM Isi '•'' 1#I . i u r 13l5/8 ti° 'PX3M bottom 13 5/8 5M FE top,w/ Valve,VG-200,2 1/16 SM FE, 2-21/16 SM SSO (� 1(lt 1 HWO,AA trim 01 ill w Starting head, INC Vetco MB-196, � riteilli , 13 5/8 3M X 13 3/8 VG-Loc _ — bottom,w/2-2"LPO 1a I� I 20/8" . " 5 Y," Page 29 Version 1 Dec, 2013 Beaver Creek 14RD fl Drilling Procedure Ilileorp 1.1.1: 20.0 Days vs Depth Days Vs Depth 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 0 5 10 15 20 25 Days Page 30 Version 1 Dec,2013 Beaver Creek 14RD 11 Drilling Procedure Ilikorp AtaAka,fit 21.0 Geo-Prog GEOLOGICAL PROGNOSIS t WELL NAME BCU I4RD (ST out ofBCU 14) FIELD: Beaver Creek SURFACE X=314378.1 LONG: 151.0343i (BCU 14 Well) STATE: Alaska Y=2430061.9 LAT:60.6475188 BOTTOMhuLE 'X=315886.7 LONG: -151.0260765 TVD REF DATUM KB _ Y=2432083.9 'LAT 60.6531 141 TVD REF ELEV 159 18'KB(Saxon 169) - COORD REF. SYSTEM NAD27 GROUND ELEV 141 - PROPOSED TD 9,500'MD/8,8 76'TVD. KOP=5,100'MD , Objective: Lower Beluga 618-B32 gas sands • j l I I Geo Summary/ Justification: The goal of the BCU 14 RD sidetrack is to replace the original BCU 14 lower Beluga production hole section with a new well. The asset team believes thatthe BCU 14 was compromised by a bad Excape completion , which was the cause for lack of production from the well. The details of the directional plan are not critical: our intent is to sidetrack the well to the NE and basically twin the original BCU 14 production hole section ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Critical Intersection Points TOP TOP NAME FORMATION FLUID TVD(FT) TVDSS(FT) Est.Pressure X Y +1- MD KOP Sterling water 4.760 -4,601 1900-2300 psi 5100 B1 Sterling water 4,911 -4,752 1900-2300 psi 315051.2 2431250.9 10 5285 B3 Sterling water/gas 5.076 -4,917 1900-2300 psi 315127.3 2431344.2 10 5489 B4 Sterling water/gas 5,272 -5,113 1900-2300 psi 315224.4 2431441.3 10 5730 B18 Beluga gas 7,253 -7,094 1000-3300 psi 315724.8 2431923.4 30 7861 B20 Beluga gas 7,418 -7,259 1000-3400 psi 315740.9 2431939.5 30 8027 B23 Beluga gas 7,685 -7,526 1000-3500 psi 315767.8 2431966.4 30 8297 B27 Beluga E gas 7,913 -7,754 3000-3600 psi 315789.3 2431988.0 30 8528 B28B Beluga gas 8,127 -7,968 3000-3600 psi 315810.9 2432009.5 30 8744 B31 Beluga !1 gas • 8,344 -8,185 3000-3600 psi 315832.4 2432031.0 30 8962 TD 8,876 -8,717See BHL above 9500 =Primary Objective =Secondary Objective TARGET RADIUS 100 ft 1 I DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of4 on for production hole section. LWD Data: GR for Production Hole section E-Line Log Data: Open Hole Quad Combo COMPLETION TYPE Gas lift completion ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD ...................... TUBING SIZE 2-7/8" OTHER COMMENTS 1. The KOP of 5,100'was selected to encounter the Sterling B sand gas shows seen in the original BCU 14 well' • 2. BCU 14 never produced gas from either the Sterling or Lower Beluga 3. We do not anticipate crossing any significant faults that would pose drilling problems. 1i 4. BCU 14 drilled with 9.5 ppg mud through the Sterling and 9.3-9.9 ppg mud through the lower Beluga i -74- Page 31 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure !Warp Alaska,LLE 22.0 Anticipated Drilling Hazards Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal(Angular, dual-composition carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 32 Version 1 Dec,2013 Beaver Creek 14RD 11 Drilling Procedure Ilileorp Alaska,GIA; 23.0 Rig Layout .. ., FCF T.999 in kil II . ,� um.� — Ilii 111 II meow r. IIi�i. _ III EE ET Y VI ��s 1111 i i_•, - ® 1, •.HatF M\ i '__ '_—spa �r�i .A9 iL I iS i �IB_�i��i.nt�� _+ ....--. ...,,-4111..i...-a. LIZJj1! IE i�f; Et a,�EZ r.r.,-U = i t a... r11111111t1111 llll - - al ._�..._.. L',41—.1 r r r II ,-�I '-11== til ' , � [ dill ininininuuuut f Taxui IL'r. v utai IPF i , — J I �ram ra, rT tit p Ee� acv ..... 11 a ....Ai x- ill1 y-rv� nr T'�'vrrxaN ! ! 'SE MO Page 33 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Ilileorp Alaska,LIR: - 24.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20'of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 34 Version 1 Dec,2013 Beaver Creek l4RD II Drilling Procedure Ilileorp Alaska,UA 25.0 Choke Manifold Schematic .,- j.,,, 67.24 43.62 I 43.62 ■1r-1r,0 ®..,7.7 ,0.43 -14.62 " '4162 18.43- _Vr,AI►y .. -0.19 -0.19 ol f Q'. '-019 0.19-- so'', 0' 1 a�� 1. �wMl .. ,' r0 9mi� 0,9-'S i Qt9 `�- 4>,,,e,i 9 70 I f r>, �_,1-� iP ttI _ "'�" u I G .;; I .., I , -�'- ] , 9.00 I_ 1k'='-64-I ' ' I 0.19.1 -- e C nlr'Ir1.1 0.19-1 e� a -a 0.19-1 7.64 00 ©' 9.154 e ill 7.64 Ii o19 fatMC.si '1 1 I I I (1, MIMEO I ( -- 0.19-1 _�0.19J 3n03 4 1•I u 0 ti.''• 14.62 .4 • 'r`)- ,f.62 i� � ,A)�/L-:.�� 1. 16.62 �,►A Ir0.,9 ! ©. oth ,.11 Lliii i I ,. . A't„ 0.,9 ,a6o ; �`�' - ,ate � i-;,-..,3414,kktil �twkAki //�� I �� l, �+cf:»��Y- � ' 1 �� !' � it ....,./1 .f N,ot�u:�Ya ail` NOM1 1.'.1 ,.'.,-0.19 VIP 112 CHOKE 0 o., -0.19 19 - 11A1111.14.A11A1111.14.0.I 0.19-- - -0.194+ -131 -14.62 -14.62 -14.62 14.62 -0.31 Ppj..N 43.62 4162 P!'r eve; 67.24 /''1.Kt' CAD -40-c3- •� .lx.r.0 1.LM J7 rant a CASKE1 G o0 4.r riga I� w.�`..'.. Le- J� ....:-..;:,,,,,....-....;• SZYf1 Ota_. -✓ O .A . ORM.14 N M-93 4.T _ �1 YYY - __ -21MM11-11-00 Page 35 Version 1 Dec, 2013 Beaver Creek 14RD Drilling Procedure Il ilrorp Ala.ka.IIA: 26.0 Casing Design Information Calculation &Casing Design Factors Swanson River Unit DATE: 12111/2013 WELL:Beaver Creek#14RD FIELD:Beaver Creek DESIGN BY:Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 8-112' Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 2790 psi(See attached MASP determination&calculation) Production Mode MASP: 2790 psi(See attached MASP determination&calculation) Collapse Calculation: Section Calculation 1,2 Normal gradient external stress(0.406 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 5-112' Top(MD) 0 Top(TVD) 0 Bottom(MD) 9.500 Bottom(TVD) 8,876 Length 9.500 Weight(ppf) 20 Grade P110 Connection DWC/C Weight ve o Bouyancy Factor(lbs) 190,000 Tension at Top of Section(lbs) 190,000 Min strength Tension(1000 lbs) 641 Worst Case Safety Factor(Tension) 3.37 Collapse Pressure at bottom(Psi) 3.604 Collapse Resistance w/o tension(Psi) 11,100 Worst Case Safety Factor(Collapse) 3.08 MASP(psi) 2.790 Minimum Yield(psi) 12.640 Worst case safety factor(Burst) 4.53 Page 36 Version 1 Dec, 2013 Beaver Creek 14RD II Drilling Procedure Ilileorp U:14.a.1,1.1; 27.0 8-1/2" Hole Section MASP El Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section el Jcorp Beaver Creek 414 RD Kenai,Alaska MD TVD Planned Top: 5100' 4760' Planned TO: 9500' 8876' Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Top Sterling Fm 4,760 2300 Water 9.3 0.4.83 Sterling 81 4,911 2300 Water 9.0 0.468 Sterling B3 5,076 2300 Gas/Water 8.7 0.453 Sterling 84 5,272 2300 Gas/Water 8.4 0.436 Top Beluga 818 7,253 3300 Gas 8.7 0.455 Beluga 820 7,418 3400 Gas 8.8 0.458 Beluga B23 7,685 3500 Gas 8.8 0.455 Beluga B27 7,913 3600 Gas 8.7 0.455 Beluga 8288 8,127 3600 Gas 8.5 0.443 Beluga 31 8,344 3600 Gas 8.3 0.431 Total Depth 8,876 3600 Gas 7.8 0.406 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date Beaver Creek 1A 8.5-9.6 ppg 215 8,854 1967 Beaver Creek 11 8.8-9.6 ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4 ppg 0 10,182 2003 Beaver Creek 14 8.7-9.8 ppg 145 8,789 2004 Assumptions: 1. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 2. Calculations assume reservoirs contain 100%gas(worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anticipated fracture gradient at 5100'TVD= 15.5 ppg EMW Fracture Pressure at 8-1/2"window considering a full column of gas from window to surface: 4759(ft)x 0.65(psi/ft) 3093 psi 3093(psi)-10.1(psi/ft)'4759(ft))= 2617 psi MASP from pore pressure;entire wellbore evacuated to gas from TD 8876(ft)x 0.406(psi/ft)= 3603 psi 3603(psi)-10.1(psi/ft)'8127(ft)1= 2790 psi ►/ Summary: 1. MASP while drilling 8-1/2"production hole is governed by SIBHP minus entire wellbore evacuated to gas from T0. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TD. Page 37 Version 1 Dec, 2013 Beaver Creek 14RD II Drilling Procedure tlileurp Alaska,IAA; 28.0 Plot (NAD 27) (Governmental Sections) f Legend ,.i _A.oU.f.,8,,,.' ii • BCU 14-RD SHL •••t--,,a _--ecu12.!1*- ' BCU 14-RD Top Beluga �' ,' 'if. % .' BCU 04 Bit, 17 `� 41 BCU 14-RD BHL • 'r lr r\ . r t Other Surface Well Locations �'�, i7t ``< ®' I I 'y Other Bottom Hole Locations j 1 �\ / r Well Paths 7 ;*"'' � r LSE Oil and Gas Unit Boundary / ` BCU 13 BHC ` • r r BCU 19 BHL' r co A028083 Ere BCU 09 BM,/ BCU S007N010W BCU 14 BHtr. ,'`""--.., 14-RD • Bill. ACV tf SVC BCU' 14-RD �. BCU.,QIABHL- BEAVER !'.•EEK UNIT -•— BCU I4-RD SHL BHL+ /--' BCU 15 BCU 02 BH'_ BCU 7RD B Prap 3s BCU O1RO,P54/ync.B+ ,x S006N010W 4 _, ---::" _ _. - --' 0 8118 ACU 07 AHl%a"`""-� a 1 II n tpC✓J 2.090 Beaver Creek Unit Feet BCU 14-R D Alaska State Plane Zona 4,NA027 tilt..*AWL*.lit. Map Date.12552013 Page 38 Version 1 Dec, 2013 Beaver Creek 14RD II Drilling Procedure Ililrorp AIai<ka,I.IA; 29.0 Surface Plat (As Built) (NAD 27) SECTION 33 .../ e gfr ....,.. • .. .. .,. .J �, art L...„ 1 "•H..~ `.•", BCU NO.to WELL r,r... . '�/�•••c., 14 8'DIA.WELL HOUSE _o ° ,,_,.».~ N=2430086.36 1 /�^� °."..« •««00E=314428.19 ®■ ELEV=1412 AS STAKED 1388'FEL O O 0 i PAD 1 A - BEAVER CREEK NO.14 GRID N:2430071.363 - ° GRID E:314368.188 • LATITUDE:60.38'51.159*N $ T7N R10W SM AK LONGITUDE: 114 OE:-15t°Oro3.7o,-w 33 34 T6N x 4 3 // ````NN V`\1 1 wr urrn • c . ; ',4-�i 4I SURVEY NOTES -*' rI%\ *'/ i.BASIS OF HIS U'D ORITONTAL COORDINATES NOS STATION ARY,NAD27 �" . ALASKA STATE P.M1C TONE 4, / oti 2.BASIS OF VERTICAL CON TRCt IS NGS MONUMENT Oft(MVO M) 40 J.OFFSETS TO SECTION LINE DETERMINED FROM TIES TO RIM SECTION / CORNERS FOUND ALONG TIC SOUTH BOUNDARY OF THE TOWNSHIP FOUND , M.SCOTT McLANE & - THIS SURVEY e/�s1, '•. 4928-S .•9T SCALE 1"=100' "�o 0 100 200 'a1 ESSIONA�N 4 I. 1 I I I 1``� ‘‘‘‘�`` ` FEET Page 39 Version 1 Dec. 2013 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 14 PTD 204-086 BCU-14RD Plan: BCU-14RD WP1.0 Sperry Drilling Services Proposal Report 03 December, 2013 Well Coordinates: 2,430,071.36 N,314,368.19 E (60°38'51.16"N,151°02'03.70"W) Ground Level: 141.00 usft Local Coordinate Origin: Centered on Well Beaver CK Unit 14 Viewing Datum: BCU 14rd plan @ 159.00usft TVDs to System: N North Reference: True Unit System: Revised US-Survey Feet_nr Version: 5000.1 Build: 70 HALLIBURTON 3600- HALLIBURTt I Hilcorp Sperry Drilling 3900- WELL DETAILS: Beaver CK Unit 14 Ground Level: 141.00 4200- +NI-S +E/-W Northing Easting Latittude Longitude Slot - 0.00 0.00 2430071.36 314368.19 60.6475441 -151.0343614 4500- KOP 9-5/8"CSG;Start Dir 12°/100':5100'MD,4759.57'TVD:65°RT T 4800- -----_ Start Dir 3°/100':5120'MD,4775.96'TVD B3__ 5100 64, 5400- -- SURVEY PROGRAM End Dir :5777.94'MD,5337.04'TVD Date:2013-12-03T00:00:00 Validated:Yes Version: 5700- Depth From Depth To Survey/Plan Tool 161.00 5100.00 BCU 14(BCU 14) MWD+SC+sag 5100.00 5400.00 BCU-14RD WP1.0(BCU-14RD) MWD Interp Azi 5400.00 9500.08 BCU-14RD WP1.0(BCU-14RD) MWD+SC+sag 6000- C - Hilcorp Energy Company re 6300- Calculation Method: Minimum Curvature • - Error System: ISCWSA CO - Scan Method: Closest Approach 3D Error Surface: Elliptical Conic Q6600 Warning Method: Error Ratio N 0Tri - FORMATION TOP DETAILS N 6900- > - TVDPath MDPath Formation 9 5/8" - 4911.00 5286.03 B 1 - 2 - 5076.00 5485.18 B3 - 5272.00 5707.02 64 ▪7200- 7253.00 7850.54 618 - 7418.00 8028.43 B20 __ --- - 7685.00 8306.42 623 618 - - 7913.00 8537.00 627 ----___ - 8127.00 8751.20 B28B Start Dir 3°/100':7952.91'MD,7347.64'TVD 7500- 8344.00 8968.20 B31 B20 CASING DETAILS _ --- 7800- B23" TVD MD Name Size 8875,80 9500.00 3 1/2" 3-1/2 -- 627 End Dir :8700.2'MD,8076'TVD 8100- ------ Project: Beaver Creek Unit B286- - Site: Beaver Creek Unit 8400 Well: Beaver CK Unit 14 ---- Wellbore: BCU-14RD 631 BCU-14RD WP1.0 8700- REFERENCE INFORMATION -- 3 1/2" Co-ordinate(N/E)Reference: Well Beaver CK Unit 14,True North ----BCU 14 Vertical(ND)Reference: BCU 14rd plan @ 159.O0usft 3 1/2"--- _- Total Depth:9500.2'MD,8876'TVD Measured Depth Reference: BCU 14rd plan @ 159.00usft 9000- Calculation Method: Minimum Curvature BCU-14RD WP1.0 BCU 14RD BHL TGT rev1 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 9300- 1 5100.00 34.47 30.46 4759.57 1100.92 606.57 0.00 0.00 25.15 - 2 5120.00 35.54 34.21 4775.96 1110.60 612.71 12.00 65.00 24.68 - 3 5330.00 35.85 45.00 4946.67 1204.66 690.59 3.00 91.58 4.27 - 4 5777.94 22.42 45.76 5337.04 1357.71 845.25 3.00 178.75 -53.15 5 7952.91 22.42 45.76 7347.64 1936.37 1439.53 0.00 0.00 -278.48 9600- 6 8700.20 0.00 45.00 8076.00 2037.07 1542.95 3.00 180.00 -317.70 7 9500.20 0.00 45.00 8876.00 2037.07 1542.95 0.00 0.00 -317.70 BCU 14RD BHL TGT rev1 -3000 -2700 -2400 -2100 -1800 -1500 -1200 -900 -600 -300 0 300 600 900 1200 1500 Vertical Section at 300.00°(600 usft/in) .8 0 _ N CO .N,- CO _ IZt i7r) - p r ae', U) O — I II ,a,� mN o, 3a - N m Z(`9 as Q (6 'O)(O O 0 co+ nth + o'.4"EZ _ d J O_ OCO CCOJ0 - Of F N _000 N —ON U r m 0 00 sr - N r222 - Nr'NNN.<ONO Z � •o co Oap _ >0100 -.-.- (/) 0 } Y O�«,L5 - p 00001? 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C7 � 2 F-.. / J N L .a V _ Z GO M O - o cn O M Q -M roo voo Q t` - ai of (n 'c��m U C 01 Cr; —o 0 Y@J@5 CO 0, _ N a U m m= n 7 _ 2 ' E d O m'o'oE In [j - 0 0-h LL m--E z »' u.. — mmc o - - ♦ . W � -. >r)w W o G W d N —O fV —0 d `N N a ~ / M w m Na M / t� • - - act=d Q ?O�� O c 2-E.--- m in `o'r 5g m 1 (.5 _ R'cm4 01 1 Iv U §U I I U 100 - 0 � —O I 1 CO I 01 - II 0 - I _ O CRI I —Or n E o d I Ell m Z 20 no - 0 CICU ..3.2 = w E¢¢ m a �Ou_�� 8 cUo o.o " - I3al E(UWW '-'Q m L 1- 2CO2tn2 2 :Y"a - cO o c p m U`U V - > mW0))w `il E C' C'MEI to T a To 7 m CO m Q I I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I I I 1 1 I I I I I I I I I I I I I I I I I 8 Q L 2 c) �6 g o o 0 0 0 0 0 0 0 m �-a;.0m N Ia 03 0 (m/gsn 00Z) +)yuoN/H4lnoS Hilcorp Energy Company HALLIBURTON Beaver Creek Unit Plan Report for Beaver CK Unit 14- BCU-14RD WP1.0 Measured Vertical Vertical Dogleg Build Turn Toolface Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate Azimuth (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 161.00 0.50 95.90 161.00 -0.06 0.62 -0.57 0.35 0.35 0.00 95.90 192.00 0.20 184.60 192.00 -0.13 0.75 -0.72 1.72 -0.97 286.13 158.02 282.00 0.20 206.50 282.00 -0.43 0.67 -0.79 0.08 0.00 24.33 100.95 404.00 0.30 186.60 404.00 -0.94 0.54 -0.93 0.11 0.08 -16.31 -51.21 553.00 0.50 188.00 552.99 -1.97 0.40 -1.33 0.13 0.13 0.94 3.50 673.00 0.80 187.60 672.98 -3.32 0.22 -1.85 0.25 0.25 -0.33 -1.07 796.00 0.80 193.30 795.97 -5.00 -0.09 -2.42 0.06 0.00 4.63 92.85 982.00 1.40 180.60 981.94 -8.54 -0.42 -3.91 0.35 0.32 -6.83 -28.55 1,108.00 1.60 184.40 1,107.89 -11.83 -0.57 -5.43 0.18 0.16 3.02 28.35 1,234.00 1.80 182.00 1,233.84 -15.56 -0.77 -7.11 0.17 0.16 -1.90 -20.80 1,357.00 0.70 185.40 1,356.81 -18.24 -0.91 -8.33 0.90 -0.89 2.76 177.84 1,483.00 0.40 281.50 1,482.80 -18.92 -1.41 -8.24 0.67 -0.24 76.27 151.82 1,609.00 1.30 354.90 1,608.79 -17.41 -1.97 -7.00 0.99 0.71 58.25 91.31 1,734.00 1.30 1.20 1,733.76 -14.58 -2.07 -5.50 0.11 0.00 5.04 93.15 1,859.00 1.40 3.80 1,858.72 -11.64 -1.94 -4.14 0.09 0.08 2.08 32.79 2,072.00 1.40 8.70 2,071.66 -6.47 -1.37 -2.05 0.06 0.00 2.30 92.45 2,121.00 1.33 5.69 2,120.65 -5.31 -1.22 -1.60 0.20 -0.14 -6.15 -134.98 13 3/8" 2,145.00 1.30 4.10 2,144.64 -4.76 -1.18 -1.36 0.20 -0.13 -6.62 -131.97 2,207.00 1.80 5.20 2,206.62 -3.09 -1.04 -0.65 0.81 0.81 1.77 3.96 2,270.00 3.20 8.70 2,269.56 -0.37 -0.68 0.41 2.23 2.22 5.56 7.97 2,334.00 5.00 13.00 2,333.39 4.12 0.22 1.87 2.85 2.81 6.72 11.84 2,397.00 7.60 15.00 2,396.00 10.82 1.91 3.75 4.14 4.13 3.17 5.82 2,459.00 10.40 18.90 2,457.24 20.07 4.79 5.89 4.62 4.52 6.29 14.22 2,521.00 12.70 25.50 2,517.98 31.52 9.53 7.50 4.27 3.71 10.65 33.14 2,583.00 13.70 34.00 2,578.35 43.76 16.57 7.53 3.52 1.61 13.71 66.92 2,646.00 13.70 34.70 2,639.55 56.08 24.99 6.39 0.26 0.00 1.11 90.34 2,710.00 14.00 35.20 2,701.69 68.64 33.77 5.07 0.50 0.47 0.78 21.99 2,772.00 15.00 33.70 2,761.72 81.44 42.55 3.87 1.72 1.61 -2.42 -21.31 2,835.00 16.00 32.70 2,822.42 95.53 51.76 2.94 1.64 1.59 -1.59 -15.44 2,898.00 16.30 31.50 2,882.94 110.37 61.07 2.30 0.71 0.48 -1.90 -48.63 2,961.00 17.30 27.30 2,943.25 126.24 69.99 2.51 2.50 1.59 -6.67 -52.54 3,024.00 18.10 25.50 3,003.27 143.39 78.50 3.72 1.54 1.27 -2.86 -35.23 3,086.00 19.90 25.30 3,061.89 161.63 87.15 5.34 2.91 2.90 -0.32 -2.17 3,148.00 21.50 26.00 3,119.86 181.38 96.64 7.00 2.61 2.58 1.13 9.12 3,211.00 22.90 28.00 3,178.21 202.58 107.46 8.23 2.52 2.22 3.17 29.29 3,274.00 24.40 29.10 3,235.92 224.77 119.54 8.86 2.48 2.38 1.75 16.90 3,336.00 25.50 29.80 3,292.13 247.55 132.40 9.11 1.84 1.77 1.13 15.34 3,399.00 27.20 29.60 3,348.59 271.84 146.26 9.26 2.70 2.70 -0.32 -3.08 3,462.00 29.90 30.80 3,403.92 297.85 161.41 9.14 4.38 4.29 1.90 12.52 3,524.00 31.50 31.90 3,457.23 324.87 177.88 8.38 2.73 2.58 1.77 19.82 3,588.00 33.30 31.70 3,511.27 354.02 195.95 7.31 2.82 2.81 -0.31 -3.49 3,651.00 36.30 30.60 3,562.99 384.79 214.54 6.60 4.86 4.76 -1.75 -12.27 3,713.00 36.50 30.00 3,612.90 416.56 233.10 6.41 0.66 0.32 -0.97 -60.92 3,776.00 36.40 30.20 3,663.57 448.94 251.87 6.34 0.25 -0.16 0.32 130.16 3,840.00 36.20 30.60 3,715.15 481.62 271.04 6.08 0.48 -0.31 0.62 130.34 3,903.00 35.60 29.20 3,766.18 513.64 289.46 6.14 1.61 -0.95 -2.22 -126.73 3,966.00 34.60 26.70 3,817.73 545.63 306.44 7.43 2.78 -1.59 -3.97 -125.84 4,029.00 34.60 26.70 3,869.59 577.59 322.52 9.49 0.00 0.00 0.00 0.00 4,091.00 34.20 26.50 3,920.74 608.91 338.20 11.56 0.67 -0.65 -0.32 -164.31 4,154.00 34.10 26.80 3,972.86 640.52 354.07 13.63 0.31 -0.16 0.48 120.83 4,216.00 33.80 26.40 4,024.31 671.48 369.57 15.68 0.60 -0.48 -0.65 -143.49 4,278.00 33.70 26.90 4,075.86 702.26 385.02 17.70 0.48 -0.16 0.81 110.01 4,341.00 33.50 27.10 4,128.34 733.33 400.85 19.52 0.36 -0.32 0.32 151.12 4,404.00 33.20 27.00 4,180.96 764.17 416.60 21.30 0.48 -0.48 -0.16 -169.66 4,464.00 33.10 27.20 4,231.20 793.38 431.54 22.96 0.25 -0.17 0.33 132.52 4,528.00 33.10 27.40 4,284.81 824.44 447.57 24.61 0.17 0.00 0.31 90.08 03 December,2013- 18:14 Page 2 of 6 COMPASS Hilcorp Energy Company HALLIBURTON Beaver Creek Unit Plan Report for Beaver CK Unit 14 -BCU-14RD WP1.0 Measured Vertical Vertical Dogleg Build Turn Toolface Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate Azimuth (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 4,590.00 33.50 28.90 4,336.63 854.45 463.63 25.71 1.48 0.65 2.42 64.72 4,652.00 33.30 29.20 4,388.39 884.28 480.21 26.27 0.42 -0.32 0.48 140.58 4,715.00 33.10 29.70 4,441.11 914.32 497.17 26.60 0.54 -0.32 0.79 126.36 4,779.00 33.20 30.10 4,494.69 944.66 514.61 26.66 0.38 0.16 0.62 65.60 4,842.00 34.80 30.10 4,546.92 975.14 532.28 26.60 2.54 2.54 0.00 0.00 4,905.00 35.10 30.20 4,598.56 1,006.35 550.41 26.51 0.48 0.48 0.16 10.85 4,969.00 34.20 30.40 4,651.21 1,037.76 568.76 26.32 1.42 -1.41 0.31 172.88 5,032.00 34.10 31.30 4,703.34 1,068.13 586.90 25.79 0.82 -0.16 1.43 101.57 5,094.00 34.30 30.70 4,754.62 1,098.00 604.85 25.19 0.63 0.32 -0.97 -59.58 5,100.00 34.47 30.46 4,759.57 1,100.92 606.57 25.15 3.60 2.82 -3.97 -38.53 /�I►f`/ 5,100.01 34.47 30.46 4,759.58 1,100.92 606.57 25.15 0.00 0.00 0.00 0.00 �� KOP 9-5/8"CSG;Start Dir 12°/100':5100'MD,4759.57'TVD:65°RT TF „0 5,120.00 35.54 34.21 4,775.96 1,110.60 612.71 24.68 12.01 5.37 18.73 65.00 W1. Start Dir 3°/100':5120'MD,4775.96'TVD 5,200.00 35.55 38.33 4,841.06 1,148.08 640.21 19.60 3.00 0.01 5.16 91.58 5,286.03 35.71 42.76 4,911.00 1,186.13 672.77 10.43 3.00 0.19 5.14 88.22 B1 5,300.00 35.75 43.47 4,922.34 1,192.09 678.34 8.58 3.00 0.30 5.11 84.62 5,330.00 35.85 45.00 4,946.67 1,204.66 690.59 4.27 3.00 0.34 5.09 84.04 5,400.00 33.75 45.08 5,004.15 1,232.89 718.85 -6.10 3.00 -3.00 0.12 178.75 5485.18 31.20 45.20 5,076.00 1,265.15 751.27 -18.04 3.00 -3.00 0.13 178.68 B3 5,500.00 30.75 45.22 5,088.71 1,270.52 756.68 -20.04 3.00 -3.00 0.14 178.58 5,600.00 27.75 45.38 5,175.95 1,304.90 791.41 -32.93 3.00 -3.00 0.16 178.57 5,700.00 24.76 45.58 5,265.62 1,335.91 822.94 -44.73 3.00 -3.00 0.20 178.43 5,707.02 24.55 45.59 5,272.00 1,337.96 825.03 -45.52 3.00 -3.00 0.22 178.25 B4 5,777.94 22.42 45.76 5,337.04 1,357.71 845.25 -53.15 3.00 -3.00 0.24 178.23 End Dir :5777.94'MD,5337.04'TVD 5,800.00 22.42 45.76 5,357.44 1,363.58 851.28 -55.44 0.00 0.00 0.00 0.00 5,900.00 22.42 45.76 5,449.88 1,390.18 878.60 -65.80 0.00 0.00 0.00 0.00 6,000.00 22.42 45.76 5,542.32 1,416.79 905.92 -76.16 0.00 0.00 0.00 0.00 6,100.00 22.42 45.76 5,634.76 1,443.39 933.25 -86.52 0.00 0.00 0.00 0.00 6,200.00 22.42 45.76 5,727.20 1,470.00 960.57 -96.88 0.00 0.00 0.00 0.00 6,300.00 22.42 45.76 5,819.65 1,496.61 987.89 -107.24 0.00 0.00 0.00 0.00 6,400.00 22.42 45.76 5,912.09 1,523.21 1,015.22 -117.60 0.00 0.00 0.00 0.00 6,500.00 22.42 45.76 6,004.53 1,549.82 1,042.54 -127.96 0.00 0.00 0.00 0.00 6,600.00 22.42 45.76 6,096.97 1,576.42 1,069.87 -138.32 0.00 0.00 0.00 0.00 6,700.00 22.42 45.76 6,189.42 1,603.03 1,097.19 -148.68 0.00 0.00 0.00 0.00 6,800.00 22.42 45.76 6,281.86 1,629.63 1,124.51 -159.04 0.00 0.00 0.00 0.00 6,900.00 22.42 45.76 6,374.30 1,656.24 1,151.84 -169.40 0.00 0.00 0.00 0.00 7,000.00 22.42 45.76 6,466.74 1,682.84 1,179.16 -179.76 0.00 0.00 0.00 0.00 7,100.00 22.42 45.76 6,559.18 1,709.45 1,206.48 -190.12 0.00 0.00 0.00 0.00 7,200.00 22.42 45.76 6,651.63 1,736.06 1,233.81 -200.48 0.00 0.00 0.00 0.00 7,300.00 22.42 45.76 6,744.07 1,762.66 1,261.13 -210.84 0.00 0.00 0.00 0.00 7,400.00 22.42 45.76 6,836.51 1,789.27 1,288.45 -221.20 0.00 0.00 0.00 0.00 7,500.00 22.42 45.76 6,928.95 1,815.87 1,315.78 -231.56 0.00 0.00 0.00 0.00 7,600.00 22.42 45.76 7,021.40 1,842.48 1,343.10 -241.92 0.00 0.00 0.00 0.00 7,700.00 22.42 45.76 7,113.84 1,869.08 1,370.43 -252.28 0.00 0.00 0.00 0.00 7,800.00 22.42 45.76 7,206.26 1,895.69 1,397.75 -262.64 0.00 0.00 0.00 0.00 7,850.54 22.42 45.76 7,253.00 1,909.14 1,411.56 -267.88 0.00 0.00 0.00 0.00 B18 7,900.00 22.42 45.76 7,298.72 1,922.30 1,425.07 -273.00 0.00 0.00 0.00 0.00 7,952.91 22.42 45.76 7,347.63 1,936.37 1,439.53 -278.48 0.00 0.00 0.00 0.00 Start Dir 3°/100':7952.91'MD,7347.64'TVD 8,000.00 21.01 45.76 7,391.38 1,948.53 1,452.01 -283.22 3.00 -3.00 0.00 180.00 8,028.43 20.15 45.76 7,418.00 1,955.50 1,459.17 -285.93 3.00 -3.00 0.00 -180.00 B20 03 December,2013- 18:14 Page 3 of 6 COMPASS Hilcorp Energy Company HALLIBURTDN Beaver Creek Unit Plan Report for Beaver CK Unit 14 - BCU-14RD WP1.0 Measured Vertical Vertical Dogleg Build Turn Toolface Depth Inclination Azimuth Depth +N/S +E/-W Section Rate Rate Rate Azimuth (usft) (0) (0) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 8,100.00 18.01 45.76 7,485.63 1,971.82 1,475.93 -292.29 3.00 -3.00 0.00 180.00 8,200.00 15.01 45.76 7,581.50 1,991.64 1,496.28 -300.00 3.00 -3.00 0.00 180.00 8,300.00 12.01 45.76 7,678.72 2,007.93 1,513.02 -306.35 3.00 -3.00 0.00 -180.00 8,306.42 11.81 45.76 7,685.00 2,008.85 1,513.96 -306.71 3.00 -3.00 0.00 -180.00 B23 8,400.00 9.01 45.76 7,777.03 2,020.65 1,526.08 -311.30 3.00 -3.00 0.00 180.00 8,500.00 6.01 45.76 7,876.17 2,029.76 1,535.44 -314.85 3.00 -3.00 0.00 180.00 8,537.00 4.90 45.76 7,913.00 2,032.21 1,537.95 -315.80 3.00 -3.00 0.00 -180.00 B27 8,600.00 3.01 45.76 7,975.85 2,035.24 1,541.06 -316.98 3.00 -3.00 0.00 180.00 8,700.20 0.00 0.00 8,076.00 2,037.07 1,542.95 -317.70 3.00 -3.00 -45.67 -180.00 End Dir :8700.2'MD,8076'TVD 8,751.20 0.00 45.00 8,127.00 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 180.00 B28B 8,800.00 0.00 45.00 8,175.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 8,900.00 0.00 45.00 8,275.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 8,968.20 0.00 45.00 8,344.00 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 B31 9,000.00 0.00 45.00 8,375.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 9,100.00 0.00 45.00 8,475.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 9,200.00 0.00 45.00 8,575.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 9,300.00 0.00 45.00 8,675.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 9,400.00 0.00 45.00 8,775.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 9,500.00 0.00 45.00 8,875.80 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 3 1/2" 9,500.10 0.00 45.00 8,875.90 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 Total Depth:9500.2'MD,8876'TVD 9,500.20 0.00 45.00 8,876.00 2,037.07 1,542.95 -317.70 0.00 0.00 0.00 45.00 BCU 14RD BHL TGT-BCU 14RD BHL TGT revl Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W Comment (usft) (usft) (usft) (usft) 5,100.01 4,759.58 1,100.92 606.57 KOP 9-5/8"CSG;Start Dir 12°/100':5100'MD,4759.57'TVD:65°RT TF 5,120.00 4,775.96 1,110.60 612.71 Start Dir 3°/100':5120'MD,4775.96'TVD 5,777.94 5,337.04 1,357.71 845.25 End Dir :5777.94'MD,5337.04'TVD 7,952.91 7,347.63 1,936.37 1,439.53 Start Dir 3°/100':7952.91'MD,7347.64'TVD 8,700.20 8,076.00 2,037.07 1,542.95 End Dir :8700.2'MD,8076'TVD 9,500.10 8,875.90 2,037.07 1,542.95 Total Depth:9500.2'MD,8876'TVD Vertical Section Information Angle Origin Origin Start Type Target Azimuth Type +N/_S +E/-W TVD (°) (usft) (usft) (usft) User No Target(Freehand) 300.00 Slot 0.00 0.00 18.00 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 161.00 5,100.00 BCU 14 MWD+SC+sag 5,100.00 5,400.00 BCU-14RD WPI.0 MWD_Interp Azi 5,400.00 9,500.08 BCU-14RD WP1.0 MWD+SC+sag 03 December,2013 - 18:14 Page 4 of 6 COMPASS Hilcorp Energy Company HALLIBURTON Beaver Creek Unit Plan Report for Beaver CK Unit 14- BCU-14RD WP1.0 Casing Details Measured Vertical Casing Hole Depth Depth Name Diameter Diameter (usft) (usft) (") (") 2,121.00 2,120.65 13 3/8" 13-3/8 17-1/2 9,500.00 8,875.80 3 1/2" 3-1/2 8-1/2 Formation Details Measured Vertical Dip Depth Depth Name Lithology Dip Direction (usft) (usft) (°) (°) 5,286.03 4,911.00 B1 5,485.18 5,076.00 B3 5,707.02 5,272.00 B4 7,850.54 7,253.00 818 8,028.43 7,418.00 B20 8,306.42 7,685.00 B23 8,537.00 7,913.00 B27 8,751.20 8,127.00 B28B 8,968.20 8,344.00 B31 Targets associated with this design TVD +N/-S +E/-W Target Name (usft) (usft) (usft) Shape BCU 14RD BHLTGT revl 8,876.00 2,037.07 1,542.95 Circle Directional Difficulty Index Average Dogleg over Survey: 1.01°/100usft Maximum Dogleg over Survey: 12.00°/100usft at 5,120.00 usft Net Tortousity applicable to Plans: 1.01°/100usft Directional Difficulty Index: 5.514 Audit Info 03 December,2013 - 18:14 Page 5 of 6 COMPASS Hilcorp Energy Company HALLIBURTON Beaver Creek Unit North Reference Sheet for Beaver Creek Unit - Beaver CK Unit 14 - BCU-14RD All data is in US Feet unless otherwise stated. Directions and Coordinates are relative to True North Reference. Vertical Depths are relative to BCU 14rd plan @ 159.00usft. Northing and Easting are relative to Beaver CK Unit 14 Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 using datum NAD 1927(NADCON CONUS),ellipsoid Clarke 1866 Projection method is Transverse Mercator(Gauss-Kruger) Central Meridian is-150.00°,Longitude Origin:0.0000000°,Latitude Origin:0.0000000° False Easting:500,000.00usft,False Northing:0.00usft,Scale Reduction:0.99993921 Grid Coordinates of Well:2,430,071.36 usft N,314,368.19 usft E Geographical Coordinates of Well:60°38'51.16"N,151°02'03.70"W Grid Convergence at Surface is:-0.90° Based upon Minimum Curvature type calculations,at a Measured Depth of 9,500.20usft the Bottom Hole Displacement is 2,555.45usft in the Direction of 37.14°(True). Magnetic Convergence at surface is:-18.04°(31 December 2013,,BGGM2013) T Magnetic Model: BGGM2013 M Date: 31-Dec-13 Declination: 17.14° Inclination/Dip: 73.62° Field Strength: 55471 Grid Nath is 0.90°West of True North(Grid Convergence) Magnetic North is 17.14°East of True North(Magnetic Declination) Magnetic North is 18.04°East of Grid North(Magnetic Convergence) To convert a True Direction to a Grid Direction,Add 0.90° To convert a Magrttic Diectbn to a The Direction,Md 17.14°East To convert a Magnetic Direction to a Grid Direction,Add 18.04° 03 December,2013 - 18:14 Page 6 of 6 COMPASS 2 m 0L I— L I 0, M 0 J J L d L m Ia N AW W MN y C O O tT2 a, L . vp a w UC O N a ti N O w U O W o C (10 K m N K V O O @ O N te � r0-� O = Z O E _ N o � � w O ■— (XS O v - , °- U) U NMI Z c M .L. _ C- ... 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Cif (u!/OG Z)JO1oed uoueaedeS o Q U Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,January 14, 2014 1:39 PM To: 'Monty Myers' Subject: RE: Beaver Creek 14RD Info(PTD 213-196) Ok on the FIT change. The casing needs to be tested to 4000 psi for 30 min. 4000 psi is based on your BOP test pressure and it will need to be tested again before the frac to higher pressure (based on model results.) Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Monty Myers [mailto_mmyershilcorp_com] Sent: Tuesday,January 14, 2014 1:37 PM To: Schwartz, Guy L(DOA) Subject: RE: Beaver Creek 14RD Info (PTD 213-196) Guy I am revisiting the questions you had on this well and am making some modifications to update the procedure. I had a typo on page 18 where I stated 12 ppg EMW fit. I would like to test to 11 ppg FIT if possible. That gives me 2 ppg overbalance for well control. I would rather change page 18 to 11 ppg FIT Also, the 4000 psi casing test,. Can this be done when I bump the plug on the cement job and hold it for 10 minutes or does it need to be the full blown charted 30 min test? I can chart with the cement pump recording data but do not want to hold it more than 10 mins. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Schwartz, Guy L(DOA) [mailto:g_uy_.schwartzt a!aska_gov] Sent:Thursday, January 02, 2014 11:34 AM To: Monty Myers Subject: RE: Beaver Creek 14RD Info (PTD 213-196) Monty, As per our phone call the FIT should be 12 ppg EMW(page 7 summary states 11 ppg FIT) after drilling out the window and test casing to 4000 psi before rig leaves location. 1 A separate sundry will be required for the completion and fracturing of the well. LDL will be required also. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Monty Myers [mailto mmyers aThilcorp.cgm] Sent:Thursday, January 02, 2014 8:58 AM To: Schwartz, Guy L(DOA) Subject: Beaver Creek 14RD Info Good morning Guy! Hope you had some good holidays and are enjoying this warm new year! Hey I am needing to get some info out to the guys at the rig to have signs made for our next well,and was wondering if I could get the PTD# And API# That has been assigned to the Beaver Creek 14 RD? The original API#for Beaver Creek 14 is 50-133-20539-00-00 The original PTD#is 204-086 I wasn't sure if this would change? Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 2 Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday,January 13, 2014 3:13 PM To: Schwartz, Guy L(DOA) pil) i3 4/ c Subject: RE: BCU#14A sidetrack You got it! I will have Schlumberger revise the cement program to include an inhibited spacer ahead of the cement job. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Schwartz, Guy L(DOA) [mailto:g y.schwartn:alaska.gov] Sent: Monday, January 13, 2014 3:09 PM To: Monty Myers Subject: RE: BCU #14A sidetrack Monty, As long as you still add the inhibitor to the mud we can approve the PTD. As we discussed take pictures of the tubing when it is pulled to see extent of any corrosion in the IA. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Monty Myers [mailto_mmyersohilcorp.com] Sent: Monday,January 13, 2014 11:01 AM To: Schwartz, Guy L(DOA) Subject: BCU #14A sidetrack Guy, After review of the BCU#14A procedure I would recommend leaving the procedure as is. - Swell packer deliverability for the 5-1/2"casing is too far out,to receive in time to run in the well.We will plan to have cement inside the window to have a testable annulus - I recommend leaving the pipe as smooth as possible for the frac job.With the newer composite plugs, I feel we have an advantage to isolate the reservoir if needed, using composite or inflatable bridge plugs. Let me know if you have any questions. 1 Just an update to where we are: Saxon 169 is currently released from SRU 22-22(11-22)and moving toward Beaver Creek. Moncla is currently decompleting the BCU#14 to prep it for the sidetrack and they should be moving off by the 16th so we can MIRU w/Saxon 169. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Thursday,January 02,2014 11:34 AM To: 'Monty Myers' Subject: RE: Beaver Creek 14RD Info (PTD 213-196) Monty, As per our phone call the FIT should be 12 ppg EMW (page 7 summary states 11 ppg FIT) after drilling out the window and test casing to 4000 psi before rig leaves location. A separate sundry will be required for the completion and fracturing of the well. CBL will be required also. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Monty Myers [mailto:mmyersahilcorp.com] Sent: Thursday, January 02, 2014 8:58 AM To: Schwartz, Guy L(DOA) Subject: Beaver Creek 14RD Info Good morning Guy! Hope you had some good holidays and are enjoying this warm new year! Hey I am needing to get some info out to the guys at the rig to have signs made for our next well,and was wondering if I could get the PTD# And API# That has been assigned to the Beaver Creek 14 RD? The original API#for Beaver Creek 14 is 50-133-20539-00-00 The original PTD#is 204-086 I wasn't sure if this would change? Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell:907.538.1168 1 Davies, Stephen F (DOA) From: Jeff Allen [fallen@hilcorp.com] Sent: Thursday, December 19, 2013 5:08 PM To: Davies, Stephen F (DOA) Cc: Monty Myers; Kevin Eastham Subject: Re: BCU 14RD Logging Program Hey Steve, We are planning on getting the data with LWD tools but will have OHL tools available if we get poor quality data from the LWD tools. We are also planning on acquiring RFT data after we TD the well to get pressure and mobility information. Let me know if there's anything else. Thanks, Jeff Sent from my iPhone On Dec 19, 2013, at 4:37 PM, "Davies, Stephen F (DOA)" <steve.daviesgalaska.gov<mailto:steve.davies@alaska.gov» wrote: Jeff, Can you help me with these questions? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Davies, Stephen F (DOA) Sent: Thursday, December 19, 2013 4:35 PM To: 'Kevin Eastham' Cc: 'Monty Myers' Subject: BCU 14RD Logging Program Kevin, Thanks again for your help with the digital log data for BCU 9. Questions: In the geologic prognosis for the planned BCU 14RD well the E-Line Log Data line specified open-hole quad combo logs. However, I don't see wireline logging operations mentioned in the Drilling Procedure section of the Permit to Drill Application, only LWD logs. Did I overlook something? Does Hilcorp plan to obtain wireline logs in BCU 14RD? Thanks, 1 Davies, Stephen F (DOA) From: Monty Myers [mmyers@hilcorp.com] Sent: Thursday, December 19, 2013 4:54 PM To: Davies, Stephen F (DOA) Cc: Kevin Eastham Subject: Re: BCU 14RD Logging Program Good afternoon Stephen. We will have quad combo LWD tools while drilling both beaver creek wells with e-line quad combos as a back up if the LWD tools don't provide sufficient data or don't work. We will probably have to run them on memory due to the length of the tools compared to the rig only being a double so we won't know if we will have to attempt e-line logs until we are able to download the data after drilling. Let me know if you need more info. Thanks and have a great evening! Monty M Myers On Dec 19, 2013, at 4:34 PM, "Davies, Stephen F (DOA)" <steve.daviesOalaska.gov<mailto:steve.davies@alaska.gov>> wrote: Kevin, Thanks again for your help with the digital log data for BCU 9. Questions: In the geologic prognosis for the planned BCU 14RD well the E-Line Log Data line specified open-hole quad combo logs. However, I don't see wireline logging operations mentioned in the Drilling Procedure section of the Permit to Drill Application, only LWD logs. Did I overlook something? Does Hilcorp plan to obtain wireline logs in BCU 14RD? Thanks, Steve Davies AOGCC 907-793-1224 1 ce RECEWED ti1N5\ STATE OF ALASKA DEC 0 5 201 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 12.1 14 1 !3 APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril 0 ' Perforate New Pod ❑ Repair Well El Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing • Time Extension❑ Operations Shutdowt❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other.❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q 204-086 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,Alaska 99503 50-133-20539-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 521 ❑ Beaver Creek Unit(BCU)#14 ' Will planned perforations require a spacing exception? Yes El No • 9.Property Designation(Lease Number): 10.FIeld/Pool(s): /1 FEDA028083 ' Beaver tep,Beluga Gas Pod 11. PRESENT WELL CONDITION SUMMARY J Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(fk s(measured): Junk(measured): 9,361' • 8,786' • 8,636' 8,064' If 8,636' N/A Casing Length Size MD Burst Collapse Structural Conductor 147' 20" 147' 147' Surface 2,124' 13-3/8" 2,124', 2,124' 3,450 psi 1,950 psi 1\ :(q1 Intermediate 7,594' 9-5/8" 7,5 7,023' 5,750 psi 3,090 psi Production 9,329' 3-1/2" 9,3e7-7 8,758' 10,160 psi 10,540 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic / `1I2" 9.3#,L-80 9,325 Packers and SSSV Type: N/A;N/A Packers and SSSV MD(t)aid ND(ft): WA;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class ager proposed work • Detailed Operations Program n BOP SketchExploratory n Stratigraphicn Development n Service n 14.Estimated Date for J 15.Well Status after proposed work: Commencing Operations: 12/131 v Oil ❑ Gasp� k3 WDSPL ❑ Suspended kms! 16.Verbal Approval: Date: WNJ El GINJ i?' WAG ❑ Abandoned ❑i•�"� Commission Representative: 0 GSTOR ❑ SPLUG ❑ 17.I hereby cedify that the foregoing is true ando reullo the best of my knowledge. Cor tact Stan Porhda Phare 907-777 412 Emosll sDafiolal�hacorD.Cor>1 Printed Name Stan Porhola Title Operations Engineer Signature4 .,44L( / I Phone 907-777-8412 Date I O 57/3 COMMISSION USE ONLY f Conditions of approval: Notify Commissions at a representative may witness ' ndry Number. 3\3— La%3 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other. s 3c psi.. /So eG s f-- 4a- Al k2Piga , ic«,.....1- Q.jopfk /elm" 04,A'2S 11 i CO Spacing Exception Required? Yes 0 No 14 Subsequent Form Required: / —'AO 7- APPROVED BY Approved by:agyCOMMISSIONER THE COMMISSION s Date: `2.-2)- /3 AL /L 7"�3 Sbit FkxaForm 10-403(Revised 10/2012) Appronths from the data approval. Attachments in Duplicate �'l ePP� `', Well Prognosis Well: BCU-14 Ililcorp Alaska,LL' Date:12/05/2013 Well Name: BCU-14 API Number: 50-133-20539-00 Current Status: Shut-in Gas Well Leg: N/A Estimated Start Date: December 16, 2013 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-086 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —3,450 psi @ 8,150'ND (Static survey November 2004 mid perf 8,721' MD) Maximum Expected BHP: — 3,450 psi @ 8,150'TVD (Static survey November 2004 mid perf 8,721' MD) Max. Allowable Surface Pressure: —2,635 psi (Based on actual reservoir conditions and gas gradient to surface(0.10psi/ft)) Brief Well Summary Beaver Creek#14 was drilled as a grassroots EXCAPE well in 2004 to target the lower Beluga gas sands. This well was fracture stimulated using the EXCAPE completion in 11 modules, but due to formation damage caused during the fracture stimulation work,the well has never r cedrhe bottom 2 modules were isolated with a bridge plug and cement to isolate water. t a ore currently has sand fill above all modules. The purpose of this work/sundry is to abandon the current perforated intervals and prepare the wellbore for ' re-drilling operations. A drilling permit application will be submitted separately for the sidetrack. Notes Regarding Wellbore Condition to'evr. • Last tag at 6,531' RKB on 8/30/13 w/a 2.50" Drive Down Bailer. ,de/7747p Slickline Procedure: 1. MIRU Slickline,PT lubricator to 3,000 psi Hi 250 Low. 2. RU 2.65"gauge ring,RIH and tag fill/obstruction (last tag at 6,531'on 8/30/13 w/2.50" bailer). 3. RU tubing stop/plug for 3-1/2"tubing, RIH and set at+/-6,500'. Bleed off tubing pressure. 4. Dump bail 35'of cement on tubing plug(13 gallons of cement). V o l� 5. Wait on cement for 12 hours. 6. Tag top of cement. 7. RD Slickline. WO Rig Procedure: 8. MIRU Moncla#405 WO Rig. 9. NU BOPE.Test to 250 psi Low/3,000 psi High,annular to 250 psi Low/1,500 psi High(hold each valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance to witness. b. Notify BLM 48 hrs in advance of BOP test. c. BPV in hanger profile. 10. Bleed any pressure off casing.Pull BPV. Well Prognosis Well: BCU-14 Ilikor)Ala,ka,LI) Date:12/05/2013 11. MU landing joint and pull 15k tension over string weight on tubing hanger. 12. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 13. RU 3.5"Tubing Jet Cutter. 14. RIH and jet cut tubing at 6,400' MD. a. Have backup cutters on location if tubing does not part. b. Plan 2nd jet cut if control lines do not part. 15. SOOH and rack back 3-1/2"tubing. 16. MU flat-bottom BHA w/casing scraper and RIH on 3-1/2"tubing out of derrick. 17. Tag cut tubing at+1-6,400' MD. - 18. Circulate well clean w/Produced Lease Water. 19. POOH. LD 3-1/2"tubing,casing scraper and flat-bottom BHA. 20. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low.. 21. RU 9-5/8"CIBP and GR/CCL tools. 22. RIH and set CIBP at+/-5,100' MD in the 9-5/8"40#casing(set 3-5 ft above a casing collar). 23. RD E-line. 24. Test casing to 2,000 psi for 30 min and chart. '® 25. Set BPV. ND BOPE. NU dry hole tree. Pull BPV. 26. RD Moncla#405 WO Rig. 27. Turn well over to production in preparation of moving in the Saxon#169 Drilling Rig. 28. Replace IA x OA pressure gauge if removed (7"x 13-3/8"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic II BC-14 ACTUAL Pad 1A SCHEMATIC Hiker!)Alaska,LLC 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 204-086 "` 20" K-55 133 ppf API#: 50-133-20539-00-00 Top Bottom Property Des: A-028083 MD 0' 147' KB Elevation: 162' (21'AGI-) 0 TVD 0' 147' Lat: N60' 38' 51.1588' Long: W151° 2' 45.491" Surface Casing Spud Date: 07/02/04 ', . 13-3/8" K-55 68 ppf BTC kv Bottom Rig Released: I MD 0' 2,124' ND 0' 2,124' ��_______�.__-__ 16"hole Cmt wl 568 sks( bbl)of r 12.0 ppg,Class G cmt Tree cxn=6-1/2"Otis -1 44 Intermediate Casing_ fff 9-5/8" L-80 40 ppf BTC ITop Bottom TOC(8/3/04 CBL)-6,690' MD 0' 7,594' • ND 0' 7,023' L 12.114"hole Cmt w/377 sks(bbls)of Tagged fill @ 6,531'KB(8130113) • G4+i ` .- 12,5 ppg Tail&510 sks( bbls)of 13.5 • w/2.50"Drive Down Bailer \ , C7 ppg Lead Class G cmt G440 Production Tubing ' 3-1/2" L-80 9.3 ppf Mod EUE ��- re)C... Top Bottom 8rd 117-''.11'' ' }}� e.,661,43t MD 0' 9,329' ,' ND 0' 8,756' 8-1/2"hole Cmt wl 832 sks( bbls) Excape System Details ; of 15.8 ppg,Class G cmt -BHP monitoring green line volume ---` tri tank located from ', _, ' 7,610'-7,653'RKBw. `� . ,e. � Excape System Details Excape System Details -11 Excape modules placed 10 Conventional flappers y -Green control line fires module 1 Mod 1 -no flapper `e .. control line fires modules 2-6 -Ceramic flapper valves below I - control line fires modules 7-11 44 -Ceramic flapper valves below each each module as follows: Flappers MD(RKB): .? module(excluding Module 1) Module 11 -7,721' +�. 1 Module 10-7,782' D' I Beluga Perfs MD(OH Lost): Module 9 -8,044 i Module 11 -7,702'-7,712' Module 8 -8,167' Module 10-7,763'-7,773' . Module 7 -8,321' Module 9-8,025'-8,035'. Module 6 -8,443' Ii Module 8-8,148'-8,158', • Module 5 -8,526' Module 7-8,302'-8,312' • Module 6-8,424'-8,434' • Module 4 -8,575' Module 3 -8,746' Module 5 8,507'-8,517' • Module 4-8,556'-8,566' ' Module 2 -8,982' I Cement @ 8,636' ELMD Wireline Set Plug 8,675' Plug @ 8,675'MD . Module 3 8,727' 8,737' _G6ES Capped w/39'of cement ' ' i '•' '"LUCCED ' Module 1 9,022 ' LAGGE-D '; i TD PBTD 9,361'MD 8,636'MD 8,786'TVD 8,064'TVD Well Name&Number. Beaver Creek Unit#14 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 2°/181 ft @ 985' Angle/Perfs:1 14.5°--•1° Maximum Deviation: 36.5°@ 3,716' Date Completed: 9/16/2004 Ground Level(above MSL): 141' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: 8/30/2013 Schematic Revision Date: 10/10/2013 BC-14 PROPOSED Pad 1A SCHEMATIC Hilcorp Alaska.LLC 113' FSL, 1,388' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 204-086 20" K-55 133 ppf API#: 50-133-20539-00-00;: Top Bottom Property Des: A-028083 '< MD 0' 147' KB Elevation: 162' (21'AGO TVD 0' 479' .t: N60' 38' 51.1588' '.•n•: W151` 2. 45.491" Surface Casing ud Date: 07/02/04 , 13-3/8" K-55 68 ppf BTC :c Released: S' Top Bottom MD 0' 2,124' /(Q/ ND 0' 2,124' 16"hole Cmt wl 568 sks( bbl)of o 12.0 ppg,Class G cmt TOC(8/3/04 CBL)-6,690' V r7 Intermediate Casing 9-5/8" L-80 40 ppf BTC Bridge Plug @ 5,100' Top Bottom MD 0' 7,594' Jet Cut Tubing @ 6,400' -I TVD 0' 7,023' , 12-1/4"hole Cmt w/377 sks(bbls)of Tubing Plug @ 6,500' I I '! ppg Led Class GO s is( bbls)of 13.5 Cap^nd w/35'Cement iProduction Tubing ti • 3-112" L-80 9.3 ppf Mod EUE Tagged fill @ 6,531'KB(8/30/13) Top Bottom 8rd w/2.50"Drive Down Bailer .S MD 0' 9,329' i ND 0' 8,756' 8-1/2"hole Cmt w/832 sks( bbls) Excape System Details i ' of 15.8 ppg,Class G cmt -BHP monitoring green line volume 1 tank located from I .�:' 7,610'-7,653'RKB I � , .% y;+ Excape System Details • -11 Excape modules placed Excape System Details '' :e -Green control line fires module 1 -10 Conventional flappers I 1 ‘ R -Mod 1-no flapper r� control line fires modules 2-6 -Mod 1Ceramflapper valves below '` G - control line fires modules 7-11 each module as follows: j'., Ceramic flapper valves below each Flappers MD(RKB): L; 14 I��6 module(excluding Module 1) Module 11 -7,721' Module 10-7,782' P Beluga Peds MD(OH Loa): 1 �'. ,,, Module 11 -7,702'-7,712' Module 9 -8,044 ! ' Y Module 8 -8,167' ; Module 10-7,763' 7,773' Module 7 -8,321' ,' �' Module 9-8,025'-8,035' Module 6 -8,443' l Ti Module 8-8,148'-8,158' Module 5 -8,526' Module 7-8,302'-8,312' ' ' Module 6-8,424'-8,434' Module 4 -8,575' TiIl Module 3 -8,746' i;; Module 4-8,556'-8,516' Module 2 -8,982' I Module 4-8,556'-8,566' Cement (a 8,636' ELMD '1' I Wireline Set Plua 8.675' Plug @ 8,675'MD !,1 ', '.' Module 3 8,727' 8,737'^LUCCED Capped w/39'of cement b / '•' Module 1 0,022' 9,032'1 LUCCED •., li '. Y1 TD PBTD 9,361'MD 8,636'MD 8,786'TVD 8,064'TVD Well Name&Number: Beaver Creek Unit#14 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 2°1181 ft @ 985' Angle/Perfs: 14.5°-4 1° Maximum Deviation: 36.5°@ 3,716' Date Completed: 9/16/2004 Ground Level(above MSL): 141' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 12/5/2013 0 II Beaver Creek BC # 14 BOP Moncla #405 12/05/2013 Ililr..rp 1,144,i.1.1.1. Beaver Creek BC#14 20X133/8X95/SX3' 0lfil LLU n 1111 LL11 n1 \ / 3.74' Shaffer 135/8SM rill al]4:on Ir 11 t t Shaffer S! - 13SSSM. C40 -'v 10.01' _ I 1 2.83' 01 OD 2 1/16 SM Kill Valves 3 1/8 SM Choke Valves Manual and HCR 1111 m,L 111) lel Manual and HCR I-1:41*.: : _ G LSI' 85Mw1 iøo 5M EFO 200eiN Shaffer St 13 5/8 5M 1.44' =E=1 i} ' 11— .i, I+it ' =P.Mwi lir+ Grade Level Mulubowl,Vetco MB-196, 13 5/8 3M stdd bottom X l i�1 �4IL ; 41 i 13 5/8 5M FE top,w/ ;'�; , _ AI:�•� ti a- 2-2 1/16 5M 550 : .I mi.-%tiv: Starting head, „ 1„,Vetco MB-196, �' _. 13 5/8 3M X 13 3/8 VG-Loc iii-) i 11.111ili bottom,w/2-2"LPO IP' !El ;L En 20" 13 3/8" . 9.625" 3.5" Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, December 19, 2013 4:37 PM To: 'jallen@hilcorp.com' Subject: FW: BCU 14RD Logging Program Jeff, Can you help me with these questions? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Davies, Stephen F (DOA) Sent: Thursday, December 19, 2013 4:35 PM To: 'Kevin Eastham' Cc: 'Monty Myers' Subject: BCU 14RD Logging Program Kevin, Thanks again for your help with the digital log data for BCU 9. Questions: In the geologic prognosis for the planned BCU 14RD well the E-Line Log Data line specified open-hole quad combo logs. However, I don't see wireline logging operations mentioned in the Drilling Procedure section of the Permit to Drill Application, only LWD logs. Did I overlook something? Does Hilcorp plan to obtain wireline logs in BCU 14RD? Thanks, Steve Davies AOGCC 907-793-1224 1 Davies, Stephen F (DOA) From: Kevin Eastham [keastham@hilcorp.com] Sent: Thursday, December 19, 2013 4:35 PM To: Davies, Stephen F (DOA) Subject: Automatic reply: BCU 14RD Logging Program I will be out of the office starting Thursday December 19th and returning on Friday January 3rd. For immediate response regarding Beaver Creek, please contact Jeff Allen. Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, December 19, 2013 4:35 PM To: 'Kevin Eastham' Cc: 'Monty Myers' Subject: BCU 14RD Logging Program Kevin, Thanks again for your help with the digital log data for BCU 9. Questions: In the geologic prognosis for the planned BCU 14RD well the E-Line Log Data line specified open-hole quad combo logs. However, I don't see wireline logging operations mentioned in the Drilling Procedure section of the Permit to Drill Application, only LWD logs. Did I overlook something? Does Hilcorp plan to obtain wireline logs in BCU 14RD? Thanks, Steve Davies AOGCC 907-793-1224 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: r �> /4c_ C7,/DFM: 2/3 /C-7‘- ,/ Development evelopment Scr\ice Exploratory Stratigraphic lest Non-Con\cntional ,,,,,_ A-S (---Z.:ec 7 Ir IELD: �_ ��=_-eE POOL: �-t Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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N- O N M V' 11) O W 0) O N M V 3)) O W 0) O N M V )f) CD N- co 0) �' O N co V IC) c0 N- oo C) M N N N N N N N ch,-, N N C) C') C') C) C) M (M M M co V V U Co M o O a) 2 o C °1 N O N 0 O D p) O cN 0 r° O u) J W N C O J a) / N % rn 0 E W aE Q o C a _i O Q U .Q co 0w a a aS Q w c9 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Hilcorp Alaska, LLC Beaver Creek Unit BCU-14A FINAL WELL REPORT DML LOGGING DATA Provided by: Approved by: Kevin Eastham Compiled by: Larry Resch Donna New Distribution: 2/18/2014 TD Date: February 01, 2014 BCU 14A 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Well Synopsis. ................................................................................................................................3 2.4 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................5 3.1 Lithostratigraphy .............................................................................................................................5 3.2 Lithologic Details.............................................................................................................................6 3.3 Connection Gases ........................................................................................................................13 3.4 Trip Gases ....................................................................................................................................13 3.5 Sampling Program / Sample Dispatch..........................................................................................13 4 DRILLING DATA..................................................................................................................................14 4.1 Directional Survey Data................................................................................................................14 4.2 Bit Record.....................................................................................................................................18 4.3 Mud Record ..................................................................................................................................19 5 SHOW REPORTS ...............................................................................................................................20 6 DAILY REPORTS ................................................................................................................................23 Enclosures: 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) Final Data CD BCU 14A 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Mudlogging Unit Computer System Canrig: 3 HP Compaq Workstations (DML, RigWatch, and Sample Catcher) 0 Ditch Gas Canrig: (2) QGM Gas Traps (with High RPM Electric-Powered Agitators) Canrig: E-Series FID THA Analysis and Chromatography. 0 Pason EDR All Drilling Parameters 0 Block Height / Depth Pason WITS Feed 0 Hookload / WOB Pason WITS Feed 0 RPM Pason WITS Feed 0 Torque Pason WITS Feed 0 Return Flow Pason WITS Feed 0 Pit Volumes Pason WITS Feed 0 Mud Gain/Loss Pason WITS Feed 0 Pump Pressure Pason WITS Feed 0 Pump Strokes Pason WITS Feed 0 Rate of Penetration Calculated from Block Position tracking 0 Mud Flow In Calculated from Pump Output/Rate tracking 0 1.2 Crew Unit Number : ML030 Unit Type : Arctic Steel Skid Unit Mudloggers Years* Days*2 Sample Catchers Years Days*2 Technician Days Larry Resch 13 15 Fred Spiers 8 10 Donna New 8 15 Justin Boutte 5 10 *1 Years experience as Mudlogger. *2 Days at well site. BCU 14A 3 2 WELL DETAILS 2.1 Well Summary Well: BCU-14A API Number: 50-133-20539-01-00 Field: Beaver Creek Unit Surface Co- Ordinates: 113’ FSL, 1388’ FEL Sec. 33, T7N, R10W SM Borough: Kenai Borough Primary Target: Depth: Various Beluga Sands 7861’ to 8962’MD State: Alaska TD Depth: 9450’MD/ 8870’TVD Rig Name / Type: Saxon 169/ Double Suspension Date: Primary Target: Beluga Sands Permit to Drill: 213176 Spud Date: January 26, 2014 Ground Elevation: 141.0’ AMSL Completion Status: Run 5” liner RKB Elevation: 159.6’ AMSL Classification: Development Gas Secondary Target: Depth: Various Sterling Sands 5489’ to 5730’MD TD Formation: Tyonek TD Date: February 01, 2014 Days Drilling: Seven Days Testing: None 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Wt (ppg) Dev. (o inc) Casing/ Liner MD (ft) TVDSS (ft) FIT (ppg) 9-5/8” 5001 -4519 13.4 8-1/2” 9450 -8710 Tyonek 9.30 6.69 5” unk N/A 2.3 Well Synopsis. BCU-14A was drilled as a sidetrack of the original BCU-14 drilled in 2004. It is believed that the original lower Beluga production section was compromised due to a failed escape completion, resulting in poor production from the original hole. BCU-14A was drilled to sidetrack the original well to the northeast. Spudded on January 26, 2014, BCU-14A was drilled from the window cut at 5109’MD to a total depth of 9450’MD with no hole issues. Running a 5” production liner is planned. BCU 14A 4 2.4 Daily Activity Summary January 23, 2014: Test BOP’s and pick up drill pipe. Perform casing test @ 3000psi for 30 minutes, slip and cut drill line, level the derrick and shim the sub; POOH with window mill. Pick up whipstock and trip in hole. January 24, 2014: Mill window in casing plus 20' of rat hole from 5083' to 5120'. Rack back stand, rig up chart recorder and perform F.I.T. to 11.0ppg EMW with 495psi. Rig down chart recorder, check flow, pump slug, and POOH. January 25, 2014: Trip out of hole and lay down BHA, Test BOPs; Pick up BHA and orient motor, download MWD, shallow pulse test; make up directional tools; trip into hole picking up singles, currently at 2610' January 26, 2014: Trip to bottom, orient tool face and drill ahead alternately sliding and rotating, Drill to 6089' pull off bottom, pump sweep, circulate; rotate and work pipe for hole cleaning, short trip out of hole to 5135', tripping back to bottom. January 27, 2014: Trip back to bottom after wiper trip at 6089' and resume drilling ahead. Drill to 7083', circulate, pump sweep, and make wiper trip to 6031'. Trip back to bottom and resume drilling. Drilling ahead. January 28, 2014: Trip back to bottom after wiper trip and resume drilling, drill to 7420', troubleshoot leak in top drive, trip out to 5038', replacing top drive. January 29, 2014: Finish replacing top drive and return to drilling; drill to 7456' problem with hydraulic pump for the top drive work to replace; finish repairing top drive, return to bottom and drill ahead. January 30, 2014: Drill ahead, Rig service – grease top drive, blocks, draw-works, oil check. Continue to drill ahead January 31, 2014: Drill ahead February 1, 2014: Drill ahead to TD of 9450’MD; pump high vis sweep and circulate out; back ream through tight spots while wiping hole to 8400’MD; pump another high vis sweep and circulate around; continue to wipe hole to shoe. February 2, 2014: POOH to bottom of window, build mud, trip to bottom, pump sweep and circulate the hole clean, Spot high viscosity mud, POOH 10 stands and blow down top drive, POOH and Lay down top drive, start rigging up wireline. February 3, 2014: Rig up SLB wireline. Run Quad Combo; XPT. Rig down wireline and make up roller cone bit assembly for a clean out run and begin trip in. Currently tripping to bottom. Current gas is 9 units. February 4, 2014: Continue to RIH to bottom with no problems encountered. CANRIG observes 246 units maximum trip gas. Circulate hole clean. POIOH sideways and prepare to run casing. CANRIG released at 1000 hrs. BCU 14A 5 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops were provided by Hilcorp geologist Kevin Eastham. PROGNOSED OBSERVED FORMATION MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) KOP-Sterling 5100 4760 -4601 5001 4678.16 -4518.56 B1 5285 4911 -4752 5313 4935.824 -4776.22 B2 5465 5063.997 -4904.40 B3 5489 5076 -4917 5499 5092.937 -4933.34 B3L 5608 5186.668 -5027.07 B4 5730 5272 -5113 5682 5259.334 -5099.73 Beluga 6330 5853.557 -5693.96 B15 7448 6901.767 -6742.17 B16 7614 7059.222 -6899.62 B17 7730 7171.772 -7012.17 B18U 7861 7253 -7094 7804 7243.214 -7083.61 B19 7902 7339.611 -7180.01 B20 8027 7418 -7259 7976 7412.348 -7252.75 B21 8058 7492.936 -7333.34 B22 8154 7587.542 -7427.94 B23 8297 7685 -7526 8245 7676.439 -7516.84 B24 8381 7810.655 -7651.05 B25 8417 7846.128 -7686.53 B26 8446 7874.622 -7715.02 B27 8528 7913 -7754 8473 7901.208 -7741.61 B28 8536 7963.954 -7804.35 B28B 8744 8127 -7968 8707 8132.464 -7972.86 B29 8740 8165.081 -8005.48 B30 8830 8254.443 -8094.84 B31 8962 8344 -8185 8935 8358.646 -8199.05 B32 9089 8511.804 -8352.20 Tyonek 9381 8801.237 -8641.64 TD 9500 8876 -8717 9450 8869.95 -8710.35 BCU 14A 6 3.2 Lithologic Details Sand, Conglomeratic Sand (5120’ to 5200') = unconsolidated; upper fine to lower fine grain; angular, subangular in part; prismoidal to subprismoidal; moderate to well sorted; no evidence of consolidation or cementation; dominantly grayish white, milky white quartz grains with abundant angular, occasionally well rounded transparent volcanic glass clasts and rare glass shards; secondary components of medium gray to grayish black lithics, feldspars, abundant reddish orange mafic minerals; note occasional well rounded pebble fragments, fractured in part; trace sublithic coal/ carbonaceous material; NSOFC. Sand, Conglomeratic Sand (5200’ to 5320') = unconsolidated; upper very fine to lower fine grain, upper fine grain common; subangular to angular, rarely subrounded; subprismoidal to subdiscoidal; fair to moderate sorting in part; note occasional lower medium, well rounded, discoidal to subdiscoidal grains/ pebbles; no evidence of consolidation or cementation; grayish white, milky white opaque, translucent quartz dominant; abundant transparent, translucent volcanic glass clasts; occasional very fine, thin, sharp edged glass shards; light to medium gray, grayish black lithics common with reddish orange mafic minerals; continued trace carbonaceous material/ sublithic coal; note trace tuffaceous claystone; NSOFC. Tuffaceous Sandstone, Tuffaceous Claystone (5320’ to 5400') = light gray to very light olive gray, yellowish gray to pale yellowish brown; very soft to soft, mushy to pasty; also firm, slightly crumbly; no definable fracture or cut- tings habit; generally dull, sparkly in part with increased clastic grains and locally abundant glass shards; subwaxy when more tuffaceous/ ashy; varies from slightly gritty, abrasive to smooth, massive in part; gradational from tuffaceous/ argillaceous sandstone to an argillaceous claystone; 20-30% loose or disaggregated sand, medium gray to grayish black lithics and reddish orange mafic minerals; locally slightly earthy with flakes, specks, streaks of organic/ carbonaceous material; note trace chlorite; NSOFC. Sand, Tuffaceous Sandstone, Tuffaceous Claystone (5400’ to 5460') = samples represented as >60% loose, disaggregated sand; poorly consolidated sandstone is medium light gray with pale yellowish brown hues, very light olive gray; upper very fine to lower fine grain; subangular to subrounded; subdiscoidal, subprismoidal in part; moderate to well sorted; varies from grain to matrix supported with abundant tuff/ devitrified ash; noncalcareous; NSOFC. Coal (5460’ to 5480' and 5500’ to 5510') = black to grayish black; firm to moderately hard; dense to crunchy, slightly crumbly in part; planar, slightly splintery; subfissle; tabular to platy cuttings habit; subvitreous, slightly sparkly, somewhat subwaxy luster; shaley; no visible outgassing. Tuffaceous Claystone, Tuffaceous Sandstone (5440’ to 5540') = yellowish gray to light pale yellowish brown; very soft; mushy to slightly pasty; pulverulent; no fracture, cuttings habit or bedding; dull, earthy, sparkly in part with increased quartz sand content; noncalcareous. Sand, Tuffaceous Sandstone (5540’ to 5620') = interval varies from 40-60% loose and/ or disaggregated sand; poorly consolidated sandstone is very light gray to yellowish gray, often with slight to moderate yellowish brown hues; lower fine to upper very fine grain; subrounded, subangular in part; subdiscoidal; moderate to well sorted; grain supported in part with minimal clay fill; trace visible porosity; often varies from matrix supported to grain supported with abundant tuff/ devitrified as matrix; quartz dominate with light to medium gray lithics, feldspars, occasional reddish orange mafic minerals ; volcanic glass clasts common; notable absence of glass shards; NSOFC. BCU 14A 7 Tuffaceous Claystone (5620’ to 5700') = yellowish gray to very light pale yellowish brown; very soft; mushy; pulverulent; earthy in part; no definable fracture, cuttings habit or bedding; silty to sandy in part; noncalcareous; often contains carbonaceous detrital flakes, specks; locally grades towards a carbonaceous shale/ earthy poorly developed coal. Sand, Tuffaceous Sand (5700’ to 5800') = interval exhibits 100% loose and/ or disaggregated sand; upper very fine to lower fine grain; subrounded, occasionally subangular; subdiscoidal; well sorted; note occasional well rounded whole pebbles, occasional pebbles with high impact fracture; no evidence of consolidation or cementation in sample; clay component believed to be very soluble; quartz dominant with secondary feldspars, trace to common mafic minerals; NSOFC. Sandstone (5780’ to 5900') = very light gray to medium gray; upper coarse through lower very fine grained; moderately high to high sphericity; moderately well round to subangular; poorly sorted; unconsolidated; cementation not readily evident; grain supported; composition predominantly 70-80% quartz, feldspars, dark gray lithic clasts; NSOFC. Tuffaceous Siltstone (5880’ to 5900') = medium gray to very light gray; soft to very slightly firm; poor to very poor induration; tenacity crumbly to slightly crunchy; cuttings habit massive to slightly blocky with well rounded edges, occasional slightly wedge like; texture silty to slightly gritty; luster dull to earthy; massive bedding; thin contorted and discontinuous laminae of very dark gray to black, very fine, carbonaceous material; NSOFC. Sandstone (5900’ to 6000') = light gray to medium dark gray; grain size mostly upper very fine to upper fine with common medium sized grains, occasional lower coarse; moderate to moderate high sphericity; moderately well rounded to subangular; poorly to very poorly sorted; predominantly unconsolidated with no evidence of matrix or cementation preserved; composition transparent to translucent colorless to white quartz 60%; feldspars 20%; dark lithics 10%; undifferentiated mineral clasts 10%; with occasional preserved specimens of conglomeritic sandstone; NSOFC. Conglomeritic Sandstone (6000’ to 6080’) = white to light gray; lower very fine to lower coarse grain size; moderate sphericity; moderately rounded with occasional subrounded; poorly sorted; easily friable; slightly calcareous cementation; matrix predominantly argillaceous = 30% of specimen; grain supported; composition transparent to translucent colorless to white quartz 60%; feldspars 20%; dark lithics 10%; undifferentiated mineral clasts 10%; NSOFC. Sandstone (6080’ to 6180') = medium gray to medium dark gray; lower fine grained to upper fine grained with rare lower medium grains; moderate to high sphericity; moderately well rounded to subangular; poorly to moderately sorted; predominantly unconsolidated with occasional preserved specimens; argillaceous cementation; in preserved specimens argillaceous matrix; grain supported; mineralogical components 60% quartz mostly transparent to translucent colorless to occasion white; 20% lithics medium gray to dark gray, with occasional frosted surfaces; 10% feldspars with common k-spar; 10% undifferentiated mineral grains with common greens and greenish yellows; associated with tuffaceous siltstones, occasional to increasingly common conglomeritic sandstones; NSOFC. Carbonaceous Shale (6200’ to 6240’) = brown to black; moderately hard to slightly hard; tenacity crunchy to slightly crumbly with common tough; well indurated; cuttings habit blocky to tabular with common irregular platy; texture smooth to very slightly silty; luster dull, earthy with common resinous to subvitreous; very thinly bedded with common laminae of near coal; common visible moderately vigorous out gassing from these laminae. Conglomeratic Sand, Conglomerate (6240' to 6320') = sand is fine to occasionally lower medium grain; subangular to subrounded, subdiscoidal; fair to moderate sorting; no evidence of consolidation or cementation; note up to 10% well rounded, intact, subprismoidal and subdiscoidal lower coarse grains; dominantly grayish white, very light gray, milky white quartz and feldspars; medium gray to grayish black clasts common; NSOFC. BCU 14A 8 Tuffaceous Claystone (6320’ to 6440') = very light olive gray to light pale yellowish brown, pale brown, light gray to medium light gray with occasional light yellowish brown hues, occasionally greenish gray with slight bluish hues; generally firm but yields easily when probed; moderate induration; pulverulent to slightly crumbly in part; no definable fracture; nodular, occasionally blocky cuttings habit; generally dull, occasionally slightly sparkly; silty to very slightly sandy in part; often subwaxy; earthy common to subshaley with intermittent organic component, carbonaceous micro laminae and detrital specks flakes; noncalcareous; no apparent bedding; localized devitrified ash component. Tuffaceous Claystone (6440’ to 6540') = medium light gray to light gray, often with slight yellowish brown hues, medium gray to light bluish gray, occasionally slight light olive gray to pale yellowish brown; firm, yields easily, crumbly in part; often soft to firm, pasty to slightly mushy; pulverulent; no definable fracture; massive; tabular to nodular cuttings habit; dull, occasionally slightly sparkly, subsucrosic in part when silty/ sandy; subwaxy when tuffaceous; dull, pulverulent with abundant devitrified ash; no apparent structure or bedding; locally very carbonaceous and varies from a poorly developed sublithic coal/ earthy carbonaceous shale; carbonaceous detrital specks, fragments, flakes, micro fine laminae common but very localized; noncalcareous. Sand, Conglomeratic Sand, Tuffaceous Sandstone, Conglomerate (6540’ to 6660') = > 80% loose or disaggregated sand and intact pebbles; sand is fine to lower fine grain; rounded to subrounded, sub- angular in part; subdiscoidal; well to moderate sorting overall; 10-15% rounded to well rounded, coarse, intact pebbles and fragments with high impact fracture; poorly consolidated, dominantly grayish white, milky white, opaque quartz and feldspars; grayish black to medium gray grains common; note trace only well rounded transparent volcanic glass clasts, reddish orange mafic minerals; sandstone appears white to light grayish white to yellowish gray with fine, angular to subangular, subprismoidal to subdiscoidal grains; well sorted in part; noncalcareous; occasionally grain supported; generally matrix supported with very soft, pulverulent devitrified ash matrix; grades towards a sublithic arenite 'ash-stone'; note trace occasional carbonaceous platy inclusions, streaks, detrital fragments; NSOFC. Tuffaceous Sandstone (6660’ to 6800') = very light gray to light gray to very light bluish gray, grayish white to yellowish gray; upper very fine to lower fine grain; subangular to subrounded; subprismoidal, subdiscoidal; well to moderate sorting; noncalcareous; very soft; matrix supported with weathered tuff/ devitrified ash; predominantly a sublithic arenite ash-stone; grayish white, milky white, very light gray opaque quartz equally represented with grayish black, dark gray to medium dark gray grains; note abundant loose well rounded coarse pebbles and coarse to very coarse sharp pebble fragments with high impact fracture; note occasional carbonaceous detrital clasts, platy fragments in some sandstone cuttings; micro laminae, flakes, streaks and staining in more massive ashy cuttings; NOFC. Tuffaceous Sandstone (6800’ to 6900') = grayish white to very light gray, occasionally with yellowish gray to very light pale yellowish brown hues; overwhelmingly a sublithic arenite/ ash-stone; very soft; pulverulent, crumbly in part; lower very fine to lower fine grain; well rounded to subrounded, angularity increasing with grain size; well sorted in part; often fair sorting with locally abundant fine, well entrained, disseminated light colored quartz, grayish black to medium dark gray lithics; carbonaceous detrital fragments, specks common with occasional larger platy/ shaley sublithic and lithic coal; note absence of any earthy carbonaceous cuttings. Tuff (6900' to 7000') = medium dark gray to medium light gray with occasional very light gray; slightly firm to soft; moderately to poorly indurated; tenacity malleable to moderately crumbly with occasional firm to crunchy; cuttings massive to wedge like and occasional irregular platy; texture smooth to very slightly gritty; luster dull to slightly waxy; NSOFC. BCU 14A 9 Tuffaceous Sandstone (6900’ to 6900') = medium dark gray to medium light gray; moderately firm to soft; easily friable; crumbly to sticky clay like tenacity with occasional slightly crunchy; grain size predominantly lower very fine to lower coarse with occasional coarser grains and rare pebble sized quartz; moderately rounded to subrounded with rare subangular; overall poorly sorted with occasional specimens presenting as moderately sorted; very easy friable; siliceous cementation; 60 % sand grains in 40% tuff matrix; mineral composition mostly transparent to translucent colorless to white quartz; abundant medium gray to medium dark gray subangular lithics; feldspars; trace undifferentiated pale green to greenish yellow mineral clasts; associated with thinly bedded tuffaceous sandstone and tuffaceous siltstone and trace very fine light gray sandstone. NSOFC Sandstone (7080’ To 7200') = medium gray to medium dark gray with occasional moderate grayish brown; upper medium to upper very coarse; very angular to angular; mod sphericity; moderately to moderately poor sorting; predominantly unconsolidated with rare preserved specimens; no visible remnants of cementation or matrix material; 50% translucent to transparent colorless to white quartz; many grains have dark inclusions; 50% dark gray to blackish gray to blackish green lithic clasts; thinly interbedded with slowly decreasing amounts of tuffaceous sandstone; trace of thinly bedded coals; rare pebble sized grains. Conglomeratic Sandstone (7200’ to 7260') = medium dark gray to medium gray; grain size predominantly very course with occasional smaller grain; predominantly angular to subangular; 50% lithic fragment and 50% quartz; cementation some with silica and some specimens argillaceous cement; variable amounts of matrix; composition predominantly lithic 60% with the remainder predominantly translucent whitish gray quartz to transparent colorless quartz. Conglomeratic Sand, Conglomerate, Pebble/ Cobble Fragments (7260’ to 7420') = note significant overall color change of samples; grayish black to medium gray with various shades in between, opaque; medium gray to light gray, opaque to translucent in part; minor milky white to grayish white; upper fine to lower medium, upper medium common; angular to very angular with thin sharp edges; prismoidal to subprismoidal; moderate sorting; occasionally coarse to very coarse grain and beyond; varies from intact rounded to fractured rounded with high angular impact surfaces; no evidence of cementation; drilled interval exhibits varying amounts of very soft, mushy and pasty argillaceous sediments; very fine to fine grained lithics well entrained common; no definable fracture, bedding or structure; massive to nodular, tabular cuttings habit in part; noncalcareous; note occasional framboidal pyrite; NSOFC. Tuffaceous Sandstone (7440’ to 7520') = medium dark gray to medium gray with occasional very light gray to very pale greenish gray; grain size lower coarse to upper very fine; moderate sphericity; angular to subrounded; moderately poor to poorly sorted with occasional specimens showing moderate sorting; very friable to increasingly unconsolidated with depth as the tuffaceous matrix washes away into drilling mud on trip up hole; cementation tuff and trace argillaceous and trace siliceous; tuff matrix 50% and sand 50%; most specimens grain supported with occasional specimens slightly matrix supported; mineral composition of the grains is mostly quartz with occasional feldspars and lithics; NSOFC. Sandstone (7520’ to 7540') = medium dark gray to light gray with occasional grayish green to moderate green; upper very fine to upper coarse grained; sphericity moderately poor to prismoidal; angular to subangular with rare moderately rounded in the finer grains; poorly sorted; presents predominantly as loose grains with rare preserved specimens being very friable, rare to occasional well lithified to moderately hard specimens; cementation argillaceous and rarely siliceous; matrix in preserved specimens is tuffaceous with these specimens commonly matrix supported; composition 40% quartz, 30% feldspars and 30% lithic fragments; trace chlorite; trace pyrite; NSOFC. Conglomeratic Sand, Conglomerate (7640’ to 7720') = 80-90% loose sand; dark gray to medium gray with shades in between, transparent medium light gray to light gray, grayish white to milky white; upper fine to lower medium grain, often coarse to very coarse; angular, subangular with sharp edges; subprismoidal; moderately to well sorted; finer grains occasionally well entrained in tuffaceous claystone; trace framboidal pyrite; NSOFC. BCU 14A 10 Tuffaceous Sand, Sand (7720’ to 7820') = up to 40 % loose sand; poorly consolidated sandstone is medium gray to medium light gray; upper very fine to lower fine grain; angular to subangular; often lower medium, subangular; occasionally coarse, rounded; subprismoidal to subdiscoidal; fair to moderate sorting; noncalcareous; matrix supported with very soft, mushy to pasty argillaceous component; lithics well entrained; dark gray to medium light gray lithics dominant; with grayish white to milky white quartz and feldspars; note increased framboidal and microcrystalline pyrite; note conglomeratic sand component with intact well rounded upper coarse to lower very coarse grains and similar sized very angular lithic fragments; NSOFC. Tuffaceous Claystone, Tuffaceous Sandstone (7820’ to 7920') = medium light gray, light bluish gray, occasionally dark yellowish brown; soft to slightly firm, yielding easily when probed; poor induration; pulverulent, malleable; no definable fracture, structure or bedding; massive, nodular to slightly tabular cuttings habit with rounded to well rounded edges; dull, subwaxy; occasionally earthy to subshaley with varying amounts of carbonaceous flakes, platy detrital clasts, micro laminae; generally clean, massive, nonabrasive, nongritty; often contains clastic and organic clasts well entrained and disseminated throughout; noncalcareous. Sandstone (7930’ to 8000') = medium dark gray to medium gray with occasional light gray to whitish gray; upper very fine to upper coarse with rare very coarse grains; moderately well rounded to subangular; sphericity moderately high with occasional prismoidal and rare discoidal; poorly to moderately poor sorting with occasional specimens exhibiting moderate sorting; mostly unconsolidated w/ occasional preserved specimens; preserved specimens show both occasional siliceous cemented cuttings and occasional argillaceous cemented specimens; matrix is sparse argillaceous/ tuffaceous; predominantly grain supported; composition of grains is mostly translucent to occasional transparent quartz and feldspars, common lithic fragments, trace chlorite and undifferentiated micaceous minerals; trace very thin, poorly developed, carbonaceous shales with very thin laminae carbonaceous material; slightly better developed specimens are very fissile and slide apart w/ very gentle pressure; thinly interbedded with clays and siltstones that are commonly moderately to very tuffaceous. NSOFC. Tuffaceous Claystone; Tuffaceous Siltstone (8040’ to 8100') = medium dark gray to light gray; very soft, very poorly to poorly indurated; tenacity mushy, sticky, crumbly to earthy, with occasional loose gooey to malleable; cuttings habit massive to subplaty to wedge like w/ most samples showing well rounded edges, common clay balls, texture smooth to very silty; luster earthy to dull; occasional thin laminae of carbonaceous material; trace carbonaceous shale; NSOFC. Note: No samples available from 8100 ft to 8160 ft due to lag software malfunction. Carbonaceous Shale (8160’ to 8180') = very dark brown to dark brownish black, black, occasional moderate reddish brown to moderate yellowish brown; very soft and crumbly to moderately hard and crunchy with occasional hard and brittle; poorly indurated to very well indurated; punky to well developed carbonaceous component; texture smooth; luster dull and earth to vitreous; fracture earthy to blocky; very thinly bedded very slow sparse outgassing visible; NSOFC. Sandstone (8200’ to 8280') = very light gray to medium dark gray; upper very fine to upper coarse with rare very coarse; moderate sphericity; subrounded to subangular; poorly sorted; poorly consolidated with sample interval presenting with common loose grains; sparse to no cementation; common argillaceous matrix; grain supported; mineralogical composition of grains mostly translucent to transparent colorless to white quartz 60%; often up to 20% feldspars and plagioclase, common dark lithics, trace chlorite. BCU 14A 11 Tuffaceous Siltstone, Tuffaceous Claystone, Tuffaceous Sand (8280’ to 8380') = very light gray to whitish gray to medium dark gray, light gray to rare pale bluish green to light green with rare moderate green, rare whitish gray; very soft to slightly firm; tenacity crumbly to slightly crunchy; cuttings habit sub tabular to slightly wedge like with all cuttings fairly rounded texture slightly to very silty; dull to earthy; slightly sticky; massive. Tuffaceous Sandstone, Coal/ Carbonaceous Shale (8380’ to 8460') = medium light gray to light gray, medium dark gray in part; upper very fine to fine grain; subrounded to subangular; subdiscoidal to subprismoidal; noncalcareous, poorly consolidated with significant tuffaceous/ argillaceous matrix; dominantly a sub-lithic arenite/ arenaceous claystone; soft to slightly firm; pulverulent, sectile; no definable fracture, structure or bedding; tabular to nodular cuttings habit with well rounded edges; dull, subwaxy, occasionally greasy luster; often contains carbonaceous detrital clasts, fragments, specks; indications of interbedded carbonaceous shale/ poorly developed coal. Tuffaceous Claystone, Carbonaceous Shale, Coal (8460’ to 8540') = claystone continues as described; coal is matte black to grayish black to dark gray; firm to moderately hard; dense, crunchy, crumbly in part; irregular, subplanar, rarely splintery fracture; tabular to subplaty cuttings habit, occasionally nodular; generally dull; shaley; no out gassing observed. Tuffaceous Claystone (8540’ to 8640') = light gray to medium light gray, medium gray in part; firm to soft, very soft in part; pasty to mushy, occasionally tacky to slimy; pulverulent, sectile; no definable fracture, structure or bedding; tabular, occasionally nodular cuttings habit; cuttings often with rounded to well rounded edges; generally dull to subwaxy, slightly greasy luster in part; dominantly smooth, non to slightly abrasive texture; noncalcareous; air dried samples readily hydrate, swell slightly and crumble; silty to sandy in part; note occasional carbonaceous shale/ poorly developed coal. Sandstone (8640' to 8760') = medium gray to light medium gray, occasional whitish gray; occasional dark medium gray; lower very fine to upper medium grained; framework predominantly colorless to white transparent to translucent quartz with up to 10% lithic and reworked sediment fragments; most grains moderately to moderate high sphericity; moderately rounded to slightly angular; moderately well to moderate poor sorting; common to occasional frosting of grain surfaces; poorly consolidated with weak slightly calcareous, argillaceous cementation; matrix material sparse to none; specimen presents with abundant loose grains and occasional preserved specimens; thinly interbedded with very thin beds of carbonaceous shale, occasional thin beds of coal, occasional beds tuffaceous sandstone; tuffaceous siltstone and tuffaceous claystone; NSOFC. Tuffaceous Siltstone (8760’ to 8980') = medium dark gray to medium dark gray, grayish brown to yellowish brown; slightly firm to moderately soft; moderately well indurated; tenacity moderately crumbly to slightly sticky with occasional slightly malleable; cuttings habit predominantly massive to somewhat wedge like with well rounded edges and corners; texture slightly silty to very silty with occasional specimens slightly gritty; luster slightly waxy to dull; somewhat tacky to malleable with occasional to common specimens showing PDC metamorphism; bedding very thin; occasional thin laminae to discontinuous stringers of carbonaceous material; thinly interbedded with carbonaceous shales, sandstone, and tuffaceous clay. Coal (8880’ to 8900') = black to very dark grayish black; very firm to slightly hard; well to moderately well indurated; tenacity crunchy to crumbly; cuttings habit sub blocky to curved to wedge like; fracture conchoidal; texture smooth; luster bright vitreous with occasional satiny to resinous; very thin bedded with bedding occasionally slightly to moderately distorted; associated w/ thinly bedded sandstones siltstones and clays w/ varying amount of tuffaceous component; NSOFC. Carbonaceous Shale (8980’ to 9060') = very dark dusky yellowish brown to moderate yellowish brown, dark grayish black to medium dark metallic gray; moderately soft to moderately firm; moderately well to poorly indurated; tenacity firmly crunchy to very crumbly, near earthy; cuttings habit sub tabular to sub blocky with common wedge like; texture very smooth to slightly silty and occasional slight grittiness due to entrained coal fragments; luster shiny metallic to dull and earthy; very thinly bedded. BCU 14A 12 Coal (9060’ to 9120') = black to very dark gray; dusky yellowish brown to very dark blackish brown, occasional moderate reddish brown; moderately soft to barely firm; moderately to poorly indurated; common flaky to crumbly with occasional moderately crunchy; luster dull to vitreous; fracture planar to conchoidal; very thinly bedded; no visible outgassing. Tuffaceous Claystone (9120’ to 9200') = very light gray to light gray, light bluish gray; firm; moderate induration; pulverulent, crumbly in part, malleable; no definable fracture, structure or bedding; tabular to nodular cuttings habit, often with well rounded edges; generally subwaxy to dull; massive, smooth, non- gritty nor abrasive; very tuffaceous in part; also yellowish gray to pale yellowish brown, grayish white with brownish hues; crumbly, crunchy; earthy with irregular, sometimes flakey cuttings habit; dull luster; silty to slightly sandy in part; generally with interlaminated carbonaceous layers, detrital fragments as flakes, clasts; in contact with low to high organic content sublithic shale/ coal. Coal, Carbonaceous Shale, Tuffaceous Claystone (9200’ to 9320') = coal/ shale is black to grayish black, dark gray, brownish black in part; firm to moderately hard; tough, dense, also brittle, slightly crunchy; irregular to hackly, splintery to subplanar fracture, occasional bird eye/ subconchoidal; hackly to platy, slightly equant cuttings habit varies from greasy to subvitreous, resinous to waxy, dull to matte luster; subfissile to fissile, banded; no outgassing observed. tuffaceous claystone is light gray to yellowish gray with yellowish brown hues, pale yellowish brown, minor light to medium light gray; firm; moderate to well indurated; malleable, sectile, crumbly to slightly crunchy in part; earthy, occasionally blocky fracture; nodular to tabular cuttings habit; no definable bedding or structure; subwaxy to dull, earthy luster; often silty to slightly sandy; earthier cuttings often in contact with layered coal, contain carbonaceous micro clasts, flakes, platy material. Tuffaceous Claystone, Tuffaceous Siltstone (9320’ to 9400') = pale yellowish brown to yellowish gray, light gray to slightly light bluish gray; firm to soft; malleable, sectile, crumbly in part, occasionally pulverulent; blocky to irregular, often earthy fracture; tabular to slightly nodular cuttings habit, often with rounded edges; varies from dull to earthy, waxy to subwaxy, occasionally greasy luster; massive, non gritty to very silty in part, occasionally sandy in part; noncalcareous; no apparent bedding or structure; note continued interbedded coal/ carbonaceous shale. Tuffaceous Claystone, Tuffaceous Siltstone (9400’ to 9450') = pale yellowish brown to yellowish gray, note decrease in gray to bluish gray cuttings; very soft to soft, rarely firm; mushy, slightly pasty in part; pulverulent; no definable fracture, cuttings habit, bedding or structure; dull, earthy; varies from smooth, massive to silty to slightly sandy in part; cuttings often contain random carbonaceous clasts believed to be recombined during processing; noncalcareous; continued interbedded coal as previously described. BCU 14A 13 3.3 Connection Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) No connection gases were observed. 3.4 Trip Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Trip to (feet) Maximum Gas (Units) Pumps Off Time (hours) 5121 Trip in with NB #1 (after mill) 0 7082 ft Wiper to 6100 ft 0 7420 ft Shoe at 5901 ft 0 8515 ft Wiper to 7496 ft 69 units 1.9 hrs 9540 ft Wiper to shoe after TD 175 units 16.5 hrs 9540 ft Clean out run after e-logs 246 units 39.9 hrs 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency* Interval Dispatched to A, B Washed and dried reference samples 20 ft 5100 ft – 9450 ft Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 Attn.: Debra Oudean (907) 777-8337 • Sample frequency may be locally altered according to drill rate constraints and zones of interest. BCU 14A 14 4 DRILLING DATA 4.1 Directional Survey Data Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 0 0 0 0 0 0 0 0 160 0.5 95.9 160.00 -0.07 0.69 0.36 0.31 191 0.2 184.6 191.00 -0.14 0.82 0.39 1.72 281 0.2 206.5 281.00 -0.44 0.74 0.10 0.08 403 0.3 186.6 403.00 -0.94 0.61 -0.38 0.11 552 0.5 188.0 551.99 -1.98 0.47 -1.29 0.13 672 0.8 187.6 671.98 -3.32 0.29 -2.47 0.25 795 0.8 193.3 794.97 -5.01 -0.02 -4.01 0.06 981 1.4 180.6 980.94 -8.55 -0.34 -7.02 0.35 1107 1.6 184.4 1106.89 -11.84 -0.49 -9.74 0.18 1233 1.8 182.0 1232.84 -15.57 -0.70 -12.83 0.17 1356 0.7 185.4 1355.81 -18.25 -0.84 -15.05 0.90 1482 0.4 281.5 1481.80 -18.93 -1.34 -15.90 0.67 1608 1.3 354.9 1607.79 -17.42 -1.90 -15.03 0.99 1733 1.3 1.2 1732.76 -14.59 -1.99 -12.83 0.11 1858 1.4 3.8 1857.72 -11.65 -1.86 -10.41 0.09 2071 1.4 8.7 2070.66 -6.48 -1.30 -5.95 0.06 2144 1.3 4.1 2143.64 -4.77 -1.10 -4.47 0.20 2206 1.8 5.2 2205.62 -3.10 -0.96 -3.05 0.81 2269 3.2 8.7 2268.56 -0.38 -0.61 -0.67 2.23 2333 5.0 13.0 2332.39 4.11 0.29 3.45 2.85 2396 7.6 15.0 2395.00 10.81 1.99 9.81 4.14 2458 10.4 18.9 2456.24 20.06 4.86 18.93 4.62 2520 12.7 25.5 2516.98 31.51 9.61 30.92 4.27 2582 13.7 34.0 2577.35 43.75 16.65 44.93 3.52 2645 13.7 34.7 2638.55 56.07 25.07 59.83 0.26 2709 14.0 35.2 2700.69 68.63 33.84 75.14 0.50 2771 15.0 33.7 2760.72 81.43 42.62 90.65 1.72 2834 16.0 32.7 2821.42 95.52 51.83 107.44 1.64 2897 16.3 31.5 2881.94 110.37 61.14 124.90 0.71 2960 17.3 27.3 2942.25 126.23 70.06 142.92 2.50 3023 18.1 25.5 3002.27 143.39 78.57 161.74 1.54 3085 19.9 25.3 3060.89 161.62 87.23 181.50 2.91 3147 21.5 26.0 3118.88 181.37 96.72 202.98 2.61 3210 22.9 28.0 3177.21 202.57 107.53 226.41 2.53 3273 24.4 29.1 3234.92 224.77 119.62 251.40 2.48 3335 25.5 29.8 3291.13 247.54 132.48 277.31 1.84 3398 27.2 29.6 3347.59 271.83 146.33 305.04 2.70 3461 29.9 30.8 3402.92 297.84 161.49 334.93 4.38 BCU 14A 15 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 3523 31.5 31.9 3456.23 324.87 177.96 366.42 2.73 3587 33.3 31.7 3510.27 354.01 196.03 400.56 2.82 3650 36.3 30.6 3561.99 384.78 214.61 436.31 4.86 3712 36.5 30.0 3611.90 416.55 233.17 472.84 0.66 3775 36.4 30.2 3662.57 448.93 251.95 509.99 0.25 3839 36.2 30.6 3714.15 481.61 271.12 547.62 0.48 3902 35.6 29.2 3765.18 513.63 289.53 584.26 1.61 3965 34.6 26.7 3816.73 545.62 306.52 620.01 2.78 4028 34.6 26.7 3868.59 577.58 322.59 655.20 0.00 4090 34.2 26.5 3919.74 608.90 338.28 689.63 0.67 4153 34.1 26.8 3971.88 640.51 354.14 724.41 0.31 4215 33.8 26.4 4023.31 671.47 369.64 758.45 0.60 4277 33.7 26.9 4074.86 702.26 385.09 792.32 0.48 4340 33.5 27.1 4127.34 733.32 400.92 826.64 0.36 4403 33.2 27.0 4179.96 764.17 416.67 860.74 0.48 4463 33.1 27.2 4230.20 793.37 431.62 893.04 0.25 4527 33.1 27.4 4283.81 824.43 447.65 927.48 0.17 4589 33.5 28.9 4335.63 854.44 463.71 961.10 1.48 4651 33.3 29.2 4387.39 884.28 480.28 994.89 0.42 4714 33.1 29.7 4440.11 914.32 497.24 1029.08 0.54 4778 33.2 30.1 4493.69 944.65 514.69 1063.79 0.38 4841 34.8 30.1 4545.92 975.13 532.35 1098.76 2.54 4904 35.1 30.2 4597.56 1006.34 550.48 1134.58 0.48 4968 34.2 30.4 4650.21 1037.76 568.84 1170.71 1.42 5031 34.1 31.3 4702.34 1068.12 586.97 1205.86 0.82 5081 34.26 30.82 4743.71 1092.18 601.47 1233.79 0.63 5120.09 34.74 33.10 4775.92 1110.96 613.19 1255.84 3.52 5181.45 34.26 36.68 4826.50 1139.46 633.05 1290.55 3.40 5241.81 34.21 40.19 4876.40 1166.05 654.15 1324.49 3.27 5304.13 33.07 44.55 4928.29 1191.56 677.39 1358.85 4.28 5366.96 32.84 46.48 4981.02 1215.5 701.77 1392.66 1.71 5429.00 32.13 45.92 5033.35 1238.57 725.82 1425.56 1.24 5491.21 31.79 46.06 5086.13 1261.44 749.50 1458.10 0.56 5552.79 30.34 45.69 5138.88 1283.57 772.31 1489.51 2.38 5614.80 28.97 45.15 5192.76 1305.10 794.17 1519.87 2.25 5677.04 27.10 45.37 5247.70 1325.69 814.95 1548.83 3.01 5739.46 25.97 43.78 5303.54 1345.55 834.52 1576.47 2.14 5801.28 24.00 44.09 5359.57 1364.35 852.64 1602.40 3.19 5863.14 22.50 45.12 5416.41 1381.74 869.78 1626.61 2.51 5924.54 21.22 44.95 5473.39 1397.89 885.95 1649.26 2.09 5985.96 20.25 45.69 5530.83 1413.19 901.41 1670.78 1.64 BCU 14A 16 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 6047.71 20.14 45.76 5588.79 1428.07 916.67 1691.86 0.18 6109.61 20.18 46.30 5646.90 1442.88 932.03 1712.93 0.31 6171.74 20.53 47.17 5705.15 1457.69 947.77 1734.24 0.74 6234.21 20.32 47.48 5763.69 1472.47 963.79 1755.70 0.38 6296.82 20.16 47.22 5822.43 1487.14 979.72 1777.02 0.29 6359.20 20.61 45.32 5880.91 1502.16 995.42 1798.47 1.28 6420.67 20.62 44.83 5938.44 1517.45 1010.75 1819.90 0.28 6483.33 20.25 44.77 5997.16 1532.97 1026.16 1841.59 0.59 6544.29 20.32 44.94 6054.34 1547.95 1041.07 1862.53 0.15 6605.86 20.96 45.25 6111.95 1563.27 1056.44 1884.02 1.05 6668.72 21.02 45.31 6170.64 1579.12 1072.44 1906.31 0.10 6729.85 20.94 45.08 6227.72 1594.54 1087.97 1927.98 0.19 6793.24 20.78 45.13 6286.95 1610.47 1103.96 1950.34 0.25 6854.38 20.76 45.03 6344.12 1625.78 1119.31 1971.81 0.07 6917.58 20.47 44.85 6403.27 1641.53 1135.03 1993.86 0.47 6979.17 20.29 44.80 6461.01 1656.74 1150.15 2015.11 0.29 7040.73 19.92 44.67 6518.82 1671.78 1165.04 2036.09 0.61 7102.00 20.18 46.30 6576.38 1686.50 1180.02 2056.87 1.01 7165.16 20.18 46.45 6635.66 1701.53 1195.79 2078.38 0.08 7227.83 19.95 46.61 6694.52 1716.32 1211.40 2099.59 0.38 7289.86 20.00 46.51 6752.82 1730.89 1226.78 2120.49 0.10 7352.04 19.79 45.92 6811.29 1745.54 1242.06 2141.39 0.47 7415.10 19.61 45.40 6870.66 1760.39 1257.26 2162.41 0.40 7476.17 19.59 45.55 6928.19 1774.76 1271.87 2182.68 0.09 7538.21 17.97 46.83 6986.93 1788.59 1286.27 2202.40 2.69 7601.90 16.92 46.32 7047.69 1801.71 1300.14 2221.24 1.67 7663.98 15.70 45.26 7107.27 1813.86 1312.64 2238.47 2.02 7724.79 14.33 44.61 7166.00 1825.01 1323.77 2254.08 2.27 7788.12 12.77 48.03 7227.57 1835.27 1334.48 2268.72 2.77 7850.07 11.01 48.73 7288.19 1843.76 1344.02 2281.24 2.85 7912.49 10.61 46.83 7349.50 1851.62 1352.69 2292.75 0.86 7973.41 10.37 46.54 7409.40 1859.23 1360.76 2303.68 0.40 8099.24 10.08 46.25 7533.23 1874.63 1376.93 2325.73 0.23 8159.41 10.03 45.55 7592.48 1881.94 1384.48 2336.11 0.22 8221.50 9.83 45.85 7653.64 1889.42 1392.14 2346.70 0.33 8284.89 9.84 44.87 7716.09 1897.03 1399.84 2357.42 0.26 8346.83 9.76 44.82 7777.13 1904.50 1407.28 2367.86 0.13 8409.86 9.75 43.97 7839.25 1912.13 1414.75 2378.46 0.23 8468.69 9.83 44.13 7897.22 1919.32 1421.71 2388.39 0.14 8530.38 9.54 44.45 7958.03 1926.75 1428.95 2398.69 0.48 8592.44 9.49 45.56 8019.24 1934.01 1436.21 2408.85 0.31 BCU 14A 17 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 8654.45 8.47 43.64 8080.49 1940.89 1443.01 2418.44 1.71 8716.86 7.75 41.77 8142.27 1947.36 1448.98 2427.20 1.23 8778.89 7.51 41.80 8203.76 1953.50 1454.47 2435.41 0.39 8841.09 7.46 40.92 8265.43 1959.58 1459.83 2443.49 0.20 8903.72 7.18 45.84 8327.55 1965.38 1465.30 2451.42 1.10 8965.38 6.88 45.70 8388.74 1970.64 1470.70 2458.88 0.49 9028.53 6.82 46.54 8451.44 1975.86 1476.13 2466.32 0.18 9090.34 6.89 46.35 8512.81 1980.94 1481.48 2473.60 0.12 9152.17 6.84 47.10 8574.20 1986.01 1486.86 2480.89 0.17 9212.39 6.84 46.80 8633.99 1990.91 1492.10 2487.95 0.06 9275.50 6.78 46.58 8696.65 1996.04 1497.55 2495.33 0.10 9337.05 6.76 46.51 8757.77 2001.03 1502.81 2502.49 0.04 9398.72 6.69 46.38 8819.02 2006.01 1508.05 2509.62 0.12 p. 9450.00 6.69 46.38 p. 8869.95 2010.13 1512.37 2515.52 0 BC U 1 4 A 18 4. 2 B i t R e c o r d Bi t S i z e M a k e Ty p e SN Je t s TF A De p t h In De p t h Ou t Fo o t a g e Dr i l l e d Bi t Ho u r s Av g . RO P (f t / h r ) Av g . WO B (kl b s ) Av g . RP M Avg. PP (psi) Grade 1 8 - 1 / 2 ” H D P S F X 5 6 5x 1 3 0. 6 4 8 1 51 2 1 ’ 9 4 5 0 ’ 4 3 2 9 ’ 6 5 . 5 7 6 6 6 7 9 2 1 1 9 3 - 2 - C T - A - X - I - B U - T D BC U 1 4 A 19 4. 3 Mu d R e c o r d Co n t r a c t o r : B a r o i d Mu d T y p e : E Z M u d 6 % K C l Da t e De p t h (f t ) MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T (p p b eq . ) pH Al k (P m ) Cl (mg/L) Ca (mg/L) 1/ 2 3 / 2 0 1 4 5 1 0 9 9 . 0 0 5 0 1 0 1 2 4 / 5 / 6 5 . 8 1 . 7 0 . 0 / 9 5 . 6 9 . 1 0 . 3 0 3 2 0 0 0 1 6 0 1/ 2 4 / 2 0 1 4 5 1 2 1 9 . 0 0 5 6 1 2 2 4 9 / 1 2 / 1 5 5 . 3 1 . 9 0 . 0 / 9 5 . 4 9 . 7 0 . 3 0 3 2 0 0 0 2 0 0 1/ 2 5 / 2 0 1 4 5 1 2 1 9 . 0 0 5 4 1 2 2 3 7 / 1 0 / 1 3 5 . 2 1 . 9 0 . 0 / 9 5 . 4 9 . 0 0 . 2 0 3 2 0 0 0 2 0 0 1/ 2 6 / 2 0 1 4 6 0 9 1 9 . 1 0 5 4 1 5 2 5 8 / 1 1 / 1 4 4 . 8 2 . 1 0 . 0 / 9 5 . 3 0 . 5 9 . 3 0 . 3 0 3 1 0 0 0 2 0 0 1/ 2 7 / 2 0 1 4 7 0 8 4 9 . 1 0 5 5 1 6 2 6 8 / 1 0 / 1 4 4 . 3 2 . 7 0 . 0 / 9 4 . 8 0 . 2 0 2 . 5 8 . 5 0 . 1 0 3 0 0 0 0 1 8 0 1/ 2 8 / 2 0 1 4 7 4 2 0 9 . 1 0 5 6 1 6 2 4 6 / 1 0 / 1 5 4 . 8 3 . 1 0 . 0 / 9 4 . 4 0 . 1 0 3 . 0 9 . 4 0 . 1 5 3 0 5 0 0 1 6 0 1/ 2 9 / 2 0 1 4 7 5 6 8 9 . 1 0 5 8 1 7 2 1 6 / 1 0 / 1 5 4 . 0 3 . 2 0 . 0 / 9 4 . 3 0 . 2 0 3 . 5 9 . 7 0 . 3 0 3 0 0 0 0 1 0 0 1/ 3 0 / 2 0 1 4 8 2 0 2 9 . 1 5 5 3 1 5 2 2 6 / 1 3 / 2 0 3 . 6 3 . 7 0 . 0 / 9 3 . 9 0 . 2 0 4 . 0 9 . 2 0 . 1 5 2 9 5 0 0 9 0 1/ 3 1 / 2 0 1 4 8 9 4 7 9 . 3 0 5 3 1 7 2 3 6 / 1 8 / 2 5 3 . 5 4 . 4 0 . 0 / 9 3 . 0 0 . 2 0 4 . 0 9 . 3 0 . 2 0 3 1 5 0 0 1 4 0 2/ 1 / 2 0 1 4 9 4 5 0 9 . 4 0 5 3 1 5 2 2 6 / 1 4 / 2 4 3 . 9 5 . 2 0 . 8 / 9 1 . 6 0 . 2 0 5 . 0 9 . 8 0 . 4 0 3 1 0 0 0 1 0 0 2/ 2 / 2 0 1 4 9 4 5 0 9 . 4 5 5 7 1 5 2 0 6 / 1 6 / 2 4 4 . 1 6 . 1 0 . 5 / 9 1 . 2 0 . 2 0 5 . 0 9 . 7 0 . 6 5 2 8 0 0 0 1 2 0 Ab b r e v i a t i o n s MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y P V = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = F i l t r a t e L o ss F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = C h l o r i d e s C a = H a r d n e s s BCU-14A 20 5 SHOW REPORTS BCU-14A 21 BCU-14A 22 BCU-14A 23 6 DAILY REPORTS HILCORP ALASKA, LLC KENAI PENINSULA, AK DAILY WELLSITE REPORT BCU 14A REPORT FOR: HILCORP ALASKA, LLC DATE: 1/24/2014 DEPTH 5109' PRESENT OPERATION: TIH W/ WHIPSTOCK TIME: MIDNIGHT YESTERDAY 5109' 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@5109' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD MW VIS PV YP Gels FL FC SOL NAF/W SD MBT pH ALK Cl- Ca+ 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) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Test BOPs and pick up drill pipe. Perform casing test @ 3000psi for 30 minutes, slip and cut drill line, level the derrrick and shim the sub; POOH with window mill. Pick up whipstock and trip in hole. CANRIG PERSONNEL ON BOARD: 2 = D. New and L. Resch __DAILY COST: $2478.00 REPORT BY: Donna New Page 1 of 1Daily Report 1/24/2014 mhtml:file://C:\Documents and Settings\EpochAdmin\My Docu ... HILCORP ALASKA, LLC Beaver creek Unit DAILY WELLSITE REPORT BCU 14A REPORT FOR: Rance Pederson DATE: Jan 24, 2014 DEPTH 5120 PRESENT OPERATION: Trip out TIME: 23:59 YESTERDAY 5080 24 HOUR FOOTAGE 40 CASING INFORMATION 9 5/8"@5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4841 34.80 30.10 4493.69 4904 35.10 30.20 4597.56 4968 34.20 30.40 4650.21 5031 34.10 31.30 4702.34 5081 34.26 30.82 4743.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 5.75" window mill 12492925 5081 5120 40 8.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 717.4 @ 5086.0 1.8 @ 5103.0 26.6 5.05 FT/HR SURFACE TORQUE 10908 @ 5087.0 6095 @ 5096.0 5963.4 6905.54 FT-LBS WEIGHT ON BIT 55 @ 5086.0 1 @ 5088.0 6.0 7.57 KLBS ROTARY RPM 86 @ 5115.0 75 @ 5087.0 66.4 79.19 RPM PUMP PRESSURE 1574 @ 5120.0 1094 @ 5086.0 1149.9 1574.55 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 5,121/4,776 MW 9.0 VIS 56 PV 12 YP 24 Gels 9/12/15 FL 5.3 FC 1.1 SOL 1.9 NAF/W 0.0/95.4 SD -- MBT -- pH 9.7 ALK 0.30 Cl- 32,000 Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 6 @ 5110.0 0 @ 5090.0 3.3 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 0 @ 5120.0 0 @ 5120.0 0.0 CONNECTION GAS HIGH N/A ETHANE (C-2) 0 @ 5120.0 0 @ 5120.0 0.0 CONNECTION GAS: AVG N/A PROPANE (C-3) 0 @ 5120.0 0 @ 5120.0 0.0 CONNECTION GAS: CURRENT N/A BUTANE (C-4) 0 @ 5120.0 0 @ 5120.0 0.0 CURRENT AVG BACKGROUND 4 / 3 PENTANE (C-5) 0 @ 5120.0 0 @ 5120.0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CEMENT CONTAMINATION DAILY ACTIVITY SUMMARY Mill window in casing plus 20' of rat hole from 5083' to 5120'. Rack back stand, rig up chart recorder and perform F.I.T. to 11.0ppg EMW with 495psi. Rig down chart recorder. Check flow, pump slug, and POOH. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3163.00 REPORT BY: Donna New Page 1 of 1Daily Report 1/25/2014 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY ... HILCORP ALASKA, LLC Beaver creek Unit DAILY WELLSITE REPORT BCU 14A REPORT FOR: Rance Pederson DATE: Jan 25, 2014 DEPTH 5120 PRESENT OPERATION: Trip in TIME: 23:59 YESTERDAY 5120 24 HOUR FOOTAGE 40 CASING INFORMATION 9 5/8"@5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4841 34.80 30.10 4493.69 4904 35.10 30.20 4597.56 4968 34.20 30.40 4650.21 5031 34.10 31.30 4702.34 5081 34.26 30.82 4743.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 5.75" window mill 12492925 5081 5120 40 8.3 3 8.5" HDBS FX56 12007303 5x13/0.6481 5120 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 5,121/4,785 MW 9.0 VIS 54 PV 12 YP 23 Gels 7/10/13 FL 5.2 FC 1/1 SOL 1.9 NAF/W 0.0/95.4 SD -- MBT -- pH 9.0 ALK 0.20 Cl- 32,000 Ca+ MWD SUMMARY INTERVAL TO TOOLS 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) @ @ CONNECTION GAS: AVG N/A PROPANE (C-3) @ @ CONNECTION GAS: CURRENT N/A BUTANE (C-4) @ @ CURRENT AVG BACKGROUND N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CEMENT CONTAMINATION DAILY ACTIVITY SUMMARY Trip out of hole and lay down BHA, Test BOPs; Pick up BHA and orient motor, download MWD, shallow pulse test; make up directional tools; trip into hole picking up singles, currently at 2610'. CANRIG PERSONNEL ON BOARD: 4 __DAILY COST: $3163.00 REPORT BY: Donna New Page 1 of 1Daily Report 1/26/2014 file://C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUME ... HILCORP ALASKA, LLC BEAVER CREEK UNIT DAILY WELLSITE REPORT BCU 14A REPORT FOR: RANCE PEDERSON DATE: Jan 26, 2014 DEPTH 6089 PRESENT OPERATION: Wiper trip TIME: 23:59 YESTERDAY 5120 24 HOUR FOOTAGE 969 CASING INFORMATION 9 5/8@5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5801.28 24.00 44.09 5359.57 5863.14 22.45 45.12 5416.41 5924.54 21.22 44.95 5473.39 5985.96 20.25 45.69 5530.83 6047.71 20.14 45.76 5588.79 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX56 12007303 5X13/0.6481 5120 (6089) 969 9.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 650.3 @ 5967.0 5.1 @ 5120.0 106.1 86.70 FT/HR SURFACE TORQUE 10345 @ 5166.0 1671 @ 5238.0 6026.7 9378.11 FT-LBS WEIGHT ON BIT 74 @ 5844.0 0 @ 5255.0 2.8 1.34 KLBS ROTARY RPM 79 @ 5120.0 2 @ 5238.0 45.1 72.95 RPM PUMP PRESSURE 1983 @ 5347.0 1437 @ 5234.0 1683.8 1868.42 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 6091/5630 MW 9.10 VIS 54 PV 15 YP 25 Gels 8/11/14 FL 4.8 FC 1/1 SOL 2.1 NAF/W 0.0/95.3 SD - MBT 0.5 pH 9.3 ALK 0.30 Cl- 31000 Ca+ MWD SUMMARY INTERVAL 5120 TO (6089) TOOLS MWD, Gamma and Directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 209 @ 5628.0 1 @ 5163.0 36.1 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 36072 @ 5636.0 179 @ 5163.0 6589.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 60 @ 5892.0 0 @ 5760.0 3.5 CONNECTION GAS: AVG 0 PROPANE (C-3) 0 @ 6089.0 0 @ 6089.0 0.0 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 6089.0 0 @ 6089.0 0.0 CURRENT AVG BACKGROUND 27 / 36 PENTANE (C-5) 0 @ 6089.0 0 @ 6089.0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY Unconsolidated sand 90%; conglomeritic sandstone 10% DAILY ACTIVITY SUMMARY Trip to bottom, orient tool faace and drill ahead alternately sliding and rotating, Drill to 6089' pull off bottom , pump sweep, circulate; rotate and work pipe for hole cleaning, short trip out of hole to 5135', tripping back to bottom. CANRIG PERSONNEL ON BOARD: Resch, New, Spiers, Boutte __DAILY COST: $3163.00 REPORT BY: Donna New HILCORP ALASKA, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU 14A REPORT FOR: Rance Pederson DATE: Jan 27, 2014 DEPTH 7082 PRESENT OPERATION: Tripping to bottom after wiper trip TIME: 23:59 YESTERDAY 6089 24 HOUR FOOTAGE 993 CASING INFORMATION 9 5/8@ 5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6793.24 20.78 45.13 6286.96 6854.38 20.76 45.03 6344.12 6917.58 20.47 44.85 6403.28 6979.17 20.29 44.80 6461.01 7040.73 19.92 44.67 6518.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX56 12007303 5X13/0.6481 5120 (7082) 1962 20.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 215.5 @ 6714.0 1.3 @ 6274.0 97.5 72.77 FT/HR SURFACE TORQUE 13440 @ 7046.0 8974 @ 6104.0 9663.1 11874.28 FT-LBS WEIGHT ON BIT 28 @ 7007.0 0 @ 7042.0 6.1 4.10 KLBS ROTARY RPM 81 @ 6263.0 70 @ 6800.0 71.8 73.96 RPM PUMP PRESSURE 2300 @ 6959.0 1652 @ 6330.0 1965.5 2155.96 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 7084/6560 MW 9.10 VIS 55 PV 16 YP 26 Gels 8/10/14 FL 4.3 FC 1/1 SOL 2.7 NAF/W 0/94.8 SD 0.20 MBT 2.5 pH 8.5 ALK 0.10 Cl- 30,000 Ca+ 180 MWD SUMMARY INTERVAL 5120 TO 7082 TOOLS MWD, Gamma and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 392 @ 6564.0 5 @ 6261.0 49.6 TRIP GAS -- CUTTING GAS @ @ WIPER GAS 29 CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 71145 @ 6564.0 812 @ 6089.0 9232.1 CONNECTION GAS HIGH 16 ETHANE (C-2) 88 @ 6565.0 4 @ 6545.0 2.1 CONNECTION GAS: AVG 1 PROPANE (C-3) 108 @ 6572.0 8 @ 6579.0 1.1 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 7082.0 0 @ 7082.0 0.0 CURRENT AVG BACKGROUND 8 / 50 PENTANE (C-5) 0 @ 7082.0 0 @ 7082.0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY 70% unconsolidated sand; 20% tuffaceous sandstone; 10% tuffaceous siltstone DAILY ACTIVITY SUMMARY Trip back to botom after wiper trip at 6089' and resume drilling ahead. Drill to 7083', circulate, pump sweep, make wiper trip to 6031'. Trip back to bottom and resume drilling. Drilling ahead. CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch, Fred Spiers, Justin Boutte __DAILY COST: $3163.00 REPORT BY: Donna New HILCORP ALASKA, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU 14A REPORT FOR: Rance Pederson DATE: Jan 28, 2014 DEPTH 7420 PRESENT OPERATION: Replacing Top Drive TIME: 23:59 YESTERDAY 7082 24 HOUR FOOTAGE 338 CASING INFORMATION 9 5/8"@5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7102 20.18 46.30 6576.37 7165 20.18 46.45 6635.66 7227 19.95 46.61 6694.52 7289 20.00 46.51 6752.82 7352 19.79 45.92 6811.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX56 12007303 5X13/0.6481 5120 (7420) 2300 25.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 152.3 @ 7111.0 2.7 @ 7392.0 80.6 81.61 FT/HR SURFACE TORQUE 15684 @ 7306.0 11472 @ 7392.0 12084.0 12367.81 FT-LBS WEIGHT ON BIT 37 @ 7208.0 3 @ 7415.0 15.9 4.10 KLBS ROTARY RPM 79 @ 7100.0 1 @ 7098.0 69.0 75.42 RPM PUMP PRESSURE 2421 @ 7400.0 1923 @ 7226.0 2178.0 2333.22 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 7084/6560 MW 9.10 VIS 56 PV 16 YP 24 Gels 6/10/15 FL 4.38 FC 1/2 SOL 3.1 NAF/W 0/94.4 SD 0.10 MBT 3.0 pH 9.4 ALK 0.105 Cl- 30,500 Ca+ 160 MWD SUMMARY INTERVAL 5120' TO 7420' TOOLS MWD, gamma and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 @ 7112.0 1 @ 7396.0 20.6 TRIP GAS -- CUTTING GAS @ @ WIPER GAS -- CHROMATOGRAPHY (ppm) SURVEY -- METHANE (C-1) 7119 @ 7112.0 214 @ 7396.0 4080.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 7419.0 0 @ 7419.0 0.0 CONNECTION GAS: AVG 0 PROPANE (C-3) 0 @ 7419.0 0 @ 7419.0 0.0 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 7419.0 0 @ 7419.0 0.0 CURRENT AVG BACKGROUND 0/20 PENTANE (C-5) 0 @ 7419.0 0 @ 7419.0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 60%; CONGLOMERITIC SANDSTONE 20%; UNCONSOLIDATED SAND 10%; TUFFACEOUS CLAYSTONE 10%. DAILY ACTIVITY SUMMARY Trip back to bottom after wiper trip and resume drilling, drill to 7420', troubleshoot leak in top drive, trip out to 5038', replacing top drive. CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch, Fred Spiers, Justin Boutte. __DAILY COST: $3163.00 REPORT BY: Donna New Hilcorp Alaska, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-14A REPORT FOR: Rance Pederson DATE: Jan 29, 2014 DEPTH 7566 PRESENT OPERATION: Drilling ahead TIME: 23:59 YESTERDAY 7420 24 HOUR FOOTAGE 146 CASING INFORMATION 95/8 @ 5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7102 20.18 46.30 6576.37 7165 20.18 46.45 6635.66 7227 19.95 46.61 6694.52 7289 20.00 46.51 6752.82 7352 19.79 45.92 6811.29 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX56 12007303 5X13/0.6481 5120 (7566) 2446 28.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 107.7 @ 7450.0 4.0 @ 7525.0 60.9 37.75 FT/HR SURFACE TORQUE 0 @ 7566.0 0 @ 7566.0 0.0 0.00000 FT-LBS WEIGHT ON BIT 36 @ 7537.0 3 @ 7422.0 6.7 9.73 KLBS ROTARY RPM 0 @ 7566.0 0 @ 7566.0 0.0 0.00000 RPM PUMP PRESSURE 2468 @ 7446.0 2037 @ 7544.0 2262.3 2156.10 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 7568/7015 MW 91.0 VIS 58 PV 17 YP 21 Gels 6/10/15 FL 4.0 FC 1/2 SOL 3.2 NAF/W 0/94.3 SD 0.20 MBT 3.5 pH 9.7 ALK 0.30 Cl- 30000 Ca+ 100 MWD SUMMARY INTERVAL 5120' TO 7566' TOOLS MWD, gamma and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 41 @ 7537.0 2 @ 7458.0 18.4 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 7125 @ 7508.0 493 @ 7458.0 3272.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 7566.0 0 @ 7566.0 0.0 CONNECTION GAS: AVG 0 PROPANE (C-3) 0 @ 7566.0 0 @ 7566.0 0.0 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 49 @ 7546.0 0 @ 7519.0 6.7 CURRENT AVG BACKGROUND 40 / 18 PENTANE (C-5) 194 @ 7561.0 0 @ 7519.0 16.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY Unconsolidated sand 80%; and tuffaceous sand 20% DAILY ACTIVITY SUMMARY Finish replacing top drive and return to drilling; drill to 7456' problem with hydraulic pump for the top drive work to replace; finish repairing top drive, return to bottom and drill ahead. CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch, Justin Boutte, Fred Spiers __DAILY COST: $3163.00 REPORT BY: Donna New Hilcorp Alaska, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-14A REPORT FOR: Rance Pederson DATE: Jan 31, 2014 DEPTH 8200 PRESENT OPERATION: Drilling ahead TIME: 23:59 YESTERDAY 7566 24 HOUR FOOTAGE 634 CASING INFORMATION 9 5/8" @ 5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7788.12 12.77 48.03 7227.57 7850.07 11.01 48.73 7288.19 7912.49 10.61 46.83 7349.50 7973.41 10.37 46.54 7409.40 8099.24 10.08 46.25 7533.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX56 12007303 5X13/0.6481 5120 8200 3080 42.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 133.8 @ 8142.0 4.2 @ 8003.0 56.2 57.78 FT/HR SURFACE TORQUE 18294 @ 8060.0 1753 @ 7793.0 9079.8 13416.81 FT-LBS WEIGHT ON BIT 74 @ 7658.0 0 @ 7901.0 16.0 22.35 KLBS ROTARY RPM 0 @ 8200.0 0 @ 8200.0 0.0 0.00 RPM PUMP PRESSURE 2446 @ 8163.0 1972 @ 7580.0 2228.4 2246.94 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8202/7634 MW 9.15 VIS 53 PV 15 YP 22 Gels 6/13/20 FL 3.6 FC 1/2 SOL 3.7 NAF/W 0/93.9 SD 0.20 MBT 4.0 pH 9.2 ALK 0.05 Cl- 29,500 Ca+ 90 MWD SUMMARY INTERVAL 5120' TO 8200' TOOLS MWD, gamma and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 163 @ 7812.0 0 @ 7940.0 24.4 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 29940 @ 7812.0 115 @ 7940.0 4480.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 217 @ 7807.0 5 @ 7799.0 3.4 CONNECTION GAS: AVG 0 PROPANE (C-3) 667 @ 8150.0 1 @ 8126.0 16.8 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 8200.0 0 @ 8200.0 0.0 CURRENT AVG BACKGROUND 36 / 24 PENTANE (C-5) 0 @ 8200.0 0 @ 8200.0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY @8200' = Tuffaceous clay 70%; Tuffaceous siltstone 30% DAILY ACTIVITY SUMMARY Drill ahead CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch, Fred Spiers, Justin Boutte __DAILY COST: $2878.00 REPORT BY: Donna New Hilcorp Alaska, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-14A REPORT FOR: Rance Pederson DATE: Jan 31, 2014 DEPTH 8946 PRESENT OPERATION: Drilling ahead TIME: 23:59 YESTERDAY 8200 24 HOUR FOOTAGE 746 CASING INFORMATION 9 5/8" @ 5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8530.38 9.54 44.45 7958.04 8592.44 9.49 45.56 8019.25 8654.45 8.47 43.64 8080.5 8716.86 7.75 41.77 8142.28 8778.89 7.51 41.8 8203.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX56 12007303 5X13/0.6481 5120 8946 3826 54.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 137.0 @ 8582.0 3.6 @ 8675.0 64.7 73.51 FT/HR SURFACE TORQUE 17297 @ 8816.0 1726 @ 8638.0 13404.4 15132.37 FT-LBS WEIGHT ON BIT 46 @ 8641.0 0 @ 8532.0 7.8 1.92 KLBS ROTARY RPM 0 @ 8946.0 0 @ 8946.0 0.0 0.00 RPM PUMP PRESSURE 2833 @ 8838.0 2051 @ 8325.0 2441.2 2682.03 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8947/8370 MW 9.30 VIS 53 PV 17 YP 23 Gels 6/18/25 FL 3.5 FC 1/2 SOL 4.4 NAF/W 0/93.0 SD 0.20 MBT 4.0 pH 9.3 ALK 0.20 Cl- 31,500 Ca+ 140 MWD SUMMARY INTERVAL 5120' TO 8946 TOOLS MWD, gamma and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 390 @ 8496.0 1 @ 8433.0 62.3 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 68491 @ 8496.0 190 @ 8433.0 10935.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 120 @ 8478.0 1 @ 8458.0 2.9 CONNECTION GAS: AVG 0 PROPANE (C-3) 82 @ 8487.0 5 @ 8499.0 1.4 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 8946.0 0 @ 8946.0 0.0 CURRENT AVG BACKGROUND 29 / 62 PENTANE (C-5) 0 @ 8946.0 0 @ 8946.0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY @8940' = Carbonaceous shale 30%, Tuffaceous siltstone30%, Tuffaceous Sandstone 20%, Sand 10%, Tuffaceous Clay10%, DAILY ACTIVITY SUMMARY Drill ahead CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch, Fred Spiers, __DAILY COST: $2878.00 REPORT BY: Donna New Hilcorp Alaska, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-14A REPORT FOR: Rance Pederson DATE: Feb 01, 2014 DEPTH 9450 PRESENT OPERATION: POOH TIME: 23:59 YESTERDAY 8946 24 HOUR FOOTAGE 504 CASING INFORMATION 9 5/8" @ 5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9212.39 6.84 46.80 8633.99 9275.50 6.78 46.58 8696.65 9337.05 6.76 46.51 8757.77 9398.72 6.69 46.38 8819.02 9450.00 6.69 46.38 8869.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS FX56 12007303 5X13/0.6481 5120 9450 4330 63.0 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 134.2 @ 9387 2.8 @ 9071 62.6 96.89 FT/HR SURFACE TORQUE 22720 @ 9145 14433 @ 8965 16425.5 16467.46 FT-LBS WEIGHT ON BIT 22 @ 8947 0 @ 9445 7.3 0.00 KLBS ROTARY RPM 0 @ 9450 0 @ 9450 0.0 0.00 RPM PUMP PRESSURE 2966 @ 9177 2577 @ 9319 2804.4 2864.65 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 8947/8370 MW 9.30 VIS 53 PV 17 YP 23 Gels 6/18/25 FL 3.5 FC 1/2 SOL 4.4 NAF/W 0/93.0 SD 0.20 MBT 4.0 pH 9.3 ALK 0.20 Cl- 31500 Ca+ 140 MWD SUMMARY INTERVAL 5120' TO 9450' TOOLS MWD, gamma, and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 220 @ 9279.0 15 @ 9243.0 47.9 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 43646 @ 9279.0 3041 @ 9131.0 9607.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 9450.0 0 @ 9450.0 0.0 CONNECTION GAS: AVG 0 PROPANE (C-3) 0 @ 9450.0 0 @ 9450.0 0.0 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 9450.0 0 @ 9450.0 0.0 CURRENT AVG BACKGROUND 2 / 48 PENTANE (C-5) 0 @ 9450.0 0 @ 9450.0 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Tuffaceous clay 60%; Tuffaceous siltstone 40% DAILY ACTIVITY SUMMARY Drill ahead to total depth at 9450', pump high vis sweep, POOH 10 stands and check well flow, continue to pull out of hole @ 6460' bit depth.. CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch, Fred Spiers, Justin Boutte __DAILY COST: $2878.00 REPORT BY: Donna New Hilcorp Alaska, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-14A REPORT FOR: REPORT FOR: Rance Pederson DATE: Feb 02, 2014 DEPTH 9450 PRESENT OPERATION: Rigging up wireline TIME: 23:59 YESTERDAY 9450 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9212.39 6.84 46.80 8633.99 9275.50 6.78 46.58 8696.65 9337.05 6.76 46.51 8757.77 9398.72 6.69 46.38 8819.02 9450.00 6.69 46.38 8869.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED Wireline assembly DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,450/8,870 MW 9.45 VIS 57 PV 15 YP 20 Gels 6/16/24 FL 4.1 FC 1/2 SOL 6.1 NAF/W 0.5/91.2 SD 0.20 MBT 5.0 pH 9.7 ALK 0.65 Cl- 28,000 Ca+ 120 MWD SUMMARY INTERVAL 9450' TO 9450' TOOLS Wireline GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 175 CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS: AVG N/A PROPANE (C-3) @ @ CONNECTION GAS: CURRENT N/A BUTANE (C-4) @ @ CURRENT AVG BACKGROUND N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Tuffaceous clay 60%; Tuffaceous siltstone 40% DAILY ACTIVITY SUMMARY POOH to bottom of window, build mud, trip to bottom, pump sweep and circulate the hole clean, Spot high vis mud, POOH 10 stands and blow down top drive, POOh and Lay down top drive, start rigging up wireline. CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch, Fred Spiers, __DAILY COST: $2878.00 REPORT BY: Donna New Hilcorp Alaska, LLC Beaver Creek Unit DAILY WELLSITE REPORT BCU-14A REPORT FOR: Rance Pederson DATE: Feb 03, 2014 DEPTH 9450 PRESENT OPERATION: Wiper trip TIME: 23:59 YESTERDAY 9450 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 5080' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9212.39 6.84 46.80 8633.99 9275.50 6.78 46.58 8696.65 9337.05 6.76 46.51 8757.77 9398.72 6.69 46.38 8819.02 9450.00 6.69 46.38 8869.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 8.5 ATMGT18 L841856 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,450/8,870 MW 9.30 VIS 45 PV 11 YP 15 Gels 5/11/15 FL 4.2 FC 1/2 SOL 4.7 NAF/W 0.5/92.5 SD 0.10 MBT 5.0 pH 9.0 ALK 0.25 Cl- 28,500 Ca+ 90 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 N/A ETHANE (C-2) @ @ CONNECTION GAS: AVG N/A PROPANE (C-3) @ @ CONNECTION GAS: CURRENT N/A BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 9 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Beluga Formation PRESENT LITHOLOGY Tuffaceous clay 60%; Tuffaceous siltstone 40% DAILY ACTIVITY SUMMARY Rig up wireline and make a wireline Quad Combo run. Rig down wireline and make up roller cone bit assembly for a clean out run and begin trip in. Currently tripping to bottom. Current gas is 9 units. CANRIG PERSONNEL ON BOARD: Donna New, Larry Resch __DAILY COST: $2193.00 REPORT BY: Donna New 2014-02-05 1 Company Hilcorp Alaska LLC Well Name Beaver Creek Unit-14A Field Name Beaver Creek Field Location SHL: 113' FSL 1388' FEL UWID 133205390100 Engineer's Name Josh Schultz Logging Date 03-Feb-2014 Report Date 02-05-2014 Prepared By Josh Schultz Run Number 1B PressureXpress Field Report Innovations in Formation Testing InSitu Pro* 3.1.0 * Mark of Schlumberger 2014-02-05 2 1 INTERPRETATION SUMMARY ............................................................................................................................................ 5 1.1 COMMENTS ............................................................................................................................................................................... 5 1.2 PRETEST SUMMARY TABLE ............................................................................................................................................................ 5 2 GRADIENT TABLE ............................................................................................................................................................... 7 3 TEST POINT TABLE ............................................................................................................................................................. 8 4 STATIONS ........................................................................................................................................................................ 10 4.1 XPT_009LTP 8478.92 FT MD .................................................................................................................................................. 10 4.1.1 Pressure vs. Time Plot .................................................................................................................................................... 10 4.1.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 11 4.2 XPT_010LTP 8489.88 FT MD .................................................................................................................................................. 12 4.2.1 Pressure vs. Time Plot .................................................................................................................................................... 12 4.2.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 13 4.3 XPT_011LTP 8496.97 FT MD .................................................................................................................................................. 14 4.3.1 Pressure vs. Time Plot .................................................................................................................................................... 14 4.3.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 15 4.4 XPT_012LTP 8490.91 FT MD .................................................................................................................................................. 16 4.4.1 Pressure vs. Time Plot .................................................................................................................................................... 16 4.4.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 17 4.5 XPT_013LTP 8517.88 FT MD .................................................................................................................................................. 18 4.5.1 Pressure vs. Time Plot .................................................................................................................................................... 18 4.6 XPT_014LTP 8518.95 FT MD .................................................................................................................................................. 19 4.6.1 Pressure vs. Time Plot .................................................................................................................................................... 19 4.6.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 20 4.7 XPT_015LTP 8545.93 FT MD .................................................................................................................................................. 21 4.7.1 Pressure vs. Time Plot .................................................................................................................................................... 21 4.7.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 22 4.8 XPT_016LTP 8544.9 FT MD .................................................................................................................................................... 23 4.8.1 Pressure vs. Time Plot .................................................................................................................................................... 23 4.8.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 24 4.9 XPT_017LTP 8556.85 FT MD .................................................................................................................................................. 25 4.9.1 Pressure vs. Time Plot .................................................................................................................................................... 25 4.9.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 26 4.10 XPT_018LTP 8559.99 FT MD ............................................................................................................................................... 27 4.10.1 Pressure vs. Time Plot ................................................................................................................................................. 27 4.10.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 28 4.11 XPT_019LTP 8656.94 FT MD ............................................................................................................................................... 29 4.11.1 Pressure vs. Time Plot ................................................................................................................................................. 29 4.11.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 30 4.12 XPT_020LTP 8717.95 FT MD ............................................................................................................................................... 31 4.12.1 Pressure vs. Time Plot ................................................................................................................................................. 31 4.12.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 32 4.13 XPT_021LTP 8723.95 FT MD ............................................................................................................................................... 33 4.13.1 Pressure vs. Time Plot ................................................................................................................................................. 33 4.13.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 34 4.14 XPT_022LTP 8730.83 FT MD ............................................................................................................................................... 35 4.14.1 Pressure vs. Time Plot ................................................................................................................................................. 35 4.14.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 36 4.15 XPT_023LTP 8752.95 FT MD ............................................................................................................................................... 37 4.15.1 Pressure vs. Time Plot ................................................................................................................................................. 37 4.16 XPT_024LTP 8753.97 FT MD ............................................................................................................................................... 38 4.16.1 Pressure vs. Time Plot ................................................................................................................................................. 38 4.16.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 39 4.17 XPT_028LTP 8402.02 FT MD ............................................................................................................................................... 40 4.17.1 Pressure vs. Time Plot ................................................................................................................................................. 40 4.17.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 41 4.18 XPT_029LTP 8400.92 FT MD ............................................................................................................................................... 42 4.18.1 Pressure vs. Time Plot ................................................................................................................................................. 42 4.18.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 43 4.19 XPT_030LTP 8391.92 FT MD ............................................................................................................................................... 44 4.19.1 Pressure vs. Time Plot ................................................................................................................................................. 44 2014-02-05 3 4.19.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 45 4.20 XPT_031LTP 8296 FT MD .................................................................................................................................................... 46 4.20.1 Pressure vs. Time Plot ................................................................................................................................................. 46 4.21 XPT_032LTP 8299.82 FT MD ............................................................................................................................................... 47 4.21.1 Pressure vs. Time Plot ................................................................................................................................................. 47 4.21.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 48 4.22 XPT_033LTP 8263.98 FT MD ............................................................................................................................................... 49 4.22.1 Pressure vs. Time Plot ................................................................................................................................................. 49 4.23 XPT_034LTP 8225.02 FT MD ............................................................................................................................................... 50 4.23.1 Pressure vs. Time Plot ................................................................................................................................................. 50 4.23.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 51 4.24 XPT_035LTP 8197.97 FT MD ............................................................................................................................................... 52 4.24.1 Pressure vs. Time Plot ................................................................................................................................................. 52 4.24.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 53 4.25 XPT_036LTP 8114.96 FT MD ............................................................................................................................................... 54 4.25.1 Pressure vs. Time Plot ................................................................................................................................................. 54 4.25.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 55 4.26 XPT_037LTP 8110.9 FT MD ................................................................................................................................................. 56 4.26.1 Pressure vs. Time Plot ................................................................................................................................................. 56 4.26.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 57 4.27 XPT_038LTP 8013.97 FT MD ............................................................................................................................................... 58 4.27.1 Pressure vs. Time Plot ................................................................................................................................................. 58 4.27.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 59 4.28 XPT_039LTP 8004.96 FT MD ............................................................................................................................................... 60 4.28.1 Pressure vs. Time Plot ................................................................................................................................................. 60 4.28.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 61 4.29 XPT_040LTP 8007.05 FT MD ............................................................................................................................................... 62 4.29.1 Pressure vs. Time Plot ................................................................................................................................................. 62 4.29.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 63 4.30 XPT_041LTP 7950.97 FT MD ............................................................................................................................................... 64 4.30.1 Pressure vs. Time Plot ................................................................................................................................................. 64 4.30.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 65 4.31 XPT_043LTP 6568.01 FT MD ............................................................................................................................................... 66 4.31.1 Pressure vs. Time Plot ................................................................................................................................................. 66 4.31.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 67 4.32 XPT_046LTP 5691.83 FT MD ............................................................................................................................................... 68 4.32.1 Pressure vs. Time Plot ................................................................................................................................................. 68 4.33 XPT_047LTP 5697.96 FT MD ............................................................................................................................................... 69 4.33.1 Pressure vs. Time Plot ................................................................................................................................................. 69 4.33.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 70 4.34 XPT_048LTP 5626 FT MD .................................................................................................................................................... 71 4.34.1 Pressure vs. Time Plot ................................................................................................................................................. 71 4.34.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 72 4.35 XPT_049LTP 5504.96 FT MD ............................................................................................................................................... 73 4.35.1 Pressure vs. Time Plot ................................................................................................................................................. 73 4.35.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 74 4.36 XPT_050LTP 5400 FT MD .................................................................................................................................................... 75 4.36.1 Pressure vs. Time Plot ................................................................................................................................................. 75 4.36.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 76 2014-02-05 4 DISCLAIMER ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED BY SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES ARE OPINIONS BASED ON INFERENCES FROM MEASUREMENTS, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS ARE NOT INFALLIBLE, AND WITH RESPECT TO WHICH PROFESSIONALS IN THE INDUSTRY MAY DIFFER. ACCORDINGLY, SCHLUMBERGER CANNOT AND DOES NOT WARRANT THE ACCURACY, CORRECTNESS OR COMPLETENESS OF ANY SUCH INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER ACKNOWLEDGES THAT IT IS ACCEPTING THE SERVICES "AS IS", THAT SCHLUMBERGER MAKES NO REPRESENTATION OR WARRANTY, EXPRESS OR IMPLIED, OF ANY KIND OR DESCRIPTION IN RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES THAT SCHLUMBERGER DOES NOT WARRANT THAT ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION IS FIT FOR A PARTICULAR PURPOSE, INCLUDING BUT NOT LIMITED TO COMPLIANCE WITH ANY GOVERNMENT REQUEST OR REGULATORY REQUIREMENT. CUSTOMER FURTHER ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE EXPLICIT UNDERSTANDING AND AGREEMENT THAT ANY ACTION TAKEN BASED ON THE SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBILITY AND NO CLAIM SHALL BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEREOF. 2014-02-05 5 1 Interpretation Summary 1.1 Comments -XPT ran with medium hole kit -Equipped with a standard probe and RFT packer -Time was not allotted to let the pressures fully stabilize 2014-02-05 6 1.2 Pretest Summary Table Table 1 Beaver Creek Unit-14A Beaver Creek Unit-14A Total Pretest Type Volumetric Drawdown Pretest 36 Pretest Status Valid Test 28 Tight Test 5 Unstabilized 2 Unrecognizable 1 Gauge QCP 36 Runs Color 1B (3-Feb-2014) 36 Formation Pressure Quality Color NA 5 Ungraded 31 Drawdown Mobility Quality Color NA 5 Ungraded 31 2014-02-05 7 2 Gradient Table Table 2 Gradient Summary Mud Before Formation Gradient Summary Well Name Gradient Top TVD Bottom TVD Top TVDSS Bottom TVDSS Density Color Gradient Comments Density Statistical Error Density Theoretical Error R2 Chi2 Probability STD Primary Gauge Repeatability Contact Depth SS psi/ft ft ft ft ft lbm/gal lbm/gal lbm/gal psi psi ft Beaver Creek Unit-14A 0.509 4876.99 8332.1 -4718.16 -8173.27 9.813 0.026 0.004 0.99994 0 3.849 QCP 0.1 Mud After Formation Gradient Summary Well Name Gradient Top TVD Bottom TVD Top TVDSS Bottom TVDSS Density Color Gradient Comments Density Statistical Error Density Theoretical Error R2 Chi2 Probability STD Primary Gauge Repeatability Contact Depth Contact Depth SS Contact Comments Contact Statistical Error Contact Theoretical Error psi/ft ft ft ft ft lbm/gal lbm/gal lbm/gal psi psi ft ft ft ft Beaver Creek Unit- 14A 0.51 4961.96 8255.11 -4803.13 -8096.28 9.817 0.024 0.004 0.99995 0 3.494 QCP 0.1 2014-02-05 8 3 Test Point Table Table 3 Pressure Related Results File No. Test No. Probe MD Probe TVD DD Mobility Mud Pres. Before Mud Pres. After Last BU Pres. Formation Pres. Temp. After Gauge Type Packer/Probe Type Pretest Type ft ft mD/cP psi psi psi psi degF 9 2 8478.92 7907.32 0.72 3937.511 3936.556 3313.856 3313.856 127.13 QCP Standard Volumetric Drawdown 10 4 8489.88 7918.11 0.57 3941.499 3941.122 3313.640 3313.640 128.41 QCP Standard Volumetric Drawdown 11 6 8496.97 7925.10 0.57 3944.376 3944.172 3300.492 3300.492 129.09 QCP Standard Volumetric Drawdown 12 8 8490.91 7919.13 1.59 3940.723 3940.570 3305.665 3305.665 129.61 QCP Standard Volumetric Drawdown 13 9 8517.88 7945.72 3954.833 3953.758 2038.443 129.97 QCP Standard Volumetric Drawdown 14 11 8518.95 7946.77 3.73 3953.472 3953.284 2610.842 2610.842 130.20 QCP Standard Volumetric Drawdown 15 13 8545.93 7973.38 1.12 3967.402 3966.587 3351.586 3351.586 130.37 QCP Standard Volumetric Drawdown 16 15 8544.90 7972.37 0.99 3965.771 3965.852 3355.820 3355.820 130.52 QCP Standard Volumetric Drawdown 17 17 8556.85 7984.15 0.33 3972.011 3971.135 3421.775 3421.775 130.70 QCP Standard Volumetric Drawdown 18 19 8559.99 7987.24 2.20 3972.748 3972.203 3340.461 3340.461 130.89 QCP Standard Volumetric Drawdown 19 21 8656.94 8082.96 0.35 4023.677 4019.770 3893.574 3893.574 131.08 QCP Standard Volumetric Drawdown 20 23 8717.95 8143.36 23.68 4051.723 4049.551 3268.178 3268.178 131.53 QCP Standard Volumetric Drawdown 21 25 8723.95 8149.31 39.74 4052.883 4051.820 3270.181 3270.181 131.77 QCP Standard Volumetric Drawdown 22 27 8730.83 8156.13 30.49 4056.482 4055.001 3272.192 3272.192 132.05 QCP Standard Volumetric Drawdown 23 28 8752.95 8178.06 4067.577 4065.554 3678.370 132.18 QCP Standard Volumetric Drawdown 24 29 8753.97 8179.06 0.16 4066.020 4065.750 3695.631 3695.631 132.29 QCP Standard Volumetric Drawdown 28 30 8402.02 7831.53 0.44 3889.978 3889.603 3663.401 3663.401 131.89 QCP Standard Volumetric Drawdown 29 31 8400.92 7830.45 0.31 3888.720 3888.452 3686.639 3686.639 131.59 QCP Standard Volumetric Drawdown 30 32 8391.92 7821.58 0.71 3883.111 3883.705 3764.417 3764.417 131.36 QCP Standard Volumetric 2014-02-05 9 File No. Test No. Probe MD Probe TVD DD Mobility Mud Pres. Before Mud Pres. After Last BU Pres. Formation Pres. Temp. After Gauge Type Packer/Probe Type Pretest Type Drawdown 31 34 8296.00 7727.06 3835.520 3835.362 1993.316 130.97 QCP Standard Volumetric Drawdown 32 36 8299.82 7730.82 5.31 3836.615 3836.021 2587.426 2587.426 130.64 QCP Standard Volumetric Drawdown 33 38 8263.98 7695.50 3817.907 3818.506 1986.442 130.49 QCP Standard Volumetric Drawdown 34 39 8225.02 7657.12 0.62 3798.191 3799.072 1872.336 1872.336 130.26 QCP Standard Volumetric Drawdown 35 42 8197.97 7630.47 0.83 3784.293 3784.862 1496.820 1496.820 130.12 QCP Standard Volumetric Drawdown 36 44 8114.96 7548.72 1.89 3742.913 3743.010 3121.160 3121.160 129.56 QCP Standard Volumetric Drawdown 37 45 8110.90 7544.73 2.21 3740.925 3740.716 3120.973 3120.973 129.31 QCP Standard Volumetric Drawdown 38 47 8013.97 7449.31 8.30 3691.715 3692.073 1988.344 1988.344 129.09 QCP Standard Volumetric Drawdown 39 49 8004.96 7440.44 0.98 3686.914 3687.425 1992.111 1992.111 128.82 QCP Standard Volumetric Drawdown 40 51 8007.05 7442.49 1.71 3687.622 3687.198 1982.245 1982.245 128.65 QCP Standard Volumetric Drawdown 41 53 7950.97 7387.33 1.15 3659.828 3660.064 1000.668 1000.668 128.53 QCP Standard Volumetric Drawdown 43 55 6568.01 6076.57 48.37 2996.823 2995.937 2600.704 2600.704 123.45 QCP Standard Volumetric Drawdown 46 59 5691.83 5260.88 2586.060 2582.227 579.988 115.26 QCP Standard Volumetric Drawdown 47 61 5697.96 5266.36 291.99 2585.261 2584.457 2068.421 2068.421 114.28 QCP Standard Volumetric Drawdown 48 63 5626.00 5202.58 28.44 2552.439 2552.242 2051.697 2051.697 113.77 QCP Standard Volumetric Drawdown 49 65 5504.96 5097.84 78.14 2499.307 2498.583 2049.626 2049.626 113.17 QCP Standard Volumetric Drawdown 50 67 5400.00 5008.83 74.60 2453.957 2453.287 2135.318 2135.318 112.39 QCP Standard Volumetric Drawdown 2014-02-05 10 4 Stations 4.1 XPT_009LTP 8478.92 ft MD 4.1.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:2 Probe MD:8478.92ft Probe TVD:7907.32ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_009LTP Beaver Creek Unit-14A Mud Before(3937.511psi)Start Drawdown(3313.602psi)Start Buildup(2399.603psi)Last Buildup(3313.856psi)Mud After(3936.556psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 2400 2600 2800 3000 3200 3400 3600 3800 4000 0 1 2 3 125.5 126.0 126.5 127.0 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3313.856 (psi) Last Read Buildup Pressure : 3313.856 (psi) Drawdown Mobility: 0.72 (mD/cP) Mud Pressure Before: 3937.511 (psi) Mud Pressure After: 3936.556 (psi) Temperature Before: 125.59 (degF) Temperature After: 127.13 (degF) Pretest Rate: 0.28 (cm3/s) Pretest Volume: 0.51 (cm3) Comments: 2014-02-05 11 4.1.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:2 Probe MD:8478.92ft Probe TVD:7907.32ft Delta Time 10 0 10 1 10 2 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2600 2800 3000 3200 Spherical Pressure(psi) Last Buildup Pressure: 3313.856 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 0.5 -0.0 2600 2800 3000 3200 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3313.856 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 12 4.2 XPT_010LTP 8489.88 ft MD 4.2.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:4 Probe MD:8489.88ft Probe TVD:7918.11ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_010LTP Beaver Creek Unit-14A Mud Before(3941.499psi)Start Drawdown(3453.51psi)Start Buildup(1917.312psi)Last Buildup(3313.64psi)Mud After(3941.122psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 2000 2500 3000 3500 4000 0 1 2 127.75 128.00 128.25 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3313.64 (psi) Last Read Buildup Pressure : 3313.64 (psi) Drawdown Mobility: 0.57 (mD/cP) Mud Pressure Before: 3941.499 (psi) Mud Pressure After: 3941.122 (psi) Temperature Before: 127.63 (degF) Temperature After: 128.41 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 1.15 (cm3) Comments: 2014-02-05 13 4.2.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:4 Probe MD:8489.88ft Probe TVD:7918.11ft Delta Time 10 0 10 1 10 2 310 410 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2000 2200 2400 2600 2800 3000 3200 Spherical Pressure(psi) Last Buildup Pressure: 3313.64 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 2000 2200 2400 2600 2800 3000 3200 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3313.64 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 14 4.3 XPT_011LTP 8496.97 ft MD 4.3.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:6 Probe MD:8496.97ft Probe TVD:7925.1ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_011LTP Beaver Creek Unit-14A Mud Before(3944.376psi)Start Drawdown(3171.633psi)Start Buildup(2073.865psi)Last Buildup(3300.492psi)Mud After(3944.172psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 2000 2500 3000 3500 4000 0.0 0.5 1.0 128.50 128.75 129.00 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Unstabilized Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3300.492 (psi) Last Read Buildup Pressure : 3300.492 (psi) Drawdown Mobility: 0.57 (mD/cP) Mud Pressure Before: 3944.376 (psi) Mud Pressure After: 3944.172 (psi) Temperature Before: 128.67 (degF) Temperature After: 129.09 (degF) Pretest Rate: 0.19 (cm3/s) Pretest Volume: 0.68 (cm3) Comments: 2014-02-05 15 4.3.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:6 Probe MD:8496.97ft Probe TVD:7925.1ft Delta Time 10 0 10 1 010 110 210 310 410 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2200 2400 2600 2800 3000 3200 Spherical Pressure(psi) Last Buildup Pressure: 3300.492 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 2200 2400 2600 2800 3000 3200 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3300.492 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 16 4.4 XPT_012LTP 8490.91 ft MD 4.4.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:8 Probe MD:8490.91ft Probe TVD:7919.13ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_012LTP Beaver Creek Unit-14A Mud Before(3940.723psi)Start Drawdown(3310.696psi)Start Buildup(2327.865psi)Last Buildup(3305.665psi)Mud After(3940.57psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 2000 2500 3000 3500 4000 0 5 10 129.00 129.25 129.50 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3305.665 (psi) Last Read Buildup Pressure : 3305.665 (psi) Drawdown Mobility: 1.59 (mD/cP) Mud Pressure Before: 3940.723 (psi) Mud Pressure After: 3940.57 (psi) Temperature Before: 129.16 (degF) Temperature After: 129.61 (degF) Pretest Rate: 0.25 (cm3/s) Pretest Volume: 9.93 (cm3) Comments: 2014-02-05 17 4.4.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:8 Probe MD:8490.91ft Probe TVD:7919.13ft Delta Time 10 0 10 1 10 2 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2400 2600 2800 3000 3200 Spherical Pressure(psi) Last Buildup Pressure: 3305.665 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 2 1 2400 2600 2800 3000 3200 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: 0.44 Ideal Slope: 0.5 Last Buildup Pressure: 3305.665 (psi) Extrapolated Pressure: 3313.761 (psi) Actual Radial Slope on Radial Derivative: 0.02 Ideal Slope: 0 Horizontal Mobility Thickness: 0.31 (mD.ft/cP) Radial Slope: -69.72 2014-02-05 18 4.5 XPT_013LTP 8517.88 ft MD 4.5.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:9 Probe MD:8517.88ft Probe TVD:7945.72ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_013LTP Beaver Creek Unit-14A Mud Before(3954.833psi)Start Drawdown(2892.184psi)Start Buildup(1888.619psi)Last Buildup(2038.443psi)Mud After(3953.758psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 2.2 2.4 2000 2500 3000 3500 4000 0.0 0.2 0.4 129.50 129.75 130.00 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : 2038.443 (psi) Drawdown Mobility: Mud Pressure Before: 3954.833 (psi) Mud Pressure After: 3953.758 (psi) Temperature Before: 129.68 (degF) Temperature After: 129.97 (degF) Pretest Rate: 0.16 (cm3/s) Pretest Volume: 0.48 (cm3) Comments: 2014-02-05 19 4.6 XPT_014LTP 8518.95 ft MD 4.6.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:11 Probe MD:8518.95ft Probe TVD:7946.77ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_014LTP Beaver Creek Unit-14A Mud Before(3953.472psi)Start Drawdown(3081.572psi)Start Buildup(1906.279psi)Last Buildup(2610.842psi)Mud After(3953.284psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 2000 2500 3000 3500 4000 0 1 2 3 129.75 130.00 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Unrecognizable Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 2610.842 (psi) Last Read Buildup Pressure : 2610.842 (psi) Drawdown Mobility: 3.73 (mD/cP) Mud Pressure Before: 3953.472 (psi) Mud Pressure After: 3953.284 (psi) Temperature Before: 129.92 (degF) Temperature After: 130.2 (degF) Pretest Rate: 0.41 (cm3/s) Pretest Volume: 0.75 (cm3) Comments: 2014-02-05 20 4.6.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:11 Probe MD:8518.95ft Probe TVD:8518.95ft Delta Time 10 0 10 1 210 310 410 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 1900 2000 2100 2200 2300 2400 2500 2600 Spherical Pressure(psi) Last Buildup Pressure: 2610.842 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 0.5 -0.0 1900 2000 2100 2200 2300 2400 2500 2600 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 2610.842 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 21 4.7 XPT_015LTP 8545.93 ft MD 4.7.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:13 Probe MD:8545.93ft Probe TVD:7973.38ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_015LTP Beaver Creek Unit-14A Mud Before(3967.402psi)Start Drawdown(3354.174psi)Start Buildup(2000.994psi)Last Buildup(3351.586psi)Mud After(3966.587psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 2000 2500 3000 3500 4000 0 130.0 130.2 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3351.586 (psi) Last Read Buildup Pressure : 3351.586 (psi) Drawdown Mobility: 1.12 (mD/cP) Mud Pressure Before: 3967.402 (psi) Mud Pressure After: 3966.587 (psi) Temperature Before: 130.15 (degF) Temperature After: 130.37 (degF) Pretest Rate: 0.24 (cm3/s) Pretest Volume: 3.78 (cm3) Comments: 2014-02-05 22 4.7.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:13 Probe MD:8545.93ft Probe TVD:7973.38ft Delta Time 10 0 10 1 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2000 2200 2400 2600 2800 3000 3200 3400 Spherical Pressure(psi) Last Buildup Pressure: 3351.586 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 2000 2200 2400 2600 2800 3000 3200 3400 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3351.586 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 23 4.8 XPT_016LTP 8544.9 ft MD 4.8.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:15 Probe MD:8544.9ft Probe TVD:7972.37ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_016LTP Beaver Creek Unit-14A Mud Before(3965.771psi)Start Drawdown(3354.457psi)Start Buildup(2005.997psi)Last Buildup(3355.82psi)Mud After(3965.852psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 2000 2500 3000 3500 4000 0 1 2 130.2 130.4 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3355.82 (psi) Last Read Buildup Pressure : 3355.82 (psi) Drawdown Mobility: 0.99 (mD/cP) Mud Pressure Before: 3965.771 (psi) Mud Pressure After: 3965.852 (psi) Temperature Before: 130.36 (degF) Temperature After: 130.52 (degF) Pretest Rate: 0.24 (cm3/s) Pretest Volume: 1.57 (cm3) Comments: 2014-02-05 24 4.8.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:15 Probe MD:8544.9ft Probe TVD:7972.37ft Delta Time 10 0 10 1 210 310 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1 -0 2200 2400 2600 2800 3000 3200 3400 Spherical Pressure(psi) Last Buildup Pressure: 3355.82 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 2200 2400 2600 2800 3000 3200 3400 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3355.82 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 25 4.9 XPT_017LTP 8556.85 ft MD 4.9.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:17 Probe MD:8556.85ft Probe TVD:7984.15ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_017LTP Beaver Creek Unit-14A Mud Before(3972.011psi)Start Drawdown(3440.833psi)Start Buildup(1972.816psi)Last Buildup(3421.775psi)Mud After(3971.135psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 2000 2500 3000 3500 4000 0 1 2 3 130.4 130.6 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3421.775 (psi) Last Read Buildup Pressure : 3421.775 (psi) Drawdown Mobility: 0.33 (mD/cP) Mud Pressure Before: 3972.011 (psi) Mud Pressure After: 3971.135 (psi) Temperature Before: 130.5 (degF) Temperature After: 130.7 (degF) Pretest Rate: 0.21 (cm3/s) Pretest Volume: 0.82 (cm3) Comments: 2014-02-05 26 4.9.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:17 Probe MD:8556.85ft Probe TVD:7984.15ft Delta Time 10 0 10 1 10 2 210 310 410 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2000 2200 2400 2600 2800 3000 3200 3400 Spherical Pressure(psi) Last Buildup Pressure: 3421.775 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 2000 2200 2400 2600 2800 3000 3200 3400 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3421.775 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 27 4.10 XPT_018LTP 8559.99 ft MD 4.10.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:19 Probe MD:8559.99ft Probe TVD:7987.24ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_018LTP Beaver Creek Unit-14A Mud Before(3972.748psi)Start Drawdown(3342.208psi)Start Buildup(2634.401psi)Last Buildup(3340.461psi)Mud After(3972.203psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 2000 2500 3000 3500 4000 0 10 20 130.50 130.75 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3340.461 (psi) Last Read Buildup Pressure : 3340.461 (psi) Drawdown Mobility: 2.2 (mD/cP) Mud Pressure Before: 3972.748 (psi) Mud Pressure After: 3972.203 (psi) Temperature Before: 130.69 (degF) Temperature After: 130.89 (degF) Pretest Rate: 0.25 (cm3/s) Pretest Volume: 9.97 (cm3) Comments: 2014-02-05 28 4.10.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:19 Probe MD:8559.99ft Probe TVD:7987.24ft Delta Time 10 0 10 1 10 2 12*10 14*10 16*10 18*10 210 22*10 24*10 26*10 28*10 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2700 2800 2900 3000 3100 3200 3300 Spherical Pressure(psi) Last Buildup Pressure: 3340.461 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 2 1 2700 2800 2900 3000 3100 3200 3300 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3340.461 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 29 4.11 XPT_019LTP 8656.94 ft MD 4.11.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:21 Probe MD:8656.94ft Probe TVD:8082.96ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_019LTP Beaver Creek Unit-14A Mud Before(4023.677psi)Start Drawdown(3817.99psi)Start Buildup(2004.772psi)Last Buildup(3893.574psi)Mud After(4019.77psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 2000 2500 3000 3500 4000 0 1 2 3 130.8 131.0 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Unstabilized Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3893.574 (psi) Last Read Buildup Pressure : 3893.574 (psi) Drawdown Mobility: 0.35 (mD/cP) Mud Pressure Before: 4023.677 (psi) Mud Pressure After: 4019.77 (psi) Temperature Before: 130.88 (degF) Temperature After: 131.08 (degF) Pretest Rate: 0.43 (cm3/s) Pretest Volume: 1.68 (cm3) Comments: 2014-02-05 30 4.11.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:21 Probe MD:8656.94ft Probe TVD:8082.96ft Delta Time 10 0 10 1 10 2 210 310 410 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2000 2500 3000 3500 Spherical Pressure(psi) Last Buildup Pressure: 3893.574 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 2000 2500 3000 3500 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3893.574 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 31 4.12 XPT_020LTP 8717.95 ft MD 4.12.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:23 Probe MD:8717.95ft Probe TVD:8143.36ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_020LTP Beaver Creek Unit-14A Mud Before(4051.723psi)Start Drawdown(3269.451psi)Start Buildup(3139.033psi)Last Buildup(3268.178psi)Mud After(4049.551psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 0 10 20 131.2 131.4 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3268.178 (psi) Last Read Buildup Pressure : 3268.178 (psi) Drawdown Mobility: 23.68 (mD/cP) Mud Pressure Before: 4051.723 (psi) Mud Pressure After: 4049.551 (psi) Temperature Before: 131.19 (degF) Temperature After: 131.53 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.77 (cm3) Comments: 2014-02-05 32 4.12.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:23 Probe MD:8717.95ft Probe TVD:8143.36ft Delta Time 10 0 10 1 10 2 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1 -0 3140 3160 3180 3200 3220 3240 3260 Spherical Pressure(psi) Last Buildup Pressure: 3268.178 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 -0 3140 3160 3180 3200 3220 3240 3260 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: 0.42 Ideal Slope: 0.5 Last Buildup Pressure: 3268.178 (psi) Extrapolated Pressure: 3268.303 (psi) Actual Radial Slope on Radial Derivative: 0.01 Ideal Slope: 0 Horizontal Mobility Thickness: 6.34 (mD.ft/cP) Radial Slope: -6.75 2014-02-05 33 4.13 XPT_021LTP 8723.95 ft MD 4.13.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:25 Probe MD:8723.95ft Probe TVD:8149.31ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_021LTP Beaver Creek Unit-14A Mud Before(4052.883psi)Start Drawdown(3270.082psi)Start Buildup(3193.571psi)Last Buildup(3270.181psi)Mud After(4051.82psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 0 10 20 131.4 131.6 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3270.181 (psi) Last Read Buildup Pressure : 3270.181 (psi) Drawdown Mobility: 39.74 (mD/cP) Mud Pressure Before: 4052.883 (psi) Mud Pressure After: 4051.82 (psi) Temperature Before: 131.52 (degF) Temperature After: 131.77 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.82 (cm3) Comments: 2014-02-05 34 4.13.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:25 Probe MD:8723.95ft Probe TVD:8149.31ft Delta Time 10 0 10 1 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1 -0 3210 3220 3230 3240 3250 3260 3270 Spherical Pressure(psi) Last Buildup Pressure: 3270.181 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 3210 3220 3230 3240 3250 3260 3270 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: 0.46 Ideal Slope: 0.5 Last Buildup Pressure: 3270.181 (psi) Extrapolated Pressure: 3270.421 (psi) Actual Radial Slope on Radial Derivative: 0.05 Ideal Slope: 0 Horizontal Mobility Thickness: 19.42 (mD.ft/cP) Radial Slope: -2.18 2014-02-05 35 4.14 XPT_022LTP 8730.83 ft MD 4.14.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:27 Probe MD:8730.83ft Probe TVD:8156.13ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_022LTP Beaver Creek Unit-14A Mud Before(4056.482psi)Start Drawdown(3272.029psi)Start Buildup(3173.004psi)Last Buildup(3272.192psi)Mud After(4055.001psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 3200 3400 3600 3800 4000 0 10 20 131.8 132.0 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3272.192 (psi) Last Read Buildup Pressure : 3272.192 (psi) Drawdown Mobility: 30.49 (mD/cP) Mud Pressure Before: 4056.482 (psi) Mud Pressure After: 4055.001 (psi) Temperature Before: 131.78 (degF) Temperature After: 132.05 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.83 (cm3) Comments: 2014-02-05 36 4.14.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:27 Probe MD:8730.83ft Probe TVD:8156.13ft Delta Time 10 0 10 1 010 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 3220 3230 3240 3250 3260 3270 Spherical Pressure(psi) Last Buildup Pressure: 3272.192 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 3220 3230 3240 3250 3260 3270 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3272.192 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 37 4.15 XPT_023LTP 8752.95 ft MD 4.15.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:28 Probe MD:8752.95ft Probe TVD:8178.06ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_023LTP Beaver Creek Unit-14A Mud Before(4067.577psi)Start Drawdown(3810.369psi)Start Buildup(1914.578psi)Last Buildup(3678.37psi)Mud After(4065.554psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 2000 2500 3000 3500 4000 0 1 2 131.8 132.0 132.2 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : 3678.37 (psi) Drawdown Mobility: Mud Pressure Before: 4067.577 (psi) Mud Pressure After: 4065.554 (psi) Temperature Before: 132.04 (degF) Temperature After: 132.18 (degF) Pretest Rate: 0.45 (cm3/s) Pretest Volume: 2.28 (cm3) Comments: 2014-02-05 38 4.16 XPT_024LTP 8753.97 ft MD 4.16.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:29 Probe MD:8753.97ft Probe TVD:8179.06ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_024LTP Beaver Creek Unit-14A Mud Before(4066.02psi)Start Drawdown(3074.531psi)Start Buildup(1874.82psi)Last Buildup(3695.631psi)Mud After(4065.75psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 2.2 2.4 2000 2500 3000 3500 4000 0.00 0.25 0.50 132.0 132.2 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3695.631 (psi) Last Read Buildup Pressure : 3695.631 (psi) Drawdown Mobility: 0.16 (mD/cP) Mud Pressure Before: 4066.02 (psi) Mud Pressure After: 4065.75 (psi) Temperature Before: 132.17 (degF) Temperature After: 132.29 (degF) Pretest Rate: 0.37 (cm3/s) Pretest Volume: 0.56 (cm3) Comments: 2014-02-05 39 4.16.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:29 Probe MD:8753.97ft Probe TVD:8179.06ft Delta Time 10 0 10 1 10 2 210 310 410 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2000 2500 3000 3500 Spherical Pressure(psi) Last Buildup Pressure: 3695.631 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 0.5 -0.0 2000 2500 3000 3500 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3695.631 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 40 4.17 XPT_028LTP 8402.02 ft MD 4.17.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:30 Probe MD:8402.02ft Probe TVD:7831.53ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_028LTP Beaver Creek Unit-14A Mud Before(3889.978psi)Start Drawdown(3677.639psi)Start Buildup(1935.483psi)Last Buildup(3663.401psi)Mud After(3889.603psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 2000 2500 3000 3500 4000 0.0 0.5 1.0 131.8 131.9 132.0 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3663.401 (psi) Last Read Buildup Pressure : 3663.401 (psi) Drawdown Mobility: 0.44 (mD/cP) Mud Pressure Before: 3889.978 (psi) Mud Pressure After: 3889.603 (psi) Temperature Before: 132.04 (degF) Temperature After: 131.89 (degF) Pretest Rate: 0.43 (cm3/s) Pretest Volume: 1.42 (cm3) Comments: 2014-02-05 41 4.17.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:30 Probe MD:8402.02ft Probe TVD:7831.53ft Delta Time 10 0 10 1 10 2 210 310 410 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2000 2500 3000 3500 Spherical Pressure(psi) Last Buildup Pressure: 3663.401 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 2000 2500 3000 3500 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3663.401 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 42 4.18 XPT_029LTP 8400.92 ft MD 4.18.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:31 Probe MD:8400.92ft Probe TVD:7830.45ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_029LTP Beaver Creek Unit-14A Mud Before(3888.72psi)Start Drawdown(3438.471psi)Start Buildup(1869.083psi)Last Buildup(3686.639psi)Mud After(3888.452psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 2000 2500 3000 3500 4000 0 131.5 131.6 131.7 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3686.639 (psi) Last Read Buildup Pressure : 3686.639 (psi) Drawdown Mobility: 0.31 (mD/cP) Mud Pressure Before: 3888.72 (psi) Mud Pressure After: 3888.452 (psi) Temperature Before: 131.73 (degF) Temperature After: 131.59 (degF) Pretest Rate: 0.35 (cm3/s) Pretest Volume: 0.74 (cm3) Comments: 2014-02-05 43 4.18.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:31 Probe MD:8400.92ft Probe TVD:7830.45ft Delta Time 10 0 10 1 10 2 210 310 410 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2000 2500 3000 3500 Spherical Pressure(psi) Last Buildup Pressure: 3686.639 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 0.5 -0.0 2000 2500 3000 3500 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3686.639 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 44 4.19 XPT_030LTP 8391.92 ft MD 4.19.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:32 Probe MD:8391.92ft Probe TVD:7821.58ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_030LTP Beaver Creek Unit-14A Mud Before(3883.111psi)Start Drawdown(3748.092psi)Start Buildup(2021.198psi)Last Buildup(3764.417psi)Mud After(3883.705psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 2000 2500 3000 3500 0 1 2 131.3 131.4 131.5 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3764.417 (psi) Last Read Buildup Pressure : 3764.417 (psi) Drawdown Mobility: 0.71 (mD/cP) Mud Pressure Before: 3883.111 (psi) Mud Pressure After: 3883.705 (psi) Temperature Before: 131.48 (degF) Temperature After: 131.36 (degF) Pretest Rate: 0.45 (cm3/s) Pretest Volume: 2.02 (cm3) Comments: 2014-02-05 45 4.19.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:32 Probe MD:8391.92ft Probe TVD:7821.58ft Delta Time 10 0 10 1 10 2 110 210 310 410 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 2200 2400 2600 2800 3000 3200 3400 3600 3800 Spherical Pressure(psi) Last Buildup Pressure: 3764.417 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 2200 2400 2600 2800 3000 3200 3400 3600 3800 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3764.417 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 46 4.20 XPT_031LTP 8296 ft MD 4.20.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:34 Probe MD:8296ft Probe TVD:7727.06ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_031LTP Beaver Creek Unit-14A Mud Before(3835.52psi)Start Drawdown(2557.216psi)Start Buildup(1477.458psi)Last Buildup(1993.316psi)Mud After(3835.362psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 1500 2000 2500 3000 3500 4000 0 130.75 131.00 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : 1993.316 (psi) Drawdown Mobility: Mud Pressure Before: 3835.52 (psi) Mud Pressure After: 3835.362 (psi) Temperature Before: 131.13 (degF) Temperature After: 130.97 (degF) Pretest Rate: 0.2 (cm3/s) Pretest Volume: 0.53 (cm3) Comments: 2014-02-05 47 4.21 XPT_032LTP 8299.82 ft MD 4.21.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:36 Probe MD:8299.82ft Probe TVD:7730.82ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_032LTP Beaver Creek Unit-14A Mud Before(3836.615psi)Start Drawdown(2588.001psi)Start Buildup(2029.971psi)Last Buildup(2587.426psi)Mud After(3836.021psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 2000 2500 3000 3500 4000 0 10 20 130.4 130.6 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 2587.426 (psi) Last Read Buildup Pressure : 2587.426 (psi) Drawdown Mobility: 5.31 (mD/cP) Mud Pressure Before: 3836.615 (psi) Mud Pressure After: 3836.021 (psi) Temperature Before: 130.71 (degF) Temperature After: 130.64 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.84 (cm3) Comments: 2014-02-05 48 4.21.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:36 Probe MD:8299.82ft Probe TVD:7730.82ft Delta Time 10 0 10 1 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2100 2200 2300 2400 2500 2600 Spherical Pressure(psi) Last Buildup Pressure: 2587.426 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 2100 2200 2300 2400 2500 2600 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: 0.42 Ideal Slope: 0.5 Last Buildup Pressure: 2587.426 (psi) Extrapolated Pressure: 2598.113 (psi) Actual Radial Slope on Radial Derivative: -0.02 Ideal Slope: 0 Horizontal Mobility Thickness: 0.47 (mD.ft/cP) Radial Slope: -91.05 2014-02-05 49 4.22 XPT_033LTP 8263.98 ft MD 4.22.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:38 Probe MD:8263.98ft Probe TVD:7695.5ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_033LTP Beaver Creek Unit-14A Mud Before(3817.907psi)Start Drawdown(1925.663psi)Start Buildup(928.349psi)Last Buildup(1986.442psi)Mud After(3818.506psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 1000 1500 2000 2500 3000 3500 0 130.00 130.25 130.50 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : 1986.442 (psi) Drawdown Mobility: Mud Pressure Before: 3817.907 (psi) Mud Pressure After: 3818.506 (psi) Temperature Before: 130.38 (degF) Temperature After: 130.49 (degF) Pretest Rate: 0.18 (cm3/s) Pretest Volume: 0.53 (cm3) Comments: 2014-02-05 50 4.23 XPT_034LTP 8225.02 ft MD 4.23.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:39 Probe MD:8225.02ft Probe TVD:7657.12ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_034LTP Beaver Creek Unit-14A Mud Before(3798.191psi)Start Drawdown(3755.929psi)Start Buildup(955.853psi)Last Buildup(1872.336psi)Mud After(3799.072psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 1000 1500 2000 2500 3000 3500 4000 0.0 0.5 1.0 1.5 129.75 130.00 130.25 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 1872.336 (psi) Last Read Buildup Pressure : 1872.336 (psi) Drawdown Mobility: 0.62 (mD/cP) Mud Pressure Before: 3798.191 (psi) Mud Pressure After: 3799.072 (psi) Temperature Before: 130.21 (degF) Temperature After: 130.26 (degF) Pretest Rate: 0.43 (cm3/s) Pretest Volume: 1.54 (cm3) Comments: 2014-02-05 51 4.23.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:39 Probe MD:8225.02ft Probe TVD:7657.12ft Delta Time 10 0 10 1 210 310 410 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 1000 1200 1400 1600 1800 Spherical Pressure(psi) Last Buildup Pressure: 1872.336 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 1000 1200 1400 1600 1800 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1872.336 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 52 4.24 XPT_035LTP 8197.97 ft MD 4.24.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:42 Probe MD:8197.97ft Probe TVD:7630.47ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_035LTP Beaver Creek Unit-14A Mud Before(3784.293psi)Start Drawdown(2077.361psi)Start Buildup(928.09psi)Last Buildup(1496.82psi)Mud After(3784.862psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 1000 1500 2000 2500 3000 3500 0.0 0.5 1.0 1.5 129.75 130.00 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 1496.82 (psi) Last Read Buildup Pressure : 1496.82 (psi) Drawdown Mobility: 0.83 (mD/cP) Mud Pressure Before: 3784.293 (psi) Mud Pressure After: 3784.862 (psi) Temperature Before: 130.02 (degF) Temperature After: 130.12 (degF) Pretest Rate: 0.38 (cm3/s) Pretest Volume: 0.58 (cm3) Comments: 2014-02-05 53 4.24.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:42 Probe MD:8197.97ft Probe TVD:7630.47ft Delta Time 10 0 10 1 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 1000 1100 1200 1300 1400 1500 Spherical Pressure(psi) Last Buildup Pressure: 1496.82 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 0.5 -0.0 1000 1100 1200 1300 1400 1500 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1496.82 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 54 4.25 XPT_036LTP 8114.96 ft MD 4.25.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:44 Probe MD:8114.96ft Probe TVD:7548.72ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_036LTP Beaver Creek Unit-14A Mud Before(3742.913psi)Start Drawdown(3116.87psi)Start Buildup(1477.063psi)Last Buildup(3121.16psi)Mud After(3743.01psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 1500 2000 2500 3000 3500 0 10 20 30 129.25 129.50 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3121.16 (psi) Last Read Buildup Pressure : 3121.16 (psi) Drawdown Mobility: 1.89 (mD/cP) Mud Pressure Before: 3742.913 (psi) Mud Pressure After: 3743.01 (psi) Temperature Before: 129.67 (degF) Temperature After: 129.56 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 19.89 (cm3) Comments: 2014-02-05 55 4.25.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:44 Probe MD:8114.96ft Probe TVD:7548.72ft Delta Time 10 0 10 1 110 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 1800 2000 2200 2400 2600 2800 3000 Spherical Pressure(psi) Last Buildup Pressure: 3121.16 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 2 1 1800 2000 2200 2400 2600 2800 3000 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3121.16 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 56 4.26 XPT_037LTP 8110.9 ft MD 4.26.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:45 Probe MD:8110.9ft Probe TVD:7544.73ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_037LTP Beaver Creek Unit-14A Mud Before(3740.925psi)Start Drawdown(3122.417psi)Start Buildup(1702.333psi)Last Buildup(3120.973psi)Mud After(3740.716psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 2000 2500 3000 3500 0 5 10 129.0 129.2 129.4 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 3120.973 (psi) Last Read Buildup Pressure : 3120.973 (psi) Drawdown Mobility: 2.21 (mD/cP) Mud Pressure Before: 3740.925 (psi) Mud Pressure After: 3740.716 (psi) Temperature Before: 129.36 (degF) Temperature After: 129.31 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.86 (cm3) Comments: 2014-02-05 57 4.26.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:45 Probe MD:8110.9ft Probe TVD:7544.73ft Delta Time 10 0 10 1 010 110 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 1800 2000 2200 2400 2600 2800 3000 Spherical Pressure(psi) Last Buildup Pressure: 3120.973 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 1800 2000 2200 2400 2600 2800 3000 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 3120.973 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 58 4.27 XPT_038LTP 8013.97 ft MD 4.27.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:47 Probe MD:8013.97ft Probe TVD:7449.31ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_038LTP Beaver Creek Unit-14A Mud Before(3691.715psi)Start Drawdown(1991.777psi)Start Buildup(1633.782psi)Last Buildup(1988.344psi)Mud After(3692.073psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 1500 2000 2500 3000 3500 0 10 20 30 128.75 129.00 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 1988.344 (psi) Last Read Buildup Pressure : 1988.344 (psi) Drawdown Mobility: 8.3 (mD/cP) Mud Pressure Before: 3691.715 (psi) Mud Pressure After: 3692.073 (psi) Temperature Before: 129.05 (degF) Temperature After: 129.09 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 19.9 (cm3) Comments: 2014-02-05 59 4.27.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:47 Probe MD:8013.97ft Probe TVD:7449.31ft Delta Time 10 0 10 1 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 1800 1850 1900 1950 Spherical Pressure(psi) Last Buildup Pressure: 1988.344 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 2 1 1800 1850 1900 1950 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1988.344 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 60 4.28 XPT_039LTP 8004.96 ft MD 4.28.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:49 Probe MD:8004.96ft Probe TVD:7440.44ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_039LTP Beaver Creek Unit-14A Mud Before(3686.914psi)Start Drawdown(3220.152psi)Start Buildup(928.995psi)Last Buildup(1992.111psi)Mud After(3687.425psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 1000 1500 2000 2500 3000 3500 0 1 2 128.4 128.6 128.8 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 1992.111 (psi) Last Read Buildup Pressure : 1992.111 (psi) Drawdown Mobility: 0.98 (mD/cP) Mud Pressure Before: 3686.914 (psi) Mud Pressure After: 3687.425 (psi) Temperature Before: 128.85 (degF) Temperature After: 128.82 (degF) Pretest Rate: 0.38 (cm3/s) Pretest Volume: 1.04 (cm3) Comments: 2014-02-05 61 4.28.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:49 Probe MD:8004.96ft Probe TVD:7440.44ft Delta Time 10 0 10 1 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 1000 1200 1400 1600 1800 2000 Spherical Pressure(psi) Last Buildup Pressure: 1992.111 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 1000 1200 1400 1600 1800 2000 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1992.111 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 62 4.29 XPT_040LTP 8007.05 ft MD 4.29.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:51 Probe MD:8007.05ft Probe TVD:7442.49ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_040LTP Beaver Creek Unit-14A Mud Before(3687.622psi)Start Drawdown(1984.384psi)Start Buildup(1001.892psi)Last Buildup(1982.245psi)Mud After(3687.198psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 1000 1500 2000 2500 3000 3500 0 2 4 128.25 128.50 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 1982.245 (psi) Last Read Buildup Pressure : 1982.245 (psi) Drawdown Mobility: 1.71 (mD/cP) Mud Pressure Before: 3687.622 (psi) Mud Pressure After: 3687.198 (psi) Temperature Before: 128.62 (degF) Temperature After: 128.65 (degF) Pretest Rate: 0.39 (cm3/s) Pretest Volume: 1.4 (cm3) Comments: 2014-02-05 63 4.29.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:51 Probe MD:8007.05ft Probe TVD:7442.49ft Delta Time 10 0 10 1 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 1200 1400 1600 1800 2000 Spherical Pressure(psi) Last Buildup Pressure: 1982.245 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 1200 1400 1600 1800 2000 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1982.245 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 64 4.30 XPT_041LTP 7950.97 ft MD 4.30.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:53 Probe MD:7950.97ft Probe TVD:7387.33ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_041LTP Beaver Creek Unit-14A Mud Before(3659.828psi)Start Drawdown(1043.52psi)Start Buildup(488.633psi)Last Buildup(1000.668psi)Mud After(3660.064psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 500 1000 1500 2000 2500 3000 3500 0 1 2 127.75 128.00 128.25 128.50 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 1000.668 (psi) Last Read Buildup Pressure : 1000.668 (psi) Drawdown Mobility: 1.15 (mD/cP) Mud Pressure Before: 3659.828 (psi) Mud Pressure After: 3660.064 (psi) Temperature Before: 128.33 (degF) Temperature After: 128.53 (degF) Pretest Rate: 0.37 (cm3/s) Pretest Volume: 1.01 (cm3) Comments: 2014-02-05 65 4.30.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:53 Probe MD:7950.97ft Probe TVD:7387.33ft Delta Time 10 0 10 1 110 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.0 0.5 -0.0 500 600 700 800 900 1000 Spherical Pressure(psi) Last Buildup Pressure: 1000.668 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1.0 0.5 -0.0 500 600 700 800 900 1000 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1000.668 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 66 4.31 XPT_043LTP 6568.01 ft MD 4.31.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:55 Probe MD:6568.01ft Probe TVD:6076.57ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_043LTP Beaver Creek Unit-14A Mud Before(2996.823psi)Start Drawdown(2600.409psi)Start Buildup(2417.914psi)Last Buildup(2600.704psi)Mud After(2995.937psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 2400 2500 2600 2700 2800 2900 3000 3100 0 10 20 30 123.5 124.0 124.5 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 2600.704 (psi) Last Read Buildup Pressure : 2600.704 (psi) Drawdown Mobility: 48.37 (mD/cP) Mud Pressure Before: 2996.823 (psi) Mud Pressure After: 2995.937 (psi) Temperature Before: 124.65 (degF) Temperature After: 123.45 (degF) Pretest Rate: 1.4 (cm3/s) Pretest Volume: 19.68 (cm3) Comments: 2014-02-05 67 4.31.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:55 Probe MD:6568.01ft Probe TVD:6076.57ft Delta Time 10 0 10 1 110 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2520 2540 2560 2580 2600 Spherical Pressure(psi) Last Buildup Pressure: 2600.704 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 -0 2520 2540 2560 2580 2600 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 2600.704 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 68 4.32 XPT_046LTP 5691.83 ft MD 4.32.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:59 Probe MD:5691.83ft Probe TVD:5260.88ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_046LTP Beaver Creek Unit-14A Mud Before(2586.06psi)Start Drawdown(1110.97psi)Start Buildup(566.801psi)Last Buildup(579.988psi)Mud After(2582.227psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 9 10 500 1000 1500 2000 2500 0 5 10 15 115 116 117 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : 579.988 (psi) Drawdown Mobility: Mud Pressure Before: 2586.06 (psi) Mud Pressure After: 2582.227 (psi) Temperature Before: 117.44 (degF) Temperature After: 115.26 (degF) Pretest Rate: 0.1 (cm3/s) Pretest Volume: 10.01 (cm3) Comments: 2014-02-05 69 4.33 XPT_047LTP 5697.96 ft MD 4.33.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:61 Probe MD:5697.96ft Probe TVD:5266.36ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_047LTP Beaver Creek Unit-14A Mud Before(2585.261psi)Start Drawdown(2124.107psi)Start Buildup(2058.657psi)Last Buildup(2068.421psi)Mud After(2584.457psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 2100 2200 2300 2400 2500 2600 0 10 20 30 114.25 114.50 114.75 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 2068.421 (psi) Last Read Buildup Pressure : 2068.421 (psi) Drawdown Mobility: 291.99 (mD/cP) Mud Pressure Before: 2585.261 (psi) Mud Pressure After: 2584.457 (psi) Temperature Before: 114.75 (degF) Temperature After: 114.28 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.85 (cm3) Comments: 2014-02-05 70 4.33.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:61 Probe MD:5697.96ft Probe TVD:5266.36ft Delta Time 10 0 10 1 -110 010 110 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2066.0 2066.5 2067.0 2067.5 2068.0 2068.5 Spherical Pressure(psi) Last Buildup Pressure: 2068.421 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 2066.0 2066.5 2067.0 2067.5 2068.0 2068.5 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 2068.421 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 71 4.34 XPT_048LTP 5626 ft MD 4.34.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:63 Probe MD:5626ft Probe TVD:5202.58ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_048LTP Beaver Creek Unit-14A Mud Before(2552.439psi)Start Drawdown(2051.989psi)Start Buildup(1947.111psi)Last Buildup(2051.697psi)Mud After(2552.242psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 1800 1900 2000 2100 2200 2300 2400 2500 2600 0 10 20 30 113.7 113.8 113.9 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 2051.697 (psi) Last Read Buildup Pressure : 2051.697 (psi) Drawdown Mobility: 28.44 (mD/cP) Mud Pressure Before: 2552.439 (psi) Mud Pressure After: 2552.242 (psi) Temperature Before: 113.91 (degF) Temperature After: 113.77 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.89 (cm3) Comments: 2014-02-05 72 4.34.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:63 Probe MD:5626ft Probe TVD:5202.58ft Delta Time 10 0 10 1 010 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2000 2010 2020 2030 2040 2050 Spherical Pressure(psi) Last Buildup Pressure: 2051.697 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 2000 2010 2020 2030 2040 2050 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 2051.697 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 73 4.35 XPT_049LTP 5504.96 ft MD 4.35.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:65 Probe MD:5504.96ft Probe TVD:5097.84ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_049LTP Beaver Creek Unit-14A Mud Before(2499.307psi)Start Drawdown(2049.983psi)Start Buildup(1926.917psi)Last Buildup(2049.626psi)Mud After(2498.583psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 1800 1900 2000 2100 2200 2300 2400 2500 0 10 20 30 113.1 113.2 113.3 113.4 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 2049.626 (psi) Last Read Buildup Pressure : 2049.626 (psi) Drawdown Mobility: 78.14 (mD/cP) Mud Pressure Before: 2499.307 (psi) Mud Pressure After: 2498.583 (psi) Temperature Before: 113.39 (degF) Temperature After: 113.17 (degF) Pretest Rate: 1.76 (cm3/s) Pretest Volume: 19.49 (cm3) Comments: 2014-02-05 74 4.35.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:65 Probe MD:5504.96ft Probe TVD:5097.84ft Delta Time 10 0 10 1 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 1960 1980 2000 2020 2040 Spherical Pressure(psi) Last Buildup Pressure: 2049.626 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 1960 1980 2000 2020 2040 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 2049.626 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: 2014-02-05 75 4.36 XPT_050LTP 5400 ft MD 4.36.1 Pressure vs. Time Plot Pressure vs. Time Plot Run No:1B Test No:67 Probe MD:5400ft Probe TVD:5008.83ft 3-FEB-2014 Hilcorp Alaska LLC Beaver Creek XPT_050LTP Beaver Creek Unit-14A Mud Before(2453.957psi)Start Drawdown(2135.74psi)Start Buildup(2027.747psi)Last Buildup(2135.318psi)Mud After(2453.287psi) p s i c m 3 d e g F ETIM_XPT (min) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 1900 2000 2100 2200 2300 2400 0 10 20 30 112.4 112.6 QCP(psi), CQG Pressure With Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure With Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard probe Primary Gauge: QCP Formation Pressure: 2135.318 (psi) Last Read Buildup Pressure : 2135.318 (psi) Drawdown Mobility: 74.6 (mD/cP) Mud Pressure Before: 2453.957 (psi) Mud Pressure After: 2453.287 (psi) Temperature Before: 112.72 (degF) Temperature After: 112.39 (degF) Pretest Rate: 1.75 (cm3/s) Pretest Volume: 19.48 (cm3) Comments: 2014-02-05 76 4.36.2 FRID, Spherical and Radial Specialized Plots Flow Regime ID Plot Run No:1B Test No:67 Probe MD:5400ft Probe TVD:5008.83ft Delta Time 10 0 10 1 -210 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1 -0 2080 2090 2100 2110 2120 2130 Spherical Pressure(psi) Last Buildup Pressure: 2135.318 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Radial Specialized Plot Radial Time Function 1 -0 2080 2090 2100 2110 2120 2130 Radial Pressure(psi) Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 2135.318 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: