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Home My WebLink About214-038DATA SUBMITTAL COMPLIANCE REPORT 4/30/2020 Permit to Drill 2140380 Well Name/No. SOLDOTNA CK UNIT 44-05 Operator Hilcorp Alaska, LLC API No. 50-133-20276-01-00 MD 11200 TVD 10923 Completion Date 6/14,/22014 Completion Status 1 -OIL Current Status P&A UIC No REQUIRED INFORMATION Mud Log No '(�,5� f� Samples No /5-11 Survey Yes v„' \Directional l No �0 DATA INFORMATION List of Logs Obtained: GR/RES/Neu/Den, mudlogs, CBL (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received _ Comments ED C 24293 Digital Data 9375 11202 5/21/2014 Electronic Data Set, Filename: SCU 44- 05_ final_export.las ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 MD.cgm ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 TVD.cgm ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05_final_export.dlis ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05_final_export.ver ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 MD.emf ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 TVD.emf ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 MD.pdf ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 TVD.pdf ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 MD.tif ED C 24293 Digital Data 5/21/2014 Electronic File: SCU 44-05 TVD.tif Log C 24293 Log Header Scans 0 0 2140380 SOLDOTNA CK UNIT 44-05 LOG HEADERS Log C 24294 Log Header Scans 0 0 2140380 SOLDOTNA CK UNIT 44-05 LOG HEADERS ED C 24294 Digital Data 5/21/2014 Electronic File: SCU 44-05 - GIS Format.txt ED C 24294 Digital Data 5/21/2014 Electronic File: SCU 44-05 Definitive Surveys.txt ED C 24294 Digital Data 5/21/2014 Electronic File: SCU 44-05 Surveys.xlsm ED C 24294 Digital Data 7/18/2014 Electronic File: SCU 44-05 - Definitive Survey Report Signed.pdf ED C 24294 Digital Data 5/21/2014 Electronic File: SCU 44-05 final survey.xlsx AOGCC Page I of 6 Thursday, April 30, 2020 DATA SUBMITTAL COMPLIANCE REPORT 4/30/2020 Permit to Drill 2140380 Well Name/No. SOLDOTNA CK UNIT 44-05 Operator Hilcorp Alaska, LLC API No. 50-133-20276-01-00 MD 11200 TVD 10923 Completion Date 6/14/2014 Completion Status 1-0I1- Current Status P&A UIC No ED C 24295 Digital Data 9201 11250 5/21/2014 Electronic Data Set, Filename: SCU_44-05.las ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Final Well Report 5- 11-2014.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44-05.dbf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44-05.mdx ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44-05_SCL.DBF ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44-05_SCL.MDX ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44-05_tvd.dbf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44-05_tvd.mdx ED C 24295 Digital Data 5/21/2014 Electronic File: scu_44-05.hdr ED C 24295 Digital Data 5/21/2014 Electronic File: scu_44-05r.dbf ED C 24295 Digital Data 5/21/2014 Electronic File: scu_44-05r.mdx ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report _04-13- 2014. pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report_04-14- 2014.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report _04-15- 2014.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report _04-16- 2014. pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report_04-17- 2014.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report_04-18- 2014.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report_04-19- 2014.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report _04-20- 2014.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report_04-21- 2014. pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05—Daily Report_set.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 tin Formation Log MD.pdf AOGCC Page 2 of 6 Thursday, April 30, 2020 DATA SUBMITTAL COMPLIANCE REPORT 4/30/2020 Permit to Drill 2140380 Well Name/No. SOLDOTNA CK UNIT 44-05 Operator Hilcorp Alaska, LLC API No. 50-133-20276-01-00 MD 11200 TVD 10923 Completion Date 6/14/2014 Completion Status 1-0I1- Current Status P&A UIC No ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 tin Formation Log TVD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 5in Formation Log MD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 5in Formation Log TVD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 Drilling Dynamics Log MD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 Drilling Dynamics Log TVD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 Gas Ratio Log MD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 Gas Ratio Log TVD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 LWD Combo Log MD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 LWD Combo Log TVD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 QFT II Combo Log MD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU 44-05 QFT II Combo Log TVD.pdf ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44- 05_2i n_Form ation_Log_M D.j pg ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44- 05_2 i n_Form ation_Log_M D.tif ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44- 05_2 i n_Fo rm at i o n_Log_T V D.j pg ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44- 05_2i n_Form ation_Log_T VD. of ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44- 05_5i n_Form ation_Log_M D.j pg ED C 24295 Digital Data 5/21/2014 Electronic File: SCU_44- 05_5in_Formation_Log_MD.tif ED C 24295 Digital Data 5/21/2014 Electronic File: SCU _44- 05-5in—Form ation_Log_TVD.jpg AOGCC Page 3 of 6 Thursday, April 30, 2020 DATA SUBMITTAL COMPLIANCE REPORT 4/30/2020 Permit to Drill 2140380 Well Name/No. SOLDOTNA CK UNIT 44-05 Operator Hilcorp Alaska, LLC MD 11200 TVD 10923 ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data API No. 50-133-20276-01-00 Completion Date 6/14/2014 Completion Status 1-0I1- Current Status P&A UIC No 5/21/2014 Electronic File: SCU_44- 05_5in_Formation_Log_TV D.tif 5/21/2014 Electronic File: SCU_44- 05_Drilling_Dynam ics_Log_MD.jpg 5/21/2014 Electronic File: SCU-44- 05_ Drilling_Dynam ics_Log_MD.tif 5/21/2014 Electronic File: SCU_44- 05_Drilling_Dynam ics_Log_TVD.jpg 5/21/2014 Electronic File: SCU_44- 05_Drilli ng_Dynam ics_Log_TVD.tif 5/21/2014 Electronic File: SCU_44- 05_G a s_R ati o_Log_M D.j pg 5/21/2014 Electronic File: SCU_44- 05_Gas_Ratio_Log_M D.tif 5/21/2014 Electronic File: SCU_44- 05_Gas_Ratio_Log_TV D.j pg 5/21/2014 Electronic File: SCU_44- 05_G as_Ratio_Log_TVD.tif 5/21/2014 Electronic File: SCU_44- 05_LW D_Combo_Log_MD.jpg 5/21/2014 Electronic File: SCU_44- 05_LW D_Combo_Log_MD.tif 5/21/2014 Electronic File: SCU_44- 05_LW D_Combo_Log_TVD.jpg 5/21/2014 Electronic File: SCU_44- 05_LW D_Com bo_Log_TVD.tif 5/21/2014 Electronic File: SCU 44-05—OIL SHOW QUALITY.As 5/21/2014 Electronic File: SCU 44-05_Pixler #1 10575- 10600.pdf 5/21/2014 Electronic File: SCU 44-05_Pixler#2 10678- 10735. pdf 5/21/2014 Electronic File: SCU 44-05_Pixler#3 10747- 10772.pdf 5/21/2014 Electronic File: SCU 44-05 Pixler#4 10786- 10881.pdf AOGCC Page 4 of 6 Thursday, April 30, 2020 DATA SUBMITTAL COMPLIANCE REPORT 4/30/2020 Permit to Drill 2140380 Well Name/No. SOLDOTNA CK UNIT 44-05 MD 11200 TVD 10923 Completion Date 6/14/2014 ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data ED C 24295 Digital Data Log C 24295 Log Header Scans ED C 25013 Digital Data Log C 25013 Log Header Scans Well Cores/Samples Information: Name Cuttings INFORMATION RECEIVED Completion Report Y Production Test Information Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: 6/14/2014 Release Date: 3/17/2014 Interval Start Stop 9440 11201 Operator Hilcorp Alaska, LLC API No. 50-133-20276-01-00 Completion Status 1 -OIL Current Status PBA UIC No Directional / Inclination Data Y Mechanical Integrity Test Information Y / NA Daily Operations Summary Y 5/21/2014 Electronic File: SCU 44-05—Show Report #1_10575-10600.pdf 5/21/2014 Electronic File: SCU 44-05—Show Report #2_10678-10735.pdf 5/21/2014 Electronic File: SCU 44-05—Show Report #3_10747-10772.pdf 5/21/2014 Electronic File: SCU 44-05—Show Report #4_10786-10881.pdf 5/21/2014 Electronic File: SCU 44-05—Show Report Data_Gas-Depth.xls 5/21/2014 Electronic File: SCU 44-05—Show Report set.pdf 5/21/2014 Electronic File: SRU 44-05—Post Drill Tops_Show Intervals.xls 0 0 2140380 SOLDOTNA CK UNIT 44-05 LOG HEADERS 10/28/2014 Electronic File: SCU44-05 4.51N CBL 2-JUN- 14.pdf 0 0 2140380 SOLDOTNA CK UNIT 44-05 LOG HEADERS Sample Set Sent Received Number Comments 8/20/2014 1487 Mud Logs, Image Files, Digital Data Y / NA Core Chips Y / NA Composite Logs, Image, Data Files Y Core Photographs Y / NA Cuttings Samples Y / NA Laboratory Analyses Y / NA AOGCC Page 5 of 6 Thursday, April 30, 2020 DATA SUBMITTAL COMPLIANCE REPORT 4/30/2020 Permit to Drill 2140380 Well Name/No. SOLDOTNA CK UNIT 44-05 Operator Hilcorp Alaska, LLC API No. 50-133-20276-01-00 MD 11200 TVD 10923 Completion Date 6/14/2014 Completion Status 1-0I1- Current Status P&A UIC No Description Date Comments Comments: Compliance Reviewed By: Date: 3 0 AOGCC Page 6 of 6 Thursday, April 30, 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Z - 3 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned J • Suspended , 20AAC 25.105 20AAC 25 110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1b. Well Class: 't Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 5. Date Com Su ., or (Abaha): 11/21/2014 12. Permit to Drill Number. 214-038 / 314-576 13. API Number: 50-133-20276-01 3. Address: 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 6. Dago Spudded: 4/12/2014 4a. Location of Well (Governmental Section): Surface: 3323' FNL, 571' FEL, Sec. 5, T7N, R9W, SM, AK Top of Productive Horizon: Total Depth: 1156' FSL, 673' FEL, Sec. 5, T7N, R9W, SM, AK 7. Date TD Reached: 4/23/2014 14. Well Name and Number: Soldotna Creek Unit (SCU) 44-05 8. KB (ft above MSL): 171.34' GL (ft above MSL): 153.34' 15. Field/Pool(s): Swanson River / Hemlock Oil 9. Plug Back Depth(MD+TVD): . 11,100'MD / 10,846' TVD - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 341,744.45 y- 2,457,909.95 Zone- 4 TPI: x- y- Zone- Total Depth: x- 341629.79 y- 2457118.24 Zone- 4 10. Total Depth (MD + TVD): • 11,200' MD / 10,923 TVD • 16. Property Designation: FEDA028996 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: NIA 18. Directional Survey: Yes ❑ No ❑/ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: WA (ft MSL) 20. Thickness of Permafrost MD/T'✓D: WA 21. Logs Obtained (List all lags here and submit electronic and printed information per 20AAC25.071): NIA 22.Re-drill/Lateral Top Window MD/TVD: NIA 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" Surf 44' Surf 44' 10-3/4" 40.5 K55 Surf 3,372' Surf 3,372' 7-5/8" 26.4 N80 Surf 3,798' Surf 3,798' 29.7 N80 3,798' 5,733' 3,798' 5,732' 33.7 IS95 P11 5,733' 1 9,390' j 5,732' 9,379' 4-1/2" 12.6 1 L80 9,180' 1 11,200' 1 9,173' 10,923' 24. Open to production or injection? Yes ❑ No F,-] If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): / 4 t7 i b umrr t , ttgr 7 t� ` �FiE1 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) WA N/A NIA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Date of Test: N/A Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. N/A Casing Press: Calculated 24 -Hour Rate --tio. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Sidewall Cores Acquired? Yes ❑ No ❑� If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. -/5- Form SForm 10-407 Revised 10/2012 �� CONTINUED ON REVERSE REr MS JAN - 9 291 bmit original only \1//G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Operations Summary, Schematic 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Joe Kaiser Email: i kaiser hi1cor .com Printed Name: Joe Kaiser Title: Operations Engineer `�— Z t r Phone: 907-777-8393 Date: Signature: < -� 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 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number ::=Well Number Start DateEnd Date SCU 44-05 P&A 50-133-20276-02-01 214-038 11/7/14 1 11/21/14 Daily Operations: 11/07/2014 - Tuesday Rig down total safety gas detectors, remove handy berm, remove cat walk, wind walls, generator units, remove pit lights and lower roof sections, pull pump houses, pit #2, clean sub and cellar. r/d top drive, remove torq. tube, pit #1, r/u bridle line and scope dwn derrick, remove rig floor wind walls, spool up drlg line, lay derrick over, lower dog house. Shipped 12 loads. Remove derrick, doghouse, draw works skid, remove upper sub and poney subs, load on trailers, pick up mats and load on trailers for transport in the morning. 100% rigged down, 60% moved. 11/08/2014- Wednesday Cont clean up and dispose of felt and liner on BCU 25, shipped pony walls, sub base, carrier, and derrick to Swanson River. Ship cranes to Swanson River. Set pony walls, sub base, carrier and derrick, spot water tank/doghouse, spot gen skid, spot HPU skid. Raise and pin derrick board windwalls, off load topdrive, BOP stack and centrifuge, spot all three pit modules, spot pump skids, spot boilers. Ship Saxon loader to Swanson River, PU plywood off BCU bridge. Hook up electric and steam lines, haul heated water for boilers, raise derrick, prep to spool up drilling line, continue to hook up mud lines. 11/09/2014 - Thursday Load hotwell with hot water for boilers, spot crane, set iron roughneck on rig floor, remove plywood from south bridge, install windwalls on pits and rig floor, set catwalk, set 3 pipeshed modules, fire up boilers, set poorboy degasser, set cattle chute, set service shacks, set gen 3 skid, set centrifuge. Welder installing pad eyes in derrick for hanging lines, transported loads to Swanson. Rig up cat walk, spool up drlg line, hook up electrical to pipe sheds, repair valves in pits, change out all rail cushions on shakers, change out valve on mix hopper install tarps on cattle shute, scope up derrick, install torque tube, hook up turn buckles on torque tube, prep top drive for picking up. 11/10/2014 - Friday Changed out pill pit valve, changed deck rubbers on shaker #2, hooked up degasser in pits (Saxon), aired up suction line boot rubbers,installed IBOP on topdrive, installed saver sub, charged up topdrive compensators, hung rig tongs, function checked topdrive, installed tension rollers on winches, installed choke shock hose on catwalk, installed kill line on mud line, RU centrifuge RU water and electric lines, function checked mud pumps, filled pits 1 and 2 with produce water, transported and RU office trailers, gen set and comm's to same. Notified of approval to kill well and de -complete. Made notifications to BLM and AOGCC of upcoming BOP test. Rig up rig floor, fix riser in pit 2, install encoder on draw works F/ DD, test phones, fill glycol pump and function test. Rig up kill line T/ tree, hook up choke line to upper annulus valve, load pits w/ 370 bbls of 8.4 ppg produced water. Rig Accepted @ 22:00 hrs, 11/10/2014.Tubing psi = 200, annulus psi 165. Circulate 8.4 ppg produce water and kill well circulating through open GLM at 10,500' and full open choke. Pumped 460 bbls produce water, lost 110 bbls to formation, FIC, 775 psi. Shut down, shut in and monitored well for pressure for 30 minutes, no pressure. Set BPV, blow down circulating lines, choke manifold and pumps. RD circ lines. 11/11/2014 - Saturday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 44-05 P&A 50-133-20276-02-01 214-038 11/7/14 11/21/14 Daily Operations: ND tree and hang in cellar, blank off SS chemical injection line, install 7 1/16" x 11" spool, Nipple up BOP, hammer up bolts, install choke, kill line, HCR, Koomey lines. Function test Koomey, change hydraulic lines, open doors, change out bottom VBR rams T/ 2-3/8" rams, function test all rams. Rig up T/ test BOP'S, fill stack, flush choke manifold, attempt to sheel test BOP'S, test failed, attempt to find leak, detected no leaks, change out BPV T/ 2 way check, shell test good. Test BOP's, Upper Pipe rams, choke valves 250 / 3,000 psi W/ 4-1/2" test joint, test #1 Failed, flange leaking @ lower pipe rams and 11" spool, tighten leaks. 11/12/2014 - Sunday Test #1: Upper pipe rams, Choke Valve #1,2,3,4,5,7, dart valve, #2 kill valve, Hyd [BOP @ 250/3,000 psi for 10 min. (Hyd IBOP Failed). Test #2: Choke Valve #6,8, kill HCR, TIW. Test #3: Choke Valve # 9,12,13, Inside Kill. (CM #13 Failed). Test #4: Choke HCR. Test #5: Hydrill @ 250/1,500 psi. Remove 4-1/2" test jt and install 2-7/8" test jt and make up cross overs. Test #6: Upper pipe rams, Inside Choke. Remove 2-7/8" Test jt. Rig up 2-3/8" test jt. Rigged up Weatherford tongs to assist making up cross overs. Bottom crossover backed off in test plug. Break flange and pick stack, retrive crossover. Test #7: 2-3/8" IBOP valve, blind rams, & perform accumlator test. Rig down testing equipment, and blow down choke lines and top drive. Install pitcher nipple, hook up flow line, hook up fill up line, secure BOP's. PJSm with all third party employee's on pulling hanger, and laying down completion string. Pick up jt DP, X0, screw into hanger, back out LDS, pull hanger, to rig floor, p/u 78K on tubing, PKR sheared @ 93K. Circulate bottoms up, pump 5,500 stks, 8.4 produced water, lost 92 bbls to well, skimmed 60 bbls crude oil off pit # 2. Remove control line F/ hanger, Lay down tubing hanger. Blow down top drive nad choke lines. Install stripping rubber, lay down 5 jts tubing, connect control line to Pollard spool unit, continue laying down tubing. 11/13/2014 - Monday Trip out laying down the 2-7/8" production string and gas mandrels F/10,600' to 7,389'. Continue Trip out laying down the 2- 7/8" production string F/ 7,389' to 3,808'. Laid down 3 gas mandrels, Hole fill 20 bbls over calcuated fill. (2 bbls/hr Losses). Continue laying down 2-7/8" tubing, F/ 3,808'T/ 1,768'. Lay down 2-3/8" tubing F/ 1768 T/ 367', lay dwn chemical injection mandrel, rig down Pollard control sheave. Continue lay down 2-3/8" tubing, packer and X nipple, F/ 367'T/ 0'. 199 bands retrived from well // 42 bbls losses. Unload pipe house of gas lift mandrels, test joints and tubing, load pipe house with 2- 7/8" work string, Strap, talley get ID'S and OD'S on XO'S, and pipe. Change bottom Rams F/ 2-3/8" T/ 2-7/8" X 5 VBR. 11/14/2014 -Tuesday Change out 2-3/8" rams to 2-7/8" x 5" VBR's. Test low and high for 10 min each test. Install 4-1/2" test jt and test same. Rig up Weatherford power tongs. and install wear bushing. Strap and pick up Mill, 4 drill collars and 54 2-7/8" drill pipe. Continue picking up 4-1/2" drillpipe to 5,513'. Continue picking up 4-1/2" drillpipe to 8,770'. Daily down hole Losses 22 bbls, total losses 152 bbls. 11/15/2014 - Wednesday Hilcorp Alaska, LLC Well Operations Summary Well Name AI Number Well Permit Number Start Date End Date SCU 44-05 P&A 50-133-20276-02-01 214-038 11/7/14 11/21/14 Daily Operations: Continue tripping in picking up the 4-1/2" drill pipe off the walk F/ 8,770' to 10,886', the milling assembly started taking weight at this depth. Make up topdrive and break circulation, drill cement stringers from 10,886' to 10,984'. Pumping 135 gpm with 35 rpm, off bottom torque is 3,800 ft/lbs. Torque spikes to 4,800 ft/lbs drilling stringers. At 10,894' the drilling torque evened out holding at 3,800 ft/lbs down to the depth of 10,915' and started stacking weight. (Posi-set Plug @ 10,915'). 135 GPM - 705 PSI - 35 RPM. Circulate bottoms up plus @ 205 gpm, 1,530 psi, Off bottom torque 3,700 ft/Ib. Service Rig and Topdrive. Trip out F/ 10,915' to 10,606', milling assembly started pulling tight due to fine debries falling down on the mill. Circulate inside the 4-1/2" liner cleaning the debries off the mill. Trip out to 10,247' and started pulling tight. Circulate inside the 4-1/2" liner cleaning the debries off the mill. Trip out to 9,687' and started pulling tight. Pump sweep and Circ a bottoms up @ 9,687', gpm 246, spp 2,100, p/u 150, s/o 148. Continue tripping out of hole F/ 9,687'T/ 1,793'. Rig up Weatherford tongs. Continue tripping out of hole standing back 2-7/8" drill pipe and collars. Clean rig floor, strap, talley overshot BHA. Make up Flat bottom shoe w/ 3-3/4" wash pipe ext, jars and bumper sub, xo's. Trip in hole with 2-7/8" collars and drill pipe. Hauled 140 bbls of class II junk fluid to KGF. Total hauled = 140 bbls. 11/16/2014 - Thursday Trip in with the 2-7/8" drill pipe to 1,812'. Rig down Weatherford tongs and elevators. Continue trip in F/ 1,812' to 9,223' with the 4-1/2" drill pipe. Went through the liner lap at 9180' with no issues. Trip in F/ 9,223' to 10,911' tagging fill, pick up to 10,907' and rig up to reverse circulate (4' of fill on plug). Attempt to reverse circulate, bring pumps on line with 48 stks (140 gpm) started showing flow at 12%, flow stopped and pressure increased plugging off the drillstring. Attempt to establish circ the long way with no success. Drill pipe plugged off. Trip out wet to 8,999", above liner lap @ 9,180'. Pump sweep @ and circulate and work pipe @ 8,999'. Trip in hole F/ 8,999'T/ 10,911' Pump through pipe every 10 stds on TIH, circulate and rotate last stand down, 84 stks/min, 243 gpm, 2,370 spp. Drill over posi set plug F/ 10,915 T/ 10,917, 83 stks/min, 243 gpm, 2,370 spp, 80RPM, 3.7 / 4.5 TRQ, 162K P/U, 160 S/0, 161 RT WT. PUSH POSI ST PLUG f/ 10,917't/ 10,987', hit cement stringers F/ 10,935'T/ 10,970', no sement F/ 10,970'T/ 10,987'. Pump hi vis sweep and circulate out @ 10, 985', 25% increase in cutting from milling rate. Trip out of hole F/ 10,987'T/ 9,500'. Junk on top of the wash pipe, pulling tight, had to circulate to pull out of liner. Hauled 70 bbls of class II junk fluid to KGF. Total hauled = 210 bbls. 11/17/2014 - Friday From 9,600' to the liner top at 9,180' pump out due to the milling assembly pulling tight. Continue tripping out on elevators F/ 9,180' to the 2-7/8" drill pipe @ 1,812'. Change out elevators and rig up Weatherford casing tongs and trip out standing the 2-7/8" drill pipe in the derrick. Change out burn shoes and add 3' of wash pipe to the assembly. Trip in to 1,935' with the 2-7/8" drillpipe. Rig down Weatherford tongs and elevators, install 4-1/2 elevators. Trip in hole W/ 4-1/2" DP F/,1935' T/ 10,900'. Wash and ream F/ 10,900'T/ 11,054', did not encounter any cement or see indication of 2nd plug @ 11,000', pipe started taking weight and torquing @ 11,054'. 83 stks/min, 243 gpm, 2,500 spp, 41k trq, 70 rpm, p/u 164k, s/o 160k, rt wt 162k wob 0 / 3k. Mill F/ 11,054'T/ 11,072'83 stks/min, 243 gpm, 2,500 spp, 4,100 / 5,600 trq, 70 rpm, p/u 164k, s/o 160k, rt wt 162k wob 0 / 5k, pump sweep @ 11,072'. Pipe stalling out, getting hung up, pulling up T/ 196 / 200 k to free, call drilling supervisor and discuss, decision made to pull out to top of liner. Trip out of hole F/ 11,072'T/ 10,777'. 11/18/2014 - Saturday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 44-05 P&A 50-133-20276-02-01 214-038 11/7/14 1 11/21/14 Daily Operations: Trip out F/ 10,777' to 10,209'. Trip in F/ 10,209' to 11,072' tagging bottom. Pick up to 11,070'. Break circulation and pump sweep around to surface. When sweep got back to the shackers no change in cuttings. Pumping 245 GPM, 2,634 PSI, MWt 8.5. Up, Dn, RT, All 162K. Trip out F/ 11,072' to 9,255'. Started pulling tight F/ 9,255' to 9,175'. Continue tripping out to the 2- 7/8" drill pipe @ 1,815'. Rig up Weatherford, casing tongs and elevators. Stand the 2-7/8" casing back in the derrick, L/D BHA. Strap 5 - 2-7/8" tubing, prep rig floor for RIH. M/U mule shoe and RIH with 2-7/8" tubing to 1,950'. R/D power tongs, C/O elevators. RIH fr: 1,950'- 8,790'. PJSM, Cut and slip 132' of drilling line. Grease drawworks, crown, top drive and blocks. Cont. RIH fr: 8,790'- 11,072'. (no issues going into top of liner at 9,180'). Circulating while mixing mud push and rigging up the cementers. Pre Job Safety meeting with all personnel involved in the cement job. Hauled 140 bbls of class II junk fluid to KGF. Total hauled = 420 bbls. 11/19/2014 - Sunday Build 25 BBIs of Mud Push @ 12 ppg PJSM with all personnel involved in cementing. Test surface lines to 4,000 psi, pump 6bbls 12ppg mud push with mud pumps. Line up cementers and pump 10 bbls cement and 3 more bbls mud push. Displace cement with produced water. Pull out slowly fr: 11,072'- 10,385', laying cement into the void. Continue tripping out stopping above the cement. (est. TOC= 10,414'). Insert nerf wiper ball and circulate the drill pipe volume + some, wash down fr: 10,385'- 10,414'. PJSM with the cementers and all involved, Pump 5 bbls water, test cement lines to 4,000 psi, pump 6 bbls of 12 ppg mud push, pump 10 bbls of 15.8 ppg cement, pump 2 bbls of 12 ppg mud push and displace w/ produced water. POOH slowly fr: 10,414'- 9,133' while letting cement fall into place (est TOC = 9,756'). Insert nerf ball into pipe and circulate at 280 gpm w/ 1,625 psi to clean up drill pipe and well bore. POOH r: 9,133'- 1,945' standing all 4-1/2" D.P. in derrick. R/U casing handling equipment, L/D all 2-7/8" D.P., R/D all casing handling equipment and remove equipment from rig floor. Remove wear ring from well head. R/U test jt and install test plug, R/U test equipment, Blow down top drive, choke and kill lines, prep for BOPE test. Replace the 4 broken brass bolts on break pads. Finish M/U test manifold, start filling stack and test equipment with water. Hauled 70 bbls of class II junk fluid to KGF. Total hauled = 490 bbls. 11/20/2014 - Monday Fill stack, choke and mud lines with water and purge the air out for the test. Test the BOP's, choke, safety valves and Hyd valves to 250 low and 3,500 high, hold each test for 5 min. Test the annuluar to 250 low and 3,500 psi high. BOPE test witnessed by AOGCC rep Lou Grimaldi. Blow down the lines, Pull test plug and install wear Bushing. Service rig and topdrive. Spot the wire line truck. Hold PJSM with crew and wire liners, hang sheaves and pickup tools._ Running down with junk basket assembly and tag cement at 9,321', POOH and L/D junk basket assembly. M/U CIBP setting tool assembly, RIH and locate collar at 8,029', pull up to 8,025', Set CIBP, POOH and R/D wireline unit. Top of CIBP @ 8.025' WLM. M/U Baker mill assembly, RIH and tag CIBP @ 8,012' DPM (8,025' WLM), filled pipe every 1,500'up wt = 118k / do wt = 110k. Circulate at 330 GPM w/ 2,000 psi for 1 surface to surface volume, added bleach to break down any polimers that are in wellbore. R/U test chart, perform CASING/ CIBP test- 2,600 psi for 30 minutes on chart (good test), bled off and opened up well, blew down top drive. POOH fr: 8,012'- 6,800'. Hauled 65 bbls ofclassII junk fluid to KGF. Total hauled = 555 bbls. 11/21J2014 -Tuesday FAR Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 44-05 P&A 50-133-20276-02-01 214-038 11/7/14 1 11/21/14 Daily Operations: Trip out with the whipstock milling assembly F/ 6,800' to surface. Inspect mills and ready floor to P/U Whipstock. Install mouse hole, strap HWDP. Pick up UBHO sub, whipstock and scribe both, M/U whipstock to mill assembly. RIH picking up 30 joint of HWDP off catwalk, continue RIH out of derrick to 7,960', filled pipe every 2,000'up= 130k / dn= 130k @ 7,950'. R/U wireline unit and Install side entry sub in string, RIH with GYRO tool. Orient whipstock, POOH with wire line due to readings not matching up with pipe movement while orienting whipstock (last reading was 54 degrees). Tattle tail was smashed, decided best option was to install new tattle tail and RBIH to confirm reading. RIH with GYRO tool and orient whipstock to 49 degrees magnetic, POOH and R/D wireline unit, cofirm tattle tail was hit. Hauled 60 bbls of class II junk fluid to KGF. Total hauled = 615 bbls. RKB: 171.34'/ GL: 153.34' AMSL KB - THF: 18.0' 20" 44' F r v jr' 10-3/4" r' 3,372' CBL TOC 4,240' l,HJ11Vlj Ut I AIL Type Size WT Grade Conn A Top Btm. Conductor 20" 1 Top(MD) Btm(MD) - Surf CBL TOC Surface 10-3/4" 40.5 K-55 9,100' 10.050" Surf 3,372' Production a 26.4 N-80 BTC 6.969" TOL 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 5-95 BTC 6.765" 5,733' 9,180' 33.7 P-110 BTC 6.765" 6,906' 9,390 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 7-5/8" 10' 60 1-11/16" Strip 8/07/14 9,390' 10,747' 10,772' +. 10,594' 12 25' 60 CBL TOC j u H-3 10,786' 9,570' 'C 10,628' 12 30' ik�! 1-11/16" Strip C7 H-11 11,020' 3 10,784' TOC 9,756' 6 28 60 2-7/8" Connex 6/06/14 E t 11,072' l,HJ11Vlj Ut I AIL Type Size WT Grade Conn ID Top Btm. Conductor 20" - Top(MD) Btm(MD) - Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 5-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 11,200' JEWELRY DETAIL No. Depth ID CID Item 1 8,025' 3.9" Bridge Plug (Set for whipstock) 2 11,109' - Fish - 14 control line bands SCU 44-05 Schematic 11-22-14 In Progress WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen LiftThreads: 3-1/2" 8RD Updated by DMA 12-12-14 x H1 PERFORATION DETAIL H-2 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9/10/14 H-1 10,678' 10,696' 10,523' 10,536' 6/6 18' 60 1-11/16" Strip/HC 9/10/14 H-1 10,701' 10,722' 10,540' 10,556' 6/6 21' 60 1-11/16" Strip/HC 8/07/14 H-1 10,725' 10,735' 10,558' 10,566' 12 10' 60 1-11/16" Strip 8/07/14 H-2 10,747' 10,772' 10,575' 10,594' 12 25' 60 1-11/16" Strip 8/07/14 H-3 10,786' 10,816' 10,605' 10,628' 12 30' 60 1-11/16" Strip 6/06/14 H-11 11,020' 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 H-12 11,072' 11,087' 10,824' 10,836' 6 15 60 2-7/8" Connex SCU 44-05 Schematic 11-22-14 In Progress WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen LiftThreads: 3-1/2" 8RD Updated by DMA 12-12-14 x H1 H-2 �+ H-3 r L � H-11 14 Bands y., '�ti0- H-12 11,109' SL -N1 6/10/14 f 4-1/2" 11,200' TD = 11,200' PBTD = 11,100' MAX HOLE ANGLE = 41° @ 10,667' SCU 44-05 Schematic 11-22-14 In Progress WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen LiftThreads: 3-1/2" 8RD Updated by DMA 12-12-14 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, November 11, 2014 10:34 AM To: 'Chad Helgeson' Cc: Donna Ambruz; Monty Myers Subject: RE: SCU 44-05 PTD#214-038 procedure change Chad, You have approval to modify the sundry wellwork to P &A as proposed below. Drilling out and cementing all open zones is certainly acceptable for the AOGCC . Need to add one modification to procedure. Pressure test cement plug (30 min/ 2500 psi) after tagged with Eline in step 19. This is before setting the CIBP. 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.aov). From: Chad Helgeson fmailto:cheigeson@hilcorp.com] Sent: Tuesday, November 11, 2014 7:44 AM To: Schwartz, Guy L (DOA) Cc: Donna Ambruz; Monty Myers Subject: SCU 44-05 PTD#214-038 procedure change Guy, Attached is a revised procedure and proposed diagram for the decompletion on SCU 44-05, Sundry # 314-576. We are drilling out the plugs that were set on wireline and cementing the entire hemlock for the plug back, per BLM's requirements. Please let me know if you have any issues with this revised plug back plan or if I need to submit anything different to you. Thanks Chad Helgeson Ilileorp Alaska, LL Well Prognosis Rev -1 Well: SCU 44-05 Date: 11/10/2014 Well Name: SCU 44-05 API Number: 50-133-20276-01 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: November 7t", 2014 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-038 First Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) AFE Number: Current Bottom Hole Pressure: — 1,350 psi @ 10,550' TVD (Based on static survey 9-26-14) Maximum Expected BHP: — 1,350 psi @ 10,550' TVD (Based on static survey 9-26-14) Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir at 7,043' TVD.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05. A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated. A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench. The well has had limited productivity since this workover (approximately 1 bopd on gaslift). The well was plugged back and sidetracked as SCU 44-05 in April 2014. Following the sidetrack of this well, the completion was ran with the Aurora AWS #1 in June 2014, completed in the Hemlock H-11 and H-12. These zones were shown to be wet and non-productive. The H-11 and H-12 were plugged back with a thru-tubing plug in June 2014. This plug was leaking and a 2nd thru-tubing plug was set in July 2014. A gaslift survey run in July 2014 found the zone to be damaged with limited fluid influx. The well was re -perforated in the Hemlock H-1 thru H-3 in August and September 2014 with a minimal increase in flow. The purpose of this work/sundry is to abandon the current perforated interval and prepare the wellbore for re - drilling operations. A drilling permit application has been submitted separately for the sidetrack. Notes Regarding Wellbore Condition • Well placed on production on 6/14/14. Zones H-11 and H-12 tested wet. Plugged back. WO Rig Procedure: 1. MIRU Saxon 169 Rig. 2. NU 11" BOPE. Test to 250 psi Low/ 3,000 psi High, annularto 250 psi Low/ 1,500 psi High (hold each valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. Notify AOGCC 24 hrs in advance to witness. Notify BLM 48 hrs in advance of BOP test. 3. Bleed any trapped pressure off tubing and casing. 4. Kill well using 8.4 ppg produced lease water. 5. MU landing joint and pull tubing hanger free. 6. Release hydraulic packer. a. Packer set for shear release at 15k overpull. 7. POOH and lay down the 2-7/8" and 2-3/8" 8RD tubing. a. MU 2-7/8" 8RD thread protectors to tubing (285 joints). Ilileorp Alaska, LL Well Prognosis Rev -1 Well: SCU 44-05 Date: 11/10/2014 b. MU 2-7/8" 8RD thread protectors to tubing (46joints). 8. Lay down the packer and all jewelry. a. Send packer to Halliburton for redress. b. Send GLM and Chemical Mandrel to Pollard for redress. 9. PU 3.8" mill & 2-3/8" drill collars (At least 4ea), 2-3/8" (min 30ft above liner top) and 4-1/2" drill pipe 10. RIH and drill cement and plugs (Posi-set @ 10,910 w/ 15ft of cement and Neo -plug at 11,000' w/ 20ft of cement) Push to bottom. 11. Circulate well clean, POOH. 12. PU mule shoe and 2-3/8" tubing and RIH to 10,500'. 13. RU Cementers, Mix 20 bbls of cement, pump down well. 14. PU above top of liner at 9,180' circulate bottom up. 15. POOH and LD 2-3/8" work string and tubing. 16. MU 6-1/2" bit w/ 7-5/8" 33.7# casing scraper and RIH on 4-1/2" drillpipe. a. Need XOs for 4-1/2" IF connections on scraper tools to 4-1/2" drillpipe. 17. RIH to +/- 9,180' MD and tag liner top. 18. SOOH. Rack back 4-1/2" drillpipe, lay down the casing scraper and 6-1/2" bit. 19. MIRU E -line. RU 3.0" bailer, RIH and tag cement top at estimated 9,780'.. 20. RU 7-5/8" 33.7# CIBP and GR/CCL tools. 21. RIH and set top of CIBP at +/- 8,034' MD in the 7-5/8" 33.7# P-110 casing (set 3-5 ft above a casing collar). 22. POOH. RD E -line. 23. Mix mud for 6-1/8" hole section. 24. PU window milling assembly on 4-1/2" DP. 25. RIH to CIBP at 8,034'. 26. Circulate well clean w/ 8.4 ppg produced lease water. 27. SOOH and rack back milling assembly. 28. PU mills and UBHO sub on a joint of HWDP. 29. PU whipstock and attach mills and milling assembly. 30. Orient whipstock above CIBP. 31. Tag up on CIBP. Set whipstock anchor. Shear off window mill from the whipstock. 32. PU 5-10' above the whipstock. 33. Circulate well over to 9.5 ppg 6% KCI/PHPA drilling mud. 34. ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic Illileorp Alaska, LLC. RK13: 171.34' / GI.: 153.34' AMS1, 1:11-'IIIF: 18.11' 211" 44' SCU 44-05 Proposed Schematic CASING DETAIL Typc Size WT Grade Conn ID Top Rtm. Conductor 20" - - - Top(TVD) Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 1 6,906' 1 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 1 91180' 1 11,200' 10-3/4" J L 3,372' TUBING DETAIL Tubing CBI, TOC Tubing 4,240' JEWELRY DETAIL (BLTOC 9,100' , TOL v,18o• ' I 7-5/8" 9,390' CBL TOC w H-11 9,570' a Prot-, u 1 ' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft }7foil` Comments 9/10/14 H-1 10,678' 10,696' 10,523' 10,536' 6/6 18' t a. �y h, H-1 11-2 it �� 4 �• I'lo. f)epth IL OD Item 1 8.034' 3.9" Brlclg,e Pluf {Set for whipstoc[,) 2 11,109' - Fish -14 control line bands WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 11-10-14 Undated by CAH 11/10/14 w H-11 PERFORATION DETAIL ' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9/10/14 H-1 10,678' 10,696' 10,523' 10,536' 6/6 18' 60 1-11/16" Strip/HC 9/10/14 H-1 10,701' 10,722' 10,540' 10,556' 6/6 21' 60 1-11/16" Strip/HC 8/07/14 H-1 10,725' 10,735' 10,558' 10,566' 12 10' 60 1-11/16" Strip 8/07/14 H-2 10,747' 10,772' 10,575' 10,594' 12 25' 60 1-11/16" Strip 8/07/14 H-3 10,786' 10,816' 10,605' 10,628' 12 30' 60 1-11/16" Strip 6/06/14 H-11 11,020' 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 H-12 1 11,072' 1 11,087' 1 10,824' 10,836' 6 1 15 1 60 1 2-7/8" Connex WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 11-10-14 Undated by CAH 11/10/14 w H-11 ' 14 Bands I,u1v' SLn] H-12 6/10/14 pry .4 4-1/2" y 11,200' TD = 11,200' PBTD = 11,] 00' MAX HOLE ANGLE = 41'rd, 10,667' WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 11-10-14 Undated by CAH 11/10/14 GOVLRNOR SEAN PARNI-.LL Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 44-05 Sundry Number: 314-576 Dear Mr. Porhola: 333 Wes! Severih Avenue; Anchorage, Alaska 99501-3572 Mnin: 907.279.1433 Fnx 907.2?G 7,,j,) 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. V�r DATED this _tday of November, 2014. Encl. Sincerely, Daniel T. Seamount, Jr. Commissioner STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION n�,13jm APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ECEI OCT 2 7 2014 „ICY "" 1. Type of Request: Abandon ❑ Plug for Redril Perforate New Pod ❑ Repair Wel[E] Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdowl ❑ 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 Strati ra hic ❑ g p ❑ Service 214-038 . 3. Address: 3800 Centerpoint Drive, Suite 1400 p 6. API Number: Anchorage, Alaska 99503 50-133-20276-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes ❑ No Soldotna Creek Unit (SCU) 44-05 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028996 I Swanson River / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD(ft): Effective Depth TVD (ft): Plugs (measured): 1 Junk (measured): 11,200 10,924 10,895 10,688 10895 WA Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,327' 3,130psi 1,580psi Intermediate Production 9,390' 7-5/8" 9,390' 9,379 6,020psi 3,400psi Liner 2,020' 4-1/2" 11,200' 10,924' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8"x2-3/8" 6.5#/L-80 x 4.7#/L-80 9,241'x 10,656' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Halliburton G-77 Hydraulic Packer; N/A 10,585' MD/10,452' TVD; 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 proposed work: ,p ?• Commencing Operations: 11/07/14 Oil ❑ Gas ❑ WDSPL ❑ Sus ended Rr p ❑ GINJ ❑ WAG ❑ Abandoned 16. Verbal Approval: Date: __]WINJ Commission Representative: GSTOR ❑ SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email s orhoIa hilcor .com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date + G Zy COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. LQ Plug Integrity ❑ BOP Test ❑Q ' Mechanical Integrity Test ❑ Clearance ❑ /L�o9cation / / Other. -3 c )� N s : 6d /I� z s i� � / °' lr� � � = C l� ( Spacing Exception Required? Yes ❑ No Subsequent Form Required: % (: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and 10-403 (Revised 10/2 NAIL lid for 12 months from the date of approval. Attachments in Duplicate FIilcorp Alaska, LLO Well Prognosis Well: SCU 44-05 Date:10/24/2014 Well Name: SCU 44-05 API Number: 50-133-20276-01 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: November 7th, 2014 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-038 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) AFE Number: Current Bottom Hole Pressure: - 1,350 psi @ 10,550' TVD (Based on static survey 9-26-14) Maximum Expected BHP: - 1,350 psi @ 10,550' TVD (Based on static survey 9-26-14) Max. Allowable Surface Pressure: - 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir at 7,043' TVD.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05. A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated. A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench. The well has had limited productivity since this workover (approximately 1 bopd on gaslift). The well was plugged back and sidetracked as SCU 44-005 in April 2014. Following the sidetrack of this well, the completion was ran with the Aurora AWS #1 in June 2014, completed in the Hemlock H-11 and H-12. These zones were shown to be wet and non-productive. The H-11 and H-12 were plugged back with a thru-tubing plug in June 2014. This plug was leaking and a 2 d thru-tubing plug was set in July 2014. A gaslift survey run in July 2014 found the zone to be damaged with limited fluid influx. The well was re -perforated in the Hemlock H-1 thru H-3 in August and September 2014 with a minimal increase in flow. �--� SCU Ric -e-.4 l q The purpose of this work/sundry is to abandon the current perforated interval and prepare tl�e wellbore fo re - drilling operations. A drilling permit application has been submitted separately for the,sidetr2ck. 1 c�1hGd✓ . j�i� �e o�� PS C� y� oUl Notes Regarding Wellbore Condition of , ( n�,�, clolly,U/e/-/n64,/ � I //'- i OG iA)42 , lecd��y- • Well placed on production on 6/14/14.Zones H-11 and H-12 tested wet. Plugged back. '0/4 /21� /V WO Rig Procedure: 1. MIRU Saxon 169 Rig. 2. NU 11" 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. Notify AOGCC 24 hrs in advance to witness. Notify BLM 48 hrs in advance of BOP test. 3. Bleed any trapped pressure off tubing and casing. 4. Kill well using 8.4 ppg produced lease water. 5. MU landing joint and pull tubing hanger free. 6. Release hydraulic packer. a. Packer set for shear release at 15k overpull. 7. POOH and lay down the 2-7/8" and 2-3/8" 8RD tubing. a. MU 2-7/8" 8RD thread protectors to tubing (285 joints). Hileorp Alaska, LLI Well Prognosis Well: SCU 44-05 Date: 10/24/2014 b. MU 2-7/8" 8RD thread protectors to tubing (46 joints). 8. Lay down the packer and all jewelry. a. Send packer to Halliburton for redress. b. Send GLM and Chemical Mandrel to Pollard for redress. 9. RU E -line, PT lubricator to 3,000 psi Hi 250 Low. 10. RU 4-1/2" 12.6# CIBP,__R. IH_and_set bride >LuB at 10,6.50' MD. 11. POOH. Test bridge plug to 2,700 psi for 30 min. 12. RU 3.0"x50' bailer, tag plug and dump bail 35' of cement on tubing plug (22 gallons of cement) to achieve a cement top at 10,615'. POOH. RD E -line. 13. MU 6-1/2" bit w/ 7-5/8" 33.7# casing scraper and RIH on 4-1/2" drillpipe. a. Need XOs for 4-1/2" IF connections on scraper tools to 4-1/2" drillpipe. 14. RIH to +/- 9,180' MD and tag liner top. 15. Circulate well clean w/ 8.4 ppg produced lease water. 16. SOOH. Rack back 4-1/2" drillpipe, lay down the casing scraper and 6-1/2" bit. 17. MIRU E -line. RU 3.0" bailer, RIH and tag -cement top at 10,615'. _ 18. RU 7-5/8" 33.7# CIBP and GR/CCL tools. 19. RIH and set top of CIBP at.+/_8,034'_MD in the 7-5/8" 33.7# P-110 casing (set 3-5 ft above a casing collar). 20. POOH. RD E -line. 21. Mix mud for 6-1/8" hole section. 22. PU window milling assembly on 4-1/2" DP. 23. RIH to CIBP at 8,034'. i, 24. Circulate well clean w/ 8.4 ppg produced lease water. 25. SOOH and rack back milling assembly. 26. PU mills and UBHO sub on a joint of HWDP. 27. PU whipstock and attach mills and milling assembly. 28. Orient whipstock above CIBP. 29. Tag up on CIBP. Set whipstock anchor. Shear off window mill from the whipstock. 30. PU 5-10' above the whipstock. 31. Circulate well over to 9.5 ppg 6% KCI/PHPA drilling mud. r t, 32._ ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** .� l Attachments:% 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic RKB: 171.34'/ GL: 153.34' AMSL KB — THF: 18.0' 20" 44' 10-3/4"� 3,372' CBL TOC 4,240' CBI, "COC.' 9,100' '_ TOL 9,180' 7-5/8" 9,390' CBL TOC 9,570' CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" - 19.75' 2.441" 3.668" Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29'7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 1 L-80 DWC/C-HT 3.958" 1 9,180' 11,200' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 9,142' Tubing 2-3/8" 4.7 L-80 BIRD 1.995" 9,142' 10,656' JEWELRY DETAIL No. Depth ID OD Item 1 19.28' 2.992" - Tubing Hanger, 3-1/2" BIRD Box x Box 2 19.75' 2.441" 3.668" XO, 3-1/2" 8RD Pin x 2-7/8" 8RD Box 3 2,755' 2.441" 4.750" 2-7/8" SFO -1 GLM #7 (Dummy) 4 4,956' 2.441" 4.750" 2-7/8" SFO -1 GLM #6 (Dummy) 5 6,779' 2.441" 4.750" 2-7/8" SFO -1 GLM #5 (Dummy) 6 8,124' 2.441" 4.750" 2-7/8" SFO -1 GLM #4 (Dummy) 7 9,129' 2.441" 4.750" 2-7/8" SFO -1 GLM #3 (Dummy) 8 9,142' 1.995" 3.063" XO, 2-7/8" BIRD x 2-3/8" 8RD 9 9,848' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #2 (T-1 latch) (Dummy) 10 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #1(T-1 latch) (Dummy) 11 10,543' 1.990" 3.750" Chemical Injection Mandrel (Dummy) 12 10,585' 1.940" 3.750" Halliburton G-77 Hydraulic Packer (15k to release) 13 10,622' 1.875" 3.063" X -Nipple 14 10,656' 1.995" 3.063" WL Entry Guide 15 10,910' - - Posi-Set Plug (Capped w/ 15' of Cement) 16 11,000' 11,087' 10,824' Thru-Tubing Plug (Capped w/ 20' of Cement) 17 11,109' 60 2-7/8" Connex Fish — 14 control line bands 14 Bands H-12 11,109' SLM 1 6/10/14 {t 4-1/2" �1 11,200' TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads. 3-1/2" BIRD SCU 44-05 Actual Schematic 09-10-14 Updated by STP 9/24/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9/10/14 H-1 10,678' 10,696' 10,523' 10,536' 6/6 18' 60 1-11/16" Strip/HC 9/10/14 H-1 10,701' 10,722' 10,540' 10,556' 6/6 21' 60 1-11/16—"Strip/HC 8/07/14 H-1 10,725' 10,735' 10,558' 10,566' 12 10' 60 1-11/16" Strip 8/07/14 H-2 10,747' 10,772' 10,575' 10,594' 12 25' 60 1-11/16" Strip 8/07/14 H-3 10,786' 10,816' 10,605' 10,628' 12 30' 60 1-11/16" Strip 6/06/14 H-11 11,020' 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 H-12 11,072' 11,087' 10,824' 10,836' 6 15 60 2-7/8" Connex 14 Bands H-12 11,109' SLM 1 6/10/14 {t 4-1/2" �1 11,200' TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads. 3-1/2" BIRD SCU 44-05 Actual Schematic 09-10-14 Updated by STP 9/24/14 20" 44' 10-2 3,3' CB 4 C1 C 11 RKB: 171.34'/ GL: 153.34' AMSL KB - THF: 18.0' CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" - Fish -14 control line bands Ft Phase Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 11,200' TUBING DETAIL Tubing Tubing JEWELRY DETAIL Depth ID OD Item 8,034' 3.9" Bridge Plug (Set for whipstock) 10,650' 3.9" Bridge Plug (Capped w/ 35' of cement) 10,910' - Posi-Set Plug (Capped w/ 15' of Cement) 11,000' Thru-Tubing Plug (Capped w/ 20' of Cement) 11,109' Fish -14 control line bands I i,auv TD = 11,200' PBTD = 11,100' MAX HOLE ANGLE = 410 @ 10 667' WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 10-24-14 Updated by STP 10/24/14 PERFORATION DETAIL ne Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 1 10,678' 10,696' 10,523' 10,536' 6/6 18' 60 1-11/16" Strip/HC 1 10,701' 10,722' 10,540' 10,556' 6/6 21' 60 1-11/16" Strip/HC 1 10,725' 10,735' 10,558' 10,566' 12 10' 60 1-11/16" Strip 2 10,747' 10,772' 10,575' 10,594' 12 25' 60 1-11/16" Strip 3 10,786' 1 10,816' 10,605' 10,628' 12 30 60 1-11/16" Strip 11 11,020' 1 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 12 11,072' 1 11,087' 10,824' 10,836' 6 1 15 1 60 2-7/8" Connex WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 10-24-14 Updated by STP 10/24/14 11dr—p Alaska. 1.1.1: SCU 44-05 Completion Procedure Rev 0 BOPE Schematic Revision 0 October, 2014 Choke Manifold Schematic SCU 44-05 Completion Procedure Rev 0 Revision 0 October, 2014 �o ,► � Llai♦ ��R�A A l _ 16 MR.M.Ii �tia l I�1.171 Revision 0 October, 2014 Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re -drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" ` j Y boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia orSte_v_e._ work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. zk4Q-oS'r- 5_ _n Nolan Hilcorp Alaska, LL_ GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Hilriirp Alarka. lJ C Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED / /201 :4 K. BENDER DATE 10/27/14 To: Alaska Oil & Gas Conservation Commission R 1� RECEIVED Guy Schwartz Natural Resource Technician OCT 2 8 2614 333 W 7th Ave Ste 100 Anchorage, AK OGCC 99501 Prints: 5" CBL CD 1 : Final Well Data flame Gate modified Type Size Files Currently on the Disc (1) Logs 10x`27/2014113:24 ... Filefolder 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 Date: v STATE OF ALASKA ALA: OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Lj Plug Perforations Perforate ./ Other Lj Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development Stratigraphic❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 214-038 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99503 50-133-20276-01 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028996 Soldotna Creek Unit (SCU) 44-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,200 feet Plugs measured 10,895 feet true vertical 10,924 feet Junk measured N/A feet Effective Depth measured 10,895 feet Packer measured 10,585 feet true vertical 10,688 feet true vertical 10,452 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,327' 3,130psi 1,580psi Intermediate Production 9,390' 7-5/8" 9,390' 9,379' 6,020psi 3,400psi Liner 2,020' 4-1/2" 11,200' 10,924' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" x 2-3/8" 6.5#/L-80 x 4.7#/L-80 9,241'x 10,656' MD 9,233'x 10,506' TVD Halliburton G-77 Packers and SSSV (type, measured and true vertical depth) Hydraulic Pkr; N/A 10,585' MD 10,452' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,000 155 Subsequent to operation: 5 16 3 625 140 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-442 Contact Stan Porhola Email sporhola Whilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date 6I2S v. Form 10-404 Revised 10/2012 YZ RBcMI.q SEP 2 P3 2T�61� Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 44-05 50-133-20276-01 314-276 8/7/14 9/10/14 Daily Operations: 08/07/2014 - Thursday Obtain permit and RU Pollard E -line. Shut in well, MU lubricator and MU 30' strip gun. Stab on well and PT with well pressure - good test. RIH w/ 30' strip gun and GPT tool. Have trouble getting through tubing jewelry. Saw fluid level — 10,150' and BHP @ 10,800'- 403 psi. Log correlation pass and tie-in w/ Halliburton LWD dated 4/20/14. Send in for verification. Move correlation pass up 2' and send for verification. Re-perf Hemlock H3 (10,786-10,816) w/ 1-11/16" Owen strip guns 6 SPF 60 deg. Positive indication of firing, POOH. No pressure change - SITP 150 psi. OOH - all shots fired and guns intact. MU 25' guns and RIH - have trouble getting through tubing jewelry. Log correlation pass and send in for verification. Troubleshoot GR issues. Re-perf Hemlock H2 (10,747'-10,772') w/ 1-11/16" Owen strip guns 6 SPF 60 dem _Positive indication of firing, POOH. No pressure change - SITP 160 psi. OOH - all shots fired and guns intact. MU 10' guns and WO new GR/CCL tool. RIH w/ 10' guns - have trouble getting through tubing jewelry. Log correlation pass and send in for verification. Re-perf Hemlock H1 (10,725'-10,735') w/ 1-11/16" Owen strip guns 6 SPF 60 deg. Positive indication of firing, POOH. No pressure change - SITP 175 psi. OOH - all shots fired and guns intact. MU 21' guns and RIH. Sat down @ 9,126' (GLM) and work tools, unable t pass. POOH w/ guns and remove curled gun tip. RIH w/ same and sat down @ 9,126' (GLM) and work tools, unable to pass. Bring well online and work tools, unable to pass. POOH and RIH w/ 1-11/16" weight bars w/ bull nose. Passed trouble spot with no issues. POOH. Cut excess tip off 21' guns and RIH. Sat down @ 9,126' (GLM) and work tools, unable to pass. Well still flowing. POOH and downsize guns to 10'. 08/08/2014 - Friday Downsize 21'x 1-11/16" strip gun into a 10' gun and RIH, tag @ 9,156', work and fell to 9,217', work and fell to 9,370', work and fell to 9,393', work and fell to 9,500'. Work tools and would not fall, acting like junk in well. POOH to add weight. Add weight bar to 10' gun and RIH to tag @ 10,519', work and fell to 10,525', work and fell to 10,557', work and fell to 10,578'. Work tools and would not fall - stuck in area of tubing packer. POOH to check guns. Add guide tip to 10' guns and RIH. Tag @ 9,156', work tools and would not fall. Not getting past GLM, decision to work on well with slickline. POOH. RD Pollard E line. 09/10/2014 - Wednesday PTW and JSA. Mobe to location. Rig up and PT to 250 psi low and 3000 psi high. Arm gun. RIH with 1.56" x 20' HC, 6 spf, 60 deg phase and tie into electronic log. Run correlation log and send to town. Get ok to shoot. Bleed well down from 400 psi to 140 psi. Spot shot from 10,701' to 10,721'. Fired gun and no pressure change. POOH. Arm gun. RIH with 1.56" x 18' HC, spf, 60 deg phase and tie into electronic log. Run correlation log and send to town. Get ok to shoot. Tubing pressure 130 psi. Spot shot from 10,678' to 10,696'. Fired gun and no pressure change. POOH. Rig down and turn well over to field. "M RKB: 171.34'/ GL: 153.34' AMSL KB — THF: 18.0' 20" 1 44' J 2 -tl , 3 10-3/4" 3,372' CBL TOC 4,240' 4 411�p FP # P ' *A nf, 5 v 0 6 CBL TOC 9,100' 7 8 TOL 9,180' d , 7-5/8" 9 9,390' t '" 1,A5)INU Ut I AIL Type Size WT CBL TOC ¢ 10` Conn ID 9,570' Btm. Conductor 20" - 19.75' 2.441" 3.668" Surf 44' Surface i 40.5 �. 13 'X 10.050" 1,A5)INU Ut I AIL Type Size WT Grade Conn ID Top Btm. Conductor 20" - 19.75' 2.441" 3.668" Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29'7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 1 9,180' 1 11,200' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf T 9,142' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 9,142' 10,656' JEWELRY DETAIL No. Depth ID OD Item 1 19.28' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x Box 2 19.75' 2.441" 3.668" XO, 3-1/2" BIRD Pin x 2-7/8" 8RD Box 3 2,755' 2.441" 4.750" 2-7/8" SFO -1 GLM #7 (Dummy) 4 4,956' 2.441" 4.750" 2-7/8" SFO -1 GLM #6 (Dummy) 5 6,779' 2.441" 4.750" 2-7/8" SFO -1 GLM #5 (Dummy) 6 8,124' 2.441" 4.750" 2-7/8" SFO -1 GLM #4 (Dummy) 7 9,129' 2.441" 4.750" 2-7/8" SFO -1 GLM #3 (Dummy) 8 9,142' 1.995" 3.063" XO, 2-7/8" 8RD x 2-3/8" 8RD 9 9,848' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #2 (T-1 latch) (Dummy) 10 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #1 (T-1 latch) (Dummy) 11 10,543' 1.990" 3.750" Chemical Injection Mandrel (Dummy) 12 10,585' 1.940" 3.750" Halliburton G-77 Hydraulic Packer (15k to release) 13 10,622' 1.875" 3.063" X -Nipple 14 10,656' 1.995" 3.063" WL Entry Guide 15 10,910' - - Posi-Set Plug (Capped w/ 15' of Cement) 16 11,000' 11,087' 10,824' Thru-Tubing Plug (Capped w/ 20' of Cement) 17 11,109' 1 60 2-7/8" Connex Fish —14 control line bands r 14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9/10/14 H-1 10,678' 10,696' 10,523' 10,536' 6/6 18' 60 1-11/16" Strip/HC 9/10/14 H-1 10,701' 10,722' 10,540' 10,556' 6/6 21' 60 1-11/16" Strip/HC 8/07/14 H-1 10,725' 10,735' 10,558' 10,566' 12 10' 60 1-11/16" Strip 8/07/14 H-2 10,747' 10,772' 10,575' 10,594' 12 25' 60 1-11/16" Strip 8/07/14 H-3 10,786' 10,816' 10,605' 10,628' 12 30' 60 1-11/16" Strip 6/06/14 H-11 11,020' 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 H-12 11,072' 11,087' 10,824' 10,836' 6 15 1 60 2-7/8" Connex r 14 GLV .; Temp CIL, H-1 Size Depth TCF PSG PSO PTRO ` H-2 7 16 93 0-931 1244 1400 1476 1 `^ 6 16 110 0.899 1219 1343 1470 1 11-3 5 16 132 0-861 1194 1281 1440 1 ' 4 16 160 0.832 1169 1228 1410 1 3 16 161 0.816 1144 1178 1390 1 15 + 2 16 167 0,807 1119 1144 1375 1 11 16 172 0.800 16 a ;+ R H-11 14 Bands H-12 11,109' SLM �� 17 6/10/14 , 4-1/2" Y* x 11,200' TD = 11,200' PBTD =11,100' MAX HOLE ANGLE = 410 @ 10 667' WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Actual Schematic 09-10-14 Updated by STP 9/24/14 Ifilrnria Ala.ka_ LII DATE 08/19//2014 U. in Ellison Hilcorp Alaska, LLL GeoTech 3800 Centerpoint Drive, Suite 10 Anchorage, AK 99503 Tele: 907 777-8339 Fax: 907 777-8510 E-mail: lellison@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA Transmitted herewith are cuttings from SCU 44-05 WELL SAMPLE INTERVAL SCU 44-05 9440'-10460' SCU 44-05 10460'-10880' SCU 44-05 10880'-11201' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: ENI -- - z.\ 0`3� THE STATE GOVERNOR SEAN PARNEL.L Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 _T jF,'=r rn Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 44-05 Sundry Number: 314-442 Dear Mr. Porhola: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 M6n: 907.279 1433 Fox: 90;'.216 7 ' 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 S day of August, 2014. Encl. STATE OF ALASKA p�� gid J'y ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUL2 8 2014 A'�'�(4�J>�� A OG 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 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 E ' Stratigraphic ❑ Service ❑ 214-038 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-20276-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B ' Will planned perforations require a spacing exception? Yes ❑ No Soldotna Creek Unit (SCU) 44-05 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028996 Swanson River/ Hemlock Oil ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,200 10,924 10,895 10,688 10895 WA Casing Length Size MD ND Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,32T 3,130psi 1,580psi Intermediate Production 9,390' 7-5/8" 9,390' 9,375 6,020psi 3,400psi Liner 2,020' 4-1/2" 11,200' 10,924' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8"x2-3/8" 6.5#/L-80 x 4.7#/L-80 9,241'x 10,656 Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Halliburton G-77 Hydraulic Packer; N/A 10,585' MD/10,452' TVD; N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic❑ DevelopmentF/] Service n 14. Estimated Date for 15. Well Status after propsed work: Commencing Operations: 07/31/14 Oil Q . Gas ❑ WDSPL ❑ Suspended ❑ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-7T7-8412 Email s rhola hilco.com Printed Name Stan Porhola Title Operations Engineer Signature ` Phone 907-777-8412 Date -7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: Ll 0 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ��• L-�ea 7_ l /�� /'� Submit Form and Fo aQ3��($� 12) Apr l i n a f 12 months from the date of approval. attachments i Duplicate r10��s A'U� u ,� ��ly .�A -e- - �V iiilcorp Alaska, LLQ Well Prognosis Well: SCU 44-05 Date: 07/28/2014 Well Name: SCU 44-05 API Number: 50-133-20276-01 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: June 31St, 2014 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-038 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: 1410656C Current Bottom Hole Pressure: — 2,600 psi @ 10,784' TVD (Estimated pressure based on offsets) Maximum Expected BHP: — 2,600 psi @ 10,784' TVD (Estimated pressure based on offsets) Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir at 4,030' TVD.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05. A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated. A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench. The well has had limited productivity since this workover (approximately 1 bopd on gaslift). The well was plugged back and sidetracked as SCU 44-05 in April 2014. Following the sidetrack of this well, the completion was ran with the Aurora AWS #1 in June 2014, completed in the Hemlock H-11 and H-12. These zones were shown to be wet and non-productive. The H-11 and H-12 were plugged back with a thru-tubing plug in June 2014. This plug was leaking and a 2nd thru-tubing plug was set in July 2014. A gaslift survey run in July 2014 found the zone to be damaged with limited fluid influx. The purpose of this work/sundry is to re -perforate the Hemlock H-1 thru H-3. Notes Regarding Wellbore Condition • Well placed on production on 6/14/14. Zones H-11 and H-12 tested wet. Plugged back. E -line Procedure: MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low. a. Tree connection is 3-1/2" Bowen. b. SITP will be 150 to 200 psi. RU 1-11/16" 6 spf Owen strip guns (will make multiple gun runs, 104' net perfs). RIH and perforate Hemlock H-1 thru H-3 interval from 10,678'-10,816' (1 run each, total of 6 spf). c. Bleed tubing pressure to 180 psi before perforating. d. Proposed perfs shown on the proposed schematic in red font. e. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. f. Correlate using Halliburton LWD Log dated 4/20/14 (Tie-in log depth is 10.678'-10,816'). g. Use Gamma/CCL/ to correlate. h. Record tubing pressures before and after each perforating run. i. No Spacing allowance required in Swanson River per CO 1236. 4. RD E -line. 5. Turn well over to production. Hilcorp Alaska, LU Attachments: 1. Actual Schematic 2. Proposed Schematic Well Prognosis Well: SCU 44-05 Date: 07/28/2014 f RKB: 171.34'/ GL: 153.34' AMSL KB — THF: 18.0' 3 10-3/4" 3,372' CBL TOC 4,240' 4 r 5 12 CBL TOC 9,100' " 71 8 TOL 9,180' 7-5/8" y 9 9,390' CBL TOC 10 9,570' r Il 12; 13 14 15 16 H-11 14 Bands 1I-12 11,109' SLM 17 6/10/14 -- 11,200' TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" - 19.75' 2.441" 3.668" Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 11,200' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 9,142' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 9,142' 10,656' 1FWF1 RY DFTAII No. Depth ID OD Item 1 19.28' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x Box 2 19.75' 2.441" 3.668" X0, 3-1/2" 8RD Pin x 2-7/8" 8RD Box 3 2,755' 2.441" 4.750" 2-7/8" SFO -1 GLM #7 (Dummy) 4 4,956' 2.441" 4.750" 2-7/8" SFO -1 GLM #6 (Dummy) 5 6,779' 2.441" 4.750" 2-7/8" SFO -1 GLM #5 (Dummy) 6 8,124' 2.441" 4.750" 2-7/8" SFO -1 GLM #4 (Dummy) 7 9,129' 2.441" 4.750" 2-7/8" SFO -1 GLM #3 (Dummy) 8 9,142' 1.995" 3.063" XO, 2-7/8" 8RD x 2-3/8" 8RD 9 9,848' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #2 (T-1 latch) (Dummy) 10 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #1(T-1 latch) (Dummy) 11 10,543' 1.990" 3.750" Chemical Injection Mandrel (Dummy) 12 10,585' 1.940" 3.750" Halliburton G-77 Hydraulic Packer (15k to release) 13 10,622' 1.875" 3.063" X -Nipple 14 10,656' 1.995" 3.063" WL Entry Guide 15 10,910' - - Posi-Set Plug (Capped w/ 15' of Cement) 16 11,000' 11,087' 10,824' Thru-Tubing Plug (Capped w/ 20' of Cement) 17 11,109' 60 2-7/8" Connex Fish —14 control line bands WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Actual Schematic 07-18-14 Updated by STP 7/25/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 6/23/14 H-1 10,678' 10,696' 10,523' 10,536' 6 18' 60 1-11/16" Owen HC 6/23/14 H-1 10,701' 10,722' 10,540' 10,556' 6 21' 60 1-11/16" Owen HC 6/23/14 H-1 10,725' 10,735' 10,558' 10,566' 6 30' 60 1-11/16" Owen HC 6/23/14 H-2 10,747' 10,772' 10,575' 10,594' 6 25' 60 1-11/16" Owen HC 6/23/14 H-3 10,786' 10,816' 10,605' 10,628' 6 30' 60 1-11/16" Owen HC 6/06/14 H-11 11,020' 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 H-12 11,072' 11,087' 10,824' 10,836' 6 15 60 2-7/8" Connex WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Actual Schematic 07-18-14 Updated by STP 7/25/14 RKB: 171.34'/ GL: 153.34' AMSL KB — THF: 18.0' 20"�I44' 10-3/4" , 3,372' CBL TOC 4,240' any CBL TOC 9,100' TOL 9,180' 7-5/8" 9,390' CBL TOC 9,570' H-3 15 i 16 H-11 14 Bands 11,109' SLM 11-12 6/10/14 17 4-1/2" 11,200' TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" - 19.75' 2.441" 3.668" Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180 11,200 TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 9,142' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 9,142' 10,656' JEWELRY DETAIL No. Depth ID OD Item 1 19.28' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x Box 2 19.75' 2.441" 3.668" XO, 3-1/2" 8RD Pin x 2-7/8" 8RD Box 3 2,755' 2.441" 4.750" 2-7/8" SFO -1 GLM #7 (Dummy) 4 4,956' 2.441" 4.750" 2-7/8" SFO -1 GLM #6 (Dummy) 5 6,779' 2.441" 4.750" 2-7/8" SFO -1 GLM #5 (Dummy) 6 8,124' 2.441" 4.750" 2-7/8" SFO -1 GLM #4 (Dummy) 7 9,129' 2.441" 4.750" 2-7/8" SFO -1 GLM #3 (Dummy) 8 9,142' 1.995" 3.063" XO, 2-7/8" 8RD x 2-3/8" 8RD 9 9,848' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #2 (T-1 latch) (Dummy) 10 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #1(T-1 latch) (Dummy) 11 10,543' 1.990" 3.750" Chemical Injection Mandrel (Dummy) 12 10,585' 1.940" 3.750" Halliburton G-77 Hydraulic Packer (15k to release) 13 10,622' 1.875" 3.063" X -Nipple 14 10,656' 1.995" 3.063" WL Entry Guide 15 10,910' - - Posi-Set Plug (Capped w/ 15' of Cement) 16 11,000' 11,087' 10,824' Thru-Tubing Plug (Capped w/ 2(Y of Cement) 17 11,109' 60 2-7/8" Connex Fish —14 control line bands WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 07-25-14 Updated by STP 7/25/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments Reperf H-1 10,678' 10,696' 10,523' 10,536' 6 18' 60 1-11/16" Strip Reperf H-1 10,701' 10,722' 10,540' 10,556' 6 21' 60 1-11/16" Strip Reperf H-1 10,725' 10,735' 10,558' 10,566' 6 10' 60 1-11/16" Strip Reperf H-2 10,747' 10,772' 10,575' 10,594' 6 25' 60 1-11/16" Strip Reperf H-3 10,786' 10,816' 10,605' 10,628' 6 30' 60 1-11/16" Strip 6/06/14 H-11 11,020' 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 1 H-12 11,072' 11,087' 10,824' 10,836' 6 15 60 2-7/8" Connex WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 07-25-14 Updated by STP 7/25/14 STATE OF ALASKA JUL 16 2014 ALA OIL AND GAS CONSERVATION COMM 3ION WELL COMPLETION OR RECOMPLETION REPORT AND LO( 1 a. Well Status: Oil ❑✓ ' Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WI NJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 b. Well Class: Development Q ' Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 5. Date Comp., Susp., or Aband.: ,�, 19Permit to Drill Number: 214-038 / 314-276 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 6. Date Spudded: ,a ' /• 4/12/2014 13. API Number: 50-133-20276-01 4a. Location of Well (Governmental Section): Surface: 3323' FNL, 571' FEL, Sec 5, T7N, R9W, SM, AK Top of Productive Horizon: 1490' FSL, 665' FEL, Sec 5, T7N, R9W, SM, AK Total Depth: 1156' FSL, 673' FEL, Sec 5, T7N, R9W, SM, AK 7. Date TDeached:: , %>� �'�4/ 1014 /ty ' 14. Well Name and Number: Soldotna Creek Unit (SCU) 44-05 ' 8. KB (ft above MSL): 171.34' • GL (ft above MSL): 153.34' ° 15. Field/Pool(s): Swanson River Field Hemlock Oil Pool . 9. Plug Back Depth(MD+TVD): • 11,100' MD / 10,846' TVD - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 341,744.45 y- 2,457,909.95 • Zone- 4 TPI: x- 341,641.19 y- 2,457,451.87 Zone- 4 Total Depth: x- 341,629.79 y- 2,457,118.24 Zone- 4 10. Total Depth (MD +TVD): . 11,200' MD / 10,923' TVD ` 16. Property Designation: FEDA028996 11. SSSV Depth (MD +TVD): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes ❑✓ No ❑ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): Elogs & mudlogs to Makana Bender 5/21/14 L 13L 22.Re-drill/Lateral Top Window MD/TVD: . 9390' MD / 9,379 TVD 23. CASING, LINERAND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 4-1/2" 12.6 L-80 9,180' 11,200' 9,173' 10,923' 6-1/8" 73bbl/330sx ° r e s( A, 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD+TVD of Top and Bottom; Perforation Size and Number): Zone Top (MD/TVD) Bottom (MD/TVD) SPF Size H-1 10,678'/10,523' 10,696'/10,536' 6 1-11/16" H-1 10,701'/10,540' 10,722710,556' 6 1-11/16" H-1 10,725710,558' 10,735'/10,566' 6 1-11/16" H-2 10,747710,575' 10,772710,594' "' 0 1-11/16" H-3 10,786'/10,605' 10,816'/10,628' ' •1-11/16" b i 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2-7/8" 9,142' 10,585' MD / 10,452' TVD 2-3/8" 10,656' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 6/24/2014 Method of Operation (Flowing, gas lift, etc.): Gas Lift Date of Test: 6/27/2014 Hours Tested: 24.00 Production for Test Period Oil -Bbl: 33 Gas -MCF: 152 Water -Bbl: 631 Choke Size: N/A Gas -Oil Ratio: 14606 Flow Tubing Press. 200 Casing Press: 1050 Calculated 24 -Hour Rate --► Oil -Bbl: 33 Gas -MCF: 152 Water -Bbl: 631 Oil Gravity - API (corr): 31 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Sidewall Cores Acquired? Yes ❑ No Q 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. RB®lu1S JUL 17 201 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 No I If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top NA NA and submit detailed test information per 20 AAC 25.071. Permafrost - Base NA NA Tyonek G1 ST 10,395 10,298' Tyonek G2 ST 10,575' 10,444' H1ST 10,677' 10,522' H2ST 10,743' 10,572' H3ST 10,784' 10,603' H9ST 10,884' 10,680' H10ST 10,921' 10,708' H11ST 11,023' 10,786' H12ST 11,073' 10,285' H13ST 11,134' 10,872' Formation at total depth: Hemlock 11,200' 10,923' 31. List of Attachments: Well schematic, Days vs Depth, MW vs Depth, Directional Survey, Daily composites, Casing and Cement report, copy of report of logs sent. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Mack Myers Email: mmyers@hilcorp.com Printed Name: Monty Mack Myers Title: Drilling Engineer Signature: — Phone: 907-777-8431 Date: 7/16/2014 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 Janise Barrett Drilling Technician Hilcorp Energy company July 16, 2014 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Re: SCU 44-05 PTD: 214-038 API: 50-133-20276-01-00 Dear Commissioner, Hilcorp Alaska, LLC P Sox 244027 A, )rage, AK 99524-4027 Tel 907 777 8389 Email jbarrett@hilcorp.com RECEIVr. !JUL 16 2014 AOGGG Enclosed for review is the 10-407 Well Completion for the Soldotna Creek Unit 44-05. If you have any questions, please don't hesitate to contact me at 777-8389 or Monty Mack Myers at 777-8431. cerely, Janise Barrett Drilling Technician Hilcorp Alaska, LLC Page 1 of 1 RKB: 171.34'/ GL: 153.34' AMSL KB — THF: 18.0' 201,n 1 44' Iia 2 3 10-3/4" n- 3,372' CBL TOC 4,240' i 4 ca G CBL TOC,' Size 9,100' " Grade Conn 7[ Top 8 TOL 20" - 19.75' 2.441" 3.668" 7-5/8" 9 — �9 390' f •`, 10-3/4" CBL TOC1 10 9,570' 10.050" Surf 3,372' Production 7-5/8" 12 13 IxI 14 H-1 H-2 H-3 e 15 " H-11 14 Bands H-12 11,109' SLM 6/10/14 16%' 4-1/2" 11,200' " TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' LHJIIVl1 UL I HIL Type Size W T Grade Conn ID Top Btm. Conductor 20" - 19.75' 2.441" 3.668" Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 11,200' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 9,142' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 9,142' 10,656' JEWELRY DFTAII No. Depth ID OD Item 1 19.28' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x Box 2 19.75' 2.441" 3.668" XO, 3-1/2" 8RD Pin x 2-7/8" 8RD Box 3 2,755' 2.441" 4.750" 2-7/8" SFO -1 GLM #7 (Dummy) 4 4,956' 2.441" 4.750" 2-7/8" SFO -1 GLM #6 (Dummy) 5 6,779' 2.441" 4.750" 2-7/8" SFO -1 GLM #5 (Dummy) 6 8,124' 2.441" 4.750" 2-7/8" SFO -1 GLM #4 (Dummy) 7 9,129' 2.441" 4.750" 2-7/8" SFO -1 GLM #3 (Dummy) 8 9,142' 1.995" 3.063" XO, 2-7/8" 8RD x 2-3/8" 8RD 9 9,848' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #2 (T-1 latch) (Dummy) 10 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #1(T-1 latch) (Dummy) 11 10,543' 1.990" 3.750" Chemical Injection Mandrel (Dummy) 12 10,585' 1.940" 3.750" Halliburton G-77 Hydraulic Packer (15k to release) 13 10,622' 1.875" 3.063" X -Nipple 14 10,656' 1.995" 3.063" WL Entry Guide 15 11,000' 60 60 2-7/8" Connex 2-7/8" Connex Thru-Tubing Plug (Capped w/ 20' of Cement) 16 11,109' Fish —14 control line bands WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads. 3-1/2" 8RD SCU 44-05 Actual Schematic 06-23-14.doc Updated by STP 6/25/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 6/23/14 H-1 10,678' 10,696' 10,523' 10,536' 6 18' 60 1-11/16" Owen HC 6/23/14 H-1 10,701' 10,722' 10,540' 10,556' 6 21' 60 1-11/16" Owen HC 6/23/14 H-1 10,725' 10,735' 10,558' 10,566' 6 10' 60 1-11/16" Owen HC 6/23/14 H-2 10,747' 10,772' 10,575' 10,594' 6 25' 60 1-11/16" Owen HC 6/23/14 H-3 10,786' 10,816' 10,605' 10,628' 6 30' 60 1-11/16" Owen HC 6/06/14 6/06/14 H-11 H-12 11,020' 11,072' 11,048' 11,087' 10,784' 10,824' 10,806' 10,836' 6 6 28 15 60 60 2-7/8" Connex 2-7/8" Connex WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads. 3-1/2" 8RD SCU 44-05 Actual Schematic 06-23-14.doc Updated by STP 6/25/14 SCU 44-05 Days Vs Depth 8500 SR SCU 44-05 Drill and Complete SCU 44-5 PLAN 9000 9500 10000 t CL v 10500 v m a 11000 11500 12000 12500 0 5 10 15 20 25 Days SCU 44-05 MW Vs Depth 9200 MW vs Depth 9400 9600 9800 10000 10200 Q. v 0 v v L 10400 v 10600 10800 11000 11200 11400 8 9 10 11 12 13 14 Mud Density (ppg) Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit SCU 44-05 50-133-20276-01-00 Sperry Drilling Definitive Survey Report 28 April, 2014 F.rmrry ly dlinrD. Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Project: Soldotna CK Unit TVD Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) Site: Soldotna CK Unit MD Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) Well: Soldotna CK Unit 33-05 North Reference: True Wellbore: SCU 44-05 Survey Calculation Method: Minimum Curvature Design: SCU 44-05 Database: Sperry EDM - NORTH US + CANADA )ject Soldotna CK Unit, Swanson River Field p System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level o Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point p Zone: Alaska Zone 04 Well Soldotna CK Unit 33-05 Well Position +N/ -S 0.00 usft Northing: 2,457,909.95 usft Latitude: 60.7247852 (usft) +EI -W 0.00 usft Easting: Tool Name 341,744.45 usft Longitude: -150.8839274 Position Uncertainty 0.00 usft Wellhead Elevation: CB -Gyro -SS 0.00 usft Ground Level: 153.34 usft 9,390.00 9,674.19 SCU 44-05 (MWD Interp AZI+Sag) (SCU MWD _Interp Azi+sag Fixed:v2:std dec with interpolated azimuth + sag 04/03/2014 Wellbore SCU 44-05 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag 04/15/2014 Magnetics Model Name Sample Date Declination Dip Angle Field Strength TVD TVDSS +NI -S +E/ -W (nT) Easting BGGM2013 2/21/2014 Section 17.16 73.71 55,509 (I (usft) (usft) (usft) (usft) esign F SCU 44-05 (°1100') (ft) Survey Tool Name 18.00 udit Notes: 0.00 18.00 -153.34 0.00 Version: 1.0 Phase: ACTUAL Tie On Depth: 9.372.34 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 125.00 (usft) (usft) (usft) (°) 0.18 18.00 0.00 0.00 185.70 609.33 437.99 2.37 -2.22 2,457,912.34 Survey Program Date 4/28/2014 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 296.34 9,372.34 SCU 33-5 (SCU 33-05) CB -Gyro -SS Fixed:v2:Camera based gyro single shot 02/11/2014 9,390.00 9,674.19 SCU 44-05 (MWD Interp AZI+Sag) (SCU MWD _Interp Azi+sag Fixed:v2:std dec with interpolated azimuth + sag 04/03/2014 9,704.36 11,164.56 SCU 44-05 (MWD+SC+Sag) (SCU 44-05 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag 04/15/2014 4/28/2014 1:44:30PM Page 3 COMPASS 5000.1 Build 70 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -153.34 0.00 0.00 2,457,909.95 341,744.45 0.00 0.00 UNDEFINED 296.34 0.50 320.00 296.34 125.00 0.93 -0.78 2,457,910.89 341,743.68 0.18 -0.85 CB -Gyro -SS (1) 609.34 0.25 305.00 609.33 437.99 2.37 -2.22 2,457,912.34 341,742.26 0.09 -2.14 CB -Gyro -SS (1) 912.34 0.25 279.00 912.33 740.99 2.85 -3.41 2,457,912.84 341,741.07 0.04 -2.50 CB -Gyro -SS (1) 1,224.34 0.50 115.00 1,224.32 1,052.98 2.38 -2.85 2,457,912.37 341,741.63 0.24 -2.09 CB -Gyro -SS (1) 1,511.34 0.50 130.00 1,511.31 1,339.97 1.05 -0.76 2,457,911.00 341,743.71 0.05 -0.97 CB-Gyro-SS(1) 1,794.34 0.50 103.00 1,794.30 1,622.96 -0.02 1.39 2,457,909.90 341,745.84 0.08 -0.11 CB-Gyro-SS(1) 2,105.34 0.50 30.00 2,105.29 1,933.95 0.85 3.39 2,457,910.75 341,747.85 0.19 -1.18 CB -Gyro -SS (1) 2,421.34 0.25 105.00 2,421.29 2,249.95 1.86 4.75 2,457,911.74 341,749.22 0.16 -2.32 CB-Gyro-SS(1) 2,701.34 0.25 65.00 2,701.29 2,529.95 1.96 5.89 2,457,911.83 341,750.37 0.06 -2.54 CB-Gyro-SS(1) 3,016.34 0.50 162.00 3,016.28 2,844.94 0.95 6.94 2,457,910.80 341,751.40 0.19 -1.63 CB-Gyro-SS(1) 3,169.34 0.25 136.00 3,169.28 2,997.94 0.07 7.38 2,457,909.92 341,751.83 0.19 -0.80 CB-Gyro-SS(1) 4/28/2014 1:44:30PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 Project: Soldotna CK Unit TVD Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) Site: Soldotna CK Unit MD Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) Well: Soldotna CK Unit 33-05 North Reference: True Wellbore: SCU 44-05 Survey Calculation Method: Minimum Curvature Design: SCU 44-05 Database: Sperry EDM - NORTH US + CANADA Survey 4/28/2014 1:44:30PM Page 4 COMPASS 5000.1 Build 70 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 3,401.34 0.50 118.00 3,401.27 3,229.93 -0.77 8.62 2,457,909.06 341,753.06 0.12 -0.09 CB-Gyro-SS(1) 3,720.34 0.75 90.00 3,720.25 3,548.91 -1.42 11.94 2,457,908.36 341,756.37 0.12 0.23 CB-Gyro-SS(1) 4,010.34 1.00 86.00 4,010.22 3,838.88 -1.25 16.36 2,457,908.48 341,760.79 0.09 -0.39 CB-Gyro-SS(1) 4,191.34 1.25 91.00 4,191.18 4,019.84 -1.17 19.91 2,457,908.51 341,764.34 0.15 -0.81 CB -Gyro -SS (1) 4,443.34 1.50 90.00 4,443.11 4,271.77 -1.22 25.96 2,457,908.38 341,770.39 0.10 -1.37 CB-Gyro-SS(1) 4,753.34 1.75 82.00 4,752.99 4,581.65 -0.56 34.70 2,457,908.92 341,779.14 0.11 -2.89 CB-Gyro-SS(1) 4,943.34 1.25 81.00 4,942.92 4,771.58 0.17 39.62 2,457,909.58 341,784.07 0.26 -4.10 CB-Gyro-SS(1) 5,223.34 1.50 65.00 5,222.84 5,051.50 2.19 45.96 2,457,911.52 341,790.43 0.16 -6.75 CB-Gyro-SS(1) 5,413.34 1.50 62.00 5,412.78 5,241.44 4.41 50.41 2,457,913.68 341,794.91 0.04 -9.40 CB-Gyro-SS(1) 5,726.34 1.25 59.00 5,725.69 5,554.35 8.10 56.95 2,457,917.27 341,801.51 0.08 -13.71 CB -Gyro -SS (1) 5,898.34 1.50 46.00 5,897.64 5,726.30 10.63 60.18 2,457,919.76 341,804.77 0.23 -16.55 CB-Gyro-SS(1) 6,204.34 1.75 35.00 6,203.51 6,032.17 17.23 65.74 2,457,926.29 341,810.42 0.13 -23.68 CB-Gyro-SS(1) 6,540.34 2.50 39.00 6,539.28 6,367.94 27.13 73.30 2,457,936.09 341,818.10 0.23 -34.28 CB-Gyro-SS(1) 6,969.34 3.00 39.00 6,967.79 6,796.45 43.13 86.25 2,457,951.91 341,831.27 0.12 -51.48 CB-Gyro-SS(1) 7,168.34 3.00 39.00 7,166.51 6,995.17 51.22 92.80 2,457,959.91 341,837.93 0.00 -60.19 CB-Gyro-SS(1) 7,399.34 3.00 39.00 7,397.20 7,225.86 60.62 100.41 2,457,969.21 341,845.67 0.00 -70.29 CB-Gyro-SS(1) 7,765.34 2.25 32.00 7,762.81 7,591.47 74.15 110.25 2,457,982.61 341,855.68 0.22 -84.74 CB-Gyro-SS(1) 8,035.34 2.25 30.00 8,032.60 7,861.26 83.24 115.71 2,457,991.62 341,861.26 0.03 -94.32 CB-Gyro-SS(1) 8,217.34 2.25 26.00 8,214.46 8,043.12 89.54 119.06 2,457,997.88 341,864.70 0.09 -100.93 CB -Gyro -SS (1) 8,376.34 2.00 32.00 8,373.35 8,202.01 94.70 121.90 2,458,003.00 341,867.61 0.21 -106.34 CB -Gyro -SS (1) 8,465.34 2.75 246.00 8,462.32 8,290.98 95.15 120.77 2,458,003.46 341,866.49 5.11 -106.67 CB-Gyro-SS(1) 8,527.34 3.50 245.00 8,524.23 8,352.89 93.75 117.70 2,458,002.10 341,863.39 1.21 -104.97 CB-Gyro-SS(1) 8,605.34 3.75 247.00 8,602.07 8,430.73 91.74 113.19 2,458,000.16 341,858.86 0.36 -102.53 CB -Gyro -SS (1) 8,684.34 4.50 259.00 8,680.87 8,509.53 90.14 107.77 2,457,998.63 341,853.42 1.44 -100.40 CB-Gyro-SS(1) 8,745.34 5.25 263.00 8,741.65 8,570.31 89.35 102.65 2,457,997.90 341,848.29 1.35 -99.10 CB-Gyro-SS(1) 8,777.34 5.75 265.00 8,773.50 8,602.16 89.03 99.60 2,457,997.62 341,845.24 1.67 -98.48 CB-Gyro-SS(1) 8,872.34 6.50 274.00 8,867.96 8,696.62 88.99 89.49 2,457,997.72 341,835.13 1.28 -97.44 CB-Gyro-SS(1) 8,965.34 7.75 279.00 8,960.24 8,788.90 90.34 78.05 2,457,999.22 341,823.71 1.50 -97.64 CB-Gyro-SS(1) 9,059.34 8.25 284.00 9,053.33 8,881.99 92.96 65.25 2,458,002.02 341,810.94 0.91 -98.98 CB-Gyro-SS(1) 9,119.34 9.25 286.00 9,112.63 8,941.29 95.33 56.43 2,458,004.51 341,802.16 1.74 -100.46 CB-Gyro-SS(1) 9,215.34 9.00 251.00 9,207.49 9,036.15 95.01 41.91 2,458,004.38 341,787.63 5.70 -98.70 CB-Gyro-SS(1) 9,307.34 10.25 240.00 9,298.20 9,126.86 88.57 28.01 2,457,998.14 341,773.65 2.41 -90.92 CB-Gyro-SS(1) 9,372.34 11.25 239.00 9,362.05 9,190.71 82.42 17.57 2,457,992.12 341,763.12 1.56 -83.75 CB-Gyro-SS(1) 9,390.00 11.32 239.87 9,379.37 9,208.03 80.66 14.59 2,457,990.40 341,760.12 1.04 -81.71 MWD _InterpAzi+sag(2) 9,424.25 11.40 233.63 9,412.95 9,241.61 76.97 8.96 2,457,986.78 341,754.44 3.59 -77.47 MWD_InterpAzi+sag(2) 9,457.18 11.84 228.74 9,445.21 9,273.87 72.81 3.80 2,457,982.70 341,749.23 3.27 -72.83 MWD_InterpAzi+sag(2) 9,486.60 12.22 224.81 9,473.98 9,302.64 68.61 -0.66 2,457,978.56 341,744.71 3.07 -68.20 MWD_Interp Azi+sag (2) 9,519.12 12.36 221.01 9,505.76 9,334.42 63.54 -5.37 2,457,973.55 341,739.93 2.52 -62.69 MWD_InterpAzi+sag(2) 9,549.54 13.54 217.92 9,535.41 9,364.07 58.27 -9.70 2,457,968.35 341,735.53 4.50 -57.02 MWD _InterpAzi+sag(2) 9,581.01 14.33 215.11 9,565.95 9,394.61 52.18 -14.20 2,457,962.31 341,730.95 3.30 -50.51 MWD_InterpAzi+sag(2) 4/28/2014 1:44:30PM Page 4 COMPASS 5000.1 Build 70 Company: Hilcorp Energy Company Project: Soldotna CK Unit Site: Soldotna CK Unit Well: Soldotna CK Unit 33-05 Wellbore: SCU 44-05 Design: SCU 44-05 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: Well Soldotna CK Unit 33-05 TVD Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) MD Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA Checked By'.Cary Taylor Approved By: �� ''�� Date: 7. 1 fo 4/28/2014 1:44:30PM Page 5 COMPASS 5000.1 Build 70 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 9,608.79 15.44 212.91 9,592.80 9,421.46 46.26 -18.19 2,457,956.45 341,726.88 4.48 -44.23 MWD_InterpAzi+sag(2) 9,644.56 18.19 210.40 9,627.03 9,455.69 37.45 -23.60 2,457,947.71 341,721.35 7.95 -34.92 MWD_InterpAzi+sag (2) 9,674.19 20.69 208.57 9,654.97 9,483.63 28.86 -28.45 2,457,939.19 341,716.39 8.68 -25.89 MWD_InterpAzi+sag(2) 9,704.36 22.40 202.35 9,683.04 9,511.70 18.86 -33.18 2,457,929.25 341,711.52 9.45 -15.47 MWD+SC+sag (3) 9,735.13 23.65 196.77 9,711.36 9,540.02 7.53 -37.19 2,457,917.98 341,707.36 8.17 -3.80 MWD+SC+sag (3) 9,768.18 23.89 192.69 9,741.61 9,570.27 -5.35 -40.58 2,457,905.15 341,703.80 5.03 9.35 MWD+SC+sag (3) 9,799.06 24.66 191.05 9,769.76 9,598.42 -17.77 43.19 2,457,892.76 341,701.03 3.31 21.97 MWD+SC+sag (3) 9,859.57 25.64 191.35 9,824.53 9,653.19 -43.00 48.18 2,457,867.60 341,695.69 1.63 47.57 MWD+SC+sag (3) 9,921.77 26.26 190.37 9,880.46 9,709.12 -69.73 -53.31 2,457,840.94 341,690.21 1.21 74.68 MWD+SC+sag (3) 9,983.31 26.43 189.72 9,935.61 9,764.27 -96.62 -58.07 2,457,814.12 341,685.08 0.54 101.91 MWD+SC+sag (3) 10,045.89 25.69 192.68 9,991.83 9,820.49 -123.58 -63.40 2,457,787.23 341,679.39 2.39 129.26 MWD+SC+sag (3) 10,107.68 25.35 193.69 10,047.59 9,876.25 -149.50 -69.47 2,457,761.40 341,672.97 0.89 155.66 MWD+SC+sag (3) 10,137.65 26.18 190.94 10,074.58 9,903.24 -162.22 -72.24 2,457,748.71 341,670.03 4.86 168.60 MWD+SC+sag (3) 10,170.05 27.41 189.30 10,103.50 9,932.16 -176.60 -74.80 2,457,734.37 341,667.27 4.43 183.16 MWD+SC+sag (3) 10,232.17 28.92 187.43 10,158.27 9,986.93 -205.61 -79.06 2,457,705.42 341,662.63 2.82 212.44 MWD+SC+sag (3) 10,294.75 29.57 186.41 10,212.87 10,041.53 -235.96 -82.74 2,457,675.12 341,658.54 1.31 243.01 MWD+SC+sag (3) 10,355.96 31.00 185.46 10,265.72 10,094.38 -266.66 -85.92 2,457,644.47 341,654.94 2.46 273.87 MWD+SC+sag (3) 10,419.21 34.03 185.05 10,319.05 10,147.71 -300.51 -89.03 2,457,610.66 341,651.38 4.80 307.87 MWD+SC+sag (3) 10,480.66 35.59 183.22 10,369.51 10,198.17 -335.49 -91.55 2,457,575.71 341,648.39 3.06 342.93 MWD+SC+sag (3) 10,542.97 37.17 181.81 10,419.67 10,248.33 -372.41 -93.16 2,457,538.82 341,646.28 2.87 379.83 MWD+SC+sag (3) 10,604.91 41.00 182.82 10,467.74 10,296.40 -411.43 -94.76 2,457,499.83 341,644.16 6.27 418.80 MWD+SC+sag (3) 10,666.79 41.21 182.78 10,514.37 10,343.03 -452.06 -96.74 2,457,459.23 341,641.63 0.34 459.43 MWD+SC+sag (3) 10,727.59 40.55 181.76 10,560.34 10,389.00 -491.82 -98.32 2,457,419.49 341,639.52 1.54 499.15 MWD+SC+sag (3) 10,788.03 39.95 181.09 10,606.47 10,435.13 -530.86 -99.29 2,457,380.47 341,638.02 1.22 538.09 MWD+SC+sag (3) 10,852.73 40.31 181.40 10,655.94 10,484.60 -572.55 -100.20 2,457,338.80 341,636.55 0.64 579.67 MWD+SC+sag (3) 10,914.81 40.03 181.39 10,703.38 10,532.04 -612.58 -101.18 2,457,298.78 341,635.04 0.45 619.60 MWD+SC+sag (3) 10,976.40 40.11 181.25 10,750.51 10,579.17 -652.22 -102.09 2,457,259.16 341,633.59 0.20 659.13 MWD+SC+sag (3) 11,038.58 39.32 180.62 10,798.34 10,627.00 -691.94 -102.74 2,457,219.45 341,632.41 1.43 698.73 MWD+SC+sag (3) 11,100.88 38.70 180.62 10,846.75 10,675.41 -731.16 -103.16 2,457,180.24 341,631.45 1.00 737.79 MWD+SC+sag (3) 11,164.56 38.09 180.84 10,896.66 10,725.32 -770.70 -103.67 2,457,140.71 341,630.42 0.98 777.19 MWD+SC+sag (3) 11,201.00 38.09 180.84 10,925.34 10,754.00 -793.18 -104.00 2,457,118.24 341,629.79. 0.00 799.59 PROJECTED to TD Checked By'.Cary Taylor Approved By: �� ''�� Date: 7. 1 fo 4/28/2014 1:44:30PM Page 5 COMPASS 5000.1 Build 70 Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field County/State: , Alaska Location (LAT/LONG): 2457909.946 / 341744.448 Job Name: 1410656P SCU 44-05 PreDrill Hilcorp Alaska, LLC PreDrill Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 3/16/2014 3/15/2014 shift change hold jsa, clean pits, pumps, manifold, and pumplines, move herculite, spot equipment, shift change hold JSA, rig up W/O rig, winterize equipment, run pump lines 3/17/2014 3/16/2014 shift change hold jsa, finish containment, work on rig, blow down well to 0, shoot fluid level could not get reading, shift change hold jsa, wait on bop, set BPV N/D rod tree N/U adapter flanges flow cross and her valves 3/18/2014 3/17/2014 shift change hold JSA discuss the days tasks, N/U bop and hydril, Preform BOPE test, test all values to 250 psi low 3000 psi high for 10 mins and chart do draw down test on koomey; witness waived by AOGCC & BLM.pressure build during test had to pump 40 bbls of FSW down tubing to remove, Holh JSA shift change, work pipe to release packer no luck; release on/off tool POOH and laydown tubing hanger, RIH relatch onto packer work pipe get packer to release, POOH S/B 314 jts 9961 ft in derrick, L/D 9 jts 2 7/8 EUE 8rd L80 tubing,L/D 9 gas lift valves, 1 on/off tool,1-5 1/2 x 2 7/8 AS -1 packer with X nipple and WLEG, start R/U wireline 3/19/2014 3/18/2014 Hold JSA shift change discuss today s activities, R/U eline R/U lubricater test to 250 low 3000 high RIH with CIBP 5 1/2 x 20 Ib and set at 10450 ft MD, RIH E -line with dump bailer 2 runs baile 3" x 50 ' dump bail 33 gallons cement R/D Eline, break subs off gas lift valves; M/U BHA = 1- 61/2 junk mill, 1 -bit sub,1- 7 5/8 casing scraper, 1 xover, RIH BHA & 315 jts 2 7/8 EUE 8rd L80 tubing to 10002 ft load hole with FSW while tripping in, finish loading hole with FSW 310 bbls total reverse circulate bottems up 1x to purge trapped gas. close safety valve and pressure up well to 2700 psi on annulus hold and chart for 30 mins, POOH L/D 2 7/8 tubulars and BHA 315 jts, RIH with Eline to tag cement tag low at 10432 ft POOH, wait on cement 3/20/2014 3/19/2014 hold JSA shift change discuss todays goals, wait on cement police location of any trash, Rih with E -Line dump bail 32 gallons cement POOH, wait on cement to set do tasks around rig and location, RIH with bailer TAG cement at 10410 ft POOH, RIH with 7 5/8 CIBP set at 9420 ft MD POOH RDMO Priority E -Line, test and chart plug at 9420 ft to 2500 psi for 30 mins, set BPV N/D BOP and spool N/U dry hole tree remove BPV, rig down Moncla 405 and equipment 3/27/2014 3/26/2014 Moiles demobe civil contrator equipment 3/31/2014 3/30/2014 Moiles Expand and level pad - cost tracking entry Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/7/2014 4/6/2014 Joe Grubb/ Jimmy Rig down , steam, water, electric lines, rig down mud lines. ; Load out pits, pump houses, pipe houses, lay derrick down, unstring blocks, pull gen sets, boilers Greco houses. ; Remove derrick, draw works skid, unstack sub base, & load out, all rig modules on new location. ; Haul mats, lay felt and liner, lay mats, set poney subs 4/8/2014 4/7/2014 Joe Grubb/ Jimmy Set sub base, install draw works skid, install derrick, set water tank, gen sets, pump houses, pits, raise derrick. ; Install lights, hook up electrical lines, hook up Greco steam & water lines, start generator # 1 and bring on line, continue hooking up service lines 4/9/2014 4/8/2014 Joe Grubb/ Jimmy Install kill line, Hammer BOP bolts up on stack, PJSM with crane crew and install the windwalls on the pits and the rig floor. ; Scope Derrick and rig up torque tube, Greco straighten and secure tube to derrick.P/U topdrive and hook up lines. ; Lay down containment and spot catwalk, hook up hyd lines, spot both pipe sheds, install cattleshoot with crane. Spot Sperry, Baroid and Canrig's buildingsand hook power to same. ; Hook up kelly hose, tongs, bails, elevators. Put IBOP and saver sub on topdrive. Rigged up cameras and Pason. ; Test all alarms and emergency shut down system. Rig up the centrifuge. Rig up and test hoppers and mix pumps. Replaced cables on risers in mud pits and check system. ; Rig move 98.6% complete /// 20 bbls of Class II fluid hauled to KGF injection plant 4/10/2014 4/9/2014 Joe Grubb/James R/U Geronimo system, R/U Rotary table hydraulics, Install HCR lines, R/U BOP catch pan, Extended pincher nipple and install same, Remove I- beam under sub Sweetsir for installing flow line, Install mouse hole ; Install PSI lines for top drive and stand pipe, Install handy berm, R/U gas detection system, C/O wash pipe, Inspect and grease crown sheaves, Orient kelly hose, Function test top drive system ; C/O manual choke on maniflod, Function test iron roughneck, , Test pit equipment, Install koomey lines, Dress derrickboard. Accepted rig at 18:00 hrs ; Function test BOPE, Clean up work areas. ; M/U test joint, R/U test equipment, Fill stack and choke manifold, Check test equipment and shell test. Tested gas alarms ; Perform BOPE test as per Sundry, 250/ 2500 psi on annular, 250/ 3500 psi on all other BOPE tests, All tests are 10 min LOW and HIGH; TEST waived witness by AOGCC on 4/ 9/ 14 at 11:58 hrs by Jim Regg TEST witnessed by Justin Miller with BLM 4/11/2014 4/10/2014 Joe Grubb/James Continue testing BOPE, Had 2 failures, Rebuilt TIW valve and re -tested, C/O IBOP and re -tested, All tests were 10 minutes low and hi at 250/ 3500 psi; M/U Sweetsir 6.625" mill assembly, P/U 19 joints HWDP, Single in hole w/ DP, strapping and rabbitting pipe as we picked up off catwalk to tag CIBP at 9,408'; PJSM, Pump HI - vis sweep, tart Displacing well to 10 ppg drilling mud. �l Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/12/2014 4/11/2014 Joe Grubb/James Displace well w/ 10 ppg drilling mud @ 241 gpm= 275 psi. Sweetsir Blow down top drive. ; R/U and Test casing to 2500 psi for 30 minutes( charted) ; R/D Test equipment and blow down same. ; Pump dry job, POOH fr: 9,408' - surface. ; M/U BHA #2, Whipstock Assembly, Total length= 654.52', Shallow test MWD tools. ; RIH fr: 654.52'- 9,390' filling pipe every +- 2,500'; UP wt= 140k / DN wt= 140k, Pump up survey, Orient whipstock to 72 degrees left, Wash down fr: 9,390' and tag at 9,408', Set down 15k to set, P/U 10k over to verify set, Set down 20k to shear bolt. ; Hauled 220 bbls class II junk fluid to KGF Total hauled= 240 bbls Hauled 0 bbls of cuttings Total cuttings hauled= 90 bbls 4/13/2014 4/12/2014 J Grubb/J Sweetsir Cut window fr: 9.390'- 9.404' and Drill open hole to 9,424' 280 gpm= 1360 psi 80 rpm w/ 2-10k wob= 7-10k torque MW= 9.8 / VIS= 44 UP / ROT / DN = 135k / 140k / 135k; Ream through window multiple times, turned pumps off and slid through with no problems, Pumped Hi -vis sweep around Total metal from window= 120 lbs ;Shut in well and perform FIT test to 832 psi w/ 9.8 ppq mud= 11.5 ppq EMW ;Drill kelly down fr: 9,424'- 9,437', To be able to break connection at rig floor.; Circulate bottoms up w/280 gpm = 1360 psi, POOH to 9,314' ; C/O saver sub on top drive; Cut and slip 210' of drill line; Flow check, Pump dry job, Blow down mud lines, POOH fr: 9,314'- BHA, L/D Milling BHA; Install wear ring; M/U Directional drilling assembly, BIT, MOTOR, STAB, FLOAT SUB, MWD, Upload MWD data, Load nuke sources, CONT. P/U FLEX COLLAR, XO, 13 JTS HWDP ; Hauled 40 bbls of cuttings to KGF Cumulative hauled= 40 bbls Hauled 185 bbls of class II junk fluid to KGF Cumulative hauled= 425 bbls Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/14/2014 4/13/2014 J Grubb/J Sweetsir Trip in F/538' to 9031', Pick up 68 extra singles off the catwalk. ; Service Rig and drawworks, inspect Crown and topdrive ; Trip in down through the whipstock to bottom at 9437' NO problems going through window; Drill F/9437' to 9,650' AVG FPH= 17' 10-15K WOB W/ 80 RPM= 6K TORQUE 234 GPM= 1500 PSI MW= 9.8 / VIS= 44 UP / DN / ROT = 185K / 170K / 178K; No surveys do to magnetic interferance ; Last 24 hrs 0 Cuttings Hauled to KGF Total of 40 bbls cuttings hauled to KGF 4/15/2014 4/14/2014 J Grubb/J Sweetsir Drill fr: 9,650'- 9,990' AVG ROP= 14.2' FPH 15K WOB W/ 89 RPM= 5950 TORQUE 250 GPM = 1845 PSI MW= 9.8 / VIS= 45 UP / DN / ROT = 185K / 174K / 178K; Hauled 145 bbls of cuttings to KGF Total hauled= 185 bbls Hauled o bbls of class II junk fluid today Total hauled= 425; 17' BELOW LINE / 17.95' CTC / 5' RIGHT OF LINE Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744:448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/16/2014 4/15/2014 R pederson/J Sweetsir Cont drilling 6.125" production hole f/9990' to 10,101'. WOB 15K, 85 rpm -5673 ft/lbs, 249 gpm-1748 psi, ROP 6 to 33 ft/hr, MW 9.8 ppg/46 vis. Flow increased to 3.3 bph, start increase MW to 10.0 ppg. ; Cont MW increase to 10.0 ppg, pump 20 bbl hi -vis sweep around at 258 gpm-1721 psi. 45 rpm -5000 ft/lbs off bott torque, BGG at 18 units. Flow check at 2 bph. ; POOH on elevators f/10,101' to 9,215' (inside 7 5/8" casing). Up wt 194K. Didn't see anything pulling through window; Monitor well, Flowing at 1.9 bbls per hour, Pump dry job, Blow down mud lines. ; POOH fr: 9,215'- BHA, Remove RA source,Download MWD data. Flow checked at 5,800' ( flowing at 2.1 bph ) Jars had damage on top of the snap ring groove. ; Hauled 105 bbls of cuttings to KGF Total hauled= 290 bbls Hauled 30 bbls of class II junk fluid to KGF Total hauled= 455 bbls ; . 10' below line / 10' CTC / .84' right of line . ; TOTAL SLIDE TIME= 18.71 HOURS TOTAL ROTATING TIME= 21.38 HOURS TOTAL DRILLING TIME= 40.09 Hilcorp Alaska, LLC Drilling Composite Report Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Rpt Date Activity Date Field Supervisor Ops Summary 4/17/2014 4/16/2014 R Pederson / J Download MWD and rack back same. Pull motor through table and remove bit. Motor in good condition. Bit graded at 3 -4 -ER -A -E -1 -WT -HR. MU new 6 1/8" Sweetsir HDBS MM64D PDC bit. ; Run motor in hole, MU topdrive on TM collar, pump through tools to warm same, upload MWD. Shallow test MWD (OK), load RA source. ; RIH with 13 jnts HWDP. Swap out drilling jars and run remaining 13 jnts HWDP to 970'. ; RIH with directional BHA on 4 1/2" DP, filling pipe every 25 stands from 970' to 8600'. Well flowing at 1.25 bph thorughout entire trip thus far. ; Cont TIH f/8600' to 9305'. Fill pipe and orient highside. Ease through window from 9390' to 9404' with no problem. Cont RIH from 9404' to TAG fill at 10,086' ; Wash down fr: 10,086'- 10,101' at 60 rpm's w/ 2-5k wob At bottoms up weight on balance scale weight was 7.4 ppg and 9.7 on pressure scale ( didn't dump any mud ) MAX gas was 750 units. ; Drill fr: 10,101'- 10,111' 2-16k wob, 45-80 rpm's= 5.5k- 6.2k torque Adjusted perameters to try to get it to drill MAX rop we ever saw was 5 FPH UP / DN / ROT= 180K / 166K / 174K MW= 10PPG / VIS= 45 ; Drill fr: 10,111'- 10,124' 14k wob w/ 80 rpm's= 6k torque Pumped nut plug sweep, When it exited the bit ROP immediately went up to 15 ; Lost generator to Drilling support offices which caused us to lose PASON to rig Brought portable light plant to plug in to toolpusher office main PASON computer to get rig running ; Drill fr: 10,124'- 10,153' 13k wob w/ 80 rpm's= 6k torque ROP= +- 17 FPH MW= 10 PPG / VIS= 46 UP / DN / ROT= 180K/ 166K/ 174K;. GOT GENERATOR SWAPPED OUT FOR OFFICES AT 06:00 HOURS: Hauled 30 bbls of cuttings to KGF Total hauled is 320 bbls ART= 4.04 AST= 1.42 ADT= 5.46; were right on the line left to right were 8.7' below line Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341 744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/18/2014 4/17/2014 R Pederson / J Cont drilling 6 1/8" hole f/10,153' to 10,420'. Sweetsir Rotating: 6K wob, 80 rpm -7100 ft/lbs, 277 gpm-2222 psi, 11 to 57 ft/hr ROP. Sliding: 3 to 8K wob, 278 gpm-2006 psi, 126 psi diff, 12 to 26 ft/hr. ; Continue drilling fr: 10,420'- 10,705'- ROP 15-50 FPH 6-8k wob w/ 85 rpm's= 8200 torque 275 gpm= 2220 psi up / do / rot = 190k / 166k / 178k mw= 10 / vis= 46 ; Grease crown, blocks, topdrive and drawworks ; AST= 8.52 hours ART= 9.19 hours ADT= 17.71 hours ; Hauled 115 bbls of cuttings to KGF Total hauled= 435 Hauled 105 bbls of class II junk fluid to KGF Total hauled= 560 bbls ; 2.83' below line / 5.1' CTC / 4.24' left of line Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/19/2014 4/18/2014 R Pederson / J Cont drilling 6 1/8" hole f/10,705' to 10,829'. Rotating: 7K wob, 80 rpm -8100 ft/lbs on bott torque, 278 gpm-2318 psi, control drilling at 50 ft/hr, BGG 36 units, 10 Sweetsir ppg/45 vis. ; Stop drilling for wiper trip. 10,829' is right at the SR fault crossing. Pump 20 bbl hi -vis sweep around at 278 gpm-1998 psi, 80 rpm -6400 ft/lbs off bott torque, up wt 201 K, dwn wt 165K, rot wt 175K. ; POOH f/10,829' to 9956' (13 stnds) with no overpull issues. Up wt 215K. ; Monitor well for 30 min. Flow stable at 1.25 bph. ; RIH on elevators from 9956' to 10,769' with no issues. MU topdrive on last stand and wash to bottom with no fill. ; Circ DP volume to remove air and orient for slide prior to connection. Max trip gas 278 units. ; Make connection at 10,829'. Drilled f/10,829' to 10,986', Rotating: 6K wob, 70 rpm -7800 ft/lbs on bott torque, 280 gpm-2120 psi. Up wt 21 OK, dwn wt 174K, rot wt 186K. ; Cont drilling fr: 10,986' to 11,065' Holding ROP at 50 FPH 6k wob w/ 70 rpm's= 7825 torque 275 gpm= 2100 psi MW= 10 ppg / VIS= 46 ; At 11,065' we started losing fluid at a rate of 30 BPH Increased background LCM fr: 20 to 30 ppb Decreased pump fr: 275 to 225 GPM Increased water fr: 3 to 10 BPH LOSSES decreased fr: 30 to +/- 13 BP ; Continue drilling fr: 11,065' to 11,165' at 6k wob w/ 70 rpm's= 7800 torque 225 gpm= 1300 psi / / LOST total returns at 11,165' ; Continue drilling f/11,165' with no returns while pumping HI -VIS 40 PPB LCM pills, gained partial returns at 11,187', drilled to 11,200' at 220 gpm= 1150 psi ; POOH to 11,140' and circulated at 117 GPM= 700 psi while building 140 bbls volume and building 35 bbl at 40 PPB LCM pill ; Pumped 35 BBL -150 VIS/ 40 PPB LCM pill and spotted outside of pipe at 117 GPM with 710 PSI ; POOH fr: 11,140' to 10,766' on elevators, up wt 215K, dwn wt 168K, rot wt 180K. ; ADT: 12.23 hrs, ART: 11.96 hrs, AST: 0.27 hrs. Currently 5.47' below and 4.59' right of the line. ; Hauled 60 bbls cuttings to KGF G&I, total hauled 495 bbls. Hauled 125 bbls class 11 fluid to KGF G&I, total hauled 685 bbls. ; Total Losses to date: 560 bbls Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/20/2014 4/19/2014 R Pederson / J Cont pull up hole from 10,766' to 8967' (inside 7 5/8" casing), no issues pulling BHA through window at 9390'. ; Monitor losses while building 600 bbls surface Sweetsir volume at 9.8 ppg. Initial losses at 25 bph. Final losses 19 bph. Built 50 bbl 40 ppb LCM pill and loaded on vac truck, built 25 bbl hi -vis pill. ; RIH 34 stnds on elevators f/8967' to 11,074'. No issues going through window, no issues in open hole. Down wt 170K. ; MU topdrive and break circ at 117 gpm= 939 psi. Once we achieved SPP lined up and pumped 50 bbls of 40 ppb LCM at 170 gpm-660 psi, followed with 20 bbls hi -vis pill. ; Chased with 2650 strokes (152 bbls) to clear pipe. ; POOH on elevators from 11,074' to 9,000', up wt 215K, no overpull issues in open hole, no issues pulling BHA through window. ; Monitor well on trip tank, Losses are at 9 BPH While monitoring we had a H2S rig evacuation drill and also went over DONNING and DOFFING a SCBA with crew.; Continue POOH fr: 9,000'- BHA, Rack back all HWDP and JARS, Remove RA source, Download MWD data. LOSSES while POOH are 9.5 BPH; . TOTAL fluids lost= 321 BBLS last 24 hours; Built 340 bbls of 3% KCL and stored in upright tanks at skim pit Hilcorp Alaska, LLC Drilling Composite Report Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Rpt Date Activity Date Field Supervisor Ops Summary 4/21/2014 4/20/2014 R Pederson / J Cont POOH LD directional BHA. Bit graded at 1 -1 -PN -N -X -1 -NO -TD. ; Clean and clear rig floor while monitoring wellbore. Well appears to be static at surface with Sweetsir no drop or flow in wellbore. ; MU cleanout assembly as follows: Smith 6 1/8" XR20 rollercone bit (no jets), bit sub, 5.812" stab, XO, 13 jnts HWDP, XO, jars, XO, 13 jnts HWDP, followed with 4 1/2" CDS 40 DP. ; BHA length 845.88'. Tripped in hole slow from 845' to 10,695', filled pipe every 25 stands. Fluid loss 30 bbls for last 12 hrs. ; Continue RIH slowly fr:10,695'- 11,075' LOSSES while RIH were +-4 BPH ; Wash fr: 11,075'- 11,150', (Tagged fill at 11,150') Started pumping at 117 gpm= 540 psi Slowly worked pump rate to 225 gpm= 780 psi Losses at 225 gpm were 30 bph Decreased to 200 gpm= 24 bph losses ; Built 50 bbl LCM pill at 50 ppb fine, medium and course Also built 25 bbl hi vis pill in preperation for spotting on bottom when we got cleaned out to 11,200' ; At bottoms up gas spiked at 640 units Cuttings were 50% coal about .3" X.3" size and 50% LCM and calcium carb Weight was water cut to 9.5 ppg also Returns cleaned up after +- 50 bbls past BU ; Reamed fr: 11,150'- 11,200', Took 5' bites at a time to decrease the chance of losses due to bringing up fill 200 gpm= 675 psi 2-5k wob w/ 20 rpm's= 6500 torque LOSSES were 24 BPH while reaming; CBU at 200 gpm= 675 psi Got 80% LCM,calcium carb and 20% coal and sand back at BU LOSSES were 24 BPH while circulating ; Pumped 40 bbls of LCM pill (50 ppb, fine, med,coarse) followed by 20 bbl HI -VIS pill and spotted outside pipe at 111 gpm= 380 psi LOSSES were 21 BPH while pumping; POOH fr: 11,200'- 9,220', up wt= 210k NO issues in open hole or going through window LOSSES were 13.5 BPH while POOH ; Monitor well for losses while letting LCM and HI -VIS pills soak in formation LOSSES @ 3:30 am were 12 BPH LOSSES @ 4:30 am were 11 BPH LOSSES @ 5:30 am were 10.5 BPH Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/22/2014 4/21/2014 R Pederson / J Cont to monitor losses on trip tank. Losses stabilized at 8.5 bph. Drill string sitting inside 7 5/8" casing at 9220'. ; PJSM on RIH and building LCM pills. ; RIH on Sweetsir elevators from 9220' to 10,775'(25 stnds). No issue going through window or in open hole. Build 65 bbls 70 ppb LCM pill and stage on vac truck. ; MU top drive and fill pipe at 111 gpm-354 psi, for 752 strokes. Build 25 bbls hi -vis pill in pill pit. ; Cont RIH on elevators from 10,775' to 11,200'. No bridges, no fill, open hole in good shape. ; MU topdrive and ease into circulation. Initial rate 111 gpm then up to 168 gpm-588 psi. Increased pump rate to 200 gpm-700 psi. Had max of 601 units gas at bottoms up, MW cut to; 9.6 ppg at bottoms up. Lined up and pumped 65 bbls of 70 ppb LCM pill followed with 20 bbls hi -vis pill. Chased pills with 2663 strokes (154 bbls) to clear drill string at 4 bpm -518 psi ; while rotating at 20 rpm -6931 ft/lbs off bott torque, and reciprocating slowly. Total losses while circulating and spotting pills = 20 bbls. ; POOH on elevators from 11,200' to 9339' (inside 7 5/8" casing) with no issues in open hole or pulling BHA through window. Up wt 230K. ; Monitor well on trip tank, prep pipeshed to LD excess DP. Drop 2" drift with wire, turn elevators. Lost 2.6 bbls in 15 minutes. ; Cont POOH from 9339' to 7,045' laying down drill pipe. ; Continue POOH racking back DP and 9 stands of HWDP, UD excess HWDP, jars, stab, bitsub and bit; Remove wear bushing from wellhead ; Clean rig floor from wet trip and clear BHA items off rig floor; R/U Weatherford casing handling equipment, prep rig floor and pipe shed for running casing. Went to test power tongs and blew a seal, C/O seal and it blew out immediately again. ; R/D power tongs and the NEW powerpack and R/U back up power tongs and OLDER powerpack. ..Tested power tongs, all works well... ; PJSM, Put shoe joint in rotary table. ; Hauled 40 bbls cuttings to KGF G&I Losses last 24 hrs = 236 Total losses to date = 1305 bbls fTl Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/23/2014 4/22/2014 R Pederson / J Greco PJSM with rig crew, Baker Reps and Weatherford Reps on liner run and working aorund casing ton__,c s_ ; Clean threads and BakerLok shoetrack assemby. Fill pipe and verify floats function properly (OK). Installed two standoff bands per joint first 15 joints, separated by stop ring mid joint. ; PU RIH with a total of 48 full joints 4 1/2" 12.6# DWC/C-HT 3.958" ID liner (3 marker pup jnts), top filling each joint, fill to capacity each 10 jnts. Torqued to 6K. Up wt 38K, dwn wt 38K. ; Top fill liner while CO elevators to 3 1/2", PU the HRDE ZXPN Flex -Lock liner top packer and hanger assembly. Mix and install PalMix and allow to set while RD Weatherford. ; Plug pinned for 850 psi, hanger pinned for 2111 psi, release pinned at 3304 psi and packer set pinned at 40K. ; PJSM discuss RIH with liner hanger. CO to 4 1/2" elevators, MU XO on first stand HWDP, MU topdrive and pump 3 bpm -85 psi, up wt 42K, dwn wt 42K, 10 rpm -2400 ft/lbs, ; 20 rpm -2400 ft/lbs. ; RIH 8 more stnds HWDP then with 4 1/2" DP, top filling on the fly, MU topdrive and fill pipe every 2,000'. RIH at 2 minutes per stand. ; Calculated displacement 6 bbls per 5 stnds, actual displacement 5 bbls per 5 stnds. Filled pipe at 4,000', 5990', 8220'. RIH with liner on 4 1/2" DP, F/ 8220'T/ 9331' at 2 min per stand. ; Circ surface to surface at 48 stks/min, well taking 8 bph, at 10 RPM p/u 146, s/o 142, rt trq 2700 ft/lbs, at 20 rpm p/u 142, s/o 142, trq 2850 ft/lbs, 20 bbl lost while circ. ; Pick up baker cement head and make up single joint DP on bottom of head, L/D cement head on cat walk. ; Continue RIH with liner on 4 1/2" DP from 9331' to 10,486'. Up wt 180K, dwn wt 165K. ; Hauled 30 bbls Class II fluid to KGF G&I Total Class II fluid hauled: 715 bbls Hauled 0 bbls cuttings to KGF G&I Total cuttings hauled: 560 bbls ; Lost 240 bbls last 24 hours Total bbls lost to date: 1516.6 bbls Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 API #: 50-133-20276-01-00 Spud Date: 4/12/2014 Job Name: 1410656D SCU 44-05 Drill Contractor Saxon 169 Hilcorp Alaska, LLC Drilling Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 4/24/2014 4/23/2014 R Pederson / J Greco Cont RIH slow from 10,486' to 11,200' (TD) with 4 1/2" liner and hanger assembly on 4 1/2" CDS-40 drill pipe. Wash through tight spots at 10,652', 10,745' and 10,797' with no problem. ; No rotating through tight spots, pumped 2.5 bpm. Had 2' fill on bottom. Up wt 182K, dwn wt 170K. Washed last stand to bottom at 2.5 bpm -415 psi. 10 rpm = 4900 to 5400 ft/lbs torque. ; Circ through cement head and topdrive initially at 2.5 bpm -415 psi, lost 6 bbls first hour, staged up to 3 bpm - 433 psi, lost 6 bbls second hour, staged up to 4 bpm -554 psi, lost 12 bbls third hour. ; Reciprocate string every 10 minutes, up wt 181 K, dwn wt 180K while pumping and rotating. Small amount of fine coal and LCM at bott up, no water cut to mud weight. ; Reduced pump rate to 3 bpm -417 psi and RU hardline to rig floor, top off frac tank with produce water, transfer mud in pits for returns, MU hardline on rig floor. ; PJSM with SLB, Baker, Peak, rig team on RU hardline and PT same. ; Install hardline to cement head, SLB pumped 5 bbls water, shut in upper and lower TIW on cement head. SLB PT line at 1000 and 6000 psi f/5 minutes each. Good test. ; Line up to rig and cont circ at 3 bpm -417 psi, SLB begin batch mixing 80 bbls 15.3 cement rig crew installed snatch block and snub line to n d,�_Rgpumped 41 bbls 12 ppg MudPush II at 5 bpm -422 psi. Lined upon SLB. SLB pumped 73 bbls (330sx) 15.3 pia cement at 5 bpm -400 to 500 �r1- �(`-ce psi wit full returns, eci rocated string once every 10 minutes ; w/20' stroke. Up wt 202K, dwn wt 180K. Dropped dart, lined up and SLB displaced with 8.5 ppg produce -wate 7 bpm -400 psi ICP. ; Started rotate and reciprocate non-stop, 83 bbls into displacement, 10 rpm -5600 ft/lbs torque. Up wt 186K, dwn wt 175K. Slowed to 2 bpm and saw dart latch wiper plug at 118 bbls into displacement, ; increased pump rate to 4 bpm -1500 psi and stopped rotation of string, parked string on depth with 10 bbl to go. Reduced pump rate to 2 bpm -1800 psi, bumped plug/landing ; collar at 158 bbls displaced, fcp 1800 psi, held 2800 psi (1000 over fcp) f/3 minutes, bled back 1 bbl to truck, floats holding. CIP at 16:30 on 4-23-14. ; Pumped a total of 272 bbls (Mud Push, cement and displacement) with 217 bbis returns. Lost 55 bbis throughout the lob. ; Set HRD ZXP liner top packer as per Baker, pressured up to 2500 psi, then up to 3000 psi and held 2 minutes. SO to 90K, PU to 115K. PU 7? to clear dogs, SO and did not tag 5? early. ; Pressure up to 4200 psi, held 2 minutes then bled off. Hanger still not set. Pressure up to 5500 psi and held 2 minutes. Hanger still not set. ; P/U to 140K, rt to left 2 turns, s/o to 120K, p/u to 140K rt 1 turn left, s/o to 115K, p/u to 142K rt to right 3 turns, and safety off, Top of liner hanger at 9179', top of landing collar at 10,077'. ; SLB press up DP to 500 psi, PU out of hanger and start pumping as psi dropped using 8.5 ppg produce water. Increase rate to 6 bpm -1020 psi and CBU 1 time. ; Had +/- 35 bbls MudPush II to surface (max 11.0 ppg) and little or no cement., test liner lap at 1000 psi, test good. ; Rack back cement head, drop 4.5" wiper ball and CBU one more time with rig using produce water. Had +/- 35 bbls MudPush II to surface (max 11.0 ppg) and little or no cement on first circ. ; Lay down drill pipe F/ 9109'T/ 8271'. ; Lay down cement head. ; Continue laying down drill pipe F/ 8271'T/1 179' ; Service rig and topdrive. ; Lost 133 bbls last 24 hours Total fluid lost to hole: 1649.6 bbls ; Hauled 100 bbis class II fluids T/ KGF, Total Class II fluids hauled = 815 bbis 0 bbls cutting hauled to KGF - Total cutting hauled = 560 bbls ,s ka, LLC osite Report Ops Summary and Baker run tool. Total Safety RD gas detection equipment. ;, I l ana d teat$" x 4 1/2" casing/liner at oved SLB cement equipment, 3 pipe shed modules and pipe bunks to Tyler Pad. ; Cameron Rep landed 1s are 3 1/2" EUE 8rnd in hanger. Moved Canrig, Sperry and Mudman shacks, various other non - 9 and flowline, ND BOP stack, choke and kill lines. Cont transporting mud to storage, produce water to stall dry hole tree, test void to 2500 psi f/15 min then 5000 psi f/30 minutes. Good tests. Shipped out ibo tools. Crane on location. ; Ru and remove cattle chute, remove catwalk roof, lay over beaver slide, )ses, load and ship mud products to staging area. ; Remove saver sub, RD tongs, cont cleaning pits, cont )rage tanks. ; RD/LD torque tube, RD containment on frac tank, ship frac tank to Tyler pad, scope down ne from centrifuge, unspool drilling line. ; Lay derrick down, finish cleaning pits, disconnect service lines, Released at 06:00 on 4-25-14 ; Haul 150 bbls class II fluids to KGF, Total hauled T/ KGF G&I = 965 bbls, DIS Hilcorp Alaska, LLC Completion Composite Report Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 Job Name: 1410656C SCU 44-05 Completion Rpt Date Activity Date Field Supervisor Ops Summary 5/17/2014 5/16/2014 Laura Katelnikoff cost entry 5/28/2014 5/27/2014 Laura Katelnikoff Held JSA and discussed job to be preformed, Laid containment and set a TWC in hanger, ND dry hole tree/NU 11' spool section and BOP's. Finail BOP witness notifacatinn MIRU WOR anti asGn6;gtt-rI anidnmPnt 5/29/2014 5/28/2014 Laura Katelnikoff Held JSA and discussed jobs to be preformed, Finished RU sub base, rig floor and manifolds., Test BOP'sequipment. Valves 250-3000psi, Rams 250-3000psi, Annular 250-1500psi. 1 FP on inside gray. Test time 6hrs and all test were charted for 10mins. SDFN 5/30/2014 5/29/2014 Laura Katelnikoff Held JSA and discussed work to be preformed., MU Landing jt, Backed out lock down pins and pulled tbg hanger., RU cat walk and perp rig to trip pipe. When to the SCU 33-33 to move rods off of AWS pipe racks and haul them to the 44-05., When to Rio pan and picked up 16 jts of 2-3/8" 8rd tbg. Waited on WBI to bring tbg from Tuboscope. Load was scheduled to arrive on location at 9am. WBI for dropped the ball and didnt pickup the pipe until 1 lam from tbg scope., MU 3-3/4" bit and sub, TIH w/16jts of 2-3/8" 8rd tbg., Tbg arrived on location, Unload onto AWS pipe racks. Tallied and TIH with 14jts. Blowout a hydraulic hose on the pipe skate. SDFN- ASW machine took hose in to repair over night. 5/3"1/LU"14 5/,JU/LU]4 uan byra sr 5atety ivieeting JSH, Mewasure ana p1cK up 110 joints of z //8" LUE tubing tagged up at 10751'., Pick up power swivel and pump and rotate. Tighten swivel ' packing and kelly hose, wash down to 10766'. SDFN. 6/1/2014 5/31/2014 Dan Byrd Sr Safety Meeting JSA, Wash and ream from 10751' to 11041' pump 3.5 bpm at 1100psi. 1300 torgue. Drilled L/C and cement from 11041' to 11073'., Circulate hole clean, Short trip from 11073' to 10700', run back in hole to 11073'., Circulate at 3.5 bpm and rig up filter unit., Filter fluid and empty dirty fluids from pits. 6/2/2014 6/1/2014 Dan Byrd Sr Safety Meeting JSA, Switch out filter units., Filter and circulate fluid to 10 microns., Rig down swivel, rig up test pump, test liner packer and casing to 3000 psi for 30 min. test good., POOH to 6000', pull 79 stds., Rig up Shlumberger to pump nitrogen, test lines to 2500 psi 5 mins. Pumped 120,000 cubic ft. of nitrogen. Recover 254bbls. fluid. 6/3/2014 6/2/2014 Dan Byrd Sr Safety Meeting JSA, POOH w/ 2 7/8 and 2 3/8 tubing, L/D bit, bit sub, X.O., Rig down flow nipple. Rig up Pollard.RIH with CBL. Tagged at 11040'. Rig down Pollard., Rig up to RIH to drill 50' more cement. Pick up bit, bit sub, X.O.RIH fill hole while running in hole. 6/4/2014 6/3/2014 Dan Byrd Sr Safety Meeting JSA, RIH with 3 3/4 bit, Pick up power swivel.Drill cement from 11073' to 11135', 4-6K on bit, 80 rpm, 3.5bpm., Circulate set back swivel, pull 3 stds. test cas . 3000 psi 30 min. Test Good 6/5/2014 6/4/2014 Dan Byrd Sr Safety Meeting JSA, RIH to 11135', rig up power swivel., Circ., mix and filter 470bbls 3% KCL., Rig down swivel POOH to 6000' 6/6/2014 6/5/2014 Dan Byrd Sr Safety Meeting JSA, Rig up BJ Baker to pump nitrogen, test lines to 3000 psi. Displace brine with 150,000 cubic ft. nitrogen., Rig down BJ Baker., POOH for BOPE test. Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 Job Name: 1410656C SCU 44-05 Completion Hilcorp Alaska, LLC Completion Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 6/7/2014 6/6/2014 Dan Byrd Sr Safety Meeting JSA with Pollard wireline, Rig up Pollard Wireline, remove flow nipple, install shooting finge and lubricator. Test to 1000psi for 5 min. Good., Run in with Gamma and CCL alone tag at 11140', Run in hole with Gamma, CCL and 15' pert gun. Corralate, shot from 11 072'to 11087' MD / 6 SPF POOH, Run in hole with Gamma, CCL and 28' erf gun. Corralate, shot from 11020' to 11048' MD / 6 SPF POOH 6/8/2014 6/7/2014 Dan Byrd Sr Safety Meeing JSA for running completion, Rig up and prep to run completion.Pick up completion. Entry guide, X -nipple, DLH Packer, chem. injection, (2) 2 3/8 GLM (5) 2 7/8 GLM, Tubing hanger,(398 bands on chem. injection line., Pick up tubing hanger, land hanger.Drop bar to set packer. Pressure to 3500psi hold for 30min. SDFN 6/9/2014 6/8/2014 Dan Byrd Sr Safety Meeting JSA, Rig up to test casing and 4 1/2"DLH packer.Test failed pressured to 1200psi at 2.5 bpm. Rigged up to reset packer, pressured to 4500psi 3 times then retest failed, pressured to 5000psi 3 times retest, failed. Unscrew lockdowns pull 20k over string wt., retest casing pump 1200psi, 2.5 bpm, test failed., Wait on Baker pumping to set packer, Rig up Baker pumping test lines to 7500psi, Open tubing pressure to 7000 psi, retest casing and packer, failed, pumping away at 2.5b m, 1200 si.SDFN 6/10/2014 6/9/2014 Dan Byrd Sr Safety Meeting JSA, Level rig, inspect drilling line., Work pipe at 123k, did not shear packer, work pipe at 130k, sheared packer after working for 10 min. Lay down hanger and pups. (hole took 60bbls fluid and gave some gas), Rig up pollard to pull setting bar, rig up lubricator, RIH, pull setting bar, rig down Pollard., POOH, with tubing and stainless steel injection line, 4 1/2" packer.SDFN 6/11/2014 6/10/2014 Dan Byrd Sr Safety Meeting JSA, POOH lay down GLM, packer, X nipple. Lost 19 bands in hole., Rig up Pollard wireline, run 6.24 OD wireline junk basket, no recovery, run 3.725 OD recovered 1 band. ran 3.7OD wiregrab recovered 1 band, tools tagging out at 11109'.Recovered 5 bands total, still tagging at 11109'. SDFN 6/12/2014 6/11/2014 Dan Byrd Sr Safety Meeting JSA for running completion., Pick up Mule shoe, X profile nipple with RHC plug, injection mandrel, packer, GLM, run in hole. Total bands in hole 206., Pick up and land hanger.Drop setting bar. Pressure to 3000 psi set packer.Hold 30 min. Rig up on casing pressure to 2500 psi hold 30 mi., Set back pressure valve. Rig down and nipple down BOPE 6/13/2014 6/12/2014 Dan Byrd Sr Safety Meeting JSA for nipple down., Demob rig floor move out sub base. Nipple down BOPE install production tree.Test tree 250 psi low, 5000 psi high., Demob ri move to D&D yard. 6/14/2014 6/13/2014 Dan Byrd Sr Safety Meeting JSA Demob rig to D&D yard, RU slickline. PT lubricator to 250/1,500 psi - test OK. RIH w/ 1.87" GR to 10,615' RKB, tag RHBC plug. RIH and pull dummy valves 7 GLM, 1 CIM)., RIH w/ live valves (top 5 GLM). 6/15/2014 6/14/2014 Billy Applewhite RIH w/ live valves in 2-3/8" GLM and 2-3/8" CIM. Standby for production to gaslift fluid. RIH w/ 2.0" JDC, set down at 9,856' SLM. POOH. RIH w/ 1.75" LIB to 10,615' SLM. Impression of fill. RIH w/ 2.0" SB to 10,615' SLM. POOH w/ RHBC ball and rod. RIH w/ 2-3/8" GS to 10,619' SLM. POOH w/ RHBC plug body. Rig down slickline. Turn well over to production. 6/19/2014 6/18/2014 Billy Applewhite SIMOPS, PTW, JSA. Mobe to location and spot equipment, Rig up lubricator, pressure test to 250 psi low and 1500 psi high., RIH w/1.75" GR, tie into Pollard pert log and tag fill at 11,070'. POOH, RIH w/1-5/8" NeoWideRange TTBP, tie into Pollard Perf log and set plug at 11,000'. Look like good set. POOH., RIH w/1-11/16" bailer of ceramic beads and set down at 10,633' correlated depth and 10,656' schematic depth. POOH and glass bottom of bailer was broken. Looks like plug was pulled back in tubing tail., Wait on LIB., RIH w/1.8" LIB and tag obstruction at 10,633' correlated depth. POOH. LIB showed Top of vent on plug., Rig down lubricator and secure well. Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 Job Name: 1410656C SCU 44-05 Completion Hilcorp Alaska, LLC Completion Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 6/21/2014 6/20/2014 Billy Applewhite MIRU SL. Test lub to 2,500psi-test ok. RIH w/ 1.75 bail with the bottom cut off to go over fish. Tag fish at 10,715'slm. EOT @ 10,662'slm. Tapped down on fish twice and fish fall to bottom. Continued TIH to 11,075' without tagging. POOH. RDMO SL., Waited on E -line Unit., MIRU EL. Pressure tested to 2,500psi-Test ok. TIH w/ 1.5 TTBP to 11,060'. Made correlation pass to 10,750'. RIH to CCL depth at 10,980. Set plug at 11,000'. PU 40' and back down tagging plug to confirm set. POOH., MU 1 11/16" dump bailer and loaded with beads. TIH to top of pump to open disk. POOH, PU csg conditioner and TIH to top of plug. Dumped the conditioner and POOH, PU 4 10' section 1 11/16" dump bailer and filled with 4 gals of cement. RIH and dump on top of plug (9.77' of cement). POOH. RD EL, secured well and SDFN 6/22/2014 6/21/2014 Billy Applewhite PJSM, PTW and JSA. Mobe to location and spot equiipment. PT lubricator to 250 psi low and 3500 psi high., RIH with 1.8" LIB and tie into Pollard CCL/GR used to set plug. Tag vent at 10,978' (11' high than est). POOH. LIB showed vent., RIH w/1 -11/16"x40' (Approx 5.1' per dump) dump bailer and dump cement at 10,978'. POOH. Good dump., RIH w/1 -11/16"x40' dump bailer and dump cement at 10,9775'. POOH. Good dump., RIH w/1 -11/16"x40' dump bailer and dump cement at 10,972'. POOH. Good dump. NOTE: Cement in Place at 2343 hrs., Rig down lubricator. WOC. Est top of cement 10,966'. 21' cement total onplug) 6/24/2014 6/23/2014 Billy Applewhite RU Pollard E -line. PT Lubricator to 250/1,500 psi - test OK., MU 30' of 1-11/16" Owen Hollow Carrier. RIH and correlate to Halliburton LWD log dated 4/20/14. Correlate guns on depth. Misfire. POOH., Repair perf gun and RIH w/ Gun #1. Correlate guns on depth. Gaslift out fluid in tubing down to GLM at 8,124' (approx. 35 bbl). SITP = 400 psi. Perforate interval from 10,786'-10,816'. POOH. All shots fired. SITP = 1,200 psi in 60 mins., RIH w/ Gun #2. Correlate guns on depth. Open well to production to lower tubing, then shut-in. SITP = 600 psi. Perforate interval from 10,747'-10,772'. POOH. All shots fired., RIH w/ Gun #3. Correlate guns on depth. SITP = 800 psi. Perforate interval from 10,701'-10,722' and 10,725'-10,735'. POOH. All shots fired., RIH w/ Gun #4. Correlate guns on depth. SITP = 1,000 psi. Perforate interval from 10,678'-10,696'. POOH. All shots fired., Rig down. Turn well over to production. 6/27/2014 6/26/2014 Chris Walgenbach See Pollard WSR 6/26/14. 7/5/2014 7/4/2014 James Ostroot Obtain permit and RU Pollard slickline. MU lubricator and tool string, stab on well. Well flowing 510 BFPD @ 150 psi FTP. GL @ 1.7 MMCFD and 960 psi. Formation gas 100 MCFD., Pressure test lubricator to 1500 psi, fix leaking plug- good test., RIH w/ 1.75" GR and tag solid @ 10,959 MD RKB. POOH. OOH- GR full of hard packed sand/possible dry cement. NOTE: last estimated TOC on plug is 10,966'., MU Pressure/Temperature/Spinner memory tool string. NOTE: PT gauges are T above spinner/bottom of tool., RIH w/ P/T/Spinner tool as follows: 3 min stop @ tubing hanger; RIH 120 FPM, 3 min stop @ 10,660'; RIH 60 FPM, 10 min stop @ 10,890'; POOH 60 FPM w/ 3 min stops from 10,820'-10,660' every 5'(33 stops); POOH 120 FPM, 3 min stop @ tubing hanger., LD tool string and lubricator. Download data- good data. RD Pollard. Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 Job Name: 1410656C SCU 44-05 Completion Hilcorp Alaska, LLC Completion Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 5/28/2014 5/27/2014 Laura Katelnikoff Held JSA and discussed job to be preformed, Laid containment and set a TWC in hanger, ND dry hole tree/NU 11' spool section and BOP's. Email BOP witness notifacation, MIRU WOR and associated equipment 5/29/2014 5/28/2014 Laura Katelnikoff Held JSA and discussed jobs to be preformed, Finished RU sub base, rig floor and manifolds., Test BOP'sequipment. Valves 250-3000psi, Rams 250-3000psi, Annular 250-1500psi. 1 FP on inside gray. Test time 6hrs and all test were charted for 10mins. SDFN 5/30/2014 5/29/2014 Laura Katelnikoff Held JSA and discussed work to be preformed., MU Landing jt, Backed out lock down pins and pulled tbg hanger., RU cat walk and perp rig to trip pipe. When to the SCU 33-33 to move rods off of AWS pipe racks and haul them to the 44-05., When to Rio pan and picked up 16 jts of 2-3/8" 8rd tbg. Waited on WBI to bring tbg from Tuboscope. Load was scheduled to arrive on location at 9am. WBI for dropped the ball and didnt pickup the pipe until 11 am from tbg scope., MU 3-3/4" bit and sub, TIH w/16jts of 2-3/8" 8rd tbg., Tbg arrived on location, Unload onto AWS pipe racks. Tallied and TIH with 14jts. Blowout a hydraulic hose on the pipe skate. SDFN- ASW machine took hose in to repair over night. 5/31/2014 5/30/2014 Dan Byrd Sr Safety Meeting JSA, Mewasure and pick up 270 joints of 2 7/8" EUE tubing tagged up at 10751'., Pick up power swivel and pump and rotate. Tighten swivel ackin and kelly hose, wash down to 10766'. SDFN. 6/1/2014 5/31/2014 Dan Byrd Sr Safety Meeting JSA, Wash and ream from 10751' to 11041' pump 3.5 bpm at 1100psi. 1300 torgue. Drilled L/C and cement from 11041' to 11073'., Circulate hole clean, Short trip from 11073' to 10700', run back in hole to 11073'., Circulate at 3.5 bpm and rig up filter unit., Filter fluid and empty dirty fluids from pits. 6/2/2014 6/1/2014 Dan Byrd Sr Safety Meeting JSA, Switch out filter units., Filter and circulate fluid to 10 microns., Rig down swivel, rig up test pump, test liner packer and casing to 3000 psi for 30 min. test good., POOH to 6000', pull 79 stds., Rig up Shlumberger to pump nitrogen, test lines to 2500 psi 5 mins. Pumped 120,000 cubic ft. of nitro en.Recover254bbls. fluid. 6/3/2014 6/2/2014 Dan Byrd Sr Safety Meeting JSA, POOH w/ 2 7/8 and 2 3/8 tubing, L/D bit, bit sub, X.O., Rig down flow nipple. Rig up Pollard.RIH with h CBL. Tagged at 11040'. Rig down Pollard., Rig up to RIH to drill 50' more cement. Pick up bit, bit sub, X.O.RIH fill hole while running in hole. '- 6/4/2014 6/3/2014 Dan Byrd Sr Safety Meeting JSA, RIH with 3 3/4 bit, Pick up power swivel.Drill cement from 11073' to 11135', 4-6K on bit, 80 rpm, 3.5bpm., Circulate set back swivel, pull 3 stds. test cas . 3000 psi 30 min. Test Good 6/5/2014 6/4/2014 Dan Byrd Sr Safety Meeting JSA, RIH to 11135', rig up power swivel., Circ., mix and filter 470bbls 3% KCL., Rig down swivel POOH to 6000' 6/6/2014 6/5/2014 Dan Byrd Sr Safety Meeting JSA, Rig up BJ Baker to pump nitrogen, test lines to 3000 psi. Displace brine with 150,000 cubic ft. nitrogen., Rig down BJ Baker., POOH for BOPE test. Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 Job Name: 1410656C SCU 44-05 Completion Hilcorp Alaska, LLC Completion Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 6/7/2014 6/6/2014 Dan Byrd Sr Safety Meeting JSA with Pollard wireline, Rig up Pollard Wireline, remove flow nipple, install shooting finge and lubricator. Test to 1000psi for 5 min. Good., Run in with Gamma and CCL alone tag at 11140', Run in hole with Gamma, CCL and 15' pert gun. Corralate, shot from 11072' to 11087' MD / 6 SPF POOH, Run in hole with Gamma, CCL and 28' erf gun. Corralate, shot from 11020' to 11048' MD / 6 SPF POOH 6/8/2014 6/7/2014 Dan Byrd Sr Safety Meeing JSA for running completion, Rig up and prep to run completion.Pick up completion. Entry guide, X -nipple, DLH Packer, chem. injection, (2) 2 3/8 GLM (5) 2 7/8 GLM, Tubing hanger,(398 bands on chem. injection line., Pick up tubing hanger, land hanger.Drop bar to set packer. Pressure to 3500psi hold for 30min. SDFN 6/9/2014 6/8/2014 Dan Byrd Sr Safety Meeting JSA, Rig up to test casing and 4 1/2"DLH packer.Test failed pressured to 1200psi at 2.5 bpm. Rigged up to reset packer, pressured to 4500psi 3 times then retest failed, pressured to 5000psi 3 times retest, failed. Unscrew lockdowns pull 20k over string wt., retest casing pump 1200psi, 2.5 bpm, test failed., Wait on Baker pumping to set packer, Rig up Baker pumping test lines to 7500psi, Open tubing pressure to 7000 psi, retest casing and packer, failed, pumping away at 2.5b m, 1200 si.SDFN 6/10/2014 6/9/2014 Dan Byrd Sr Safety Meeting JSA, Level rig, inspect drilling line., Work pipe at 123k, did not shear packer, work pipe at 130k, sheared packer after working for 10 min. Lay down hanger and pups. (hole took 60bbls fluid and gave some gas), Rig up pollard to pull setting bar, rig up lubricator, RIH, pull setting bar, rig down Pollard., POOH, with tubing and stainless steel injection line, 4 1/2" packer.SDFN 6/11/2014 6/10/2014 Dan Byrd Sr Safety Meeting JSA, POOH lay down GLM, packer, X nipple.Lost 19 bands in hole., Rig up Pollard wireline, run 6.24 OD wireline junk basket, no recovery, run 3.725 OD recovered 1 band. ran 3.7OD wiregrab recovered 1 band, tools tagging out at 11109'.Recovered 5 bands total, still tagging at 11109'. SDFN 6/12/2014 6/11/2014 Dan Byrd Sr Safety Meeting JSA for running completion., Pick up Mule shoe, X profile nipple with RHC plug, injection mandrel, packer, GLM, run in hole. Total bands in hole 206., Pick up and land hanger.Drop setting bar. Pressure to 3000 psi set packer.Hold 30 min. Rig up on casing pressure to 2500 psi hold 30 mi., Set back pressure valve. Rig down and nipple down BOPE 6/13/2014 6/12/2014 Dan Byrd Sr Safety Meeting JSA for nipple down., Demob rig floor move out sub base. Nipple down BOPE install production tree.Test tree 250 psi low, 5000 psi high., Demob ri move to D&D yard. 6/14/2014 6/13/2014 Dan Byrd Sr Safety Meeting JSA Demob rig to D&D yard, RU slickline. PT lubricator to 250/1,500 psi - test OK. RIH w/ 1.87" GR to 10,615' RKB, tag RHBC plug. RIH and pull dummy valves 7 GLM, 1 CIM)., RIH w/ live valves (top 5 GLM). 6/15/2014 6/14/2014 Billy Applewhite RIH w/ live valves in 2-3/8" GLM and 2-3/8" CIM. Standby for production to gaslift fluid. RIH w/ 2.0" JDC, set down at 9,856' SLM. POOH. RIH w/ 1.75" LIB to 10,615' SLM. Impression of fill. RIH w/ 2.0" SB to 10,615' SLM. POOH w/ RHBC ball and rod. RIH w/ 2-3/8" GS to 10,619' SLM. POOH w/ RHBC plug body. Rig down slickline. Turn well over to production. 6/19/2014 6/18/2014 Billy Applewhite SIMOPS, PTW, JSA. Mobe to location and spot equipment, Rig up lubricator, pressure test to 250 psi low and 1500 psi high., RIH w/1.75" GR, tie into Pollard perf log and tag fill at 11,070'. POOH, RIH w/1-5/8" NeoWideRange TTBP, tie into Pollard Perf log and set plug at 11,000'. Look like good set. POOH., RIH w/1-11/16" bailer of ceramic beads and set down at 10,633' correlated depth and 10,656' schematic depth. POOH and glass bottom of bailer was broken. Looks like plug was pulled back in tubing tail., Wait on LIB., RIH w/1.8" LIB and tag obstruction at 10,633' correlated depth. POOH. LIB showed Top of vent on plug., Rig down lubricator and secure well. Well Name: SRF SCU 44-05 (SCU 33-5 ST) Field: Swanson River Field State: Alaska Location (LAT/LONG): 2457909.946 / 341744.448 Job Name: 1410656C SCU 44-05 Completion Hilcorp Alaska, LLC Completion Composite Report Rpt Date Activity Date Field Supervisor Ops Summary 6/21/2014 6/20/2014 Billy Applewhite MIRU SL. Test lub to 2,500psi-test ok. RIH w/ 1.75 bail with the bottom cut off to go over fish. Tag fish at 10,715'slm. EOT @ 10,662'slm. Tapped down on fish twice and fish fall to bottom. Continued TIH to 11,075' without tagging. POOH. RDMO SL., Waited on E -line Unit., MIRU EL. Pressure tested to 2,500psi-Test ok. TIH w/ 1.5 TTBP to 11,060'. Made correlation pass to 10,750'. RIH to CCL depth at 10,980. Set plug at 11,000'. PU 40' and back down tagging plug to confirm set. POOH., MU 1 11/16" dump bailer and loaded with beads. TIH to top of pump to open disk. POOH, PU csg conditioner and TIH to top of plug. Dumped the conditioner and POOH, PU 4 10' section 1 11/16" dump bailer and filled with 4 gals of cement. RIH and dump on top of plug (9.77' of cement). POOH. RD EL, secured well and SDFN 6/22/2014 6/21/2014 Billy Applewhite PJSM, PTW and JSA. Mobe to location and spot equiipment. PT lubricator to 250 psi low and 3500 psi high., RIH with 1.8" LIB and tie into Pollard CCUGR used to set plug. Tag vent at 10,978'(1 V high than est). POOH. LIB showed vent., RIH w/1 -11/16"x40' (Approx 5.1' per dump) dump bailer and dump cement at 10,978'. POOH. Good dump., RIH w/1 -11/16"x40' dump bailer and dump cement at 10,9775'. POOH. Good dump., RIH w/1 -11/16"x40' dump bailer and dump cement at 10,972'. POOH. Good dump. NOTE: Cement in Place at 2343 hrs., Rig down lubricator. WOC. Est top of cement 10,966'. 21' cement total onplug) 6/24/2014 6/23/2014 Billy Applewhite RU Pollard E -line. PT Lubricator to 250/1,500 psi - test OK., MU 30' of 1-11/16" Owen Hollow Carrier. RIH and correlate to Halliburton LWD log dated 4/20/14. Correlate guns on depth. Misfire. POOH., Repair perf gun and RIH w/ Gun #1. Correlate guns on depth. Gaslift out fluid in tubing down to GLM at 8,124' (approx. 35 bbl). SITP = 400 psi. Perforate interval from 10,786'-10,816'. POOH. All shots fired. SITP = 1,200 psi in 60 mins., RIH w/ Gun #2. Correlate guns on depth. Open well to production to lower tubing, then shut-in. SITP = 600 psi. Perforate interval from 10,747'-10,772'. POOH. All shots fired., RIH w/ Gun #3. Correlate guns on depth. SITP = 800 psi. Perforate interval from 10,701'-10,722' and 10,725'-10,735'. POOH. All shots fired., RIH w/ Gun #4. Correlate guns on depth. SITP = 1,000 psi. Perforate interval from 10,678'-10,696'. POOH. All shots fired., Rig down. Turn well over to production. 6/27/2014 6/26/2014 Chris Walgenbach See Pollard WSR 6/26/14. 7/5/2014 7/4/2014 James Ostroot Obtain permit and RU Pollard slickline. MU lubricator and tool string, stab on well. Well flowing 510 BFPD @ 150 psi FTP. GL @ 1.7 MMCFD and 960 psi. Formation gas 100 MCFD., Pressure test lubricator to 1500 psi, fix leaking plug- good test., RIH w/ 1.75" GR and tag solid @ 10,959 MD RKB. POOH. OOH- GR full of hard packed sand/possible dry cement NOTE. last estimated TOC on plug is 10,966'., MU Pressure/Temperature/Spinner memory tool string. NOTE: PT gauges are T above spinner/bottom of tool., RIH w/ P/T/Spinner tool as follows: 3 min stop @ tubing hanger; RIH 120 FPM, 3 min stop @ 10,660'; RIH 60 FPM, 10 min stop @ 10,890'; POOH 60 FPM w/ 3 min stops from 10,820'-10,660' every 5' (33 stops); POOH 120 FPM, 3 min stop @ tubing hanger., LD tool string and lubricator. Download data- good data. RD Pollard. Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No. SCU 44-05 County Kenai Peninsula Burough State Alaska CASING RECORD TD 11200.00 Shoe Depth 11200.00 Supv Date 23 -Apr -14 Rance Pederson / Jimmy Greco PBTD: 11,077.49' MD / 10,823' TVD Csg Wt. On Hook: 140,976 Type Float Collar: Float No. Hrs to Run: 21.5 Csg Wt. On Slips: N/A Type of Shoe: Bullnose Casing Crew: Wfd Fluid Description: 9.8 ppg 6% KCL / PV = 10 YP=15 HTHP = 15.9 Liner hanger Info (Make/Model): HRD-E ZXPN PKR - Flex -Lock Liner Hanger Liner top Packer?: X Yes No Liner hanger test pressure: 1000 and 3000 Centralizer Placement: Centralizers on each joint in shoe track, Stand off band on joints 5 thru 42 . Total of 55 CFMF_NTING RFPnRT Preflush (Spacer) Casing (Or Liner) Detail Setting Depths No. of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 41/2 Density (ppg) 15.3 BTC Wfd 1.62 11,200.00 11,198.38 2 41/2 12.6 L-80 BTC 79.71 11,159.39 11,159.39 F. Collar 41/2 Post Flush (Spacer) BTC Wfd 1.34 11,118.67 11,117.33 1 41/2 12.6 L-80 BTC 38.76 11,117.33 11,078.57 Landing collar 41/2 FCP (psi): 1800 Pump used for BTC Non -Baker 1.08 11,078.57 11,077.49 48 41/2 12.6 L-80 BTC X Yes No Vol to Surf: 35 bbls Spacer 1,865.36 9,252.63 11,036.70 LH/PKR 75/8 Method Used To Determine TOC: BTC Baker 30.80 9,210.71 9,180.00 Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Density (ppg) Volume pumped (BBLs) Totals Tail Slurry UJ Type: Csg Wt. On Hook: 140,976 Type Float Collar: Float No. Hrs to Run: 21.5 Csg Wt. On Slips: N/A Type of Shoe: Bullnose Casing Crew: Wfd Fluid Description: 9.8 ppg 6% KCL / PV = 10 YP=15 HTHP = 15.9 Liner hanger Info (Make/Model): HRD-E ZXPN PKR - Flex -Lock Liner Hanger Liner top Packer?: X Yes No Liner hanger test pressure: 1000 and 3000 Centralizer Placement: Centralizers on each joint in shoe track, Stand off band on joints 5 thru 42 . Total of 55 CFMF_NTING RFPnRT 9570` J"" Preflush (Spacer) Type: Mud Push II Density (ppg) 12 Volume pumped (BBLs) 45 Lead Slurry > Type: EZBLOK Density (ppg) 15.3 Volume pumped (BBLs) 73 Mixing / Pumping Rate (bpm): 5 Tail Slurry Type: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): co Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Produce water Density (ppg) 8.5 ppg Rate (bpm): 5 bpm Volume (actual / calculated): 147/156 FCP (psi): 1800 Pump used for disp: Schlumberger Plug Bumped? X Yes No Bump press 2800 Casing Rotated? X Yes No Reciprocated? X. Yes No % Returns during job 80 Cement returns to surface? Yes X No Spacer returns? X Yes No Vol to Surf: 35 bbls Spacer Cement In Place At: 16:30 Date: 4/23/2014 Estimated TOC: 9179' Method Used To Determine TOC: Volume Calculation Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry UJ Type: �Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm) u) Post Flush (Spacer) 0 z Type: Density (ppg) Rate (bpm): Volume:0 U Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped? No Bump press Casing Rotated? Yes No Reciprocated? _Yes 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: 9570` J"" Landon Ellison Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 IN, i'rii hi'hi .1,11. Fax: 907 777-8510 E-mail: lellison@hilcorp.com DATE 05/21/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 E log data Prints: ROP DGR EWR-Phase4 ALD CTN MD DGR EWR-Phase4 ALD CTN TVD CD 1 : Final Well Data Name Date modified T�vpe CGIVI 4,x25,'201411;.11 .x.€+11 File fodder DUS+I.AS 4/25/201411,11 AM File fc[der EMF 4/25/201411;11 ,+s.M File folder PDF 4125/2014 11:11 AM File folder TIFF 4/25/201411,11 AM File folder CD 2: Directional survey 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: Landon Ellison Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 Ifileorli :UaMkca. I,I.4; Fax: 907 777-8510 E-mail: lellison@hilcorp.com DATE 05/21/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Mudlog data Prints: Final Well Report Formation Log MD 2" Formation Log TVD 2- LWD Combo Log MD 2" LWD Combo Log TVD 2" Drilling Dynamics MD 2" Drilling Dynamics TVD 2" Gas Ratio Log MD 2" Gas Ratio Log TVD 2" CD 1 : Final Well Data A Files Currently on the Disc (7) Daily Reports DML Data LAS Data Log PDFs Log TIFFs Show Reports SCU 44 -05 -Final Well Report 5-11-2014.pdf 5./11/2014 3:47 131`,�1 File folder 5r`11/2014 3:47 PP.,,I File fclder 5/11/2014 3:47 PPaI File fcfder 5/11/2014 3:47 PPA File folder 5,11/2014 3:47 13P,,1 File fodder 5/11/2014 3;47 Pl%I File folder 5/11/2014 33.2 PfVI Adobe Acrobat D... Please include current contact information if different from above. .256 K8 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: Hilrnrp .hawk U A DATE 05/21/14 L .idon Ellison Hilcorp Alaska, L GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 Fax: 907 777-8510 E-mail: lellison@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 E log data Prints: ROP DGR EWR-Phase4 ALD CTN MD DGR EWR-Phase4 ALD CTN TVD CD 1 : Final Well Data 2' �2°l 3 Name CGM DLIS+ LAS EMF PDF TIFF CD 2: Directional survey '2_4( Z9 y Date modified Type 4/25,1201411:11 AM Filefolder 4/25,'201411:11 AM File folder 4/°25,{2111411:11 AM File folder 4/''25;°201411:11 AM File folder 4/25/201411:11 AM File folder Please include current contact information if different from above. 2\4-03q DATA LOGGED B 2Z/2014 M K BENDER RECEI , MAY 2 ] 2G14 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: L_ .idon Ellison Hilcorp Alaska, L GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 Hilrurp tlu+ka, LLAT Fax: 907 777-8510 E-mail: lellison@hilcorp.com DATA LOGGED /I012014 Z M K BENDER DATE 05/21/14 RECEIVED To: Alaska Oil & Gas Conservation Commission I'My 2 1 2014 Makana Bender Natural Resource Technician ��11,, GCC 333 W 7th Ave Ste 100 l:. Anchorage, AK 99501 Mudlog data Prints: Final Well Report Formation Log MD 2" Formation Log TVD 2" LWD Combo Log MD 2" LWD Combo Log TVD 2" Drilling Dynamics MD 2" Drilling Dynamics TVD 2" Gas Ratio Log MD 2" Gas Ratio Log TVD 2" CD 1 : Final Well Data . Files Currently on the Disc (7) Daily Reports 5/11,/2014 3:47 PM File folder DML Data 5;"11?`2014 3:47 HA File folder LAS Data 5/11/2f114 3:47 PM File folder Log PDFs 5,11,x'2014 3:47 PtA File folder Log TIFFS 5,x.1/'2014 3:47 PM File folder Show Reports 5/1112014 3:47 Plot File folder '[ SCU 44-05_Final Well Report 5-11-2014.pdf 5/11,`2014 3:32 PM Adobe Acrobat D... 256 KB 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: THE STATE GOVERNOR SEAN PARNE t Stan Porhola Operations Engineer Hilcorp Alaska, LLC 1 t ..- O-39' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 44-05 Sundry Number: 314-276 Dear Mr. Porhola: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 t0ain: 907.279.1433 Fcx: 907.276.7541-> 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 Aday of May, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 iRFECEIVED APR 3 0 2014 AI 1. Type of Request: Abandon ❑ Plug for RedriL Perforate New Pod ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ j Perforated Pull Tubing❑ s j) l' -Time Extension ❑ Operations Shutdovn ❑ 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 Stratigraphic ❑ Service ❑ 214-038 - 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-20276-01 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes ❑ No ❑Q Soldotna Creek Unit (SCU) 44-05 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028996 . I Swanson River / Hemlock Oil 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): 10,870 10,760 10,827 10,723 WA WA Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,32T 3,130psi 1,580psi Intermediate Production 9,390' 7-5/8" 19,390' 9,379 6,020psi 3,400psi Liner 4-1/2" 11,200' 10,924' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A WA WA 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 ❑ BOP Sketch n Exploratory n Stratigraphic❑ Development n Service ❑ 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: 05/10/14 p Oil Gas ❑ ❑ WDSPL ❑ Suspended ❑ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email s orhola hilco.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date — �o COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test [d Mechanical Integrity Test ❑ Location Clearance ❑ Other: + 3060 RBE�MAY 0 7 2014 `A Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY _ Approved by: COMMISSIONER THE COMMISSION Date: S - /� Submit Form and Form 10-403 (Revised 10/2012) Af )vR�ppcatl�t a t fir 12 months from the date of approval. Attachments in Duplicate Hilcorp Alaska, LU Well Prognosis Well: SCU 44-05 Date: 04/30/2014 Well Name: SCU 44-05 API Number: 50-133-20276-01 Current Status: New Sidetrack Oil Well Leg: N/A Estimated Start Date: May 10th, 2014 Rig: Aurora AWS #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-038 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: 1410656C Current Bottom Hole Pressure: — 0 psi @ 10,784' TVD (Well is not perforated) Maximum Expected BHP: — 2,600 psi @ 10,784' TVD (Estimated pressure based on offsets) Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir at 4,030' TVD.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05. A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated. A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench. The well has had limited productivity since this workover (approximately 1 bopd on gaslift). The well was plugged back and sidetracked as SCU 44-05 in April 2014. The purpose of this work/sundry is to run the initial completion on this sidetrack. Notes Regarding Wellbore Condition Well filled with 8.5 ppg produced water. Tubing hanger landed w/ BPV installed. Lift threads are 3-1/2" 8RD. WO Rig Procedure: 1. MIRU Aurora AWS #1 WO Rig. 2. 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. 3. Bleed any pressure off casing. Pull BPV. 4. Pull tubing hanger and lay down. a. Lift threads are 3-1/2" 8RD. 5. PU 3-3/4" bit on 2-7/8" DP and XO to 2-7/8" 8RD. 6. RIH to above liner top. 7. RU and pressure test liner lap to 3,000 psi for 30 min and chart 'Co F �r 8. RIH and tag landing collar at 11,077'. 3 9. Drill out landing collar and cement to float collar at 11,117'. 10. Circulate well clean w/ 8.5 ppg produced water. 11. kOH. LD 3-3/4" bit, and 2-7/8" DP. 12. PU 4-1/2" casing scraper and XO to 2-3/8" 8RD and XO to 2-7/8" 8RD. 13. RIH to float collar at 11,117'. Scrape packer interval at +/- 10,570'. Hilcorp Alaska, LU Well Prognosis Well: SCU 44-05 Date: 04/30/2014 14. Circulate well clean w/ 8.5 ppg 3% KCI fluid (filter fluid going downhole). 15. POOH. LD 4-1/2" Casing Scraper. 16. MIRU E -line. 17. RIH and run cement bond log from PBTD (11,117') to 9,000' MD. 18. RD E -line. 19. PU completion jewelry and hydraulic packer. 20. RIH and set packer at +/- 10,570' MD. a. Leave tubing tail to land at +/- 10,650'. b. Pre -load lower X -profile with RHCP plug (load plug in proper direction). c. Use bands to secure chemical injection line to tubing. d. Space out Gaslift Mandrels per proposed schematic. e. Run dummy valves in Gaslift Mandrels. f. Run dummy valve in Chemical Injection Mandrel. 21. Drop RHCP prong. Pressure up to 3,500 psi and set hydraulic packer. 22. Test tubing to 3,500 psi for 30 min and chart. 23. Test casing to 2,500 psi for 30 min and chart. 24. Set BPV. ND ROPE. NU tree. Pull BPV. Set TWC. Test tree to 250/5,000 psi. Pull TWC. 25. RD Aurora AWS #1 WO Rig. 26. Turn well over to production. 27. Replace IA x OA pressure gauge if removed (7-5/8" x 10-3/4"). Slickline Procedure: 28. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 29. RIH and pull prong from RHBC plug. POOH. 30. RIH and pull dummy valves from each gaslift mandrel (9 mandrels). POOH. 31. RIH and pull dummy valve from the chemical injection mandrel. POOH. 32. RIH and set live valve in chemical injection mandrel. POOH. 33. RIH and set live valves in each gaslift mandrel (9 mandrels). POOH. 34. RIH and pull RHBC plug body from X -profile. POOH. 35. RIH w/ 1.75"x20' dummy gun and tag PBTD. POOH. E -line Procedure: 36. Rig up gaslift lines to tree. Production to gaslift off top of well to achieve desired underbalance. a. Est BHP = 2,600 psi. Est underbalance = 500 psi (Fluid level at GLM #4 @ 6,400'). 37. MIRU E -line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 38. RU 1-11/6" 6 spf HC wireline guns (will make 1 run per interval, 28' gun and 15' gun). �rt� 39. Bleed tubing pressure down to 150 psi or line pressure, as directed by Reservoir Engineer., 40. RIH and perforate the Hemlock H-12 from 11,072'-111087' (151 (1 run total of 6 spf). 41. RIH and perforate the Hemlock H-11 from 11,020'-11,048' (28')_(l run total of 6 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. d. Correlate using proposed Cement Bond log. (Tie-in log depth is pending). e. Record tubing pressures before and after each perforating run. 42. RD E -line. 43. Turn well over to production. Hilcorp Alaska, LLI Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic Well Prognosis Well: SCU 44-05 Date: 04/30/2014 20", 10-3/4', Ground Elev: 152.0' Above MSL KB -THF = 19.28'/ KB -GL = 17.5' TD = 11,200'/ PBTD = 11,077' MD TD = 10,924'/ PBTD = 10,828' MD Soldotna Creek Unit Well SCU 44-05 Liner Run: 4/23/2014 ACTUAL SCHEMATIC PTD: 214-038 API: 50-133-20276-01 CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10;050 Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 11,200' TUBING DETAIL Tubing JEWELRY DETAIL NO. Depth ID OD Item PERFORATIONS (Open Hole) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Length Date Max Dev. 41- @ 10,667' Downhole Revised: 4/23/14 Updated by STP 4/29/14 20' Soldotna Creek Unit Well SCU 44-05 PROPOSED SCHEMATIC PTDo214038pletion na,• „„ �i:,.� :,. u.r API: 50-133-20276-01 Ground Elev: 152.0' Above MSL KB -THF = 19.28'/ KB -GL = 17.5' CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" 2 20' 2.441" 3.668" Surf 44' Surface 30-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29'7 N-80 BTC 6.875" 1 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390 Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 1 11,200' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 9,150' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 9,150' 10,650' JEWELRY DETAIL NO. Depth ID OD Item 1 19' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x Box 2 20' 2.441" 3.668" XO, 3-1/2" 8RD Pin x 2-7/8" 8RD Pin 3 2,300' 2.441" 4.750" 2-7/8" SFO -1 Mandrel 8RD #1 4 4,000' 2.441" 4.750" 2-7/8" SFO -1 Mandrel 8RD #2 5 5,300' 2.441" 4.750" 2-7/8" SFO -1 Mandrel 8RD #3 6 6,400' 2.441" 4.750" 2-7/8" SFO -1 Mandrel 8RD #4 7 7,300' 2.441" 4.750" 2-7/8" SFO -1 Mandrel 8RD #5 8 8,100' 2.441" 4.750" 2-7/8" SFO -1 Mandrel 8RD #6 9 8,900' 2.441" 4.750" 2-7/8" SFO -1 Mandrel 8RD #7 10 9,150' 1.995" 3.063" XO, 2-7/8" 8RD x 2-3/8" 8RD 11 10,000' 1.990" 3.750" 2-3/8" GLMAX-1 Mandrel 8RD #8 (T-1 latch) 12 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 Mandrel 8RD #9 (T-1 latch) 13 10,530' 1.990" 3.750" Chemical Injection Mandrel 14 10,570' 1.950" 4.125" DLH Hydraulic Packer (40k to release) 15 10,620' 1.875" 3.063" X -Nipple 16 10,650' 1.995" 3.063" WL Entry Guide PERFORATIONS (Open Hole) Top Btm Top Btm Size SPF Length Date (MD) (MD) (TVD) (TVD) .1,020' 11,048' 10,784' 10,806' 6 1-11/16" 28 Proposed .1,072' 11,087' 10,824' 10,836' 6 1-11/16" 15 Proposed TD = 11,200'/ PBTD = 11,117' 1 Max Dev. 41' @ 10,667' Downhole Revised: 4/23/14 Updated by STP 4/30/14 Floor 0 Aurora Well Service 3000# BOP Stack 11" Shaffer 3K 14' 1" —►Starting Head Varies n A - 31116" SK HCR valve B - 31116" SK Gate valve C - 31116" 6K Gate valve D - 31116" SK HCR valve E - 3" 200# Ball Valve 11" Shaffer 3K ! -� PIPE RAMS i i 11" Shaffer 3K BLIND RAMS III ._... i Will 1 i- 14' 1" —►Starting Head Varies n A - 31116" SK HCR valve B - 31116" SK Gate valve C - 31116" 6K Gate valve D - 31116" SK HCR valve E - 3" 200# Ball Valve THE STATE Gj0VLRN0R SLAN PARNLLL Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 44-05 Sundry Number: 314-368 Dear Mr. Porhola: 333 'Wesl Sevenih Avenue A.nc'roroce. Alosko 99501-3572 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 . Foerster Chair DATED this glda of June, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUN 16 2014 QTS 610110,- 1. 1191tq_, 1. T e of Request: Abandon Type q ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ ' Change Approved Program ❑ Suspend ❑ Plug Perforations Perforate Q Pull Tubing❑ Time Extension ❑ Operations Shutdom ❑ 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 1Z 1 Stratigraphic ❑ Service ❑ 214-038 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99503 50-133-20276-01 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes ❑ No Soldotna Creek Unit (SCU) 44-05 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028996 I Swanson River/ Hemlock Oil , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 1 Plugs (measured): Junk (measured): 10,870 10,760 10,827 10,723 ' WA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,327' 3,130psi 1,580psi Intermediate Production 9,390' 7-5/8" 9,390' 9,379 6,020psi 3,400psi Liner 2,020' 4-1/2" 11,200' 10,924' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8"x2-3/8" 6.5#/L-80 x 4.7#/L-80 9,241'x 10,656' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Halliburton G-77 Hydraulic Packer; N/A 10,585' MD/10,452' TVD; N/A 12. Attachments: Description Summary of Proposal ❑- 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory n Stratigraphic❑ Development n , Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 06/20/14 Oil ❑✓ • Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email s orhola hilco.com Printed Name Stan Porhola/ Title Operations Engineer Signature. Phone 907-777-8412 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: � Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: i c _JM APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 (Revised 10/2012)l% d l d or 12 months from the date of approva . Attachments in Duplicate RBEMS JUN 19 204 Hilcorp Alaska, LL, Well Prognosis Well: SCU 44-05 Date: 06/16/2014 Well Name: SCU 44-05 API Number: 50-133-20276-01 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: June 201h, 2014 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-038 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: 1410656C Current Bottom Hole Pressure: — 2,600 psi @ 10,784' TVD (Estimated pressure based on offsets) Maximum Expected BHP: — 2,600 psi @ 10,784' TVD (Estimated pressure based on offsets) Max. Allowable Surface Pressure: — 0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir at 4,030' TVD.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05. A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated. A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench. The well has had limited productivity since this workover (approximately 1 bopd on gaslift). The well was plugged back and sidetracked as SCU 44-05 in April 2014. Following the sidetrack of this well, the completion was ran with the Aurora AWS #1 in June 2014, completed in the Hemlock H-11 and H-12. These zones were shown to be wet and non-productive. The purpose of this work/sundry is to plugback the H-11 and H-12 and recomplete uphole in the H-1 thru H-3. / Notes Regarding Wellbore Condition 0 Well placed on production on 6/14/14. Zones H-11 and H-12 tested wet. E -line Procedure: 1. MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low. a. Tree connection is 3-1/2" Bowen. b. SITP will be 150 to 200 psi. 2. MU 1-5/8" NeoWideRange TTBP. JL' 3. RIH and set thru-tubing bridge plug at 11,000' MD in the 4-1/2" 12.6#. 4. RU 1-11/16" bailer, dump bail 10' of cement on tubing plug (6.4 gallons of cement) to achieve a cement top at 10,990'. 5. Wait on cement 18 hours. 6. RIH w/ 1.75" GR and tag cement at +/- 10,990'. 7. RU 1-11/16" 6 spf Owen Hollow Carrier guns (will make multiple gun runs, 104' net perfs). 8. RIH and perforate Hemlock H-1 thru H-3 interval from 10,678'-10,816' (1 run each, total of 6 spf). c. Bleed tubing pressure to 180 psi before perforating d. Proposed perfs shown on the proposed schematic in red font. e. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. f. Correlate using Halliburton LWD Log dated 4/20/14 (Tie-in log depth is 10.678'-10.816'). q. Use Gamma/CCL/ to correlate. L Hilcorp Alaska, LLQ h. Record tubing pressures before and after each perforating run. L No Spacing allowance required in Swanson River per CO 1236. RD E -line. 10. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic Well Prognosis Well: SCU 44-05 Date: 06/16/2014 RKB: 169.5' / GL: 152' AMSL KB — THF: 19.28' 1 zo" f � 2 44' 10-3/4" 3,372' CBL CBL 4,240' lil�, I I I 4 6 CBL CBL x' Size 9,100' Grade 7 ID 8 Btm. TOL LA I 20" 9,180,- ,180'.7-5/8" 19.75' 2.441" 3.668" Surf 44' 7-5/8"9 30-3/4" 9,390' K-55 CBL TOC 10 10.050" 9,570' 11 12 13 7X 14 ' y� fi 4 1 + fly' 'a H-11 14 Bands H 12 11,109' SLM 15 6/10/14 r 4-1/2" '- 11,200' TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' PIllpl l\ irl.J y lA\1A Type Size WT Grade Conn ID Top Btm. Conductor 20" - 19.75' 2.441" 3.668" Surf 44' Surface 30-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 11,200 TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 9,142' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 9,142' 10,656' JFWFLRY DFTAII No. Depth ID OD Item 1 19.28' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x Box 2 19.75' 2.441" 3.668" XO, 3-1/2" 8RD Pin x 2-7/8" 8RD Box 3 2,755' 2.441" 4.750" 2-7/8" SFO -1 GLM #7 (Dummy) 4 4,956' 2.441" 4.750" 2-7/8" SFO -1 GLM #6 (Dummy) 5 6,779' 2.441" 4.750" 2-7/8" SFO -1 GLM #5 (Dummy) 6 8,124' 2.441" 4.750" 2-7/8" SFO -1 GLM #4 (Dummy) 7 9,129' 2.441" 4.750" 2-7/8" SFO -1 GLM #3 (Dummy) 8 9,142' 1.995" 3.063" XO, 2-7/8" 8RD x 2-3/8" 8RD 9 9,848' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #2 (T-1 latch) (Dummy) 30 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #1(T-1 latch) (Dummy) 11 10,543' 1.990" 3.750" Chemical Injection Mandrel (Dummy) 12 10,585' 1.940" 3.750" Halliburton G-77 Hydraulic Packer (15k to release) 13 10,622' 1.875" 3.063" X -Nipple 14 10,656' 1.995" 3.063" WL Entry Guide 15 11,109' - Fish —14 control line bands WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Actual Schematic 06-11-14 Updated by STP 6/12/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Stm(TVD) SPF Ft Phase Comments 6/06/14 H-11 11,020' 11,048' 1 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 H-12 11,072' 11,087' 10,824' 10,836 6 15 60 2-7/8" Connex WELL DATA PTD: 214-038 API: 50-133-20276-03 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Actual Schematic 06-11-14 Updated by STP 6/12/14 RKB: 169.5'/ GL: 152' AMSL KB — THF: 19.28' 20" 1 44' 2 3 10-3/4" 3,372' CBL CBL 4,240' 4 6 CBL CBL 9,100' 71 8 TOL 9,180' 7-5/8"9 9,390' CBL TOC 10 9,570' 11 12 13 14 15 CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" - 19.75' 2.441" - Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 9,390' Liner 4-1/2" 12.6 L-80 DWC/C-HT 3.958" 9,180' 11,200' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD 2.441" Surf 9,142' Tubing 2-3/8" 4.7 L-80 8RD 1.995" 9,142' 10,656' JEWELRY DETAIL No. Depth ID OD Item 1 19.28' 2.992" - Tubing Hanger, 3-1/2" 8RD Box x Box 2 19.75' 2.441" 3.668" XO, 3-1/2" 8RD Pin x 2-7/8" 8RD Box 3 2,755' 2.441" 4.750" 2-7/8" SFO -1 GLM #7 (Dummy) 4 4,956' 2.441" 4.750" 2-7/8" SFO -1 GLM #6 (Dummy) 5 6,779' 2.441" 4.750" 2-7/8" SFO -1 GLM #5 (Dummy) 6 8,124' 2.441" 4.750" 2-7/8" SFO -1 GLM #4 (Dummy) 7 9,129' 2.441" 4.750" 2-7/8" SFO -1 GLM #3 (Dummy) 8 9,142' 1.995" 3.063" XO, 2-7/8" 8RD x 2-3/8" 8RD 9 9,848' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #2 (T-1 latch) (Dummy) 10 10,500' 1.990" 3.750" 2-3/8" GLMAX-1 GLM #1(T-1 latch) (Dummy) 11 10,543' 1.990" 3.750" Chemical Injection Mandrel (Dummy) 12 10,585' 1.940" 3.750" Halliburton G-77 Hydraulic Packer (15k to release) 13 10,622' 1.875" 3.063" X -Nipple 14 10,656' 1.995" 3.063" WL Entry Guide 15 11,000' 60 2-7/8" Connex Thru-Tubing Plug (Capped w/ 10' of Cement) 16 11,109' 1 11,087' 10,824' Fish —14 control line bands H-1 1 H-2 H3 H-11 goJML 14 Bands H-12 W E n5 11,109' SLM 16 6/10/14 4-1/2" 11,200' TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 06-16-14 Updated by STP 6/16/14 PERFORATION DETAIL Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments Proposed H-1 10,678' 10,696' 10,523' 10,536' 6 18' 60 1-11/16" Owen HC Proposed H-1 10,701' 10,722' 10,540' 10,556' 6 21' 60 1-11/16" Owen HC Proposed H-1 10,725' 10,735' 10,558' 10,566' 6 10' 60 1-11/16" Owen HC Proposed H-2 10,747' 10,772' 10,575' 10,594' 6 25' 60 1-11/16" Owen HC Proposed H-3 10,786' 10,816' 10,605' 10,628' 6 30' 60 1-11/16" Owen HC 6/06/14 H-11 11,020' 11,048' 10,784' 10,806' 6 28 60 2-7/8" Connex 6/06/14 H-12 11,072' 1 11,087' 10,824' 10,836' 6 1 15 60 2-7/8" Connex H-1 1 H-2 H3 H-11 goJML 14 Bands H-12 W E n5 11,109' SLM 16 6/10/14 4-1/2" 11,200' TD =11,200' PBTD =11,100' MAX HOLE ANGLE = 41° @ 10,667' WELL DATA PTD: 214-038 API: 50-133-20276-01 Lease: FEDA-028996 Spud Date: 4/12/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD SCU 44-05 Proposed Schematic 06-16-14 Updated by STP 6/16/14 THE STATE of 7�`� TT,. GOVERNOR SEAN PARNELL Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 333 West Sevenih Avenue Anchorage, Alaska 99501-3572 Dain: 907.279.1433 Fcx:907.276.7542 Re: Swanson River Field, Hemlock Oil Pool, SCU 44-05 Hilcorp Alaska, LLC Permit No: 214-038 Surface Location: 3323' FNL, 571' FEL, SEC. 5, T7N, R9W, SM, AK Bottomhole Location: 1230' FSL, 685' FEL, SEC. 5, T7N, R9W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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, 4t'� Cathy P oerster Chair DATED this Zday of March, 2014. STATE OF ALASKA AL .<A OIL AND GAS CONSERVATION COMM. SON PERMIT TO DRILL 20 AAC 25.005 MAR 11 2014 1 a. Type of Work: 1b. Proposed Well Class: Development -Oil ❑� - Service - Winj ❑ Single Zone ❑✓ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill Q ' Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244. Soldotna Creek Unit (SCU) 44-05 (SCU 33-5 ST) 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Anchorage AK 99503 MD: 11500 TVD: 11152 Hemlock 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 3323' FNL, 571' FEL, Sec 5, T7N, R9W, SM, AK A028996 • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1492' FSL, 680' FEL, Sec 5, T7N, R9W, SM, AK NA SRF Soldotna Creek Unit 4/1/2014 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1230' FSL, 685' FEL, Sec 5, T7N, R9W, SM, AK A028996 - 1,000 Unit Acres 4,601' FWL (Unit Boundary) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 188.6 feet 15. Distance to Nearest Well Open Surface: x-341744.448 • y- 2457909.946 Zone -4 GL Elevation above MSL: 170 feet to Same Pool: 1 ,860ft 16. Deviated wells: Kickoff depth: 9,400' • feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 40 degrees Downhole: 3226 • Surface: 2111 - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 6-1/8" 4-1/2" 12.6 L-80 DWC/C 2300 9200 9189 11500 11152 279 sxs 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): 10,870 10,760 NA 10,827 10,723 NA Casing Length Size Cement Volume MD TVD Conductor/Structural 44' 20" none 44' 44' Surface 3372' 10-3/4" 1035 sks G cmt 3,327' 3,327' Intermediate Production 10585' 7-5/8" 645 sks G cmt 10,585' 10,510' Liner 486' 5-1/2" 100 sks 10,870' 10,760' Perforation Depth MD (ft): See attached schematic Perforation Depth TVD (ft): See attached schematic 20. Attachments: Property Plat ❑✓ BOP Sketch 0 Drilling Program Q✓ Time v. Depth Plot Q Shallow Hazard Analysis Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program ❑� 20 AAC 25.050 requirements 21 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Janise Barrett Contact Email jbarrett,�hilcorp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature - Phone 907-777-8431 Date 3/11/2014 Commission Use Only Permit to Drill Number. �_ �_� ?�C , API Number: f /_ 50- —/33 — ��Z_ 74–�/-��` Permit Approval Bate: �� See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 35�i SL `�d rJ l �.S 7 — Samples req'd: Yes ❑ No© Mud log req'd: Yes ❑ No ❑� ./ HZS measures: Yes ❑ No � Directional svy req'd: Yes d No ❑ f� Ser'V'- /1 Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No C_ 0 !� Approved by APPROVED BY COMMISSIONER THE COMMISSION Date: 3-417—& Form 10-401 ( vised 10/2012) This e i d fo o s rom the date of approval (20 AAC 25.005(g)) Attachments in Dup cater Hilcorp Ener® Company 3/11/14 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: SCU 33-5 ST (SCU 44-5) Dear Commissioner, Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Please find enclosed the 10-401 Application for Permit to Drill for the SCU 44-05. MAR 11 2014 A'10GCC FSA 5w"c`i 6"- 33_5 . 3/y-ul SCU 44-05 is a development oil well planned to be re -drilled in a Southerly direction from SCU 33-5 utilizing the existing casing program down to 9400' MD / 9389' TVD. At 9400' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 2100' x 6-1/8" open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated (TCP) based on LWD data obtained while drilling the interval. The well will be completed with a gas lift assembly on 2-7/8" production tubing. Drilling operations are expected to commence approximately April 1st, 2014. 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 wellbore preparation for the sidetrack. General sequence of operations pertaining to this approved drilling procedure: • MOB Saxon Rig #169 to SCU 44-05, NU and test BOPE (5 days) • Perform clean out run to plug (9400') and test casing. Displace to mud. (1 day) • Set Whipstock, mill 6.625" window at 9400'. Perform FIT to 11 ppg (2 Days) • Drill 6-1/8" production hole from 9400' to 11500' MD. (4 Days) • Perform short trip and condition mud. POOH (1 day) • LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. (1 Days) • POOH, laying down DP and liner running tools, ND BOPE (1 day) • RDMO (1 Day) 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 1 of i Hilcorp Alaska, LLC SCU 44-05 (SCU 33-05 ST) Drilling Program Soldotna Creek Reviewed by: 3 • if. l y � 03� Approved B <' 12-0y': Revision 0 March 11, 2014 SCU 44-05 Drilling Procedure Rev 0 Ifile-p Alaska, LIX 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 Summary...................................................................................................................... 7 8.0 Mandatory Regulatory Compliance / Notifications..................................................................8 9.0 R/U and Preparatory Work.....................................................................................................11 10.0 BOP N/U and Test....................................................................................................................12 11.0 Mud Program and Density Selection Criteria........................................................................13 12.0 Whipstock Running Procedure...............................................................................................14 13.0 Whipstock Setting Procedure: ................................................................................................. 17 14.0 Drill 6-1/8" Hole Section..........................................................................................................19 15.0 Run 4.5" Production Casing.................................................................................................... 22 16.0 Cement 4.5" Production Casing.............................................................................................. 25 17.0 RDMO...................................................................................................................................... 28 18.0 BOP Schematic........................................................................................................................ 29 19.0 Wellhead Schematic.................................................................................................................30 21.0 Geo-Prog.................................................................................................................................. 32 22.0 Anticipated Drilling Hazards.................................................................................................. 33 23.0 Rig Layout................................................................................................................................34 24.0 FIT Procedure.......................................................................................................................... 35 25.0 Choke Manifold Schematic...................................................................................................... 36 26.0 Casing Design Information......................................................................................................37 27.0 6-1/8" Hole Section MASP....................................................................................................... 38 28.0 Plot (NAD 27) (Governmental Sections)................................................................................. 39 29.0 Surface Plat (As Built) (NAD 27)............................................................................................. 40 30.0 Surface Plat (As Built) (NAD 83)............................................................................................. 41 31.0 Directional Program (Pl)........................................................................................................ 42 SCU 44-05 Drilling Procedure Rev 0 Ililcorp Alaxka, LIA; 1.0 Well Summary Well SCU 44-05 Pad & Old Well Designation Sidetrack of existing well SCU 33-5 (PTD#175-039) Planned Completion Type 4-1/2" 12.6# L-80 Liner Target Reservoir(s) Hemlock Planned Well TD, MD / TVD 11500' MD / 11152' TVD PBTD, MD / TVD 11420' MD / 10924' TVD Surface Location (Governmental) 3323' FNL, 571' FEL, Sec 5, T7N, R9W, SM, AK Surface Location (NAD 27) X=341744.448, Y=2457909.946 Surface Location (NAD 83) X=1481767.093, Y=2457671.200 Top of Productive Horizon (Governmental) 1492' FSL, 680' FEL, Sec 5, T7N, R9W, SM, AK TPH Location NAD 27 X=341625.87, Y=2457453.75 TPH Location (NAD 83) X=1481648.5, Y=2457214.995 BHL (Governmental) 1230' FSL, 685' FEL, Sec 5, T7N, R9W, SM, AK BHL (NAD 27) X=341618.06, Y=2457192.3 BHL (NAD 83) X=1481640.684, Y=2456953.542 AFE Number 1410656D AFE Drilling Das 16 AFE Drilling Amount $3.14 MM Work String 4-1/2" 16.6# S-135 CDS-40 RKB — GL 18.6' Ground Elevation 170' AMSL BOP Equipment 11" 5M T3 -Ener (Model 7082) Annular BOP 11" 5M T3 -Ener Model 6011i) Double Ram 11" 5M T3 -Energy (Model 6011i) Single Ram Page 2 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 llilcorp Alu4 a. LLC 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp P.�compmY Changes to Approved Permit to Drill Date: March 03, 2014 Subject: Changes to Approved Permit to Drill for SCU 44-05 (SCU 33-05 ST) File #: SCU 44-05 (SCU 33-05 ST) Drilling Program Any modifications to SCU 44-05 Drilling Program will be documented and approved below. Changes to an approved APD will be communicated to the BLM and AOGCC. Change Approval Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Ililcwrp UtAa. LId: 3.0 Tubular Program: Hole Section QD ",.,.: Wt(#/ft) Cots 1410 ID in Daft i#. Grate Conn Top Bottom Conductor 20 16.6 S-135 CDS-40 17693 16769 595k 0 44 Surface 10-3/4" 40.5 0 3372 Production 7-5/8" 26.4 6.969 6.844 N-80 BTC 0 3798 Production 7-5/8" 29.7 6.875 6.750 N-80 BTC 3798 5733 Production 7-5/8" 33.7 6.765 6.640 S -95/P-110 BTC 5733 10585 Liner 5-1/2" 20 4.778 4.653 N-80 BTC 1 10384 10870 6-1/8" 4-1/2" 12.6 5.0" 3.918 3.833 L-80 i DWC/C 1 9200 11500 4.0 Drill Pipe Information: Hole OD (in) Section ID (in) TJ ID in(in) TJ OD Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k -lbs) 6-1/8" 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 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 niieurp Alaska, IA,(: 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, Ikeller e,hilcorp.com, mm ers 2hilcorp com and ibarrettghilcorp.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 pmazzoliniga hilcorp.com, lkeller(2hilcorp.com and mmyers(2hilcorp.com 5.4 EHS Incident Reporting L 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: O: (907) 777-6726 C: (907) 227-3189 b. Mark Tornai: O: (907) 283-1372 C: (907) 748-3299 c. Thad Eby: O: (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: O: 907-777-8369 C: 907-317-1275 iii. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally L Send final "As -Run" Casing tally to mmyers@hilcorp.com and jbarrett(2hilcorp.com 5.6 Casing and Cmt report i. Send casing and cement report for each string of casing to mmyers&hilcorp.com and jbarrett(ahilcorp.com Page 5 Revision 0 March, 2014 U thleorp AN.Aa, LIA: 6.0 Planned Wellbore Schematic 20" V) RKB to TBG Hanger = 18.6' SCU 44-05 Drilling Procedure Rev 0 EXISTING CASING DETAIL Type Size 'N7 Grade Conn ID Top MM. Conductor 20" 41 1 " On,/L�ff toc! 4.3" I surf 44! Surface I0-3/4- 4D5 K-55 Surf 3,372' Production 7-5/8" 26.4 N-90 6.9691, Surf 3,792' 29.7 N-80 6.87/5- 3,799' 5,733' 33.7 5 95 6.765- 1 5,733' 1 6,906' 33-7 P-110 6.765- 1 6,906' 1 1;,'585, Liner 5-1/2, 20 N-81) 4.779" 1 10 384! 1 10,87(' ) JEWELRY DETAIL OD Item KOP: 7-5/8" X 4-1/2" ZXP liner hanger Build: 4-1/2- 12.6# L -ED IYNCIC Hold: 232 from 9604'-10125' MD G EQUVAEN7 41 1 " On,/L�ff toc! 4.3" I A.' -I -X Retr'evab-le Packer 3.5" ELIE 'X' Landing Nipple 33" EUE %LEG Window at -9,4007, DriU 6-1.8" hole to 11,500' , Run 4-1.1- 12.64, L-90 Liner, Cement w.'67 I to above liner top. t. !" " ®N JR Page 6 Revision 0 March, 2014 INCLINATION DETAIL KOP: 9400' MD/9389TVD Build: 8.0?/100' Hold: 232 from 9604'-10125' MD Build: 4.02/100' to 402 from 10125'-10591' IVID t at TD: 40-0 limuth: 1958 at 1012-5' MID & 1802 to TD Window at -9,4007, DriU 6-1.8" hole to 11,500' , Run 4-1.1- 12.64, L-90 Liner, Cement w.'67 I to above liner top. t. !" " ®N JR Page 6 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Ih1corr AlaA,, LLC 7.0 Drilling Summary SCU 44-05 is a development oil well planned to be re -drilled in a Southerly direction from SCU 33-5 utilizing the existing casing program down to 9400' MD / 9389' TVD. At 9400' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 2100' x 6-1/8" open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated (TCP) based on I" data obtained while drilling the interval. The well will be completed with a gas lift assembly on 2-7/8" production tubing. Drilling operations are expected to commence approximately April 1 st, 2014. ✓' 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 coveP&A end wellbore preparation for the sidetrack. llv�S�Ln 31Z! -sl/ %SS" -f General sequence of operations pertaining to this approved drilling procedure: 1. MOB Saxon Rig #169 to SCU 44-05, NU and test BOPE (5 days) 2. Perform clean out run to plug (9400') and test casing. Displace to mud. (1 day) 3. Set Whipstock, mill 6.625" window at 9400'. Perform FIT to 11 ppg (2 Days) ' 4. Drill 6-1/8" production hole from 9400' to 11500' MD. (4 Days) 5. Perform short trip and condition mud. POOH (1 day) 6. LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. (1 Days) 7. POOH, laying down DP and liner running tools, ND BOPE (1 day) 8. RDMO (1 Day) Page 7 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 11ilmrp Ala. ku, 111.4; 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 SCU 44-05. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 10/10 min (annular to 50% rated AT, 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 and BLM 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 Hilcorp requests approval to install a 3-1/8" 5M HCR valve on kill line in lieu of a check valve. Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. c Page 8 Revision 0 March, 2014 llilcvrp Alaska, 1.1.1: Summary of BOP Equipment and Test Requirements SCU 44-05 Drilling Procedure Rev 0 Hole Section Equipment Test Pressure(psi) • 11" x 5M T3 -Energy (Model 7082) Annular BOP • 11" x 5M T3 -Energy Double Ram o Blind ram in him cavity Initial Test: 250/3500 (Annular 2500 psi) • Mud cross 6-1/8" • 11" x 5M T-3 Energy Single Ram • 3-1/8" 5M Choke Line Subsequent Tests: • 2-1/16" x 5M Kill line 250/3500 • 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. Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, & testing • Any other notifications required in APD. Additional requirements may be stipulated on APD. Page 9 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 nae,Tp Almku, LLC Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regg_galaska.gou Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 % Email: ge.schwartzng,alaska.gov Victoria Ferguson / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.p-ov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) BLM Justin Miller / BLM Petroleum Engineer / (0): 907-271-3406 (C): 907-717-4039 Use the below email address for BOP notifications to the BLM: BLM AK AKSO EnergySection Notifications@blm.gov I/ Page 10 Revision 0 March, 2014 llilcv rp Alaska, LLC ME .1 9.2 SCU 44-05 Drilling Procedure Rev 0 R/U and Preparatory Work 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 9400' MD. • RDMO workover rig. 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 6-1/8" 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" liners installed in mud pumps. • HHF-1000 Pumps are rated at 3457 psi (80%) with 5" liners and can deliver 306 gpm at 120 spm. This will allow us to drill the 6-1/8" hole section with (1) mud pump. Page 11 Revision 0 March, 2014 10.0 BOP N/U and Test SCU 44-05 Drilling Procedure Rev 0 10.1 N!U 11" x 5M BOP as follows: • BOP configuration from Top down: l l" x 5M annular BOP/1 I" 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" VBR in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5" VBR. • N/U bell nipple, install flowline. 10.2 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 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" test joint. • Ensure gas monitors are calibrated and tested in conjunction w/ BOPE. 10.3 R/D BOP test assy. 10.4 Continue mixing mud for 6-1/8" hole section. 10.5 Set wearbushing in wellhead. Ensure ID of wearbushing > 7". Page 12 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 tlileorp Ala kn, LL(: 11.0 Mud Program and Density Selection Criteria 11.1 6-1/8" Production hole mud program summary: Primary weighting material to be used for the hole section will be Calcium Carbonate to minimize solids. We will have barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. 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: 9.5 ppg 6% KCl/PHPA fresh water based drilling fluid. Properties: MD Dens' Viscosity Plastic Viscosity Yield Point PH API Fluid 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ Loss 9400' - 1500' 9.5-10.5 - 40-53 15-25 1 15-25 8.5-9.5 <_6.0 System Formulation: 6% KCI / EZ Mud DP Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb (initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC -L 1 ppb BARACARB 5/25/50 10-20 ppb BAROTROL PLUS 2 ppb SOLTEX 2 ppb (if needed) BAROID 41 as required for a 9.5 —10.5 ppg ALDACIDE G 0.1 ppb BARACOR 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 13 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 tlilmrp AlaAu. LIA: 12.0 Whipstock Running Procedure 12.1 M/U window milling assembly and TIH w/ 4-1/2" DP off of pipe rack. • Use a 6.625" taper mill and a 6.625" 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 (9400' 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. Pressure test casing to 2500 psi / 30 m' Chart record casing test & keep track of the amount of fluid pumped. Stage up to 2500 psi in 50 psi increments. 12.4 1 -vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.5 TOH. 12.6 Makeup mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Make up UBHO sub. 12.10 Orient UBHO to starter mill. 12.11 Leave assembly hanging in the elevators, and stand back on floor. 12.12 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.13 Pickup 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 14 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 llikmrp Alaska, IAX 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. 12.14 If needed, open BOP Blinds. 12.15 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.16 Release pick up system at this point, Make up mills. 12.17 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. 12.18 The assembly can now be picked up to ensure that the shear bolt is tight. 12.19 Remove the handling system. 12.20 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing. 12.21 Run in hole at 1 Y2 to 2 minutes per stand. 12.22 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.23 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.24 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 15 Revision 0 March, 2014 11ife—p Alnaka. 1.1.(: SCU 44-05 Drilling Procedure Rev 0 WindowMaster G2 System on TorqueMaster BTA 7-5/8" 33.7# Csg — WindowMaster G2 On BTA BHA #1 Connection Length O_D. BOTTOM TRIP ANCHOR 3 Y2 IF -Box X Bottom Guide 3.21' 6.18" WINDOW MASTER WHIPSTOCK Shear Bolt X 3 Y. IF -Pin 14.6' 6.00" WINDOW MILL -1/2 Reg -Pin X Mill 1.5' 6.63" LOWER WATER MELON MILL -1/2 IF -Box X 3-1/2 Reg -Box 5.5' 6.50" FLEX JOINT -1/2 IF- Box X 3-1/2 IF -Pin 6.6' 4.75" UPPER WATER MELON MILL -1/2 IF- Box X 3-1/2 IF -Pin 5.8' 6.63" 1 JT HWDP -1/2 IF -Box X 3-1/2 IF -Pin 30' 5.25" MWD Survey Tool -1/2 IF-BoxX 3-1/2 IF -Pin 3' 4.75" UBHO -1/2 IF -Box X 3-1/2 IF -Pin 3' 4.75" Bowen Lubricated Bumper Jar -1/2 IF -Box X 3-1/2 IF -Pin 15' 4.75" 6 DRILL COLLARS -1/2 IF -Box X 3-1/2 IF -Pin 180 4.75" 30 JTS — HWDP -1/2 CDS40 Box X 4-1/2 CDS40-Pin 900' 4.75" CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 16 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Hilemrp Alaska, LIA; 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. We will orient Whipstock face using MWD and will have Gyrodata as backup. Ensure that UBHO and gyro tool mate up properly before making up UBHO sub. 13.2 Orient Whipstock to desired direction by turning DP in '/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 220 AZT 140 AZ Desired orientation of the Whipstock face is in 140 to 220 degrees azimuth. Hole Angle at window interval (9400' MD) is < 12 deg. The wellbore trajectory is also planned to 180 degrees azimuth. Highside of the casing at 9400' is at 240 degrees azimuth. 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 9.5 ppg 6% KCl/PHPA drilling fluid. 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 17 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 thleorpAlx-ku. LLC 13.10 Estimated metal cuttings volume from cutting window: 7-5/8" 3'/ REG -P X MILL 33.7# N-80 Cuttings Weight Window 3'/ IF -13 X 3'/ REG -13 5.5 6.5 FLEX JOINT Length Casing Weight Min (lbs) Avg (lbs) Max (lbs) 13 33.7# 80 110 140 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 11.5 ppg EMW. f j • (11.5 — 9.5) * 0.052 * 9389' tvd = 976 psi Note: Offset.field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 11 ppg FIT results in a 2 ppg kick margin while drilling the interval with a 9.5 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 Un Mills CnnnPctinn I Pnnfh n n WINDOW MILL 3'/ REG -P X MILL 0.98 6.63 NEW LOWER WATERMELON MILL 3'/ IF -13 X 3'/ REG -13 5.5 6.5 FLEX JOINT 3'/ IF -13 X 3'/ IF -P 6.5 4.75 UPPER WATERMELON MILL 3'/z" IF -13 X 3'h" IF -P 5.83 6.63 FLOAT SUB 3'h" IF -B X 3'h" IF -P 3.00 4.75 XO sub and 30 'ts-HWDP 4'/2" CDS40-B X 3'/2" IF -P 900' 5.25 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 18 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 flilcorp Alavka, LLC 14.0 Drill 6-1/8" Hole Section 14.1 P/U 6-1/8" 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 0.46 — 0.56 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 200 - 300 gpm. 14.6 Motor AKO should be set at 1.5 deg. Must keep up with 8 deg/100 DLS in the build section of the wellbore. 14.7 Primary bit will be the HDBS 6-1/8" MM64D PDC bit. Ensure to have a back up bit available on location. Page 19 Revision 0 March, 2014 thle.orp Almska, LU: PRODUCT SPECIFICATIONS Cutter Type SelectCutter IADC Code M434 Body Type MATRIX Total Cutter Count 61 Cutter Distribution Iomm 13mm Face 12 25 Gauge 0 I8 Up Drill 0 6 Number of Large Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 0 Number of Micro Nozzles 6 Number of Ports (Size) 0 Number of Replaceable Ports (Size) 0 Junk Slot Area (sq in) 5.51 Normalized Face Volume 26.73% API Connection 3-Il2 REG, PIN Recommended Make -Up Torque' 5,173 — 7,665 Ft'lbs. Nominal Dimensions" Make -Up Face to Nose 9.31 in - 236 mm Gauge Length 2 in - 51 mm Sleeve Length 0 in - 0 mm Shank Diameter 4.5 in -114 mm Break Out Plate (Mat.#/Legacyfl) 181953+44030 Approximate Shipping Weight 85Lbs. - 39Kg. SPECIAL FEATURES Up -Drill Cutters on Gage Pads, 1132" Relieved Gaffe, Optimized Dual Row - "D" Feature SCU 44-05 Drilling Procedure Rev 0 Material #778247 'Bit specific rcrnnunended make-up torque is a function of the bit I.D_ and actual bit sub O.D. utilized as specified in API RP7G Section A_8 "Design dimensions arc nominal and nmy vary slightly on manufactured Product. lialliburton Drill Bits and Servim models are continuously reviewed and refined. Product specifications may change without notice. 2013 Halliburton. All rights reserved. Sales of Halliburton products and services will be in accord solely'kvith the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 20 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Irileorp Almka, LLC 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill 6-1/8" hole to 11500' MD using 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 API fluid loss < 6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.11 Hilcorp Geologists will follow mud 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 assembly, handle BHA as appropriate. V Page 21 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Hilcarp AlaAa, LIA: 15.0 Run 4.5" Production Casing 15.1 R/U Weatherford 4.5" casing running equipment. • Ensure 4.5" DWC/C 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 and tally verified 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 4.5" 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. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 4.5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5800 ft -lbs 6500 ft -lbs 7200 ft -lbs Page 22 Revision 0 March, 2014 11ilcorp Alaska, LLA; Technical Specifications Connection Type: Size(O.D.): Weight (Wail): DWC/C Tubing 4-1/2 in 12.60 Iblft (0.271 in) standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) 95,000 Minimum Ultimate Strength (psi) SCU 44-05 Drilling Procedure Rev 0 Grade: L-80 AAM USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713-4793200 Fax: 713479-3234 E-mail: VAMUSAsalesgrram-a.com Page 23 Revision 0 March, 2014 Pipe Dimensions 4.500 Nominal Pipe Body O.D. (in) 3.958 Nominal Pipe Body I.D.(in) 0.271 Nominal Wall Thickness (in) 12.60 Nominal Weight (Ibslft) 12.25 Plain End Weight (lbs/ft) 3.600 Nominal Pipe Body Area (sq in) SCU 44-05 Drilling Procedure Rev 0 Grade: L-80 AAM USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713-4793200 Fax: 713479-3234 E-mail: VAMUSAsalesgrram-a.com Page 23 Revision 0 March, 2014 Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (lbs) 7,500 Minimum Collapse Pressure (psi) 8,430 Minimum Internal Yield Pressure (psi) 7,700 Hydrostatic Test Pressure (psi) SCU 44-05 Drilling Procedure Rev 0 Grade: L-80 AAM USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713-4793200 Fax: 713479-3234 E-mail: VAMUSAsalesgrram-a.com Page 23 Revision 0 March, 2014 Connection Dimensions 5.000 Connection O.D. (in) 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter (in) 3.94 Make-up Loss (in) 3.600 Critical Area (sq in) 100.0 Joint Efficiency (%) SCU 44-05 Drilling Procedure Rev 0 Grade: L-80 AAM USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713-4793200 Fax: 713479-3234 E-mail: VAMUSAsalesgrram-a.com Page 23 Revision 0 March, 2014 Connection Performance Properties 288,000 Joint Strength (lbs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (lbs) 288,000 Compression Rating (lbs) 7,500 API Collapse Pressure Rating (psi) 8,430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft -lbs) 6,500 Maximum Final Torque (ft -lbs) 7,200 Connection Yield Torque (ft -lbs) SCU 44-05 Drilling Procedure Rev 0 Grade: L-80 AAM USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713-4793200 Fax: 713479-3234 E-mail: VAMUSAsalesgrram-a.com Page 23 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Hik»rp Alaska, LIA: 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 7-5/8" casing. Ensure hanger/pkr will not be set in a 7-5/8" connection. 15.8 Before picking up Baker ZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/ liner on DP no faster than 1 min / stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 7" window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack -off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.19 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Ililcorp Alaska, LLG 16.0 Cement 4.5" Production Casing • Cement will be mixed using batch mixer to ensure consistent density 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 5 bbls 12.5 ppg MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 10 bbls 12.5 ppg MUDPUSH Il spacer. 16.6 Mix and pump 67 bbls of 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 50% 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 7-5/8" casing and 4-1/2" casing. Est TOC 8900' TMD. 16.7 Displacement fluid will be produced water. —122 bbls of -8.6 ppg produced water Cement Calculations 7-5/8" x 4-1/2 DP" Overlap: (9200' — 8900') x 0.026 = 7.8 bbls 7-5/8" x 4-1/2" Liner Overlap: (9400'— 9200') x 0.026 = 5.2 bbls 6-1/8" OH x 4-1/2" Liner: (11500' — 9400') x 0.01677 x 1.5 = 52.8 bbls Shoe Track: 80' x 0.01522 = 1.2 bbls Total Volume (bbls): 7.8 + 5.2 + 52.8 + 1.2 = 67 bbls Total Volume (ft3): 67 bbls x 5.615 ft3/bbl = 376 0 Total Volume (sx): 376 ft3 / 1.35 ft3/sk = 279 sx Page 25 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 9ilcorp Alwku, LLC. Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk `/ Mixed Water 5.879 gaUsk Mixed Fluid 5.879 gaUsk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF / 1000 psi Additives Code Description Concentration G D046 D202 D400 D154 Cement Anti Foam Dispersant Gas Control Agent Extender 94 lb/sk 0.2% BWOC 1.5% BWOC 0.8% BWOC 8.0% BWOC 16.8 Drop DP dart and displace with 8.6 ppg produced water. 16.9 Pump cement at max rate of 4 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re -zeroed at this point 16.10 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.11 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.12 Slack off total liner weight plus 30k to confirm hanger is set. 16.13 Do not overdisplace by more than % shoe track (-1 bbls). Shoe track volume is 1.8 bbls. 16.14 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 rlileurp Alaeka. LLC 16.15 Bleed pressure to zero to check float equipment. 16.16 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.17 Rotate slowly and slack off 50k downhole to set ZXPN. 16.18 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack -off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 16.19 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.20 Pick up to the high -rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re -tag the liner top, and circulate the well clean. 16.21 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.22 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.23 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.24 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 16.25 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set -down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 March, 2014 flikeurp Alaska, LLC SCU 44-05 Drilling Procedure Rev 0 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 & cmt report + "As -Run" liner tally to mmyers(q-)hilcorp.com Pre -&S T,—S t' G ws i � J�, 3 6M f" 17.0 RDMO _ G 8 �--. 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. S c 5 Page 28 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 FTilmrp Alavku. LLC 18.0 BOP Schematic Page 29 Revision 0 March, 2014 �l Hilcorp Alaska, IdA; 19.0 Wellhead Schematic Swanson River SCU 44-05 10%X 75/8X27/8 BHTA, Bowen, 3 1/8 SM FE X 3" Bowen top Valve, swab, WKM-M, 3 1/8 SM FE, HWO, DO trim Valve, Wing, WKM-M, 2 1/16 5M FE, HWO, DD trim Valve, master, WKM-M, 3 1/8 5M FE, HWO, DO trim Valve, master, WKM-M, 3 1/8 SM FE, HWO, DO trim Tbg head, Seaboard, S-8, 11 5M X 7 1/16" 5M, w/ 2- 2 1/16 5M SSO, BG bottom prep, bored out for 7 5/8 casing Casing head, CIW-WF, 115M X 10 Y SOW bottom, w/ 2- 2" LPO SCU 44-05 Drilling Procedure Rev 0 Tubing hanger, Seaboard SC -E- CL, 7 X 3 % EUE 8rd Lift and susp, 3" Type H BPV profile, 3/8 control line prep, dovetail body seals 411 1 3 Adapter, Seaboard SM-E-CLN 7 1/16 5M stdd X 3 1/8 5M stdd top, w/ Y2 npt control line exit Valve, WKM-M, 2 1/16 5M FE, HWO, AA Page 30 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 1lilcorp AlitAn, LLC 20.0 Days vs Depth 0 sse j :ese ELS sTs r Days Vs Depth SCL 44-05 1 SCU 33- 5 ST) 0 2 4 6 s 10 12 14 16 is Days Page 31 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 t ilcorp Alaska, LLC 21.0 Geo-Prog �I1:ie7��:7sulULy50 Fr @ the Hemlock level ' �.. Triple Combo LWD on Production hole section ✓' Ilk COMPLETION TYPE [Gas liftcompletion or Rod Pump ANTICIPATED RATES 2000 bpd gross fluid EQUIPMENTARTIFICIAL LIFT •D TUBING SIZE 2 7/8" or 3.5" 1. The Tyonek Hi Pressure water sand will be above the KOP! Y 2. We anticipate crossing the C faultwith a throw of -250 feet. Page 32 Revision 0 March, 2014 GEOLOGICAL-. ► /� r X YPad Swanson River r�is':A'•!341749.4 Alaska . • • • a KB • • • - 170 18' KB (Saxon 169) 'INAD27 152' ..•-• • • M11500.00' 11077.003 TVD Drill a sidetrack out ofthe SCU 33-05 well to test the Hemlock H1-3 zones in fault block D •. than cut the C fault to test the 1-19-13 sands in fault block C. Geo Surrimaryl Based on subsurface evaluation and reservoir modeling results ANTICIPATED•- -A•N TOPS & GEOHAZARDS EXPECTED TOP Formation FORMATION FLUID MD TVD Est Pressure X _Y +/- HP—H20 Behind Pipe 8,960 8,955 341829.09 2458004.57 KOP 9,400 9,389 341669.7 2457807.3 SR_G2ST Tyonek Oil OIIANet 10,567 10,438 1200-2500# �' 341629.8 2457534.1 25 SR_H1ST Hemlock Oil Oil 10,681 10,520 1000-1400# 341626.2 2457454.0 25 SR_H3ST Hemlock Oil Oil 10,794 10,597 1000-1400# 341623.8 2457371.0 25 SR—FC 10,827 10,619 341623.1 2457347.3 40 SR_H9ST Hemlock Oil Oil 10,854 10,638 1200-1800# 341622.5 2457327.1 25 SR_H10ST Hemlock Oil Oil 10,899 10,668 1200-1800# 341621.6 2457294.3 25 SR_H11ST Hemlock Oil Oil 10,967 10,714 1200-1800# 341620.1 2457244.9 25 SR_H12ST Hemlock Oil Oil 11,044 10,767 2200-3200# 341618.5 2457188.3. 25 SR_H13ST Hemlock Oil Oil 11,112 10,813 _ 2200-3200# i 341617.0 2457138.7 25 rr ObjectivePrimary .... • •. �I1:ie7��:7sulULy50 Fr @ the Hemlock level ' �.. Triple Combo LWD on Production hole section ✓' Ilk COMPLETION TYPE [Gas liftcompletion or Rod Pump ANTICIPATED RATES 2000 bpd gross fluid EQUIPMENTARTIFICIAL LIFT •D TUBING SIZE 2 7/8" or 3.5" 1. The Tyonek Hi Pressure water sand will be above the KOP! Y 2. We anticipate crossing the C faultwith a throw of -250 feet. Page 32 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Hileorp Alaeka, LLC 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. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 33 Revision 0 March, 2014 23.0 Rig Layout SCU 44-05 Drilling Procedure Rev 0 Page 34 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 tlikmrp Alaska, LLC 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 35 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Ililcorp AlaAa, LII: 25.0 Choke Manifold Schematic H:- �: 7. NYd'JE MM R GA94'ES Page 36 Revision 0 March, 2014 11deorp AhAn. LIT SCU 44-05 Drilling Procedure Rev 0 26.0 Casing Design Information Calculation & Casing Design Factors Hole Size Hole Size 6-1/8" Hole Size Swanson River Unit DATE: 2/21/2014 WELL: SCU 44-05 (SCU 33-5 ST) FIELD: Soldotna Creek Unit DESIGN BY:Monty M Myers Design Criteria: Mud Density: Mud Density: 9.5 ppg Mud Density: Drilling Mode MASP: 3226 psi (See attached MASP determination & calculation) Production Mode MASP: 2111 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 Page 37 Revision 0 March, 2014 Cas ng Section Calculation/Specification 1 2 3 4 Casin OD 4-1/2" To MD 9,200 T0�(Tv __ _._......_....._..__ _ _ ._._. mmBottom 9,189 �P - _ MD) 11,500 Bottom TVD 11,152 .._..Length _ _.2,300 Weight 12.6 Grade L-80 Connection 'Bou DWC/C Weight w/o anc Factor lbs 28,980 _ Tension at Top of Section (Ibs� _....._................_.................._..............._......_._.._._.._. 28,980 ...... _...... ....._.......;_............. ..... ...... _Min stren th Tension 1000 lbs 288 _.... .... _................... Worst Case Safety Factor Tension mm 9.94 Collapse Pressure at bottom (Psi) _....... ....._........................._.._.._.._........_......_...........................................-......_..:.........._......_.._......_..._.._........_ 4,528 Colla,ise Resistance w/o tension Psi 7,500 �T . Worst Case Safety Factor Collapse) 1.66 MASP psi) _.._......_....._._..._.._.._._.._.._._....._.........._..... ......._......._....._.......... _............. _.._.... 3,226 ......... _..... _..... _........_._.._ i ................ ................... _............ ;..... ....................... Minimum Yield si 8,430 ._ ....... _............ ; Worst case safety factor (Burst) 2.61 Page 37 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Iliicorp MnAa, LIA: 27.0 6-1/8" Hole Section MASP IN FX Maximum Anticipated Surface Pressure Calculation Hilcor� 6-1/8" Hole Section SCU 44-05 Kenai, Alaska MD TVD Planned Top: 0 0 Planned TD: 11500 11152 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad SR_G2ST 10,438 2500 OIL/WATER 4.6 0.240 SR_H1ST 10,520 1400 OIL 2.6 0.133 SR_H3ST 10,597 1400 OIL 2.5 0.132 FAULT 10,619 SR_H9ST 10,638 1800 OIL 3.3 0.169 S R_H 10ST 10,668 1800 OIL 3.2 0.169 SR_H11ST 10,714 1800 OIL 3.2 0.168 SR_H12ST 10,767 3200 OIL 5.7 0.297 SR_H13ST 10,813 3200 OIL 5.7 0.296 TD 11,077 3200 OIL 5.6 0.289 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date SCU 21-4 12 ppg 0 10,965 1961 SCU 44-33 11.3- 12.5 ppg 9,216 10,747 2013 SCU 41A-4 11.2 ppg 9,300 10,807 2013 Assumptions: 1. Maximum planned mud density for the 6-1/8" 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 9062' TVD =12.5 ppg EMW Fracture Pressure at 6" window considering a full column of gas from window to surface: 9389 (ft) x 0.65(psi/ft)= 6102 psi V/ 6102 (psi) - [0.1(psi/ft)*9389(ft)]= 5163 psi �µ s A*f-I�`'' MASP from pore pressure; entire wellbore evacuated to gas from TD / 11152 (ft) x 0.29(psi/ft)= 3226 psi / 3226(psi) - [0.1(psi/ft)*11152 (ft)]= 2111 psi V/ Summary: 1. MASP while drilling 6-1/8" production hole is governed by SIBHP minus entire wellbore evacuated to gas from TD. 2. MASP during production mode is governed by SI BHP minus entire wellbore evacuated to gas from TD. Page 38 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 11ilcorp Algt4a, LLC. 28.0 Plot (NAD 27) (Governmental Sections) 0 1,000 xow tI Soldotna Creek Unit Feet SCU 44-05 (Option A) Alaska State Plane Zane 4, hiAD27 INI—p ai«:.t.:.. I.u: Map Date: 2'2712014 Page 39 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 I ilcorp Alaska, LL(: 29.0 Surface Plat (As wilt) (NAD 27) T8N SECTION 1 INE (.%407 70 SCALFI �.M - r"m' a;Xi Iia "A'""'" " FROfflC140 +4Une t � -Arm - SECTION. 05 T07N R09W SEWARD MERIDIAN. ALASKA BMEET 1 SECTION COR ICOMMUTEDI N:. 2461225AW E 3423-53. 112 I SCU 33-05 I ASBUILT SURFACE LOCATION 3VT FNL (UTS) NAD 27 ASP ZONE 4 N:2457909.946 w E:341744.448 LAT: 60`43'29.227"N Z LON: 150*5V02.139"W I 0 571' FEL U 3323'FNL IUJI ELEV: 163,335' NAVDU I �9CB CZa (h ai F6L. i �,B 3J.113�� yClliT[[Y 0 i SRF 42.05 PAD I NOTES 1. BASIS OF HORIZONTAL: NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP -2. THE ALASKA STATE PLANE COORDINATES NAD &3 ZONE 4 IN FEET ARE: N = 2458384 578 E a 1483669.444 ELEV. = 2t2.690 (NAVD88) 2. SECTION LINES SHOWN ARE COMPLETED FROM MONUMENT TIES ALONG THE NORTH TOWNSHIP LINE OF TOWNSHIP 7N RANGE 9W 3. DATUM TRANSFORMATI DNS {NAD83 ASPZ4 TO NAD27 ASPZ4) b!ITRE DONE USIA'; MrP',CON SOFTWARE VERSION 8.0.1. SCALE FEET OF��,j 10 #.iiWrA/Ft* 00 4 SEAN A. 'AWA 1Er I` A " Cvnwttinr Irr f FrfFeu mrw» ,a1�nr r.Bzw r c Buzau Baiauaca...ic aceas ttzrc 'K?1 2. FAz W.Ixxaxs t� B..�aM€�sMw�T,ec« Ililenrp Ahm1a. ar "'' ' HILLGCIRP ALASKA, LLC SWANSON RIVER FIELD WELL SCU 33-05 AS BUILT SURFACE LOCATION NAD 27 �.M - r"m' a;Xi Iia "A'""'" " FROfflC140 +4Une t � -Arm - SECTION. 05 T07N R09W SEWARD MERIDIAN. ALASKA BMEET 1 Page 40 Revision 0 March, 2014 SCU 44-05 Drilling Procedure Rev 0 Nilmrp Alaska, LIX 30.0 Surface Plat (As Built) (NAD 83) 78N SECTION LINE (NOT TO SCALE) 1_ BASIS OF HORIZONTAL: NA083 US FEET POSITION (EPOCH2010) SECTION COIF ICOIdPUTE01 N: 2!54986.906 AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP THE ti T<9�3Tv.8�Ei I SCU 33-05 -2. ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE S 9 ASBUILT SURFACE LOCATION 332x FNL (NTs1 NAD 83 ASP ZONE 4 N:2457671.2000 ELEV. = 212-696 4NAVD88) w E:1481767.093 0 tiSTAN A, Md.#M 1 LAT: 60'4327.196"N d LON:150'53'10.131"W I 571' FEL ALONG THE NORTH TOWNSHIP LINE OF TOWNSHIP 7N RANGE 9W U 3323' FNL �J5 I 'C: I w ELEV: 153.335 NAVD88 FEE7 � I Il�ecu>x..c� 8T ' FEL � f L � 0 SRF 42.05 PAD I I NOTES 1_ BASIS OF HORIZONTAL: NA083 US FEET POSITION (EPOCH2010) aaaaa�t AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP THE DF rI I �+ 4 +f•!k'4 I -2. ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE +' j y�v lrr N = 24`x83#14.578............'.* E a 1483659.444 i ELEV. = 212-696 4NAVD88) 0 tiSTAN A, Md.#M 1 /lll 2, SECTION LINES SHOWN ARE COMPUTED FROM MONLKAENT TIES SCALE '^ -r /+lt ALONG THE NORTH TOWNSHIP LINE OF TOWNSHIP 7N RANGE 9W Q Y" �J5 I 'C: FEE7 °£ mT HILLCORP ALASKA, LLC —A�- - s ansui[ing Int SWANSON RIVER FIELD Wmd2vaslt. WELL SCU 33-05 rW KM AS BUILT SURFACE LOCATION NAD 83 Faufe,Ha 1two 'rwrw6Fr•««a rprnaanin� rra:,+r x►r o(!< ho 11 -mum 11 raxm r�Tiaa r.n eacamrmmlrx ;2Ds-.: iv..rm>N SECTION. 0 T07N R09W OEST.�... v;rr� pec-�rorinu ,y� 1 111Irorp Atlu1*%a. LC.(: SEt"JARD MERIDIAN, ALASKA Page 41 Revision 0 March, 2014 Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit Soldotna CK Unit 33-05 SCU 44-05 Plan: SCU 44-05 WP3.0 Sperry Drilling Services Combo Report 10 March, 2014 Well Coordinates: 2,457,909.95 N, 341,744.45 E (60° 43'29.23" N, 150° 53' 02.14" W) Ground Level: 153.34 usft Local Coordinate Origin: Centered on Well Soldotna CK Unit 33-05 Viewing Datum: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) TVDs to System: N North Reference: True Unit System: Revised US -Survey Feet_nr Version: 5000.1 Build: 70 HALLIBUR'TON HALLISURTQN Sperry Drilling Proj Soldotna CK Unit Site: Soldotna CK Unit Well: Soldotna CK Unit 33-05 Wellbore: SCU 44-05 SCU 44-05 WP3.0 CASING DETAILS TVD MD Name Size 10453.77 10585.00 7 5/8" 7-5/8 11152.20 11499.99 4 1/2" 4-1/2 Hilcorp Energy Company Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Elliptical Conic Warning Method: Error Ratio 945 960 975 9900 c 10050 0 0 ch r 10200 m U j 10350 N F- 10500 10650 KOP Lgl Coords:2043 FSL 502 FEL Sec 5 T7N R9VV SM AK - KOP in 7-5/8" Csg;Start Dir 120/100': 9400' MD, 9389.18'TVD : -65° TF --------------- End Dir :9420'MD,9408.75'TVD Start Dir 81/100': 9440' MD, 9428.27'TVD -------------End Dir :9624.85'MD, 9604.26'TVD SURVEY PROGRAM SECTION DETAILS Date: 2014-03-10T00:00:00 Validated: Yes Version: Depth From Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFaceVSect 9400.00 Target 1 9400.00 11.36 240.35 9389.18 79.68 12.89 0.00 0.00 -80.57 2 9420.00 12.56 230.30 9408.75 77.32 9.50 12.00 -65.00 -77.88 3 9440.00 12.56 230.30 9428.27 74.54 6.16 0.00 0.00 -74.78 4 9624.85 23.42 195.81 9604.26 26.08 -19.46 8.00 -61.89 -24.02 5 10125.01 23.42 195.81 10063.21 -165.22 -73.61 0.00 0.00 171.71 6 10591.13 40.24 180.01 10458.46 -407.07 -99.09 4.00 -33.38 414.89 7 10676.13 40.24 180.01 10523.34 -461.98 -99.10 0.00 0.00 469.54 SCU 44-05 SR H1 ST Tgt1 revi 8 10974.83 40.24 180.01 10751.34 -654.95 -99.12 0.00 0.00 661.55 SCU 44-05 SR_H12ST Tgt2 rev1 9 11500.00 40.24 180.01 11152.21 -994.22 -99.16 0.00 0.00 999.16 90009150 WELL DETAILS: Soldotna CK Unit 33-05 Ground Level: 153.34 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 0.00 0.00 2457909.95 341744.45 60.7247852 -150.8839274 945 960 975 9900 c 10050 0 0 ch r 10200 m U j 10350 N F- 10500 10650 KOP Lgl Coords:2043 FSL 502 FEL Sec 5 T7N R9VV SM AK - KOP in 7-5/8" Csg;Start Dir 120/100': 9400' MD, 9389.18'TVD : -65° TF --------------- End Dir :9420'MD,9408.75'TVD Start Dir 81/100': 9440' MD, 9428.27'TVD -------------End Dir :9624.85'MD, 9604.26'TVD - - Start Dir 4°/100' : 10125.01' MD, 10063.21'TVD ---------- - - - - -- End Dir : 10591.13'MD, 10458.46'TVD 75/8'__- SCU 44-05 SR_H1ST Tgt1 rev, 5 1/2"- 10800- SCU /2"_10800SCU 33-05 SCU 44-05 SR_H12ST Tgt2 rev1 10950 FORMATION TOP DETAILS Total Depth : 11500' MD, 11152.21' TVD 11100 No formation data is available REFERENCE INFORMATION 4 1/2" - - - - - Coordinate (N/E) Reference: Well Soldotna CK Unit 33-05, True North 11250 -Vertical (TVD) Reference: SCU 44-05 revised @ 171.34usft (1 53.34'GL+1 8.0'Rig) Measured Depth Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) SCU 44-05 W133.0 Calculation Method: Minimum Curvature BHL Lgl Coords: 1231 FSL 685 FEL Sec 5 T7N R9W SM AK 11400 -600 -450 -300 -150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 Vertical Section at 185.70° (300 usft/in) SURVEY PROGRAM Date: 2014-03-10T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 296.34 9400.00 SCU 33-5 (SCU 33-05) CB -Gyro -SS 9400.00 9700.00 SCU 44-05 WP3.0 (SCU 44-05) MWD Interp Azi 9700.00 11500.00 SCU 44-05 WP3.0 (SCU 44-05) MWD+SC+sag - - Start Dir 4°/100' : 10125.01' MD, 10063.21'TVD ---------- - - - - -- End Dir : 10591.13'MD, 10458.46'TVD 75/8'__- SCU 44-05 SR_H1ST Tgt1 rev, 5 1/2"- 10800- SCU /2"_10800SCU 33-05 SCU 44-05 SR_H12ST Tgt2 rev1 10950 FORMATION TOP DETAILS Total Depth : 11500' MD, 11152.21' TVD 11100 No formation data is available REFERENCE INFORMATION 4 1/2" - - - - - Coordinate (N/E) Reference: Well Soldotna CK Unit 33-05, True North 11250 -Vertical (TVD) Reference: SCU 44-05 revised @ 171.34usft (1 53.34'GL+1 8.0'Rig) Measured Depth Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) SCU 44-05 W133.0 Calculation Method: Minimum Curvature BHL Lgl Coords: 1231 FSL 685 FEL Sec 5 T7N R9W SM AK 11400 -600 -450 -300 -150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 Vertical Section at 185.70° (300 usft/in) HALLIBURTQN Sperry Drilling 120 CU 33-05 60 0 -60 / 120 Project., Soldotna CK Unit 180- Site: Soldotna CK Unit Well: Soldotna CK Unit 33-95 Wellbore: SCU 44-05 I zoo SCU 44-05 WP3.0 -300 w M CU 42B- U -IMI 42-05Y SCU 42B -OS SCU 42 5X. KOP Lgl Coords:2043 FSL 502 FEL See 5 T7N R9W SM AK ----- KOP in 7-5/8" Csg;Start Dir 12°/100' : 9400' MD, 9389.18'TVD : -650 TF End Dir : 9420' MD, 9408.75' TVD 10 3/4" Start Dir 8'/100': 9440' MD, 9428.27'TVD End Dir : 9624.85' MD, 9604.26' TVD SCU 44-05 SR HIST Tgtl revi ------ SCU 44-05 SR H12ST Tgt2 rear - - - - - - 4 1/2"_ SCU 44-05 WP3.0 ------ Start Dir 41/100': 10125.01' MD, 10063.2 FTVD COMPANY DETAILS: Hilcorp Energy Company Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D Error Surface: Elliptical Conic Warning Method: Error Ratio REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Soldotna CK Unit 33-05, True North Vertical (TVD) Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig Measured Depth Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig Calculation Method: Minimum Curvature End Dir : 10591.13' MD, 10458.46' TVD CASING DETAILS TVD MD Name Size 10453.77 10585.00 7 5/8" 7-5/8 11152.20 11499.99 41/2" 4-1/2 WELL DETAILS: Soldotna CK Unit 33-05 Ground Level: 153.34 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 0.00 0.00 2457909.95 341744.45 60.7247852 -150.8839274 Total Depth: 11500' MD, 11152.21' TVD BHL Lgl Coords: 1231 FSL 685 FEL Sec 5 T7N R9W SM AK SECTION DETAILS ec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target 1 9400.00 11.36 240.35 9389.18 79.68 12.89 0.00 0.00 -80.57 2 9420.00 12.56 230.30 9408.75 77.32 9.50 12.00 -65.00 -77.88 3 9440.00 12.56 230.30 9428.27 74.54 6.16 0.00 0.00 -74.78 4 9624.85 23.42 195.81 9604.26 26.08 -19.46. 8.00 -61.89 -24.02 5 10125.01 23.42 195.8110063.21 -165.22 -73.61 0.00 0.00 171.71 6 10591.13 40.24 1 80.0 1 10458.46 -407.07 -99.09 4.00 -33.38 414.89 7 10676.13 40.24 180.01 10523.34 -461.98 -99.10 0.00 0.00 469.54 SCU 44-05 SR HIST Tgt1 revi 8 10974.83 40.24 180.01 10751.34 -654.95 -99.12 0.00 0.00 661.55 SCU 44-05 SR_H12ST Tgt2 rev1 9 11500.00 40.24 180.01 11152.21 -994.22 -99.16 0.00 0.00 999.16 -480 -420 -360 -300 -240 -180 -120 -60 0 60 120 ISO 240 300 360 420 480 540 West( -)/East(+) (150 usft/in) SURVEY PROGRAM Date: 2014-03-10T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 296.34 9400.00 SCU 33-5 (SCU 33-05) CB -Gyro -SS 9400.00 9700.00 SCU 44-05 WP3.0 (SCU 44-05) MWD_Interp Azi 9700.00 11500.00 SCU 44-05 WP3.0 (SCU 44-05) MWD+SC+sag Total Depth: 11500' MD, 11152.21' TVD BHL Lgl Coords: 1231 FSL 685 FEL Sec 5 T7N R9W SM AK SECTION DETAILS ec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target 1 9400.00 11.36 240.35 9389.18 79.68 12.89 0.00 0.00 -80.57 2 9420.00 12.56 230.30 9408.75 77.32 9.50 12.00 -65.00 -77.88 3 9440.00 12.56 230.30 9428.27 74.54 6.16 0.00 0.00 -74.78 4 9624.85 23.42 195.81 9604.26 26.08 -19.46. 8.00 -61.89 -24.02 5 10125.01 23.42 195.8110063.21 -165.22 -73.61 0.00 0.00 171.71 6 10591.13 40.24 1 80.0 1 10458.46 -407.07 -99.09 4.00 -33.38 414.89 7 10676.13 40.24 180.01 10523.34 -461.98 -99.10 0.00 0.00 469.54 SCU 44-05 SR HIST Tgt1 revi 8 10974.83 40.24 180.01 10751.34 -654.95 -99.12 0.00 0.00 661.55 SCU 44-05 SR_H12ST Tgt2 rev1 9 11500.00 40.24 180.01 11152.21 -994.22 -99.16 0.00 0.00 999.16 -480 -420 -360 -300 -240 -180 -120 -60 0 60 120 ISO 240 300 360 420 480 540 West( -)/East(+) (150 usft/in) Sperry r3ritling REFERENCE INFORMATION Do -ordinate (N/E) Reference: Well Soldotna CK Unit 33-05, True North Vertical (TVD) Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig easured Depth Reference: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig Calculation Method: Minimum Curvature 60 -100 -90 -80 -70 -60 -50 -40 -30 -20 -10 0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 West( -)/East(+) (25 us111in) HALLIBURTQN Plan Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Measured ND below Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Section Comments (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) (usft) 100.00 0.15 320.00 -71.34 100.00 0.08 N 0.07 W 2,457,910.03 341,744.38 0.00 -0.07 200.00 0.33 320.00 28.66 200.00 0.40 N 0.33 W 2,457,910.35 341,744.12 0.18 -0.36 300.00 0.50 319.91 128.66 300.00 0.95 N 0.80 W 2,457,910.91 341,743.66 0.17 -0.87 400.00 0.41 317.04 228.65 399.99 1.55 N 1.33 W 2,457,911.52 341,743.14 0.09 -1.41 500.00 0.33 312.77 328.65 499.99 2.01 N 1.79 W 2,457,911.98 341,742.69 0.09 -1.83 600.00 0.26 305.86 428.65 599.99 2.34 N 2.18 W 2,457,912.32 341,742.30 0.09 -2.12 700.00 0.24 297.30 528.65 699.99 2.57 N 2.55 W 2,457,912.55 341,741.93 0.04 -2.30 800.00 0.24 288.58 628.65 799.99 2.74 N 2.94 W 2,457,912.72 341,741.54 0.04 -2.43 900.00 0.25 280.03 728.65 899.99 2.84 N 3.36 W 2,457,912.83 341,741.13 0.04 -2.49 1,000.00 0.06 238.11 828.65 999.99 2.86 N 3.64 W 2,457,912.85 341,740.85 0.21 -2.48 1,100.00 0.21 122.63 928.65 1,099.99 2.73 N 3.53 W 2,457,912.73 341,740.95 0.24 -2.37 1,200.00 0.44 115.70 1,028.64 1,199.98 2.47 N 3.03 W 2,457,912.45 341,741.45 0.24 -2.15 1,300.00 0.50 118.94 1,128.64 1,299.98 2.08 N 2.26 W 2,457,912.06 341,742.21 0.06 -1.85 1,400.00 0.50 124.19 1,228.64 1,399.98 1.63 N 1.53 W 2,457,911.60 341,742.94 0.05 -1.47 1,500.00 0.50 129.41 1,328.63 1,499.97 1.11 N 0.83 W 2,457,911.07 341,743.63 0.05 -1.02 1,600.00 0.49 121.62 1,428.63 1,599.97 0.60 N 0.14 W 2,457,910.55 341,744.32 0.07 -0.58 1,700.00 0.49 111.93 1,528.63 1,699.97 0.22 N 0.62 E 2,457,910.16 341,745.07 0.08 -0.28 1,800.00 0.49 101.99 1,628.62 1,799.96 0.03S 1.44 E 2,457,909.89 341,745.89 0.09 -0.11 1,900.00 0.41 79.84 1,728.62 1,899.96 0.06S 2.22 E 2,457,909.86 341,746.66 0.19 -0.16 2,000.00 0.41 53.08 1,828.62 1,999.96 0.22 N 2.86 E 2,457,910.13 341,747.31 0.19 -0.50 2,100.00 0.49 30.95 1,928.61 2,099.95 0.81 N 3.37 E 2,457,910.71 341,747.83 0.19 -1.14 2,200.00 0.38 41.07 2,028.61 2,199.95 1.44 N 3.80 E 2,457,911.33 341,748.27 0.14 -1.81 2,300.00 0.28 62.68 2,128.61 2,299.95 1.80 N 4.23 E 2,457,911.69 341,748.71 0.16 -2.21 2,400.00 0.24 97.32 2,228.61 2,399.95 1.88 N 4.66 E 2,457,911.76 341,749.13 0.16 -2.33 2,500.00 0.24 94.06 2,328.61 2,499.95 1.81 N 5.08 E 2,457,911.68 341,749.55 0.02 -2.30 2,600.00 0.24 79.26 2,428.61 2,599.95 1.83 N 5.49 E 2,457,911.70 341,749.96 0.06 -2.37 2,700.00 0.25 65.18 2,528.61 2,699.95 1.96 N 5.89 E 2,457,911.83 341,750.36 0.06 -2.53 2,800.00 0.22 110.52 2,628.60 2,799.94 1.99 N 6.26 E 2,457,911.85 341,750.74 0.18 -2.60 2,900.00 0.32 145.23 2,728.60 2,899.94 1.69 N 6.60 E 2,457,911.55 341,751.07 0.19 -2.34 3,000.00 0.47 160.44 2,828.60 2,999.94 1.08 N 6.90 E 2,457,910.93 341,751.36 0.19 -1.76 3,100.00 0.35 152.27 2,928.60 3,099.94 0.37 N 7.17 E 2,457,910.22 341,751.63 0.13 -1.08 3,200.00 0.28 131.83 3,028.60 3,199.94 0.03S 7.48 E 2,457,909.82 341,751.93 0.13 -0.71 3,300.00 0.39 123.00 3,128.60 3,299.94 0.38S 7.95 E 2,457,909.46 341,752.39 0.12 -0.42 3,373.34 0.47 119.14 3,201.93 3,373.27 0.66S 8.42 E 2,457,909.18 341,752.85 0.12 -0.18 10 3/4" 3,400.00 0.50 118.05 3,228.59 3,399.93 0.76S 8.61 E 2,457,909.07 341,753.05 0.12 -0.09 3,500.00 0.56 106.80 3,328.59 3,499.93 1.11S 9.47 E 2,457,908.71 341,753.90 0.12 0.17 3,600.00 0.64 97.96 3,428.58 3,599.92 1.33S 10.49 E 2,457,908.48 341,754.92 0.12 0.28 3,700.00 0.73 91.17 3,528.58 3,699.92 1.42S 11.68 E 2,457,908.37 341,756.11 0.12 0.25 3,800.00 0.82 88.66 3,628.57 3,799.91 1.41S 13.03 E 2,457,908.36 341,757.46 0.09 0.11 Hileorp Energy Company Soldotna CK Unit 10 March, 2014 - 17:19 Page 2 of 8 COMPASS HA LL.IBURTQN Plan Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Section Comments (usft) (^) V) (usft) (usft) (usft) (usft) (usft) (usft) ('1100usft) (usft) 3,900.00 0.90 87.26 3,728.56 3,899.90 1.35S 14.53 E 2,457,908.40 341,758.96 0.09 -0.09 4,000.00 0.99 86.11 3,828.54 3,999.88 1.26S 16.18 E 2,457,908.47 341,760.61 0.09 -0.35 4,100.00 1.12 88.75 3,928.52 4,099.86 1.17S 18.02 E 2,457,908.53 341,762.45 0.14 -0.62 4,200.00 1.26 90.96 4,028.50 4,199.84 1.17S 20.10 E 2,457,908.50 341,764.53 0.14 -0.83 4,300.00 1.36 90.52 4,128.48 4,299.82 1.20S 22.38 E 2,457,908.44 341,766.81 0.10 -1.02 4,400.00 1.46 90.15 4,228.45 4,399.79 1.22S 24.84 E 2,457,908.39 341,769.27 0.10 -1.25 4,500.00 1.54 88.35 4,328.41 4,499.75 1.20S 27.46 E 2,457,908.38 341,771.89 0.10 -1.54 4,600.00 1.62 85.65 4,428.37 4,599.71 1.05S 30.22 E 2,457,908.49 341,774.65 0.11 -1.95 4,700.00 1.70 83.21 4,528.33 4,699.67 0.77S 33.11 E 2,457,908.73 341,777.54 0.11 -2.52 4,800.00 1.63 81.81 4,628.29 4,799.63 0.37S 36.06 E 2,457,909.09 341,780.50 0.09 -3.22 4,900.00 1.36 81.29 4,728.25 4,899.59 0.02 N 38.65 E 2,457,909.44 341,783.09 0.26 -3.85 5,000.00 1.29 77.29 4,828.23 4,999.57 0.41 N 40.86 E 2,457,909.80 341,785.31 0.12 -4.46 5,100.00 1.38 71.33 4,928.20 5,099.54 1.04 N 43.09 E 2,457,910.40 341,787.55 0.16 -5.31 5,200.00 1.48 66.12 5,028.17 5,199.51 1.94 N 45.41 E 2,457,911.28 341,789.88 0.16 -6.44 5,300.00 1.50 63.79 5,128.14 5,299.48 3.06 N 47.77 E 2,457,912.36 341,792.26 0.07 -7.79 5,400.00 1.50 62.21 5,228.10 5,399.44 4.25 N 50.10 E 2,457,913.52 341,794.60 0.04 -9.20 5,500.00 1.43 61.27 5,328.07 5,499.41 5.47 N 52.36 E 2,457,914.71 341,796.88 0.07 -10.64 5,600.00 1.35 60.34 5,428.04 5,599.38 6.65 N 54.48 E 2,457,915.86 341,799.01 0.08 -12.02 5,700.00 1.27 59.30 5,528.01 5,699.35 7.80 N 56.46 E 2,457,916.98 341,801.00 0.08 -13.36 5,800.00 1.35 52.85 5,627.99 5,799.33 9.03 N 58.33 E 2,457,918.19 341,802.90 0.17 -14.78 5,900.00 1.50 45.93 5,727.96 5,899.30 10.66 N 60.21 E 2,457,919.79 341,804.80 0.23 -16.58 6,000.00 1.58 41.96 5,827.92 5,999.26 12.59 N 62.07 E 2,457,921.70 341,806.69 0.13 -18.69 6,100.00 1.66 38.37 5,927.88 6,099.22 14.75 N 63.89 E 2,457,923.83 341,808.53 0.13 -21.01 6,200.00 1.75 35.13 6,027.84 6,199.18 17.13 N 65.67 E 2,457,926.19 341,810.34 0.13 -23.56 6,300.00 1.96 36.45 6,127.78 6,299.12 19.75 N 67.55 E 2,457,928.78 341,812.26 0.22 -26.36 6,400.00 2.19 37.66 6,227.72 6,399.06 22.64 N 69.74 E 2,457,931.64 341,814.48 0.23 -29.44 6,500.00 2.41 38.65 6,327.64 6,498.98 25.79 N 72.21 E 2,457,934,76 341,817.00 0.23 -32.83 6,600.00 2.57 39.00 6,427.54 6,598.88 29.18 N 74.96 E 2,457,938.12 341,819.79 0.16 -36.48 6,700.00 2.69 39.00 6,527.44 6,698.78 32.75 N 77.84 E 2,457,941.64 341,822.72 0.12 40.31 6,800.00 2.80 39.00 6,627.32 6,798.66 36.47 N 80.86 E 2,457,945.32 341,825.79 0.12 -44.31 6,900.00 2.92 39.00 6,727.20 6,898.54 40.35 N 84.00 E 2,457,949.16 341,828.98 0.12 48.48 7,000.00 3.00 39.00 6,827.06 6,998.40 44.38 N 87.26 E 2,457,953.14 341,832.30 0.08 -52.82 7,100.00 3.00 39.00 6,926.93 7,098.27 48.44 N 90.55 E 2,457,957.17 341,835.65 0.00 -57.19 7,200.00 3.00 39.00 7,026.79 7,198.13 52.51 N 93.85 E 2,457,961.19 341,838.99 0.00 -61.56 7,300.00 3.00 39.00 7,126.65 7,297.99 56.58 N 97.14 E 2,457,965.21 341,842.34 0.00 -65.94 7,400.00 3.00 39.00 7,226.52 7,397.86 60.64 N 100.43 E 2,457,969.23 341,845.69 0.00 -70.31 7,500.00 2.79 37.45 7,326.39 7,497.73 64.61 N 103.56 E 2,457,973.16 341,848.87 0.22 -74.57 7,600.00 2.58 35.66 7,426.28 7,597.62 68.37 N 106.35 E 2,457,976.88 341,851.71 0.22 -78.59 7,700.00 2.38 33.57 7,526.18 7,697.52 71.94 N 108.82 E 2,457,980.41 341,854.22 0.22 -82.38 Hilcorp Energy Company Soldotna CK Unit 10 March, 2014 - 17:19 Page 3 of 8 COMPASS FWWM'11111111=1�i Plan Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Measured 12.56 230.30 TVD below Vertical Local Coordinates Map Coordinates Dogleg Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°/100usft) 7,800.00 2.25 31.74 7,626.10 7,797.44 75.31 N 110.97 E 2,457,983.75 341,856.42 0.15 7,900.00 2.25 31.00 7,726.03 7,897.37 78.66 N 113.01 E 2,457,987.08 341,858.51 0.03 8,000.00 2.25 30.26 7,825.95 7,997.29 82.04 N 115.01 E 2,457,990.43 341,860.55 0.03 8,100.00 2.25 28.58 7,925.87 8,097.21 85.45 N 116.95 E 2,457,993.82 341,862.54 0.07 8,200.00 2.25 26.38 8,025.80 8,197.14 88.93 N 118.76 E 2,457,997.27 341,864.39 0.09 8,300.00 2.12 28.94 8,125.72 8,297.06 92.34 N 120.51 E 2,458,000.65 341,866.19 0.16 8,400.00 0.95 6.62 8,225.67 8,397.01 95.25 N 122.14 E 2,458,003.54 341,867.86 1.29 8,500.00 3.17 245.38 8,325.60 8,496.94 94.41 N 119.14 E 2,458,002.75 341,864.85 3.75 8,600.00 3.73 246.87 8,425.40 8,596.74 91.88 N 113.51 E 2,458,000.29 341,859.18 0.57 8,700.00 4.69 260.15 8,525.14 8,696.48 89.92 N 106.54 E 2,457,998.42 341,852.18 1.36 8,800.00 5.91 267.35 8,624.70 8,796.04 88.87 N 97.30 E 2,457,997.50 341,842.94 1.39 8,900.00 6.87 275.68 8,724.09 8,895.43 89.26 N 86.29 E 2,457,998.04 341,831.93 1.33 9,000.00 7.93 280.92 8,823.24 8,994.58 91.15 N 73.39 E 2,458,000.10 341,819.06 1.26 9,100.00 8.93 285.40 8,922.19 9,093.53 94.50 N 59.37 E 2,458,003.64 341,805.09 1.20 9,200.00 8.82 256.52 9,020.99 9,192.33 95.68 N 44.18 E 2,458,005.02 341,789.91 4.41 9,300.00 10.14 240.78 9,119.63 9,290.97 89.22 N 29.14 E 2,457,998.76 341,774.79 2.90 9,400.00 11.36 240.35 9,217.84 9,389.18 79.68 N 12.89 E 2,457,989.45 341,758.41 1.22 9,400.01 11.36 240.35 9,217.85 9,389.19 79.68 N 12.89 E 2,457,989.45 341,758.41 0.00 9,420.00 12.56 230.30 9,237.41 9,408.75 77.32 N 9.50 E 2,457,987.13 341,754.99 12.01 9,440.00 12.56 230.30 9,256.93 9,428.27 74.54 N 6.16 E 2,457,984.40 341,751.61 0.00 9,500.00 15.40 214.17 9,315.17 9,486.51 63.77 N 3.34 W 2,457,973.76 341,741.96 8.00 9,600.00 21.70 198.40 9,409.98 9,581.32 35.19 N 16.66 W 2,457,945.36 341,728.26 8.00 9,624.85 23.42 195.81 9,432.93 9,604.27 26.08 N 19.46 W 2,457,936.29 341,725.34 8.00 9,700.00 23.42 195.81 9,501.88 9,673.22 2.66S 27.59 W 2,457,907.66 341,716.82 0.00 9,800.00 23.42 195.81 9,593.64 9,764.98 40.91 S 38.42 W 2,457,869.56 341,705.48 0.00 9,900.00 23.42 195.81 9,685.40 9,856.74 79.16S 49.25 W 2,457,831.46 341,694.14 0.00 10,000.00 23.42 195.81 9,777.16 9,948.50 117.41S 60.08 W 2,457,793.36 341,682.79 0.00 10,100.00 23.42 195.81 9,868.92 10,040.26 155.66S 70.91 W 2,457,755.26 341,671.45 0.00 10,125.01 23.42 195.81 9,891.87 10,063.21 165.22S 73.61 W 2,457,745.73 341,668.62 0.00 10,200.00 25.98 192.04 9,960.00 10,131.34 195.63S 81.10 W 2,457,715.42 341,660.72 4.00 10,300.00 29.51 187.98 10,048.50 10,219.84 241.46S 89.09 W 2,457,669.71 341,652.11 4.00 10,400.00 33.13 184.73 10,133.92 10,305.26 293.10S 94.77 W 2,457,618.14 341,645.74 4.00 10,500.00 36.83 182.06 10,215.84 10,387.18 350.32S 98.11 W 2,457,560.98 341,641.64 4.00 10,585.00 40.01 180.14 10,282.43 10,453.77 403.12S 99.09 W 2,457,508.20 341,639.94 4.00 10,591.13 40.24 180.01 10,287.12 10,458.46 407.07S 99.09 W 2,457,504.25 341,639.89 4.00 Hilcorp Energy Company Soldotna CK Unit Vertical Section Comments (usft) -85.95 -89.49 -93.05 -96.64 -100.28 -103.84 -106.90 -105.77 -102.69 -100.04 -98.09 -97.38 -97.99 -99.93 -99.59 -91.67 -80.57 -80.57 KOP Lgl Coords:2043 FSL 502 FEL Sec 5 T7N R9W SM AK - KOP in 7-5/8" Csg;Start Dir 121/100': 9400' MD, 9389.18'TVD :-65* TF -77.88 End Dir : 9420' MD, 9408.75' TVD -74.78 Start Dir 81/100': 9440' MD, 9428.27'TVD -63.13 -33.37 -24.02 End Dir : 9624.85' MD, 9604.26' TVD 5.39 44.52 83.66 122.79 161.93 171.71 Start Dir 4°/100' : 10125.01' MD, 10063.217VD 202.72 249.11 301.06 358.32 410.96 7 5/8" 414.89 End Dir : 10591.13' MD, 10458.46' TVD 10 March, 2014 - 17:19 Page 4 of 8 COMPASS W • Plan Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Measured Local Coordinates Section TVD below Vertical Local Coordinates Map Coordinates Dogleg Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate (usft) V) V) (usft) (usft) (usft) (usft) (usft) (usft) (°i100usft) 10,600.00 40.24 180.01 10,293.89 10,465.23 412.80S 99.09 W 2,457,498.52 341,639.81 0.00 10,671.87 40.24 180.01 10,348.75 10,520.09 459.23S 99.10 W 2,457,452.09 341,639.18 0.00 10,676.13 40.24 180.01 10,352.00 10,523.34 461.98S 99.10 W 2,457,449.34 341,639.14 0.00 10,700.00 40.24 180.01 10,370.22 10,541.56 477.40S 99.10 W 2,457,433.92 341,638.93 0.00 10,800.00 40.24 180.01 10,446.55 10,617.89 542.00 S 99.11 W 2,457,369.32 341,638.05 0.00 10,900.00 40.24 180.01 10,522.88 10,694.22 606.61S 99.12 W 2,457,304.73 341,637.18 0.00 10,974.83 40.24 180.01 10,580.00 10,751.34 654.95S 99.12 W 2,457,256.39 341,636.52 0.00 11,000.00 40.24 180.01 10,599.21 10,770.55 671.21 S 99.13 W 2,457,240.13 341,636.30 0.00 11,026.31 40.24 180.01 10,619.30 10,790.64 688.21 S 99.13 W 2,457,223.13 341,636.07 0.00 11,100.00 40.24 180.01 10,675.54 10,846.88 735.81 S 99.13 W 2,457,175.53 341,635.42 0.00 11,200.00 40.24 180.01 10,751.88 10,923.22 800.42S 99.14 W 2,457,110.94 341,634.54 0.00 11,255.03 40.24 180.01 10,793.88 10,965.22 835.96S 99.14 W 2,457,075.39 341,634.06 0.00 11,300.00 40.24 180.01 10,828.21 10,999.55 865.02S 99.15 W 2,457,046.34 341,633.67 0.00 11,400.00 40.24 180.01 10,904.54 11,075.88 929.62S 99.16 W 2,456,981.74 341,632.79 0.00 11,499.99 40.24 180.01 10,980.86 11,152.20 • 994.22S 99.16 W 2,456,917.15 341,631.91 0.00 11,500.00 40.24 Plan Annotations Measured Depth (usft) 9,400.01 9,400.01 9,420.00 9,440.00 9,624.85 10,125.01 10,591.13 11,499.99 11,499.99 180.01 10,980.87 11,152.21 994.22S 99.16 W 2,456,917.15 341,631.91 0.00 Vertical Local Coordinates Section Depth +N/ -S +E/ -W Comment (usft) (usft) (usft) 9,389.19 79.68 12.89 KOP Lgl Coords:2043 FSL 502 FEL Sec 5 T7N R9W SM AK 9,389.19 79.68 12.89 KOP in 7-5/8" Csg;Start Dir 120/100' : 9400' MD, 9389.18'TVD : -65" 661.55 SCU 44-05 SR_H12ST Tgt2 rev1 TF 9,408.75 77.32 9.50 End Dir : 9420' MD, 9408.75' TVD 9,428.27 74.54 6.16 Start Dir 81/100': 9440' MD, 9428.27'TVD 9,604.27 26.08 -19.46 End Dir : 9624.85' MD, 9604.26' TVD 10,063.21 -165.22 -73.61 Start Dir 41/100' : 10125.01' MD, 10063.217VD 10,458.46 -407.07 -99.09 End Dir : 10591.13' MD, 10458.46' TVD 11,152.20 -994.22 -99.16 BHL Lgl Coords: 1231 FSL 685 FEL Sec 5 T7N R9W SM AK 11,152.20 -994.22 -99.16 Total Depth : 11500' MD, 11152.21' TVD , Hileorp Energy Company Soldotna CK Unit Vertical Section Comments (usft) 420.59 466.80 SCU 44-05 (Opt B) SR -H1 ST Tgt1 - SCU 44-05 SR -HIST Tgt1 469.54 SCU 44-05 SR_H1ST Tgt1 revi 484.88 549.16 613.45 661.55 SCU 44-05 SR_H12ST Tgt2 rev1 677.73 694.65 SCU 44-05 SR_H12ST Tgt2 742.02 806.30 841.68 SCU 44-05 (Opt B) SR_H12ST Tgt2 870.59 934.87 999.15 BHL Lgl Coords: 1231 FSL 685 FEL Sec 5 T7N R9W SM AK - Total Depth : 11 500'MD, 11152.21' TVD - 4 1/2" 999.16 10 March, 2014 - 17:19 Page 5 of 8 COMPASS is /_\ � ■I i=��1 _� �•T►�l Hilcorp Energy Company Soldotna CK Unit Plan Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Vertical Section Information Target Name Dip Dip Angle Origin Origin Start Type Target Azimuth Type +N/_S +E/ -W TVD +E/ -W (1) (usft) (usft) (usft) TD No Target (Freehand) 185.70 Slot 0.00 0.00 18.00 Survey tool program -461.98 -99.10 plan hits target center From To Survey/Plan Survey Tool (usft) (usft) 296.34 9,400.00 SCU 33-5 0.00 CB -Gyro -SS 9,400.00 9,700.00 SCU 44-05 WP3.0 MWD_Interp Azi 9,700.00 11,500.00 SCU 44-05 WP3.0 MWD+SC+sag Casing Details Measured Vertical Casing Hole Depth Depth Name Diameter Diameter (usft) (usft) 3,373.34 3,373.27 10 3/4" 10-3/4 12-1/4 10,585.00 10,453.77 7 5/8" 7-5/8 9-7/8 11,499.99 11,152.20 41/2" 4-1/2 6-1/8 Design Targets Target Name Dip Dip hit/miss target Angle Dir. TVD +N/ -S +E/ -W Shape (1) (1) (usft) (usft) (usft) SCU 44-05 SIR _WST 0.00 0.00 10,523.34 -461.98 -99.10 plan hits target center Point SCU 44-05 SR H12S1 0.00 0.00 10,751.34 -654.95 -99.12 plan hits target center Point Directional Difficulty Index Northing Easting (usft) (usft) 2,457,449.34 341,639.14 2,457,256.39 341,636.52 Latitude Longitude 60.7235214 -150.8844809 60.7229935 -150.8844810 Average Dogleg over Survey: 1.71 °/100usft Maximum Dogleg over Survey: 12.00 °/100usft at 9,420.00 usft Net Tortousity applicable to Plans: 1.71 °/100usft Directional Difficulty Index: 5.034 10 March, 2014 - 17:19 Page 6 of 6 COMPASS HALLIBURTON Plan Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Audit Info Hilcorp Energy Company Soldotna CK Unit 10 March, 2014 - 17:19 Page 7 of 8 COMPASS HALL.IBURTON Hilcorp Energy Company Soldotna CK Unit North Reference Sheet for Soldotna CK Unit - Soldotna CK Unit 33-05 - SCU 44-05 All data is in US Feet unless otherwise stated. Directions and Coordinates are relative to True North Reference. Vertical Depths are relative to SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig). Northing and Easting are relative to Soldotna CK Unit 33-05 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 -150.0000000°, Longitude Origin:0.0000000°, Latitude Origin:0.0000000° False Easting: 500,000.00usft, False Northing: 0.00usft, Scale Reduction: 0.99992850 Grid Coordinates of Well: 2,457,909.95 usft N, 341,744.45 usft E Geographical Coordinates of Well: 60° 43'29.23" N, 150° 53'02.14" W Grid Convergence at Surface is: -0.77° Based upon Minimum Curvature type calculations, at a Measured Depth of 11,500.00usft the Bottom Hole Displacement is 999.16usft in the Direction of 185.70° ( True). Magnetic Convergence at surface is: -17.93° (21 February 2014, , BGGM2013) T Magnetic Model: BGGM2013 M Date: 21 -Feb -14 Declination: 17.16° Inclination/Dip: 73.71' Field Strength: 55509 wool Grid Nath is 0.77° West of True North (Grid Convergence) Magnetic North is 17AT East of True Nath (Magnetic Dedhatial) Magnetic North is 17.93° East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Acid 0.77° To convert a Ma"ic Direction to a True Direction, Add 17.16° East To convert a Magnetic Direction to a Grid Direction, Add 17.93° 10 March, 2014 - 17:19 Page 8 of 8 COMPASS Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit Soldotna CK Unit 33-05 SCU 44-05 SCU 44-05 WP3.0 Sperry Drilling Services Clearance Summary Anticollision Report 10 March, 2014 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: Soldotna CK Unit - Soldotna CK Unit 33-05 - SCU 44-05 - SCU 44-05 WP3.0 Well Coordinates: 2,457,909.95 N, 341,744.45 E (60° 43'29.23" N, 150° 53' 02.14" W) Datum Height: SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig) Scan Range: 9,400.00 to 11,500.00 usft. Measured Depth. Scan Radius is 1,348.20 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Version: 5000.1 Build: 70 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services N,ALL.IBURTON Anticollision Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Hilcorp Energy Company Soldotna CK Unit Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: Soldotna CK Unit - Soldotna CK Unit 33-05 - SCU 44-05 - SCU 44-05 WP3.0 Scan Range: 9,400.00 to 11,500.00 usft. Measured Depth. Scan Radius is 1,348.20 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Soldotna CK Unit Soldotna CK Unit 314-4 - SCU 34B-05 - SCU 34B-05 W Soldotna CK Unit 314-4 - SCU 34B-05 - SCU 34B-05 W Soldotna CK Unit 33-05 - SCU 33-05 - SCU 33-05 Soldotna CK Unit 33-05 - SCU 33-05 - SCU 33-05 Soldotna CK Unit 42-05RD - SCU 42-05RD - SCU 42-0 Soldotna CK Unit 42-05RD - SCU 42A-05 - SCU 42A-0 Soldotna CK Unit 42B-05 - SCU 42B-05 - SCU 42B-05 Survey fool imo4ram 11,287.46 1,075.43 11,287.46 1,017.63 11,031.58 18.604 Ellipse Separation 11,325.00 1,076.09 11,325.00 1,018.23 11,031.58 18.599 Clearance Factor 9,400.00 1,182.43 9,400.00 1,137.93 9,204.42 26.566 Clearance Factor 9,400.00 1,182.43 9,400.00 1,137.99 9,204.42 26.604 Clearance Factor 9,400.00 577.39 9,400.00 532.48 9,386.12 12.856 Clearance Factor From To (usft) (usft) 296.34 9,400.00 9,400.00 9,700.00 SCU 44-05 WP3.0 9,700.00 11,500.00 SCU 44-05 WP3.0 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool CB -Gyro -SS M W D_I nterp Azi MWD+SC+sag Pass - Pass - Pass - Pass - Pass - 10 March, 2014 - 17:14 Page 2 of 4 COMPASS HAL.L.IBURTON Anticollision Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to SCU 44-05 revised @ 171.34usft (153.34'GL+18.0'Rig). Northing and Easting are relative to Soldotna CK Unit 33-05. Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04. Central Meridian is -150.00°, Grid Convergence at Surface is. -0.77 `. 1201 Z) 0 0 c O T 801 Q N M A Ladder Plot Measured Depth (2000 usfUin) Hileorp Energy Company Soldotna CK Unit LEGEND CK Unit314-4, SCU 346-05, SCU 346-05 WP2.0 (KOP @ CK Unit 33-05, SCU 33-05, SCU 33-05 VO CK Unit42-05RD, SCU 42-05RD, SCU 42-05RD V 0 CK Unit42-05RD, SCU42A-05, SCU 42A-05 VO CK Unit42-05X, SCU42-05X, SCU42-05X VO CK Unit42-05Y, SCU 42-05Y, SCU 42-05Y VO CK Unit426-05, SCU426-05, SCU4213-05 VO CK Unit426-05, SCU 426-05PB1, SCU42B-05 PB1 VO )5 WP3.0 10 March, 2014 - 17:14 Page 3 of 4 COMPASS ----------------------- i I 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 I 1 - - - I --- I I I I I I I 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 I I I I - - - -I- I I I I I I 1 I - -- - - -I - - - - - I I I I - - - - -I - - - - - I I I I - - - - -I - - - - - I I I I ---------0 - - - - -I ---------- I I I I I I I I 0 2000 4000 Fenn 800O 10000 Measured Depth (2000 usfUin) Hileorp Energy Company Soldotna CK Unit LEGEND CK Unit314-4, SCU 346-05, SCU 346-05 WP2.0 (KOP @ CK Unit 33-05, SCU 33-05, SCU 33-05 VO CK Unit42-05RD, SCU 42-05RD, SCU 42-05RD V 0 CK Unit42-05RD, SCU42A-05, SCU 42A-05 VO CK Unit42-05X, SCU42-05X, SCU42-05X VO CK Unit42-05Y, SCU 42-05Y, SCU 42-05Y VO CK Unit426-05, SCU426-05, SCU4213-05 VO CK Unit426-05, SCU 426-05PB1, SCU42B-05 PB1 VO )5 WP3.0 10 March, 2014 - 17:14 Page 3 of 4 COMPASS HALLIBURTON Anticollision Report for Soldotna CK Unit 33-05 - SCU 44-05 WP3.0 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor Hileorp Energy Company Soldotna CK Unit LEGEND Ana CK Unit 314-4, SCU 34B-05, SCU 34B-05 WP2.0 (KOP @ 74D( Dtna CK Unit 33-05, SCU 33-05, SCU 33-05 V0 Dtna CK Unit42-05RD, SCU 42-05RD, SCU 42-05RD V 0 Ana CK Unit42-05RD, SCU 42A-05, SCU 42A-05 VO Dtna CK Un it42-05X, SCU 42-05X, SCU 42-05X VO Dina CK Unit42-05Y, SCU 42-05Y, SCU 42-05Y VO Etna CK Unit42B-05, SCU42B-05, SCU42B-05 VO tnaCKUnit42B-05,SCU42B-05PB1,SCU42B-05PB1 VO 44-05 WP3.0 10 March, 2014 - 17:14 Page 4 of 4 COMPASS iJ lVI _ L L. �i __H 1,1 ,VE,T L N,�,,IAE: -5,l-v-f'�� C ieci� 1::0 fal All o _-i6,`e i- etteT / pa[-agraphs to he Fnciud.eci IM "'rartse-nit2a.L tetter C111`1_'C11K i G PT TOK Is' i - — 1'EX.T FOR APT'ROVAL, LE i > ER I MU1.11 IhC I)Crnllt is for a new \N-ellbote scLImcnt 01 c lstin2 Nve11 Permit i Al FR;1!No. API No. 50- Revised 5/2013 (11last mo dl'?lts Piodticilon slimild CoI1LInUC to be rCportcd as ('I funclioll of 111C orl'_1111al In AI'l nU1111)Cr are A11 mimbei- stated ab(1V e. tw1 ecn 60-69) � — -- ------ X11 accordaiicc with 20 AAC 25.005(j). all l-ccords. &1a alld lop acquired for the pilot bole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) fi-om 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 pennafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this pennit: 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 also required for this well: Well Logging 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. Revised 5/2013 WELL PERMIT CHECKLIST Field & Pool SWANSON RIVER, HEMLOCK OIL - 772100 Well Name: SOLDOTNA CK UNIT 44-05 Program DEV Well bore seg PTD#: 2140380 Company HILCORP ALASKA LLC Initial Class/Type DEV/PEND GeoArea 820 Unit 51950 On/Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well lies in lease FEDA028996. 3 Unique well name and number Yes Yes. 4 Well located in a defined pool Yes This well is located within Soldotna Creek Unit, Swanson River Field. 5 Well located proper distance from drilling unit boundary Yes This well will open Swanson River, Hemlock Oil Pool - 772100 governed by CO 1238. 6 Well located proper distance from other wells Yes CO 123B, Rule 5: There shall be no restrictions as to the well spacing within the Hemlock Oil Pool 7 Sufficient acreage available in drilling unit Yes except that no wellbore may be open to test or regular production in a well within 500' of the external 8 If deviated, is wellbore plat included Yes property line of the Affected Area [of CO 123B] where the owners and landowners are not the same on 9 Operator only affected party Yes both sides of the line. As planned, this well conforms to spacing requirements. 10 Operator has appropriate bond in force Yes Bond number 022035244. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 3/13/2014 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in SCU 33-05 (motherbore) Engineering 19 Surface casing protects all known USDWs NA Surface casing is set at 3372' and and fully cemented. 20 CMT vol_ adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA_ window will be cut at 9400ft... liner will be fully cemented . (4.5" liner) 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes BTC calc_s_provide for 4.5" liner. Meets industry standards. 24 Adequate tankage or reserve pit Yes All waste to be transported to G & I facility 25 If a re -drill, has a 10-403 for abandonment been approved Yes 314-111 sundry approved. 26 Adequate wellbore separation proposed Yes Proximity analysis performed... wellbore diverges from 33-05 27 If diverter required, does it meet regulations NA Wellhead in place.. Will use BOPE Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max form _ation press= 3226 psi (5.7 ppg EMW) Will drill with 9.5-10.5 ppg mud GLS 3/14/2014 29 BOPEs, do they meet regulation Yes Saxon 169 has 5000 psi 11" BOPE 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2111 psi Will test BOPE to 3500 psi 31 Choke manifold complies w/API RP -53 (May 84) Yes 5000 psi choke manifold. 32 Work will occur without operation shutdown Yes Workover rig will come in to run tubing and perforate well. 33 Is presence of H2S gas probable No H2S not expected.. Rig has sensors -and alarms 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes H2S not reported from Soldotna Creek Unit or S_w_anson River Field. Geology 36 Data presented on potential overpressure zones Yes Und-erpressured reservoir_(2.5 to -5.7 ppg_EMW)_expected; will be drilled_ using 9.5 - 10.0 ppg mud. High- Appr Date 37 Seismic_ analysis of shallow gas zones _N_A pressure_Tyonek Water Sand _(9.6ppg) lies 440'_ MD (434' TVD) above the planned kick-off_ point. SFD 3/13/2014 38 Seabed condition survey (if off -shore) NA_ 39 Contact name/phone for weekly_ progress reports [exploratory only] N_A Geologic Engineering Public ST of existing well SCU 33-05 to the south. Commissioner: Date: Co ssione : Date Commissioner Date