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210-186
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 07/23/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number 18-13 187-100 50-029-21756-00-00 18-13PB1 187-100 50-029-21756-70-00 18-13PB2 187-100 50-029-21756-71-00 18-13A 197-223 50-029-21756-01-00 18-13B 207-157 50-029-21756-02-00 18-13BPB1 207-157 50-029-21756-72-00 18-13BPB2 207-157 50-029-21756-73-00 18-13BPB3 207-157 50-029-21756-74-00 18-13C 210-186 50-029-21756-03-00 Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/25/2023 Main Folder Contents: Please include current contact information if different from above. T39261 T39262 T39263 T39264 T39265 T39266 T39267 T39268 T3926918-13C 210-186 50-029-21756-03-0 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.24 08:23:01 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 116' 13-3/8"K-55/L-80 4428' 9-5/8" L-80 8242' 7" L-80 8295' 4-1/2" L-80 8295' 3-1/2" x3-3/16"L-80 8353' 2-3/8" L-80 8722' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Choke Size: Sr Res EngSr Pet GeoSr Pet Eng PRUDHOE BAY, PRUDHOE BAY OIL None Oil-Bbl: Water-Bbl: MWD DIR, GR, RES, GR / CCL / MCNL 29# 8805' 9202' 8066' 8-1/2" 500 sx Class G 9267' Set Whipstock Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Oil-Bbl: Flow Tubing N/A Gas-Oil Ratio: 36' 36' Per 20 AAC 25.283 (i)(2) attach electronic information 47# 9202' 35' 8004' 91.5# 68#/72# 116' 35' 9103' CASING WT. PER FT.GRADE 2/6/2011 CEMENTING RECORD 5959066 1900' (Approx.) SETTING DEPTH TVD 5959158 TOP HOLE SIZE AMOUNT PULLED 694787 697320 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. 50-029-21756-03-00 PBU 18-13C ADL 028321 1045' FNL, 371' FWL, Sec. 19, T11N, R15E, UM, AK 2426' FSL, 552' FWL, Sec. 20, T11N, R15E, UM, AK 79-190 1/30/2011 12650' / 8721' 9267' / 8332' 54.8' 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 692133 5960832 2400' FSL, 1983' FEL, Sec. 19, T11N, R15E, UM, AK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 7/8/2024 210-186 324-248 & 324-173 SIZE DEPTH SET (MD) 8548' / 7920' PACKER SET (MD/TVD) 4.7# 8594' 9305' 9300' / 8353' 30" 8.81#/6.2# 3" 78 sx Class G BOTTOM 17-1/2" 1694# Poleset 36'3500 sx CS III, 600 sx G, 100 sx CS II 12.6# 36' 8698' 4482' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 779' 523 sx Class G6" TUBING RECORD 141 sx Class G 12641' 9300' 930 sx Class G 7946' 8357' 12-1/4" 4-1/8" 8662' / 7984' 8718'4-1/2" 12.6# 13Cr80/L-80 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 17.4' By James Brooks at 11:53 am, Jul 23, 2024 Abandoned 7/8/2024 JSB RBDMS JSB 080524 xGDSR-8/27/24MGR26DEC2025 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 9767' 8664' 9383'8412' 9452'8465' 9767'8664' Zone 1 9767' 8664' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Monty Myers / Bo York Contact Name: Joe Lastufka Digital Signature with Date:Contact Email:joseph.lastufka@hilcorp.com Contact Phone:907-777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Zone 1 Summary of Pre-Rig Work, Daily Drilling Summary, Wellbore Schematic Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Base CGL - Zone 2 Authorized Title: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base CGL - Zone 3 Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Drilling Manager 07/23/24 Monty M Myers Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.07.23 09:37:48 - 08'00' Bo York (1248) ACTIVITYDATE SUMMARY 4/3/2024 ***WELL S/I ON ARRIVAL*** BRUSH w/ 4-1/2'' BLB, 3.80'' SLOW GOING OUT OF THE LUBE, CLEAN UP AREA IN MULTI SPOTS FROM SURFACE TO ABOUT ~3000' SLM, TAG LTP @ 8510' SLM RAN 4-1/2'' GR, S/D @ LATCH 45 KB LTP @ 8510' SLM (see log & cont on next day) ***WSR CONT ON 4-4-24*** 4/3/2024 T/I/O = 2350/140/50. Temp = SI. IA FL (SL). No AL. IA FL @ 6225' (sta # 2 SO). SL in control of valves upon departure. 21:30 4/4/2024 ***WSR CONT FROM 4-3-24*** PULLED & LEFT 45 KB LTP @ 868' SLM (see log) BRUSHED TBG & TAGGEDTOP OF 45 KB LTP w/ 2' x 1-7/8'' STEM, 4-1/2'' BLB, 3.85'' G-RING @ 879' SLM (lrs pumped 40 bbls hot diesel) PULLED 45 KB LTP UP TO 300' SLM, ATTEMPT TO JAR BACK DOWN WHILE PUMPING (lrs pumped 50bbl hot) PULLED 45 KB LTP (see log, 1 element missing) RAN BRUSH & WIRE GRAB TO DEPOYMENT SLV @ 8530'SLM/8526'MD(no recovery) RAN 10'x1.56'' DMY GUN w/1.75'' CENT TO 9400'SLM SET 3.81'' PX-PLUG w/ BAITED PRONG IN X-NIP @ 8518'MD PULLED RK-GLV FROM STA#2 & STA#3 @ 6225', 3009' MD SET RK-DGLV IN STA# 3 @ 3009' MD ***WSR CONT. ON 04-05-2024*** 4/4/2024 T/I/O=2190/130/50 Assist Slickline as Needed Pump 50 bbls 180* diesel down tbg FWHPs=1640/135/55 4/4/2024 Assist Slickline w/ B&F (CTD) Pumped 40 bbls 180* DSL down Tbg while SL brushed. SL in control of well per LRS departure. IA,OA=OTG 4/5/2024 T/I/O = 861/863/48 (CIRC - OUT) Pumped 362 bbls of 120*F 1% KCL down TBG tanking returns up the IA and down the flowline of 18-12 via hardline. Pumped 172 bbls of AMB*F DSL down IA taking returns up the TBG and down the flowline of 18- 12 via hardline. ***Job Continued 4-6-24*** 4/5/2024 ***CONT. FROM 04-04-2024*** SET FLOW SLEEVE IN STA# 2 @ 6225' MD STANDBY FOR FUILDS CIRC. WELL W/ 365 BBLS 1% KCL, 172 BBLS DIESEL ***WSR CONT. ON 04-06-2024*** 4/5/2024 T/I/O = VAC/50/80. Temp = SI. T, IA FL ( assist slickline). No AL. T FL @ 1480' & IA FL @ 1430'. Slickline in control of well upon departure. 22:30 4/5/2024 ( CIRC OUT ) Proceedure needed revision. Called to another job while on stanby for well support. Will return at a later time. DSO notified upon departure. Daily Report of Well Operations PBU 18-13C Daily Report of Well Operations PBU 18-13C 4/6/2024 ***Job Continued from 4-5-24*** (CTU) U-Tubed T/IA. FP 18-12 FL 5 60/40 , 70 crude pressured up to 1500 psi. Combo MIT TxIA (PASSED) Pumped 6 bbls diesel to reach max applied pressure 2750 psi. 15 min Loss T-56 psi IA-52 psi. 30 min Loss T-27 psi , IA-27 psi. 45 min Loss T-23 psi IA-21 psi. 60 min Loss T-20 psi IA-20 psi. 75 min Loss T-17 psi. IA-18 psi. Bleed back 5 bbls bbls to starting pressure. MIT-T (PASSED) Pumped 2.25 bbls DSL to reach max applied pressure 2750 psi. 15 min Loss T-78 psi . 30 min Loss T-32 psi. Bleed back 2 bbls to T/I/O=890/319/62. RD Turn well over to SL. 4/6/2024 ***WSR CONT. FROM 04-05-2024*** C-MIT (Pass) PULLED RK-FS IN STA#2 @ 6225' MD SET RK-DGLV IN STA#2 @ 6225' MD LRS PERFORMED PASSING 2,500 psi MIT-T (see lrs log) PULLED P-PRONG FROM PLUG BODY @ 8518'MD PULLED 4-1/2" PX-PLUG FROM X-NIP @ 8518'MD ***WELL LEFT S/I ON DEPARTURE*** 5/9/2024 ***WELL SHUT IN ON ARRIVAL*** (TUBING CUT) MIRU AKEL PT PCE 250 LP 3000 HP RUN 1.50" RCT CUT 2 3/8 LINER @ 9305' CCL STOP DEPTH= 9296.9. CCL-CUTTER=8.1' LAY DOWN FOR THE EVENING ***JOB CONTINUES ON 10-MAY-24 WSR*** 5/10/2024 ***JOB CONTINUES FROM 09-MAY-24 WSRL*** (TUBING CUT) RU AKEL PRESSURE TEST PCE 250LP 3000HP RIH WITH 1.50" RCT CUT 2 3/8 PIPE @ 9000' (CCL STOP DEPTH=8991.9) (CCL-CUTTER=8.1') RDMO AKEL ***WELL SHUT IN ON DEPARTURE, READY FOR COIL*** 5/22/2024 LRS CTU #1, 1.5" Blue Coil, Job Objective: Fish liner ( 2 sections) MIRU. Function test BOPs. Make up Baker Fishing BHA w/ 4" GS. L&K well w/ 220bbls 1% KCL while RIH. Reduce to min rate once loaded and continue RIH. Tag sleeve @ 8532' CTM and stack down 4k. PUH and ~1.5k heavier. RIH and stack down again. PUH weight the same. POOH. Flowcheck well. No flow. Unable to get fluid level to surface @ 2.6 bpm. Stat continuous hole fill @ .5 bpm on trip sheet. PJSM. Well control drill. Unload and spot crane. Flow check and break off lubricator. Lay down deployment sleeve and 468' of 2-3/8" 6.4# STL liner (14 Jts and a 26.9' cut joint). ***Cont on 5/23/24*** 5/23/2024 LRS CTU 1 1.5" Blue Coil Job Scope: Fish Liner (2 sections) Pre CTD Maintain .5 bpm hole fill w/ 1% KCL. MU and RIH w/ 2-1/8 Baker BHA w/ Hyd releasable spear OAL 25.9'.Up/Dn Wts 17.1/ 7K. Tag @ 9008'. Stack 3K down. Latched up. PU to 5K over. Stack 4K down. Pulled free @ 6K over. Broke back to ~2.5k over. POH. Increase fill rate to .7 bpm to allow for pipe displacement. OOH flow check - no flow. Break lubricator and lay down 305' liner. MU BOT MHA and NS 2.72" whip stock drift. Freeze protect the well 38 bbls diesel. RIH. Drift to 9265 CTMD. Jetted down to 9292 CTMD. Drifted clean post jetting to 9292. POOH RDMO. ***Job complete*** Daily Report of Well Operations PBU 18-13C 5/25/2024 ***WELL S/I ON ARRIVAL*** R/U POL 61 DRIFT 13' x 2.75'' DMY WHIPSTOCK (cont on next day) ***WSR CONT ON 5-26-24*** 5/26/2024 ***WSR CONT FROM 5-25-24*** DRIFTED 3-1/2'' BAIT SUB 13' x 2.72'' DMY WHIPSTOCK, S/D HIGH @ 9208' SLM, WORKED DOWN TO 9292' SLM RAN 3-1/2'' BLB, 2.74'' G-RING, BRUSH FROM 9208'SLM TO TUBING STUB @ 9295'SLM, MAKE MULTIPLE PASSES RAN 2.72'' WHIPSTOCK DRIFT 2 MORE TIMES w/SAME RESULTS RAN 2.75'' CENT, 3'x1-1/2'', 2.74'' G-RING TO S/D ON XO @ 9142'MD, UNABLE TO WORK PAST RAN KJ, 3'x1-1/2'', 2.74'' G-RING, S/D ON TUBING STUB @ 9295'SLM RAN 20'x1.75'' DD-BAILER TO 9295'SLM(NO ISSUES) RAN HES 24 ARM CALLIPER PERPROGRAM (good data) ***JOB COMPLETE, WELL LEFT S/I*** 6/17/2024 T/I/O=SI/0/50. Pre CDR3.Removed tree cap assembly and evacuated wellbore fluids above SSV. Removed 4" companion blind with chemical injection and installed CDR target 90 and kill line #2. Installed 4 x 7" x-over on swab with 7" tapped blind on top. Torqued flanges to API spec. Pressure tested against top of Swab valve to 500 / 3500 psi for 5 min. Passed. PT kill lin and x-over agaisnt SSV to 500/5000 psi. Passed. ***Job Complete*** Final WHP's SI/0/50. 6/21/2024 *** WELL SI ON ARRIVAL *** T/I/O = 2500/0/0 LOG CONTINUOUS GYRO SURVEY FROM SURFACE TO 9257 FT, TAGGED. POOH, COMPLETE, RDMO. T/I/O = 2500/0/0 *** WELL SI ON DEPARTURE *** 6/22/2024 T/I/O = SI/0/0. Pre CDR3. Removed tree cap assembly and installed 4" slip blind above swab valve flange. Installed 4 x 7" x-over with tapped blind on top. Torqued flanges to API spec. PT on top of 4" slip blind to 500/5000 psi. Passed. PT under slip blind through kill line and swab to 500/5000 psi. Passed. Final WHP's SI/0/0. ***Job Complete*** STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 18-13C JBR 08/15/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:3 Test with 2" X 2-3/8" Multi Joint FP on Valve B5 and B8 HCR on kill and choke Greased and cycled both passed. FP on Audible alarm for flow indicator Canrig was getting fixed passed. 8 Accumulator bottles at 1000 psi precharge Avg. Test Results TEST DATA Rig Rep:Matt TurcotteOperator:Hilcorp North Slope, LLC Operator Rep:Tom Kavanaug/Wade Willia Rig Owner/Rig No.:Nabors CDR3AC PTD#:2101860 DATE:7/4/2024 Type Operation:WRKOV Annular: 250/5000Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopKPS240704074408 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 11.5 MASP: 2460 Sundry No: 324-248 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2"P Annular Preventer 1 7-1/16"P #1 Rams 1 Blind Shears P #2 Rams 1 2"P #3 Rams 1 2-3/8"P #4 Rams 1 2"P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"FP Kill Line Valves 1 2-1/16"P Check Valve 0 NA BOP Misc 2 2" piper valve P System Pressure P2950 Pressure After Closure P2100 200 PSI Attained P22 Full Pressure Attained P62 Blind Switch Covers:PAllStations Bottle precharge P Nitgn Btls# &psi (avg)P4@2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P FPFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P8 #1 Rams P4 #2 Rams P4 #3 Rams P4 #4 Rams P4 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9999 9 9 9 99 9 FP FP FP on Audible alarm for flow indicator FP on Valve B5 and B8 HCR P.I. Supv Comm: Rig Coil Tubing Unit?Yes Rig Contractor Rig Representative Operator Operator Representative Well Permit to Drill #2101860 Sundry Approval #324-248 Operation Inspection Location Working Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure P P Flow Rate Sensor P Operating Pressure P P Mud Gas Separator P Fluid Level/Condition P P Degasser P Pressure Gauges P P Separator Bypass P Sufficient Valves P P Gas Detectors P Regulator Bypass P P Alarms Separate/Distinct P Actuators (4-way valves)P P Choke/Kill Line Connections P Blind Ram Handle Cover P P Reserve Pits NA Control Panel, Driller P P Trip Tank P Control Panel, Remote P P Firewall P P 2 or More Pumps P P Kelly or TD Valves NA Independent Power Supply P P Floor Safety Valves P N2 Backup P P Driller's Console P Condition of Equipment P P Flow Monitor P Flow Rate Indicator FP Pit Level Indicators P Valves P PPE P Gauges P Remote Hydraulic Choke P Well Control Trained P Gas Detection Monitor P FOV Upstream of Chokes P Housekeeping P Hydraulic Control Panel P Targeted Turns P Well Control Plan P Kill Sheet Current NA Bypass Line P FAILURES:1 CORRECT BY: COMMENTS Kam St.John 7/3/2024INSPECT DATE AOGCC INSPECTOR Corrected before departing rig. Nabors CDR3AC Nabors Hilcorp North Slope LLC MISCELLANEOUS Flange/Hub Connections Drilling Spool Outlets Flow Nipple Control Lines RIG FLOOR ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT HCR Valve(s) Manual Valves Annular Preventer Working Pressure, BOP Stack Stack Anchored Choke Line Kill Line Targeted Turns Pipe Rams Blind Rams Matt Turcotte Wade Williams Locking Devices, Rams BOP STACK The audio was not working on flow indicator but CanRig rep fixed it. A fill line has been added to this rig and all looked good on the piping and connection.All else looked really good on the rig. CHOKE MANIFOLD PBU 18-13C MUD SYSTEM PBU 18-13C Pre-Drilling CLOSING UNIT 2024-0703_Rig_Nabors_CDR3AC_PBU_18-13C_ksj rev. 4-19-2023 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12650 None Casing Collapse Conductor 470 Surface 1950 / 2670 Intermediate 4760 Liner 7020 Liner 7500 Liner Liner 11780 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Trevor Hyatt Monty Myers Contact Email: Contact Phone:907-777-8396 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 2460 None 7967 - 8375 PBU 18-13C Prudhoe Bay Prudhoe Bay Oil Pool Drilling Manager trevor.hyatt@hilcorp.com 8742 12605 8747 May 5, 2024 8526 - 126414115 4-1/2" 12.6# 7929 - 8743 4-1/2" Baker S-3 Packer 4-1/2" Baker S-3 Packer 8698 - 9202 Perforation Depth MD (ft): 8805 - 9202 11210 - 12600 504 2-3/8" 8723 - 8747 706 3-1/2" x 3-3/16" 8594 - 9300 8025 - 83164-1/2" 80 20" 13-3/8" 9-5/8" 4446 7"397 9068 MD 1490 8160 3450 / 5380 6870 36 - 4429 35 - 8263 8087 - 8316 36 - 4482 35 - 9103 Length Size Proposed Pools: 36 - 116 36 - 116 13Cr80 / L-80 TVD Burst 33 - 8718 8430 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 028321 210-186 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 50-029-21756-03-00 Hilcorp North Slope, LLC AOGCC USE ONLY 11200 Tubing Grade: Tubing MD (ft): 8548 / 7941 8662 / 8005 Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Set Whipstock, Mill Window Drilling Manager 04/25/24 Monty M Myers By Grace Christianson at 8:06 am, Apr 26, 2024 MGR29APR2024 *Well Completion Report of 3/11/2011 SFD 2460 CDW 04/26/2024 110' *110' * * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) for alternate plug placement with fully cemented liner in upcoming sidetrack. All drilling below confining zones and within the PB oil pool. 10-407 Plug for Redrill DSR-4/29/24SFD 5/16/2024JLC 5/17/2024 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: April 25, 2024 Re:PBU 18-13C Sundry Request Sundry approval is requested to set a whipstock and mill the window in 18-13C, as part of the pre-rig and drilling/completing of the proposed 18-13D CTD lateral. Proposed plan for PBU 18-13D Producer: Prior to drilling activities, prep work will be conducted to set the well up for screening. The LTP will be pulled followed by a cut (e-line) and pull (service coil) on current 2-3/8" liner. Once the 3-1/4" liner is open and clear, the screening will be conducted to drift for whipstock and MIT (caliper if needed). E-line will set a 3-1/4" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See 18-13D PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 3- 1/4" packer whipstock and mill a single string 2.74" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 4 and lands in Zone 1A. The lateral will continue in Zone 1A to TD. The proposed sidetrack will be completed with a 2-3/8 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing Ivishak perforations via the packer whipstock and liner top packer set post rig (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start May 2024): 1. Eline/Coil: Pull LTP, cut 2-3/8 liner, pull liner (see Sundry 324-173) 2. Slickline: Dummy WS drift and Caliper (if needed) a. Drift and Caliper past whipstock setting location 3. Fullbore: MIT-IA to 2,500 psi (minimum) 4. E-line: Set 3-1/4 packer whipstock* a. Top of whipstock at 9,260 MD (top of window at 9,260 MD = pinch point) b. Oriented 0° ROHS (high side) 5. Service Coil: Mill Window (mill with rig if needed) a. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,460 psi IV. Mill 2.74 window plus 10 of rat hole V. Single string window exit out of 3-1/4 liner 6. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: Reference PBU 18-13D PTD submitted in concert with this request for full details. General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,460 psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Production Lateral 4. Run and Cement Liner* 5. Freeze Protect and RDMO 6. Set LTP* and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) PTD Sundry 324-428 , p y p p g ( p This completion will completely isolate and abandon the parent Ivishak perfs. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coils departure. Additionally, all BHAs will be lubricated and there is no plan to open hole a BHA. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Hole Size: The window and 10 of formation will be milled/drilled with a 2.74 OD mill. Well Control: BOP diagram is attached. AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. 20 AAC 25.036 (c)(4)(C) requires that a BOPE assembly must include a firewall to shield accumulators and primary controls. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: DS 18 is an H2S pad. Max H2S reading is on 18-01A: 450 ppm in 2013. Last H2S recorded on 18-13: 16 ppm in 2019. Reservoir Pressure: The estimated reservoir pressure is expected to be 3,340 psi at 8,800 TVD. (7.3 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 psi (from estimated reservoir pressure). Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 )( )( ) q A variance is requested Coiled Tubing BOPs 12,278' Packer Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer PBU 18-13C 324-248 SFD 4/29/2024 SFD 4/29/2024 210-186 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 18-13C Pull CTD Liner Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 210-186 50-029-21756-03-00 ADL 0028321 12650 Surface Intermediate Tie Back Liner Liner 8742 4445 9068 397 700 4109 12605 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 8747 36 - 4481 35 - 9103 8805 - 9202 8600 - 9300 8532 - 12641 36 - 4428 35 - 8263 8087 - 8316 7970 - 8375 7935 - 8743 2670 4760 7020 11780 5380 6870 8160 11200 11210 - 12600 4-1/2" 12.6# 13CR-80 25 - 87188723 - 8747 Conductor 80 20" 36 - 116 36 - 116 1490 470 4-1/2" Baker S-3 No SSSV 8548 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 440-0331 PRUDHOE BAY 4/5/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov / 7941 By Grace Christianson at 8:14 am, Mar 21, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.20 15:17:03 - 08'00' Bo York (1248) DSR-3/21/24 10-404 A.Dewhurst 22MAR24 * Note that a 10-403 will be required for abandonment before sidetracking a new well. MGR25MAR24JLC 3/26/2024 Liner Pull Procedure 18-13C PTD: 210186 Well Name:18-13C pull liner pre CTD API Number:50-029-21756-03 Current Status:Offline Uncompetitive Rig:CTU Estimated Start Date:4/5/24 Estimated Duration:2days Regulatory Contact:Carrie Janowski Permit to Drill Number:210-186 First Call Engineer:David Bjork (907) 440-0331 (c) Second Call Engineer: AFE Number:241-00052 Cost / IOR Current Bottom Hole Pressure:3,330 psi @ 8,800 TVD 7.3 PPGE Max. Anticipated Surface Pressure:2,450psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 2,420psi (4/12/2020) Min ID:1.85 ID liner top @ 8,532MD Max Angle:96 Deg @ 12,650 Brief Well Summary: 2011 CTD sidetracked into Z1A, currently shut in due to uncompetitive GOR. Objective: The objective of this procedure is to pull the existing CTD liner from cased hole at 9,300ft. A 2011 SCMT log indicates the top of cement is in open hole at 10,900ft. The wellbore will be sidetracked from the 3-1/4 liner at 9,260ft. Procedure: Slickline-dummy station #1, #2, and #3. Set PX at 8,518ft MIT to 2,500-psi CMIT-IA to 2,500-psi. Pull KB packer from 8,510ft. Drift for cutter to 9,300ft. Eline -Cut 2-3/8" liner at 9,300 and 9,000ft. Coiled Tubing Notes: Due to the necessary open hole undeployment of liner, 24-hour crew and WSS coverage is required. Note: The well will be killed and monitored before making up the patch. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen, it will either be killed by bullheading while POOH or circulating bottoms up. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with liner pulling tool. 3. Bullhead 140 bbls of KWF, 8.4 ppg 1% KCl or 8.5 ppg down the tubing to the formation. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 140 bbls b. 4-1/2 Tubing 8,718 X .0152bpf = 133 bbls c. 3-1/2 Tubing 424 x 0.0087bpf = 4 bbls d. 3-3/16 Liner 164 X .0076bpf = 1.2bbls 4. At surface, prepare for recovery of 2-3/8 4.6# STL liner. Liner Pull Procedure 18-13C PTD: 210186 5. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying patch to ensure the well remains killed and there is no excess flow. 6.Pickup safety joint and TIW valve and space out before MU fishing assembly.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of patch. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 7. RIH and latch upper portion of 2-3/8 liner. Pull to surface. Break lubricator connection at QTS and begin laying down liner per schedule below. Use lift nubbins. Fluids man-watch must be performed while laying down liner to ensure the well remains killed and there is no excess flow. 8. RIH and latch lower portion of 2-3/8 liner. Pull to surface. Break lubricator connection at QTS and begin laying down liner per schedule below. Use lift nubbins. Fluids man-watch must be performed while laying down liner to ensure the well remains killed and there is no excess flow. 18-13C Liner Recovery 9. RDMO CTU. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Sundry Change Form LinerInterval Patch Length Weight of patch (lbs) 8,532ft 9,000ft 9,000ft 9,300ft 468ft 300ft 2152lbs (4.6ppf) 1,380lbs (4.6ppf) Fishing to be performed with PCE. Pump pipe displacement while POOH. Stop at surface to confirm well is dead. Kill well if necessary. Review well control steps before laying down liner. - mgr Liner Pull Procedure 18-13C PTD: 210186 Current Wellbore Schematic Liner Pull Procedure 18-13C PTD: 210186 Proposed Schematic Liner Pull Procedure 18-13C PTD: 210186 Coiled Tubing BOPs Liner Pull Procedure 18-13C PTD: 210186 Standing Orders for Open Hole Well Control during Perf Gun Deployment (Utilize same methodology and percautions for extended patch) Liner Pull Procedure 18-13C PTD: 210186 Equipment Layout Diagram Liner Pull Procedure 18-13C PTD: 210186 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 0 ,C U d C N U N m o E .c 0 1E0)O JJNNC o N ' N Na, IS ON 03 m o I (p m UQ UQ 0 C aO)CC a) J n iU> U> oC� a a Z nJ -J OC 2 CL of > lL omU Iii m m C7 Do m Cha o o Ew = O . Ea E o) Uce r a m o m m m N 5 d UU IX UJJ o0 c a a a s O O a iv) m(9 o 0 0 mL1-1oS Z °0)O )z Ea) aE 2I N E a aN N (00 a ' N > > a) EOE ca aH H >-. m E •F- J� QU a) =w E g:. E m uU a) 00 0 c . 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Address SUITE 100 ANCHORAGE,AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Page 1 of 1 411 co -uWV - - DDN O m -o r 1 ' `t a m 3 m D z = a a i7 mN y o O m d m c m am 3 p > m. °ra msgm 2m 14) > = m5 Illr — X zmbA ° ° nTc .rEire ' r °Dr * . xy �W _ biOIi aZ . � NWayNowy WiNA �Wlde = to q m a t o CD. d H 0 7 r _ w 0 o w x e -icp m °w° gm I- ,XI CD co I XI In m ca � � xavoa�n°r° �zv-z � f �vz � � F V 1 C e_ 0 0 0 3 M A A O« A c_ c_ m -ICO 664566 bbbbb$b0l$ gbl� bb o` m -< ba�,tc)-p, cop��000g-. 00g A++oo � -. 14, a O A -h NOIN+ NW W NOD WoNOUTAO z z . . . . . . r r r r r r r r r r r r r r O mocc000DODDDpc000000 z 1,0000000000000000000 0 mmmmmmmmmmmmmmmmmmm M > 0000000000000000000 m -1 -) -11111111 -1 -1 -1 -i -1-1 -i11 -i c m0000000000000000000 M m m m m m m m m 71 71 71 71 71 71 71'71 71 71 71 m zo N N N N N N n N N N N N N v N N n N O mz111111z111111n11z1 0 mr r r r z N ,g m O m m -C c > < o c) m 7 I -t 1 0 NN + N Ni O V NNAN OE O 02 N N N p CO Ol OE Op bLLi.biOLLLLDLLDL,TDL � L 0 oeecamecccecceEy.0mmc o; 1" 7 7 t0 +'7 -7 10 7 7 m 7 17 g m . . . . - + - + - i co r D N D 0 sD o l\> cn 0 3 i o0o o = <c m 0 'c P ert= d Dco � ' > > C 0 - = a » fn n 0 0. < , m cc N j 0 $ p m o CT N m la =0 D 0- C CA 52 -40) * .-. 900 m N C 3 7 W N X a m y W C° •D• mm Nm 1 p 2 m m m o O - 1 -h'i C ) 0 3 03 0 0 N0 141 6' bp Date 05-12-2011 Transmittal Number:93192 iti, BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data& Electronic Log Prints for the following wells: 15-11CPB1 al 0-143 IAgKCom 18-13C a io-1$cv /4 A-39A c).10- !'$S 1 a-t logb F-28B lao-/6 /`{Coal s-oic a.10- ,-14 i'-11-^3:-'S-18B 'Q 10-Dad i L/tr'3 0 S-129 -129PB1 S-129P62\_, QJ0--(33 /-/( 3a s i i Ple a and Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center '-, ', ' S ''',_11 i�a I = d Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd.PO Box 196612 Anchorage,AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 ® Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 2/13/2011 210-186 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 1/30/2011 50-02921756-03-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: I Surface: 2/6/2011 PBU 18-13C 1045'FNL,371'FWL,SEC. 19,711N, R15E, UM 8. KB(ft above MSL): 54.80' 15.Field/Pool(s): Top of Productive Horizon: 2578'FNL,3313'FWL,SEC. 19,T11 N, R15E,UM GL(ft above MSL): Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 2822'FNL, 514'FWL, SEC.20,T11 N, R15E, UM 12605' 8747' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 692133 y- 5960832 Zone- ASP4 12650' 8742' ADL 028321 TPI: x- 695113 y- 5959377 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 6972.81 Y- 5959188 Zone- ASP4 None 18.Directional Survey: ®Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD DIR, GR, RES, GR/CCL/MCNL 9301' 8375' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED See Attached 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes,list each interval open .SIZE DEPTHSET(MD) PACKER SET(MD/ (MD+TVD of Top&Bottom;Perforation Size and Number): TVD) 1.56"Gun Diameter,6 spf 4-1/2", 12.6#,L-80 8718' 8548'/7941' MD TVD MD TVD 8662'/8005' 11210'-11530' 8723'-8734' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 11590'-11650' 8735'-8734',/ 11710'-11880' 8734'-8736' t.3:1,,1,tP_.,Ctil DEPTH INTERVAL(MD)I AMOUNT AND KIND OF MATERIAL USED 11960'-12330' 8738'-8752' ► t 2500' _Freeze Protected w/38 Bbls of 60/40 McOH 12450'-12600' 8753'-8747' fi 12 IA 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): March 7,2011 Flowing Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 3/10/2011 8 Test Period 4 314 8,011 2 128 25,498 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. Not Avail. Not Avail. 24-Hour Rate 4 943 24,034 7 Not Available 28. CORE DATA Conventional Core(s)Acquired? 0 Yes IN No Sidewall Core(s)Acquired? 0 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 MC 250.071. None RECEIVED RBDMS MAR 2'1 Bill a MAR I 1 ZU1 Form 10-407 Revised 12/2009 A3.--i,CONTINUED ON REV SESIt Original Only.74., , Oil&Gas Cons.CORU111iS ' G Anr",„ 29. GEOLOGIC MARKERS(List all formations a,._.narkers encountered): 30. FORMATION TESTS NAME MD ND Well Tested? 0 Yes 0 No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Top CGL/Zone 3 9383' 8433' None Base CGL/Zone 2C 9452' 8486' 23SB/Zone 2B 9530' 8546' 22TS 9569' 8573' 21TS/Zone 2A 9650' 8626' Zone 1B 9767' 8685' TDF/Zone 1A 10237' 8718' Formation at Total Depth(Name): TDF/Zone 1A 10237' 8718' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Terrie Hubble / to k� l;��9 Title: Drilling Technologist Date: (13//0(//It j// PBU 18-13C 210-186 Prepared By Name/Number Terrie Hubble, 564-4628 Well Number Permit No./Approval No. Drilling Engineer: Matthew Ross,564-4387 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 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Altemating-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 elevation 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 ND 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 12/2009 Submit Original Only C WELL NAME: 18-13C 23. Attachment-Casing, Liner and Cementing Record Casing Setting Depth MD Setting Depth TVD Hole Size Wt. Per Ft. Grade Top Bottom Top Bottom • Size Cementing Record 20" 91.5# H-40 Surface 110' Surface 110' 30" 1694#Poleset 13-3/8" 72#/68# K-55/L-80 Surface 4482' Surface 4482' 17-1/2" 3500 sx CS III,600 sx'G',Top Job: 100 sx CS II 9-5/8" 47# L-80 Surface 9103' Surface 8263' 12-1/4" 930 sx Class'G' 7" 29# L-80 8805' 9202' 8087' 8316' 8-1/2" 500 sx Class'G' 4-1/2" 12.6# L-80 8698' 9202' 8025' 8316' 6" 523 sx Class'G' 3-1/2"x 3-3/16" 881#,/6.2# L-80 8594' 9301' 7968' 8375' 4-1/8" 141 sx Class'G' 2-3/8" 4.7# L-80 8540' 12641' 7937' 8743' 3" 78 sx Class'G' 18-13C, Operations Summary From To Operation Summary 1/27/11 12:00 AM 1/27/11 8:00 AM WARM UP MOVING SYSTEM AND PREPARE TO MOVE RIG OVER 18-13C WHEN WELL PREP IS COMPLETED. 1/27/11 8:00 AM 1/27/11 10:00 AM MOVE RIG ONTO 18-13C. POSITION RIG OVER WELL. RIG ACCEPT AT 1000 HRS. 1/27/11 10:00 AM 1/27/11 3:30 PM PREPARE RIG FOR OPERATIONS. STAGE EQUIPMENT, CONNECT LINES. LOCK OUT TAG OUT WELL 18-15 BY DRILL SITE OPERATOR AND NORDIC 1 WSL. NU BOP. 1/27/11 3:30 PM 1/27/11 4:30 PM CONDUCT PRE-SPUD MEETING WITH DAY CREW 1/27/11 4:30 PM 1/27/11 5:15 PM CONDUCT RIG EVACUATION DRILL AND CONDUCT AAR AFTERWARDS 1/27/11 5:15 PM 1/27/11 6:00 PM CLEAR RIG FLOOR, MOBILIZE BOP TEST EQUIPMENT TO FLOOR 1/27/11 6:00 PM 1/27/11 7:00 PM MU BOP TEST EQUIPMENT. BODY TEST STACK TO LOOK FOR LEAKS. 1/27/11 7:00 PM 1/27/11 7:30 PM PRE-SPUD WITH NIGHT CREW WHILE WAITING ON AOGCC REP 1/27/11 7:30 PM 1/28/11 12:00 AM BOP TEST WITH 2" AND 2 3/8" TEST JOINTS TO 250 PSI LOW AND 3500 PSI HIGH. AOGCC REP JOHN CRISP ON SITE TO WITNESS TEST. WSL ROB O'NEAL AND TOURPUSHER TOM KILFOYLE WITNESSED TEST. TIGER TANK STAGED, HARD LINE RIGGED UP AND TESTED TO 4000 PSI. 1/28/11 12:00 AM 1/28/11 5:30 AM BOP TEST WITH 2"AND 2 3/8"TEST JOINTS TO 250 PSI LOW AND 3500 PSI HIGH. AOGCC REP JOHN CRISP ON SITE TO WITNESS TEST. WSL ROB O'NEAL AND TOOLPUSHER TOM KILFOYLE WITHNESSED TEST. 1/28/11 5:30 AM 1/28/11 6:00 AM CONDUCT RIG EVACUATION DRILL-ALL HANDS ACCOUNTED FOR AT SATELITE CAMP INCLUDING TRUCK DRIVER. -CONDUCT AAR: NOTE AREAS OF IMPROVMENT. - DRILL WAS CONDUCTED AT CREW CHANGE, COULD DO BETTER JOB OF INFORMING INCOMING CREWS. - RESPONSE TIME WAS GOOD. 1/28/11 6:00 AM 1/28/11 9:45 AM NORDIC ELECTRICIAN CALIBRATES GAS ALARMS. SLB HOLDS PJSM FOR SLACK MANAGEMENT. REVIEW SLACK MANAGEMENT PRE-LOADED IN REEL-2.7%. CALL SLB CELL LEADER, THIS IS SUFFICIENT SLACK. 1/28/11 9:45 AM 1/28/11 10:30 AM CUT CIL BACK. HEAD UP BHA. TEST ELINE 54 OHMS. 1/28/11 10:30 AM 1/28/11 11:00 AM PULL TEST TO 25K LB. GOOD. MU BAKER UQC (NO CHECKS). 1/28/11 11:00 AM 1/28/11 11:45 AM FILL CT W/ KCL. 1/28/11 11:45 AM 1/28/11 12:00 PM PT CTC AND INNER REEL IRON TO 200 PSI LOW/4000 PSI HIGH. GOOD. 1/28/11 12:00 PM 1/28/11 1:00 PM MU TO WELL. TEST INNER REEL VALVE AND PACKOFF TO 200 PSI //3500 PSI, GOOD. PUMP SLACK FORWARD. UNSTAB. FIND -8" PIECE OF 5/16" ELINE INUQC BODY. INFORM ODE. 1/28/11 1:00 PM 1/28/11 1:30 PM INSTALL BAKER CHECKS IN UQC AND TEST, GOOD. 1/28/11 1:30 PM 1/28/11 3:30 PM PU AND RU VALVE SHOP LUBRICATOR. 1/28/11 3:30 PM 1/28/11 4:00 PM PJSM FOR PULLING TWC W/ PRESSURE BENEATH. Page 1 of 9 18-13C, Operations Summary From To Operation Summary 1/28/11 4:00 PM 1/28/11 5:00 PM PULL TWC. SIWHP 1350 PSI. ISOLATE WELL W/ MASTER SSV. LD VALVE SHOP LUBRICATOR. 1/28/11 5:00 PM 1/28/11 6:00 PM STAB ON NOZZLE. PRESSURE TEST LUBRICATOR AGAINST SWAB VALVE. LIQUID PACK STACK AND TIGER TANK HARD LINE WITH NEAT METHANE. PUMP 25 BBLS NEAT METHANE INTO COIL, FOLLOW IWTH 2% KCL TO PLACE METHANE AT NOZZLE. 1/28/11 6:00 PM 1/28/11 6:45 PM PJSM ON RIH, DISPLACING FLUID, HANGING RETURNS. STAGE PERSONNEL, MAKE CHECKS ON BOP, TREE AND HARDLINE TO TIGER TANK. 1/28/11 6:45 PM 1/28/11 7:30 PM MAINTAIN 1350 PSI ON BOP STACK AGAINST CHOKE. OPEN WELL. NO ISSUES. 1350 PSI FROM WELL. RIH WITH NOZZLE ASSEMBLY AGAINST CLOSED CHOKE. 1/28/11 7:30 PM 1/28/11 9:15 PM RIH WITH NOZZLE ASSEMBLY PUMPING AT .2 BPM, MAINTAIN CLOSED CHOKE. SLOW PUMP RATE TO .1 BPM DUE TO NO PRESSURE BUILDUP; WANT TO ENSURE METHANE WILL BE IN NOZZLE AT WHIPSTOCK. -WHP INCREASE AT 2000'. CONTINUE TO HOLD CHOKE UNTIL WHIP REACHES 1540 PSI. MONITOR AND ADJUST CHOKE TO MAINTAIN APPROXIMATELY 1500-1560 PSI WHILE RUNNING IN HOLE AT 80-90 FPM, .1 BPM. -INCREASE IN RATE TO .25 BPM, MAINTAIN 1510-1560 PSI WHILE RIH AT 90 FPM. -DECREASE RIH RATE AT 9200'. TAG AT 9303'. PU, RE-TAG AT 9303'. -WEIGHT CHECKS GOOD THROUGHOUT RIH. -SIWHP AT TAG 1590 PSI -SET DOWN 2000LBS ON WHIPSTOCK, NO MOVEMENT. 1/28/11 9:15 PM 1/28/11 10:40 PM BEGIN DISPLACMENT WITH 8.4 PPG 2% KCL AT 2 BPM, 2720 PSI CIRC PRESSURE, 1570 SIWHP. MAINTAIN PUMP AND PRESSURE SCHEDULE ACCORDING TO PLAN ADDENDUM. - 5 BBLS AWAY, 1490 PSI SIWHP -15 BBLS AWAY, 1400 PSI - 25 BBLS AWAY, 1250 PSI -30 BBLS AWAY, 1170 PSI -40 BBLS AWAY, 1050 PSI -45 BBLS AWAY, 1000 PSI -55 BLLS AWAY, 910 PSI -60 BBLS AWAY, 860 PSI -70 BBLS AWAY, 700 PSI - 75 BBLS AWAY, 650 PSI -85 BBLS AWAY, 570 PSI -90 BBLS AWAY, 490 PSI -100 BBLS AWAY, 400 PSI -110 BBLS AWAY, 300 PSI -120 BBLS AWAY, 150 PSI FINAL CIRCULATING PRESSURE AT 2 BPM AT 2470 PSI WITH 150 PSI WHP. CONTINUE DISPLACING WELL WITH 2% KCL TO CLEAN UP RESIDUE, ENSURE ALL KCL ALL THE WAY AROUND. 1/28/11 10:40 PM 1/29/11 12:00 AM FLOW CHECK WELL. STATIC. SWITCH TO 8.6 PPG MUD AND DISPLACE AT IN AND OUR RATES OF 2 BPM, ICP 3440 PSI, MW IN 8.6 PPG, MW OUT 8.4 PPG. -MUD ALL THE WAY AROUND. FCP AT 3830 PSI, MW IN AND OUT 8.6 PPG. IN AND OUT RATES 2 BPM. BEGIN FOLW CHECK ON WELL. 1/29/11 12:00 AM 1/29/11 1:15 AM FLOW CHECK WELL. STATIC. JOLE FULL AFTER FLOW CHECK. COMPLETE TAKING ON 8.6 PPG MUD INTO PITS WHIL PECIPROCATING. Page 2 of 9 18-13C, Operations Summary From To Operation Summary 1/29/11 1:15 AM 1/29/11 3:00 AM POH WITH NOZZLE BHA. NO P ROBLEMS WITH DISPLACEMENTS. CONDUCT AAR ON DISPLACEMENT WHILE POH. PJSM ON LD NOZZLE BHA, MU MILLING BHA. 1/29/11 3:00 AM 1/29/11 4:30 AM LD NOZZLE BHA. MU 2.74" MILLING BHA. DID NOT RUN CENTRALIZER ON BHA. VERIFY SECURITY, RE-ALIGN STRAPS SECURING HEARD LINE IN REEL HOUSE. 1/29/11 4:30 AM 1/29/11 7:30 AM RIG W/WINDOW MILLING ASSEMBLY. 80 FT/MIN. 1/29/11 7:30 AM 1/29/11 8:15 AM LOG TIE-IN. CORRECTION OF (+5.5'). DRY TAG WHIPSTOCK AT 9300' MD. STACK 2K LB ON WS, NO MOVEMENT. PU CLEAN UP 9298' MD AT 24K LB. PAINT WHITE FLAG AT 9288' MD (CTDS DEPTH, END OF BIT) 1/29/11 8:15 AM 1/29/11 11:30 AM FREESPIN 1.55BPM AT 3575 PSI W/ FULL RETURNS. ENGAGE AT 9301' MD. 200 PSI MOTOR WORK, 200 LB DHWOB. AFTER -2 MINUTES, SEE SUDDEN LOSSES (0.25 BPM LOSSES AT 1.55 BPM PUMP RATE). NO CHANGE IN MOTOR WORK OR DHWOB W/ LOSSES. LOSSES SLOWLY HEAL AFTER - 10 MINUTES, -2BBLS TOTAL LOST. CALL SLOPE SUPT - PICK UP OFF WHIPSTOCK AND RETAG TO CONFIRM THAT IT HAS NOT STARTED TO MOVE WITH THE TORQUE WE APPLIED WHEN ENGAGING CASING W/ MILL. TAG WHIPSTOCK W/3200 LB DHWOB. NO MOVEMENT. RESUME MILLING OPERATIONS FROM 9301' MD. TIME MILLING AHEAD AT 3780 PSI AT 1.57 BPM (FREESPIN 3580 PSI) W/ FULL RETURNS. BHWOB - 1600 LB. BHP/PVT/ECD:4128 PSI / 334BBL/8.63 PPG. IAP: 400 PSI. OAP: 0 PSI. MM (4AIN DENSITY IS 8.6 PPG - ECD SEEMS LOW. FIND THAT BAKER DOES NOT HAVE ACCURATE SURVEY DATA INPUT INTO THEIR ALOGRITHM. HAVE BAKER FIX PROBLEM. ECD = 9.6PPG. 1/29/11 11:30 AM 1/29/11 2:00 PM TIME MILL AHEAD AT 9303.5' MD AT 1.55 BPM AT 3590 PSI W/ FULL RETURNS. 1K LB DHWOB. BHP/ECD/PVT: 4120PSI / 9.6 PPG /331 BBL. �;�' 1/29/11 2:00 PM 1/29/11 5:00 PM TIME MILL AHEAD AT 9306' MD AT 1.51 BPM AT 3505 PSI W/ (►u"' FULL RETURNS. 700 LB DHWOB. BHP/ECD/PVT: 4118 PSI / P-rD 9.59 PPG/328 BBL. 1/29/11 5:00 PM 1/29/11 6:00 PM MILL RAT HOLE TO 9316'. CATCH SAMPLE, SAND IN SAMPLE. TOW @ 9300.7'. BOW @ 9305.8'/ 1/29/11 6:00 PM 1/29/11 7:30 PM DRESSING WINDOW: REAM UP AND DOWN (3X) @ 1 FPM. CONDUCT DRY RUN. WINDOW IN GOOD SHAPE. 1/29/11 7:30 PM 1/29/11 9:30 PM FLOW CHECK WELL. STATIC. POH WITH MILLING BHA. 1/29/11 9:30 PM 1/29/11 10:00 PM PJSM ON LD MILLING BHA AND MAKING UP DRILLING BHA. 1/29/11 10:00 PM 1/29/11 11:00 PM LD MILLING BHA. MILL IN GAUGE AT 2.74". INSPECT TREE BOLTS, ALL GOOD. PU, MU 2.7"x3" DRILLING BHA WITH RESISTIVITY TOOL. 1/29/11 11:00 PM 1/30/11 12:00 AM RIH WITH DRILLING BHA. 1/30/11 12:00 AM 1/30/11 12:30 AM RIH TO 9040' WITH DRILLING BHA 1/31/11 12:00 AM 1/31/11 2:30 AM RIH WITH 2.73" DRILLING BHA. CONDUCT TIE-IN AT 9226'. - 2' CORRECTION MADE. Page 3 of 9 18-13C, Operations Summary From To Operation Summary 1/31/11 2:30 AM 1/31/11 5:00 AM ORIENT BIT TO 270 DEG. EXIT WINDOW WITH NO PROBLEM. OBTAIN SLOW PUMP RATES FOR KILL SHEET. FREE SPIN 3120 PSI. -TAG TD, BEGIN TO DRILL AHEAD AT 9321.3' MD AT 1.5 BPM AT 3190 PSI (70 PSI MOTOR WORK). - DHWOB 1.75K. BHP/ECD/PVT: 4142 PSI /9.58 PPG / 309 BBL. MAINTAIN TFO AT 270 DEG ORIENTATION. - DRILL AHEAD TO 9336' MD WITH CONSISTENT MOTOR WORK, MW IN 8.5, MW OUT 8.6, 1.5 BPM, 3150-3250 PSI, .7-2.3K WOB - MOTOR WORK PICKED UP AT 9337', WITH PRESSURES PICKING UP FROM 3250 TO 3350-3400 PSI - DRILLED AHEAD WITH NO PROBLEMS TO 9348'; AT 9348' ON BOTTOM PSI ROSE TO 3780 PSI, WOB TO 5.6K, 9.64 ECD. PU AND ATTEMPT TO DRILL AHEAD; GEO SUSPECTS ENTERED INTO CHERT ZONE - DRILL AHEAD TO 9350' - FINAL BHP/ECD/PVT: 4129 PSI /9.61 PPG / 308 BBL, MW IN AND OUT 8.6 PPG 1/31/11 5:00 AM 1/31/11 7:30 AM POH FOR BHA CHANGE. CIRC THROUGH OPEN EDC AS POOH, INCREASING RATE AS PUH TO MAINTAIN CT PRESSURE AT -4000 PSI. PERFORM IN/OUT JOG NEAR SURFACE, NO INCREMENTAL RETURNS OBSERVED. CLOSE EDC. FLOW CHECK- GOOD. 1/31/11 7:30 AM 1/31/11 8:30 AM LD BHA. GRADE BIT 3,2, BROKEN/CRACKED TEETH. INSPECT 50' OF CT FOR CHROME ABRASION, NONE NOTED. MU BUILD BHA W/ 1.2 DEG AKO MOTOR AND NEW T-REX BI-CENTERED BIT. 1/31/11 8:30 AM 1/31/11 10:30 AM RIH CIRCULATING MIN RATE THROUGH BIT, FULL RETURNS. 1/31/11 10:30 AM 1/31/11 11:00 AM LOG TIE-IN, CORRECTION OF (-1'). WEIGHT CHECK, 26K LB. 1/31/11 11:00 AM 1/31/11 3:40 PM BOBD. FREESPIN 1.55 BPM AT 3350 PSI. ROP -30 FPH UNTIL HIT ZONE 3 AT-9385' MD. ROP SLOWS TO -10 - 15 FPH HERE. 12:00 - DRILLING AHEAD AT 9385' MD AT 13 FPH AT 1.52 BPM AT 3450 PSI W/ FULL RETURNS W/ 1K LB DHWOB. BHP/ECD/PVT: 4183 PSI /9.65 PPG/ 306 BBLS. IAP=0 PSI, OAP=110 PSI. 14:15 - DRILLING AHEAD AT 9402' MD AT 10 FPH AT 1.61 BPM AT 3640 PSI W/ FULL RETURNS AND 2K LB DHWOB. BHP/ECD/PVT: 4175 PSI /9.61 PPG / 305 BBL. Page 4 of 9 18-13C, Operations Summary From To Operation Summary 1/31/11 3:40 PM 1/31/11 11:00 PM DRILLING AHEAD AT 9408' MD AT 1.54 BPM AT 3430 PSI W/ FULL RETURNS AND 2300 LB DHWOB. BHP/ECD/PVT: 4165 PSI /9.59 PPG/ 304 BBL. 16:30 - DRILLING AHEAD AT 9412' MD AT 1.54 BPM AT 3470 PSI W/ FULL RETURNS AND 1900 LB DHWOB. BHP/ECD/PVT: 4170 PSI / 9.59 PPG / 304 BBL. SAMPLE FROM 9400' MD - CONGLOMERATE, 70-80% CHERT. - DRILLING AHEAD WITH SLOW ROP DUE TO THE CHERT FROM 9420'-9448' AT 1.5 BPM, 3370-3450 PSI, 9.61- 9.64 ECD, .9-2.3 WOB, 4170-4190 PSI BHP, MW IN 8.58 PPG, MW OUT 8.62 PPG - ROP PICKED UP AT 9448' FROM 10 FPH TO '40 FPH; MOST LIKELY BROKE THROUGH CHERT- BLED OA DOWN FROM 800 PSI TO 0 PSI; 90% FLUID, -4 GAL-298 PVT 1/31/11 11:00 PM 1/31/11 11:25 PM SHORT TRIP TO WINDOW. NO PROBLEMS WITH TRIP. RUN BACK TO BOTTOM. 1/31/11 11:25 PM 2/1/11 12:00 AM DRILLING AHEAD FROM 9500' MD AT 1.53 BPM AT 3630- 3720 PSI W/ FULL RETURNS, 1.4-2.9K DHWOB. - BEGINNING PARAMETERS: FREE SPIN AT 3220 PSI. MW IN 8.58 PPG, MW OUT 8.62 PPG. BHP/ECD/PVT: 4230 PSI /9.65 PPG /297 BBL. - DRILLED TO 9520' 2/1/11 12:00 AM 2/1/11 3:10 AM DRILLING AHEAD FROM 9520' MD AT 1.49-1.57 BPM AT 3666- 3800 PSI W/ FULL RETURNS, 1.4-2.89K DHWOB. - BEGINNING PARAMETERS: FREE SPIN AT 32400 PSI. MW IN 8.6 PPG, MW OUT 8.62 PPG. BHP/ECD/PVT: 4250 PSI / 9.66 PPG/298 BBL - FORMATION SEEMS TO HAVE CLEANED UP; LESS VIBRATION AT BIT, MUCH CLEANER SURVEYS 2/1/11 3:10 AM 2/1/11 3:35 AM SHORT TRIP TO CLEAN HOLE, POOH @ 25 FPM PUMPING 1.5 BPM @ 3325 CIRC PRESSURE. FULL RETURNS. - ST TO BOTTOM OF WINDOW, RBIH @ 30 FPM. 2/1/11 3:35 AM 2/1/11 7:20 AM BACK TO DRILLING BUILD. - 3325 PSI FREESPIN, DRILLING W/ 300 - 350 PSI MOTOR WORK. -AVERAGE ROP, 40 -45 FPH, TF 45 -60L. LOSING MAYBE 1 BPH. DRILL AHEAD TO 9800' MD. WIPER TO WINDOW. 2/1/11 7:20 AM 2/1/11 8:30 AM WIPER TO WINDOW (CLEAN). CORRECTION OF (+1'). RBIH CLEANLY TO BOTTOM. 2/1/11 8:30 AM 2/1/11 12:30 PM FREESPIN 1.5 BPM AT 3380 PSI. BOBD. 09:00 - DRILL AHEAD AT 1.51 BPM AT 3590 PSI W/ FULL RETURNS ON OUT MM AND 2200 LB DHWOB. BHP/ECD/PVT: 4366 PSI / 9.74 PPG/277 BBL. ROP -35 FPH. IAP: 375 PSI. OAP: 260 PSI. ROP PICKED UP TO -80 FPH, SAMPLES SHOW VERY LITTLE CHERT. 2/1/11 12:30 PM 2/1/11 3:00 PM REACH TD OF BUILD SECTION. POH FOR BHA CHANGE. SLOW FLOW AND PULLING SPEED THROUGH WINDOW. OPEN EDC ABOVE LINER TOP AT 9140', POH AT 2.2 BPM, 3880 PSI. 2/1/11 3:00 PM 2/1/11 3:15 PM LD BHA. BIT GRADE: 2/1/11 3:15 PM 2/1/11 4:45 PM CONDUCT CHROME MANAGEMENT ON COIL. CUT 50' OF COIL. REHEAD, PULL TEST TO 30K, OK. 2/1/11 4:45 PM 2/1/11 6:00 PM REHEAD CTK, PRESSURE TEST CTK, CHARTED. Page 5 of 9 18-13C, Operations Summary From To Operation Summary 2/1/11 6:00 PM 2/1/11 6:45 PM PJSM. PICK UP LATERAL SECTION BHA. 2/1/11 6:45 PM 2/1/11 8:30 PM RIH W/ LATERAL BHA ON 2" COIL © 80 FPM. 2/1/11 8:30 PM 2/1/11 9:30 PM LOG F/9280' -9365' @ 250 FT/HR. -1' CORRECTION. 2/1/11 9:30 PM 2/1/11 10:00 PM RUN TO BOTTOM AND COMMENCE DRILLING LATERAL SECTION. - DRILL F/ 9950', 3350 PSI FREESPIN @ 1.5 BPM, 200 - 300 PSI MOTOR WORK. - TF 85L, 1K WOB, AVG ROP = 120 FPH. -TEMPORARY PARTIAL LOSS OF RETURNS @ 9979'/ IN RATE 1,5BPM, OUT RATE 1.2 BPM. - FULL RETURNS BACK BY 9985', TOTAL FLUID LOST 3 - 5 BBLS. 2/1/11 10:00 PM 2/1/11 11:00 PM CONTINUE TO DRILL AHEAD,TF 90 - 95L. - ROP 110-125 FPH. LOSS RATE 5 BPH. 2/1/11 11:00 PM 2/1/11 11:15 PM WT TRANSFER/ SHORT TRIP TO 9900'. 2/1/11 11:15 PM 2/2/11 12:00 AM DRILL AHEAD F/ 10038' TO 10,075' AT 1.47 BPM, 3520-3600 PSI, 4425 PSI BHP, MW IN 8.63, MW OUT 8.67, 9.84 PPG ECD, 1.2-2.1K WOB, 248 PVT-AVG -4BPH LOSSES 2/2/11 12:00 AM 2/2/11 12:25 AM DRILL AHEAD F/ 10,075' TO 10,100' AT 1.47 BPM, 3520-3600 PSI, 4425 PSI BHP, MW IN 8.63, MW OUT 8.67, 9.84 PPG ECD, 1.2-2.1K WOB, 247 PVT 2/2/11 12:25 AM 2/2/11 1:30 AM SHORT TRIP FROM 10,100' TO WINDOW. NO ISSUES. RUN BACK TO BOTTOM. PVT 243, LOST 4 BBLS ON SHORT TRIP. -TRUCKS FOR MUD SWAP ON LOCATION AND RU 2/2/11 1:30 AM 2/2/11 3:30 AM FREE SPIN AT 3500 PSI. CONTINUE TO DRILL AHEAD F/ 10,100' TO 10,250' AT 1.50-1.52 BPM, FULL RETURNS, 3580- 3680 PSI, 4433-4462 PSI BHP, MW IN 8.64, MW OUT 8.69, 9.85 9.91 PPG ECD, 1.0-1.5K WOB, 235 PVT-AVERAGING 4 BPH LOSSES -CROSSED ANTICIPATED FAULT AT 10,232' WITH NO ISSUES 2/2/11 3:30 AM 2/2/11 4:30 AM WIPER TRIP TO WINDOW FROM 10,250'. NO ISSUES. RUN BACK TO BOTTOM WITH NO PROBLEMS. - 3 BBL LOSS ON TRIP 2/2/11 4:30 AM 2/2/11 6:00 AM FREE SPIN AT 3450 PSI. CONTINUE TO DRILL AHEAD F/ 10,250' TO 10,300'AT 1.49-1.52 BPM, FULL RETURNS, 3570- 3850 PSI, 4470-4480 PSI BHP, MW IN 8.64, MW OUT 8.68, 9.94 PPG ECD, 1.6-2.5K WOB, 230 PVT-AVERAGING 3-4 BPH LOSSES SLOW PUMP RATE = 0.75 BPM AT 2280 PSI; 1.5 BPM AT 3585 PSI. 2/2/11 6:00 AM 2/2/11 8:25 AM WIPER TRIP TO WINDOW FROM 10400'. LOG TIE-IN +3' CORRECTION. 2/2/11 8:25 AM 2/2/11 9:50 AM DRILL AHEAD FROM 10400' 2/2/11 9:50 AM 2/2/11 11:15 AM WIPER TRIP FROM 10550' 2/2/11 11:15 AM 2/2/11 1:10 PM DRILL AHEAD FROM 10550'. 1.53/1.53 BPM - 3900 PSI 8.72/8.71 PPG ECD = 10.03 PPG PREP TO BEGIN MUD SWAP. FINISH MUD SWAP 2/2/11 1:10 PM 2/2/11 3:00 PM WIPER TRIP TO WINDOW FROM 10700' Page 6 of 9 18-13C, Operations Summary From To Operation Summary 2/2/11 3:00 PM 2/2/11 5:20 PM ESTABLISH NEW SLOW PUMP RATES AFTER MUD SWAP. 0.75 BPM © 2400 PSI AND 1.5 BPM © 3700 PSI. DRILL AHEAD FROM 10700' DRILL TO 10726'AND ENCOUNTER LOSSES .25 BPM. LOSSES SLOWING BY 10734' DRILL AT 1.54 BPM AND 3995 PSI. PVT = 337 BBLS, ECD = 9.95 PPB 2/2/11 5:20 PM 2/2/11 7:15 PM WIPER TRIP TO WINDOW FROM 10850'. CONTINUE WITH WIPER TO TOP OF LINER AT 9140'. OPEN EDC, INCREASE FLOW TO CLEAN ABOVE LINER TOP. MAKE TWO PASSES. TAKE MANUAL STRAP, 321 BBLS. 2/2/11 7:15 PM 2/2/11 8:30 PM CLOSE EDC, RUN BACK IN HOLE. CONDUCT TIE-IN AT 9320'; + 4-1/2' CORRECTION. CONTINUE RIH. 11 BBL LOSS DURING WIPER TRIP. TAKE MANUAL STRAP TO CONFIRM. - ENCOUNTER SHALES FROM 10,770-10,805 MD. WIPE THROUGH SEVERAL TIMES 2/2/11 8:30 PM 2/2/11 10:15 PM FREE SPIN 3730 PSI AT 1.49 BPM. DRILL AHEAD FROM 10,850' to 11,000'. BEGIN PVT 325 BBBLS. - 1.53/1.57 BPM, 3900-4030 PSI, MW IN 8.55, MW OUT 8.56 PPG, ECD 10.03- 10.17 PPG, 1.2-1.4K WOB, FULL RETURNS (.01 TO .02 BPM LOSSES AT TIMES) - END PVT 316 2/2/11 10:15 PM 2/3/11 12:00 AM WIPER TRIP TO WINDOW. DURING WIPER, TOWN GEO HAS REQUESTED -5' DROP IN TVD TARGET. INCREASE IN DRAG AT SAME 10,770-10,800' INTERVAL ON TRIP UP. TIGHT HOLE AT 10,250' ON TRIP BACK IN. 2/3/11 12:00 AM 2/3/11 12:30 AM RIH AFTER WIPER TRIP TO WINDOW. DURING WIPER, TOWN GEO HAS REQUESTED -5' DROP IN TVD TARGET. TIGHT HOLE AT 10,250'AND 10,770-10,805' ON TRIP BACK IN. PVT AFTER TRIP 305 BBLS; 11 BBL LOSS ON TRIP 2/3/11 12:30 AM 2/3/11 3:30 AM FREE SPIN 3780 PSI AT 1.47 BPM. DRILL AHEAD FROM 11,000' to 11,150'. BEGIN PVT 305 BBBLS - 1.44/1.57 BPM, 3900-4230 PSI, MW IN 8.57, MW OUT 8.58 PPG, ECD 10.15- 10.35 PPG, .7-3.0K WOB, FULL RETURNS - DROPPED DOWN 2' TVD, ENTERED INTO SHALE ZONE FROM 10,980'-11,030'. GEO REQUESTS TO MOVE BACK UP -2' TVD. CAME OUT OF SHALES. - END PVT 293; AVG LOSSES 4 BPH WHILE DRILLING 2/3/11 3:30 AM 2/3/11 6:00 AM WIPER TRIP TO WINDOW. BEGIN PVT 293 BBLS. NO ISSUES ON TRIP TO THE WINDOW. TIGHT HOLE AGAIN FROM 10,780'-10,805' 2/3/11 6:00 AM 2/3/11 9:20 AM WIPER TRIP TO WINDOW WITH HEAVY CUTTINGS OBSERVED AT SHAKER. ECD = 10.24 PPG AT 1.5 BPM AND 4000 PSI. ESTABLISH SLOW PUMP RATE: 0.75 BPM © 2650 PSI. 1.5 BPM @ 4000 PSI. PVT= 285 BBLS HAD TO WORK THROUGH AND BACK REAM THROUGH SHALE INTERVAL FROM 10980' - 11080'. 2/3/11 9:20 AM 2/3/11 11:40 AM DRILL AHEAD FROM 11150' 1.5 BPM , 4000 PSI, MW = 8.6PPG AND PVT = 275 BBLS 2/3/11 11:40 AM 2/3/11 1:45 PM WIPER TRIP TO WINDOW FROM 11300'. PVT = 269 BBLS OPEN EDC AND JET TOP OF LINER 2/3/11 1:45 PM 2/3/11 1:55 PM TIE-IN FROM 9325. CORRECT+10' Page 7 of 9 18-13C, Operations Summary From To Operation Summary 2/3/11 1:55 PM 2/3/11 3:00 PM CONTINUE WIPER TRIP TO BOTTOM. 2/3/11 3:00 PM 2/3/11 4:45 PM DRILL AHEAD FROM 11300'. ADD - 60 BBLS OF XS KCL WITH ADDITIVES TO LOWER LSRV. 2/3/11 4:45 PM 2/3/11 7:15 PM WIPER TRIP TO WINDOW FROM 11450'. NO ISSUES RUNNING BACK TO BOTTOM. 2/3/11 7:15 PM 2/3/11 9:40 PM FREE SPIN 3505 PSI AT 1.46 BPM. DRILL AHEAD FROM 11,450' TO 11,600' - 1.46-1.47 BPM , 3690-3830 PSI, MW IN 8.6 PPG, MW OUT 8.65 PPG, 1.01-1.87K WOB, 10.11-10.2 ECD, END PVT= 300 BBLS - CONDUCT 150' WIPERS AS PRESSURES DICTATE - CONDUCTED UNNANOUNCED KICK WHILE DRILLING DRILL AND AAR 2/3/11 9:40 PM 2/4/11 12:00 AM WIPER TRIP TO WINDOW FROM 11,600'. BEGIN PVT 300 BBLS. TRIP TO WINDOW WITH NO ISSUES. BEGIN TRIP TO BOTTOM. LD BHA. CHANGE OUT MOTOR, HOURED OUT. MU AGITATOR AND R-1 FLOAT SUB (SUB TESTED TO 300 PSI LOW, 1500 PSI HIGH ON CHART). - REPLACE BIT. BIT GRADE: - CONDUCT ROUTINE MAINTENANCE BEFORE RUNNING IN HOLE 2/4/11 12:00 AM 2/4/11 1:00 AM RUNNING BACK TO BOTTOM FROM WIPER TRIP TO WINDOW. BOBBLE AT 11,027'. END PVT 289 BBLS. LOSS OF 11 BBLS DURING WIPER TRIP. 2/4/11 1:00 AM 2/4/11 4:15 AM FREE SPIN 3500 PSI AT 1.40 BPM. DRILL AHEAD FROM 11,600' TO 11,750' - 1.39-1.46 BPM , 3770-4050 PSI, MW IN 8.62 PPG, MW OUT 8.70 PPG, 1.46-1.78K WOB, 10.26-10.35 ECD, END PVT = 278 BBLS - CONDUCT 150-200' WIPERS AS PRESSURES DICTATE 2/4/11 4:15 AM 2/4/11 6:00 AM WIPER TRIP TO WINDOW FROM 11750'. BEGIN PVT = 278 BBLS OPEN EDC AND JET TOP OF LINER 2/4/11 6:00 AM 2/4/11 8:00 AM WIPER TRIP BACK TO BOTTOM. 2/4/11 8:00 AM 2/4/11 11:45 AM DRILL AHEAD FROM 11750' ROP - 110 FPH 1.44/1.43 BPM 4039 PSI CIRCULATING PRESSURE 8.62/8.65 PPG PVT = 263 BBLS ECD = 10.33 PPG. 2/4/11 11:45 AM 2/4/11 3:00 PM WIPER TRIP TO WINDOW FROM 11900' 2/4/11 3:00 PM 2/4/11 5:50 PM DRILL AHEAD FROM 11900' ROP -V 60 FPH 1.54/1.54 BPM 3669 PSI CIRCULATING PRESSURE 8.61/8.67 PPG PVT= 311 BBLS ECD = 10.04 2/4/11 5:50 PM 2/4/11 10:00 PM WIPER TRIP TO WINDOW. OPEN EDC ABOVE 3 1/2" LINER, POOH. CONDUCT JOG AT SURFACE. POP OFF INJECTOR. PJSM ON LAYING DOWN BHA AND MAKING UP NEW BHA. 2/4/11 10:00 PM 2/4/11 11:40 PM LD BHA. REPLACE MOTOR AND BIT. BIT GRADE: 1-2-CT-A- X-I-WT-BHA- MU AGITATOR - CONDUCT BOP FUNCTION TEST AND CHANGE OUT HIGH PRESSURE SCREENS 2/4/11 11:40 PM 2/5/11 12:00 AM RIH WITH DRILLING BHA. CONDUCT SHALLOW HOLE AGITATOR TEST. CONTINUE TO RIH TO TD. 2/5/11 12:00 AM 2/5/11 3:00 AM RIH WITH DRILLING BHA. CONDUCT TIE-IN AT 9320'; 0' CORRECTION. RIH TO TD OF 12,050'. Page 8 of 9 • 18-13C, Operations Summary From To Operation Summary 2/5/11 3:00 AM 2/5/11 5:15 AM FREE SPIN 3550 PSI AT 1.40 BPM. DRILL AHEAD FROM 12,050' to 12,200'. - 1.40/1.41 BPM, 3700-3880 PSI CIRCULATING PRESSURE, MW IN 8.61, MW OUT 8.67 PPG, ECD 10.14-10.17 PPG - BEGIN PVT 292 BBLS, END PVT 284 BBLS 2/5/11 5:15 AM 2/5/11 6:00 AM WIPER TRIP TO WINDOW 2/5/11 6:00 AM 2/5/11 9:00 AM CONTINUE WIPER TRIP BACK TO BOTTOM 2/5/11 9:00 AM 2/5/11 11:50 AM DRILL AHEAD FROM 12200' 1.46/1.45 BPM, 3650 PSI CIRCULATING PRESSURE, 8.53/8.59 PPG, ECD = 10.01 PPG SWAP TO NEW QUICK DRILL MUD SYSTEM. 2/5/11 11:50 AM 2/5/11 1:30 PM WIPER TRIP TO WINDOW FROM 12350' 2/5/11 1:30 PM 2/5/11 7:50 PM DRILL AHEAD FROM 12350', 1.55/1.52, 3800 PSI CIRCULATING PRESSURE, 8.53/8.59 PPG, ECD = 10.06 PVT = 334 BBLS TEMPORARILY UNABLE TO MOVE COIL AT 12405'. DISCUSS OPTIONS WITH DRILLING ENGINEER. COIL PULLED FREE AFTER MAX OVER-PULL. AFTER COIL PULLED FREE, WIPE LENGTH OF BHA AND RESUME DRILLING. DRILL TO 12,469' WITH MULTIPLE SHORT TRIPS. DISCUSS OPTION OF INCREASING LUBRICANTS. CONDUCT WIPER TRIP WHILE LUBRICANTS GET SHIPPED OUT. 2/5/11 7:50 PM 2/6/11 12:00 AM WIPER TRIP FROM 12,469' TO WINDOW. CONTINUE TO TOP OF 3 1/2" LINER. OPEN EDC, WASH OVER SEVERAL TIMES. CLOSE EDC, RUN TO WINDOW. CONDUCT TIE-IN LOG AT 9325'; +17' CORRECTION. CONTINUE TO RIH TO 12,469. 2/6/11 12:00 AM 2/6/11 4:15 AM DRILL AHEAD FROM 12,469' TO TD OF 12,650'. - 1.40-1.43 BPM, 3610-3730 PSI CIRCULATING PRESSURE, MW IN 8.54, MW OUT 8.62 PPG, ECD 10.08-10.17 PPG - BEGIN PVT 314 BBLS, END PVT 297 BBLS -STICKY AT 12,505'; PU AND MAKE BHA WIPER TRIP - INCREASE LUBES BY 1%; ABLE TO DRILL AHEAD SLOWLY, LOW WEIGHT TRANSFER -TD CALLED AT 12,650' CTD 2/6/11 4:15 AM 2/6/11 1:00 PM WIPER TRIP TO WINDOW. WIPER TRIP BACK TO BOTTOM. LOG TIE-IN PASS AT 9320'. CORRECT +5'. CONTINUE TO RIH TO TD. TAG AT 12,653'. PU, RE-TAG TO CONFIRM. 2/6/11 1:00 PM 2/6/11 6:30 PM POH WITH DRILLING BHA. LAY IN 30 BBL PERF PILL WITH STICKLESS 20 COARSE BEADS. OPEN EDC ABOVE 3 1/2" LINER TOP, PUMP AT MAX RATE WHILE POH. AT SURFACE, MAKE JOG TO 500'. PU, POP OFF INJECTOR. PJSM ON LAYING DOWN BHA. 2/6/11 6:30 PM 2/6/11 7:15 PM LD BHA. BIT GRADE 1-1-WT-A-X-I-WT-TD Change to Completion Phase Page 9 of 9 • North America -ALASKA- BP Page 1 of 11 Operation Summary Report Common Well Name: 18-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/6/2011 End Date: 2/13/2011 X3-00Y9J-C(1,305,200.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release:2/14/2011 Rig Contractor:NORDIC CALISTA UWI:500292175600 Active Datum:24: 1311/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 2/6/2011 19:15 - 22:45 3.50 CASING P RUNPRD MOBILIZE LINER RUNNING TOOL AND SHOE BHA TO RIG FLOOR. CONDUCT SLACK MANAGEMENT WITH E-LINE;PUMP LINE FORWARD. CUT 15'COIL. PUMP AND CATCH 3/4"BALL TO ENSURE DRIFT. PJSM ON MAKING UP LINER ASSEMBLY. CHANGE OUT PACKOFFS IN INJECTOR. 22:45 - 00:00 1.25 CASING P RUNPRD MOBILIZE LINER RUNNING EQUIPMENT TO RIG FLOOR. RU LINER RUNNING EQUIPMENT. 2/7/2011 00:00 - 04:45 4.75 CASING P RUNPRD MU LINER ASSEMBLY PER WELL PLAN. RAN SHOE TRACK PER WELL PLAN,134—..ITS 2 3/8" 4.7#L-80 STL TUBING WITH CEMENTRALIZERS(MARKER JOINT PLACED BETWEEN JOINTS 88 AND 89),BAKER DEPLOYMENT SLEEVE AND SELBRT. -CONDUCTED ANNOUNCED KICK DRILL WHILE TRIPPING LINER. GOOD LEARNING I DRILL FOR CREW. 04:45 - 12:00 7.25 I CASING P RUNPRD MU COIL TO LINER ASSEMBLY. RIH WITH LINER ASSEMBLY. TIE-IN AT WINDOW FLAG, +5'CORRECTION. CONTINUE TO RIH. 12:00 - 00:00 12.00 CASING P RUNPRD RIH WIIJ LJNER._SLOW PROGRESS. ADD 80 BBL 3%EXTRA SLICK KCL PILL TO LOWER PRESSURES. PRESSURES DID NOT DROP AS MUCH AS EXPECTED BUT ACTED AS LO-VIS PILL TO HELP WITH CLEANING UP - CUTTINGS. • -CONTINUE USING A PUMP AND RELAX METHOD TO RIH WITH LINER TO 12,597'. WORK HARD TO GET TO 12,616'. -PUMP 20 BBL 2%KCL EXTRA SLICK LO-VIS PILL TO STIR UP AND CLEAN UP CUTTINGS -RIH TO 12,621'WITH VARYING PUMP RATES TO STAY BELOW 2000 PSI 2/8/2011 00:00 - 01:00 1.00 CASING P ' RUNPRD RIH WITH LINER BHA FROM 12,621'. TAG TD POSITIVE INDICATION WITH 11K SET DOWN WEIGHT. PU,BREAKOVER AT 48K, RE-TAG TD WITH 11K DOWN WEIGHT. 01:00 - 02:00 1.00 CASING P RUNPRD LAUNCH 5/8"BALL. LOST RETURNS DURING PUMPING. PUMP DOWN,CUT PUMP RATE DOWN AT 25 BBLS AWAY. BALL SEATED. PRE - P HEAR RUNNING TOOL TO RELEASE FROM LINER. BLEED OFF PRESSURE. PU TO GET BREAKOVER. SET BACK DOWN,PU AGAIN TO CONFIRM BREAKOVER AT 27K. SET DOWN 10K, PREPARE TO DISPLACE TO KCL. Printed 3/8/2011 4:02:08PM North America-ALASKA- BP Page 2 of 11 • Operation Summary Report Common Well Name: 18-13 AFE No Event Type: COM-ONSHORE(CON) Start Date: 2/6/2011 End Date: 2/13/2011 X3-00Y9J-C(1,305,200.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 I Spud Date/Time: 11/3/1987 12:00:00AM Rig Release: 2/14/2011 Rig Contractor: NORDIC CALISTA UWI:500292175600 Active Datum:24: 13 11/3/1987 00:01 ©54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 1-02:00 - 06:00 4.00 CASING P O I RUNPRD I PREPARE TO DISPLACE TO 8.4 PPG 2% EXTRA SLICK KCL. WITH MUD IN COIL: INITIAL CIRCULATING PRESSURE 2520 PSI AT.2 BPM IN WITH NO RETURNS, INCREASE TO 2615 PSI AT 1.04 BPM WITH NO RETURNS. -KCL AT BIT:CIRCULATING PRESSURE 2420 PSI AT 1 BPM,1180 PSI AT.5 BPM,970 PSI AT .3BPM -CONTINUE CIRCULATING AND ESTABLISH RETURNS. INCREASE RATE TO.4 BPM WITH .2 BPM RETURNS. INCREASE RATE TO.58 BPM WITH.56 BPM RETURNS AT 875 PSI AFTER 130 BBLS KCL AWAY. TWO TRUCKS FILLING WITH 2%KCL AT PLANT;510 BBLS KCL ON LOCATION -PLAN IS TO CONTINUE CIRCULATING UNTIL RETURNS ARE 1 TO 1 AND KCL ALL THE WAY AROUND. ONCE AROUND,WILL CIRCULATE 2 BU AND EVALUATE SYSTEM. 06:00 - 12:00 6.00 CASING P RUNPRD CONTINUE TO CIRCULATE BOTTOMS UP. -RETURNS INCREASING TO 1:1 -KEEP CIRCULATING BOTTOMS UP WHILE QUICKDRILL INTERFACE CLEANS UP -.72 BPM IN AND.71 BPM OUT -1.04 BPM IN AND 0.82 BPM OUT -1.51 BPM IN AND.80 BPM OUT -1.51 BPM IN AND.92 BPM OUT(2303 PSI) -1.0 BPM IN AND.94 BPM OUT(1600 PSI) 12.00 - 12:20 0.33 CASING P RUNPRD CONDUCT PJSM WITH CEMENT CREW AND RIG TEAM. DISCUSS MUSTER AREA,GOOD COMMUNICATION AND JOB PROCEDURE. • Printed 3/8/2011 4:02:08PM North America -ALASKA- BP Page 3 of 11 • • Operation Summary Report Common Well Name: 18-13 AFE No Event Type: COM-ONSHORE(CON) Start Date: 2/6/2011 End Date:2/13/2011 X3-00Y9J-C(1,305,200.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release: 2/14/2011 Rig Contractor: NORDIC CALISTA UWI:500292175600 Active Datum:24: 13 11/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 12:20 - 15:40 3.33 CASING P I (ft) RUNPRD PRESSURE TEST AND BATCH UP CEMENTERS. BEGIN PUMPING16.1 BBL 15,8PPG CEMENT STAGE: 10 BBLS=2500 PSI 15 BBLS=3500 PSI 16.1 BBLS SHUT DOWN CEMENTERS AND LINE UP WITH RIG PUMP. ZERO IN MM. M 2#BIOZAN STAGE: 10 BBLS= 1.03 BPM IN/0.87 BPM OUT @ 2985 !,va'°A' PSI. 20 BBLS= 1.0 BPM IN/0.77 BPM OUT @ 1194 PSI. 30 BBLS= 1.0 BPM IN/0.76 BPM OUT @ 1597 PSI. 39.2 BBLS SHUT DOWN PUMPS AND SIDE EXHAUST 2BBLS CEMENT AND 3 BBLS 2# BIOZAN. PUH TO COIL BREAKOVER+ 13'AND SIDE EXHAUST 2 BBLS CEMENT AND 3 BBLS 2# BIOZAN. 1.0 BPM IN 1.0 BPM OUT @ 1315 PSI. SET BACK DOWN WITH COIL WITH 10K DOWN LAUNCH LINER WIPER PLUG WITH.3 BBLS AND 2500 PSI AT 2.9 BBLS BEHIND PIPE, LOST RETURNS LOWERED RATE T0.4 BPM WITH NO RETURNS SAW LINER WIPER PLUG LAND AL15.6.BBLS (15.8 BBLS CALCULATED) PRESSURE UP TO 2245 PSI AND HOLD PRESSURE. ;OPEN BAKER CHOKE AND BLEED OFF COIL !PRESSURE 'CHECK FLOATS. FLOATS APPEAR TO BE HOLDING WITH NO RETURNS NOTED AT SHAKER. UNSTING FROM LINER TOP AND PUMP 5 BBLS 2#BIOZAN AT 1 BPM NEAR LINER TOP. 115:40 - 17:00 1.33 CASING P RUNPRD POOH WITH LINER '—.► ► = 17:00 - 17:15 0.25 CASING P RUNPRD FLOW CHECK WELL.NO FLOW. 17:15 - 17:45 0.50 CASING P RUNPRD 1 LD LINER RUNNING BHA. BAKER TOOLS LOOKED GOOD AND THEY TOOK THEM BACK TO THEIR SHOP. 17:45 - 18:15 0.50 CASING P RUNPRD PJSM TO MU UP NOZZLE CLEAN OUT BHA#8 (2"NOZZLE,3/4"BALL DISCONNECT,DBPV, XO,2 JTS 2-1/16"CSH,XO, QUICK CONNECT THE CTC). 18:15 - 20:15 2.00 CASING P RUNPRD MU UP NOZZLE CLEAN OUT BHA#8 LISTED ABOVE. 20:15 - 21:45 1.50 CASING P RUNPRD RIH AND TAG AT 8557'WITH THE 2.33"XO TWICE ON 3"GS ID OF 2.25". CORRECTED DEPTH+8.5'. 78FPM,2.96 BPM,3000 PSI, DN WT 13K, PVT 307 BBLS. ZERO LOSSES RIH. Printed 3/8/2011 4:02:08PM North America -ALASKA- BP Page 4 of 11 • Operation Summary Report Common Well Name: 18-13 AFE No Event Type: COM-ONSHORE(CON) Start Date:2/6/2011 End Date: 2/13/2011 X3-00Y9J-C(1,305,200.00) Project: Prudhoe Bay I Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud DatefTime: 11/3/1987 12:00:00AM Rig Release: 2/14/2011 Rig Contractor:NORDIC CALISTA UWI:500292175600 Active Datum:24:1311/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 21:45 - 23:15 1.50 CASING P I (h) RUNPRD AT TOP OF LINER(8549')PUMP A HIGH VIS 30 BBL SWEEP,FOLLOWED BY REGULAR VIS 30 BBLS,FOLLOWED BY ANOTHER 30 BBL HIGH VIS SWEEP.THEN CBU. 23:15 00:00 0.75 CASING P RUNPRD POOH CHASING SWEEPS. PAINT EOP FLAG AT 4000'. EOP FLAG AT 4,000'AND A 4,378'MILL AND MOTER BHA,THE FLAG WILL COME ACROSS THE HORSES HEAD WHEN THE MILL IS 172' • FROM THE TOL. 2/9/2011 00:00 - 01:30 1.50 CASING P RUNPRD POOH AND LD NOZZLE CLEAN OUT BHA#8 (CTC, QUICK CONNECT,XO,2 JTS OF 2 1/16" CSH,XO, DBPV, HYD DISCONNECT AND 2" NOZZLE). 01:30 - 02:00 0.50 CASING P RUNPRD PJSM TO PU CSH. 02:00 - 04:30 2.50 CASING P RUNPRD MU MILL AND MOTOR CLEAN OUT BHA#9 (XO, DISCONNECT SUB, CIRC SUB,1-11/16" MUD MOTOR AND USED HUGHES 1.85"MILL). PU 56 JOINTS OF 1"CSH SINGLES OFF PIPE RACK, RATTLE AND DRIFT.PUMP THROUGH CSH TO VERIFY CLEAN. 04:30 - 06:00 1.50 CASING P RUNPRD TRIP IN HOLE WITH 13 STANDS OF 1"CSH OUT OF DERRICK. PUMP THROUGH CSH TO VERIFY CLEAN.CREW CHANGE AND PJSM. 06:00 - 09:30 3.50 CASING P RUNPRD TRIP IN HOLE WITH REMAINING 30 STANDS OF 1"CSH OUT OF DERRICK FOR A TOTAL OF 142 JTS.BREAK CIRCULATION EVERY 10-15 STANDS TO ENSURE PIPE CLEAR OF DEBRIS. 09:30 - 10:00 0.50 CASING P RUNPRD RD FROM HYDRIL PIPE HANDLING. MU COIL TO REMAINING BHA (XO, HYD DISCONNECT, DBPV,XO,2 JTS OF 2-1/16"CSH,XO,QUICK CONNECT AND CTC)AND STAB INJECTOR. 10:00 - 11:00 1.00 CASING P RUNPRD RIH ON COIL FROM 4377-8544. TAG UP W/ MILL AT 8544. PU AND RE TAG TO CONFIRM. 11:00 - 12:00 1.00 CASING N HMAN 8,555.00 RUNPRD DETERMINED THAT THE MILL IN THE.I!.QLE IS 1.85"OD INSTEAD OF PLANNED 1.75 OD_ DEPLOYMENT SLEEVE HAD 1.78"MIN ID. CIRCULATE 1 BPM 3400 PSI WHILE DISCUSSING OPTIONS. ONE FOR ONE RETURNS WHILE CIRCULATING. 12:00 - 12:30 0.50 CASING N HMAN 8,555.00 RUNPRD ADD BIOZAN 0.5 PPB TO SYSTEM AND PUMP MILL FLUID TO BIT. 1 BPM IN AND 1 BPM OUT 12:30 - 13:40 1.17 CASING N HMAN 8,555.00 RUNPRD 1 MILL OUT 1.78"MIN ID(0.25"LONG)AND 1.82 !ID(1.0 IN LONG)ON DEPLOYMENT SLEEVE FROM 8555'. 1.0 BPM,3200 PSI OFF,3400 PSI ON. 13:40 - 16:00 2.33 i CASING P RUNPRD J RIH 33 FPM WITH MILL/CLEANOUT BHA FROM 8545'-LANDING COLLAR PBTD OF 12600'CTMD(UNCORRECTED). PUMPING 1 BPM ON RIH. 16:00 - 18:00 2.00 CASING P RUNPRD TAG UP LANDING COLLAR TWICE AT 12,600'_ CTMD-PUMP—3.5 BBLS OF HI-VIS SWEEP AROUND THE MILL PRIOR TO POH. PUMP REMAINDER OF THE 25 BBL SWEEP AROUND I AND CHASE OUT OF HOLE 66 FPM. 1 BPM, 3250 PSI @ 12,580' Printed 3/8/2011 4:02:08PM North America-ALASKA- BP Page 5 of 11 Operation Summary Report Common Well Name: 18-13 AFE No Event Type: COM-ONSHORE(CON) Start Date:2/6/2011 End Date:2/13/2011 X3-00Y9J-C(1,305,200.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release: 2/14/2011 Rig Contractor:NORDIC CALISTA UWI:500292175600 Active Datum:24: 13 11/3/1987 00:01 @54.80ft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 18:00 - 18:30 0.50 CASING P RUNPRD PJSM TO LD CLEAN OUT BHA#9(QUICK CONNECT,XO,2 JTS OF 2 1/16"CSH,XO, DBPV,HYD DISCONNECT,AND XO.SB 71 JTS OF 1"CSH.LD XO,DISCONNECT SUB,CIRC SUB,1-11/16"MUD MOTOR AND USED HUGHES 1.85"MILL). 18:30 - 19:30 1.00 CASING P RUNPRD LD CLEAN OUT BHA#9 LISTED ABOVE AND RU TO SB 1"CSH. --- -----19:30 - 21:30 2.00 CASING P RUNPRD STANDING BACK 71 JTS OF 1"CSH. LOU GRIMALDI WITH AOGCC WAIVED WITNESS TO BOP TEST. 21:30 - 21:45 0.25 CASING P RUNPRD SAFETY JOINT DRILL. 21:45 - 22:30 0.75 CASING P RUNPRD LD THE REST OF TIMENILL AND MOTOR CLEAN OUT BHA#9. MILL IN GOOD CONDITION AND SAME 1.85" OD. FILL HOLE. LOST-1 BBLS PER HOUR DURING TRIP OUT OF HOLE. 22:30 - 23:00 0.50 EVAL P OTHCMP PJSM TO PU AND RUN LOGGING TOOLS BHA #10. REVIEWED PROCEDURE FOR HANDLING RADIO ACTIVE SOURCE. 23:00 - 00:00 1.00 EVAL P OTHCMP RU SLB TOOLS(MCNUGR/CCUSCMT)AND BRING EVERYTHING TO THE FLOOR. 2/10/2011 00:00 - 01:45 tip _. EVAL ' P OTHCMP MU LOGGING TOOLS AND RIH. STARTED 40 HR BATTERY AT 1:45. TURN THE E TOOL ON. 01:45 - 02:35 0.83 EVAL, P OTHCMP MU THE REST OF LOGGING BHA#10 (PORTED SUB,CIRC SUB, DISCONNECT SUB AND XO). 02:35 - 05:30 2.92 EVAL -- P I OTHCMP RU TO RUN 70 STANDS OF CSH FROM THE DERRICK(THAT WILL LEAVE ONE STAND IN THE DERRICK).CHECKING TORQUE ON EVERY CONNECTION RUNNING IN THE HOLE. EXTRA SAFE WITH RADIO ACTIVE SOURCE BELOW THE CSH. 05:30 - 07:00 1.50 EVAL P OTHCMP MU THE REST OF THE LOGGING BHA#10 THAT GOES ABOVE THE 70 STANDS OF 1"CSH(XO, HYD DISCONNECT, DBPV,XO,2 JTS 2-1/16"CSH,XO, QUICK CONNECT TO CTC). PUMP TO CLEAR LINES 1.3 BPM-4255 PSI. 07:00 - 08:45 1.75 EVAL P OTHCMP RIH WITH LOGGING BHA ON COIL TUBING FROM 4429'TO 8344'CTMD(200'ABOVE TOP OF LINER FROM YESTERDAY'S TAG)AT 80- 100 FPM PUMPING 0.35 BPM ON RIH. 08:45 - 11:00 2.25 EVAL P OTHCMP LOG INITIAL CNUSCMT DOWNPASS FRQM 8344'-12570'CTMD AT 30 FPM. PUMPING 0.4 BPM,910 PSI AT LINERTOP. LOSS RATE-2 BPH 11:00 - 12:45 1.75 EVAL P I OTHCMP LOG REPEAT CNUSCMT PASS UP FROM 12570'-10900'CTMD AT 30 FPM. PUMPING 0.4 BPM,920 PSI AT TD. INCREASE LOG SPEED TO 60 FPM FROM 10900'-8344'CTMD. PUMPING 0.4 BPM,820 PSI AT LINERTOP. Printed 3/8/2011 4:02:08PM North America-ALASKA- BP Page 6 of 11 • Operation Summary Report Common Well Name: 18-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/6/2011 End Date:2/13/2011 X3-00Y9J-C(1,305,200.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release:2/14/2011 Rig Contractor:NORDIC CALISTA UWI: 500292175600 Active Datum:24: 13 11/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs )s Task Code NPT NPT Depth Phase Description of Operations '12:45 - 13:30 0.75 EVAL i P (ft) I OTHCMP I BRING PUMPS ONLINE PUMPING 37 DEGF 1 FLUID DOWN COIL. 1 FOR 1 RETURNS. 1.3 BPM IN AND OUT. BBLS AWAY TEMP IN PUMP PSI RATE 3.0 40.1 3779 PSI 1.16 I I BPM I 5.0 38.4 3864 PSI 1.16 BPM 10.0 37.3 4500 PSI 1.28 BPM 15.7 37.0 4640 PSI 1.28 BPM 28.0 36.6 4560 PSI 1.27 BPM 36.0 37.0 4400 PSI 1.27 • 4PM 5.4 36.7 2730 PSI 1.23 BPM BETWEEN 40&45 BBLS AWAY NEW COLD KCL ENTERING HYDRIL-SAW PRESSURE FALL OFF FROM 4400 PSI TO 2730 PSI. STABALIZED AT-2730 PSI PRIOR TO BULLHEADING. CONTINUE CIRCULATING. • • PERFORM KICK DRILL,STRAP PITS, LOOK FOR LOSSES,MONITOR FLOW-IN FLOW-OUT. 13:30 - 15:30 2.00 EVAL i P i OTHCMP CLOSE IN ANNULUS,MONITOR WELLHEAD PRESSURE. BEGIN INJECTING INTO ' LINERLAP. BBLS TEMP IN PUMP PSI RATE WHP • 49.9 36.7 3940 PSI 1.20 BPM 1216 59.5 36.9 4165 PSI 1.21 BPM 11476 67.9 36.8 4255 PSI 1.21 BPM 1545 75.2 36.8 4280 PSI 1.21 BPM I 11580 1101.6 36.9 4250 PSI 1.21 BPM 11534 j 131.6 37.3 4220 PSI 1.20 BPM 11509 150.0 37.3 4200 PSI 1.20 BPM 1480 SWAP TO PERF PILL AND CONTINUE INJECTING COLD KCL INTO LINER LAP WHILE I• SENDING PERF PILL INTO COIL. 36.5 BBLS PERF PILL PUMPED. 1.0 BPM,4180 PSI,1223 WHP. 15:30 - 16:45 1.25 EVAL P OTHCMP I RIH LOGGING DOWN FOR REPEAT TEMPERATURE PASS FROM 8345-12570 CTMD. LOG 30 FPM INTO LINER TOP AND THEN INCREASE SPEED TO 60 FPM. PUMPS OFF WHILE LOGGING DOWN PASS. 16:45 - 18:35 1.83 EVAL P OTHCMP POH FROM 12570'TO TOP OF LINER LAYING IN 36 BBL PERF PILL_WHILE PULLING. SEND 2 BBLS AROUND CORNER PRIOR TO STARTING OUT OF HOLE. LOSS RATE OF-2 BPH WHILE PULLING OUT OF LINER. 18:35 - 18:50 0.25 EVAL P OTHCMP PJSM TO LD LOGGING BHA#10 AND STAND 1 BACK 70 STANDS OF 1"CSH. Printed 3/8/2011 4:02:08PM North America-ALASKA- BP Page 7 of 11 Operation Summary Report Common Well Name: 18-13 AFE No Event Type:COM-ONSHORE(CON) Start Date: 2/6/2011 End Date:2/13/2011 X3-00Y9J-C(1,305,200.00) Project:Prudhoe Bay I Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release:2/14/2011 Rig Contractor: NORDIC CALISTA UWI:500292175600 Active Datum:24: 13 11/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:50 - 19:30 0.67 EVAL P OTHCMP TAG UP AT SURFACE. POP INJECTOR OFF WELL. LD FIRST PART OF LOGGING BHA#10(CTC TO QUICK CONNECT,XO,2 JTS 2-1/16"CSH, XO,DBPV,HYD DISCONNECT AND XO). 19:30 - 22:00 2.50 EVAL P OTHCMP LD 2 JOINTS OF 1"CSH AND STAND BACK 69 STANDS OF 1"CSH IN DERRICK. 22:00 - 22:15 0.25 EVAL P OTHCMP PJSM TO LD LOGGING TOOLS WITH. NEUTRON SOURCE. 22:15 - 23:30 1.25 EVAL P OTHCMP LD REST OF LOGGING BHA AND LOGGING TOOLS(XO,DISCONNECT SUB,CIRC SUB, PORTED SUB,MCNL AND SCMT). 23:30 - 00:00 0.50 BOPSUR P OTHCMP MASTER AND SWAB VALVE CLOSED.PVT= 197BBL OPEN RAM BODY CAVITIES TO CLEAN AND INSPECT. 2/11/2011 00:00 03:30 3.50 BOPSUR P OTHCMP MASTER AND SWAB VALVE CLOSED. OPEN RAM DOORS TO CLEAN AND INSPECT RAMS. 03:30 - 04:00 0.50 BOPSUR P OTHCMP SERVICE TREE VALVES. 04:00 04:15 0.25 BOPSUR P OTHCMP PJSM TO TEST BOPE., 04:15 - 12:30 8.25 BOPSUR P ! OTHCMP LOU GRIMALDI WITH AOGCC WAIVED WITNESS TO BOP TEST. RU AND TEST BOPE. I 'PERFORM ACCUMULATOR DRAWDOWN TEST. TEST ALL BOP COMPONENTS TO 250 AND 3500 PSI. TEST CHOKE MANIFOLD AND MUD CROSS VALVES TO 250 AND 3500 PSI. TEST ANNULAR TO 250 AND 2500 PSI. 2-1/16"CHECK VALVE BONNET FAILED,C/O GASKET AND RETEST GOOD. HOLE TOOK 13 BBLS TO FILL AFTER BOP TEST. HOLE LOSING 1 BPH. 12:30 - 13:00 0.50 ' PERFOB P OTHCMP PJSM TO PU PERF GUNS,LOAD PIPE SHED WITH GUNS. REVIEW PROCEDURE FOR RUNNING PERF GUNS AS PER SLB. 13:00 - 15:00 2.00 PERFOB P OTHCMP RU TO RUN 1.56"HSD PERFORATING GUNS.. -BRING GUNS TO PIPESHED,SPACE OUT AND 'VERIFY COUNT AND CHARGE SPACING. 15:00 - 20:00 5.00 PERFOB P OTHCMP MU PERF BHA#11 (BOTTOM NOSE,1397'OF Ij 1.56"6 SPF GUNS, E-FIRE HEAD, HYD DISCONNECT 5/8"BALL,XO). MONITOR FLUID DISPLACEMENT. 20:00 - 22:00 2.00 PERFOB P OTHCMP RU AND TIH WITH 90 JTS 1"CSH. MONITOR FLUID DISPLACEMENT. 22:00 - 23:00 1.00 PERFOB P OTHCMP MU REST OF BHA#11 (XO,HYD DISCONNECT 3/4"BALL,DBPV,XO,2 JTS 2-1/16"CSH,XO, QUICK CONNECT TO CTC). 23:00 - 23:30 0.50 ' PERFOB P OTHCMP TEST INNER REEL VALVE TO 250 AND 3500 PSI AND CHART. 23:30 - 00:00 0.50 PERFOB P OTHCMP MU INJECTOR AND RIH WITH COIL TUBING CONVEYED PERF GUNS. - 2/12/2011 00:00 - 02:00 2.00 PERFOB P OTHCMP RIH WITH 1.56"HSD 6 SPF 1606 PJ PERF GUNS. TAG BOTTOM AT 12603'. Printed 3/8/2011 4:02:08PM North America -ALASKA- BP Page 8 of 11 Operation Summary Report Common Well Name: 18-13 1AFE No Event Type: COM-ONSHORE(CON) Start Date:2/6/2011 End Date: 2/13/2011 [X3-00Y9J-C(1,305,200.00) Project: Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release:2/14/2011 Rig Contractor: NORDIC CALISTA UWI:500292175600 Active Datum:24 1311/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 02:25 0.42 PERFOB P OTHCMP BEGIN FIRING SEQUENCE. GUNS FIRED AT 02:25. GOOD INDICATION ON SHOT INDICATOR. CIRCULATING PRESSURE DROPPED OFF AND LOST 5 BLLS OF FLUID. 02:25 - 03:50 1.42 PERFOB P OTHCMP POOH.SLOWLY PULLED 22K OVER ON UPSTROKE AFTER SHOTS FIRED BEFORE BREAKING BACK OVER TO 30K COIL TUBING WEIGHT. NO OTHER OVERPULLS SEEN WHILE POH TO TOL. POOH 50 FPM PUMPING 0.8 BPM. 03:50 - 04:05 0.25 PERFOB P OTHCMP 15 MINUTE FLOW CHECK AT 8474'(—TOL).NO FLOW.PVT 200BBL. 04:05 - 05:00 0.92 PERFOB P OTHCMP POOH WITH;GUNS FROM TOL TO SURFACE. POOH 100 FPM PUMPING 1 BPM. 05:00 - 05:20 0.33 PERFOB P OTHCMP 20 MINUTE FLOW CHECK AT SURFACE.NO FLOW TOOK 1/2 BBL TO FILL. 05:20 - 06:00 0.67 PERFOB : R,, OTHCMP POP OFF INJECTOR AND LD BHA#11 (QUICK CONNECT,2-1/16 TUBING, DBPV,HYD) RIG UP TO PULL AND LAY DOWN HYDRIL. PVT 184BBL. 06:00 - 09:45 3.75 PERFOB P OTHCMP PULL AND LD 90 JOINTS 1"CS HYDRIL FROM 4170'-1408'CTMD. LOSS RATE—1 BPH. 109:45 - 10:15 0.50 PERFOB P OTHCMP RD FROM LAYING DOWN CS HYDRIL. RU AND PREP PIPE SHED TO LAY DOWN GUN STRING. 10:15 - 13:30 3.25 PERFOB P OTHCMP LAY DOWN HYD DISCONNECT, E-FIRE HEAD, AND 66 PERF GUNS. ALL SHOTS FIRED AND HOLES ALLIGNED TO y SCALLOPS. NO ISSUES W/TRAPPED PRESSURE. CLEAN AND CLEAR RIG FLOOR. 13:30 - 14:30 1.00 PERFOB P OTHCMP PJSM.UNLOAD PERF GUNS FROM PIPESHED,RID AND CLEAR RIG FLOOR. CONTINUE TO MONITOR WELL. 14:30 - 15:00 0.50 CASING P RUNPRD PJSM.LOAD 4 1/2"KB LTP AND RUNNING ► EQUIPMENT ONTO RIG FLOOR. 15:00 - 16:00 1.00 CASING P RUNPRD M/U 4 V2"LTP BHA(3"SEAL ASSY.,LOCATOR,10'PUP, LTP, RUNNING TOOL,X/O, HYD. DISC.,X/O. M/U 2 JOINTS 2 1/16"CSH,BAKER QUICK CONNECT). M/U INJECTOR. CONFIRM NO AREA OF 50% COIL LIFE OVER GOOSENECK WHILE SETTING PACKER. DRIFT DISCONNECT SUB WITH 5/8"BALL-PASSES THROUGH. 16:00 - 19:10 3.17 CASING P RUNPRD ESTABLISH CIRCULATION.PVT 166 BBLS. RIH WITH LTP 70 FPM.26 BPM,360 PSI. RIH TO 8548', P/U WT 26K,S/0 WT 16 K RIH 2.6 FPM TO 8691'TAG AND PRESSURE UP TO 700 PSI. THE CTDS SYSTEM WAS INCORRECT,THE EOP SYSTEM WAS CORRECT. CORRECTED CTDS FROM 8690.58'TO 8548'. Printed 3/8/2011 4:02:08PM North America -ALASKA- BP Page 9 of 11 Operation Summary Report Common Well Name: 18-13 AFE No Event Type: COM-ONSHORE(CON) Start Date:2/6/2011 End Date:2/13/2011 X3-00Y9J-C(1,305,200.00) i Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM 'Rig Release:2/14/2011 Rig Contractor.NORDIC CALISTA UWI:500292175600 Active Datum:24: 13 11/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) _ (ft) 19:10 - 00:00 4.83 CASING P RUNPRD STING INTO DEPLOYMENT SLEEVE AT 8,548', SEE PRESSURE INCREASE. STACK 10K TO 8558'. P/U 26K TO BREAK OVER AT 8552,SPACE OUT 1'AND PAINT FLAG AT 8551'. PU 20'AND LAUNCH 5/8"STEEL BALL. PUMPING 1 BPM AT 1030 PSI. PUMPED 22 BBLS 60/40 METHONAL FORM BALL LAUNCH TO BALL OVER GOOSENECK +3BBLS. BALL OVER GOOSENECK AT 19 BBLS, BROUGHT RATE DOWN TO.4 BPM AT 430 PSI. AT 27 BBL AWAY BROUGHT RATE DOWN TO .25 BPM AT 350 PSI. BALL ON SEAT AT 44.3 BBLS. I 1 i STING BACK IN AT 8558'STACKING 10K. P/U TO BREAK OVER AT 8552'SPACE OUT 1' TO 8551'. PRESSURED UP TO 2500 PSI, BLEED OFF THE COIL AND SET DOWN 10K AT 8557'. PU TO NEUTRAL WT AND PT THE BACKSIDE LOW FOR 5 MINUTES AND HIGH FOR 30 MINUTES. i PRESSURED UP TO 270 AND BLED OFF TO 140 IN 4 MINUTES. DOUBLE CHECKED ALL VALVES WERE DOUBLE BLOCKED AND TRIED 5 MORE TIMES. 2/13/2011 00:00 - 00:30 0.50 CASING P RUNPRD TRIED THE HIGH PRESSURE TEST AT 2400P.S1.JNJECTED 3 BPM SEVERAL TIMES. I CALLED SUPERINTENDENT AND DECIDED TO _ PULL LTP AND RUN ANOTHER ONE. 00:30 - 02:45 2.25 CASING N , DFAL ' 8,540.00 RUNPRD PULL LTP OUT OF HOLE. LESS THAN 70 FPM,.9 BPM DOWN KILL LINE AND HELD 200 PSI BACK PRESSURE TO PREVENT SWABBING. - 02:45 - 03:00 0.25 CASING N DFAL 8,540.00 RUNPRD CT AT SURFACE. FLOW CHECK THE WELL. 03:00 - 03:30 0.50 CASING N DFAL 8,540.00 RUNPRD SB INJECTOR AND LD LTP RUNNING BHA#12 (CTC, QUICK CONNECT,2 JTS 2-1/16"CSH, 3/4"HYD DISCONNECT, LTP RUNNING TOOL WITH 5/8"BALL SEAT,10'SPACER PUP AND SEAL ASSEMBLY). LOOKED AT KB LTP AND IT STILL LOOKED GOOD.WILL TAKE TO SHOP AND INSPECT. 03:30 - 06:00 2.50 CASING P RUNPRD RUNNING 1"CSH IN HOLE FORM THE DERRICK. LAY 1"CSH DOWN IN THE PIPE SHED. 06:00 - 07:00 1.00 CASING N DFAL 8,540.00 RUNPRD WAIT ON TOOLS TO ARRIVE FROM BAKER SHOP. 07:00 - 07:30 0.50 CASING N DFAL 8,540.00 RUNPRD PJSM.LOAD SECOND 4-1/2"KB LTP AND RUNNING EQUIPMENT ONTO RIG FLOOR. 07:30 - 08:30 1.00 CASING N DFAL 8,540.00 RUNPRD M/U 4-1/2"LTP BHA,MULE SHOE,3"SEAL ,ASSEMBLY., LOCATOR,10'PUP, LTP, !RUNNING TOOL, X/0, HYD. DISC.,X/O. OPEN MASTER VALVE ON TREE. M/U 2 JOINTS 2-1/16"CSH,X/O, BAKER DISC. M/U INJECTOR. CONFIRM NO AREA OF COIL 'OVER 50%OF FATIGUE LIFE. Printed 3/8/2011 4:02:08PM North America -ALASKA- BP Page 10 of 11 Operation Summary Report Common Well Name: 18-13 AFE No Event Type: COM-ONSHORE(CON) Start Date:2/6/2011 End Date:2/13/2011 X3-00Y9J-C(1,305,200.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release:2/14/2011 Rig Contractor:NORDIC CALISTA UWI:500292175600 Active Datum:24: 13 11/3/1987 00:01 @54.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 11:00 2.50 CASING N DFAL 8,540.00 RUNPRD ESTABLISH CIRCULATION. RIH WITH LTP 80 FPM.23 BPM,170 PSI. LOSING FLUID-3 BPH RIH TO 8500'P/U WT 26 K, S/O WT 16 K RIH 10 FPM TO 8544'MD TO SEE PRESSURE INCREASE TO 450 PSI. 11:00 - 13:00 2.00 CASING N DFAL 8,540.00 RUNPRD STING INTO DEPLOYMENT SLEEVE AT 8546' PER EOP DEPTH,SEE PRESSURE INCREASE TO 400 PSI. TAG UP AND STACK 10K AT 8552', CORRECT DEPTH TO LINER HARDWARE- 8546.3' P/U TO 8540 FOR BREAK OVER. PU 13'AND RIH TO CONFIRM TAG. STACK OUT 8K AT TOL-8540, PU 20', ROLL PUMPS 0.25 BPM SO AGAIN AND STILL TAG TOP OF LINER, BUT FELL INTO LINER TOP IN 2 SECONDS PRESSURE INCREASE&TAG UP AGAIN AT 8546-STACK 10K. PU TO BREAK OVER PLUS 3 FEET AND RETAG OK. PU 1 FOOT AND PAINT FLAG. P/U WT 26 K. P/U TO BALL DROP DEPTH 8502', LAUNCH 5/8"BALL. PUMP 4 BBLS H2O THEN 60-40 MEOH. 1.25 BPM,1050 PSI-1600 PSI(1600 @ 28 BBLS), BALL OVER GOOSENECK AT 21 BBLS REDUCE RATE TO 0.45 BPM 400 PSI ICP AT 28 BBLS, PRESSURE CLIMBING AS 60-40 MEOH TRAVELS DOWN HOLE. CYCLE PUMPS AT 47.5 BBLS AWAY AND WORK PIPE TO SEAT BALL. 750 PSI FCP PRIOR TO BALL ON SEAT, SEE 1000 PSI W/BALL ON SEAT AT 56.7 BBLS. COIL VOLUME 41.2 BBLS. STING BACK IN TO 8546'STACKING 10K, P/U TO BREAKOVER PLUS 1.5', P/U WT 30K. 13:00 - 13:15 0.25 CASING N DFAL 8,540.00 RUNPRD PRESSURE UP TO 1800 PSI TO SET PACKER ELEMENTS. HOLD PRESSURE AT 1800 PSI FOR 5 MINUTES. STACK OUT 10K ON LINER TOP PACKER,NO MOVEMENT. 13:15 - 14:30 1.25 CASING N DFAL 8,540.00 RUNPRD RIG UP TO PRESSURE TEST PACKER. PRESSURE UP BACK SIDE TO 250 PSI LOW FOR 5 MIN. NO BLEED OFF. GOOD TEST. CONTINUE TO PRESSURE UP TO 2440 PSI. PRESSURE BLED OFF 45 PSI IN FIRST 15 MINUTES,3 PSI IN SECOND 15 MINUTES. PRESSURE UP ON COIL TO 4100 PSI AND SHEAR OFF KB LTP. 14:30 - 16:30 2.00 CASING P RUNPRD POOH,POP OFF WELL AND STAND BACK INJECTOR. 16:30 - 17:30 I 1.00 CASING P RUNPRD LD BHA#13(CTC,QUICK CONNECT,2 JTS 2-1/16"CSH,3/4"HYD DISCONNECT,LTP RUNNING TOOL WITH 5/8"BALL SEAT,10' SPACER PUP AND SEAL ASSEMBLY). Printed 3/8/2011 4.02:08PM North America-ALASKA- BP Page 11 of 11 Operation Summary Report Common Well Name: 18-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:2/6/2011 End Date:2/13/2011 X3-00Y9J-C(1,305,200.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 11/3/1987 12:00:00AM Rig Release:2/14/2011 Rig Contractor:NORDIC CALISTA UWI:500292175600 Active Datum:24:1311/3/1987 00:01 (054.80ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 19:00 1.50 CASING P RUNPRD MU AND RIH TO 2500'WITH FREEZE PROTECT BHA#14(JET SWIRL NOZZLE, DUAL BPV XO TO CTC). WITH 40 BBLS 60/40 METHANOL IN COIL LAID IN 38BBLS,2 BBLS LEFT IN COIL.POOH. 19:00 - 19:30 0.50 CASING P RUNPRD FLOW CHECK WELL. 19:30 - 20:00 0.50 CASING P RUNPRD POP OFF WELL AND STAND BACK INJECTOR. LD BHA#14(JET SWIRL NOZZLE,DUAL BPV XO TO CTC). 20:00 - 20:30 0.50 CASING P RUNPRD PJSM TO PU AND TEST LUBRICATOR THEN SET BPV. 20:30 - 22:00 1.50 CASING P RUNPRD BRING LUBRICATOR UP TO FLOOR AND RU. GREASE TREE VALVES. CLOSE MASTER VALVE AND SSV. PT TO 250 AND 3500 PSI FOR 5 MINUTES EACH AND CHART. SET BPV. 22:00 - 00:00 2.00 CASING P RUNPRD PT MV AND SSV 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. RIG DOWN LUBRICATOR. RELEASE RIG AT 24:00. Printed 3/8/2011 4:02:08PM WWI BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 18 18-13 500292175600 18-13C Survey: MWD Survey Report - Geographic 07 February, 2011 Qbp Milli BAKER MOMS Survey Report- Geographic 0 bp 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-13 Project: Prudhoe Bay ND Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Site: PB DS 18 MD Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Well: 18-13 North Reference: True Wellbore: 18-13C Survey Calculation Method: Minimum Curvature Design: 18-13C Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 18,TR-11-14 1 Site Position: Northing: 5,959,213.15ft Latitude: 70°17'35.252 N From: Map Easting: 691,583.44ft Longitude: 148°26'55.555 W' Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.46° Well 18-13 API No 500292175600 Well Position +N/-S 0.00 ft Northing: 5,960,832.76 ft Latitude: 70°17'51.039 N +E/-W 0.00 ft Easting: 692,133.18 ft Longitude: 148°26'38.331 W' Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 16.00 ft Wellbore 18-13C API No 500292175603 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 1/24/2011 21.86 81.01 57,664 Design 18-13C Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,290.97 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) r) 38.80 0.00 0.00 109.19 Survey Program Date: 2/7/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 2,706.80 6,880.80 Survey#1 MWD(18-13PB1) MWD MWD-Standard 7,265.80 9,155.80 Survey#1 MWD(18-13PB2) MWD MWD-Standard 9,202.00 9,290.97 MWD(18-13BPB1) MWD MWD-Standard 9,299.20 12,650.00 MWD(18-13C) MWD MWD-Standard 2/7/2011 9:30.01 AM Page 2 COMPASS 2003.16 Build 73 AWER BHUG S Survey Report-Geographic 0 bp 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-13 Project: Prudhoe Bay ND Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Site: PB DS 18 MD Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Well: 18-13 North Reference: True Wellbore: 18-13C Survey Calculation Method: Minimum Curvature Design: 18-13C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,290.97 48.37 127.90 8,368.28 -1,881.18 2,270.31 5,959,010.34 694,450.70 70°17'32.534 N 148°25'32.169 W TIP 9,299.20 47.38 127.45 8,373.80 -1,884.92 2,275.14 5,959,006.74 694,455.63 70°17'32.498 N 148°25'32.029 W, KOP 9,330.02 45.78 118.98 8,395.01 -1,897.17 2,293.82 5,958,994.96 694,474.61 70°17 32.377 N 148°25'31.484 W, 9,359.64 42.86 110.32 8,416.22 -1,905.82 2,312.58 5,958,986.79 694,493.58 70°17'32.292 N 148°25'30.938 W 9,379.20 42.38 104.30 8,430.61 -1,909.76 2,325.21 5,958,983.18 694,506.31 70°17'32.253 N 148°25'30.570 W 9,405.88 39.76 100.37 8,450.73 -1,913.52 2,342.32 5,958,979.86 694,523.51 70°17'32.216 N 148°25'30.071 W 9,435.82 38.83 91.59 8,473.92 -1,915.51 2,361.13 5,958,978.36 694,542.37 70°17'32.196 N 148°25'29.523 W 9,464.80 39.94 82.48 8,496.34 -1,914.54 2,379.45 5,958,979.79 694,560.66 70°17'32.206 N 148°25'28.989 W 9,497.24 40.49 85.48 8,521.11 -1,912.35 2,400.28 5,958,982.51 694,581.42 70°17'32.227 N 148°25'28.382 W 9,525.66 42.00 83.81 8,542.48 -1,910.60 2,418.93 5,958,984.74 694,600.02 70°17'32.245 N 148°25'27.838 W 9,557.50 45.61 77.30 8,565.47 -1,906.94 2,440.64 5,958,988.95 694,621.63 70°17'32.280 N 148°25'27.206 W 9,590.06 48.10 68.07 8,587.76 -1,899.85 2,463.26 5,958,996.62 694,644.05 70°17'32.350 N 148°25'26.547 W 9,614.82 49.49 63.46 8,604.07 -1,892.20 2,480.23 5,959,004.70 694,660.83 70°17'32.425 N 148°25'26.052 W 9,652.38 51.75 54.94 8,627.93 -1,877.33 2,505.11 5,959,020.20 694,685.31 70°17'32.571 N 148°25'25.327 W'. 9,680.34 56.26 48.17 8,644.37 -1,863.25 2,522.78 5,959,034.72 694,702.62 70°17'32.710 N 148°25'24.812 W 9,699.44 58.99 43.20 8,654.60 -1,851.98 2,534.31 5,959,046.28 694,713.85 70°17'32.821 N 148°25'24.476 W 9,725.68 62.19 36.96 8,667.49 -1,834.50 2,549.00 5,959,064.14 694,728.09 70°17'32.993 N 148°25'24.047 W 9,761.90 67.14 31.61 8,683.00 -1,807.45 2,567.40 5,959,091.64 694,745.79 70°17 33.258 N 148°25'23.511 W 9,791.64 71.82 35.68 8,693.42 -1,784.29 2,582.83 5,959,115.19 694,760.63 70°17'33.486 N 148°25'23.061 W 9,820.46 75.95 41.15 8,701.42 -1,762.61 2,600.04 5,959,137.30 694,777.27 70°17'33.699 N 148°25'22.559 W 9,850.32 77.99 47.56 8,708.16 -1,741.83 2,620.37 5,959,158.59 694,797.06 70°17'33.904 N 148°25'21.966 W 9,880.62 80.70 54.30 8,713.77 -1,723.08 2,643.47 5,959,177.92 694,819.68 70°17'34.088 N 148°25'21.293 W 9,910.54 84.38 60.97 8,717.66 -1,707.22 2,668.52 5,959,194.42 694,844.31 70°17'34.244 N 148°25'20.563 W 9,945.36 90.58 68.05 8,719.19 -1,692.27 2,699.88 5,959,210.17 694,875.28 70°17'34.391 N 148°25'19.649 W 9,976.72 90.46 64.62 8,718.91 -1,679.69 2,728.60 5,959,223.48 694,903.67 70°17'34.514 N 148°25'18.812 W'. 10,004.88 90.31 59.55 8,718.72 -1,666.51 2,753.48 5,959,237.29 694,928.20 70°17'34.644 N 148°25'18.087 W 10,034.94 92.30 55.13 8,718.03 -1,650.29 2,778.77 5,959,254.14 694,953.06 70°17'34.803 N 148°25'17.349 W 10,066.02 90.89 52.47 8,717.17 -1,631.95 2,803.84 5,959,273.12 694,977.65 70°17'34.984 N 148°25'16.618 W 10,096.12 90.40 49.62 8,716.83 -1,613.03 2,827.24 5,959,292.64 695,000.56 70°17'35.170 N 148°25'15.936 W 10,125.06 90.12 48.00 8,716.70 -1,593.97 2,849.02 5,959,312.24 695,021.85 70°17'35.357 N 148°25'15.301 W 10,155.10 88.74 51.78 8,717.00 -1,574.62 2,871.99 5,959,332.17 695,044.31 70°17'35.547 N 148°25'14.632 W 10,185.10 89.11 56.42 8,717.56 -1,557.04 2,896.28 5,959,350.37 695,068.14 70°17'35.720 N 148°25'13.924 W 10,208.74 89.26 60.72 8,717.90 -1,544.71 2,916.44 5,959,363.20 695,087.98 70°17'35.841 N 148°25'13.336 W 10,245.26 89.14 66.31 8,718.41 -1,528.44 2,949.11 5,959,380.31 695,120.23 70°17'36.001 N 148°25'12.384 W 10,275.16 89.17 70.61 8,718.85 -1,517.46 2,976.92 5,959,391.99 695,147.74 70°17'36.109 N 148°25'11.573 W' 10,305.00 89.54 74.85 8,719.18 -1,508.60 3,005.40 5,959,401.57 695,175.99 70°17'36.196 N 148°25'10.743 W 10,335.04 89.20 75.42 8,719.51 -1,500.90 3,034.43 5,959,410.02 695,204.81 70°17'36.272 N 148°25'9.897 W 10,366.84 90.92 71.07 8,719.48 -1,491.73 3,064.88 5,959,419.96 695,235.01 70°17'36.362 N 148°25'9.009 W 10,395.16 90.92 67.32 8,719.03 -1,481.68 3,091.34 5,959,430.69 695,261.20 70°17'36.460 N 148°25'8.238 W 10,426.90 91.13 62.80 8,718.46 -1,468.30 3,120.11 5,959,444.79 695,289.62 70°17'36.592 N 148°25'7.399 W 10,462.84 90.21 58.72 8,718.04 -1,450.75 3,151.46 5,959,463.14 695,320.51 70°17'36.764 N 148°25'6.485 W 10,495.34 89.72 54.22 8,718.06 -1,432.80 3,178.55 5,959,481.77 695,347.13 70°17'36.941 N 148°25'5.696 W 10,528.62 89.20 49.44 8,718.37 -1,412.24 3,204.70 5,959,502.99 695,372.75 70°17'37.143 N 148°25'4.933 W 10,570.38 89.82 44.51 8,718.73 -1,383.76 3,235.22 5,959,532.25 695,402.52 70°17'37.423 N 148°25'4.044 W 10,601.94 89.57 41.44 8,718.90 -1,360.67 3,256.73 5,959,555.87 695,423.44 70°17'37.650 N 148°25'3.416 W 10,635.74 88.22 43.78 8,719.55 -1,335.80 3,279.61 5,959,581.32 695,445.67 70°17'37.894 N 148°25'2.749 W 10,660.30 88.50 47.52 8,720.25 -1,318.64 3,297.16 5,959,598.92 695,462.77 70°17'38.063 N 148°25'2.238 W 10,691.84 91.87 54.06 8,720.15 -1,298.72 3,321.58 5,959,619.46 695,486.68 70°17'38.259 N 148°25'1.526 W 10,720.06 90.77 57.63 8,719.50 -1,282.88 3,344.92 5,959,635.89 695,509.61 70°17'38.415 N 148°25'0.845 W 10,755.82 91.14 63.96 8,718.90 -1,265.44 3,376.12 5,959,654.12 695,540.34 70°17'38.586 N 148°24'59.936 W 10,780.32 90.80 68.35 8,718.49 -1,255.54 3,398.52 5,959,664.59 695,562.48 70°17'38.683 N 148°24'59.283 W 10,809.78 89.79 72.52 8,718.34 -1,245.68 3,426.27 5,959,675.15 695,589.97 70°17'38.780 N 148°24'58.474 W 10,845.24 90.00 77.47 8,718.40 -1,236.50 3,460.51 5,959,685.20 695,623.96 70°17'38.870 N 148°24'57.476 W 2/7/2011 9:30:01AM Page 3 COMPASS 2003.16 Build 73 N+a� BAKER MIMES Survey Report- Geographic 0 bp [NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-13 Project: Prudhoe Bay TVD Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Site: PB DS 18 MD Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Well: 18-13 North Reference: True Wellbore: 18-13C Survey Calculation Method: Minimum Curvature Design: 18-13C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,875.16 88.19 82.25 8,718.87 -1,231.24 3,489.95 5,959,691.22 695,653.26 70°17'38.922 N 148°24'56.618 W 10,905.12 89.42 86.30 8,719.50 -1,228.25 3,519.74 5,959,694.97 695,682.96 70°17'38.951 N 148°24'55.749 W 10,934.98 90.31 90.42 8,719.57 -1,227.40 3,549.59 5,959,696.58 695,712.77 70°17'38.959 N 148°24'54.880 W 10,953.20 90.64 94.39 8,719.42 -1,228.16 3,567.79 5,959,696.29 695,730.98 70°17'38.952 N 148°24'54.349 W 10,996.66 90.00 100.03 8,719.17 -1,233.61 3,610.88 5,959,691.94 695,774.21 70°17'38.898 N 148°24'53.093 W 11,024.94 87.30 104.07 8,719.84 -1,239.51 3,638.52 5,959,686.75 695,801.99 70°17'38.840 N 148°24'52.288 W 11,055.58 88.80 108.72 8,720.88 -1,248.15 3,667.89 5,959,678.86 695,831.56 70°17'38.755 N 148°24'51.432 W 11,085.44 90.80 111.89 8,720.99 -1,258.51 3,695.89 5,959,669.22 695,859.82 70°17'38.653 N 148°24'50.616 W 11,114.68 90.21 116.40 8,720.73 -1,270.47 3,722.57 5,959,657.95 695,886.79 70°17'38.535 N 148°24'49.839 W 11,144.92 90.55 122.67 8,720.53 -1,285.37 3,748.86 5,959,643.73 695,913.45 70°17'38.388 N 148°24'49.073 W 11,170.40 87.48 125.98 8,720.97 -1,299.73 3,769.90 5,959,629.91 695,934.85 70°17'38.247 N 148°24'48.460 W 11,205.20 85.45 130.80 8,723.11 -1,321.29 3,797.11 5,959,609.05 695,962.60 70°17'38.035 N 148°24'47.667 W 11,243.14 87.20 134.65 8,725.55 -1,346.98 3,824.92 5,959,584.09 695,991.06 70°17'37.782 N 148°24'46.857 W 11,274.94 90.03 136.27 8,726.32 -1,369.63 3,847.21 5,959,562.01 696,013.92 70°17'37.559 N 148°24'46.207 W 11,305.16 89.05 135.93 8,726.56 -1,391.41 3,868.17 5,959,540.78 696,035.43 70°17'37.345 N 148°24'45.597 W 11,335.32 89.02 131.76 8,727.07 -1,412.29 3,889.91 5,959,520.46 696,057.69 70°17'37.139 N 148°24'44.964 W 11,365.08 88.87 127.97 8,727.61 -1,431.36 3,912.75 5,959,501.98 696,081.01 70°17'36.952 N 148°24'44.298 W 11,400.54 87.97 123.59 8,728.59 -1,452.08 3,941.50 5,959,482.01 696,110.28 70°17'36.748 N 148°24'43.461 W 11,439.58 88.77 117.78 8,729.70 -1,471.99 3,975.04 5,959,462.97 696,144.32 70°17'36.552 N 148°24'42.484 W 11,461.78 86.56 117.53 8,730.61 -1,482.28 3,994.69 5,959,453.18 696,164.22 70°17'36.450 N 148°24'41.911 W 11,497.14 86.81 113.45 8,732.65 -1,497.47 4,026.55 5,959,438.81 696,196.45 70°17'36.301 N 148°24'40.983 W 11,528.00 87.61 109.57 8,734.16 -1,508.77 4,055.22 5,959,428.25 696,225.40 70°17'36.190 N 148°24'40.148 W 11,555.38 88.44 105.85 8,735.10 -1,517.09 4,081.28 5,959,420.59 696,251.67 70°17'36.108 N 148°24'39.388 W 11,585.48 91.07 102.92 8,735.23 -1,524.57 4,110.43 5,959,413.87 696,281.00 70°17'36.034 N 148°24'38.539 W 11,617.08 91.29 98.64 8,734.58 -1,530.48 4,141.46 5,959,408.75 696,312.16 70°17'35.976 N 148°24'37.634 W 11,645.76 90.03 95.24 8,734.25 -1,533.94 4,169.92 5,959,406.02 696,340.71 70°17'35.941 N 148°24'36.805 W 11,674.76 90.80 91.65 8,734.04 -1,535.68 4,198.86 5,959,405.02 696,369.68 70°17'35.924 N 148°24'35.962 W 11,704.74 89.42 87.12 8,733.98 -1,535.36 4,228.83 5,959,406.10 696,399.63 70°17'35.927 N 148°24'35.088 W 11,737.62 89.82 83.47 8,734.20 -1,532.66 4,261.60 5,959,409.64 696,432.31 70°17'35.953 N 148°24'34.133 W 11,766.18 89.42 79.80 8,734.39 -1,528.51 4,289.85 5,959,414.51 696,460.45 70°17'35.994 N 148°24'33.310 W 11,794.58 89.66 77.08 8,734.62 -1,522.82 4,317.67 5,959,420.91 696,488.11 70°17'36.050 N 148°24'32.499 W 11,834.88 88.65 83.45 8,735.21 -1,516.01 4,357.36 5,959,428.73 696,527.61 70°17'36.117 N 148°24'31.342 W 11,864.08 89.85 87.23 8,735.59 -1,513.64 4,386.46 5,959,431.85 696,556.64 70°17'36.140 N 148°24'30.494 W 11,895.14 88.10 93.44 8,736.15 -1,513.82 4,417.49 5,959,432.46 696,587.67 70°17'36.138 N 148°24'29.590 W'. 11,925.28 88.43 98.47 8,737.06 -1,516.94 4,447.45 5,959,430.10 696,617.69 70°17'36.107 N 148°24'28.717 W 11,955.12 88.43 103.72 8,737.88 -1,522.68 4,476.71 5,959,425.11 696,647.09 70°17'36.050 N 148°24'27.864 W 11,984.98 85.42 107.95 8,739.48 -1,530.81 4,505.39 5,959,417.72 696,675.96 70°17'35.970 N 148°24'27.028 W 12,014.94 85.98 112.76 8,741.73 -1,541.20 4,533.39 5,959,408.05 696,704.22 70°17'35.868 N 148°24'26.213 W 12,037.12 85.03 115.70 8,743.47 -1,550.28 4,553.55 5,959,399.50 696,724.60 70°17'35.779 N 148°24'25.625 W 12,067.18 85.54 120.26 8,745.94 -1,564.33 4,580.00 5,959,386.13 696,751.40 70°17'35.640 N 148°24'24.855 W 12,096.92 87.36 123.19 8,747.78 -1,579.93 4,605.24 5,959,371.17 696,777.03 70°17'35.487 N 148°24'24.119 W 12,127.34 88.28 126.52 8,748.94 -1,597.30 4,630.18 5,959,354.44 696,802.41 70°17'35.316 N 148°24'23.393 W 12,157.08 89.45 130.98 8,749.53 -1,615.91 4,653.36 5,959,336.44 696,826.06 70°17'35.132 N 148°24'22.717 W 12,187.10 89.75 131.91 8,749.74 -1,635.78 4,675.87 5,959,317.15 696,849.06 70°17'34.937 N 148°24'22.062 W 12,226.82 89.69 127.39 8,749.93 -1,661.12 4,706.44 5,959,292.60 696,880.27 70°17'34.687 N 148°24'21.171 W 12,257.94 88.46 124.83 8,750.44 -1,679.45 4,731.58 5,959,274.92 696,905.86 70°17'34.507 N 148°24'20.439 W 12,292.18 88.22 121.28 8,751.43 -1,698.12 4,760.26 5,959,256.99 696,935.01 70°17'34.323 N 148°24'19.604 W 12,322.86 89.94 118.06 8,751.92 -1,713.30 4,786.91 5,959,242.50 696,962.04 70°17'34.174 N 148°24'18.827 W 12,352.08 90.43 114.71 8,751.83 -1,726.29 4,813.08 5,959,230.19 696,988.53 70°17'34.046 N 148°24'18.065 W 12,379.74 88.43 111.04 8,752.10 -1,737.03 4,838.56 5,959,220.09 697,014.28 70°17 33.940 N 148°24'17.322 W 12,417.12 89.42 104.90 8,752.80 -1,748.56 4,874.09 5,959,209.48 697,050.09 70°17'33.826 N 148°24'16.287 W 12,441.78 90.34 105.51 8,752.86 -1,755.03 4,897.89 5,959,203.63 697,074.04 70°17'33.763 N 148°24'15.594 W 12,467.30 91.32 102.59 8,752.49 -1,761.22 4,922.64 5,959,198.07 697,098.94 70°17'33.702 N 148°24'14.873 W 12,497.14 89.66 99.48 8,752.23 -1,766.93 4,951.92 5,959,193.11 697,128.36 70°17'33.645 N 148°24'14.019 W 12,527.08 92.15 97.00 8,751.76 -1,771.22 4,981.54 5,959,189.58 697,158.08 70°17'33.603 N 148°24'13.156 W 2/7/2011 9:30:01 AM Page 4 COMPASS 2003.16 Build 73 Mall , BAKER HUGHES Survey Report-Geographic 0 bp LNTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-13 Project: Prudhoe Bay TVD Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Site: PB DS 18 MD Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drillinc Well: 18-13 North Reference: True Wellbore: 18-13C Survey Calculation Method: Minimum Curvature Design: 18-13C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 12,557.98 92.67 94.60 8,750.46 -1,774.34 5,012.25 5,959,187.24 697,188.86 70°17'33.572 N 148°24'12.261 W 12,586.76 95.16 92.25 8,748.49 -1,776.06 5,040.91 5,959,186.26 697,217.55 70°17'33.555 N 148°24'11.426 W 12,600.70 96.15 90.34 8,747.12 -1,776.37 5,054.78 5,959,186.30 697,231.42 70°17'33.552 N 148°24'11.022 W 12,650.00 96.15 90.34 8,741.84 -1,776.66 5,103.80 5,959,187.26 697,280.43 70°17'33.549 N 148°24'9.594 W TD 2/7/2011 9:30:01 AM Page 5 COMPASS 2003.16 Build 73 WELLHEAD= 11'FMC 1 ö-1 _{ V - 1/2"CHROME TBG*"*ORIGINAL,"A"&"B" ACTUATOR= BAKER C PJC DI FT . .BORES NOT SHOWN BELOW WHIPSTOCK'S"` KB. ELEV= 48' X BF*..ELEV = KOP= 3450' 2110' -14-1/2"HES X NIP, ID=3.813" Max Angle= 96°@ 12650' 20"CONDUCTOR, 110' ' GAS LIFT MANDRELS Datum MD= N/A ID=? ST MD TVD DEV TYPE VLV LTCH PORT DATE Datum TVD= 8800'SS 3 3009 3008 6 MMG DOME RK 16 02/28/11 13-3/8"CSG, 68#,K-55 BUTT, ID= 12.415" H 111' 2 6225 6009 25 MMG SO RK 20 02/28/11 1 8479 7902 55 MMG DMY RK 0 10/13/07 13-3/8"CSG,724,L-80 BUTT, ID=12.347" H 4482' ' 8518' -4-1/2"HES X NIP, ID=3.813" 2-3/8"KB LINER TOP PKR, ID=2.36" 8524' '' 3.70"BKR DEPLOY SLEEVE, ID=3.00" - 8540' 1 1 8548' H9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" 2.70"BTT DEPLOY SLEEVE, ID= 1.78" -I 8456' ' H m 8583' -14-1/2"HES X NIP, ID=3.813"(BEHIND CT LNR) Minimum ID = 1.78" @ 8546' 8594' - 3.70" DEPLOY SLV, ID=3.00" 2.70" BTT DEPLOY SLEEVE 8604' H 3-1/2" HOWCO X NIP, ID=2.81" 4-1/2"TBG, 12.5#, 13CR-80 VAM TOP, H 8635' I .0152 bpf, ID=3.958" 8614' H4-1/2"HES X NIP, ID=3.813" 4-1/2"TBG STUB(11/03/07) - 8632' 8644' -1 9-5/8"X 4-1/2"UNIQUE OVERSHOT 8662' -19-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" MN 8696' -14-1/2"HES X NIP, ID=3.813" BEHIND 9-518"X 7"BKR ZXP LTP w/6'TIEBK SLV H 8698' l &HMC LNR HGR, ID=6.250" 8718' -14-1/2"WLEG, ID=3.958" CT LNR (;T x=; l 8718' -7"X 4-1/2"XO, ID=3.938" 4-1/2"TBG, 12.6#L-80 IBT, .0152 bpf, ID=3.958" H 8718' n;1 8805' 10'TIW TIEACK SLV ZIA w/ 9-5/8"X 7"LNR HGR, ID=? 9-5/8"CSG,47#, L-80 BUTT, ID=8.681" -I 9103' 3-1/2"LNR, 9.2#, L-80 STL, .0087 bpf, ID=2.992" - 9142' 4-1/2"LNR, 12.64, L-80 IBT, .0152 bpf, ID=3.958" - -9202 9142' H 3-1/2"X 3-3/16"XO, ID=2.786" 7"LNR, 29#, L-80 BTC, .0371 bpf, ID=6.184" H -9202 MILLOUT WINDOW(18-13B) 9202'-9211' 4-1/2"MONOBORE WHIPSTOCK(11/08/07) -I 9202' I 3-3/16"BKR WHIPSTOCK (01/10/11) H 9300' w/2 RA TAGS @ 9305' 3-3/16" MILLOUT WINDOW(18-13C)9300'-9306' 3-3/16"LNR, 6.2#, L-80 TCII, .0076 bpf, ID=2.80" H -9306 PERFORATION SUMMARY 4111111111114%REF LOG: MCNL GR ON 02/10/11 ANGLE AT TOP PERF: 86'@ 11210' ` Note: Refer to Production DB for historical perf data ` SIZE SPF INTERVAL Opn/Sqz DATE ` 1.56" 6 11210- 11530 0 02/12/11 ` 1�,�3G 1.56" 6 11590- 11650 0 02/12/11 D 1.56" 6 11710- 11880 0 02/12/11 1.56" 6 11960- 12330 0 02/12/11 PBTD ± 12605' AO• AI 1.56" 6 12450- 12600 0 02/12/11 0 2-3/8"LNR,4.7#, L-80 STL, 12641' (Q,13 .0039 bpf, ID=1.995" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/06/87 ROWAN 41 ORIGINAL COMPLETION 03/04/11 JLJ/PJC GLV 0/0(02/28/11) WELL: 18-13C 02/25/98 D9 SIDETRACK(18-13A) 03/09/11 TH/PJC WHIPSTOCK CORRECTION PERMIT No: 2101860 01/14/07 016 RWO API No: 50-029-21756-03 12/09/07 NORDIC 2 CTD SIDETRACK(18-13B) SEC 19,T11 N, R15E, 1045'FNL&371'FWL 02/13/11 NORDIC 1 CTD SIDETRACK(18-13C) 03/04/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) mVmv 3.2.^'D oo'?vr NiT 61f m s o m E qi p 9 agRtomos mx*ozao`-?<F* f xmw m and DO Nom-.^�n0)."NN m 3 o W IIIV f0)w,Ow7C�*>r r 33 N. - oxx xD LLU mmmm'D D o m 00888,08800 0 0 8 O,0 j 8 O O O 8N N+Om.1mmmA 2 2 mvmmmrnmj3 G) 0D A7UmmmC)O0 D 3000;;;33:r- ZD CCC222m�. 7 000.<.<0m m (7�0 C .D222yr pn�nU 7 -"" 00„›....... 4mmm2 o , 0000mm ml t Z 1Ummm1`7m5.07.v r O °�,�o,731 a-Z'a--kA 0 l)C* d ' t o 4! P3 t 4 00000000022 N' NNNN mo+uNm+00(00W .Lr gi D. q *C. In D Eilff Cyt/ o o O I ,� o ; o 130 .0 xgz V DNDDw m ouffm_ ''_ �c __ 0 g*- ;.; 0m09' sA4K0> _ mm �� om xDm0m ry m S _ N MI y ' 0 0C ,9 3 3 ; 17,1!::.) ,,;) ;'-' ...) -17 i.J : 0 w o m scirgE orF 'U I SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-13C BP Exploration (Alaska), Inc. Permit No: 210-186 Surface Location: 1045' FNL, 371' FWL, SEC. 19, T11N, R15E, UM Bottomhole Location: 2818' FNL, 285' FWL, SEC. 20, T11N, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 0,/ Daniel T. Seamount, Jr. Chair DATED this Z7day of December, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA REC I V hWte ALAS OIL AND GAS CONSERVATION COMM 'ON DEC 1 6 2010 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil&Gas Cons.Com fli$$Ion la.Type of work: lb.Proposed Well Class: ®Development Oil 0 Service-Winj 0 Single Zone 1 c. Specify if vittied for: ❑ Drill Z Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 - PBU 18-13C 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12400' TVD 8674'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028321 1045'FNL,371'FWL,SEC. 19,T11N, R15E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3111'FNL,2914'FWL,SEC. 19,T11N, R15E,UM January 10,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2818'FNL,285'FWL,SEC.20,T11N, R15E, UM 2560 24,700' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 54.80' feet 15.Distance to Nearest Well Open Surface: x- 692133 y-5960832 Zone- ASP4 GL Elevation above MSL: feet to Same Pool: 400' 16.Deviated Wells: Kickoff Depth: 9320 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3324 Surface: 2444 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 3" 2-3/8" 4.7# L-80 STL 3830' 8570' • 7953' - 12400` 8674'ss 61 sx Class'G' ✓ 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 11550' 8752' 10450' 11509' 8752' None Casing Length Size Cement Volume MD ND Conductor/Structural Surface 110' 20" 1694#Poleset 110' 110' Intermediate 4482' 13-3/8" 3500 sx CS III,600 sx'G',Top Job: 100 sx CS II 4482' 4429' Production 9103' 9-5/8" 930 sx Class'G' 9103' 8263' Liner 942' 7" 500 sx Class'G' 8805'-9202' 8087'-8316' Liner 4399' 4-1/2" 523 sx Class'G' 8698'-9202' 8025'-8316' Liner 2974' 3-1/2"x3-3/16"x2-7/8" 141 sx Class'G' 8572'- 11546' 7954'-8752' Perforation Depth MD ft: rets°'-u 0 Perforation Depth ND ft: 873s'-8738' P ( ) Below Plug`0580'-11510' P ( ) Below Plug 8743'-8752' 20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the f.regoing is true and correct. Contact Matthew Ross,564-4387 Printed Name Jo ;•M e„,rr% Title Engineering Team Leader Prepared By Name/Number Signature •' Phone 564-4711 /Date /27/06 Elizabeth Barker,564-4628 Commission Use Only Permit To Dri API Number: Permit proval Dat : See cover letter for Number: �/0,fes( 50-02921756-03-00 \ ,\i."ari �' D other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbedethane,gas hydrates,or gas contained shales: Er -Y JS� Psi �DP aS Samples Req'd: DYes Other: P tel' �No Mud Log Req'd: ❑ es �No 4 2S-OD /05- ,'rin K l r v' st C H2S Measures: Yes 0 No Directional Survey Req'd: Yes 0 No 1 ��z7 APPROVED BY THE COMMISSION G �0 Date EpleyAPPROVED Form 10-401 Revised 07/2009 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit In Duplicate ORIGINIAI .z.,.. ,Z To: Alaska Oil & Gas Con.,avation Commission From: Matthew Ross 0 b p CTD Engineer Date: December 6, 2010 Re: 18-13C Permit to Drill request Approval is requested for a permit to drill a CTD sidetrack from well 18-13B. 18-13B is a 2007 horizontal CST in Zone lA in the Ivishak. After drilling three plugbacks,the well was finally completed in an area very close to a well with high offtake. The well was brought online in Feb 2008 and started to cycle immediately and the gas rate peaked after the well's first cycle. A Spinner-Temp-Press log was run over the liner lap region in March 2008. It indicated the liner top was not leaking. In May 2008, STP/MCNL/Borax logs were performed to diagnose the source of gas production in 18- 13B, but no channels were identified and no significant point-source entry of gas was found. In Aug 2008,a CIBP was set over 930'of the lower perfs at 10,540' leaving 150'of the upper perfs open. The CIBP was not successful in reducing the gas but did reduce the oil,and the well was once again shut-in for high GOR. The well has been brought online twice in the last two years with high GOR. The well showed no ability to cycle and remains shut-in for high GOR. The proposed plan for well 18-13C is to sidetrack out of the 18-13B 3-3/16"production liner with a Coiled Tubing Drilling rig on or around January 10,2010. The existing perforations will be isolated by the primary cement job after drilling and running liner. The sidetrack will exit the 3-3/16" liner in the Zone 3 and drill a 3" hole in the target zone 1 A sands. `,i pks CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin December 27, 2010). 1. S Pull LTP at 8572' MD. 2. S Dummy WS drift to 9500' MD. Drift 4-1/2"to TOL at 8594' MD for new LTP. 3. F Load&kill well prior to setting WS. Freeze protect well to 2000'MD. 4. E Set 3-3/16"Packer WS at 9300' MD. ✓ P ,$ - Tse .' CHI T ? 5. V PT MV, SV, WV. 6. D Bleed gas lift and production flowlines down to zero and blind flange. 7. 0 Remove wellhouse, level pad. 8. V Set TWC-24hr prior to rig arrival. Rig Work: (scheduled to begin on January 10, 2011) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC. 2. Mill 2.74"window at 9300' MD and 10' of rathole. 3. Drill Build: 3.0" OH, 630' (15°/100). 4. Drill Lateral: 3.0" OH, 2470' (12°/100). T''s 5. Run 2-3/8" solid cemented completion leaving TOL at 8570' MD. P 1b 6. Pump primary cement leaving TOC at 9200' MD, 12.6 bbls of 15.8 ppg liner cmt planned. 7. Cleanout run. 8. Run MCNL/GR/CCL log. 9. Perforate 1300ft. 10. Run 4-1/2" liner top packer and test liner lap to 2,400 psi. 11. Freeze protect well, set BPV and RDMO. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Run generic GLV's. 3. ASRC flowback. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Geo Vis for milling window and drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2-3/8" STL, 4.7 pounds per foot, L-80 solid liner-8570' MD to 12400' MD. • A minimum of 12.6 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9200' MD. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 91.5°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—24,700 ft. • Distance to nearest well within pool—400 ft_to 1 8-12^B Logging • MWD directional, Gamma Ray and resistivity will be run over all of the open hole section. • Cased hole GR/CCUMCNL logs will be run. Anti-Collision Failures • 18-15B—29 ft. ctr-ctr; Shut in due to high GOR/ • 18-28—320 ft ctr-ctr; Shut in due to high GOR • 18-28PB1 —280 ft ctr-ctr; Shut in producer, deep plug set Hazards • Two mapped fault crossings at 9,610' MD and at 10,232' MD. • The maximum recorded H2S level on Drill Site 18 pad was 70 ppm on well 18-18B on 5/22/2010. • Lost circulation risk is considered low for this well due to the planned fault crossing. Reservoir Pressure • The reservoir pressure on 18-13B is expected to be 3324 psi at 8,800'TVDSS. (7.3 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft)to surface is 2444 psi. Matthew Ross CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble ■ 01= c' a ►� z m M�� � � z � x C) U Cl u1 Lo ° 0 C) 00 10 CO Z O) O) - - l'... co O O OCNC r v v 1- CD N 0) 0 0 N 0 °0 V) CO CO 0 Po n ,. Q ✓ 4 .0 n CL O Lo a a w Q U 0 O 0 D a 0 0 a) U a) rn c m N. 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Ba 18A88888gg8888� 8888888888 - o'-'1 CI 0A oENNsvq.,R8mmmE8LN, NrRr N an�mm az 38g88 e$$'8e88 __0 0 Br, co."---------- g o."— uumNNNNF - 'Iom_ G O� n naa o n GR88S 8G2r874:M81gM8988og - '3 E _ ^ fflfgaER- v7 g ti; o o J 0 zAV 1@ Vm^.Nir`2'£.18mmBl $8v-FaSe8t9b48 / wE ��437,4"81-.."-"7,�82'.3. 0.• 4 2sasa ins**%i 4 a§mm A k-- 212 2 ��.�'qq �r1 ER2��GRAFa�Wmms,7, 221 � lrLv ZF. � - N g�ssgMZZW488aWam2;22:2 ms N ISD30 wo V.)888889 000000�^R m^��8 8888898 8 2_4 _m & o '8 i m_-g a § m4ssaaW rs T. s I 4° m.-Nr,fmm^mm��Noaa mm^mmo N (U!/8 o8)gidaU tBoRian ankL mar BP sAICER HUM S Travelling Cylinder Report 0 bp 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 18 MD Reference: 24:13 11/3/1987 00:01 @ 54.80ft(generic drilling rig2; Site Error: 0.00ft North Reference: True Reference Well: 18-13 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 18-13C Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 5 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Lis DS 02 L2-03-L2-03-L2-03 Out of range L2-03A-L2-03A-L2-03A 9,308.50 11,575.00 760.82 232.83 546.36 Pass-Major Risk L2-10-L2-10-L2-10 10,800.00 10,175.00 871.41 360.56 547.26 Pass-Major Risk PB DS 18 18-11 -18-11A-18-11A Out of range 18-11 -18-11 DPN-18-11 DPN Out of range 18-12-18-12-18-12 12,170.41 10,050.00 592.40 446.43 236.12 Pass-Major Risk 18-12-18-12A-18-12A 12,170.41 10,050.00 592.40 447.10 235.61 Pass-Major Risk 18-12-18-12B-18-12B 12,170.41 10,050.00 592.40 447.37 235.40 Pass-Major Risk 18-12-Plan 3,18-12C-Plan 3 12,170.41 10,050.00 592.40 448.00 234.96 Pass-Major Risk 18-13-18-13-18-13 9,303.97 9,300.00 15.98 11.48 11.63 Pass-Major Risk 18-13-18-13A-18-13A 9,297.64 9,300.00 13.97 11.25 9.69 Pass-Major Risk 18-13-18-13B-18-13B 9,350.01 9,350.00 0.87 3.37 -0.94 FAIL-Major Risk 18-13-18-13BPB1 -18-13BPB1 9,350.01 9,350.00 0.87 3.37 -0.94 FAIL-Major Risk 18-13-18-13BPB2-18-13BPB2 9,350.01 9,350.00 0.87 3.37 -0.94 FAIL-Major Risk 18-13-18-13BPB3-18-13BPB3 9,350.01 9,350.00 0.87 3.37 -0.94 FAIL-Major Risk 18-13-18-13PB2-18-13PB2 9,303.97 9,300.00 15.98 11.48 11.63 Pass-Major Risk 18-14-18-14-18-14 9,298.28 9,725.00 1,387.37 238.96 1,148.95 Pass-Major Risk 18-14-18-14A-18-14A 9,296.05 9,700.00 1,341.29 224.58 1,116.69 Pass-Major Risk 18-14-18-14APB1 -18-14APB1 9,296.05 9,700.00 1,341.29 224.23 1,117.04 Pass-Major Risk 18-14-18-14B-18-14B 9,290.97 9,700.00 1,359.11 223.35 1,135.70 Pass-Major Risk 18-14-18-14B-18-148 wp06 9,300.00 9,725.00 1,380.06 223.48 1,156.49 Pass-Major Risk 18-14-18-14C-18-14C 9,290.97 9,700.00 1,359.11 223.37 1,135.69 Pass-Major Risk 18-14_DIMS-18-14-18-14 Out of range 18-14_DIMS-18-14A-18-14A Out of range 18-14_DIMS-18-14B-18-146 Out of range 18-14_DIMS-18-14C-18-14C Out of range 18-15-18-15-18-15 11,375.00 10,975.00 598.98 394.30 204.94 Pass-Major Risk 18-15A-18-15A-18-15A 10,225.00 10,110.00 477.39 155.89 334.47 Pass-Major Risk 18-15B-18-15B-18-15B 10,067.53 10,625.00 29.10 98.71 -67.15 FAIL-Major Risk 18-16-18-16-18-16 Out of range 18-16A-18-16A-18-16A Out of range 18-16B-18-16B-18-16B Out of range 18-22-18-22-18-22 9,290.97 9,650.00 1,130.94 277.47 856.62 Pass-Major Risk 18-22-18-22A-18-22A 9,425.00 10,000.00 940.24 267.14 674.73 Pass-Major Risk 18-24_DIMS-18-24-18-24 Out of range 18-24_DIMS-18-24A-18-24A Out of range 18-24_DIMS-18-24B-18-24B Out of range 18-25-18-25-18-25 12,388.21 10,400.00 820.64 475.72 386.37 Pass-Major Risk 18-25A-18-25A-18-25A 12,384.62 10,375.00 830.68 476.41 399.83 Pass-Major Risk 18-25APB1 -18-25APB1 -18-25APB1 12,384.62 10,375.00 830.68 476.41 399.83 Pass-Major Risk 18-28-18-28-18-28 12,350.00 11,100.00 320.94 476.47 -153.21 FAIL-Major Risk 18-28PB1 -18-28PB1 -18-28PB1 11,425.00 10,150.00 281.71 397.61 -108.47 FAIL-Major Risk 18-29-18-29C-18-29C 12,400.00 11,550.00 1,380.24 356.60 1,133.87 Pass-Major Risk 18-32-18-32-18-32 10,870.41 9,625.00 987.80 323.92 671.64 Pass-Major Risk 18-32-18-32A-18-32A 10,870.41 9,625.00 987.80 324.23 671.28 Pass-Major Risk 18-32-18-32A-Plan#103 10,870.41 9,625.00 987.80 324.21 671.31 Pass-Major Risk 18-32-18-328-18-326 11,025.00 10,225.00 746.12 350.03 398.26 Pass-Major Risk 18-33-18-33-18-33 Out of range 18-33-18-33A-18-33A Out of range 18-33-18-33APB1 -18-33APB1 Out of range 18-34-18-34-18-34 11,325.00 9,850.00 656.44 383.35 283.44 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 11/30/2010 4:56:26PM Page 3 of 72 COMPASS 2003.16 Build 73 ot 0000 vigil 1 iv 02F.H120AWURWM --4,- d s��,QE18 $$�1gesr2g,. m . a .,!.� �q...,90,...,.. c...... ooa-- 8$'$$$SN$$$ $ $$8$$$$8$ a 33m� ss�� 4 5. S W $ $g3gw7aggg IN N m ! !! m `. i s d •! .,,Ilil 831,3 seii 7. .. i,i5,7;)!...,..1,S851 sgs.s1s !yna..4E.Ag2 P: &W� a r i u 1, _';_; : :.. a. 1 r :i::: 1 !;m w'o 1• o II Z m �mm2W�0rr��msg^rms m�1�m0 oe LLm o �g Fa mm% a umrmgNem as wmsem,A;s .mm„sggdi ig e ix 16111 2§ V, ligri ^888888 8 s mm m_ ,,.mmrmm_______ e a m wm ?o m N 7S m M ` No, � ab m <O oe= a 6 a C N 'g 12 LL ((f ./\% D7 m� m �ao °D 61 fA S LL m m �, C illi?.1 gore U rts . : BPI* i :O. v T m„ `; 8 N `a0m 2m- •-.- ,L §e yC—'g Akin •4N d U a CD C ' 441111111441111111 H XI 401 iiiiiiiiiiiii4111111111111111111411111111111111 1 i N 1 TREE= 4-1/16" CM/ WELLHEAD= 11' FMC 1 8-13 B S. .Y NOTES: WELL ANGLE >70°@ 9786' ACTUATOR= BAKER C ***4-1/2"CHROME TBG*** KB.ELEV= 54.8' BF.ELEV= ^ KOP= 3450' 2110' H4-1/2"HES X NIP,ID=3.813" Max Angle= 94°@ 12441' 20"CONDUCTOR, --I 110' i Datum MD= WA Ip=? GAS LIFT MANDRELS Datum TVD= 8800'SS 4111 , ST MD TVD DEV TYPE VLV LTCH PORT DATE 3 3009 3008 6 MMG DMY RK 0 10/09/10 13-318"CSG,68#,K-55 BUTT, ID=12.415" -I 111' L 2 6225 6009 25 MMG DMY RK 0 10/09/10 1 8479 7902 55 MMG DMY RK 0 10/13/07 13-3/8"CSG,72#, L-80 BUTT,ID=12.347" -I 4482' 8518' --14-112"HES X NIP,ID=3.813" gr, x 8548' _--19-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" Minimum ID =2.377" @ 9942' 3 8572' -13.70"45 HYDRAULIC KB PKR,ID=2.56" 1 8579' 2-7/8"SPACER PIPE w/SEAL ASSY,ID=2.38" 3-3/16" X 2-7/8" XO � ---1 8583' -14-1/2"HES X NIP,ID=3.813"(BEHIND CT LNR) 8594' -I3.70"DEPLOY SLV,ID=3.00" 4-1/2"TBG,12.5#,13CR-80 VAM TOP, 8635' i 8604' 3-1/2"HOWCO X NIP,ID=2.81" .0152 bpf,ID=3.958" 4-1/2"TBG STUB(11/03/07) -I 8632' NNN, 8614' -I4-1/2"HES X NIP,ID=3.813" �� 8644' -9-5/8"X 4-1/2"UNIQUE OVERSHOT BKR 6'TIEBACK SLV,ID=7.500" - 8698' I 8662' -I9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" 9-5/8"X 7" BKR ZXP LTP,ID=6.313" -I 8705' _l J \ 8696' -14-1/2"HES X NIP,ID=3.813" BEHIND 9-5/8"X 7"BKR HMC LNR HGR,ID=6.250" I-f 8711' . 8718' -14-1/2"WLEG,ID=3.958" CT LNR 4-1/2"TBG,12.6#L-80 IBT,.0152 bpf,ID=3.958" I 8718' 8718' --17"X 4-1/2"XO,ID=3.938" 10'TIW TIEBACK SLV,ID=? -I 8805' 9-5/8"X 7"TIW LNR HGR,ID=? -I 8815' 9-5/8"CSG,47#,L-80 BUTT,ID=8.681" -I 9103' ........-1 9142' -3-1/2"X 3-3/16"XO,1D=2.786" 3-1/2"LNR,9.2#,L-80 STL,.0087 bpf,ID=2.992" -I 9142' 7"MILLOUT WINDOW(18-13B) 9202'-9211' 4-1/2"MONOBORE WHIPSTOCK(11/08/07) --I 9202' RA TAG1-1 9211' 9942' -13-3/16"X 2-7/8"XO,ID=2.377" FISH-WHIPSTOCK DEBRIS(11/06/07) I-I 9233' 10450' -12-7/8"GBP(08/07/08) PERFORATION SUMMARY REF LOG: MCNL GR ON 12/05/07 � !/ A NGLE AT TOP PERF: 87°@ 10160' Note:Refer to Production DB for historical perf data 3-3/16"LNR,6.2#, --I 9942' I 4 SIZE SPF INTERVAL Opn/Sqz DATE TCII STL,.0076 bpf, • .�:4� 2" 6 10160-10310 0 12/07/07 ID=2.80" 2" 6 10580-11510 C 12/07/07 PBTD 11510' I I 2-7/8"LNR,6.16#,L-80 STL, -I 11546' 7"LNR,29#,L-80 BTC,.0371 bpf,ID=6.184" 10277' ..... .0058 bpf,ID=2.441" i TREE= 4-1/16"CMV 18-1 3 C SA NOTES: WELL ANGLE >70 WELLHEAD= 11'FMC °@ 9786' ACTUATOR= BAKER C P inrn'"d CTD S iletiack *** "CHROME TBG*** KB.ELEV= 54.8' BF.ELEV= KOP= 3450' 2110' -14-1/2"HES X NIP, ID=3.813" Max Angle= 94°@ 12441' 20"CONDUCTOR, H 110' Datum MD= _WA GAS LIFT MANDRELS ID=? ST MD TVD DEV TYPE VLV LTCH PORT DATE Datum TVD 8800'SS 3 3009 3008 6 MMG DMY RK 0 10/09/10 13-3/8"CSG,68#, K-55 BUTT, ID= 12.415" - 111' ' 2 6225 6009 25 NhAG DMY RK 0 10/09/10 1 8479 7902 55 rVTV1G DMY RK 0 10/13/07 13-3/8"CSG,72#, L-80 BUTT, ID=12.347" -1 4482' 8518' H 4-1/2"HES X NIP, ID=3.813" 4-1/2"x 2-3/8"KB LIP H 8560' i-- 5Z ►�� 8548' -I9-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" Top of Proposed 2-3/8"L:: . H 8570' I I ` ' [ 8572' -13.70"KB PKR, ID=2.56"to be pulled c li 5 Eli 8579' I2-7/8"SPACER PIPE %SEAL ASSY !D=2 Minimum ID = 1.75?" 8560' 8583' --I4-112"HES X NIP,ID=3.813"(BEHIND CT LNR) :?-318" KB It 8594' -{3.70"DEPLOY SLV, ID=3.00" ' 8604' H3-1/2"HOWCO X NIP, ID=2.81" 4-1/2"TBG, 12.5#, 13CR-80 VAM TOP, - 8635' .0152 bpf, ID=3.958" 8662n-19-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" l BEHIND CT LNR 4-1/2"TBG, 12.6#L-80 IBT, .0152 bpf, ID=3.958" - 8718' .----i< a T S G R 8996' ort • , 9-5/8"CSG,47#, L-80 BUTT, ID=8.681" H 9103' 1---419142' H3-1/2"X 3-3/16"XO, ID=2.786" 3-1/2"LNR,9.2#, L-80 STL, .0087 bpf, ID=2.992" H 9142' 7"MILLOUT WINDOW(18-138) 9202'-9211' RA TAG -1 9211' -.__. 7"LNR,29# L-80 BTC .0371 bpf,ID=6.184" 1027T 9942' ` � , 3-3/16"LNR,6.2#, TCII STL, .0076 bpf, ,�/iNDOW(18-13A) 9747 -975 . ID=2.80" / 2-3/8"L-80 LINER,Cemented&Perforated H 12400' PERFORATION SUMMARY REF LOG: MCNL GR ON 12/05/07 • 9300' -13-3/16"pkr w hipstock ANGLE AT TOP PERF: 87°©10160' Note: Refer to Production DB for historical perf data -- - SQE SPF INTERVAL Opn/Sqz DATE 2" 6 10160- 10310 0 12/07/07 ' 9942' -I3-3/16"X 2-7/8"XO, ID=2.377" 2" 6 10580- 11510 12/07/07 •_ 10450' H2-7/8"CIBP(08/07/08) H wiz 2-7/8"LNR,6.16#, L-80 STL, H 11546' 4-1/2"LNR, 12.6#, L-80 IBT, .0152 bpf, ID=3.958" - 13097' 1 *� 0058 bpf, ID=2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/06/87 ROWAN 41 ORIGINAL COMPLETION 09/05/08 JKCJPJC SET CIBP(08/07/08) WELL: 18-13 02/25/98 D9 SIDETRACK(18-13A) 10/09/10 RCT/AGR GLV GO(10/09/10) PERMIT No: 01/14/07 D16 RWO 11/12/10 MSE PROPOSED CTD SIDETRACK API No: 50-029-21756-0 12/09/07 NORDIC 2 CTD SIDETRACK(18-13B) SEC 19, T11 N, R15E, 1045'FNL&371' FWL 01/15/08 GJF/PJC GLV C/O(01/07/08) 04/13/08 LBS/PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 1 I Y 'I 2 ' i. U 4 1� „ 2 m _ 1 C : Iill 41 I .1,. '3o x NH I ew II ® 1 • DA kI 0 In'N C ' mg ,, I® I '; 2 s 1 O 1 v 21 g la [ ' S Z C 73 1. I m p 1 A 1 n so I ' ' v :E ' r 11 N - � G7 -=-- n 301'1 O 1I g • 44 • IIl 1 m a Lii Ill Mill ,_ , 2. A 1:11 m O 1 =11 : 1=1 • H 73,010 • p= ma r Og jig isi I m p I Z 11a II = I V E g ' 3 D LH! nil d Z N 11 115. q71 7 ' i O inl ilii 1 r III = IL- 3—.......-1', 0 ''II 0 0 ,11 it? 0 ii $0E v 3 1'3 1E11 I 11°111i I 411 I all° NI 1 a 1111 II s i • 0,4 o • I=I I 14 I = 1 s S 7T a 11 9 N 9 < f 1- 1 11 Alaska Department of Natural Resources Land Administration System Page 1 of,21( Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28321 rd Printable Case File Summary See Township,Range, Section and Acreage? 0 Yes Q No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28321 Ma''._ Search for Status Plat Updates As of 12/20/2010 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2480.000 Date Initiated: 05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 015E Section: 17 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 015E Section: 18 Section Acres: 599 Meridian: U Township: 011N Range: 015E Section: 19 Section Acres: 601 Meridian: U Township: 011N Range: 015E Section: 20 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-151 T11N, R15E, UM 17, 18, 19, 20 2480.00 End of Case Summary Last updated on 12/20/2010. http://dnr.alaska.gov/projects/las/Case Summary.cfin?FileType=ADL&FileNumber=283... 12/20/2010 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME f.eF/4/ PTD# 2A0/F6 / Development Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD: .4177141/40‘. / POOL: ..0, ,e,/,0e'.Z.v/O/G - Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 7E To u) a 0'i a N N _ a) ❑ o N a a) c Q C O a) O L w, ❑ p a 3 E O c2 o) n 0) U n 2t)t) co a C 3 rn L N co N co 3 O Lr) aLo = co ,-- '- N U) a N a CO C = lV E -o C o 3 CO E a) j o 0 • 3 ,_ Ma os CLc QO M cri a0 ao 0 °- w .0 COo n N C o) n a) 0 0 0. o m 3 Z O n ° a) M L co a ° a) c co } m ~ 3 0 o as '� o o.E CO co c Q n -o a) n 0 c o w co • co CO M L a) O a CO a) N O= rn m co aai c N n o a rM) aa> co 3 aoo rn 7 7 c 0 ti 0 U a m II N rn ,_ IY N E co C L 0. 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