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Home My WebLink About204-1161a. 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: 54.3' 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 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20"x34" A-53 110' 9-5/8" L-80 2,692' 7" L-80 4,969' 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 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 617 sx AS Lite, 379 sx 'G', 212 sx 'G' 6781' / 4644' 3690' - 6829'4-1/2" 12.6# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 295 sx Class 'G' 48" 31' 3,442' 260 sx Arctic Set (Approx.)215.5# STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 2/14/2022 4719' FSL, 1517' FEL, Sec. 11, T11N, R11E, UM, AK 2224' FNL, 1530' FWL, Sec. 01, T11N, R11E, UM, AK 204-116 Schrader Bluff Oil Pool, Orion Dev Area 82.8' 3,491' / 2,720' Prudhoe Bay Field / 7/22/2004 HOLE SIZE AMOUNT PULLED 50-029-23213-00-00 PBU V-213 590785 5969968 2552' FNL, 1272' FWL, Sec. 01, T11N, R11E, UM, AK CEMENTING RECORD 5973291 SETTING DEPTH TVD 5973622 BOTTOM TOP 8-3/4" 32' 12-1/4"31' CASING WT. PER FT.GRADE 593531 593784 TOP SETTING DEPTH MD 32' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 29' DEPTH SET (MD) 3497' / 2713', 6653' / 4549', PACKER SET (MD/TVD) x 3-1/2" 9.3# L-80 40# 110' 29' 7,205' Gas-Oil Ratio:Choke Size: Set EZSV 3491' Set Whipstock Water-Bbl: PRODUCTION TEST Not on Injection Date of Test: Flow Tubing Oil-Bbl: suspension, or abandonment, 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 if necessary 3611' N/A MWD / GR /, MWD / GR / RES / DEN / NEU / PWD, USIT Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 7/12/2004 ADL 028240 00-001 1900' (Approx.) N/AN/A None 7,225' / 4,985' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 6126, 6375' 31 Bbls Cement, Set Cement Retainer By Meredith Guhl at 8:35 am, Mar 10, 2022 xG Abandoned 2/14/2022 MDG RBMDS 3/10/2022 MDG DLB 04-27-2022 DSR-3/10/22MGR18AUG2022 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 6582' 4496' 3817' 2914' 6101' 4164' 6371' 4343' 6405' 4367' 6463' 4409' 6582' 4496' 6667' 4559' 7068' 4862' Base SB 7068' 4862' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 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: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Schrader Bluff NC Schrader Bluff OA Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Schrader Bluff NB Ugnu Ugnu MB This form and the required attachments provide a complete and concise record for each well drilled 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, 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 Schrader Bluff Formation at total depth: Schrader Bluff NA Summary of Pre-Rig Work, Daily Drilling Report, Wellbore Schematic Signature w/Date: 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. INSTRUCTIONS 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). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Schrader Bluff OB 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 3.9.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.03.09 19:08:55 -09'00' Monty M Myers ACTIVITYDATE SUMMARY 1/11/2022 T/I/O = 1720/575/150. Temp = 110. PPPOT-IC (PASS), PPPOT-T (PASS). Pre RWO. PPPOT-IC: Stung into test port (250 psi), bled void to 0 psi. Monitor for 10 min (0 psi). Pumped hyd oil across test void to opposite port, good returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Did not function LDS. The packoff will not be pulled for this RWO. PPPOT-T: Stung into test port (0 psi), bled to 0 psi. Monitor for 10 min (0+ psi). Functioned LDS out to 4-5/8" and back in to 3-5/8", all moved freely but ***1 GLAND NUT IS STUCK, FLAGGED FOR C/O BEFORE RWO***. Re-torqued gland nuts and LDS to 450 ft/lbs. Pumped hyd oil across test void to opposite port, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi, RDMO. 1/18/2022 T/I/0 =1300/300/0 Assist Slickline (injectivity test). Travel to location, spot in stand by. Job continues next day. 1/18/2022 ***WELL SI ON ARRIVAL*** R/U HES 759 ***CONT WSR ON 01/19/2022*** 1/19/2022 Job continued from previous day. Assist Slickline ( INJ test ) Pumped 98 bbls Diesel down tbg to load and pumped 40 bbls diesel to achieve an injectivity test of 1765 psi @ 2 bbls/min. Pumped 2 bbls 60/40 down IA followed by 79 bbls Diesel down IA to achieve injectivity test of 1820 psi @2 bbls/min Pad op notified of Well Status and Sline in control of well upon departure. CV's= OTG FWHP's= 1540/1820/20 1/19/2022 ***CONT WSR FROM 01/18/2022*** DRIFT TO 6,798' SLM W/ 2.80" CENT. PULL RMX PRONG @ 6,817' MD PULL RMX PLUG BODY @ 6,817' MD PASS 2 BPM INJECTIVITY TEST ON OBD SET WHIDDON @ 6,468' MD PULL STA. # 5 BK DGLV @ 6,347' MD (POCKET LEFT EMPTY) PASS 2 BPM INJECTIVITY TEST ON IA PULL WHIDDON @ 6,468' MD ***WELL LEFT SI*** 1/26/2022 T/I/O= 290/290/50 CMIT T x IA PASSED to 1000 psi. (P&A-Pre Sidetrack) Pumped 1.8 bbls of diesel to reach test pressure. 1st 15 mins Tbg lost 15 psi, IA lost 0 psi. 2nd 15 mins T/IA had no loss for a total of 15/0 psi in 30 mins. Bled back `1.5 bbls, FWHP's 300/300/50. Hung tags, notify Pad-op. Well shut in upon departure IA/OA= OTG 1/26/2022 ***WELL S/I ON ARRIAL*** JOB SCOPE: P&A SET 4.5" HES EZ-DRILL SVB CEMENT RETAINER (CAST IRON) AT 6375' MD. IN FULL JOINT BELOW GLM#5. LOG TIED INTO TUBING TALLY DATED 26-JUL-04. CCL STOP DEPTH=6366.9', CCL OFF SET=8.1', ME SET DEPTH=6375' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED*** 1/29/2022 350/250/0 Disconnected piping and removed VSM from wellhead to approx. 40 behind wellhead for Rig clearance. N/D production tree, N/U dryhole tree. Performed PT on tree...Pass. FWP's 350/250/0 Daily Report of Well Operations PBU V-213 Daily Report of Well Operations PBU V-213 2/5/2022 ***WELL S/I ON ARRIVAL*** (plug & abandonment-resevoir) TAGGED CEMENT @ 6126' SLM (GOOD SAMPLE). T-BIRD PERFORMED STATE WITNESSED MITT 2300 PSI (PASSED). T-BIRD PERFORMED STATE WITNESSED MITIA 2300 PSI (PASSED). ***WELL S/I ON DEPARTURE; READY FOR E-LINE*** 2/5/2022 T/I/O= 0/0/50 Assist Slickline, AOGCC State witness MIT. AOGCC State witness (Bob) MIT-T ***PASSED**** to 2223 psi. pumped 1 bbl 60/40 to reach max applied psi of 2300 psi with a target of 2000 psi. 1st 15 min TBG lost 53 psi. 2nd 15 min TBG lost 24 psi. total loss of 78 psi in 30 min. Bled TBG back to 500 psi. Bled back 0.7 bbls 60/40. AOGCC (Bob Noble) State witness MIT-IA ***PASSED*** to 2138 psi. Pumped 2.2 bbls 60/40 to reach max applied psi of 2300 psi with a target psi of 2000 psi. 1st 15 min IA lost 133 psi. 2nd 15 min IA lost 28 psi. Total loss of 161 psi in 30 min. Bled OA back to 0 psi. Bled back 1.7 bbls 60/40. Tags hung on IAC & MV. SL in Control of well @ departure. FWHP= 330/0/70 2/6/2022 WELL S/I UPON ARRIVAL CUT TUBING AT 3690.0', CCL TO CUTTER = 21.2', CCL STOP DEPTH = 3668.8' WELL LEFT S/I UPON DEPARTURE 2/8/2022 T/IA/OA= 100/150/50 CMIT T x IA PASSED to 2085/2140 psi Pumped 2 bbls of 60/40 down TBG and IA to acheive test pressure. 1st 15min= T/IA lost 55/65 . 2nd 15min= T/IA lost 25/25 Total loss of 90/110. Bled back 2 BBLS to achieve FWHP=100/150/50 ) T-BIRD PERFORMED STATE WITNESSED MITT 2300 PSI (PASSED). T-BIRD PERFORMED STATE WITNESSED MITIA 2300 PSI (PASSED) TAGGED CEMENT @ 6126' SLM (GOOD SAMPLE)@( ) CUT TUBING AT 3690.0', Activity Date Ops Summary 2/2/2022 Move rig from V-105 to V-213 on the same pad. Set rig down and accept at 14:00. Start rig up checklists. Remove tree cap. Install BOPs. Get test joints ready. M/U nozzle with no floats, get injector on well. Wells support spot 40 bbl tank and choke trailer. Finish securing stack. Swap out drilling risers. Line up valves. Flush lines. Configure test joints. Change out chart recorder. Get good shell test. Test BOPs. 2/3/2022 Continue testing BOPE on test #2 of 7 plus drawdown test. Test #2 - Pass. Test #3 - Pass. Test #4 - Pass. Test #5 - Pass. Test #6 - Pass. Drawdown Test - Pass. Test #7 - Pass. Test #8 - Pass. RD Test Equipment Verify Valve Alignment with checklist and update board. 239psi IAP PJSM to inflow test CMT Retainer. Line up well to a closed choke B, open SV (24 turns) & MV (24 turns). IAP dropped from 238psi to 5psi from just filling the stack and line to choke B. Open Whitey Valve to ensure stack is full, bled off to 0psi, fill stack with diesel using the test pump Stack is full @ 12:35, start 30 min inflow test monitoring Whitey Valve at Rig Floor. Good no inflow test, prep to install BHI floats, test to 2500psi. MU Nozzle BHA and PT the QTS RIH with Nozzle BHA, taking returns to the Tiger Tank. WHP = 0 psi IAP = 0 psi OAP = 121 psi Tag CMT Retainer 2x at 6388' online with pump displacing well to 1% Slick KCl. Appear to be on slight losses. With clean KCl around purge riser with air out to tiger tank then flow check 30 min, good. Fill well with 1.0 bbl. Circ on bottom 10 min, get 1:1 returns. POOH. Flag pipe at 6100' EOP. Tag stripper. 10 min flow check is good. Lift off well. Remove nozzle, UQC and install cable boot. M/U CT to 1 jt 2-3/8" PH6. M/U injector. Pump slack out with fresh water. Cable is heard moving. Lift off well and pull cable out of PH6. Remove 1 jt PH6 from stack. 177' cable pumped out. Cut off CT connector, dress CT and install BTT slip connector. Pull test 35k, PT 4000 psi, good. Install ball catcher nozzle. M/U injector to well. Drop 3/4" ball pump it around. Recover ball. M/U BHA #2, cement stinger + 4 jts 2-3/8" PH6. Drift and rattle PH6. M/U injector. RIH BHA #2. 2/4/2022 Stop at 6100' at the flag, depth it within 0.5'. Online with pump at 2 bpm for baseline above retainer. 2.0 bpm at 1930psi, IAP = 431psi, shut down pump and RIH to sting into Retainer. Pumps off IAP = 369psi. Tag Retainer at 6388.77', PU and retag Tag at same depth, close choke, online with pump walking up to 2.0 bpm not to exceed 1000psi over baseline pressure. We are stung into the retainer and injecting 2.0 bpm at 2785psi. Hold PJSM to Batch up and pump CMT. IAP = 372psi OAP = 190psi Batch up 35 bbls of CMT. CMT wet at 07:00 with 5:58 thickening time (12:58). Verify 15.8ppg CMT on Mud Balance. Fluid pack and PT CMT line to 250 low and 5000 high. Pump PowerVis Contam to Reel then shut down. Good low & high PT Online with 5 bbls of fresh water followed by CMT down the coil. Zero CMT MM at lead of CMT, pumping 1.0 bpm at 1020psi. 31 bbls CMT pumped 39.7 bbls away, CMT at stinger. Pump 16 bbls of CMT through retainer. Shut down pump at 55.7 bbls, PU 10'. Line up to take returns from the tubing, pump 1 bbl into tubing. Shut down pump and line up to take returns from the IA. Pump pumped 4.75 bbls into IA and pressures on IA & TBG are climbing Call OE and discuss laying in the rest of the CMT in TBG then squeeze more CMT into the IA when we are are Safety. Line up to take returns from the tubing and lay in remaining 9.25 bbls of CMT . Online at 1 bpm pulling at 66 fpm from 9377'. Last of the CMT out at 5773' TOC = 5769' Stop at safety and discuss volume to squeeze into the IA. Close choke on TBG, online with pump to squeeze 3 bbls more into the IA. Open choke on IA and pump 3 bbls of CMT into IA. 3 bbls pumped, close IA choke, TOC at 5966' in TBG Line to pump PowerVis down the coil and RIH. 5750' PowerVis at nozzle, wash down contaminating residual CMT from 5769' to 6000'. 7.75 bbls of CMT pumped into IA, TOC in IA at 6067'. POOH chasing contaminated CMT. Swap to Diesel to FP from 3100' MD (2500' TVD) IAP = 330psi. Good diesel at surface, reduce rate for pipe displacement and tag up. IAP = 220psi with Diesel FP to surface. Hold a PJSM to LD the BHA while flow checking well. Verify X-O's for Safety Joint are on the rig floor Good no flow, PU the injector and LD the BHA BHA OOH, Stinger looks good, LO BOT Tools and prep to flush surface lines. Flush surface lines and then pump slack back Pumped slack back, PU injector and RU to cut pipe. Cut 240' of CT, cable not seen. Install CT connector. Pull test to 50k is good. Install nozzle and pump slack forward. Install BHI UQC with no floats. Purge reel and surface lines with air. Wells support rig down choke trailer and trip tank IA line. Remove BOPs, install tree cap. 2/5/2022 Vac remaining fluids out of pits. Purge steam lines, complete RDMO checklists. Rig released at 06:00. 2/9/2022 R/D U-Tube Manifold and all 1502 components. Grease all plug valves and mud manifold and around Rig. Respool both Tuggers. Bridle up and Scope down Derrick. Remove 1502 Companion flanges from Wellhead and install blank Flanges. Prep Possum Belly Dump Line for Repair. C/O Valve/Seat MP #2 pod 3 and 4 C/O Wear plate gasket on MP #2. C/O Pulsation Dampener Gauges on MP #1. Perform Monthly EAM on both Pumps. Clean Magnetic filters, check TQ on fluid ends, check lube pump coupler, clean rod wash and oil suction strainers. Finish cleaning mud pits. WOW (Temp below -35°F) and V-213A pad prep to be completed before calling trucks for Rig Move to V Pad. C/O choke manifold valve #15. Fix Mouse hole bushing. Check/Air up tires on all Mods. Welder cut out old Possum Belly Dump Line and install new Flange. Re assemble Mud Pumps. Clean and clear Rig Floor of unneeded handling subs/XO’s. Clean up ears on all 1502 components. Work on rig inspections/hitchly paperwork. Clean/secure cellar and pipeshed for rig move. Perform monthly EAM on catwalk hydraulics and C/O filters. perform monthly EAM on test pump. Set rig mats and lay herculite on V-213A. B/D water system. prep pits for welding projects Prep and secure shop for rig move. Redress VBR's. Remove cuttings tank. C/O bearing on drag chain. Disconnect all pit mezzanine interconnect lines. Flip up roof caps and install stair wrench's. WOW (Temp below -35°F). Change out bearings on drag chain. Set rig mats over buried cable on pad. Remove ice from pipe-shed floor. Replace bolt on pipe lift column. Check torque on lift column bolt. Blow down steam lines. Unplug and move break shack and envirovac. R/D interconnects. Swap to cold start at 04:00. Turn stompers to walk off well. Jack up Gen mod and install jeep. Jack up pipeshed. NES on location at 05:00. Pull Gen mod and mud mod and stage on pad. 2/10/2022 Unhitch truck from Pipe Shed, cover with hooch and heat tires. Jack up catwalk hitch truck and pull away from Sub, cover with hooch and heat tires. Remove both Geo spans from lower utilidor and install 2 new ones. At 10:00 Convoy Gen Mod and Mud Mod to V-Pad. Remove out riggers, raise DS Stairs. Stomp Sub off Z-220. Turn Stompers and Rotate Sub and install front steering arm on Sub. Install rear sub tires and remove steering arms. Hook up sow to sub base and line up convoy with pipe shed, cattle chute and sub. At 15:30 Convoy Pipe Shed, Cat Walk and Sub to V-Pad. Set cattle chute and pipeshed to side of pad. Drop mods and hooch/warm tires. Stage gen mod and mud mod to edge of pad. Set rig mats. Stage sub base. Remove front steering arms. Walk sub forward to install rear steering arms. Remove rear tires off sub. Cont. removing rear tires. Turn sub 90° and walk back over V-213A. Spot, shim and set sub base. Drive and re-stage mud mod back to unhook truck. Hook truck to cattle chute and begin spotting. 50-029-23213-01-00API #: Well Name: Field: County/State: PBW V-213A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska Rig released at 06:00. 2/11/2022 Spot Catwalk into position and set down. Set outriggers on Sub. Turn and retract stompers, install covers. Verify stairs and cattle chute line up properly. Spot and set down pipe shed. Spot and set down Mud Mod. Verify hose and flow line alignment and scope out Interconnect. Spot Gen Mod, remove Jeep and set down Gen Mod. Release NES Trucks at 10:00 to move Satellite Camp and Shop f/ Z pad to V pad. Assist NES welder with possum belly repair. Hook up interconnects and take on Fuel. Assist Electrician plugging in Rig. Rig on Gen Power @ 12:00. Bring on Steam System to Rig. Move Satellite Camp and shop to V-Pad. Continue to safe out walkways and landings. Work on Rig Acceptance Check List. Prep and Scope Derrick. Unplug upper derrick section. Verify outriggers in place and check stompers pressure. Scope up derrick. Bridle down. Assist NES welder installing new hinges on centrifuge dump hatches, weld crack on shaker #2. Lay herculite and spot cuttings box. spot break shack and enivorvac. Perform post rig move derrick inspection. Function test all mud pit equipment, pipe shed equipment. Load up herculite from Z-pad and bring to shop. Bring XT-39 crossover, TIW, Dart valve to rig floor. Install companion flange on IA. Get 1502 components and hoses ready for circulating out freeze protect. Bring pipe handling equipment to rig floor. Take on 290 bbls seawater and build soap pill. Function test mud pumps. Rig accepted at 23:30 R/U circulation hoses. iniital SITP 50 pis, ISICP 80 psi. Bleed pressure. Shut in and monitor. SITP= 0, SICP 35 psi. Tubing on vac - underbalanced. Pre-RWO meeting with rig crew. Verify rig up and line up. Circulate out freeze protect down tubing out IA. Pump 50 bbls hot soap pill followed by 170 bbls 8.5 ppg seawater. ICP 230 psi at 1 bpm, FCP 695 psi at 2.5 bpm, observe erratic pressures up to 1250 psi. Shut down and monitor well. Tubing on vac, IA slight flow. 8.0 ppg coming out IA. Pump remaining 36 bbls seawater 2.5 bpm 695 psi. Monitor well, still underbalanced tubing vac, IA slight flow. Cont. to monitor until balanced - static. Blow down and rig down circulating hoses/1502 components. Install BPV. Install tree cap. Begin breaking studs on tree. 2/12/2022 Finish braking studs on Tree. Remove Tree and set aside. Install CTS Plug and PT to 4000 psi f/5 min. Inspect lift threads on Tbg Hgr with XO (8.5 turns) Check LDS, clean and fill Void/Hanger with oil. Istall DSA to Wellhead. Hook up bridge crane and remove cross chains from stack. Land Stck on DSA. Install cross chains, remove bridge cranes. N/U Choke/Kill lines, hole fill line and 1502 components. Install KOOMEY lines and energize system. Install drip pan and hoses. N/U 4" line to Beyond Orbit valve and all lines to Beyond Choke. Obtain RKB's: GL 26.71', LLDS 24.90', ULDS 22.89', LPR 20.72', Annular 13.40'. SIMOPS: Load and process 4" DP. C/O Saver Sub, Dies and Bell Guide to 4" XT-39. Grease Choke manifold and Manuals/HCR's on Stack. P/U 4.5” and 3.5” Doughnut Test Jts. Mark same with Annular, UPR, LPR positions and lay back down. Pull Bushings and remove Bowl Saver. Install MPD Test Cap and Tighten Clamp. Clean and clear rig floor. Send old saver sub and changing stand off rig floor. Send down 4.5" IF TIWand dart valves. Clean up and ut away 5" die blocks and bell guide. Adjust top drive back up wrench height. M/U XT-39 test sub to top drive. Flood stack and beyond lines. Cycle chokes. Close choke and PT beyond hardline 250/1250 - good. Bleed off and blow down lines. Break RCD clamp and remove test cap. Install riser, center stack. Tighten RCD clamp and inflate airboot. M/U test joint. Flood lines, purge air. Test BOPE's 250/3000 psi, AOGCC right to witness waived by Guy Cook. Check gas alarms, PVT sensors. F/P UPR's - function and retest. F on choke manifold #4. Cont testing, replace choke manifold valve 4 after drawdown and re-test - good. Accumulator drawdown: starting pressure 3000 psi, final 1500 psi, first 200 psi recharge 28 sec, Final 98 secs. 6 (N2) at 2325 psi average. Sim Ops while changing out/testing choke manifold 4: Rig down testing equipment, L/D test joint. Clean and clear rig floor. Break out test sub from top drive. Bring Weatherford power tongs and pipe handling equipment to rig floor. C/O elevators. Bring wear bushing to rig floor. Pull CTS plug and BPV. Observe fluid level drop in tubing. M/U landing joint to hanger. BOLDS. P/U hanger to floor, free at 102K, PUW 66K. Break out and L/D hanger and landing joint. Rig up to circulate. M/U XO and head pin. Circulate 50 bbls heated soap pill followed by fresh water staging pumps up to 7 bpm, 230 psi. Observe 34 bbls diesel returns at beginning of circulation. Monitor well, static. R/D circulating equipment. 2/13/2022 POOH laying down 4.5" TCII tubing from 3690', (87 joints, XN landing nipple, 1 cut joint) Calculated hole fill. Clean and clear rig floor. Rig down Weatherford tubing equipment. Mobilize BHA components to rig floor. Install wear ring. M/U Casing scraper BHA. Junk mill, 7" casing scraper, bit sub, watermelon mill, oil jar and XO as per Baker. Pick up, drift (2.3") and single in hole with casing scraper assembly to 655'. Calc displacement. Service rig: grease crown, top drive, drawworks, wash pipe, IBOP, iron roughneck, cobra heads. Pick up, drift (2.3") and single in hole with casing scraper assembly from 655' to top of stub at 3690', tag top of stub with 5K. Calc displacement. Calculated displacement observed. P/U 75K, S/O 65K Displace to 9.5 ppg milling fluid at 330 gpm, 665 psi. Monitor well, static. Pump dry job. POOH to 29'. Calculated hole fill observed. Pick up, drift (2.3"), and single in hole with remaining drill pipe in shed to 3,054'. P/U 70K, S/O 55K. Calculated hole fill observed. Circulate surface to surface at 330 gpm, 600 psi. Monitor well, static. pump dry job. POOH racking back drill pipe to surface. L/D BHA. Clean and clear rig floor. Service rig: grease and inspect crown sheaves. Grease blocks. Check top drive gear oil. Inspect carriage frame. Spot in E- Line. R/U E-line. Install sheave in elevators. M/U CCL and CIBP. RIH with CIBP. Tag top of stump lightly at 3690' and correlate. Locate collar at 3516'. Set CIBP at 3611', good indication of set. POOH and R/D E-Line M/U Whipstock assembly. M/U TM, DM, Float sub and XO. L/D to pipe shed. P/U Joint of HWDP and M/U milling assembly and scribe line. M/U whipstock with 35K shear bolt and anchor (14K shear on anchor). Scribe line and measure RFO = 4.57/4.67 = 352.29°. 2/14/2022 Continue to M/U Whipstock BHA and 10 jts 4" HWDP. TIH to 375'. Shallow pulse Test MWD tools on 1st Jt of HWDP, 200 GPM, 375 PSI. Test Good. B/D Top Drive and Choke Lines. TIH with Whipstock Milling Assy on 4" DP from Derrick to 3463' MD @ 30-40 fpm. PU 73K , SO 64K. PU working single, fill pipe and orient tool face to 32º ROHS. Shut down pumps and RIH to 3509' and tag top of CIBP. Set Whipstock as per Baker Rep, observe bottom trip anchor shear @ 14K down and shear Whipstock bolt at 35K down. Parameters, 300 GPM, 1110 PSI, RPM 80, Tq 4K, PU 73K, SO 64K, Rot 68K Mill Window (TOW 3491', BOW 3504') erratic TQ/multiple stall starting window. 300 GPM, 1150 PSI, rpm 60-80, TQ 3-7K, WOB 2K. P/U 78K, S/O 65K, ROT 69K. Drill 20' of new hole to 3524'. Work through window multiple times. Shut down pumps/rotary. Trip through window with 2-3K drag down a 3-5K drag up Pump 30 bbls high vis sweep (no increase in cuttings) and circulate hole clean at 300 gpm/1150 psi even MW in/out. Rig up to perform FIT, flood and purge lines. Shut UPR's. Pump down IA and drill pipe. Attempt to perform FIT to 308 psi (11.7 ppg), pressured up to 246 psi, shut down as the well started taking fluid. 0.8bbls pumped 0.2 bbls bled back. Circulated hole. Discuss options with town, AOGCC approves to drill ahead using original LOT of 13.4 ppg from parent well due to: the Ugnu being open, clean, and permeable in this location in the uncemented 7” annulus and an original PB1 of v-213 at 3571’ MD. Any of which could impact the FIT and take fluid. Monitor well, static. Pump 15 bbls dry job. Finish rigging down circ. hoses/testing equipment. L/D working single. Simulate kick while drilling drill. Kelly up and call drill. Space- out. Monitor well. All hands respond accordingly. Hold after action review with rig crews. Discuss kick indicators, importance of early detection and why, well control equipment, types of barriers, sequence of well shut in. install stripping rubber and air slips. Cont POOH on elevators from 3432' to surface. L/D BHA starter mill 3/8" under-gauge, second mill 1/16" under-gauge, top mill in gauge. Clean and clear rig floor. Pull wear bushing. M/U Johnny Whacker and flush out BOPE stack. L/D Johnny whacker. Blow down top drive. Install wear ring. Bring BHA components to rig floor. M/U BHA. M/U NOV PDC bit to mud motor (1.5° bend), DM collar. Measure RFO = 0.01/4.8 = 0.75°. M/U GM collar, ILS, ADR, ILS, PWD, TM and float sub. Plug in and upload MWD. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:11 Township:11N Range:11E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:7225 ft MD Lease No.:ADL 28240 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3442 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 7205 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:4.5"O.D. Tail@ 6829 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 6375 ft MD 6126 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 2300 2247 2223 IA 0 0 0 OA 75 75 75 Initial 15 min 30 min 45 min Result Tubing 620 595 586 IA 2299 2166 2138 OA 150 140 140 Remarks: Attachments: Plug back for redrill of PBU V-213A. A slick line tag was performed and sample came back showing the thickness of modeling clay with a lot of small 1/8-inch hard pieces that looked like cement. I also witnessed passing MITs of the tubing and inner annulus. February 5, 2022 Bob Noble Well Bore Plug & Abandonment PBU V-213 Hilcorp North Slope LLC PTD 2041160; Sundry 321-629 none Plugging Data: Test Data: P Casing Removal:Casing/Tubing Data (Depths a P rev. 11-28-18 2022-0205_Plug_Verification_PBU_V-213_bn             Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 2/04/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU Orin V-213 (PTD 204-116) Cement Retainer 01/26/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/07/2022 By Abby Bell at 3:45 pm, Feb 04, 2022 ,ISHUIRUDWLQJ 7\SHRI5HTXHVW 2SHUDWRU1DPH $GGUHVV &XUUHQW:HOO&ODVV3HUPLWWR'ULOO1XPEHU $3,1XPEHU 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Ğ͘ /ŶĐƌĞĂƐĞĐĞŵĞŶƚǀŽůƵŵĞƚŽĂĐĐŽƵŶƚĨŽƌϰͲϭͬϮ͟ǆϳ͟ĂŶŶƵůĂƌƐƉĂĐĞŝĨ Őůǀ;ƐͿǁĞƌĞŽƉĞŶĞĚƵƉŝŶ ƐůŝĐŬůŝŶĞƐƚĞƉϯϬ Ĩ͘ ƵůůŚĞĂĚĨůƵŝĚƐŝŶƚŽKƐĂŶĚƐĂŚĞĂĚŽĨĐĞŵĞŶƚ͘ Ő͘ hƐĞĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌƐĂƐŶĞĞĚĞĚĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚ͘ ϭϰ͘ ^ǁĂƉƚŽϭй<> ŽƌƐŝŵŝůĂƌ ĨŽƌĚŝƐƉůĂĐĞŵĞŶƚĂŶĚĂƚƚĞŵƉƚƚŽ ŝŶũĞĐƚĨƵůůǁĞůůďŽƌĞǀŽůƵŵĞŽĨĐĞŵĞŶƚďĞůŽǁ ƌĞƚĂŝŶĞƌ ŽĨ ;цϭϲ ďďůƐͿƉƌŝŽƌƚŽƵŶƐƚŝŶŐŝŶŐ͘ Ś͘ ŽŶŽƚĞǆĐĞĞĚ ϭϬϬϬƉƐŝĂďŽǀĞ ŝŶŝƚŝĂůŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞ ŝ͘ &ƵůůǁĞůůďŽƌĞĐĂƉĂĐŝƚǇďĞůŽǁƌĞƚĂŝŶĞƌĞƐƚцϭϲ ďďůƐ ŝ͘ ϰϬϬ͛ŽĨ͘ϬϬϴϳďƉĨϯͲϭͬϮ͟ ŝŝ͘ ϯϬϬ͛ŽĨ͘ϬϯϳϭďƉĨϳ͟ ŝŝŝ͘ ϭϬϬ͛ŽĨ͘ϬϭϱϮďƉĨϰͲϭͬϮ͟ ϭϱ͘ hŶƐƚŝŶŐĨƌŽŵƌĞƚĂŝŶĞƌĂŶĚůĂǇĐĞŵĞŶƚŝŶĂƚϭ͗ϭƵƉĨƌŽŵ ϲϯϳϱ͛DƚŽ ϲϭϭϬ͛D͘ ũ͘ >ĂǇŝŶ ĨŝŶĂů цϰ ďďůƐŽĨĐĞŵĞŶƚ͘ ϭϲ͘ ŝƐƉůĂĐĞ Ϯ ďďůƐĐĞŵĞŶƚĨƌŽŵƚŚĞƚƵďŝŶŐƚŽƚŚĞ/͕ƚĂŬŝŶŐƌĞƚƵƌŶƐŽĨĨƚŚĞ/ ͘ Ŭ͘ ϭϬϬĨƚŽĨdƵďŝŶŐĂŶĚ/ ĐĂƉĂĐŝƚǇĂďŽǀĞƚŚĞƌĞƚĂŝŶĞƌĞƐƚ Ăƚ ϯ͘ϰďďůƐ ŝ͘ ϭϬϬ͛ŽĨ͘ϬϭϱϮďƉĨϰͲϭͬϮ͟ ŝŝ͘ ϭϬϬ͛ŽĨ͘ϬϭϴϲďƉĨ ϰͲϭͬϮ͟ǆϳ͟ ĂŶŶƵůƵƐ ů͘ &ŝŶĂůĞƐƚŝŵĂƚĞĚdKŝŶƚƵďŝŶŐŝƐϲϮϰϰ͛D ŵ͘ &ŝŶĂůĞƐƚŝŵĂƚĞĚdKŝŶ/ŝƐϲϮϰϬ͛D ϭϳ͘ WhƚŽƐĂĨĞƚǇ ĚĞƉƚŚĂƚцϲ͕ϬϬϬ D ĂŶĚƐǁĂƉ ƚŽ ĐŽŶƚĂŵŝŶĂƚĞ͘ ϭϴ͘ Z/,ƚŽ ĐůĞĂŶŽƵƚͬĐŽŶƚĂŵŝŶĂƚĞ ĨƌŽŵ цϲ͕ϮϰϬ͛ D ƚŽƐƵƌĨĂĐĞ͘ ϭϵ͘ WKK,ĂŶĚĐŝƌĐƵůĂƚĞĐŽŝůƚƵďŝŶŐĐůĞĂŶĂƐŶĞĞĚĞĚ͘ ϮϬ͘ ^ƚŽƉƚŽĨƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐ ĨƌŽŵΕϮϱϬϬ͛ Ϯϭ͘ ZDK ^ůŝĐŬůŝŶĞŶĚ,ŽƚKŝů ϮϮ͘ EŽƚŝĨǇK'ĂƚůĞĂƐƚϮϰŚƌƐƉƌŝŽƌƚŽƉůƵŐƉƌĞƐƐƵƌĞƚĞƐƚŝŶŐĂŶĚ ĚĞƉƚŚǀĞƌŝĨŝĐĂƚŝŽŶ͘ Ϯϯ͘ D/Zh ^>ƵŶŝƚ ĂŶĚ,ŽƚKŝů Ϯϰ͘ Z/,ǁŝƚŚĚƌŝĨƚĂŶĚƚĂŐĐĞŵĞŶƚƉůƵŐ͕ĞƐƚŝŵĂƚĞĚĂƚ ϲϮϰϬ͛ D Ϯϱ͘ D/dͲdƚƵďŝŶŐƚŽ ϮϬϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ Ϯϲ͘ ^ǁĂƉŽǀĞƌĂŶĚD/dͲ/ƚŽ ϮϬϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ Ϯϳ͘ ZDK ƌd^ 3URYLGH RSSRUWXQLW\ IRU $2*&& WR ZLWQHVV 6/ WDJ DQG 0,77 0,7,$ EMP 6WHSV 6XSHUVHGHG 6HH DWWDFKHG HPDLO EMP ,$ &HPHQW KDV SRWHQWLDO WR 8WXEH EDFN LQWR WXELQJ GHSHQGLQJ RQ EDODQFH RI IOXLGV LQ ,$ DQG WXELQJ 0HDVXUH UHWXUQV WR DVVXUH RQO\ EEOV FHPHQW LQ ,$ tĞůůWƌŽŐŶŽƐŝƐ ZĞǀŝƐŝŽŶη Ϯ ϭͲϮϴͲϮϮ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭͬϮϴͬϮϮ ůŝŶĞ Ϯϴ͘ D/Zh>ĂŶĚWd͘ Ϯϵ͘ DhϰͲϭͬϮ͟ :ĞƚƵƚƚĞƌ ϯϬ͘ Z/,ĂŶĚĐƵƚŵŝĚũŽŝŶƚŝŶϰͲϭͬϮ͟ƚƵďŝŶŐĂƚΕϯϳϬϬ͛D Ă͘ dĂƌŐĞƚtŚŝƉƐƚŽĐŬͬtŝŶĚŽǁĚĞƉƚŚΕϯϱϱϬ͛D ϯϭ͘ sĞƌŝĨǇŝŶũĞĐƚŝǀŝƚǇ ƚŚƌŽƵŐŚƚŚĞĐƵƚ Ă͘ WĞƌĨŽƌŵD/dͲdǆ/ƚŽϮϬϬϬƉƐŝƉŽƐƚĐƵƚ͘ ϯϮ͘ ZDK ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ZͲϮKW ^ĐŚĞŵĂƚŝĐ tĞůůWƌŽŐŶŽƐŝƐ ZĞǀŝƐŝŽŶη Ϯ ϭͲϮϴͲϮϮ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭͬϮϴͬϮϮ tĞůůWƌŽŐŶŽƐŝƐ ZĞǀŝƐŝŽŶη Ϯ ϭͲϮϴͲϮϮ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭͬϮϴͬϮϮ tĞůůWƌŽŐŶŽƐŝƐ ZĞǀŝƐŝŽŶη Ϯ ϭͲϮϴͲϮϮ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭͬϮϴͬϮϮ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Wyatt Rivard Cc:Rixse, Melvin G (OGC);Sean Mclaughlin Subject:RE: [EXTERNAL] V-213i (PTD 204-116) Change to approved Sundry Date:Monday, January 31, 2022 2:05:00 PM Wyatt, I’ll attach this revised procedure to the Sundry. Note: If you decide not to displace the CT with diesel in step 14 below because you need water spacer or some other reason, that will be fine as long as the 6 bbl volume of cement placed in the IA is based on returns measured from the IA. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, January 31, 2022 1:00 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Subject: RE: [EXTERNAL] V-213i (PTD 204-116) Change to approved Sundry Hello Bryan, For the CTD operations/reservoir abandonment plug we will have a lubricator and stripper rigged up above the BOPs. On the cement plug side, we actually ended up with full diesel fluid columns on the tubing and the IA after pre-cement injectivity tests on the TBG x Formation (139 bbls pumped) and IAxTBGxFormation (79 bbls pumped + 2700’ initial completion diesel freeze protect 7/28/04). With diesel on both sides of the tubing, we’ll go ahead and displace the cement with diesel as well. This should leave us with consistent hydrostatics on either side of the tubing and less chance of unexpected U-tube. Since we do have the room, we’ll go ahead and pump an 8 extra bbls of cement (displacing extra 4 bbls to the IA). This should leave us with at least 300’ of cement in the TBG and IA. If this sounds acceptable, I will updated our procedure accordingly. CDR-2 Cementing (updates in red) 10.MIRU CDR-2 and spot ancillary equipment. 11.Pressure test BOPE to 2500 psi a.Give AOGCC 24 hr notice prior to BOPE test b.Test against swab and master valves (no TWC) c. Test annular and both sets of 2” rams. d. Do not Test 2-3/8” pipe/slip rams. 12. RIH and sting into cement retainer set at ± 6375’. a. Establish injection pressure at ~ 2BPM while stung into retainer. b. Monitor CTBS pressure before and after stinging into retainer to confirm stung in. 13. Begin to mix 15.8 ppg class G cement. Once blends are up, pump ±28 bbls Class G cement down the coil tubing with backside SI. c. Increase cement volume to account for 4-1/2”x7” annular space if glv(s)were opened up in slickline step 30 d. Bullhead fluids into OBD sands ahead of cement. e. Use freshwater spacers as needed around the cement. 14. Swap to diesel for displacement and attempt to inject full wellbore volume of cement below retainer of (±16 bbls) prior to unstinging. f. Do not exceed 1000 psi above initial injection pressure g. Full wellbore capacity below retainer est ±16 bbls i. 400’ of .0087 bpf 3-1/2” ii. 300’ of .0371 bpf 7” iii. 100’ of .0152 bpf 4-1/2” 15. Unsting from retainer and lay cement in at 1:1 up from 6375’ MD to 5580’ MD. h. Lay in final ±12 bbls of cement. 16.Displace 6 bbls cement from the tubing to the IA, measuring returns off the IA . i. Final estimated TOC in tubing is 5980’ MD j. Final estimated TOC in IA is 6025’ MD 17. PU to safety depth at ±5,200 MD and swap to contaminate. 18.RIH to cleanout/contaminate from ±5,980’ MD to surface. 19.POOH and circulate coil tubing clean as needed. 20.Stop to freeze protect tubing from ~2500’ as needed. 21.RDMO Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads) O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.com Hilcorp Alaska, LLC | Anchorage, AK 99503 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, January 31, 2022 10:33 AM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] V-213i (PTD 204-116) Change to approved Sundry Hi Wyatt, Just going over the V-213i Sundry application. A couple questions/comments: 1. Are you planning to perform this CT work with a lubricator and stripper, or open hole? 2. There are a couple points in the procedure where your cement has the opportunity to move unintentionally between the tubing and IA, potentially leaving TOC where you don’t want it. Since there are only 2 bbls of cement planned into the IA, you could lose all of it if the CT crew is not careful. It’s important to the AOGCC because we won’t have the opportunity to verify the cement top in the IA. a. In step 16.k., depending on the fluid density in the IA compared to the fluid density in the tubing, when you open returns from the IA and pump 2 bbls into the IA, fluid might U-tube into the IA, putting more cement into the IA than intended. You can address this issue by measuring the 2 bbls returned from the IA, rather than measuring the 2 bbls pumped into the IA. b. In step 20, when you freeze protect tubing from 2500’, if there is less freeze protection in the IA than in the tubing, the fluids will be out of balance and the cement can U-tube back into the tubing while you are freeze protecting. You could address this by maintaining back-pressure on the tubing until you get to surface and close the return valve, but that relies on a choke operator being on top of his game for the entire operation. If he let’s pressure drop, U-tubing can occur. If you are confident that there is freeze protection fluid in the IA to at least 2500’, then U-tubing shouldn’t occur, even if the choke operator lets pressure go to 0 psi. c. Both of these issues could probably be ignored if you pumped a larger volume of cement into the tubing and IA. It begs the question, why such a small volume of cement when you are cutting almost 2500’ above planned TOC? It would be cheap insurance to pump more cement. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the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y Samantha Carlisle at 9:00 am, Dec 17, 2021 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV KRXUQRWLFHWR$2*&&WRZLWQHVVVOLFNOLQHWDJDQG0,77WRSVL $2*&&WRZLWQHVV0,7,$WRSVL 6)'0*5'(& '65 dts 12/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.12.22 15:09:47 -09'00' RBDMS HEW 12/28/2021 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭϮͬϭϲͬϮϭ tĞůůEĂŵĞ͗sͲϮϭϯ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϮϭϯͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KŶůŝŶĞt'/ŶũĞĐƚŽƌ WĂĚ͗WhsͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶƵĂƌǇ ϮϬ ƚŚ ϮϬϮϮ ZŝŐ͗ŽŝůdƵďŝŶŐ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ďďŝĞĂƌŬĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϰͲϭϭϲ &ŝƌƐƚ ĂůůŶŐŝŶĞĞƌ͗tǇĂƚƚZŝǀĂƌĚ ;ϵϬϳͿϳϳϳͲϴϱϰϳ;KͿ ;ϱϬϵͿϲϳϬͲϴϬϬϭ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ƌŽĚŝĞtĂŐĞƐ ;ϵϬϳͿ ϱϲϰͲϱϬϬϲ ;KͿ ;ϳϭϯͿ ϯϴϬͲϵϴϯϲ ;DͿ &EƵŵďĞƌ͗ϮϭϱͲϬϯϳϭϴ :ŽďdǇƉĞ͗ŽŝůWůƵŐďĂĐŬ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϭ͕ϳϱϭ ƉƐŝΛ ϰϰϬϬ͛ds ;^,W ϳͬϮϵͬϮϬϭϮ Dtс ϳ͘ϳ ƉƉŐͿ DĂǆŝŵƵŵ ǆƉĞĐƚĞĚ,W͗ϭ͕ϳϱϭƉƐŝΛϰϰϬϬ͛ds ;Dtс ϳ͘ϳ ƉƉŐͿ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐ͗ϭ͕ϯϭϭ ƉƐŝ ;Ϭ͘ϭ ƉƐŝͬĨƚ ŐĂƐŐƌĂĚŝĞŶƚͿ DŝŶ/͗ϯ͘ϳϮϱ͟ yEΛϵϳϰϱ͛D DĂǆŶŐůĞ͗ϰϰĞŐΛϴϰϯϭD ZĞĨĞƌĞŶĐĞ>ŽŐ͗dƵďŝŶŐdĂůůǇĚĂƚĞĚϳͬϮϲͬϬϰ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ sͲϮϭϯŝƐĂŶĂĐƚŝǀĞt'ŝŶũĞĐƚŽƌŝŶƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨ ĨŽƌŵĂƚŝŽŶ͘dŚĞǁĞůůŚĂƐůŝŵŝƚĞĚƵƚŝůŝƚǇǁŝƚŚDƐƚŽŽĨĨƐĞƚ ƉƌŽĚƵĐĞƌ;ƐͿŝŶKĂŶĚK͘dŚĞǁĞůůŝƐƉůĂŶŶĞĚĨŽƌĂŶƵƉĐŽŵŝŶŐƐŝĚĞƚƌĂĐŬĨŽƌŝŵƉƌŽǀĞĚͬĐŽŶƚŝŶƵĞĚƐƵƉƉŽƌƚŽĨ ŽĨĨƐĞƚƐ ŝŶĂĚĚŝƚŝŽŶƚŽ ĂŶ ƵƉĐŽŵŝŶŐŶĞǁĚƌŝůů ƉƌŽĚƵĐĞƌ͘ WƌŝŽƌƚŽƐŝĚĞƚƌĂĐŬŝŶŐ͕ƚŚĞĞǆŝƐƚŝŶŐƌĞƐĞƌǀŽŝƌŵƵƐƚďĞWΘ͛ĚĂŶĚǁĞůůƉƌĞƉƉĞĚĨŽƌƐŝĚĞƚƌĂĐŬ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x K'ǁŝƚŶĞƐƐ D/dͲ/ ƉĞƌĨŽƌŵĞĚƚŽϭϲϰϲ ƉƐŝ ŽŶϯͬϭϰͬϮϭ KďũĞĐƚŝǀĞ͗ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐǁŽƌŬŝƐƚŽ ĐŽŵƉůĞƚĞƌĞƐĞƌǀŽŝƌĂďĂŶĚŽŶŵĞŶƚŽĨƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨĨŽƌŵĂƚŝŽŶĂŶĚĐƵƚƚƵďŝŶŐ ŝŶƉƌĞƉĞƌĂƚŝŽŶ ĨŽƌƵƉĐŽŵŝŶŐsͲϮϭϯƌŽƚĂƌǇƐŝĚĞƚƌĂĐŬ͘ ^ƵŶĚƌǇWƌŽĐĞĚƵƌĞ ^ůŝĐŬůŝŶĞ Θ,ŽƚKŝů ϭ͘ D/Zh^>ĂŶĚWd͘ Ϯ͘ Z/,ĂŶĚƉƵůůZDyƉƌŽŶŐĂŶĚƉůƵŐďŽĚǇĨƌŽŵϲϴϭϳ͛D͘ ϯ͘ ŽŶĨŝƌŵŝŶũĞĐƚŝǀŝƚǇŽĨĂƚůĞĂƐƚϮWDŝŶƚŽKĂƚϮϬϬϬƉƐŝ͘ Ă͘ /ĨŝŶũĞĐƚŝŽŶƌĂƚĞŝŶƐƵĨĨŝĐŝĞŶƚ͕ƉƵůůĚŵǇ ǀĂůǀĞ;ƐͿĂƐŶĞĞĚĞĚƐƚĂƌƚŝŶŐǁŝƚŚĚĞĞƉĞƐƚǁĂƚĞƌĨůŽŽĚ ŵĂŶĚƌĞůƵŶƚŝůŝŶũĞĐƚŝǀŝƚǇĂĐŚŝĞǀĞĚ͘ ϰ͘ Z/,ĂŶĚƉƵůů'>sĨƌŽŵ'>DĂƚϲϯϰϳ͛DĂŶĚůĞĂǀĞƉŽĐŬĞƚŽƉĞŶ Ă͘ sĞƌŝĨǇŝŶũĞĐƚŝǀŝƚǇŽĨĂƚůĞĂƐƚϮWDĚŽǁŶƚŚĞ/ƚŚƌŽƵŐŚ '>s ĂƚϮϬϬϬƉƐŝŵĂǆƉƌĞƐƐƵƌĞ͘ ϱ͘ ZDK ůŝŶĞ ϲ͘ D/Zh>ĂŶĚWd͘ ϳ͘ DhϰͲϭͬϮ͟ ƐůĞĞǀĞƐƚǇůĞ;ƚĞƐƚĂďůĞͿ ĐĞŵĞŶƚƌĞƚĂŝŶĞƌ͘ ϴ͘ Z/,ĂŶĚƐĞƚƌĞƚĂŝŶĞƌĂƚ цϲϯϳϱ͕͛ ďĞůŽǁ ŽƉĞŶƉŽĐŬĞƚ Ă͘ D/dͲdǆ/ƚŽϭϬϬϬƉƐŝƚŽĐŽŶĨŝƌŵŐŽŽĚƐĞƚ͘ ď͘ dŝĞͲ ŝŶƚŽƚƵďŝŶŐƚĂůůǇĚĂƚĞĚϳͲϮϲͲϮϬϬϰ ϵ͘ ZDK ĂĐƚŝǀĞt'ŝŶũĞĐƚŽƌǁĞůůŚĂƐůŝŵŝƚĞĚƵƚŝůŝƚǇǁŝƚŚDƐƚ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭϮͬϭϲͬϮϭ ŽŝůdƵďŝŶŐ ϭϬ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚ ĂŶĚƐƉŽƚ ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚ͘ ϭϭ͘ WƌĞƐƐƵƌĞƚĞƐƚKW ϭϮ͘ Z/,ĂŶĚƐƚŝŶŐŝŶƚŽ ĐĞŵĞŶƚ ƌĞƚĂŝŶĞƌƐĞƚĂƚ ц ϲϯϳϱ͛͘ Đ͘ ƐƚĂďůŝƐŚ ŝŶũĞĐƚŝŽŶ ƉƌĞƐƐƵƌĞĂƚΕϮWD ǁŚŝůĞƐƚƵŶŐŝŶƚŽ ƌĞƚĂŝŶĞƌ͘ Ě͘ DŽŶŝƚŽƌ d^ƉƌĞƐƐƵƌĞďĞĨŽƌĞĂŶĚĂĨƚĞƌƐƚŝŶŐŝŶŐŝŶƚŽƌĞƚĂŝŶĞƌ ƚŽĐŽŶĨŝƌŵƐƚƵŶŐŝŶ͘ ϭϯ͘ ĞŐŝŶƚŽ ŵŝǆ ϭϱ͘ϴƉƉŐĐůĂƐƐ' ĐĞŵĞŶƚ͘KŶĐĞďůĞŶĚƐĂƌĞƵƉ͕ ƉƵŵƉцϮϬ ďďůƐ ůĂƐƐ'ĐĞŵĞŶƚĚŽǁŶƚŚĞ ĐŽŝůƚƵďŝŶŐ ǁŝƚŚďĂĐŬƐŝĚĞ^/͘ Ğ͘ /ŶĐƌĞĂƐĞĐĞŵĞŶƚǀŽůƵŵĞƚŽĂĐĐŽƵŶƚĨŽƌϰͲϭͬϮ͟ǆϳ͟ĂŶŶƵůĂƌƐƉĂĐĞŝĨ Őůǀ;ƐͿǁĞƌĞŽƉĞŶĞĚƵƉŝŶ ƐůŝĐŬůŝŶĞƐƚĞƉϯϬ Ĩ͘ ƵůůŚĞĂĚĨůƵŝĚƐŝŶƚŽK ƐĂŶĚƐĂŚĞĂĚŽĨĐĞŵĞŶƚ͘ Ő͘ hƐĞĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌƐĂƐŶĞĞĚĞĚĂƌŽƵŶĚƚŚĞĐĞŵĞŶƚ͘ Ś͘ ŽŝůĐĂƉĂĐŝƚǇĞƐƚ цϭϯ͘ϱ ďďů;ϲϯϳϱ͛ ŽĨ ϭ͘ϳϱ͟Žŝů ǁͬϬ͘ϭϰϱ͟ǁĂůůͿ͘ ϭϰ͘ ^ǁĂƉƚŽϭй<>ĨŽƌĚŝƐƉůĂĐĞŵĞŶƚĂŶĚĂƚƚĞŵƉƚƚŽ ŝŶũĞĐƚĨƵůůǁĞůůďŽƌĞǀŽůƵŵĞŽĨĐĞŵĞŶƚďĞůŽǁƌĞƚĂŝŶĞƌ ŽĨ ;цϭϲ ďďůƐͿƉƌŝŽƌƚŽƵŶƐƚŝŶŐŝŶŐ͘ ŝ͘ ŽŶŽƚĞǆĐĞĞĚ ϭϬϬϬƉƐŝĂďŽǀĞ ŝŶŝƚŝĂůŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞ ũ͘ &ƵůůǁĞůůďŽƌĞĐĂƉĂĐŝƚǇďĞůŽǁƌĞƚĂŝŶĞƌĞƐƚ цϭϲ ďďůƐ ŝ͘ ϰϬϬ͛ŽĨ͘ϬϬϴϳďƉĨϯͲϭͬϮ͟ ŝŝ͘ ϯϬϬ͛ŽĨ͘ϬϯϳϭďƉĨϳ͟ ŝŝŝ͘ ϭϬϬ͛ŽĨ͘ϬϭϱϮďƉĨϰͲϭͬϮ͟ ϭϱ͘ hŶƐƚŝŶŐĨƌŽŵƌĞƚĂŝŶĞƌĂŶĚůĂǇĐĞŵĞŶƚŝŶĂƚϭ͗ϭƵƉ ĨƌŽŵ ϲϯϳϱ͛DƚŽϲϭϭϬ͛D͘ Ŭ͘ >ĂǇŝŶ ĨŝŶĂů цϰ ďďůƐŽĨĐĞŵĞŶƚ͘ ϭϲ͘ ŝƐƉůĂĐĞ Ϯ ďďůƐĐĞŵĞŶƚĨƌŽŵƚŚĞƚƵďŝŶŐƚŽƚŚĞ/͕ƚĂŬŝŶŐƌĞƚƵƌŶƐŽĨĨƚŚĞ/͘ ů͘ ϭϬϬĨƚŽĨdƵďŝŶŐĂŶĚ/ ĐĂƉĂĐŝƚǇĂďŽǀĞƚŚĞƌĞƚĂŝŶĞƌĞƐƚ Ăƚ ϯ͘ϰďďůƐ ŝ͘ ϭϬϬ͛ŽĨ͘ϬϭϱϮďƉĨϰͲϭͬϮ͟ ŝŝ͘ ϭϬϬ͛ŽĨ͘ϬϭϴϲďƉĨ ϰͲϭͬϮ͟ǆϳ͟ ĂŶŶƵůƵƐ ŵ͘ &ŝŶĂůĞƐƚŝŵĂƚĞĚdKŝŶƚƵďŝŶŐŝƐϲϮϰϰ͛D Ŷ͘ &ŝŶĂůĞƐƚŝŵĂƚĞĚdKŝŶ/ŝƐϲϮϰϬ͛D ϭϳ͘ WhƚŽƐĂĨĞƚǇ ĚĞƉƚŚĂƚцϲ͕ϬϬϬ D ĂŶĚƐǁĂƉ ƚŽĐŽŶƚĂŵŝŶĂƚĞ͘ ϭϴ͘ Z/,ƚŽ ĐůĞĂŶŽƵƚͬĐŽŶƚĂŵŝŶĂƚĞ ĨƌŽŵ цϲ͕ϮϰϬ͛ D ƚŽƐƵƌĨĂĐĞ͘ ϭϵ͘ WKK,ĂŶĚĐŝƌĐƵůĂƚĞĐŽŝůƚƵďŝŶŐĐůĞĂŶĂƐŶĞĞĚĞĚ͘ ϮϬ͘ ^ƚŽƉƚŽĨƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐ ĨƌŽŵΕϮϱϬϬ͛ Ϯϭ͘ ZDK ^ůŝĐŬůŝŶĞŶĚ,ŽƚKŝů ϮϮ͘ EŽƚŝĨǇK'ĂƚůĞĂƐƚϮϰŚƌƐƉƌŝŽƌƚŽƉůƵŐƉƌĞƐƐƵƌĞƚĞƐƚŝŶŐĂŶĚĚĞƉƚŚǀĞƌŝĨŝĐĂƚŝŽŶ͘ Ϯϯ͘ D/Zh ^>ƵŶŝƚ ĂŶĚ,ŽƚKŝů Ϯϰ͘ Z/,ǁŝƚŚĚƌŝĨƚ ĂŶĚƚĂŐĐĞŵĞŶƚƉůƵŐ͕ĞƐƚŝŵĂƚĞĚĂƚ ϲϮϰϬ͛ D Ϯϱ͘ D/dͲdƚƵďŝŶŐƚŽ ϮϬϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ Ϯϲ͘ ^ǁĂƉŽǀĞƌĂŶĚD/dͲ/ƚŽ ϮϬϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶƵƚĞƐ Ϯϳ͘ ZDK ůŝŶĞ Ϯϴ͘ D/Zh>ĂŶĚWd͘ Ϯϵ͘ DhϰͲϭͬϮ͟:ĞƚƵƚƚĞƌ ϯϬ͘ Z/,ĂŶĚĐƵƚŵŝĚũŽŝŶƚŝŶϰͲϭͬϮ͟ƚƵďŝŶŐĂƚΕϯϳϬϬ͛D Ă͘ dĂƌŐĞƚtŚŝƉƐƚŽĐŬͬtŝŶĚŽǁĚĞƉƚŚΕϯϱϱϬ͛D ϯϭ͘ sĞƌŝĨǇŝŶũĞĐƚŝǀŝƚǇ ƚŚƌŽƵŐŚƚŚĞĐƵƚĚĞƉƚŚ ϯϮ͘ ZDK 6WDWHWRZLWQHVV 6WDWHWRZLWQHVV tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭϮͬϭϲͬϮϭ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW ^ĐŚĞŵĂƚŝĐ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭϮͬϭϲͬϮϭ ƐƵŝůƚ^ĐŚĞŵĂƚŝĐ͗ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗ sͲϮϭϯ ĂƚĞ͗ ϭϮͬϭϲͬϮϭ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ͗ MEMORANDUM State of Alaska Permit Number: 204-116-0 Alaska Oil and Gas Conservation Commission TO: 1im Regg �,t ,{ `f lq (1tu DATE: Friday, March 19, 2021 P.I. Supervisor ' IP � SUBJECT: Mechanical Integrity Tests l Hilcorp Norlh Slope. LLC Well V-213 FROM: Jeff Jones PRUDHOE BAY ON ORIN V-213 Petroleum Inspector 4421 Tubing Src: Inspector 978 Reviewed By: P.I. Suprl jE— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-213 API Well Number 50-029-23213-00.00 Inspector Name: Jeff Jones Permit Number: 204-116-0 Inspection Date: 3/14/2021 - [nsp Num: mitIJ210316135039 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well v-213 " Type Inj N' TVD 4421 Tubing 972 978 970 PTD 2041160 �'Pe Test SPT' Test psi Isoo IA 261 1712 1661 1646 " BBL Pumped: 1 BBL Returned: 1 1.1 OAzas 287 - Interval 4YRTST ' P/17 P Notes: I well inspected, no exceptions noted, ✓ Friday, March 19, 2021 Pane I of I 1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Thursday, September 3, 2020 11:04 AM To:Winston, Hugh E (CED) Subject:FW: Cancellation: Sundry #319-528 for V-213 (PTD 204-116) From:Rixse,MelvinG(CED)<melvin.rixse@alaska.gov> Sent:Wednesday,September2,20203:53PM To:AbbieBarker<Abbie.Barker@hilcorp.com> Cc:Carlisle,SamanthaJ(CED)<samantha.carlisle@alaska.gov> Subject:RE:Cancellation:Sundry#319Ͳ528forVͲ213(PTD204Ͳ116) Abbie, Noted.Thanks. MelRixse SeniorPetroleumEngineer(PE) AlaskaOilandGasConservationCommission 907Ͳ793Ͳ1231Office 907Ͳ223Ͳ3605Cell CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission(AOGCC), StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,useor disclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwardingit, and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactMelRixseat(907Ͳ793Ͳ1231)or(Melvin.Rixse@alaska.gov). CCSamanthaCarlisle From:AbbieBarker<Abbie.Barker@hilcorp.com> Sent:Wednesday,September2,20203:40PM To:Rixse,MelvinG(CED)<melvin.rixse@alaska.gov> Cc:BrodieWages<David.Wages@hilcorp.com>;WyattRivard<wrivard@hilcorp.com>;JoeKaiser <jkaiser@hilcorp.com>;StanGolis<sgolis@hilcorp.com> Subject:Cancellation:Sundry#319Ͳ528forVͲ213(PTD204Ͳ116) GoodAfternoonMel, Uponreview,HNSwillnotbeexecutinganyoftheworkcoveredbySundry#319Ͳ528.ThissundrycoveredanMBE treatmentonWellVͲ213(PTD#204Ͳ116)andwasapprovedbytheCommissiononNovember21,2019.Pleasecancel Sundry#319Ͳ528. Thankyou, Abbie RBDMS HEW 9/4/2020 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bernhard Stechauner GC2 Lead PE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU V-213 Permit to Drill Number: 204-116 Sundry Number: 319-528 Dear Mr. Stechauner: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J .Price Chair !� DATED this 1d day of November, 2019. 1BDMSf"/NOV 212019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 21 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other MBE Treatment 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 204-116 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ® 6. API Number: 50.029-23213-00-00 7. IF perforating: What Regulation or Conservation Ober governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU V-213 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028240 PRUDHOE BAY, SCHRADER BLUF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (it): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7225 4985 6817 4671 6817 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" X 34" 32-110 32-110 Surface 3410 9-5/8" 31-3442 31-2692 5750 3090 Intermediate Production 7176 7" 29-7205 29-4969 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6582 - 6937 4496 - 4761 4-J/ /2" 12.6# x 3-1/2" 9.2# L-80 26-6829 Packers and SSSV Type: 3-1/2" Baker Premier Ret. Packer Packets and SSSV MD (ft) and TVD (ft): 6479/4421 3-1/2" Baker Premier Ret. Packer 6653/4549 4-12" Baker S-3 Packer 6781 / 4644 4-1/2" HES Red Spyder Valve 3076/2496 12. Attachments: Proposal Summary a Wellbore Schematic El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: 11/29/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herem will not Contact Name: Stechauner, Bernhard be deviated from without prior written approval. Contact Email: Bemhard.Stechauner@bp.com Authorized Name: Stechauner, Bernhard Contact Phone: +1 907 564 4594 Authorized Title: GC2 Lead PE ' Authorized Signature:�- % Date: ��i �.�:I/ I✓ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IBDMS �"'/ Nov 2 12019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing E tion Required? Yes ❑ No Subsequent Form Required: q6* Approved by: COMMISSIONER APPROVED BYTHE C COMMISSION JQ1Jq I Date!I Form 10-403 Revised 04/2017 ORIGINAL RECEIVE® NOV 18 2019 Submit Form and Approved application is valid for 12 months from the date of approy�I. �O f4tt��s in Duplicate � III19rk v 10-403 Sundry Application for Well PBU V-213 PTD #204-116 Expected Start Date: November 29, 2019 Current condition of well: WAG Injection Well, Operable, Online: Gas Injection Rate: 650 Mscf/Day Injection Pressure: 1701 psi Reservoir Pressure (OA): 1077 psi Program Objective(s): The goal of this program is to seal off the OA MBE with MARCIT gel, to improve waterflood pattern sweep efficiency, OOIP recovery and reduce V -204's WC. Pending a successful treatment in the OA, the OBa will be Red -Dye tested and treated. The OA zone is currently capable of injecting 3 bpm at zero WHIP. Success will be measured as an injectivity of less than 1.5 bpm at 1000 psi. This is in-line with what is considered to be matrix flow in the OA zone. Proposed Program: 1. Pump MARCIT gel treatment to fill MBE void space and prevent short circuiting of injection fluids to V-204. 2. Flow back V-204 to monitor for gel returns. 3. Determine MBE treatment success by conducting open pocket injectivity test and monitoring sandface pressures. BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU V-213 PTD #204-116 Pump Schedule: Pumping Schedule (INJ) well V-213 Fluid T Work Desc I 0 ' Test Rate (bpm) AFE _ APBSURVE Post-MARCIT In Test Date WI&i8 700 Meer Alex You mun 2 Phone 9075644864 TBG H2S Value NA H2S Date NA Perform post-treatment injectivity fest on OA and SRTs once valves have been set. Pump Schedule Peh0rm post-MfARCIT injectivity test on OA zone to determine if MBE has been repaired. Target pressures are 400, 600. 800, 7000 and 7200 psi with a maximum rate of 3 bpm. Hold each step for at least 10 minutes. Hold at pressure step longer if rate has not Stabilized - Allow rate and pressure to stabilize before increasing pressure_ Perform SRT at 800, 1000, 1200 and 1400 psi once ST43 is set. Target 0.22 bpm (+1-75%). -Hold each step for 10 minutes. Once obtain a passing test, SL to pull PX plug and perform cumulative SRT. Target 0.66 bpm (+1- I5%). - Hold each step for 10 minutes. If cumulative test fails, SL to troubleshoot. Repeat SRT as necessary. - Each valve is sized for 022 bpm on crude. Adjust target rates accordingly while troubleshooting. Maximum allowable Injection rate is t bpm with We valves set. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 MIT #3 Test Type Inq Pressure Max ied Pressure Test Fluid Integrity Um(ts Confirmed St Fluid T P Into Volume (bbls) Rate (bpm) Pressure 7 Post-MARCIT In Test Crude TBG 700 3 max) See below 2 W FRN SRTs Crude TBG 150 See below See below 3 4 5 6 7 Peh0rm post-MfARCIT injectivity test on OA zone to determine if MBE has been repaired. Target pressures are 400, 600. 800, 7000 and 7200 psi with a maximum rate of 3 bpm. Hold each step for at least 10 minutes. Hold at pressure step longer if rate has not Stabilized - Allow rate and pressure to stabilize before increasing pressure_ Perform SRT at 800, 1000, 1200 and 1400 psi once ST43 is set. Target 0.22 bpm (+1-75%). -Hold each step for 10 minutes. Once obtain a passing test, SL to pull PX plug and perform cumulative SRT. Target 0.66 bpm (+1- I5%). - Hold each step for 10 minutes. If cumulative test fails, SL to troubleshoot. Repeat SRT as necessary. - Each valve is sized for 022 bpm on crude. Adjust target rates accordingly while troubleshooting. Maximum allowable Injection rate is t bpm with We valves set. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 MIT #3 Test Type Inq Pressure Max ied Pressure Test Fluid Integrity Um(ts Confirmed 10-403 Sundry Application for Well PBU V-213 PTD #204-116 Wellbore Schematic: SPF ZOfE MHNAL -- -- — NlL1EAD= Fm; V-213 SAFE SAFETY NOTES: H23 REANNG5 AVERAGE 125 PPm ACSWTOR= 641072 0592 - 6627 YI ^'WaL R®'SA SSSY WNBI ON YI "• GIB. fiE4 - 81..8'. DMY TG 14-12' X4-12' -- �.aFv= sa:s' 00a 1025 9 -se TAMPDRrcauRD=e.aia j KOP= 3w 0 0728/15 MY.3 An* _ 59' � 3093', 2(P' CONIXIOTOR ^ 106' 5 3076' 4-12' "M X NP, D= 3.813' DWImMD= 6585•: 064917 70=204=M4 400, Minimum ID = 2.813" @ 6634' 13-1/2" HES X NIPPLE 46S0RATDN SL AWRY Rff LOG: USIT ON 0725'64 ANCLEAT TOPPERF: 43' Q 0582' lion' T4P(M M lRMirtiMn rYi f... I.i�..vJ �A�_r SIZE SPF ZOfE MHNAL _ ST MD ND DEV _TYPEYLV S07. ' 412' S OA 0592 - 6627 36313 4519 42 MMO-W DMY TG 14-12' X4-12' 5 00a 5667-6702 DMY RK 0 0728/15 1 6739 5 08E 6717-6742 064917 70=204=M4 4-12' 5 OBd 68V-6937 312' TBG. 911, L -i6 TDI, .0087 bpr, 6—= 2992'�--�- tem 7123' _. meals; bLiWJAi) s! -:r hx 19 uc j1lnane) 01/14/191 MSIJW WFRGO(11112110) —j 14534' - j j!LH15 X til. t) IIT WATERFLGOD MANDRELS _ ST MD ND DEV _TYPEYLV _ LATCH DMY RK PORT 0 _ GATE 022&19 4 8552 {4761 43 MM6W 36313 4519 42 MMO-W DMY TG 0 07W/19' 2 6679 1 458342 :� IM46-W DMY RK 0 0728/15 1 6739 4613 42 MIIO-W P 15XJR RK I 15L 064917 X842' 312' ME.9XNP,D n2e13' 6663• 7' % 312' 8KR FRBA 802, D= 6766' 312•FBXtF,D=2.613'1 6778' 2'XO,D=2.930' 6781' TX 412'(6(8 S3 PRR D=3. 676 i� 4-i2'%3-12'XQ D-2930' 6886' 312'FF.i%FP,D=2.813' 681r n31/7'FES XPW. D=2.813' 8877 ] 12' Rio( HOOP & 0.15%,81M /5a4-LPORT(SETW19117) was f131/Y WLEG, D-3.OQ" 6828' ft.lxtl acr,Fnlw n:mt nx 415 ORON LRT _ NELL V213 Align PEFWNb:F041160 API lb: 50-029.23213-00 SEC1i,T11RR"F 552 RV.8151T FwR - ... SP ExpMrAlm4(AwW BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED n n nn1n Form 10-400 Revised 04/2017RRgDWEW EB U Submit Original Only 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations (r� f ❑ yg�hu((tItl�p��ww((Dg,,�� Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change A�lry0p.4/Parc CID Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: MBE Treatment 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 11 Exploratory ❑ 5. Permit a Drill Number. 204-116 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Stratigraphic ❑ Service RI 1 6. API Number. 50-029-23213-00-00 7. Property Designation (Lease Number): ADL 028240 8. Well Name and Number: PBU V-213 9. Logs (List logs and submit electronic and panted data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, SCHRADER BLUF OIL 11. Present Well Condition Summary. Total Depth: measured 7225 feet Plugs measured 6817 feet true vertical 4985 feet Junk measured None feet Effective Depth: measured 6817 feet Packer measured 6479 16653 / 6781 feet true vertical 4671 feet Packer true vertical 4421 / 4548 14643 feet Casing: Length: Size: MD: TVD: Burst: Collapse Structural Conductor so 20" x 34" 32-112 32-112 Surface 3410 9-5/8" 31 -3442 31 -2692 5750 3090 Intermediate Production 7176 7" 29-7205 29-4969 7240 5410 Liner Perforation Depth: Measured depth: 6582-6627 feet True vertical depth: 4496-4761 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# x 3-1/2" 9.2#, L-80 26-6829 26-4413 3-1/2" Baker Premier Ret. Packer 6479 4421 Packers and SSSV (type, measured and 3-1/2" Baker Premier Ret. Packer 6653 4548 true vertical depth) 4-1/2" Baker S-3 Packer 8781 4643 12. Stimulation or cement squeeze summary: Pump MARCIT Gel Treatment into OA Zone. HES pumped 30 bbls of 2% KCL Q 80 deg F, 30 bible of 10m ppm linear gel spacer, 70 bible of 15% accelerated gel @ 10m ppm and 30:1 polymer to crosslinker. Intervals treated (measured): OA Zone Treatment descriptions including volumes used and final pressure: 100 bbis MARCIT Gel. Final Pressures: OA = 450 psi, IA = 300 psi, TBG = 1100 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 374 50 1100 Subsequent to operation: 0 0 1216 300 1100 14. Attachments: (required psr2o MC 25070.25 071. &25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 herebycervi that the foregoing y g Sundry Number or N/A if C.O. Exempt: y regoin is true and corcect [o the best of m knowledge. 318-018 Authorized Name: Youngmun, Alex Contact Name: Youngmun, Alex Authorized Title: Kuupawk Bluff PE Contact Email: younakQBP.com ``Schrader Authonzed Signature: f v ` W n Date: gigi fin,Contact Phone: +1 907 564 4864 Form 10-400 Revised 04/2017RRgDWEW EB U Submit Original Only Daily Report of Well Operations PBU V-213 ACTIVITYDATF RI IMMARY ***WELL INJECTING ON ARRIVAL*** (Reservoir Sweep Mod) LRS FREEZE PROTECTED THE TBG & FL. DRIFTED W/ 2.805" G -RING TO RMX PRONG @ 6798' SLM. SET 3-1/2" PX -PLUG BODY @ 6629' SLM (6642' MD). SET 98" P -PRONG W/3-1/2" BAIT SUB ON TOP @ 6629' SLM (6642' MD). PULLED ST #4 RK-DMY GLV FROM 6543' SLM (6552' MD). SET BP SPMG IN ST #4 @ 6543' SLM (6552' MD). TAGGED ST #4 W/ 1.75" LIB (IMPRESSION OF RK LATCH). PULLED TG-WFRV FROM ST#3 6605' SLM (6613' MD). 11/12/2018 ***JOB CONTINUED ON 13-NOV-2018*** ***CONTINUE WSR FROM 11/12/18 SWCP 4518***(reservoir sweep mod) BRUSH & FLUSH W/ 4-1/2" BRUSH & 2.805" G -RING TO 6629' SLM. ***WELL LEFT S/I ON DEPARTURE*** 11/13/2018 ***ST#3 @ 6613' MD LEFT EMPTY*** HES Pumping Services Job Scope: MARCIT gel to repair MBE between V-2131 and V-204 in Schrader Bluff OA Zone. RU HES & LRS pumps. LRS injected 200 bbis of 110 deg F diesel down well to warm tubulars. HES pumped 30 bbis of 2% KCL @ 80 deg F, 30 bbis of 10m ppm linear gel spacer, 70 bbis of 15% accelerated gel @ 10m ppm and 30:1 polymer to crosslinker, 30 bbis of 2% 1/6/2019 KCL, 42 bbis Diesel. ***Job Com Tete** ***WELL S/I ON ARRIVAL*** (Reservoir sweep mod) LRS ATTEMPTED POST MARCIT GEL TREATMENT INJECTIVITY TEST ON OA ZONE. LRS PUMPED 115 BBLS OF CRUDE AT 3 BPM & NEVER CAUGHT ANY PRESSURE. SET TG-P15XJR AT ST #3 (6,613' MD). LRS PERFORMED STEP RATE TEST ON WFR IN ST #3 (High but OK'd by WSL). 1/18/2019 *"*JOB IN PROGRESS, CONTINUED ON 1/19/19 WSR*** ***CONTINUED FROM 1/18/19 WSR*** (Reservior sweep mod) PULL P -PRONG & 3-1/2" PX PLUG BODY FROM 6,626' SLM / 6,642' MD. LRS PERFORMED SUCCESSFUL STEP RATE TEST ON FULL WFR DESIGN. ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** 1/19/2019 1DRIFT TO 3,100' SLM W/ 3.70" x 20' DUMMY WHIPSTOCK FOR SUBSIDENCE SURVEILLANCE. Taff = - 4-1116• CNV VWEIJiFAD= RMC ACTUATOR= BAKER OKB. ELB/ = 82.9 BF. BEV = 54.3 KOP= 300 Max Angle = 59" @ 3193' Datum MD= 6564' Datum TVD = 4400 SS 1 106' A 9-5/8- CSG, 40#, L -BO BTC, D = 8.835" —L 3447 T MAw m rr vw RA TAG 6603' Minimum ID =2.813" @ 6534- 3-112" HES X NIPPLE TBG, 12.6#, L -W TCI, .0152 bpf, ID = 3.958" 6468' T MARCOR "ff W1 RA TAG —6520- 13-112" MARK 520' 13.12"MARKS RJOMw/RA TAG H 6622' I PERFORATDN SUMMARY Rr'F LOG: USIf ON 0725/04 ANGLE AT TOP PERF: 43'@6582' Wte: Infer to Production DB for historical perf data SIZE SPF ZONE WE RVAL OprVSgz SHOT SOZ 4-12" 5 OA 6582-6627 O 0724104 6613 4-12' 5 08a 6667-6702 O 0724104 2 4-12' 5 OBb 6717-6742 O 0724104 0728115 4-12' 5 OBd 6862-6937 O 0724/04 RK 15L 9.2#, L-80 TCI, .0087 bpf, D = 2.992' 6829' 7" CSG, 26#, L -BO BTC -M, .0371 bpf, D = 6.276" 7205' V-213 SAFETY WFBI ON M NOTES: WELL RBQREADINGS S V WHEN ON MAVBtAGE 125 I — IC7S-7III21E:\ur7:tIC-1 646T 1—J4-12" FES X NP, D = 3.813" 6479' H 7- X 3-12' BKR FROM PK R, 1 j3-12'HESXNP,D=2.813" WATRZFLOOD MANORRS ST RUITVDIDEVI 07/27104 TARLP INITIAL COMPLETION 0121/19 EPC/JMJ GLV 00 (01118/19) TYPE I VLVLATCH PORE DATE 4 6552 4474 43 MMG-W SPMG RK 0 11/12/18 3 6613 4519 42 MMG-W R15XJR TG 15L 01/18119 2 6679 4568 42 MMG-W DMV RK 0 0728115 1 6739 4613 42 MIIG•W R15XJR RK 15L 08/19/17 I T X 3-12" BKR PREM PKR D= 2.875' I 6768' —13-1/2- FES X NP, D = 2.813- 677W 3-12' X 4-12" XO, D = 2.930" 6781' H 7" X 4-12" BKR S-3 PKR D = 6785' 11 4-12" X 3-12' XO, D = 2.930' 3-12" FES X NP, D = 2.813" 68� 312'FESXNP,D=2.813' 15/64"L PORT (SIT 08119/17) 6829' 312" WLEG, D= 3.00" 6829' ELMD LOGO ON 07/01/05 DATE RB/ BY COMMENTS DATE FEV BY COMMENTS 07/27104 TARLP INITIAL COMPLETION 0121/19 EPC/JMJ GLV 00 (01118/19) 09/11/15 CJNJMJ VVFR aO & RMX BODY CRDATE (07 0121/19 EPD/JMT RJLL13D PXN (LUG (01119119) 0823/17 TFA/JMD WFR a0 & RBOC BODY UPDATE 0125/18 EZ/JMD ADDED SPRING WBGHTTO VVFR 01/14/19 M3/JMD SETPXPLUG(11/12118) 01/14/19 M3/JMJ WFRa0(11112/18) Ow01N LW WAL: V-213 PORMT No: 82041160 AR No: 50-029-23213-00 SEC 11. TI 1 K R11 F- 56Z FN- & 1517' FEL BP Exploration (Alaska) • OF77" S \\ cv THE STATE Alaska Oil and Gas F - of® TT ee Conservation Commission ACAs tistt == 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF `�"S' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Eric Zoesch Production Engineer BP Exploration(Alaska), Inc. SCANt O PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU V-213 Permit to Drill Number: 204-116 Sundry Number: 318-018 Dear Mr. Zoesch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair J DATED this3 day of January, 2018. R DM3 LA- F'_ - 1 2018 STATE OF ALASKA JAN i s 2018 •ALASKA OIL AND GAS CONSERVATION COMMI 1 0•T5 1 1 3:..1 11 APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 ` Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other MBE Treatment RI ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-116 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service ll• 6. API Number: 50-029-23213-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No RI PBU V-213 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028240 • PRUDHOE BAY,SCHRADER BLUF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7225 • 4985 ' 6817 4671 6817 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" 32-110 32-110 Surface 3413 9-5/8" 31-3444 31 -2694 5750 3090 Intermediate Production 7179 7" 29-7208 29-4971 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6582-6937 4496-4761 4-1/2;3-1/2 L-80 26-6832 Packers and SSSV Type: 2x3.5 BKR PREM RET,4.5 BKR PREM RET Packers and SSSV MD(ft)and TVD(ft): 6482/4423,6655/4550,6783/4645 4-1/2"MCX I-SSSV 3076, 2495.80 12.Attachments: Proposal Summary 0 Wellbore Schematic E] 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ® • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG RI - GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Zoesch,Eric be deviated from without prior written approval. Contact Email: zoeseO@BP.com Authorized Name: Zoesch,Eric Contact Phone: +1 907 564 4695 Authorized Title: Production Engineer Authorized Signature: - i/ Date: ///1//i COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 I Other: d Post Initial Injection MIT Req'd? Yes 0 No L9 Spacing Exception Required? Yes 0 No 1 Subsequent Form Required: /b — 4--oo Lf APPROVED BYTHE Approved by: C COMMISSIONER COMMISSION Dater I .5" 10 0 /Zb // � RE'DM'S 1,\.,-1:12 - 1 2C18 � K�.� ORIGINAL ,. 1. ‘?,/3 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) January 15, 2018 To Whom it May Concern: Attached please find the Sundry Application for Matrix Bypass Event (MBE) treatment • for well # V-213, Permit to Drill # 204-116. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR, LHD, EAZ,BPG 10/12215) General Information Well Name: V-213 Well Type: WAG Injection Well API Number: 50-029-23213-00 Well Activity Conventional 4 Classification: Activity Description: MBE Treatment Cost Code/AFE: APBINJEC Field/Reservoir: ORION 12 Month Avg IOR, bopd: Job Type: Reservoir Sweep Mod Estimated Cost, $K: AWGRS Job Scope: RESERVOIR SWEEP MOD Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Eric Zoesch Contact numbers: (907)564-4695 (406)270-9837 Well Intervention Engineer: Abhijeet Tambe Contact numbers: (907)564-4993 (907)331-9184 Lead Engineer: Ryan Rupert Contact numbers: (907)564-4238 (907)301-1736 Date Created: January 10. 2018 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate In)Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 10/30/2017 575 0 1,375 Current Status: Operable . Flowing - Inclination>70°at Depth(ft) N/A Recent H2S (date, ppm) #N/A 0 ppm Maximum Deviation(Angle and 60° 5,066'MD Depth) Datum depth,ft TVDss 4.400'TVDss Dogleg Severity(Angle and Depth) 5° 2,348'MD Reservoir pressure(date, 7/27/2015 1077 psi(OA) Minimum ID and Depth 2.813" 6.534'MD psig) Reservoir Temp, F 84° F Shut-in Wellhead Pressure 10 psi Known mech. integrity None problems(specifics) Last downhole operation(date, operation) 8/19/2017 WFRV C/O& MBE diagnostics(Red dye and open-pocket) Most recent TD tag(date,depth,toolstring OD) 8/17/2017 6,817' MD Drifted to RMX and pulled no problem Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M. fill out Non Rig Surface Equipment Checklist. Comments,well history, V-213 is a three-zone regulated injector in Orion that supports multilateral producer V-204. The well has background information,etc: known MBE's in the OA and OBa zones These MBE's were treated successfully in 2014, but the OA treatments has failed and the MBE is active again. Exact time of failure is difficult to determine due to lack of zonal pressure gauges The OBa MBE treatment appears to still be holding, as injectivity was a moderate 1.75 bpm at 600 psi in August 2017 The goal of this program is to treat the OA MBE with MARCIT gel. a new product to BP. Conoco has used • the gel several times to successfully treat MBE's. Pending a successful treatment in the OA the OBa will be Red-Dye tested and repaired in the same manner if needed. Red Dye test on the OA inticates a potential MBE volume of 60 BBLS. This zone is currently capable of injecting 3 bpm at zero WHP. Success will be measured as an injectivity of less than 1.5 bpm at 1000 psi. This is in-line with what is considered to be matrix flow in the OA zone. • S Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 2,D%. 3.Does the planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice,GP 100220(AKA 10-50),by either being documented as Legacy Equipment or having the required design assurance work completed?https://gwo.bpglobal.com/sites/gwo2/GlobalLibrary/100220.pdf Suspected Well Problem: MBE's in OA and OBa Specific Intervention or Well Objectives: 1 Prepare well for MBE treatment by opening up OA zone and isolating remainder of well 2 Pump MARCIT gel treatment into OA zone 3 Flow back V-204 and sample for gel returns 4 Perform injectivity tests on OA,then reinstall valves.Target injectivity 1.5 bpm at 1000 psi. Key risks,critical issues: Mitigation plan: MBE size estimated via Red Dye job. If severe damage 1 Incorrect gel volume causes formation damage is seen(i.e. injectivity is too low or producer loses PI), the gel can be broken up with bleach Portable testers will be on V-204 for the initial POP to 2 Incorrect gel volume causes premature failure catch any large amounts of gel that come through due to gel failure or job volume issues Extensive testing has been performed to determine gel 3 Poor gel design causes pumping issues or premature failure properties at reservoir temperature.Thickening time as well as final gel strength has been determined for various blends. Chemical incompatibility causes formation damage or issues 4 pumping the job Vendor is testing chemical compatibility Unused gel needs to be disposed of,or gel is flowed back in 5 producer Waste management plan is to be completed prior to job 6 Dirty wellbore causes gel contamination Perform B&F prior to pumping gel job 7 Diesel contaminates gel and causes issues Pump spacers anytime cross-linked gel is to be used in addition to Diesel 8 Crossflow causes contamination/misplacement of gel SI V-213 and producer V-204 three days prior to job Use Diesel when possible to minimize hydrostatic 9 Well is on vac, causing issues pumping job column. Increase viscosity of linear gel to provide increased backpressure Summary Service Line Activity Step# 1 S Prepare well for MARCIT Treatment 2 F A/SL w/B&F 3 Special Projects Pump MARCIT Treatment per detailed procedure 4 F Post-job Inj test 5 S Install live WFRV, prepare well for injection 6 T Perform flowback on V-204 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): Set PX plug at 6642' MD. 1 S Pull live WFRV from ST#3 @ 6613' MD. Perform B&F with hot dead crude(well may be on a vac). RDMO 2 F A/SL with B&F by pumping hot crude as needed Ensure V-213 and V-204 have been SI for 3 days minimum. Pump MARCIT gel treatment in V-213 per attached detailed procedure. 3 Special Projects Pump Schedule. 100 bbls 2%KCL: 150 bbls Linear:60 bbls MARCIT; 20 bbls Linear; 82 bbls Diesel This over-displaces the MARCIT 2.5 bbls into the formation. Diesel is used to lighten the hydrostatic column to reduce chances of fluid movement downhole, 4 F After 48 hours. perform post-job injectivity test with crude at 400.600.800. 1000, and 1200 psi. Maximum allowable injection rate is 3 bpm Call APE with test results. MIRU SL for WFRV reinstall. 5 S Install live WFRV, port size 15&light spring(300 bwpd) Perform SRT on single valve. targeting 0.22 bpm(+1-15%)on crude. If test passes, pull PX plug then RDMO. Bring V-204 online according to SLBU procedure. Sample every 15 minutes for gel returns,diverting to tanks if gel concentration is above 1%. 6 T Once V-204 is stable, obtain 12-hour piggyback test. After test. POI V-213 at target injection rate of 900 bwpd. Once gel returns(if any) have tapered to zero, continue sampling V-204 for another 12 hours then obtain another 12-hour piggyback test and RDMO. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 900 Expected Production Rates: FTP(psi): 1200 Choke setting: PI(bfpd/psi dp) Post job POP instructions: POP/POI per instructions in detailed procedure and above. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info, etc • S bp Portable Test Separator Work Request Date 1/10/2018 APE: APBINJEC • Name Eric Zoesch Contact Number 1 (907) 564-4695 Contact Number 2 (406) 270-9837 Well V-204 Current Status: Operable Latest H2S Value: Welltest(or expected rates): Oil Water Fgas GL FTP FGOR WC (bopd) (bwpd) (MMCFD) (MMCFD) (psi) (scf/stb) (%) Base Case 800 1500 0.5 2.0 370 625 65% High rate case(if applicable) 1000 1800 0.5 2.0 370 500 64% #1 Well IOR HP/LP #2 well IOR HP/LP Return Well preference V-113 200 LP V-109 300 LP Return well comments Tie in behind V-204 wellhouse for returns if possible. Otherwise use V-109 or V-113. Well Clean/Raw Well Clean/Raw PBGL source #1 #2 PBGL comments Key Risk,Critical issues Mitigation Plan Divert to tanks if gel/solids concentration is higher than allowable.See chemical datasheet for details on chemicals 1 Gel flowback to plant being pumped. 2 Solids/gel in pad kit Rig up at well, not at test header 3 Solids potential Medium Background unique to this operation(Only if required, beyond SoR background) MARCIT gel MBE treatment is to be pumped in offset injector V-213. There is potential for some gel to be produced out V-204, so a flowback is needed after the job. • • Portable Test Separator Objectives 1 Perform flowback of V-204,sampling for gel and diverting to tanks as needed. 2 Once well has cleaned up,compare WC from two tests:V-213 offline and V-213 online. 3 4 Pad Separator piggyback? Piggyback PORTABLE TEST SEPARATOR PROCEDURE Perform slow beanup of V-204, sampling for solids and gel returns. Divert to tanks as needed. Once well is beaned upen and GL is stable at—2MM with no gel returns,perform 12-hour piggyback test. Once well test is complete, POI V-213 at its target rate of 900 bwpd. After another 12 hours of stabilization with the injector online,perform 12-hour piggyback test. RDMO, leaving well online. Notes: Well will be POP'd via"RP: Generic Unloading Procedure using GL"unless otherwise specified Target solids will be<0.1% upon RDMO, unless otherwise specified Target PH will be 6.5-7 per RP upon RDMO unless otherwise specified 0 • Li Li H IT k k e \ e_ 2 e) S f [ f E » = oa \ \ k \ e 2 0 ± $ o ± @ 0 _ _ ® = _ 0 = = « m ) k = \ e \ k = \ c / k = \ % E 3 » y ® k » » y k 3 ± e % < _ •o e 5 < _ = e ± < _ C-- 7/5 e x f 2 — e x a 2 — e x 7 2 a) i ƒ % T / 2 / a) \ / / / / Z % / ) \ o # a_ cNIx Co \ a 2a I I \ 1 a o = E / Z > \ \ o E -o / \ c M / e 3 G ) a. \ _ - :7-*.: co $ 2 N / / { / } 2 LLJ \ -o a) \ -o F- / 2 \ 7 A C" g E o _ 0 $ E a..' \ & = b u \ ¥ ) = \ u a k ± \ ± ° _ / \ \ 0 < / k o l) \ / \ / LU f E a) co a k a # 0_ Co & / E 2 — CO # 10 CO w • • Fullbore Pumping Design Template #N/A 0 ppm H2S(date/ppm) 2000 Max Pumping Pressure(psi) Crude Main Fluid Type 100 Main Fluid Volume(bbls) Crude Freeze Protect Type 35 Freeze Protect Volume(bbls) Inj i Recent Tbg Fluid Level(ft) Surf Recent IA Fluid Level(ft) If Applicable Recent OA Fluid Level(ft) If Applicable Expected Tbg Fill Up Volume(bbls) If Applicable Expected IA Fill Up Volume(bbls) If Applicable Expected OA Fill Up Volume(bbls) If Applicable Wellbore Volume to Perfs(bbls) If Applicable Anticipated Bottom Hole Pressure (psi) Yes Tubing/Casing within Pressure Limits? Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) 4 5 8430 6744 Tubing Collapse(psi) 4.5 7500 6000 Casing Burst(psi) 7 7240 5792 Casing Collapse(psi) 7 5410 4328 Select Input Depth Integrity Issues? Select Select No Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Yes Production Packer within Pressure Limits? Rated Packer dp Max Anticipated dp at Packer Not Necessary Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) • • Li LI LI k k k H2 e_ 2 e_ ) E E m E 2 e [ C 0 C t e \ 0 e ) 0 e \ 0 : & cn = _ : & m _ ) _ ' _ ' _ ± _ \ m 2 » _ \ m \ � _ \ o. = a - o. = e — � E � - > � g » � g > � 2 » e I < _ = e I < ® = e % < ® _ # e x « 2 « e x 7 2 — e x 7 2 a) / / / 7 / / / % £ / 2 / % \ ( < 7 y 2 o o$ E 2 0 \ eL ƒ a) 1- / a) $ k y / \ > c a ` @ 3 @ m o /_ I I \ CO £ \ £ 7 rnr 25 % a) / \ \ _ e > E \ � E \ g k \ / / ® # § . M / \ _ \ \ 3 0 ± m m # < < o N '> \ % 3 © ' o 2 } \\ /ƒ < k a) I- ƒ ƒ 6 f 0» / j z \ ° / £ � E . { 2H / CD E 10 / 6 o -a- - / u a ) @ \ \ \ \ { \ \ t \ / � / o \ o. CO \ \ u) 4 tE \ a E { - § 0 / m/ 0 / ƒ E N CO # r = w • • Fullbore Pumping Design Template #N/A 0 ppm H2S(date/ppm) 1200 Max Pumping Pressure(psi) Crude Main Fluid Type 100 Main Fluid Volume(bbls) Crude Freeze Protect Type 35 Freeze Protect Volume(bbls) Inj Recent Tbg Fluid Level(ft) Surf Recent IA Fluid Level(ft) If Applicable Recent OA Fluid Level(ft) If Applicable Expected Tbg Fill Up Volume(bbls) If Applicable Expected IA Fill Up Volume(bbls) If Applicable Expected OA Fill Up Volume(bbls) If Applicable Wellbore Volume to Perfs(bbls) If Applicable Anticipated Bottom Hole Pressure (psi) Yes Tubing/Casing within Pressure Limits? Size _ Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) 4.5 8430 6744 Tubing Collapse(psi) 4.5 7500 6000 Casing Burst(psi) 7 7240 5792 Casing Collapse(psi) 7 5410 4328 Select Input Depth Integrity Issues? Select Select No Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Yes Production Packer within Pressure Limits? Rated Packer dp Max Anticipated dp at Packer Not Necessary Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) TREE= 4-1/16'CPA II AIM_ FAC V-21 3 SAFETY NOTES: 142S READINGS AVERAGE 125 ppm WEIEN ON MI"'"WELL REQ'S A SSSV WHEN ON MI"' 1ACTUATOR= BAKER OKB.ER/4-- 1 BF B_EV= 82.8' 54.3' KOP= 30(7 20*CONDUCTOR — 106' A'2 — 1026 —9 1 ."°".. I -5/13"TAM FORT COLLAR,113=8.813' 1 1 Max Angle= 59' .4;3093' 1 3076 -41/2-I-ES X NIP,ID=3 813' Datum IAD= 6564' 'Datum TV 0= 4400'SS 1 9-5/8"CSG,408,L-80 BTC,ID=8.835" —{ 3442" GAS LFT VA N)RELS r7"MARKER JT AN RA TAG — 6003' ST TPA) TV D DEV TY PE V LV LATCH P0/TI DATE 1 ' 5 6347 4326 45 KBG-2 DMY BK 0 11/27/04 Minimum ID =2.813- ti• 6534' 1-7 645T-1—4-172"FES X NIP,ID=3.813' 3-112" HES X NIPPLE 6468' —4-1/2"X 3-1/2'X0,13=2.992" I 4-1/2'TBG,12.6#,L-80 TCI, 0152 bpf.ID=3.958' H 6468' 1 / 72,4 z 6479' —IT X 3-172"BKR FRIBA PKR,ID 4_875' I r MARKER JONT W RA TAG — 6620' —4 6534' H3-1/2"FES X Ni',0=2.813" WATFPFLODD MANDRELS ST Iii() TVD1DEV TYPE I VLV LATCH FORT CATE I-1 -4 4 6552 44741 43 111.1G-W DAY F8( 0 07/28/15 . 0 3 6613 45191 42 IIING-W 1 P-15XJR1 TG 15 08/19/17 Li 2 6679 4568, 42 IA IA G-W1 [WY 1 F8( 0 07/28/15 1 16739 4613 42 MIAG-W 1 P-15XJR1 RK 15 08/19/17 3-1/2'MARKER JOINT w/RA TAG —I 6622' r--0—{ 6642' I—I-TUT FES X NV,ID=2.813" X 1 6653' --V X 3-1/2-BKR PRIEM PKR,D=2.875" -MI L LI PERFORATION SURNARY I 6768' —3-1/2-FES X FIRE)=2.813" I REF LOG:USTI ON 07/25/04 .......„ 1- 6779' —3-1/2"X 4-1/2"XO,I)=2.930' ANGLE AT TOP PERE: 43'14 6582' Note:Fefer to Production CEI for historical perf data 2 6781' H7"X 4-1/2'BKR S-3 RKR,130-=3.875" SEE SPF[ZOIC N1ERVAL Opn/Sqz SHOT SOL 6756' —4-1/2"X 3-1/T XO,ID=2.930' I 4-1/2"* 5 OA 6582-6627 0 07/24/04 ffI 6806' —3-1/2"FES X NIP,I)=2.813" 4-1/2"r 5 10/3a 6667-6702 0 07724/04 I 4-1/2"' 5 10Bb 6717-6742 0 07/24/04 14-1/2"I' 5 Oficl 6862-6937 0 07/24/04 i 1 68ir J—3-112"FES X KIP,10=2813" I 1411----- 681r 1—3-1/2"RNIX BOOY&R-15XJR WFR, 15/64'FORT(SET 08119/17) 3-VT'TBG,9.2a,L-80 TCI, 0087 bpf,ID=2,992" H 6829' " r 6829' —13-1r2"W_EG,C=3,00" 0 , 6829' Hati()LOGGED ON 07/01/05 L PBTD J- 7123' 1 4•41.4444 4444444404. .444444 4 44444444 41 I r CSG,26#,L-80 BTC-N, 0371 bpf,ID=6.278' I— 7206 l 4 64&&‘•"14 DATE REV BY COAIU'ITS r DATE FEV BY COMENTS ORION INT 07/27/04 TA/TLP INTIAL COMPLETION 08/23/17 T7A/J6/E)WER C/0&RPM BODY UPCATE NELL V-213 09/26/14 JIMA()RLL RIAUSET XX PLUG(09I17/14) FErairrtb.' 041160 09/26/14 JACKIE)WFR 00(0918414) API No 50-029-23213-00 02/23/15 GJ6/PJC MEL XX/SET RIO(BODY w/PRONG- SF4'11,T11N,R11E,562'FTC&1517'Fa 02/24/15 GJB/PJC SET P-15)(JR VIER(12/64"FORT) A , 09/11/15 CINKIK)WR GO&MU BOO( LEGATE(07/28115) BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,April 10,2017 TO: Jim Regg 0Yr' `, i `1`\� SUBJECT: Mechanical Integrity Tests P.I.Supervisor �� + rBP EXPLORATION(ALASKA)INC. V-213 FROM: Guy Cook PRUDHOE BAY UN ORIN V-213 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-213 API Well Number 50-029-23213-00-00 Inspector Name: Guy Cook Permit Number: 204-116-0 Inspection Date: 3/28/2017 Insp Num: mitGDC170328155638 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-213 Type Inj W TVD 4421 Tubing 1241 1 1272 1233 1206 PTD 2041160 Type Test SPT Test psi 1500 IA 7 1900 1856 1849 .,--- BBL BBL Pumped: 1.5 BBL Returned: 1.2 OA 188 279 283 1 282 Interval 4YRTST P/F P Notes: All went well with no issues. Lou Grimaldi was on site with me. SCANNED AUG 15201 Monday,April 10,2017 Page 1 of 1 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a (2 y.. - J L (p Well History File Identifier Organizing (done) o Two-sided 11111111111111111/1 o Rescan Needed 1111111111111111111 R,CAN ¢ Color Items: o Greyscale Items: DIGITAL DATA ~skettes, No. ~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: q I bJn to 151 YVlP Project Proofing 1111111111111111111 BY: ~ Date q 'ft> J ()" J- x 3~ = &; ó Date: ql h Job 151 V\1P Scanning Preparation BY: ~ + 13 = TOTAL PAGES 17 3 (Count does not include cover shJat) 1\1\/\ P 151 I , J Production Scanning Stage 1 Page Count from Scanned File: 7 1-1- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES Date: q I (¡; I 0 ~ 11/1111111111' "III NO BY: ~ 151 YV\f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: 151 11I11111111I11 "III Scanning is complete at this point unless rescanning is required. ReScanned 11I1111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ,. ~ ,. 4~~~~,:-.'.~,~ ;v~~,,:~ ';. ~ ~C.1~~ ~ . ~ ~+~ • bp ~~~~I~~~ ocr o s zpo9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Alealca Oil & Gas Cons. G~mm~~:in~ Anchorag~ Subject: Corrosion Inhibitor Treatments of GPB V-Pad a,~ ~"" f~(D Dear Mr. Maunder, Y" °~'` ~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name; API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Repo~t of Sundry Operations (10-404) Date V-pad 8/13/2009 Weli Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-o3 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 5002923008b000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 5002923o83ot00 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031 Q30 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30l2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-2o1 2012220 5o02s230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-2t 1 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 12 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2Q09 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 "~ 2080200 50029233830000 NA 1.75 NA ~5 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 MEMORANDUM • To: Jim Regg ~ / ~ 3, 3l ~~' P.I. Supervisor FROM: John Cnsp Petroleum Inspector State of Alaska • Alaska Oil and Gas CouservaYion Commission DATE: Monday, March 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-213 PRUDHOE BAY UN ORIN V-213 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~'~-- Comm Well Name: PRUDHOE BAY UN ORIN V-213 Insp Num• mitJCr090302075420 Rel Insp Num: API Well Number: 50-029-23213-00-00 Permit Number: 204-116-0 Inspector Name: John Crisp Inspection Date• 2/25/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- - Well V-213 -- T3'pe InJ. i -- W TVD 4421 IA 420 4000 3920 3920 P T i 2041160 --- ---- )'peTeSt SPT Test psi 1500 °~ QA I 250 420 430 430 Interval _ 4YRTST p~F P a Tubing Sao Sao 9so 9so i i Notes: 3 bbl's pumped for test. _ Monday, March 02, 2009 Page 1 of 1 • • ~._ -~~_ ~--, MICROFILMED 03/01/2008 DO NOT PLACE M .. r,, r, ;. ~, ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicheiCvrPgs_InsertslMicrofilm Marker.doc Schlumberger RËCEIVEO SfP 1 5 2006 4Jaska Oil & Gas Cons. ~ ~~_. -.' 09/15106 NO. 3963 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oi' & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Polaris Well Job # Log Description Date BL Color CD V-213 40010719 OH EDIT OF MWD/LWD 07/22/04 2 1 V-213 PB1 40010719 OH EDIT OF MWD/LWD 07/18/04 2 1 5-216 11296702 INJECTION PROFILE 07/18/06 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechn¡cal Data Center LR2·1 900 E Senson Slvd. Anchorage AK 99508-4254 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Date Delivered: Received by: . ,t'\t)~ SCANNED: 5£P 1 ûJ'vv usc- [)tAI - II Co # 11...( /3k, W\ .tt l'i 13-:r PBU V-213 (50-029-23213-00) . . Andy, No open hole logging data was submitted for PBU V-213 API 50-029-23213-00. Please send over bluelines, reproduceables, and digítallogging data for this well as soon as possible. TNX Howard 1 of 1 9/5/2006 11 :27 AM ;¿ 8 ~~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 PermittoDrill 2041160 Well Name/No. PRUDHOE BAY UN ORIN V-213 Operator BP EXPLORATION (ALASKA) INC MD 7225 Completion Date 7/28/2004 Completion Status WAGlN Current Status WAGIN TVD 4985 REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: 5f!ú.¿ I J.. J V 0 ~ t.( API No. 50-029-23213-00-00 Ç0 .....- (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ,iD D Asc Directional Survey J~t Directional Survey D DirectiO"nal Survey Rpt Directional Survey /ËD C Tf 12742 Sonic ,J..-0'9 12742 Sonic ~ Injection Profile Log Log Run Scale Media No Interval OH/ Start Stop CH Received 8/6/2004 0 0 8/6/2004 0 9215 Open 8/9/2004 0 9215 Open 8/9/2004 4870 7104 Case 9/27/2004 4870 7104 Case 9/27/2004 5955 7055 Open 7/25/2006 Blu 5 Blu Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORM~ Well Cored? Ý Q/ Daily History Received? ~N (þ/N Chips Received? ~ Analysis ~ Received? Formation Tops Comments: MJHlj o(l4--~4l,- \)j¡' E~¿{{¿ ~~ ~~~ )-J-,r-Å..\\a ~ -- Comments PB1 PB1 ULTRA SONIC IMAGING TOOL, USIT-GR-CCL ULTRA SONIC IMAGING TOOL, USIT-GR-CCL Injection Profile - REVISED 05-0CT-2005 PRES, TEMP, GRADIO, SPIN 1-Jul-2005 . Permitto Drill 2041160 MD 7225 TVD 4985 ~_._-- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Well Name/No. PRUDHOE BAY UN ORIN V-213 Operator BP EXPLORATION (ALASKA) INC Completion Date 7/28/2004 Completion Status WAGIN Current Status WAGIN '~ Date: API No. 50-029-23213-00-00 UIC Y )-µ~h . . Ws C!\I ..---,. . . WELL LOG TRANSMITTAL RECEI\/ED AUC :: U [UUb ProActive Diagnostic Services, Inc. 4Iaska 011 & Gas ConS. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and lor Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1J 2J 3J 4J 5J 6J 7J 1 BL / EDE Disk 1 BL / EDE Disk v - 213i 1 0-Jul-06 Injection Profile v - 216i 11-Jul-06 Injection Profile Print Name: (Q- tL- ~- h (l.;f-) lAe m(\~ \A.l.<.e,(ft Date: ?J 180, / () (r, Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@.MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM C:\Documen1s and Settings\PDS Anchomge - MPL\Desktop\Transmit_ Original.doc e;xe.. 904 - /I CJJ b r<!.. t- 904 ~t3Ö Scblumbel'gel' SChlumberger·DCS 2525 Gambell St. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well V-212 L·212 L-216 L-215 V·213 (REDO) ()eff-- ¡ / c:\ e-) ¡Q Job# Log Description 11225953 INJECTION PROFILElWFL 11217240 INJECTION PROFILE 11217241 INJECTION PROFILE 11217242 INJECTION PROFILE 11076450 INJECTION PROFILE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~7 / ê;5/ ()c.., 04108/06 04116/06 04117/06 04/18/06 07/01/05 06/28/06 NO. 3873 Company: Alaska Oil & Gas Cons Comm Artn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis Polaris Date CD BL Color . Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage. AK 99503-2838 A ATTN: Beth /1 /J Received by: (' _ _ ~""- . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conse ation Commission TO: Jim Regg 1/ I t P.I. Supervisor . (\'ffN 34 ûç; DATE: Monday, Febr ary 28,2005 SUBJECT: Mechanical In egrity Tests BP EXPLORAT N (ALASKA) INC V-213 PRUDHOE BA UN ORIN V-213 FROM: Jeff Jones Petroleum Inspector Src: Inspector d.. O~ :,~~~ By, P.I. Suprv 6Bl-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN ORIN V-213 API Well Number: 50-029-23213-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ050219124521 Permit Number: 204-116-0 Inspection Date: 2/19/2005 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I V-213 Type Inj. P TVD I 442] IA 0 I 2000 1945 1940 P.T. I 2041160 TypeTest SPT Test psi I 2000 OA 140 300 290 290 Interval INITAL PIF P Tubing ]220 1240 1220 i 1220 I Notes: 2 BBLS 60/40 methanol pumped. 1 well house inspected; no exceptions noted. ~CANNED .JAN 0 3 2007 ..,'" .'.~ -. . ".(t...; Monday, February 28, 2005 Page 1 of 1 TREË = WELLHEAD - A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = ."...____...,,',...______,.,_____u., ""__' Datum ND = 4-1/16" CrN FMC NA 82.8' 59 @ 3093' SS . V-213 ~OTES' I 9-5/8" CSG, 40#, L-80, ID = 8.835" I Minimum ID = 2.813" @ 6534' 3-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 6468' ÆRFORA TION SUMMA RY REF LOG: SWS CDR ON 07/22/04 ANGLE AT TOP PERF: 42 @ 6590' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 6590 -- 6635 0 07/24/04 4-1/2" 5 6675 -- 6710 0 07/24/04 4-1/2" 5 6725 - 6750 0 07/24/04 4-1/2" 5 6870 -- 6945 0 07/24/04 13-112" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I I PBTD , 17" CSG, 26#, L-80, 10 = 6.276" I DATE 07/27/04 09/13/04 11/28/04 REV BY COMMENTS TAITLP ORIGINAL COMPLETION JDM/PG WF MANDREL CORRECTIONS GJB/TLP GL V CIO 6827' 7123' 7205' DATE REV BY r----j 1025' H 9-5/8" TAM PORT COLLAR, 10=8.813# I 3076' -I 4-1/2" HES X NIP, 10 = 3.813" I 6003' 1-17" MARKER JTW/ RA TAG I ST MD NO 4 6552 4475 3 6613 4519 2 6679 4568 1 6739 4613 PORT DATE 07/26/04 07/26/04 07/26/04 07/26/04 -14-1/2" HES X NIP, 10 = 3.813" I -14-1/2" X 3-112" XO, 10 = 2.992" I 7" X 3-1/2" BKR PREMIER PKR, 10 =2.875" -13-1/2" TBG CENTRALIZER w IRA MARKER I -13-1/2" HESX NIP, 10=2.813" I -17" X 3-112" BKR PREMIER PKR, 10 = 2.875" 6806' -13-1/2" HES X NIP, 10 = 2.813" I -13-1/2" X 4-112" XO, 10 = 2.930" I -17" X 4-1/2" BKR S-3 PKR, 10 = 3.875" , -14-1/2" X 3-1/2" XO, 10 = 2.930" I -I3-1/2"HESXNIP, 10=2.813" I 6817' -I3-1/2"HESXNIP,ID=2.813" I 6829' -13-1/2" WLEG, 10 = 3.00" I COMMENTS ORION UNIT WELL: V-213 PERMIT No: 2041160 API No: 50-029-23213-00 SEC 11, T11N, R11E, 4718' NSL & 1517' WEL BP Exploration (Alaska) ..A STATE OF ALASKA ALAS~ AND GAS CONSERVATION COM.ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG V 2004 ~~~"~i! ~~~~~fJ";~tmnrlrM§~ i 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 1m WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD / GR, MWD I GR / RES I DEN / NEU I PWD, USIT CASING, LINER AND CEMENTING RECORD SETtING DePTH MD S$I~ DePTH'tvD aOrtTQM aOrtTOM 110' Surface 110' 3442' 28' 2692' 7205' 26' 4969' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4719' NSL, 1517'WEL, SEC. 11, T11N, R11E Top of Productive Horizon: 2732' NSL, 1274' EWL, SEC. 01, T11N, R11E, UM Total Depth: 3055' NSL, 1528' EWL, SEC. 01, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590785 y- 5969968 Zone- ASP4 TPI: x- 593533 y- 5973296 Zone- ASP4 Total Depth: x- 593783 Y- 5973623 Zone- ASP4 18. Directional Survey 1m Yes 0 No 22. 20" x 34" 9-5/8" 215.5# 40# 26# A53 L-80 L-80 Surface 28' 26' 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5spf MD TVD MD TVD 6590' - 6635' 4502' - 4535' 6675' - 6710' 4565' - 4591' 6725' - 6750' 4602' - 4621' 6870' - 6945' 4710' - 4767' 26. Date First Production: October 1, 2004 Date of Test Hours Tested One Other 5. Date Comp., Susp., or Aband. 7/28/2004 6. Date Spudded 7/12/2004 7. Date T.D. Reached 7/22/2004 8. KB Elevation (ft): 82.8' 9. Plug Back Depth (MD+ TVD) 7123 + 4905 10. Total Depth (MD+TVD) 7225 + 4985 11. Depth where SSSV set (Nipple) 3076' MD 19. Water depth, if offshore NIA MSL 1b. Well Class)' o Development 0 Exploratory o Stratigraphic 1m Service 12. Permit to Drill Number 204-116 13. API Number 50- 029-23213-00-00 14. Well Name and Number: PBU V-213i 15. Field / Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Ft Ft 16. Property Designation: ADL 028240 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 48" 260 sx Arctic Set (Approx.) 12-1/4" 617 sx AS Lite, 379 sx 'G', 212 sx 'G' 8-314" 295 sx Class 'G' 24. SIZE 4-1/2", 12.6#, L-80 3-1/2", 9.2#, L-80 TUalNGREÚQRD DEPTH SET (MD) 6468' 6468' - 6829' PACKER SET (MD) 6479',6653',6781' 25. DEPTH INTERVAL (MD) 2700' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 90 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BsL GAs-McF WATER-BsL PRODUCTION FOR TEST PERIOD ... CALCULATED ...... 24-HoUR RATE""'" OIL-BsL Flow Tubing Casing Pressure Press. GAs-McF W A TER-BsL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 RBÐMS afL CONTINUED ON REVERSE SIDE NO'4 0 :3 7m\l\ ~rz: G 28.. GEOLOGIC MARKER. 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Ugnu Ugnu Ma Ugnu MB1 Ugnu MB2 Ugnu MC 3817' 6025' 6101' 6216' 6326' 2914' 4118' 4164' 4237' 4311' None Schrader Bluff NA Schrader Bluff NB Schrader Bluff NC 6371' 6405' 6463' 4343' 4367' 4409' Schrader Bluff OA 6591' 4503' Schrader Bluff OBa Schrader Bluff OBb Schrader Bluff OBc Schrader Bluff OBd Schrader Bluff OBe Schrader Bluff OBf 6676' 6729' 6807' 6876' 6960' 7016' 4566' 4605' 4663' 4715' 4779' 4822' Base Schrader Bluff 7068' 4862' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Q!IftJ...¡ ~ ~ Title Technical Assistant Date II.. D ~.: 0<...( PBU V-213i 204-116 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Thomas Schaefer, 564-4685 Permit No. I Approval No. 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only c¡(~ 7 Schlumberger Schlumberger·OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ~6 -1'l~-114A - It'" 51-213 V·213 L-211 :lo lj~ ¡ t¡ /W~;115 ,¡' W·215 203 -I' r ~-215 ,2,J~ 1.31,..- W-215 PB1 Job' Log Description 10662970 SCMT 10877764 USIT 10877764 CH EDIT PDC·GR (USIT 10679059 US IT 10679059 CH EDIT PDC-GR (US IT) 10662954 US IT 10662954 CH EDIT PDC-GR (US IT) 40009586 OH EDIT MWD DATA 40009586 OH EDIT MWD, GR DATA 11/17/03 07/25/04 07/25/04 03/12/04 03/12/04 09/20/03 09/20/03 09/09-16/03 09/09·10/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrolechnlcal Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ¥7(of NO. 3219 09/27/04 Company: Alaska Oil & Gas Cons Comm "Attrr. ,<b[1 LJl;I'd::tUJI -- 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orlan Polaris Color Date BL 2 2 CD . Schlumberger-DCS 2525 Gambel! St, Sulle 400 :~'~~'~'4¡~ . .. STATE OF ALASKA e ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 181 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 7/28/2004 ~ 6. Date Spudded 7/12/2004 21. Logs Run: MWD I GR, MWD I GR / RES / DEN / NEU / PWD, USIT CASING, LINER AND CEMENTING RECORD SeTÏINGDt:FmiMD SÊTTING DEP'TftTVÖ . . Top BoTTOM ',Of' BOTTOM Surface 110' Surface 110' 28' 3442' 28' 2692' 26' 7205' 26' 4969' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4719' NSL, 1517' WEL, SEC. 11, T11N, R11E ' Top of Productive Horizon: 2732' NSL, 1274' EWL, SEC. 01, T11N, R11E, UM Total Depth: 3055' NSL, 1528' EWL, SEC. 01, T11N, R11E, UM ., 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590785" y- 5969968'~ Zone- ASP4 TPI: x- 593533 y- 5973296 Zone- ASP4 Total Depth: x- 593783 y- 5973623 . Zone- ASP4 18. Directional Survey 181 Yes 0 No No. of Completions 22. 20" x 34" 215.5# 40# 26# A53 L-80 L-BO 9-5/8" 7" 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Gun Diameter, 5 spf MD TVD MD TVD 6590' - 6635' 4502' - 4535' 6675' - 6710' 4565' - 4591' 6725' - 6750' 4602' - 4621' 6870' - 6945' 4710' - 4767' 26. Date First Production: Not on Injection Yet Date of Test Hours Tested 7. Date T.D. Reached 7/22/2004 8. KB Elevation (ft): 82.8' 9. Plug Back Depth (MD+ TVD) 7123 + 4905 10. Total Depth (MD+TVD) ,,7225 + 4985 11. Depth where SSSV set (Nipple) 3076' MD 19. Water depth, if offshore N/A MSL RECEIVED AUG 2' 7 2004 Ala~h em 8. Gas Cons C -'. 1b. Well Class: . Dn!lll13SIJn o Developmen~~~atory o Stratigraphic 181 Service 12. Permit to Drill Number 204-116 13. API Number 50- 029-23213-00-00 14. Well Name and Number: PBU V·213i 15. Field / Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Ft Ft 16. Property Designation: ADL 028240 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 48" 260 sx Arctic Set (Approx.) 12-1/4" 617 sx AS Lite, 379 sx 'G', 212 sx 'G' 8-3/4" 295 sx Class 'G' SIZE 4-1/2", 12.6#, L-80 3-1/2",9.2#, L-80 DEPTH INTERVAL (MD) 2700' DEPTH SET (MD) 6468' 6468' - 6829' PACKER SET (MD) 6479',6653',6781' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 90 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oil-Bel GAs-McF WATER-Bel CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". "'--;--:;';-;,:--;,;-;"1 \, Cfj?!\~,~;.;~·'~'I.~ t \ 2-2ii~tf- \ \ 1~')'¡:"'lJ \ I '1J tr." .~ \ .....j'I>~\ t~,_:.J PRODUCTION FOR TEST PERIOD .. CALCULATED -iI.. 24-HoUR RATE""'" Oil-Bel Flow Tubing Casing Pressure Press. 27. None GAs-McF WATER-Bel RiIIIS Bfl t\CD () 31fJn~ ~r C)t~\G\NAL, Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) \,gÝ 28. e GEOLOGIC MARKERS NAME MD TVD Ugnu 3817' 2914' Ugnu Ma 6025' 4118' Ugnu MB1 6101' 4164' Ugnu MB2 6216' 4237' Ugnu MC 6326' 4311' Schrader Bluff NA 6371' 4343' Schrader Bluff NB 6405' 4367' Schrader Bluff NC 6463' 4409' Schrader Bluff OA 6591' 4503' Schrader Bluff OBa 6676' 4566' Schrader Bluff OBb 6729' 4605' Schrader Bluff OBc 6807' 4663' Schrader Bluff OBd 6876' 4715' Schrader Bluff OBe 6960' 4779' Schrader Bluff OBf 7016' 4822' Base Schrader Bluff 7068' 4862' e 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RE.CE\VED þ..\) G ~ , '2.\)Û4 . C romisSIOI"I . &. Gas Coos. \I ~\as\(a ß\\ ~t\t"o{a\\e 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. ~"" II"" fJ d 4/7 Teme Hubble "'-l0 VUU'_ ~Q Title Technical Assistant PBU V-213i 204-116 Well Number Permit No. I Approval No. Date Cfó.. ^ 7-0'-( Prepared By Name/Number: Terrie Hubb/e, 564-4628 Drilling Engineer: Thomas Schaefer, 564-4685 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. ITEM 1a: 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 elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Name: V-213 Common Name: V-213 7/17/2004 LOT 3,475.0 (ft) 2,692.0 (ft) 9.00 (ppg) 620 (psi) 1,879 (psi) 13.43 (ppg) - e Printed: 8/3/2004 9: 11 :20 AM It e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 7/11/2004 7/28/2004 Spud Date: 7/11/2004 End: 7/28/2004 7/11/2004 08:00 - 12:00 4.00 MOB P PRE Move rig & pits from V-01 to V-213i. Spot & level sub and pits. Accept rig @ 1200 hrs 7-11-04. RT- GL 28.5'. 12:00 - 16:30 4.50 RIGU P PRE Take on water, NU 20"BOP components and diverter system. Load shed wI BHA. Mix spud mud. 16:30 - 17:00 0.50 RIGU P PRE Service top drive. 17:00 - 18:30 1.50 RIGU P PRE Cut and slip drilling line - adjust brakes. 18:30 - 20:00 1.50 RIGU P PRE PU 24 jts 4" HWDP - std back. MU jar std - std back. 20:00 - 20:30 0.50 RIGU P PRE Function test Diverter - test witness waived by Chuck Sheve w/ AOGCC. 20:30 - 21 :30 1.00 RIGU P PRE PU 7" DC's & std back. Bring stab., xo's, eel. to rig floor. 21 :30 - 00:00 2.50 RIGU P PRE MU BHA#1 - adjust motor to 1.83 deg, orient motor & UHBO sub. 7/1212004 00:00 - 00:30 0.50 RIGU P PRE Pre- spud meeting - RU Gyro 00:30 - 01 :00 0.50 RIGU P PRE Fill hole - check for leaks. 01 :00 - 04:00 3.00 DRILL P SURF Spud in at 01 :00 Hrs. Dir drill f/11 0' to 355'. 04:00 - 05:00 1.00 DRILL P SURF Pull up and add jar stand. 05:00 - 17:00 12.00 DRILL P SURF Dir drill f/355' to 1,567'. 83 up 70 dwn, 650 gpm 2150 psi. 17:00 - 17:30 0.50 DRILL P SURF CBU 2X @ 650 gpm 2,150 psi. 17:30 - 19:30 2.00 DRILL P SURF POOH - Pump 2 stands outfrom 1,097' to 910'. 19:30 - 20:30 1.00 DRILL P SURF Pulled BHA - Change bit, adjust motor to 1.5 deg, orient tools. clean floor. 20:30 - 21 :00 0.50 DRILL P SURF Service top drive. 21 :00 - 21 :30 0.50 DRILL P SURF RIH w/ BHA. 21 :30 - 23:00 1.50 DRILL P SURF PU 6 jts 4" DP and stand back. RIH to 1,473'. Washed last std to bottom. Wash down @ 875' & 1,076'. 23:00 - 00:00 1.00 DRILL P SURF Dir Drill from 1,567' to 1,596'. 660 gpm, 2,150 psi 7/13/2004 00:00 - 02:00 2.00 DRILL P SURF Dir drill from 1,596' to 1,875'. 650 gpm 2,200 psi. 02:00 - 03:00 1.00 DRILL N SFAL SURF Work on Mud Pump #1- liner packing leak. 03:00 - 03:30 0.50 DRILL P SURF Dir drill from 1,875' - 1,938'. 100K up, 75K dwn, 650 gpm @ 2,2200 psi, TOR 4500 Nib. 03:30 - 04:00 0.50 DRILL N SFAL SURF Work on Mud Pump #2 - change suction valve seat 04:00 - 11 :30 7.50 DRILL P SURF Dir drill from 1,938' to surface TD @ 3,455'. 670 gpm - 3,450 psi, 100K up,75K down, Torque 2.5 - 4K. 11 :30 - 13:30 2.00 DRILL P SURF Circ and cond mud for wiper trip - add new mud, rot & recip @ 660 gpm 100 rpm. 13:30 - 14:30 1.00 DRILL P SURF POOH from 3,455' to 2,075'. 130up, 60 dwn w/ intermitt. drag- wiped ok. 14:30 - 15:30 1.00 DRILL P SURF Back ream fl 2,075' to 1,845' - CBU while back reaming. 15:30 - 16:00 0.50 DRILL P SURF POOH from 1 ,845' to 1 ,350'. 16:00 - 19:30 3.50 DRILL P SURF Tight @ 1,350'. Packing off- pumping mud away. Work pipe back down to 1,458'. CBU - sd & gravel over shakers. Back ream up to 1,192'. Up 11 OK, DWN 64K, 560 gpm 1700 psi, 60 rpm, 4K torque. 19:30 - 20:00 0.50 DRILL P SURF Pump out f/1 ,192' to 1,004'. Cont to POOH to 820'. 20:00 - 21 :00 1.00 DRILL P SURF RIH to TD - work thru tight spots @ 1,918',2,000', & 2,780'. 21 :00 - 23:00 2.00 DRILL P SURF Circ and cond mud & hole for surface csg. CBU 3X @ 644 gpm 3,250 psi. Rot & recip 100rpm. 23:00 - 00:00 1.00 DRILL P SURF Start POOH to run 95/8" csg. 120up, 75 dwn. 7/14/2004 00:00 - 02:00 2.00 DRILL P SURF POOH to run surface csg. Pump out fl 2,020' to 1,550' ( tight I swabbing). 02:00 - 04:30 2.50 DRILL P SURF Handle I L.D. BHA. 04:30 - 05:00 0.50 DRILL P SURF Clear rig floor. PJSM. 05:00 - 05:30 0.50 CASE P SURF Make dummy run with landing jt and hanger. Printed: 8/312004 9: 11 :30 AM tit e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 7/11/2004 Rig Release: 7/28/2004 Rig Number: Spud Date: 7/11/2004 End: 7/28/2004 7/14/2004 05:30 - 07:00 1.50 CASE P SURF RU tools to run 95/8" csg. 07:00 - 09:00 2.00 CASE N SURF Work on skate. 09:00 - 12:30 3.50 CASE P SURF PJSM - Run 95/8" csg to 1,825'. 12:30 - 00:00 11.50 CASE P SURF Taking weight from 1,825' - 1,850'. Wash down f/1,850' -2,120'. 5.5 BPM 300 psi. Run 1 jt fl 2,120' - 2,160' 150K up 75K dwn. Con't to wash csg down f/ 2,160' - 2,240'. Packed off @ 2,240'. Regained circ. Con't to wash casing down to 2,550'- 6-7 BPM 300 . 400 psi. 7/15/2004 00:00 - 02:30 2.50 CASE P SURF Wash csg down f/2,550' to 3,410'.6-7 BPM 500 ·750 psi. 140 up, 65 down. Make up hanger and landing jt. Wash to btm @ 3,441'. 02:30 - 03:00 0.50 CASE P SURF LD fill up tool. Blow down. MU cementing head. Land csg on landing ring. 03:00 - 06:00 3.00 CASE P SURF Circ hole clean wI 300 vis, 9.7 ppg mud. No mud loss. Cond mud for cement job. 10 BPM 600psi. Recipicate pipe. PJSM. 06:00 - 08:30 2.50 CEMT P SURF Test cement lines to 3,500 psi. Dowell cmnt'd 9 5/8 csg - pumped 75 bbls mud push spacer @ 10.1 ppg, 495 bbls (625 sx) Articset lite @ 10.7 ppg, 79 bbls ( 380 sx) class "G tail @ 15.8 ppg. Redpicate pipe, full returns. 08:30 - 09:00 0.50 CEMT P SURF Displace with rig pumps @ 10 BPM 500 psi. Full returns. Bumped plug to 3,000 psi. No cement to surface. 09:00 - 10:00 1.00 CEMT P SURF Check floats - held. RD cementing head & LD top pup on landing jt. 10:00 - 10:30 0.50 CEMT P SURF Change out bails and elevators. 10:30 - 12:00 1.50 CEMT P SURF Prepare to run Tam collar shifting tool to do a second stage cement job. Clear rig floor & move BHA in derrick. 12:00 - 13:00 1.00 CEMT P SURF MU Tam collar shift tool & RIH to 1,025'. Engage port collar and test to 800 psi. 13:00 - 17:00 4.00 CEMT P SURF Shift open port collar and circ out 300 bbls contaminated mud. Stage pumps up to 8 bpm - circ & cond mud for second stage cement job. 17:00· 19:00 2.00 CEMT P SURF Test lines to 2,500 psi. Re-test TAM collar to 1,000 psi. Open TAM collar. Dowell pumped second stage - pumped 25 bbls water, 168 bbls (182 sx) ASL cmnt @ 10.7 ppg. Displaced w/ 12 bbls water. Circ 30 bbls good 10.7 ppg cmnt to surface. Cement standing at surface. Close TAM. Blow choke, drop ball and test to 1,000 psi. Cement in place @ 18:30 hrs. 19:00 - 20:30 1.50 CEMT P SURF Flush cement fl diverter. Circ 6.5 BPM to clean up DP / annulus. RD circ pup. 20:30 - 21 :30 1.00 CEMT P SURF POH & LD shifting tool. 21 :30 - 22:30 1.00 CEMT P SURF MU 9 5/8 pup - break out and lay down landing jt. - clear rig floor. 22:30 - 00:00 1.50 DJVRTR P SURF Clean out under rotary table. ND diverter. 7/16/2004 00:00 - 02:00 2.00 DIVRTR P SURF ND Diverter - install cement hose in derrick. 02:00 - 03:00 1.00 WHSUR P SURF NU 11"- 5M Split Speed Head. Test to 1,000 psi. 03:00 . 03:30 0.50 BOPSUF P SURF NU 135/8" 5M BOPE. Install 5" liners in pumps. 03:30 - 04:30 1.00 BOPSUF N SURF PJSM - level rig to line up skate. Clean pits 04:30 - 06:00 1.50 BOPSUF P SURF NU 135/8" 5M BOPE. 06:00 - 06:30 0.50 BOPSUP P SURF Set test plug. RU to test BOP's. 06:30 - 11 :00 4.50 BOPSUP P SURF Test BOPE to 250/4,000 psi annular to 250/3,500 psi.witness waived by Lou Grimaldi wI AOGCC. 11 :00 - 12:00 1.00 BOPSUF P SURF RD test equip. Pull test plug. Install wear ring - ID 915/16. 12:00 - 15:30 3.50 DRILL P PROD1 RIH PU 105 jts 4" DP. Printed: 8/312004 9:11 :30 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 7/11/2004 Rig Release: 7/28/2004 Rig Number: Spud Date: 7/11/2004 End: 7/28/2004 7/16/2004 15:30 - 17:00 1.50 DRILL P PROD1 POH - stand back 35 stds. 17:00 - 17:30 0.50 DRILL P PROD1 Clean rig floor. 17:30 - 20:00 2.50 DRILL P PROD1 MU SHA #3 20:00 - 20:30 0.50 DRILL P PROD1 RIH PU 4" DP to 1,318'. 20:30 - 21 :00 0.50 DRILL P PROD1 Shallow test MWD. Test tam port collar to 1,000 psi. Held. 21 :00 - 23:00 2.00 DRILL P PROD1 Drills - kick while tripping drill, stripping drill followed by well kill drill. Slow down choke & kill lines - manifold. 23:00 - 00:00 1.00 DRILL P PROD1 Cut and slip drilling line. 7/17/2004 00:00 - 00:30 0.50 DRILL P PROD1 Service top drive. Grease crown. 00:30 - 02:30 2.00 DRILL P PROD1 RIH I PU 4" DP to 3,275'. 02:30 - 03:30 1.00 DRILL P I PROD1 Circ air out of hole. Test 9 5/8" csg to 3,500 psi for 30min. Lost 50 psi. 03:30 - 05:00 1.50 DRILL P PROD1 Tag float collar @ 3,358'. Drill plugs, FC, good cement, and shoe @ 3,441 '. Wash to btm @ 3,455'. Up wt 116K, DWn wt 76K, RPM 50, 500 gpm- 1,950 psi, WOS - 5 to 8K, TO 4-6K. 05:00 - 05:30 0.50 DRILL P PROD1 Drill 20' new hole f/3,455' to 3,475'. 05:30 - 06:00 0.50 DRILL P PROD1 CSU. PJSM. Displace hole new wI 9.0 ppg LSND mud. 06:00 - 06:30 0.50 DRILL P PROD1 Perform LOT. EMW = 13.4 ppg. Obtain base line ECD 9.72 ppg and SPR. 06:30 - 00:00 17.50 DRILL P PROD1 Dir drill from 3,475' to 6,635'. Up wt 135K, Dwn wt 79K, Rot wt 98K, TO on 7.9, TO off 6.9,597 gpm 2,700 psi, off btm 2,516 psi. Cal ECD 10. ppg, ECD = 10.73 ppg. Top of Ugnu @ 3,970' PROD1 MD, 2,966' TVD. 7/18/2004 00:00 - 15:30 15.50 DRILL P Dir drill from 6,635' to pilot hole TD 9,215' MD, 5,090' TVD. Top of Schrader @ 7,214' MD, 4,201' TVD. Up wt 182K, Dwn wt 94K , 597 gpm - 3,280 psi, TO 12.5K, 100 RPM, ECD cal = 10.42, ECD = 10.64. ART 7.56 hrs, AST = .66 hrs. 15:30 - 17:00 1.50 DRILL P PROD1 Circ and cond mud and hole for wiper trip. Pump low I high vis sweep around. Cal ECD = 10.42, ECD = 10.64 17:00 - 00:00 7.00 DRILL P PROD1 POOH to 8,972'. Sack ream f/8,972' to 7,230'. Pumping 400- 580 gpm. Hole tight to 83001 high torque. Mad pass log up f/ 8,086' to 7,975',7,716' -7,230', and 7,346' -7,230'. 7/19/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Continued to POOH t/6916', RIH to TD 9215' 01 :00 - 03:00 2.00 DRILL P PROD1 Stage up pumps to/600 gpm, 240 stks, 3350 psi, 100 rpm, tq 9-11 K. CSU 2X wllowhigh sweep. Cal ECD = 10.32 ppg , Act ECD = 10.32. No pmp up wt n= 185K dn wt = 90K. Monitor well 10 min. 03:00 - 06:00 3.00 DRILL P I PROD1 Pull 5 stds, pump dry job, con!. POOH, intermitent over pull of 10k-18k f 4500'-4200' 06:00 - 07:30 1.50 DRILL P PROD1 CSU 2X a 4200', 240 spm, 600 gpm, 2130 psi, 100 rpm, 5-8k torq, ECD = 10.34 ppg (intermitent torq to 12K) . 07:30 - 09:00 1.50 DRILL P PROD1 Sack ream f/4200' to 3441'. Circ high vis sweep @shoe, 240 spm, 600 gpm, 1947 psi, tq = 3-4k, ECD =10.32, monitor well f/10 min. Pump dry-job. POOH 09:00 - 12:00 3.00 DRILL P PROD1 Cont to POOH, handle SHA#3 12:00 - 13:00 1.00 DRILL P PROD1 Lay down SHA #3 13:00·13:30 0.50 DRILL P PROD1 Clean and clear rig floor. 13:30 - 14:00 0.50 PXA P ASAN PU/RU 3.5" tubing equip f/P&A 14:00·16:00 2.00 PXA P ASAN RIH 1X1 w/3.5" 9.3# tubing and plug catcher (1343') 16:00 - 16:30 0.50 PXA P ASAN LDIRD 3.5' tubing equipment 16:30 - 20:00 3.50 PXA P ASAN RIH w/3 1/2' tubing on drillpipe to 9215' TMD 20:00 - 22:30 2.50 PXA P ASAN Condition mud and circulate at 600 gpm w/2400 psi 22:30 - 23:30 1.00 PXA P ASAN Pump 20 bbls water & PT lines t/3K - pump 106 bbls of 15.8 Printed: 8/312004 9: 11 :30 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 7/11/2004 Rig Release: 7/28/2004 Rig Number: Spud Date: 7/11/2004 End: 7/28/2004 7/19/2004 22:30 - 23:30 1.00 PXA P ABAN ppg class G cmt - 3 bbls H20 tail - rig displace w/68 bbls of 9.5 ppg mud at @8 bpm w/1550 psi 23:30 - 00:00 0.50 PXA P ABAN POOH to 8100', up WI (no pmp) 173K 7/20/2004 00:00 - 03:00 3.00 PXA P ABAN BRK CIRC. @8100', STAG UP T/600 GPM, 240 SPM, 2790 PSI, UP WT. 152K, DN WT 68K, W/PMPS 03:00 - 03:30 0.50 PXA P ABAN PMP 15 BBLS H20, PT LINE T/3K, 106 BBLS CLASS G 15.5 PPG CMT, 3 BBL WATER, DISP W/57 BBLS 9.5 PPG MUD F/RIG @ 8 BPM, 1425 PSI 03:30 - 04:30 1.00 PXA P ABAN POOH T/6900', UP WT. NO PMP 150K 04:30 - 06:00 1.50 PXA P ABAN DROP DP DART. BRK CIRC. @ 6900', STAG UP TO 600 GPM, 240 SPM, 1940 PSI, RT 15 RPM, TQ 4-5K, UP WT 129K, DN WT 68K 06:00 - 09:30 3.50 PXA P ABAN MONITOR WELL F/10 MIN, PULL 5 STANDS, PUMP DRY JOB, CON'T TO POOH TISHOE, MONITOR WELL, CON'T TO POOH T3.5" TUBING 09:30 - 1 0:00 0.50 PXA P ABAN RIG UP 3.5" TUBING HANDLING EQUIPMENT 10:00 - 12:00 2.00 PXA P ABAN POOH W/3.5" TUBING & LD 1X1 12:00 - 12:30 0.50 PXA P ABAN POOH W/3.5" TUBING & LD 1X1 12:30 - 13:30 1.00 PXA P ABAN RD TUBING HANDLING EQUIPMENT AND CLEAR & CLEAN FLOOR 13:30 - 16:00 2.50 PXA P ABAN MU BHA #4 & TEST MWD @ 1128' (TEST GOOD) 16:00 - 17:30 1.50 PXA P ABAN CUT DRLG LINE - 74', SERVICE TOP DRIVE 17:30 - 20:00 2.50 PXA P ABAN RIH TO 4565' (TIGHT) 20:00 - 21 :00 1.00 PXA P ABAN RIH F/4485' TO 4671' W/500 GPM @ 2000 PSI - 60 RPM 21 :00 - 22:00 1.00 PXA P ABAN RIH F/4671, TO 6166' (NO CIRCULATION) 22:00 - 00:00 2.00 PXA P ABAN RIH F/6166' TO 6915' W/550 GPM @ 2500 PSI - 60 RPM, TOP OF CEMENT TAGGED AT 6915' TMD. CONFIRMED W/ 50K SET DOWN. 7/21/2004 00:00 - 02:30 2.50 STKOH P PROD2 POOH F/6915' TO 3891' TO SWAP MUD SYSTEMS, UP WT 174K, DN WT 77K 02:30 - 03:00 0.50 STKOH P PROD2 BRK CIRC AT 3891', STG UP PMP'S T/600 GPM, 240 SPM, 1450 PSI, 80 RPM, TQ 5K, DISPLACED HOLE W/NEW FW LSND 9.0 PPG MUD 03:00 - 07:30 4.50 STKOH P PROD2 POOH TO 3591', BEGIN OH SIDETRACK, CONT. DRLG T/4485' 07:30 - 08:00 0.50 DRILL N RREP PROD2 C/O DISCHARGE VALVE #1 MP, #2 CYLINDER 08:00 - 12:00 4.00 DRILL P PROD2 CONT. DRLG F/4458' T/5231', UP WT 135K, DN WT 76K, RPM 76, SPM 240, GPM, 600, PSI ON 2120, OFF 1840, TQ ON 8K, OFF 6.5K, WOB 10-20K 12:00 . 00:00 12.00 DRILL P PROD2 DRILL F/5231, TMD Tn200' TMD UP WT 187K, DN WT 87K, RPM 100, SPM 240, GPM, 3000, PSI ON 2820, OFF 1840, TQ ON 10K, OFF 8.5K, WOB 10-20K 7/22/2004 00:00 - 02:00 2.00 DRILL P PROD2 CBU 3X @ 240 SPM, 600 GPM, 2770 PSI, 100 RPM, TQ 8-10K,PMP LOW/HI VIS-HI WT SWEEP COMBO, CAL ECD ATTD 10.11 PPG, ECD (PWD) WHEN SHUT DOWN FIST 10.35 PPG, MONITOR WELL F/10 MIN 02:00 - 02:30 0.50 DRILL P PROD2 POOH TO 6950' (W/O PUMPS), 30K OVERPULL AT THAT POINT. DECISION MADE TO RETURN TO BOTTOM TO BACK-REAM OUT 02:30 - 03:00 0.50 DRILL P PROD2 CIRCULATE BU PRIOR TO BEGIN SHORT TRIP. 03:00 - 11 :30 8.50 DRILL P PROD2 BACK REAM T/GHOST REAMER DEPTH AT 6192', @600 GPM,100 RPM, REDUCED GPM TO 450-550 GPM DUE TO INCREASE ECD'S, FINAL ECD 10.41 PPG @600 GPM, 2581 Printed: 8/312004 9:11 :30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 7/11/2004 Rig Release: 7/28/2004 Rig Number: Spud Date: 7/11/2004 End: 7/28/2004 7/22/2004 03:00 - 11 :30 8.50 DRILL P PROD2 PSI, CON'T TO POOH W/INTERMITENT OVER PULL @5171', 5082', WIPE OK, CONT., BEGAN TO SWAB @4700', BACKREAM F/4700' TO 3441'. 11 :30 - 12:00 0.50 DRILL P PROD2 PMP LOW/HIGH SWEEP COMBO AT SHOE, 555 GPM, 1700 PSI, 100 RPM 12:00 - 14:00 2.00 DRILL P PROD2 RIH F/3441, - 7225' 14:00 - 15:30 1.50 DRILL P PROD2 CONDITION MUD & CIRC, 600 GPM, 2900 PSI, 100 RPM CALC ECD = 10.11 ACT ECD = 10.12 UP WT PMP'S ON 202K, ROT WT PMP'S ON 122K, DN WT PMP'S ON 87K, UP WT PMP'S OFF 208K, DN WT PMP'S OFF 91K, SPOT G-SEAL PILL IN OH (10 PPB) 15:30 - 20:00 4.50 DRILL P PROD2 MONITOR WELL, BEGIN TOOH, PULL 2 WET, PUMP DRY JOB & POOH 20:00 - 22:00 2.00 DRILL P PROD2 HANDLE/LD BHA #4 22:00 - 22:30 0.50 CASE P PROD2 CLEAN & CLEAR RIG FLOOR 22:30 - 00:00 1.50 BOPSUPP PROD2 FUNCTION ALL RAMS & FLUSH STACK, PULL WIRING & INSTALL TEST PLUG, CHANGE TOP RAM TO 7" 7/23/2004 00:00 - 00:30 0.50 BOPSUF P PROD2 FINISH CIO RAMS TIT' AND TEST DOOR SEALS T/3500 PSI F/5 MIN 00:30 - 02:30 2.00 CASE P PROD2 R/U 7" CASING EQUIP, MAKE DUMMY LANDING/HANGER, R/U FLOOR VALVE 02:30 - 10:00 7.50 CASE P PROD2 P/U 7" BTC-MOD L-80, #26 PPF, DOPE WIBOL 2000 NM, CHECK FLOAT-OK, CONT. 1X1, 80 FT/MIN IN W/CASING, BRK. CIRC EVERY 10 JT. F/5MIN, SPOT RA TAG ABOVE JTS #16 & #28, RIH T/SHOE (3441'), CBU X 1.5 @ 6 BPM, 170 PSI @ 15 SPM, 260 PSI @ 40 SPM, UP WT 106K, DN WT 80K 10:00 - 12:00 2.00 CASE P PROD2 CONT. RIH WI?" CASING @ 1MIN PER JT, BREAK CIRC EVERY 5 JT'S, CIRC 10 MIN EVERY 15TH JT F/3441 '-4811', UP WT 135K, DN WT 92K @ 4811' W/PUMP ON 12:00 - 17:30 5.50 CASE P PROD2 CONT. RIH WIT' CASING F/481 l' FILLING EVERY JT, BREAKING CIRC EVERY 5 JTS, CIRC 10 MIN EVERY 15TH JT, CBU @5400', UP WT 94K, DN WT 85K, CONTINUE RIH WI?"~ CSG, 6538' - UP WT = 190K, DN = 105, 6885' - UP WT = 200K, DN = 105K, 7177' - UP = 231K, DN = 106K 17:30 - 18:30 1.00 CASE P PROD2 MU LNDG JT, LAD FRANKS TOOL, MAKE UP XO AND CEMENT HEAD 18:30 - 20:30 2.00 CASE P PROD2 CIRC AND RECIPROCATE CASING IN PREP F/CMT JOB, 40 SPM = 308 PSI, 86 SPM = 470 PSI, 100 SPM = 500 PSI, 123 SPM = 605 PSI, UP WT = 220 K, DN WT = 100K 20:30 - 22:15 1.75 CEMT P PROD2 PT CMT LINES T/4000 PSI, PUMP 25 BBLS CW100, 35 BBLS MUD PUSH, 63 BBLS TAIL SLURRY @15.8 PPG - 326 SXS CLASS G CMT, CHASE W/SEAWATER, BUMP PLUG @4785 STKS 22:15 - 23:00 0.75 CEMT P PROD2 TEST CASING TO 4000 PSI F/30 MIN AGAINST PLUG, BLED DOWN 100 PSI IN 30 MINS 23:00 - 00:00 1.00 CEMT P PROD2 RIG DOWN CEMENT EQUIPMENT 7/24/2004 00:00 - 00:30 0.50 CASE P PROD2 SEND OUT CSG EQUIP & LONG BAILS 00:30 - 01 :00 0.50 CASE P PROD2 INSTALL 7" PO & TEST TO 5000 PSI F/10MIN 01 :00 - 03:30 2.50 BOPSUP P PROD2 FLUSH STACK W/PORTED SUB, INSTALL TEST LUG & C/O UPPER PIPE RAMS TO 3 1/2" X 6", TEST DOOR SEALS TO 4000 PSI ·OK" 03:30 - 03:30 24.00 PERFOB P OTHCMP RIU TO RUN PERF GUNS, LOAD GUNS IN PIPE SHEAD Printed: 8/312004 9: 11 :30 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 7/11/2004 Rig Release: 7/28/2004 Rig Number: Spud Date: 7/11/2004 End: 7/28/2004 7/24/2004 03:30 - 05:00 1.50 PERFOB P OTHCMP PJSM, MIU 379.66' OF 4.5 5SPF 4505PJ GUN ASSEMBLY W/SPACER PUPS 05:00 - 06:00 1.00 PERFOB P OTHCMP P/U REMAINDER OF BHA W/ANADRIL SLIM PULSE LWD GR, SHALLOW HOLE TEST MWD - OK 06:00 - 10:30 4.50 PERFOB P OTHCMP RIH W/GUN ASSY ON 4" DP, TAG F/C AT 7123', 164K UP, 84K DN 10:30 - 12:00 1.50 PERFOB P OTHCMP P/U 10', BRK CIRC W/SW AT 3 BPM AT 100 PSI, DISPLACE WELL TO 9.3 PPG NACL BRINE AT 6 BPM AT 480 PSI FREEZE PROTECT OA W172 BBLS DEAD CRUDE FCP 3 BPM AT 1000 PSI, SHUT OA W/1000 PSI 12:00 - 16:30 4.50 PERFOB P OTHCMP LOG OOH W/PERF GUNS TO 6884'. MWD SIGNAL BAD. RELOG @ 1 OO'/HR. GOOD SIGNAL. 16:30 - 18:00 1.50 PERFOB P OTHCMP SPOT GUNS ON DEPTH. PRACTICE RUN FOR FIRING SEQUENCE, FIRE GUNS AT 6945' 18:00 - 19:30 1.50 PERFOB P OTHCMP MONITOR WELL, POOH ABOVE PERFS T/6511', CBU 2X 2 100 SPM = 550 PSI 19:30 - 20:00 0.50 PERFOB P OTHCMP RIH T/7071', NO PROBLEMS, MONITOR WELL 20:00 - 00:00 4.00 PERFOB P OTHCMP POOH, LEVE 25 STANDS TOTAL IN DRK, LAY DOWN 4" DP TOTAL LOSSES F/LAST 12 HOURS = 39 BBLS 7/25/2004 00:00 - 00:30 0.50 PERFOB P OTHCMP LDIBHA 00:30 - 03:00 2.50 PERFOB P OTHCMP PJSM, UD SPENT GUNS & BLANKS, ALL SHOTS FIRED 03:00 - 03:30 0.50 PERFOB P OTHCMP CLEAR & CLEAN FLOOR, SEND OUT SCHLUMBERGER & BAKER TOOLS 03:30 - 04:30 1.00 PERFOB P OTHCMP RIH W/8 STDS HWDP & LD 24 JTS 04:30 - 06:00 1.50 BOPSUPP LOWER1 C/O UPPER PIPE RAMS TO 7" & TEST DOOR SEALS TO 3500 PSI "OK" 06:00 - 07:30 1.50 EVAL P LOWER1 PJSM, BRING SWLS TOOLS TO RIG FLOOR, R/U 7" LUBRICATOR & SCHLUMBERGER EQUIP 07:30 - 09:30 2.00 EV AL P LOWER1 RIH W/6.04" OD GR & JB ON E-LlNE TO 6985' WNERY LITTLE DEBRIS. 09:30 - 11 :30 2.00 EV AL P LOWER1 MAKE 2ND GRlJB RUN, 2 TABLESPOONS OF DEBRIS RETURNED 11 :30 - 12:00 0.50 EV AL P LOWER1 RID GRIJB, R/U USIT LOG 12:00 - 14:00 2.00 EV AL P LOWER1 FINISH WIRELlNE RU, RUN USIT LOG, TOOL FAILURE, POOH 14:00 - 17:30 3.50 EV AL P LOWER1 BO LUBRICATOR, CHANGE OUT END OF TOOL, MAKE UP WB, RIH W/USIT LOGGING TOOL. LOG F/7105' TO 4900'. GOOD BOND TO TOC @ 5140'. POOH, RD WL EQUIP, LD LUBRICATOR. 17:30 - 19:00 1.50 BOPSUPP RUNCMP PULL WEAR BUSHING, INSTALL TEST PLUG, CHANGE OUT 7" RAMS TO 3 1/2' X 6', TEST DOOR SEALS TO 4000 PSI, PULL TEST PLUG, RIG DOWN TEST JOINT 19:00 - 20:00 1.00 BOPSUP P RUNCMP CUT AND SLIP 74' OF DRILLING LINE 20:00 - 20:15 0.25 WHSUR P RUNCMP DUMMY RUN WfTUBING HANGER 20:15 - 21:30 1.25 RUNCOMP RUNCMP RIG UP TO RUN TBG, C/O BAILS, RU TONGS, TORQ TURN, ETC 21 :30 - 22:30 1.00 RUNCOMP RUNCMP PJSM, RIH W/COMPLETION 22:30 - 23:00 0.50 RUNCOMN DFAL RUNCMP HUNG UP #3 GLM IN WELLHEAD, TORE OFF DIVERTER Printed: 8/3/2004 9: 11 :30 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 7/11/2004 Rig Release: 7/28/2004 Rig Number: Spud Date: 7/11/2004 End: 7/28/2004 7/25/2004 22:30 - 23:00 0.50 RUNCOrvN DFAL RUNCMP TAB (RECOVERED) 23:00 - 00:00 1.00 RUNCOII¡J\J DFAL RUNCMP WAIT ON NEW GLM FI DEADHORSE TOUR FLUID LOSS = 0 WELL FLUID LOSS = 60 BBLS 7/26/2004 00:00 - 03:00 3.00 RUNCOrvN DFAL RUNCMP WAIT ON NEW GLM F/DEADHORSE, SERVICE DRAWWORKS, RUFFNECK, CHOKE & MANIFOLD, CENTRIFUGE, DRAGCHAIN, WHILE WAITING ON GLM 03:00 - 04:00 1.00 RUNCOrvN DFAL RUNCMP M/U REPLACEMENT GLM #3 & REST OF 3.5" 9.2# L-80 TBG & JEWELRY TO 2300 FT LBS TQ USING JET LUBE SEAL GAURD PIPE DOPE (NOTE: RA MARKER AT 6633.25 (BOTTOM) - 6632.58 (TOP» 04:00 - 12:00 8.00 RUNCOMP RUNCMP CIO TO 4.5" TOOLS, RUN 4.5" 12.6# L-BO TC-II JEWLERY & TBG AS PER RUNNING DETAIL, 3850 FT LBS TQ USING JET LUBE, DEPTH 4500' 64K DN TOUR LOSS 5 BBLS WELL LOSS 65 BBLS 12:00 - 14:00 2.00 RUNCOMP RUNCMP RUN 4.5" 12.6# L-BO TC-II JEWLERY & TBG PER COMPLETION DETAIL, 3850 TQ - JET LUBE SEAL GUARD 14:00 - 14:30 0.50 RUNCOMP RUNCMP MAKE UP TUBING HANGER/LANDING JT AND LAND AT 6830', UP = 11 OK, DN = 75K, TRA VL ASSY = 35K 14:30 - 15:30 1.00 RUNCOMP RUNCMP CLEAR FLOOR/RIG UP SWLS FOR LOGGING 15:30 - 17:00 1.50 RUNCOiIIP RUNCMP RIH W/GR LOG, LOCATE RA MARKER FIDEPTH CONTROL, POOH, PACKERS ON DEPTH 17:00 - 19:00 2.00 RUNCOrvN DFAL RUNCMP BREAK OFF PACK OFF, PULL SWL T, MISSING 2 EA 2 1/8" ROLLERS AND 2 EA PINS FROM WT BAR, WOO, RIG DOWN SWLS 19:00 - 22:00 3.00 RUNCOrvN DFAL RUNCMP WAIT ON SL, PULL TUBING UP l' & DRAIN STACK, LAND TUBING, RILDS 22:00 - 00:00 2.00 RUNCOIVN DFAL RUNCMP RIG UP WIRELlNE (WAIT ON PARTS) TOUR LOSS = 2 BBLS WELL LOSS = 67 BBLS 7/27/2004 00:00 - 02:00 2.00 RUNCOrvN DFAL RUNCMP RU SLlCKLlNE, MU 4 1/2" BRUSH ASSEMBLY 02:00 - 04:00 2.00 RUNCOrvN DFAL RUNCMP RIH W/4 1/2" BRUSH ON SL TO 6474', POOH 04:00 - 06:30 2.50 RUNCOrvN DFAL RUNCMP C/O TOOL, RIH W/3.5" BRUSH & MAGNET ON SLlCKLlNE, POOH & RETRIEVE 2 EACH 2.015" FORLLERS FROM RHC BODY 06:30 - 07:00 0.50 RUNCOrvN DFAL RUNCMP WAIT ON SL (ANALYSE ROLLER & C/O TOOLS) 07:00 - 09:00 2.00 RUNCOrvN DFAL RUNCMP RIH WIGS PULLING TOOL W/SHEAR DN ASSEMBLY TO RETRIEVE RHC PLUG, JAR DN & SHEAR TOOL, POOH 09:00 - 10:30 1.50 RUNCOrvN DFAL RUNCMP CONVERT GS PULLING TOOL OVER TO SHEAR UP ASSEMBLY & RIH, LATCH-UP & RETRIEVE RHC PLUG, POOH, PLUG WAS CLEAN, NO PINS 10:30 - 12:00 1.50 RUNCOMP RUNCMP RlU & REVERSE CIRC CORROSION INHIBITOR DN 4 1/2" BY 7" ANNULUS AT 3 BPM, 200 PSI & SHOT WICLEAN 9.3 PPG BRINE BETWEEN TOP PKR & 4 1/2" GLM TOUR LOSS = 4 BBLS WELL LOSS = 71 BBLS 12:00 - 12:30 0.50 RUNCOrvN DFAL RUNCMP RIG DOWN CIRC EQUIP, RU SLlCKLlNE 12:30 - 14:00 1.50 RUNCOrvN DFAL RUNCMP RU 3.5 X-LINE PLUG, RIH TO TOP 7" X 3.5" PACKER Printed: 8/312004 9: 11 :30 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-213 V-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 7/11 /2004 Rig Release: 7/28/2004 Rig Number: Spud Date: 7/11/2004 End: 7/28/2004 7/27/2004 12:30 - 14:00 1.50 RUNCOMN DFAL RUNCMP @6480', WORK PLUG THROUGH PACKER 14:00 - 14:30 0.50 RUNCOMN DFAL RUNCMP POOH TO INSPECT X-LINE PLUG SEALS, PLUG WAS NOT ON THE TOOL STRING 14:30 - 16:00 1.50 RUNCOMN DFAL RUNCMP SWAP TOOLS TO RETRIEVE PLUG, RIH TO 6472', TAG UP ON X-LINE PLUG, POOH, NO PLUG 16:00 - 17:30 1.50 RUNCOMN DFAL RUNCMP REDRESS RETRIEVING TOOL, RIH, TAG UP @6472', POOH W/X-LlNE PLUG, PIN FROM SINKER BAR WHEEL CAUGHT IN PACKING 17:30 - 18:30 1.00 RUNCOMN DFAL RUNCMP WAIT ON SL (INSPECT & REDRESS 3.5" X-LINE PLUG 18:30 - 20:30 2.00 RUNCOMN DFAL RUNCMP RIH WITH X-LINE PLUG - SET @680T, POOH 20:30 - 22:30 2.00 RUNCOMP RUNCMP PULL LANDING JT, PRESSURE TUBING TO 4200 PSI, HOLD F/30 MIN, BLEED TUBING TO 2500 PSI, PRESSURE ANNULUS TO 4000 PSI, HOLD F/30 MIN, BLEED ANNULUS TO 0 PSI, BLEED TBG TO 0 PSI, PRESSURE ANNULUS TO 2500, SHEAR OUT DCK VALVE 22:30 - 00:00 1.50 RUNCOMP RUNCMP RD WIRELlNE (SLlCKLlNE), DRAIN STACK, SET TWC & TEST TOUR LOSS = 3 BBLS WELL LOSS = 74 BBLS 7/28/2004 00:00 - 01 :00 1.00 WHSUR P WHDTRE PULL RISER, REMOVE MOUSEHOLE & ND BOP STACK 01 :00 - 01 :30 0.50 WHSUR P WHDTRE SNAKE TREE 7 ADAPTER FLANGE IN CELLAR & PREP 01 :30 - 03:00 1.50 WHSUR P WHDTRE NU ADAPTER FLANGE & TREE, TEST BOT TO 5000 PSI "OKI' 03:00 - 04:00 1.00 WHSUR P WHDTRE RU DSM & PULL TWC W/LUBRICATOR 04:00 - 06:00 2.00 WHSUR P WHDTRE RU LITTLE RED & PJSM, PUMP 90 BBLS DIESEL DOWN 4.5" X 7" ANNULUS TO AND ALLOW TO U TUBE TO TUBING, TO FREEZE PROTECT IA AND TUBING DOWN TO 2300' TVD (2700' MD) AT 2.4 BPM - 1275 PSI, SUCK REMAINING FLUID FI PITS 06:00 - 07:00 1.00 WHSUR P WHDTRE RD & BL DN CIRC LINES, LUBRICATE BPV IN W/DSM & TEST F/BELOW TO 1000 PSI, RD DSM & LlL RED, INSTALL VR PLUGS IN IA & OA WELLHEAD OUTLETS. 07:00 - 08:00 1.00 RIGD P WHDTRE SECURE CELLAR F/RIG, MOVE TO V-204 RIG RELEASED FROM V-213i AT 08:00 HRS 7/28/04 Printed: 8/3/2004 9: 11 :30 AM bp V-213 Survey Report Schlumberger Report Date: 22-Jul-04 Survey f DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 45.000" Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 It, E 0.000 It Structure I Slot: V-Pad / Plan V-213 (S-W) TVD Reference Datum: Rotary Table Well: V-213 TVD Reference Elevation: 82.80 It relative to MSL Borehole: V-213 Sea Bed I Ground Level Elevation: 54.30 It relative to MSL UWlfAPI#: 500292321300 Magnetic Declination: 24.906" Survey Name f Date: V-213 / July 22, 2004 Total Field S1rength: 57570.631 nT Tort f AHD I DOli ERD ratio: 124.089" /4774.98 It/ 5.934 / 0.958 Magnetic Dip: 80.818" Grid Coordinate System: NAD27 Alaska State Planes. Zone 04. US Feet Declination Date: July 19, 2004 Location LatlLong: N 70.32768174, W 149.26373616 Magnetic Declination Model: BGGM 2003 Location Grid N/E YIX: N 5969968.370 ItUS, E 590785.030 ftUS North Reference: True North Grid Convergence Angle: +0.69329489" Total Corr Mag North·> True North: +24.906" Grid Scale Factor: 0.99990936 Local Coordinates Referenced To: Well Head e Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting Latitude Longitude Survey Tool I Depth Section Departure Model (It) (deg) (deg) (It) (It) (It) (It) (It) (It) ( degf100 It) ( degJ100 It) ( degf100 It) (ltUS) (ltUS) RTE 0.00 0.00 0.00 -82.80 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 596.9968.37 590785.03 N 70.32768174 W 149.26373616 BP _UNKNOWN First Gyro Station 100.00 0.28 17.61 17.20 100.00 0.22 0.24 0.23 0.07 0.28 0.28 0.00 5969968.60 590785.10 N 70.32768238 W 149.26373556 BP _GYD GC MS 200.00 1.71 1.08 117.18 199.98 1.51 1.97 1.96 0.18 1.44 1.43 -16.53 5969970.33 590785.18 N 70.32768709 W 149.26373473 BP _GYD GC MS 300.00 4.11 0.61 217.05 299.85 5.14 7.05 7.03 0.24 2.40 2.40 -0.47 5969975.41 590785.19 N 70.32770096 W 149.26373419 BP _GYD GC MS 400.00 6.82 350.24 316.58 399.38 11.13 16.55 16.47 -0.73 2.87 2.71 -10.37 5969984.83 590784.10 N 70.32772674 W 149.26374205 BP _GYD GC MS 500.00 9.08 347.65 415.62 498.42 18.82 30.38 30.03 -3.42 2.29 2.26 -2.59 5969998.36 590781.25 N 70.32776379 W 149.26376390 BP _GYD GC MS Last Gyro Station 540.00 9.85 355.96 455.07 537.87 22.76 36.94 36.53 -4.34 3.92 1.93 20.77 5970004.84 590780.25 N 70.32778154 W 149.26377133 BP _GYD GC MS First MWD+IFR+MS 579.35 10.31 353.95 493.82 576.62 27.18 43.83 43.39 -4.95 1.47 1.17 -5.11 5970011.69 590779.56 N 70.32780027 W 149.26377626 BP _MWD+IFR+MS 671.02 11.95 358.76 583.76 666.56 38.90 61.51 61.04 -6.02 2.05 1.79 5.25 5970029.32 590778.28 N 70.32784849 W 149.26378494 BP _MWD+IFR+MS 762.85 14.96 3.10 673.06 755.86 54.31 82.87 82.38 -5.58 3.46 3.28 4.73 5970050.67 590778.45 N 70.32790680 W 149.26378141 BP _MWD+IFR+MS 854.69 16.76 4.20 761.40 844.20 73.15 107.97 107.43 -3.97 1.99 1.96 1.20 5970075.73 590779.76 N 70.32797522 W 149.26376834 BP _MWD+IFR+MS 948.63 17.55 7.81 851.17 933.97 94.69 135.67 134.97 -1.05 1.41 0.84 3.84 5970103.30 590782.34 N 70.32805046 W 149.26374469 BP _MWD+IFR+MS 1041.12 19.73 17.12 938.82 1021.62 119.61 165.17 163.71 5.44 3.98 2.36 10.07 5970132.12 590788.49 N 70.32812899 W 149.26369204 BP _MWD+IFR+MS 1134.83 20.73 26.36 1026.77 1109.57 149.31 197.51 193.70 17.46 3.57 1.07 9.86 5970162.25 590800.15 N 70.32821091 W 149.26359454 BP _MWD+IFR+MS 1227.78 23.80 30.68 1112.78 1195.58 183.08 232.71 224.58 34.34 3.74 3.30 4.65 5970193.33 590816.65 N 70.32829527 W 149.26345766 BP _MWD+IFR+MS 1321.22 26.29 31.39 1197.43 1280.23 221.47 272.26 258.46 54.74 2.68 2.66 0.76 5970227.45 590836.64 N 70.32838784 W 149.26329222 BP _MWD+IF. 1413.60 27.70 31.72 1279.75 1362.55 262.25 314.19 294.19 76.69 1.53 1.53 0.36 5970263.44 590858.15 N 70.32848545 W 149.26311425 BP _MWD+IF 1507.44 30.30 33.86 1361.82 1444.62 306.72 359.68 332.41 101.35 2.98 2.77 2.28 5970301.95 590882.34 N 70.32858985 W 149.26291426 BP _MWD+IFR 1598.27 32.13 36.03 1439.49 1522.29 353.06 406.75 370.97 128.33 2.36 2.01 2.39 5970340.83 590908.85 N 70.32869521 W 149.26269549 BP _MWD+IFR+MS 1692.08 33.90 38.07 1518.16 1600.96 403.68 457.85 411.75 159.14 2.23 1.89 2.17 5970381.97 590939.16 N 70.32880660 W 149.26244565 BP _MWD+IFR+MS 1785.97 32.95 38.77 1596.52 1679.32 455.05 509.57 452.27 191.27 1.09 -1.01 0.75 5970422.88 590970.80 N 70.32891730 W 149.26218504 BP _MWD+IFR+MS 1879.63 34.66 38.30 1674.34 1757.14 506.83 561.68 493.03 223.73 1.85 1.83 -0.50 5970464.03 591002.76 N 70.32902866 W 149.26192181 BP _MWD+IFR+MS 1972.29 37.05 38.02 1749.44 1832.24 560.71 615.95 535.71 257.26 2.59 2.58 -0.30 5970507.10 591035.77 N 70.32914524 W 149.26164990 BP _MWD+IFR+MS 2065.20 39.87 40.68 1822.19 1904.99 618.20 673.72 580.35 293.92 3.52 3.04 2.86 5970552.18 591071.88 N 70.32926720 W 149.26135258 BP _MWD+IFR+MS 2160.26 44.51 41.22 1892.60 1975.40 681.87 737.55 628.55 335.76 4.90 4.88 0.57 5970600.88 591113.13 N 70.32939886 W 149.26101325 BP _MWD+IFR+MS 2254.01 48.62 41.29 1957.04 2039.84 749.79 805.61 679.72 380.64 4.38 4.38 0.07 5970652.58 591157.39 N 70.32953864 W 149.26064925 BP _MWD+IFR+MS 2347.57 53.40 42.84 2015.89 2098.69 822.39 878.31 733.66 429.37 5.27 5.11 1.66 5970707.10 591205.45 N 70.32968601 W 149.26025406 BP _MWD+IFR+MS 2440.82 56.75 44.13 2069.27 2152.07 898.80 954.75 789.11 481.99 3.77 3.59 1.38 5970763.18 591257.39 N 70.32983749 W 149.25982731 BP _MWD+IFR+MS 2534.77 56.49 44.15 2120.96 2203.76 977.25 1033.20 845.41 536.62 0.28 -0.28 0.02 5970820.14 591311.34 N 70.32999129 W 149.25938420 BP _MWD+IFR+MS 2627.52 57.27 45.10 2171.64 2254.44 1054.92 1110.88 900.70 591.19 1.20 0.84 1.02 5970876.07 591365.23 N 70.33014230 W 149.25894162 BP _MWD+IFR+MS SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) Plan V-213 (S-W)\V-213\V-213\V-213 Generated 8/5/2004 10:46 AM Page 1 of 3 Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Eaating Latitude Longitude Survey Tool f Depth Section Departure Model (It) (dog) (dog) (It) (It) (It) (It) (It) (It) (dog/1001t) (deg/1001t) (dog/1001t) (ItUS) (ItUS) 2720.65 57.15 44.89 2222.08 2304.88 1133.22 1189.17 956.06 646.55 0.23 -0.13 -0.23 5970932.09 591419.90 N 70.33029354 W 149.25849265 BP _MWD+IFR+MS 2813.90 57.93 44.92 2272.12 2354.92 1211.90 1267.85 1011.79 702.09 0.84 0.84 0.03 5970988.49 591474.76 N 70.33044577 W 149.25804215 BP _MWD+IFR+MS 2907.22 57.21 44.81 2322.17 2404.97 1290.66 1346.62 1067.62 757.66 0.78 -0.77 -0.12 5971044.98 591529.64 N 70.33059827 W 149.25759147 BP _MWD+IFR+MS 3001.17 56.93 44.70 2373.24 2456.04 1369.52 1425.48 1123.61 813.18 0.31 -0.30 -0.12 5971101.63 591584.48 N 70.33075124 W 149.25714115 BP _MWD+IFR+MS 3093.46 58.70 46.36 2422.40 2505.20 1447.61 1503.58 1178.32 868.92 2.45 1.92 1.80 5971157.00 591639.55 N 70.33090067 W 149.25668902 BP _MWD+IFR+MS 3187.31 58.23 44.83 2471.49 2554.29 1527.60 1583.57 1234.28 926.06 1.48 -0.50 -1.63 5971213.65 591696.01 N 70.33105354 W 149.25622550 BP _MWD+IFR+MS 3280.79 57.59 44.90 2521.15 2603.95 1606.79 1662.77 1290.42 981.93 0.69 -0.68 0.07 5971270.45 591751.19 N 70.33120687 W 149.25577233 BP _MWD+IFR+MS 3373.07 56.73 44.60 2571.19 2653.99 1684.32 1740.30 1345.48 1036.52 0.97 -0.93 -0.33 5971326.17 591805.10 N 70.33135728 W 149.25532957 BP _MWD+IFR+MS 3400.07 56.34 44.55 2586.08 2668.88 1706.85 1762.82 1361.52 1052.32 1.45 -1.44 -0.19 5971342.40 591820.71 N 70.33140110 W 149.25520134 BP _MWD+IFR+MS Tie-In Survey 3478.49 55.D7 47.93 2630.27 2713.07 1771.60 1827.60 1406.33 1099.09 3.91 -1.62 4.31 5971387.76 591866.93 N 70.33152349 W 149.25482197 BP _MWD+IFR+MS First MWD+IFR+MS 3573.07 54.72 45.88 2684.67 2767.47 1848.93 1904.97 1459.19 1155.59 1.81 -0.37 -2.17 5971441.30 591922.78 N 70.33166787 W 149.25436367 BP _MWD+IFR+MS 3667.15 52.70 45.42 2740.35 2823.15 1924.75 1980.80 1512.19 1209.82 2.18 -2.15 -0.49 5971494.95 591976.35 N 70.33181265 W 149.25392381 BP _MWD+IFR+MS 3760.91 52.47 45.17 2797.32 2880.12 1999.22 2055.27 1564.58 1262.75 0.32 -0.25 -0.27 5971547.96 592028.64 N 70.33195574 W 149.25349445 BP _MWD+IFR+MS 3854.07 53.37 44.75 2853.48 2936.28 2073.54 2129.59 1617.17 1315.26 1.03 0.97 -0.45 5971601.18 592080.51 N 70.33209939 W 149.25306844 BP _MWD+IF:e 3946.82 55.84 44.71 2907.20 2990.00 2149.14 2205.19 1670.88 1368.47 2.66 2.66 -0.04 5971655.53 592133.05 N 70.33224609 W 149.25263683 BP _MWD+IF 4039.61 56.82 44.15 2958.65 3041.45 2226.36 2282.42 1726.02 1422.52 1.17 1.06 -0.60 5971711.32 592186.44 N 70.33239672 W 149.25219830 BP _MWD+JFR+MS 4133.58 57.64 44.36 3009.51 3092.31 2305.37 2361 .43 1782.62 1477.66 0.89 0.87 0.22 5971768.57 592240.88 N 70.33255130 W 149.25175097 BP _MWD+IFR+MS 4227.02 57.09 42.27 3059.90 3142.70 2384.01 2440.12 1839.86 1531.64 1.97 -0.59 -2.24 5971826.46 592294.16 N 70.33270766 W 149.25131306 BP _MWD+IFR+MS 4319.05 56.46 41.67 3110.33 3193.13 2460.89 2517.10 1897.10 1583.13 0.88 -0.68 -0.65 5971884.31 592344.94 N 70.33286399 W 149.25089538 BP _MWD+IFR+MS 4412.85 55.62 40.27 3162.73 3245.53 2538.50 2594.90 1955.84 1634.14 1.53 -0.90 -1.49 5971943.65 592395.23 N 70.33302443 W 149.25048151 BP _MWD+IFR+MS 4505.33 55.95 40.33 3214.73 3297.53 2614.71 2671.37 2014.16 1683.60 0.36 0.36 0.06 5972002.57 592443.98 N 70.33318374 W 149.25008021 BP _MWD+IFR+MS 4598.93 56.27 40.98 3266.92 3349.72 2692.19 2749.07 2073.10 1734.22 0.67 0.34 0.69 5972062.11 592493.88 N 70.33334474 W 149.24966950 BP _MWD+IFR+MS 4692.46 57.75 41.82 3317.85 3400.65 2770.48 2827.52 2131.94 1786.10 1.75 1.58 0.90 5972121.57 592545.04 N 70.33350545 W 149.24924857 BP _MWD+IFR+MS 4785.68 57.59 42.03 3367.70 3450.50 2849.13 2906.29 2190.55 1838.73 0.26 -0.17 0.23 5972180.80 592596.96 N 70.33366552 W 149.24882156 BP _MWD+IFR+MS 4878.58 57.55 41.90 3417.52 3500.32 2927.44 2984.70 2248.85 1891.17 0.13 -0.04 -0.14 5972239.73 592648.67 N 70.33382476 W 149.24839614 BP _MWD+IFR+MS 4971.36 57.96 41.23 3467.02 3549.82 3005.77 3063.17 2307.57 1943.23 0.75 0.44 -0.72 5972299.06 592700.02 N 70.33398512 W 149.24797373 BP _MWD+IFR+MS 5066.03 59.51 39.59 3516.16 3598.96 3086.42 3144.09 2369.18 1995.67 2.21 1.64 -1.73 5972361.31 592751.71 N 70.33415342 W 149.24754818 BP _MWD+IFR+MS 5158.99 59.11 38.63 3563.60 3646.40 3165.94 3224.03 2431.21 2046.10 0.99 -0.43 -1.03 5972423.93 592801.38 N 70.33432283 W 149.24713900 BP _MWD+IFR+MS 5251.20 59.00 39.10 3611.02 3693.82 3244.57 3303.11 2492.79 2095.73 0.45 -0.12 0.51 5972486.10 592850.25 N 70.33449102 W 149.24673633 BP _MWD+IFR+MS 5345.05 57.97 39.03 3660.08 3742.88 3324.15 3383.12 2554.91 2146.15 1.10 -1.10 -0.D7 5972548.82 592899.91 N 70.33466068 W 149.24632719 BP _MWD+IFR+MS 5438.95 56.94 39.96 3710.59 3793.39 3402.93 3462.27 2615.99 2196.49 1.38 -1.10 0.99 5972610.50 592949.50 N 70.33482752 W 149.24591871 BP _MWD+IFR+MS 5532.58 56.81 40.29 3761.76 3844.56 3481.06 3540.68 2675.95 2247.02 0.33 -0.14 0.35 5972671.06 592999.30 N 70.33499128 W 149.24550864 BP _MWD+IFR+MS 5625.77 56.77 40.36 3812.80 3895.60 3558.77 3618.65 2735.39 2297.47 0.08 -0.04 0.08 5972731.10 593049.03 N 70.33515363 W 149.24509921 BP _MWD+IFR+MS 5720.10 56.84 40.97 3864.44 3947.24 3637.48 3697.59 2795.26 2348.91 0.55 0.07 0.65 5972791.59 593099.73 N 70.33531716 W 149.24468180 BP _MWD+IFR+MS 5812.17 56.26 42.27 3915.19 3997.99 3714.17 3774.41 2852.69 2399.93 1.34 -0.63 1.41 5972849.63 593150.05 N 70.33547400 W 149.24426778 BP _MWD+IF~. 5906.42 56.40 43.21 3967.45 4050.25 3792.54 3852.85 2910.30 2453.16 0.84 0.15 1.00 5972907.87 593202.58 N 70.33563133 W 149.24383580 BP _MWD+IFR+ 5999.62 54.56 42.84 4020.26 4103.06 3869.28 3929.63 2966.43 2505.56 2.00 -1.97 -0.40 5972964.63 593254.28 N 70.33578464 W 149.24341061 BP _MWD+IFR+MS 6093.39 52.35 44.06 4076.10 4158.90 3944.58 4004.96 3021.13 2557.36 2.58 -2.36 1.30 5973019.94 593305.41 N 70.33593400 W 149.24299028 BP _MWD+IFR+MS 6187.79 49.70 41.79 4135.47 4218.27 4017.91 4078.34 3074.84 2607.35 3.37 -2.81 -2.40 5973074.24 593354.74 N 70.33608068 W 149.24258460 BP _MWD+IFR+MS 6281.21 47.04 39.97 4197.53 4280.33 4087.54 4148.16 3127.61 2653.05 3.20 -2.85 -1.95 5973127.56 593399.80 N 70.33622481 W 149.24221364 BP _MWD+IFR+MS 6373.57 44.38 39.35 4262.02 4344.82 4153.36 4214.26 3178.49 2695.25 2.92 -2.88 -0.67 5973178.94 593441.38 N 70.33636378 W 149.24187117 BP _MWD+IFR+MS 6467.00 43.38 39.14 4329.36 4412.16 4217.80 4279.03 3228.65 2736.22 1.08 -1.07 -0.22 5973229.58 593481.74 N 70.33650075 W 149.24153866 BP _MWD+IFR+MS 6560.75 42.69 39.02 4397.88 4480.68 4281.44 4343.00 3278.31 2776.56 0.74 -0.74 -0.13 5973279.73 593521.46 N 70.33663639 W 149.24121131 BP _MWD+IFR+MS 6655.44 42.26 38.48 4467.73 4550.53 4345.00 4406.94 3328.17 2816.58 0.60 -0.45 -0.57 5973330.07 593560.87 N 70.33677258 W 149.24088647 BP _MWD+IFR+MS 6748.25 42.04 38.19 4536.53 4619.33 4406.86 4469.23 3377.03 2855.21 0.32 -0.24 -0.31 5973379.38 593598.91 N 70.33690600 W 149.24057292 BP _MWD+IFR+MS 6841.15 41.38 38.42 4605.89 4688.69 4468.25 4531.04 3425.53 2893.52 0.73 -0.71 0.25 5973428.34 593636.63 N 70.33703847 W 149.24026195 BP _MWD+IFR+MS 6934.11 40.28 38.20 4676.22 4759.02 4528.61 4591.82 3473.22 2931.20 1.19 -1.18 -0.24 5973476.48 593673.72 N 70.33716872 W 149.23995613 BP _MWD+IFR+MS 7028.50 39.28 38.25 4748.76 4831.56 4588.58 4652.21 3520.67 2968.57 1.06 -1.06 0.05 5973524.37 593710.51 N 70.33729829 W 149.23965281 BP _MWD+IFR+MS 7121.63 38.56 37.52 4821.22 4904.02 4646.64 4710.72 3566.84 3004.50 0.92 -0.77 -0.78 5973570.97 593745.88 N 70.33742440 W 149.23936117 BP _MWD+IFR+MS SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( do31r1-546 ) Plan V-213 (S-W)\V-213\V-213\V-213 Generated 8/5/2004 10:46 AM Page 2 of 3 4 Comments Last MWD+IFR+MS TD ( Projected) Le!!al Description: Measured I Inclination I Azimuth I Sub·Sea TVD I TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting Depth Section Departure (II) (deg) (deg) (II) (II) (II) (II) (II) (II) (deg/1001l) (degf1001l) (degf1001l) (IIUS) (IIUS) 7151.33 38.42 37.54 4844.47 4927.27 4664.97 4729.20 3581.50 3015.76 0.47 -0.47 0.07 5973585.76 593756.96 7225.00 38.42 37.54 4902.18 4984.98 4710.36 4774.98 3617.80 3043.65 0.00 0.00 0.00 5973622.40 593784.41 Latitude Survey Tool Model 1- Longitude N 70.33746443 W 149.23926977 BP _MWD+IFR+MS N 70.33756357 W 149.23904335 BP _BLIND Survey Type: Definitive Survey NOTES: GYD GC MS - ( Gyrodata - gyro compassing m/s -- Older Gyrodata gyro multlshots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multlshot Into open hole" model. ) MWD + IFR + MS - ( In-field referenced MWD with mult-statlon analysis and correction applied In post-processing.) Surface: 4718 FSL 1517 FEL S11 T11N R11E UM BHL: 3055 FSL 3750 FEL S1 T11N R11E UM Northln!! {Y} fftUSl 5969968.37 5973622.40 Eastin!! (XI fftUSl 590785.03 593784.41 SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) Plan V-213 (S-W)\V-213\V-213\V-213 e e Generated 8/5/2004 10:46 AM Page 3 of 3 V-213PB1 Survey Report Schlumberger Report Date: 19-Jul-04 Survey I DlS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 45.000' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft structure I Slot V-Pad / Plan V-213 (S-W) NO Reference Datum: RTE Well: V-213 NO Reference Elevation: 82.80 ft relative to MSL Borehole: V-213PB1 Sea Bed I Ground level Elevation: 54.30 ft relative to MSL UWlIAPI#: 500292321370 Magnetic Declination: 24.910' Survey Name I Date: V-213PB1 / July 19, 2004 Total Field Strength: 57570.301 nT Tort I AHD I 0011 ERD ratio: 212.420' /7041.81 ft / 6.433 / 1.383 Magnetic Dip: 80.818' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 15. 2004 location LatiLong: N 70.32768174, W 149.26373616 Magnetic Declination Model: BGGM 2003 Location Grid NlE YIX: N 5969968.370 ftUS, E 590785.030 ftUS North Reference: True North Grid Convergence Angle: -+<J.69329489· Total Corr Mag North -> True North: +24.910' e Grid Scale Factor: 0.99990936 Local Coordinates Referenced To: Well Head I Comments Measured I Inclination I Azimuth I Sub-Sea NO I NO I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting latitude longitude Survey Tool I Depth Section Departure Model (ft) (deg ) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (deg/100ft) (degI100ft) (flUS) (ftUS) RTE 0.00 0.00 0.00 -82.80 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5969968.37 590785.03 N 70.32768174 W 149.26373616 First Gyro Station 100.00 0.28 17.61 17.20 100.00 0.22 0.24 0.23 0.07 0.28 0.28 0.00 5969968.60 590785.10 N 70.32768238 W 149.26373556 BP _GYD GC MS 200.00 1.71 1.08 117.18 199.98 1.51 1.97 1.96 0.18 1.44 1.43 -16.53 5969970.33 590785.18 N 70.32768709 W 149.26373473 BP _GYD GC MS 300.00 4.11 0.61 217.05 299.85 5.14 7.05 7.03 0.24 2.40 2.40 -0.47 5969975.41 590785.19 N 70.32770096 W 149.26373419 BP _GYD GC MS 400.00 6.82 350.24 316.58 399.38 11.13 16.55 16.47 -0.73 2.87 2.71 -10.37 5969984.83 590784.10 N 70.32772674 W 149.26374205 BP _GYD GC MS 500.00 9.08 347.65 415.62 498.42 18.82 30.38 30.03 -3.42 2.29 2.26 -2.59 5969998.36 590781.25 N 70.32776379 W 149.26376390 BP _GYD GC MS Last Gyro Station 540.00 9.85 355.96 455.07 537.87 22.76 36.94 36.53 -4.34 3.92 1.93 20.77 5970004.84 590780.25 N 70.32778154 W 149.26377133 BP _GYD GC MS First MWD+IFR+MS 579.35 10.31 353.95 493.82 576.62 27.18 43.83 43.39 -4.95 1.47 1.17 -5.11 5970011.69 590779.56 N 70.32780027 W 149.26377626 BP _MWD+IFR+MS 671.02 11.95 358.76 583.76 666.56 38.90 61.51 61.04 -6.02 2.05 1.79 5.25 5970029.32 590778.28 N 70.32784849 W 149.26378494 BP _MWD+IFR+MS 762.85 14.96 3.10 673.06 755.86 54.31 82.87 82.38 -5.58 3.46 3.28 4.73 5970050.67 590778.45 N 70.32790680 W 149.26378141 BP _MWD+IFR+MS 854.69 16.76 4.20 761.40 844.20 73.15 107.97 107.43 -3.97 1.99 1.96 1.20 5970075.73 590779.76 N 70.32797522 W 149.26376834 BP _MWD+IFR+MS 948.63 17.55 7.81 851.17 933.97 94.69 135.67 134.97 -1.05 1.41 0.84 3.84 5970103.30 590782.34 N 70.32805046 W 149.26374469 BP _MWD+IFR+MS 1041.12 19.73 17.12 938.82 1021.62 119.61 165.17 163.71 5.44 3.98 2.36 10.07 5970132.12 590788.49 N 70.32812899 W 149.26369204 BP _MWD+IFR+MS 1134.83 20.73 26.36 1026.77 1109.57 149.31 197.51 193.70 17.46 3.57 1.07 9.86 5970162.25 590800.15 N 70.32821091 W 149.26359454 BP _MWD+IFR+MS 1227.78 23.80 30.68 1112.78 1195.58 183.08 232.71 224.58 34.34 3.74 3.30 4.65 5970193.33 590816.65 N 70.32829527 W 149.26345766 BP _MWD+IFR+MS 1321.22 26.29 31.39 1197.43 1280.23 221.47 272.26 258.46 54.74 2.68 2.66 0.76 5970227.45 590836.64 N 70.32838784 W 149.26329222 BP MWD+IF_ 1413.60 27.70 31.72 1279.75 1362.55 262.25 314.19 294.19 76.69 1.53 1.53 0.36 5970263.44 590858.15 N 70.32848545 W 149.26311425 BP _MWD+IF 1507.44 30.30 33.86 1361.82 1444.62 306.72 359.68 332.41 101.35 2.98 2.77 2.28 5970301.95 590882.34 N 70.32858985 W 149.26291426 BP _MWD+IFR+MS 1598.27 32.13 36.03 1439.49 1522.29 353.06 406.75 370.97 128.33 2.36 2.01 2.39 5970340.83 590908.85 N 70.32869521 W 149.26269549 BP _MWD+IFR+MS 1692.08 33.90 38.07 1518.16 1600.96 403.68 457.85 411.75 159.14 2.23 1.89 2.17 5970381.97 590939.16 N 70.32880660 W 149.26244565 BP _MWD+IFR+MS 1785.97 32.95 38.77 1596.52 1679.32 455.05 509.57 452.27 191.27 1.09 -1.01 0.75 5970422.88 590970.80 N 70.32891730 W 149.26218504 BP _MWD+IFR+MS 1879.63 34.66 38.30 1674.34 1757.14 506.83 561.68 493.03 223.73 1.85 1.83 -0.50 5970464.03 591002.76 N 70.32902866 W 149.26192181 BP _MWD+IFR+MS 1972.29 37.05 38.02 1749.44 1832.24 560.71 615.95 535.71 257.26 2.59 2.58 -0.30 5970507.10 591035.77 N 70.32914524 W 149.26164990 BP _MWD+IFR+MS 2065.20 39.87 40.68 1822.19 1904.99 618.20 673.72 580.35 293.92 3.52 3.04 2.86 5970552.18 591071.88 N 70.32926720 W 149.26135258 BP _MWD+IFR+MS 2160.26 44.51 41.22 1892.60 1975.40 681.87 737.55 628.55 335.76 4.90 4.88 0.57 5970600.88 591113.13 N 70.32939886 W 149.26101325 BP _MWD+IFR+MS 2254.01 48.62 41.29 1957.04 2039.84 749.79 805.61 679.72 380.64 4.38 4.38 0.07 5970652.58 591157.39 N 70.32953864 W 149.26064925 BP _MWD+IFR+MS 2347.57 53.40 42.84 2015.89 2098.69 822.39 878.31 733.66 429.37 5.27 5.11 1.66 5970707.10 591205.45 N 70.32968601 W 149.26025406 BP _MWD+IFR+MS 2440.82 56.75 44.13 2069.27 2152.07 898.80 954.75 789.11 481.99 3.77 3.59 1.38 5970763.18 591257.39 N 70.32983749 W 149.25982731 BP _MWD+IFR+MS 2534.77 56.49 44.15 2120.96 2203.76 977.25 1033.20 845.41 536.62 0.28 -0.28 0.02 5970820.14 591311.34 N 70.32999129 W 149.25938420 BP _MWD+IFR+MS 2627.52 57.27 45.10 2171.64 2254.44 1054.92 1110.88 900.70 591.19 1.20 0.84 1.02 5970876.07 591365.23 N 70.33014230 W 149.25894162 BP _MWD+IFR+MS SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( do31 rt-546 ) Plan V-213 (S-W)\V-213\V-213PB1\V-213PB1 Generated 8/5/2004 12:42 PM Page 1 of 3 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easting Latitude Longitude Survey Tool Depth Section Departure Model (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (deg/loolt) (deg/1001t) (deg/1001t) (ltUS) (ltUS) 2720.65 57.15 44.89 2222.08 2304.88 1133.22 1189.17 956.06 646.55 0.23 -0.13 -0.23 5970932.09 591419.90 N 70.33029354 W 149.25849265 BP _MWD+IFR+MS 2813.90 57.93 44.92 2272.12 2354.92 1211.90 1267.85 1011.79 702.09 0.84 0.84 0.03 5970988.49 591474.76 N 70.33044577 W 149.25804215 BP _MWD+JFR+MS 2907.22 57.21 44.81 2322.17 2404.97 1290.66 1346.62 1067.62 757.66 0.78 -0.77 -0.12 5971044.98 591529.64 N 70.33059827 W 149.25759147 BP _MWD+IFR+MS 3001.17 56.93 44.70 2373.24 2456.04 1369.52 1425.48 1123.61 813.18 0.31 -0.30 -0.12 5971101.63 591584.48 N 70.33075124 W 149.25714115 BP _MWD+JFR+MS 3093.46 58.70 46.36 2422.40 2505.20 1447.61 1503.58 1178.32 868.92 2.45 1.92 1.80 5971157.00 591639.55 N 70.33090067 W 149.25668902 BP _MWD+IFR+MS 3187.31 58.23 44.83 2471.49 2554.29 1527.60 1583.57 1234.28 926.06 1.48 -0.50 -1.63 5971213.65 591696.01 N 70.33105354 W 149.25622550 BP _MWD+IFR+MS 3280.79 57.59 44.90 2521.15 2603.95 1606.79 1662.77 1290.42 981.93 0.69 -0.68 0.07 5971270.45 591751.19 N 70.33120687 W 149.25577233 BP _MWD+IFR+MS 3373.07 56.73 44.60 2571.19 2653.99 1684.32 1740.30 1345.48 1036.52 0.97 -0.93 -0.33 5971326.17 591805.10 N 70.33135728 W 149.25532957 BP _MWD+IFR+MS 3400.07 56.34 44.55 2586.08 2668.88 1706.85 1762.82 1361.52 1052.32 1.45 -1.44 -0.19 5971342.40 591820.71 N 70.33140110 W 149.25520134 BP _MWD+IFR+MS 3478.49 55.07 47.93 2630.27 2713.07 1771.60 1827.60 1406.33 1099.09 3.91 -1.62 4.31 5971387.76 591866.93 N 70.33152349 W 149.25482197 BP _MWD+IFR+MS 3571.96 57.25 46.62 2682.32 2765.12 1849.17 1905.23 1459.01 1156.11 2.61 2.33 -1.40 5971441.12 591923.30 N 70.33166738 W 149.25435945 BP _MWD+IFR+MS 3667.61 64.00 49.34 2729.22 2812.02 1932.35 1988.53 1514.71 1218.04 7.48 7.06 2.84 5971497.57 591984.54 N70.33181954 W149.25385715 BP_MWD+IF:¡ 3759.56 68.93 51.20 2765.93 2848.73 2016.26 2072.80 1568.56 1282.86 5.67 5.36 2.02 5971552.19 592048.70 N 70.33196661 W 149.25333129 BP _MWD+IF 3853.09 68.83 45.74 2799.65 2882.45 2103.30 2160.04 1626.37 1348.15 5.45 -0.11 -5.84 5971610.79 592113.27 N 70.33212453 W 149.25280171 BP _MWD+IF 3945.77 68.59 51.70 2833.33 2916.13 2189.43 2246.39 1683.32 1413.00 6.00 -0.26 6.43 5971668.50 592177.43 N 70.33228005 W 149.25227560 BP _MWD+IFR+MS 4040.94 68.07 49.39 2868.48 2951.28 2277.45 2334.83 1739.51 1481.29 2.32 -0.55 -2.43 5971725.52 592245.03 N 70.33243354 W 149.25172166 BP _MWD+IFR+MS 4133.52 67.61 49.59 2903.40 2986.20 2362.93 2420.57 1795.21 1546.48 0.54 -0.50 0.22 5971781.99 592309.53 N 70.33258566 W 149.25119283 BP _MWD+IFR+MS 4227.68 68.28 47.99 2938.76 3021.56 2450.00 2507.84 1852.70 1612.12 1.73 0.71 -1.70 5971840.27 592374.47 N 70.33274269 W 149.25066027 BP _MWD+IFR+MS 4320.04 67.00 43.11 2973.91 3056.71 2535.38 2593.25 1912.48 1673.08 5.08 -1.39 -5.28 5971900.78 592434.70 N 70.33290597 W 149.25016570 BP _MWD+IFR+MS 4413.66 65.77 49.37 3011.44 3094.24 2621.08 2679.01 1971.79 1734.98 6.27 -1.31 6.69 5971960.82 592495.87 N 70.33306795 W 149.24966354 BP _MWD+JFR+MS 4505.41 67.07 44.36 3048.16 3130.96 2705.09 2763.09 2029.27 1796.31 5.20 1.42 -5.46 5972019.03 592556.49 N 70.33322494 W 149.24916602 BP _MWD+IFR+MS 4598.55 69.07 45.34 3082.95 3165.75 2791.48 2849.48 2090.51 1857.24 2.36 2.15 1.05 5972081.01 592616.67 N 70.33339222 W 149.24867166 BP _MWD+IFR+MS 4692.42 69.16 47.89 3116.42 3199.22 2879.14 2937.19 2150.75 1920.97 2.54 0.10 2.72 5972142.01 592679.66 N 70.33355673 W 149.24815459 BP _MWD+JFR+MS 4785.84 68.66 46.55 3150.03 3232.83 2966.24 3024.35 2209.95 1984.95 1.44 -0.54 -1.43 5972201.97 592742.91 N 70.33371841 W 149.24763555 BP _MWD+IFR+MS 4877.48 68.09 46.58 3183.81 3266.61 3051.39 3109.54 2268.52 2046.81 0.62 -0.62 0.03 5972261.28 592804.05 N 70.33387837 W 149.24713365 BP _MWD+IFR+MS 4970.44 68.29 44.71 3218.35 3301.15 3137.69 3195.84 2328.85 2108.51 1.88 0.22 -2.01 5972322.35 592865.02 N 70.33404315 W 149.24663298 BP _MWD+IFR+MS 5064.81 68.35 40.50 3253.22 3336.02 3225.28 3283.53 2393.38 2167.86 4.15 0.06 -4.46 5972387.58 592923.57 N 70.33421939 W 149.24615144 BP _MWD+IFR+MS 5157.86 67.70 41.50 3288.04 3370.84 3311.36 3369.82 2458.50 2224.47 1.22 -0.70 1.07 5972453.38 592979.38 N 70.33439726 W 149.24569210 BP _MWD+IFR+MS 5250.79 67.61 46.64 3323.39 3406.19 3397.26 3455.76 2520.23 2284.22 5.12 -0.10 5.53 5972515.82 593038.38 N 70.33456585 W 149.24520723 BP _MWD+JFR+MS 5344.32 67.33 46.24 3359.23 3442.03 3483.63 3542.15 2579.77 2346.83 0.50 -0.30 -0.43 5972576.10 593100.26 N 70.33472843 W 149.24469926 BP _MWD+IFR+MS 5437.47 66.43 41.41 3395.83 3478.63 3569.24 3627.82 2641.54 2406.13 4.87 -0.97 -5.19 5972638.58 593158.81 N 70.33489714 W 149.24421801 BP _MWD+/FR+MS 5532.53 65.69 42.41 3434.40 3517.20 3656.00 3714.70 2706.20 2464.17 1.24 -0.78 1.05 5972703.93 593216.04 N 70.33507373 W 149.24374710 BP _MWD+IFR+MS 5625.98 65.29 46.32 3473.18 3555.98 3741.00 3799.72 2766.97 2523.60 3.83 -0.43 4.18 5972765.41 593274.74 N 70.33523971 W 149.24326480 BP _MWD+IF. 5719.06 65.82 44.92 3511.70 3594.50 3825.73 3884.45 2826.24 2584.16 1.48 0.57 -1.50 5972825.40 593334.57 N 70.33540156 W 149.24277339 BP MWD+IF 5812.99 65.40 45.08 3550.49 3633.29 3911.27 3970.00 2886.73 2644.65 0.47 -0.45 0.17 5972886.62 593394.32 N 70.33556675 W 149.24228251 BP _MWD+IFR 5906.70 66.44 43.34 3588.72 3671.52 3996.82 4055.55 2948.05 2704.30 2.03 1.11 -1.86 5972948.65 593453.21 N 70.33573423 W 149.24179845 BP _MWD+IFR+MS 6000.14 65.84 41.55 3626.52 3709.32 4082.18 4141.01 3011.11 2761.97 1.87 -0.64 -1.92 5973012.39 593510.11 N 70.33590643 W 149.24133043 BP _MWD+IFR+MS 6092.90 65.46 43.50 3664.77 3747.57 4166.60 4225.51 3073.38 2819.08 1.96 -0.41 2.10 5973075.35 593566.46 N 70.33607651 W 149.24086691 BP _MWD+IFR+MS 6186.34 64.34 42.75 3704.41 3787.21 4251.17 4310.13 3135.14 2876.93 1.40 -1.20 -0.80 5973137.80 593623.55 N 70.33624516 W 149.24039748 BP _MWD+IFR+MS 6280.65 64.75 42.96 3744.94 3827.74 4336.27 4395.28 3197.56 2934.85 0.48 0.43 0.22 5973200.91 593680.70 N 70.33641563 W 149.23992743 BP _MWD+IFR+MS 6374.05 66.19 44.20 3783.72 3866.52 4421.21 4480.25 3259.11 2993.42 1.96 1.54 1.33 5973263.16 593738.52 N 70.33658371 W 149.23945204 BP _MWD+IFR+MS 6467.93 66.60 42.39 3821.32 3904.12 4507.19 4566.27 3321.72 3052.41 1.82 0.44 -1.93 5973326.47 593796.74 N 70.33675469 W 149.23897330 BP _MWD+IFR+MS 6561.66 67.54 42.99 3857.83 3940.63 4593.44 4652.60 3385.17 3110.94 1.16 1.00 0.64 5973390.62 593854.50 N 70.33692796 W 149.23849825 BP _MWD+IFR+MS 6654.84 67.21 44.21 3893.68 3976.48 4679.42 4738.60 3447.45 3170.25 1.26 -0.35 1.31 5973453.61 593913.04 N 70.33709805 W 149.23801687 BP _MWD+IFR+MS 6747.17 66.68 41.37 3929.84 4012.64 4764.30 4823.56 3509.79 3227.96 2.89 -0.57 -3.08 5973516.63 593969.99 N 70.33726827 W 149.23754850 BP _MWD+IFR+MS 6841.35 66.47 42.34 3967.29 4050.09 4850.59 4909.98 3574.15 3285.62 0.97 -0.22 1.03 5973581.68 594026.86 N 70.33744404 W 149.23708048 BP _MWD+IFR+MS 6935.03 66.69 44.29 4004.52 4087.32 4936.51 4995.94 3636.69 3344.59 1.92 0.23 2.08 5973644.93 594085.06 N 70.33761483 W 149.23660186 BP _MWD+IFR+MS SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( do31 rt-546 ) Plan V-213 (S-W)\V-213\V-213PB1\V-213PB1 Generated 8/5/2004 12:42 PM Page 2 of 3 Comments Measured I Inclination I Azimuth I Sub·Sea 1VD I NO Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Eaating Latitude Longitude Survey Tool Depth Section Departure Model (It) (deg) (deg) (It) (It) (It) (It) (It) (It) ( degJ100 It) ( degl100 It) ( degl100 It) (ltUS) (flUS) 7028.81 66.23 40.47 4041.99 4124.79 5022.37 5081.91 3700.18 3402.53 3.77 -0.49 -4.07 5973709.11 594142.22 N 70.33778821 W 149.23613155 BP _MWD+IFR+MS 7121.52 65.29 44.76 4080.07 4162.87 5106.81 5166.43 3762.38 3459.74 4.34 -1.01 4.63 5973771.99 594198.67 N 70.33795806 W 149.23566718 BP _MWD+IFR+MS 7214.18 65.79 42.90 4118.44 4201.24 5191.13 5250.78 3823.23 3518.14 1.91 0.54 -2.01 5973833.53 594256.33 N 70.33812420 W 149.23519311 BP _MWD+IFR+MS 7307.20 65.78 44.65 4156.59 4239.39 5275.94 5335.61 3884.48 3576.83 1.72 -0.01 1.88 5973895.48 594314.27 N 70.33829147 W 149.23471673 BP _MWD+IFR+MS 7400.66 65.97 45.05 4194.79 4277.59 5361.24 5420.91 3944.95 3636.99 0.44 0.20 0.43 5973956.67 594373.68 N 70.33845659 W 149.23422844 BP _MWD+IFR+MS 7494.28 66.10 46.38 4232.82 4315.62 5446.78 5506.46 4004.68 3698.23 1.31 0.14 1.42 5974017.13 594434.19 N 70.33861969 W 149.23373134 BP _MWD+IFR+MS 7588.31 65.29 40.17 4271.55 4354.35 5532.38 5592.14 4067.02 3756.94 6.08 -0.86 -6.60 5974080.17 594492.14 N 70.33878992 W 149.23325470 BP _MWD+IFR+MS 7682.04 65.51 38.06 4310.58 4393.38 5617.15 5677.36 4133.14 3810.70 2.06 0.23 -2.25 5974146.93 594545.09 N 70.33897047 W 149.23281825 BP _MWD+IFR+MS 7775.93 65.14 41.80 4349.78 4432.58 5702.11 5762.67 4198.55 3865.45 3.64 -0.39 3.98 5974212.99 594599.04 N 70.33914909 W 149.23237381 BP _MWD+IFR+MS 7870.62 65.01 42.79 4389.69 4472.49 5787.88 5848.54 4262.07 3923.23 0.96 -0.14 1.05 5974277.20 594656.05 N 70.33932253 W 149.23190470 BP _MWD+IFR+MS 7962.57 64.57 42.68 4428.85 4511.65 5871.01 5931.73 4323.17 3979.69 0.49 -0.48 -0.12 5974338.98 594711.75 N 70.33948938 W 149.23144639 BP _MWD+IFR+MS 8057.75 64.82 40.59 4469.54 4552.34 5956.90 6017.78 4387.48 4036.85 2.00 0.26 -2.20 5974403.96 594768.13 N 70.33966498 W 149.23098231 BP _MWD+IFR+MS 8151.18 64.40 42.27 4509.60 4592.40 6041.14 6102.18 4450.76 4092.70 1.69 -0.45 1.80 5974467.91 594823.20 N 70.33983778 W 149.23052890 BP MWD+IFR+MS 8244.71 63.49 41.76 4550.69 4633.49 6125.05 6186.21 4513.19 4148.94 1.09 -0.97 -0.55 5974531.01 594878.67 N 70.34000823 W 149.23007230 BP ~MWD+IFe 8337.24 63.16 39.95 4592.23 4675.03 6207.51 6268.89 4575.72 4203.02 1.78 -0.36 -1.96 5974594.18 594931 .99 N 70.34017899 W 149.22963319 BP _MWD+IFR+MS 8431.77 62.41 39.98 4635.46 4718.26 6291.25 6352.95 4640.15 4257.02 0.79 -0.79 0.03 5974659.26 594985.20 N 70.34035492 W 149.22919477 BP _MWD+IFR+MS 8525.06 62.20 43.32 4678.83 4761.63 6373.69 6435.55 4701.86 4311.90 3.18 -0.23 3.58 5974721.62 595039.33 N 70.34052342 W 149.22874917 BP _MWD+IFR+MS 8616.32 62.02 41.86 4721.52 4804.32 6454.28 6516.21 4761.24 4366.49 1.43 -0.20 -1.60 5974781.65 595093.19 N 70.34068556 W 149.22830598 BP _MWD+IFR+MS 8711.13 62.03 41.86 4765.99 4848.79 6537.88 6599.94 4823.60 4422.36 0.01 0.01 0.00 5974844.68 595148.30 N 70.34085583 W 149.22785230 BP _MWD+IFR+MS 8804.14 62.02 40.22 4809.62 4892.42 6619.83 6682.08 4885.56 4476.29 1.56 -0.01 -1.76 5974907.27 595201.47 N 70.34102499 W 149.22741440 BP _MWD+IFR+MS 8899.73 61.44 41.11 4854.90 4937.70 6703.77 6766.27 4949.42 4531.15 1.02 -0.61 0.93 5974971.79 595255.55 N 70.34119936 W 149.22696895 BP _MWD+IFR+MS 8990.53 61.06 41.84 4898.57 4981.37 6783.23 6845.87 5009.06 4583.87 0.82 -0.42 0.80 5975032.06 595307.54 N 70.34136222 W 149.22654086 BP _MWD+IFR+MS 9083.70 60.83 41.71 4943.82 5026.62 6864.54 6927.32 5069.80 4638.13 0.28 -0.25 -0.14 5975093.45 595361.05 N 70.34152806 W 149.22610027 BP _MWD+IFR+MS Last MWD+IFR+MS 9139.47 60.65 40.66 4971.08 5053.88 6913.09 6975.97 5106.42 4670.17 1.67 -0.32 -1.88 5975130.44 595392.64 N 70.34162804 W 149.22584012 BP _MWD+IFR+MS TD ( Projected) 9215.00 60.65 40.66 5008.10 5090.90 6978.73 7041.81 5156.36 4713.06 0.00 0.00 0.00 5975180.89 595434.93 N 70.34176440 W 149.22549178 BP _BLIND Survey Type: Definitive Survey NOTES: GYD GC MS - ( Gyrodata . gyro compassing m/s -- Older Gyrodata gyro multlshots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multlshot Into open hole" model. ) MWD + IFR + MS - ( In-field referenced MWD with mult-statlon analysis and correction applied In post-processing.) Leaal Description: Northlna IYJ IftUSl Eastlna IX) IftUSl Suñace : 4718 FSL 1517 FEL S11 T11N R11E UM 5969968.37 590785.03 BHL: 4593 FSL 2080 FEL S1 T11 N R11 E UM 5975180.89 595434.93 e SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) Plan V-213 (S-W)\V-213\V-213PB1\V-213PB1 Generated 8/5/2004 12:42 PM Page 3 of 3 e TREE = 4-1/16" CIW WELLHE'AD= FMC ACTU/\ Tö-íf;;;~--- NA ï<B:"B..EV =82".8' SF. äEV =54.3; KOP";;;;" ....._~, "~'_M_M . . '-'3Õ~Ô' IVBx Angle = 59 @-3õ93' D3tum I\iD = D3tum TVD = SS I 9-5/8" CSG, 40#. L-80, ID = 8.835" H 3442' I Minimum ID = 2.813" @ 6534' I 3-1/2" H ES X NIP PLE 14-1/2" mG, 12.6#, L-80, .0152 bpf, D =3.958" H 6468' 13-1/2" mGCENfRALIZERW/RA MARKER H 6632' Note: SIZE 4 -1/2" 4-1/2" 4-1/2" 4-1/2" PERFORATION SUrvTv1ARY Ra= LOG: SWS COR ON 07/22/04 A NGLE AT TOP ÆRF: 42 @ 6590' Refer to Production DB for historcal perf data SPF INfERV AL Opn/Sqz DA TE 5 6590 - 6635 0 07/24/04 5 6675 - 6710 0 07/24/04 5 6725 - 6750 0 07/24/04 5 6870 - 6945 0 07/24/04 13-112" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" H 6827' I PBTD H 7123' 1 7" CSG. 26#, L-80, 10 = 6.276" H 7205' OATE REV BY COMrvENfS 07/27/04 TAITLP ORIGINAL COMPLETION V -213 I----' z z 2( ::--f I t~ L -- ST 5 4 3 2 1 "\ I I l ~ I r . " ~ ~ I I ~ I I \ I [J ~ DATE REV BY COWMENfS e SAÆTYNOTES: GLM's @ STA #1-#4 ARE 3-1/2" X 1-1/2" MMG-Ws, WHICH ARE W A TERR.OOD MANDRB.S. 1025' H 9-518" TAM PORT COLLAR, 10 = 8.813# 3076' H 4-1/2" HES X NIP, ID = 3.813" 1 6003' MD 6347 6552 6613 6679 6739 6457' 6468' 6479' 6520' 6534' 6642' 6653' 6768' 6779' 6781' 6785' 6806' 6817' 6829' TVO 4326 4475 4519 4568 4613 1-17" MARKER.IT WI RA TAG 1 WATERFLOOO MANDRELS OE\! TYPE VL V LATCH 39 KBG-2 OCK BEK 39 MMG-W DllAY RK 39 MMG-W DllAY RK 38 MMG-W DllAY RK 38 MMG- W DllAY RK PORT DATE ? 07(26/04 07(26/04 07(26/04 07(26/04 07(26104 H4-1/2"HESXNIP, 10=3.813" 1 1-+-1/2" X 3-1(2" XC, 10 = 2.992" I H 7" X 3-1/2" BKR PRBIi1IER A<R, 10 =2.875" H7" MARKER.IT WI RA TAG 1 H3-1/2" HES X NIP, ID = 2.813" I H3-1/2"HESXNIP, 10=2.813" 1 H7" X 3-1/2" BKR PRBIi1IER A<R, 10 = 2.875" H3-1/2"HESXNIP, 10=2.813" I H3-1/2" X 4-1(2" XC, 10 = 2.930" 1 H7"X4-1/2"BKRS-3PKR,10=3.875" 1 H4-1/2"X 3-1(2" XC, 10 =2.930" I H3-1/2" HES X NIP, 10 = 2.813" 1 H3-1/2"HESXNIP, ID=2.813" I H3-1/2"WLEG, 10= 3.00" I ORION IJ'JIT WELL: V-213 ÆRMTNo: 2041160 API No: 50-029-23213-00 SEC11, T11N, R11E,4718'NSL& 1517'WEL BP Exploration (Alaska) SCHLUMBERGER Survey report 22-Jul-2004 09:20:28 Page 1 of 4 Client......... .... ......: BP EXPLORATION INC. Field. . . . . . . . . . . . . . . . . . . .: ORION Well. . . . . . . . . . . . . . . . . . . . .: V213i API number......... ......: 50-029-23213-00 Engineer.... .............: M. Perdomo COUNTY:... ......... ......: NORTH SLOPE BOROUGH STATE: . . . . . . . . . . . . . . . . . . .: ALASKA Spud date.." . . . . . . . . . . . . : Last survey date. ..... ...: Total accepted surveys. ..: MD of first survey....,..: MD of last survey........: 11-Jul-04 22-Jul-04 81 o . 00 ft 7225.00 ft . ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS. ...... ....: Mason & Taylor ----- Geomagnetic data ---------------------- Magnetic model... ..... ...: BGGM version 2003 Magnetic date....... .....: 16-Jul-2004 Magnetic field strength.,: 1151.43 HCNT Magnetic dec (+E/W-)... ..: 24.91 degrees Magnetic dip........ ,....: 80.82 degrees ----- Depth reference ----------------------- Permanent datum.... ......: MEAN SEA LEVEL Depth reference. ... ......: DRILLER'S PIPE TALLY GL above permanent.......: 56.30 ft KB above permanent. ......: N/A TOP DRIVE OF above permanent. ......: 82.80 ft ----- Vertical section origin---------------- Latitude (+N/S-) ... ......: 0.00 ft Departure (+E/W-).. ......: 0.00 ft ----- MWD survey Reference Criteria --------- Reference G... ...... ... ..: 1002.68 mGal Reference H. ........ .....: 1151.43 HCNT Reference Dip.... ...... ..: 80.82 degrees Tolerance of G...........: (+/-) 2.50 mGal Tolerance of H...........: (+/-) 6.00 HCNT Tolerance of Dip.........: (+/-) 0.45 degrees ----- Platform reference point--------------- Latitude (+N/S-)... ......: -999.25 ft Departure (+E/W-).. ......: -999.25 ft Azimuth from Vsect Origin to target: 45.00 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 24.91 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 24.91 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction . [(c)2004 IDEAL ID9_1A_41] ;A D ~t - I { fa SCHLUMBERGER Survey report 22-Jul-2004 09:20:28 Page 1 of 4 Client......... .... ......: BP EXPLORATION INC. Field. . . . . . . . . . . . . . . . . . . .: ORION Well. . . . . . . . . . . . . . . . . . . . .: V213i API number.... ...........: 50-029-23213-00 Engineer........... ......: M. Perdomo COUNTy:......... ... ......: NORTH SLOPE BOROUGH STATE: . . . . . . . . . . . . . . . . . . .: ALASKA Spud date. . . . . . . . . . . . . . . . : Last survey date..... ....: Total accepted surveys...: MD of first survey.... ...: MD of last survey........: ll-Jul-04 22-Jul-04 81 0.00 ft 7225.00 ft . ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...... '" ..: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: MEAN SEA LEVEL Depth reference.... ......: DRILLER'S PIPE TALLY GL above permanent. .... ..: 56.30 ft KB above permanent.. .....: N/A TOP DRIVE OF above permanent.. ... ..: 82.80 ft ----- Geomagnetic data ---------------------- Magnetic model... ........: BGGM version 2003 Magnetic date.. ..........: 16-Jul-2004 Magnetic field strength..: 1151.43 HCNT Magnetic dec (+E/W-)... ..: 24.91 degrees Magnetic dip..... ...... ..: 80.82 degrees ----- Vertical section origin---------------- Latitude (+N/S-) .........: 0.00 ft Departure (+E/W-).. ......: 0.00 ft ----- MWD survey Reference Criteria --------- Reference G.. ..... .......:. 1002.68 mGal Reference H..... .... .., ..: 1151.43 HCNT Reference Dip.... ...... ..: 80.82 degrees Tolerance of G...........: (+/-) 2.50 mGal Tolerance of H...........: (+/-) 6.00 HCNT Tolerance of Dip.. .... ...: (+/-) 0.45 degrees Azimuth from Vsect Origin to target: 45.00 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) ... ..: 24.91 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 24.91 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction . ----- Platform reference point--------------- Latitude (+N/S-) .........: -999.25 ft Departure (+E/W-) ... .....: -999.25 ft [(c)2004 IDEAL ID9_1A_41] SCHLUMBERGER Survey Report 22-Jul-2004 09:20:28 Page 2 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.28 17.61 100.00 100.00 0.22 0.23 0.07 0.24 17.61 0.28 GYR None 3 200.00 1. 71 1. 08 100.00 199.98 1. 51 1. 96 0.18 1. 97 5.14 1. 44 GYR None 4 300.00 4.11 0.61 100.00 299.85 5.14 7.03 0.24 7.04 1. 97 2.40 GYR None 5 400.00 6.82 350.24 100.00 399.38 11.13 16.47 -0.73 16.49 357.47 2.87 GYR None 6 500.00 9.08 347.65 100.00 498.42 18.82 30.03 -3.42 30.23 353.50 2.29 GYR None. 7 540.00 9.85 355.96 40.00 537.87 22.76 36.53 -4.34 36.79 353.23 3.92 MWD IFR MS None 8 579.35 10.31 353.95 39.35 576.62 27.18 43.39 -4.95 43.67 353.50 1. 47 MWD IFR MS None - 9 671.02 11. 95 358.76 91. 67 666.56 38.90 61. 04 -6.02 61. 33 354.37 2.05 MWD IFR MS None 10 762.85 14.96 3.10 91. 83 755.86 54.31 82.38 -5.58 82.57 356.13 3.46 MWD IFR MS None 11 854.69 16.76 4.20 91. 84 844.20 73.15 107.43 -3.97 107.50 357.88 1. 99 MWD IFR MS None - 12 948.63 17.55 7.81 93.94 933.97 94.69 134.97 -1. 05 134.97 359.55 1. 41 MWD IFR MS None 13 1041.12 19.73 17.12 92.49 1021. 62 119.61 163.71 5.44 163.80 1. 90 3.98 MWD IFR MS None 14 1134.83 20.73 26.36 93.71 1109.57 149.31 193.70 17.46 194.48 5.15 3.57 MWD IFR MS None - 15 1227.78 23.80 30.68 92.95 1195.58 183.08 224.58 34.34 227.19 8.69 3.74 MWD IFR MS None 16 1321.22 26.29 31. 39 93.44 1280.23 221. 47 258.46 54.74 264.20 11.96 2.68 MWD IFR MS None - 17 1413.60 27.70 31.72 92.38 1362.55 262.25 294.19 76.69 304.02 14.61 1. 53 MWD IFR MS None - 18 1507.44 30.30 33.86 93.84 1444.62 306.72 332.41 101. 35 347.52 16.96 2.98 MWD IFR MS None 19 1598.27 32.13 36.03 90.83 1522.29 353.06 370.97 128.33 392.54 19.08 2.36 MWD IFR MS None 20 1692.08 33.90 38.07 93.81 1600.96 403.68 411. 75 159.14 441.43 21.13 2.23 MWD IFR MS None 21 1785.97 32.95 38.77 93.89 1679.32 455.05 452.27 191.27 491. 05 22.92 1. 09 MWD IFR MS None . - 22 1879.63 34.66 38.30 93.66 1757.14 506.83 493.03 223.73 541.42 24.41 1. 85 MWD IFR MS None - 23 1972.29 37.05 38.02 92.66 1832.24 560.71 535.71 257.26 594.28 25.65 2.59 MWD IFR MS None - 24 2065.20 39.87 40.68 92.91 1904.99 618.20 580.35 293.92 650.54 26.86 3.52 MWD IFR MS None - 25 2160.26 44.51 41. 22 95.06 1975.40 681. 87 628.55 335.76 712.61 28.11 4.90 MWD IFR MS None 26 2254.01 48.62 41.29 93.75 2039.84 749.79 679.72 380.64 779.04 29.25 4.38 MWD IFR MS None 27 2347.57 53.40 42.84 93.56 2098.69 822.39 733.66 429.37 850.07 30.34 5.27 MWD IFR MS None 28 2440.82 56.75 44.13 93.25 2152.07 898.80 789.11 481.99 924.67 31. 42 3.77 MWD IFR MS None - 29 2534.77 56.49 44.15 93.95 2203.76 977.25 845.41 536.62 1001. 34 32.41 0.28 MWD IFR MS None - 30 2627.52 57.27 45.10 92.75 2254.44 1054.92 900.70 591.19 1077.39 33.28 1. 20 MWD IFR MS None [(c)2004 IDEAL ID9_1A_41] SCHLUMBERGER Survey Report 18-Jul-2004 04:10:55 Page 3 of 4 -------- -~---- ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2720.65 57.15 44.89 93.13 2304.88 1133.22 956.06 646.55 1154.16 34.07 0.23 MWD IFR MS None 32 2813.90 57.93 44.92 93.25 2354.92 1211. 90 1011.79 702.09 1231. 52 34.76 0.84 MWD IFR MS None 33 2907.22 57.21 44.81 93.32 2404.97 1290.66 1067.62 757.66 1309.14 35.36 0.78 MWD IFR MS None 34 3001. 17 56.93 44.70 93.95 2456.04 1369.52 1123.61 813 .18 1387.00 35.89 0.31 MWD IFR MS None 35 3093.46 58.70 46.36 92.29 2505.20 1447.61 1178.32 868.92 1464.05 36.41 2.45 MWD IFR MS None 36 3187.31 58.23 44.83 93.85 2554.29 1527.60 1234.28 926.06 1543.06 36.88 1. 48 MWD IFR MS None. 37 3280.79 57.59 44.90 93.48 2603.95 1606.79 1290.42 981. 93 1621.53 37.27 0.69 MWD IFR MS None 38 3373.07 56.73 44.60 92.28 2653.99 1684.32 1345.48 1036.52 1698.43 37.61 0.97 MWD IFR MS None 39 3400.07 56.34 44.55 27.00 2668.88 1706.85 1361.52 1052.32 1720.79 37.70 1. 45 MWD IFR MS None 41 3573.07 54.72 45.88 94.58 2767.47 1848.93 1459.19 1155.59 1861.35 38.38 1. 81 MWD IFR MS None 42 3667.15 52.70 45.42 94.08 2823.15 1924.75 1512.19 1209.82 1936.59 38.66 2.18 MWD IFR MS None 43 3760.91 52.47 45.17 93.76 2880.12 1999.22 1564.58 1262.75 2010.58 38.91 0.32 MWD IFR MS None 44 3854.07 53.37 44.75 93.16 2936.28 2073.54 1617.17 1315.26 2084.50 39.12 1. 03 MWD IFR MS None 45 3946.82 55.84 44.71 92.75 2990.00 2149.14 1670.88 1368.47 2159.75 39.32 2.66 MWD IFR MS None 46 4039.61 56.82 44.15 92.79 3041.45 2226.36 1726.02 1422.52 2236.68 39.49 1.17 MWD IFR MS None 47 4133.58 57.64 44.36 93.97 3092.31 2305.37 1782.62 1477.66 2315.43 39.66 0.89 MWD IFR MS None 48 4227.02 57.09 42.27 93.44 3142.70 2384.01 1839.86 1531. 64 2393.95 39.78 1. 97 MWD IFR MS None 49 4319.05 56.46 41.67 92.03 3193.13 2460.89 1897.10 1583.13 2470.88 39.84 0.88 MWD IFR MS None 50 4412.85 55.62 40.27 93.80 3245.53 2538.50 1955.83 1634.14 2548.67 39.88 1. 53 MWD IFR MS None 51 4505.33 55.95 40.33 92.48 3297.53 2614.71 2014.16 1683.60 2625.14 39.89 0.36 MWD IFR MS None . 52 4598.93 56.27 40.98 93.60 3349.72 2692.19 2073.10 1734.22 2702.83 39.91 0.67 MWD IFR MS None 53 4692.46 57.75 41.82 93.53 3400.65 2770.48 2131. 94 1786.10 2781.25 39.96 1. 75 MWD IFR MS None 54 4785.68 57.59 42.03 93.22 3450.50 2849.13 2190.55 1838.73 2859.97 40.01 0.26 MWD IFR MS None 55 4878.58 57.55 41. 90 92.90 3500.32 2927.44 2248.85 1891.17 2938.34 40.06 0.13 MWD IFR MS None 56 4971.36 57.96 41.23 92.78 3549.82 3005.77 2307.57 1943.23 3016.79 40.10 0.75 MWD IFR MS None 57 5066.03 59.51 39.59 94.67 3598.96 3086.42 2369.18 1995.67 3097.70 40.11 2.21 MWD IFR MS None 58 5158.99 59.11 38.63 92.96 3646.40 3165.94 2431.21 2046.10 3177.63 40.08 0.99 MWD IFR MS None 59 5251.20 59.00 39.10 92.21 3693.82 3244.57 2492.79 2095.73 3256.69 40.05 0.45 MWD IFR MS None 60 5345.05 57.97 39.03 93.85 3742.88 3324.15 2554.91 2146.15 3336.69 40.03 1.10 MWD IFR MS None ((c)2004 IDEAL ID9_1A_41] SCHLUMBERGER Survey Report 22-Jul-2004 09:20:28 Page 4 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (it) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5438.95 56.94 39.96 93.90 3793.39 3402.93 2615.99 2196.49 3415.84 40.02 1. 38 MWD IFR MS None - 62 5532.58 56.81 40.29 93.63 3844.56 3481.06 2675.95 2247.02 3494.25 40.02 0.33 MWD IFR MS None - 63 5625.77 56.77 40.36 93.19 3895.60 3558.77 2735.39 2297.47 3572.22 40.03 0.08 MWD IFR MS None - 64 5720.10 56.84 40.97 94.33 3947.24 3637.48 2795.26 2348.91 3651.15 40.04 0.55 MWD IFR MS None - 65 5812.17 56.26 42.27 92.07 3997.99 3714.17 2852.69 2399.93 3727.94 40.07 1. 34 MWD IFR MS None 66 5906.42 56.40 43.21 94.25 4050.25 3792.54 2910.30 2453.17 3806.29 40.13 0.84 MWD IFR MS None . - 67 5999.62 54.56 42.84 93.20 4103.06 3869.28 2966.43 2505.56 3882.98 40.19 2.00 MWD IFR MS None - 68 6093.39 52.35 44.06 93.77 4158.90 3944.58 3021.13 2557.36 3958.19 40.25 2.58 MWD IFR MS None - 69 6187.79 49.70 41.79 94.40 4218.27 4017.91 3074.84 2607.35 4031.48 40.30 3.37 MWD IFR MS None - 70 6281.21 47.04 39.97 93.42 4280.33 4087.54 3127.61 2653.05 4101.29 40.31 3.20 MWD IFR MS None - 71 6373.57 44.38 39.35 92.36 4344.82 4153.36 3178.49 2695.25 4167.40 40.30 2.92 MWD IFR MS None - 72 6467.00 43.38 39.14 93.43 4412.16 4217.80 3228.65 2736.22 4232.15 40.28 1. 08 MWD IFR MS None - - 73 6560.75 42.69 39.02 93.75 4480.68 4281. 44 3278.31 2776.56 4296.11 40.26 0.74 MWD IFR MS None - 74 6655.44 42.26 38.48 94.69 4550.52 4345.00 3328.17 2816.58 4360.03 40.24 0.60 MWD IFR MS None - 75 6748.25 42.04 38.19 92.81 4619.33 4406.86 3377.03 2855.21 4422.28 40.21 0.32 MWD IFR MS None - 76 6841.15 41.38 38.42 92.90 4688.69 4468.25 3425.53 2893.52 4484.06 40.19 0.73 MWO IFR MS None - 77 6934.11 40.28 38.20 92.96 4759.02 4528.61 3473.22 2931.20 4544.80 40.16 1.19 MWO IFR MS None - 78 7028.50 39.28 38.25 94.39 4831. 56 4588.58 3520.67 2968.57 4605.16 40.14 1. 06 MWO IFR MS None - 79 7121.63 38.56 37.52 93.13 4904.02 4646.64 3566.84 3004.50 4663.62 40.11 0.92 MWD IFR MS None - 80 7151.33 38.42 37.54 29.70 4927.26 4664.97 3581.50 3015.76 4682.09 40.10 0.47 MWD IFR MS None 81 7225.00 38.42 37.54 73.67 4984.98 4710.36 3617.80 3043.65 4727.82 40.07 0.00 Projection to TO. [(c)2004 IDEAL I09_1A_41] SCHLUMBERGER Survey report Client............ ..... ..: BP Exploratin (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: V-213PB1 API number.......... .....: 50-02-23213~ Engineer....... ..... .....: Vasiliy Ageyev RIG: . . . . . . . . . . . . . . . . . . . . .: NABORS 9ES STATE:............. ... ...: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... ........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum....... ...: MEAN SEA LEVEL Depth reference.... .... ..: Driller's Pipe Tally GL above permanent.......: 54.30 ft KB above permanent.. ... ..: N/A - TopDrive OF above permanent.......: 82.80 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) ... ......: -999.25 ft Departure (+E/W-)..... ...: -999.25 ft Azimuth from rotary table to target: 45.00 degrees [(c)2004 IDEAL 108 1C_02] 19-Jul-2004 03:26:39 Spud da t e. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey... .....: Page 1 of 5 11-Jul-04 19-Jul-04 102 0.00 ft 9215.00 ft . ----- Geomagnetic data ---------------------- Magnetic model....... ....: BGGM version 2003 Magnetic date.......... ..: 11-Jul-2004 Magnetic field strength..: 1151.43 HCNT Magnetic dec (+E/W-). ....: 24.92 degrees Magnetic dip..... ... .....: 80.82 degrees ----- MWD survey Reference Reference G..............: Reference H...... ........: Reference Dip............: Tolerance of G......... ..: Tolerance of H......... ..: Tolerance of Dip.... .....: Criteria --------- 1002.68 mGal 1151.43 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.92 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.92 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction . ~.ov(- ((\0 SCHLUMBERGER Survey Report 19-Jul-2004 03:26:39 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) lOaf) type (deg) -------- ------ ------- ------ -------- -------- ----------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- ---------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.28 17.61 100.00 100.00 0.22 0.23 0.07 0.24 17.61 0.28 GYR None 3 200.00 1.71 1. 08 100.00 199.98 1. 51 1. 96 0.18 1. 97 5.14 1. 44 GYR None 4 300.00 4.11 0.61 100.00 299.85 5.14 7.03 0.24 7.04 1. 97 2.40 GYR None 5 400.00 6.82 350.24 100.00 399.38 11.13 16.47 -0.73 16.49 357.47 2.87 GYR None 6 500.00 9.08 347.65 100.00 498.42 18.82 30.03 -3.42 30.23 353.50 2.29 GYR None 7 540.00 9.85 355.96 40.00 537.87 22.76 36.53 -4.34 36.79 353.23 3.92 MWD IFR MS None . 8 579.35 10.31 353.95 39.35 576.62 27.18 43.39 -4.95 43.67 353.50 1. 47 MWD IFR MS None 9 671. 02 11.95 358.76 91. 67 666.56 38.90 61. 04 -6.02 61.33 354.37 2.05 MWD IFR MS None 10 762.85 14.96 3.10 91. 83 755.86 54.31 82.38 -5.58 82.57 356.13 3.46 MWD IFR MS None 11 854.69 16.76 4.20 91.84 844.20 73.15 107.43 -3.97 107.50 357.88 1. 99 MWD IFR MS None 12 948.63 17.55 7.81 93.94 933.97 94.69 134.97 -1. 05 134.97 359.55 1. 41 MWD IFR MS None 13 1041.12 19.73 17.12 92.49 1021. 62 119.61 163.71 5.44 163.80 1. 90 3.98 MWD IFR MS None - 14 1134.83 20.73 26.36 93.71 1109.57 149.31 193.70 17.46 194.48 5.15 3.57 MWD IFR MS None - 15 1227.78 23.80 30.68 92.95 1195.58 183.08 224.58 34.34 227.19 8.69 3.74 MWD IFR MS None 16 1321.22 26.29 31. 39 93.44 1280.23 221.47 258.46 54.74 264.20 11. 96 2.68 MWD IFR MS None - 17 1413.60 27.70 31.72 92.38 1362.55 262.25 294.19 76.69 304.02 14.61 1. 53 MWD IFR MS None 18 1507.44 30.30 33.86 93.84 1444.62 306.72 332.41 101. 35 347.52 16.96 2.98 MWD IFR MS None 19 1598.27 32.13 36.03 90.83 1522.29 353.06 370.97 128.33 392.54 19.08 2.36 MWD IFR MS None 20 1692.08 33.90 38.07 93.81 1600.96 403.68 411.75 159.14 441.43 21.13 2.23 MWD IFR MS None - 21 1785.97 32.95 38.77 93.89 1679.32 455.05 452.27 191.27 491.05 22.92 1. 09 MWD IFR MS None. - 22 1879.63 34.66 38.30 93.66 1757.14 506.83 493.03 223.73 541.42 24.41 1. 85 MWD IFR MS None - 23 1972.29 37.05 38.02 92.66 1832.24 560.71 535.71 257.26 594.28 25.65 2.59 MWD IFR MS None 24 2065.20 39.87 40.68 92.91 1904.99 618.20 580.35 293.92 650.54 26.86 3.52 MWD IFR MS None - 25 2160.26 44.51 41.22 95.06 1975.40 681. 87 628.55 335.76 712.61 28.11 4.90 MWD IFR MS None 26 2254.01 48.62 41.29 93.75 2039.84 749.79 679.72 380.64 779.04 29.25 4.38 MWD IFR MS None 27 2347.57 53.40 42.84 93.56 2098.69 822.39 733.66 429.37 850.07 30.34 5.27 MWD IFR MS None - 28 2440.82 56.75 44.13 93.25 2152.07 898.80 789.11 481.99 924.67 31. 42 3.77 MWD IFR MS None 29 2534.77 56.49 44.15 93.95 2203.76 977.25 845.41 536.62 1001.34 32.41 0.28 MWD IFR MS None 30 2627.52 57.27 45.10 92.75 2254.44 1054.92 900.70 591.19 1077.39 33.28 1. 20 MWD IFR MS None - [(c)2004 IDEAL ID9_1A_41] SCHLUMBERGER Survey Report 18-Jul-2004 04:10:55 Page 3 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2720.65 57.15 44.89 93.13 2304.88 1133.22 956.06 646.55 1154.16 34.07 0.23 MWD IFR MS None - - 32 2813.90 57.93 44.92 93.25 2354.92 1211. 90 1011.79 702.09 1231. 52 34.76 0.84 MWD IFR MS None 93.32 - - 33 2907.22 57.21 44.81 2404.97 1290.66 1067.62 757.66 1309.14 35.36 0.78 MWD IFR MS None - - 34 3001. 17 56.93 44.70 93.95 2456.04 1369.52 1123.61 813 .18 1387.00 35.89 0.31 MWD IFR MS None - - 35 3093.46 58.70 46.36 92.29 2505.20 1447.61 1178.32 868.92 1464.05 36.41 2.45 MWD IFR MS None 36 3187.31 58.23 44.83 93.85 2554.29 1527.60 1234.28 926.06 1543.06 36.88 1. 48 MWD IFR MS None - - 37 3280.79 57.59 44.90 93.48 2603.95 1606.79 1290.42 981. 93 1621. 53 37.27 0.69 MWD IFR MS None . 3373.07 56.73 44.60 92.28 2653.99 - - 38 1684.32 1345.48 1036.52 1698.43 37.61 0.97 MWD IFR MS None - - 39 3400.07 56.34 44.55 27.00 2668.88 1706.85 1361. 52 1052.32 1720.79 37.70 1. 45 MWD IFR MS None - - 40 3478.49 55.07 47.93 78.42 2713.07 1771. 60 1406.33 1099.09 1784.87 38.01 3.91 MWD IFR MS None 41 3571.96 57.25 46.62 93.47 2765.12 1849.17 1459.01 1156.11 1861.53 38.39 2.61 MWD IFR MS None 3667.61 - - 42 64.00 49.34 95.65 2812.02 1932.35 1514.71 1218.04 1943.70 38.80 7.48 MWD IFR MS None - - 43 3759.56 68.93 51. 20 91.95 2848.73 2016.26 1568.56 1282.86 2026.35 39.28 5.67 MWD IFR MS None - - 44 3853.09 68.83 45.74 93.53 2882.45 2103.30 1626.37 1348.15 2112.48 39.66 5.45 MWD IFR MS None - - 45 3945.77 68.59 51.70 92.68 2916.13 2189.43 1683.32 1413.00 2197.76 40.01 6.00 MWD IFR MS None 46 4040.94 68.07 49.39 95.17 2951.28 2277.45 1739.51 1481. 29 2284.76 40.42 2.32 MWD IFR MS None - - 47 4133.52 67.61 49.59 92.58 2986.20 2362.93 1795.21 1546.48 2369.46 40.74 0.54 MWD IFR MS None - - 48 4227.68 68.28 47.99 94.16 3021.56 2450.00 1852.70 1612.12 2455.90 41.03 1. 73 MWD IFR MS None - - 49 4320.04 67.00 43.11 92.36 3056.71 2535.38 1912.48 1673.08 2541.02 41.18 5.08 MWD IFR MS None - - 50 4413.66 65.77 49.37 93.62 3094.24 2621.08 1971. 79 1734.98 2626.42 41. 34 6.27 MWD IFR MS None 51 4505.41 67.07 44.36 91.75 3130.96 2705.09 2029.27 1796.31 2710.10 41.52 5.20 MWD IFR MS None. - - 52 4598.55 69.07 45.34 93.14 3165.75 2791.48 2090.51 1857.24 2796.35 41.62 2.36 MWD IFR MS None - - 53 4692.42 69.16 47.89 93.87 3199.22 2879.14 2150.75 1920.97 2883.72 41.77 2.54 MWD IFR MS None - - 54 4785.84 68.66 46.55 93.42 3232.83 2966.24 2209.95 1984.94 2970.50 41. 93 1. 44 MWD IFR MS None - 55 4877.48 68.09 46.58 91.64 3266.61 3051.39 2268.52 2046.81 3055.42 42.06 0.62 MWD IFR MS None 56 4970.44 68.29 44.71 92.96 3301.15 3137.69 2328.85 2108.51 3141. 56 42.16 1. 88 MWD IFR MS None - - 57 5064.81 68.35 40.50 94.37 3336.02 3225.28 2393.38 2167.86 3229.22 42.17 4.15 MWD IFR MS None - - 58 5157.86 67.70 41. 50 93.05 3370.84 3311.36 2458.50 2224.47 3315.49 42.14 1. 22 MWD IFR MS None - - 59 5250.79 67.61 46.64 92.93 3406.19 3397.26 2520.23 2284.22 3401. 36 42.19 5.12 MWD IFR MS None - - 60 5344.32 67.33 46.24 93.53 3442.03 3483.63 2579.77 2346.83 3487.52 42.29 0.50 MWD IFR MS None [(c)2004 IDEAL ID8_1C_02J SCHLUMBERGER Survey Report 19-Jul-2004 03:26:39 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5437.47 66.43 41. 41 93.15 3478.63 3569.24 2641.54 2406.13 3573.12 42.33 4.87 MWD IFR MS None 62 5532.53 65.69 42.41 95.06 3517.20 3656.00 2706.20 2464.17 3660.00 42.32 1. 24 MWD IFR MS None 63 5625.98 65.29 46.32 93.45 3555.98 3741. 00 2766.97 2523.60 3744.96 42.37 3.83 MWD IFR MS None 64 5719.06 65.82 44.92 93.08 3594.50 3825.73 2826.24 2584.16 3829.56 42.44 1. 48 MWD IFR MS None 65 5812.99 65.40 45.08 93.93 3633.29 3911.27 2886.73 2644.65 3915.02 42.49 0.47 MWD IFR MS None 66 5906.70 66.44 43.34 93.71 3671. 52 3996.82 2948.05 2704.30 4000.53 42.53 2.03 MWD IFR MS None 67 6000.14 65.84 41. 55 93.44 3709.32 4082.18 3011.10 2761.97 4085.98 42.53 1. 87 MWD IFR MS None . 68 6092.90 65.46 43.50 92.76 3747.57 4166.60 3073.38 2819.08 4170.48 42.53 1. 96 MWD IFR MS None 69 6186.34 64.34 42.75 93.44 3787.21 4251.17 3135.14 2876.93 4255.09 42.54 1. 40 MWD IFR MS None 70 6280.65 64.75 42.96 94.31 3827.74 4336.27 3197.56 2934.85 4340.25 42.55 0.48 MWD IFR MS None 71 6374.05 66.19 44.20 93.40 3866.52 4421.21 3259.11 2993.42 4425.20 42.57 1. 96 MWD IFR MS None 72 6467.93 66.60 42.39 93.88 3904.12 4507.19 3321.72 3052.41 4511. 21 42.58 1. 82 MWD IFR MS None 73 6561. 66 67.54 42.99 93.73 3940.63 4593.44 3385.17 3110.94 4597.53 42.58 1.16 MWD IFR MS None 74 6654.84 67.21 44.21 93.18 3976.48 4679.42 3447.45 3170.25 4683.53 42.60 1.26 MWD IFR MS None 75 6747.17 66.68 41.37 92.33 4012.64 4764.30 3509.79 3227.96 4768.47 42.60 2.89 MWD IFR MS None 76 6841.35 66.47 42.34 94.18 4050.09 4850.59 3574.15 3285.62 4854.88 42.59 0.97 MWD IFR MS None 77 6935.03 66.69 44.29 93.68 4087.32 4936.51 3636.69 3344.59 4940.83 42.60 1. 92 MWD IFR MS None 78 7028.81 66.23 40.47 93.78 4124.79 5022.37 3700.18 3402.53 5026.78 42.60 3.77 MWD IFR MS None 79 7121. 52 65.29 44.76 92.71 4162.87 5106.81 3762.38 3459.74 5111.29 42.60 4.34 MWD IFR MS None 80 7214 .18 65.79 42.90 92.66 4201.24 5191.13 3823.23 3518.14 5195.61 42.62 1. 91 MWD IFR MS None 81 7307.20 65.78 44.65 93.02 4239.39 5275.94 3884.48 3576.83 5280.43 42.64 1.72 MWD IFR MS None . 82 7400.66 65.97 45.05 93.46 4277.59 5361. 24 3944.95 3636.99 5365.66 42.67 0.44 MWD IFR MS None 83 7494.28 66.10 46.38 93.62 4315.62 5446.78 4004.68 3698.23 5451.09 42.72 1. 31 MWD IFR MS None 84 7588.31 65.29 40.17 94.03 4354.35 5532.38 4067.02 3756.94 5536.72 42.73 6.08 MWD IFR MS None 85 7682.04 65.51 38.06 93.73 4393.37 5617 .15 4133.14 3810.70 5621.77 42.68 2.06 MWD IFR MS None 86 7775.93 65.14 41.80 93.89 4432.58 5702.11 4198.55 3865.45 5706.97 42.63 3.64 MWD IFR MS None 87 7870.62 65.01 42.79 94.69 4472.49 5787.88 4262.07 3923.23 5792.84 42.63 0.96 MWD IFR MS None 88 7962.57 64.57 42.68 91. 95 4511.65 5871. 01 4323.17 3979.69 5876.03 42.63 0.49 MWD IFR MS None - - 89 8057.75 64.82 40.59 95.18 4552.34 5956.90 4387.48 4036.85 5962.06 42.62 2.00 MWD IFR MS None 90 8151.18 64.40 42.27 93.43 4592.40 6041.14 4450.76 4092.70 6046.44 42.60 1. 69 MWD IFR MS None [(c)2004 IDEAL ID8_1C_02] SCHLUMBERGER Survey Report 19-Jul-2004 03:26:39 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8244.71 63.49 41.76 93.53 4633.48 6125.05 4513.19 4148.94 6130.46 42.59 1. 09 MWD IFR MS None 92 8337.24 63.16 39.95 92.53 4675.03 6207.51 4575.72 4203.02 6213.10 42.57 1. 78 MWD IFR MS None - 93 8431.77 62.41 39.98 94.53 4718.26 6291. 25 4640.15 4257.02 6297.08 42.53 0.79 MWD IFR MS None 94 8525.06 62.20 43.32 93.29 4761.63 6373.69 4701.86 4311.90 6379.65 42.52 3.18 MWD IFR MS None - 95 8616.32 62.02 41. 86 91.26 4804.32 6454.28 4761.24 4366.49 6460.31 42.52 1. 43 MWD IFR MS None 96 8711.13 62.03 41. 86 94.81 4848.79 6537.88 4823.60 4422.36 6544.04 42.52 0.01 MWD IFR MS None - . 97 8804.14 62.02 40.22 93.01 4892.42 6619.83 4885.56 4476.29 6626.15 42.50 1. 56 MWD IFR MS None - 98 8899.73 61.44 41.11 95.59 4937.70 6703.77 4949.42 4531.15 6710.29 42.47 1. 02 MWD IFR MS None - 99 8990.53 61.06 41.84 90.80 4981. 37 6783.23 5009.06 4583.87 6789.89 42.46 0.82 MWD IFR MS None 100 9083.70 60.83 41.71 93.17 5026.62 6864.54 5069.80 4638.13 6871.33 42.45 0.28 MWD IFR MS None 101 9139.47 60.65 40.66 55.77 5053.88 6913.09 5106.42 4670.17 6919.97 42.45 1. 67 MWD IFR MS None - - 102 9215.00 60.77 40.66 75.53 5090.83 6978.77 5156.39 4713.09 6985.81 42.43 0.16 Projection to TD [(c)2004 IDEAL ID8_1C_02J . . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Robin Deason Well No V-213 Date Dispatched: LI Installation/Rig Nabors 9ES Dispatched By: N.Rose Data No Of Prints No of Floppies Surveys 2 Received By: tJJJ óJJJ (j /).~ ~.v\ Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907 -564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery Vl.l, 10-02-03 Schlumberger Private :J. (j cl-J/~ l~((~ . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Robin Deason Well No V-213 PB1 J., ~.... - u ~ Date Dispatched: 20-J u 1-04 Installation/Rig Nabors 9ES Dispatched By: N. Rose Data No Of Prints No of Floppies Surveys ,/ 2 Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99503 nrose1@slb.com Fax: 907-561-8417 LWD Log Delivery V 1.1 , 10-02-03 Schlumberger Private ;;:;' ¿ ( q¿ '1 ~ . (ill . rN '-, LJ~_:::J FRANK H. MURKOWSKI, GOVERNOR A I,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-213i BP Exploration (Alaska) Inc. Permit No: 204-116 Surface Location: 4718'NSL, 1517' WEL, SEe. 11, TIIN, RIlE (As Staked) Bottomhole Location: 2983' NSL, 1525' EWL, SEe. 01, TIIN, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced service well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (PBU V-213i plus PH) and API number (50-029-2328-70) from records, data and logs acquired for well PBU V-213i. In accordance with 20 AAC 25.005(f), all records permit to drill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 65 60 (pager). BY ORDER.QF THE COMMISSION DA TED thi~ day of June, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. B Drill 0 Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4718' NSL, 1517' WEL, SEC. 11, T11N, R11E (As Staked) Top of Productive Horizon: 2760' NSL, 1326' EWL, SEC. 01, T11N, R11E, UM Total Depth: 2983' NSL, 1525' EWL, SEC. 01, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590785 y- 5969968 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 3716 feet Maximum Hole Angle: 57 . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 UN 2 ZD04 rb. Current Well claö Stratigraphic Test ~ ~~~?~tOry 8 =~=}~:W¡:8~W~,~~~s" 5. Bond: II Blanket 0 Single Well 11. Well NameiindNíJmber: Bond No. 2S100302630-277 PBU V-213i / 6. Proposed Depth: 12. Field / Pool(s): MD 7176 TVD 4915 Prudhoe Bay Field I Orion ...../ 7. Property Designation: Schrader Bluff ADL 028240 \lJ6 A- "/2.71 ¿COt 8. Land Use Permit: 13. Approximate ~D1e: J~04 14. Distance to'"f.fearest Property: 12,860' 9. Acres in Property: 2560 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 82.8 feet V-106 is 1945' away at 6694' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 2167 Surface: 1676 ~ Hole 48" 12-1/4" 8-314" Casing 20" x 34" 9-5/8" Weight 215.5# 40# 26# Grade A53 L-80 L-80 Coupling Welded BTC BTC-M Length 80' 3570' 7176' . MD 34' 34' 34' TVD 34' 34' 34' MD 114' 3570' 7176' TVD 114' 2748' 4915' (including stage data) 260 sx Arctic Set (Approx.) 560 sx Arcticset Lite, 348 sx 'G' 278 sx Class 'G' ........ / 7" 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): Depth TVD Junk (measured): Structural . Conductor Surface Intermediate Production Liner 20. Attachments II Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IperfOration Depth TVD (ft): II Drilling Program 0 Time vs Depth Plot o Seabed Report II Drilling Fluid Program o Shallow Hazard Analysis II 20 MC 25.050 Requirements Date: Contact Thomas Schaefer, 564-4685 Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Lo I Crane Title Senior Drilling Engineer Phone Permit Approvt'1 _ I iL Date: ? 13°/ D T Mud Log Required Directional Survey Required API Number: Number: ...2ð 9 - / /t:: 50- ð .2...9 - 2.. 3 2./3 Conditions of Approval: Samples Required D Yes ~o . . _HYdrogen Sulfide Me~sures DYes p No ]So PI:: tooo eSt, .O-SS Lh)(I\} See cover letter for other requirements DYes ~No .%--Yes D No A-lte-fl1-t\-te ßOPE reç/ (!veÕKet?Ll4[ /~ ~·-fprVVI!('. Date ?ÆtJ ~~ / ~~~'VD~lte APPROVED BY THE COMMISSION ORIGINAL · Well Plan Summary .r Prudhoe Bay Orion V·213i Permit I Type of Well (producer or injector): Surface Location: V-213i Polygon 2A Target (Pilot Hole) Top OA: V-213i Polygon 2A BHL (Pilot Hole): V-213i Polygon 2 Target 1 Top OA: V-213i Polygon 2 Target 2 Top OBe: V-213i Polygon 2 BHL: I USH Injector 4,719' FSL, 1,517' FEL, Sec. 11, T11N, R11E /' X = 590,785 Y = 5,969,968 3,954' FSL, 2,611' FWL, Sec. 1, T11 N, R11 E X = 594,855 Y = 5,974,535 Z = 4560' TVDss 4,464' FSL, 3,112' FWL, Sec. 1, T11 N, R11 E X = 595,349 Y = 5,975,051 Z = 5000' TVDss 2,760' FSL, 1,326' FWL, Sec. 1, T11 N, R11 E X = 593,585 Y = 5,973,325 Z = 4,455' TVDss 2,914' FSL, 1,463' FWL, Sec. 1, T11 N, R11 E X = 593,720 Y = 5,973,480 Z = 4,715' TVDss 2,983' FSL, 1,525' FWL, Sec. 1, T11 N, R11 E ,/ X = 593,781 Y = 5,973,550 Z = 4,833' TVDss I AFE Number: I 5M3555 I Rig: I Nabors 9ES r I Estimated Start Date: I Jul 7m 2004 /f I Operating days to complete: 118.4 Pilot MD 9,118' (Pilot) TVDrkb: TD 5,083' Max Inc. 67° KBE 82.80' Inj KOP 3,716' TVDrkb: TD 2,828' Inc. 57° KBE 82.80' Inj MD 7,176' TVDrkb: TD 4,915' Max Inc. 57° KBE 82.80' Well Design: USH Grassroots Schrader Injector with appraisal pilot hole. 4- W' X 3-%" TCII Completion. The 0 sands will have a 4-%" X 3-W' TCII Completion in the Schrader Bluff Current Well Information General V-213i PB1: Distance to Nearest Property: -11,365' at top OA to the nearest PBU property line Distance to Nearest Well in Pool: 2,750' from PB1 top of OA at 8,276' MD to V-103 top OA at 7,360' MD V-213i Mainbore: Distance to Nearest Property: -12,860' at top OA to the nearest PBU property line Distance to Nearest Well in Pool: 1,945' from V-213i top of OA at 6,694' MD to V-106 top OA at /' 6,315'MD API Number: Well Type: Current Status: BHP (PB1): BHP (Mainbore): BHT: 50-029- ????? Development - Orion Schrader Injector New well, 20" X 34" insulated conductor 2,098 psi @ 4,715' TVDss (8.6 ppg EMW). Normal pressure gradient. 2,137 psi @ 4,810' TVDss (8.6 ppg EMW). Normal pressure gradient. 100°F @ 4,833' TVDss estimated (from L-pad Temp Log) Final Mechanical Condition V-213i: Nabors 9ES: Conductor: . G.r Prudhoe Bay Orion V-213i Permit Cellar Box above MSL = 54.3' KB I MSL = 28.5' 20" X 34", 215.5 I bitt, A53 ERW set at 114' RKB % Mile Well bore Near Wellbore Mechanical Integrity Summary: There are no other wells within 14 mile ot this injector at its penetration at the Top OA structure. No Wellbore Near Wellbore integrity issues. Target Estimates Estimated Reserves: 1.135 MMBO Materials Needed - (use PES stock when possible) Surface Casing: Intermediate Casing: L-80 Completion: 3,570' 1 each 1 each 25 each 1 assembly 1 lot 9-%",40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12 14" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" casing pups 5',10',20'. 7,176' 1 each 75 each 2 lots 2 each 2 each 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8 14" Rigid Straight Blade Centralizers 7" casing pups 5', 10', 20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 4 112" 12.60 I bitt , L-80, TCII tubing 3112" 9.30 Ib/tt, L-80, TCII tubing Baker PRM Production Packer 7" X 3-%" Baker S-3 Production Packer 7" X 3-%" Halliburton 4-112" X-Nipple (3.813" ID) Halliburton 3-112" X-Nipple (2.813" ID) 11" X 4-112" FMC tubing hanger 4-1/16", 5m Cameron Tree 4-112" x 1" KBG-2 GLM 3- 112" x 1-112" MMG injection mandrels 3 112" RA Tag 6,700' 300' 2 each 1 each 2 each 6 each 1 each 1 each 1 each 4 each 1 each 2 e Grer Prudhoe Bay Orion V-213i Permit Surface and Anti-Collision Issues Surface Shut-in Wells: Nearby Wells Distance to Target Well Rig N9ES Wellhead Separati, V-1l5 14.80 -15.20 V-I00 15.22 -14.78 V-1l7 35.38 5.38 Separation of the target wellhead from nearest well is 14.80'. Surface close approach limit for Nabors 9ES is 30' separation from rig well center to wellhead. Smallest rig to wellhead separation is therefore -14.78'. V-115 & V- 100 will therefore require surface shut-in and wellhouse removal in order to move over well. V-117 should be evaluated before rig move as to whether it will require wellhouse removal and shut in for rig move. Close Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. / Well List: V-100 V-03 V-111 16.29-ft 41 .30-ft 67.27 399.00-ft 1218.87-ft 1166.16-ft 9.83-ft 19.17-ft 45.34-ft Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Survey and Logging Program 12-%" Hole Section: Surface Gyro will be needed (run to 1200' as conditions dictate) Open Hole: MWD I GR Cased hole: None MWD I GR 1 Res I Den I Neu I PWD (Den Neu recorded only) USIT Bond Log Mud Program Interval Pilot Hole 9,118' MD Mainbore 7,176' MD Density (ppg) ~ YP 23-30 23-30 I Spud - Freshwater Mud YP PH FL 50-70 8.5-9.0 NC-8.0 30-45 8.5-9.0 8.0 30-40 8.5-9.0 5.0-7.0 Freshwater Mud (LSND) PH: 9.0-9.5 <600 Chlorides PV API Filtrate MBT 12-18 4-6 < 20 12-18 4-6 < 20 121fi¡" Surface Hole Mud Properties: Interval Density (ppg) Initial 8.5 - 9.2 Base Perm - 9.5 Interval TD Funnel vis 250-300 200-250 200-250 3 - Ger Prudhoe Bay Orion V-213i Permit - Formation Markers (Based on Schlumberger WP4/P6) SV6 -895 987 977 412 8.8 No SV5 -1 565 1723 1648 720 8.8 No SV4 -1705 1901 1788 784 8.8 Poss. Gas Hydrates Base Permafrost -1705 1901 1788 784 8.8 No r·~ SV3 -2110 2552 2193 971 8.8 Poss. Gas Hydrates Fault 1 -2120 2571 2203 SV2 -2215 2745 2298 1019 8.8 Poss. Gas Hydrates SVl -2555 3368 2638 1175 8.8 Poss. Gas Hydrates UG4 -2875 3998 2958 1338 9.0 Thin coal UG4A -2915 4100 2998 1355 8.9 Heavy Oil betw 2920' and 3100' 55 UG3 -3325 5141 3408 1524 8.7 Thin coals/poss. Heavy oil -3850 6473 3933 1741 8.7 Heavy Oil betw 3945' UGl - 4000' 55 Top Schrader Bluff/Ma -4090 7083 4173 1840 8.7 Sand No-water Fault 2 -4095 7095 4178 Mbl -41 90 7337 4273 1881 8.7 No-water Mb2 -4265 7527 4348 1912 8.7 No-water Mc -4335 7705 4418 1941 8.7 No-water Na -4400 7870 4483 1968 8.7 No Nb -4425 7933 4508 1978 8.7 Yes Nc -4470 8047 4553 1997 8.7 Yes OA -4560 8276 4643 2034 8.7 Yes OBa -4260 8420 4703 2059 8.6 Yes OBb -4660 8508 4743 2075 8.6 Yes OBc -4715 8622 4798 2098 8.6 Yes OBd -4765 8718 4848 2119 8.6 Yes OBe -4815 8810 4898 2139 8.6 Yes OBf -4860 8889 4943 2158 8.6 Yes OBCBase 8965 4988 4652 2176 8.5 No T.D. -5000 9118 5083 InjectÎonfjeg UG4 -2870 3942 2953 1336 9.0 Thin Coal 9T -2908 4010 2991 1352 8.9 Heavy Oil betw 2915' UG4A and 3050' 55 UG3 -3285 4688 3368 1508 8.8 Thin coals/poss. Heavy oil UGl - Faulted Top -3810 5631 3893 1724 8.7 Poss. Heavy Oil Top Schrader Bluff/Ma -4055 6071 4138 1825 8.7 Sand No-water Mbl -41 00 6152 4183 1844 8.6 No-water Mb2 -4170 6278 4253 1873 8.6 No-water Mc -4235 6385 4318 1900 8.6 No-water Na -4300 6484 4383 1927 8.6 No Nb -4320 6513 4403 1935 8.6 Yes Nc -4360 6569 4443 1951 8.6 Yes OA -4450 6688 4533 1989 8.6 Yes OBa -451 5 6771 4598 2015 8.6 Yes OBb -4555 6822 4638 2032 8.6 Yes OBc -4610 6892 4638 2055 8.6 Yes OBd -4660 6956 4743 2075 8.6 Yes OBe - Base injection -4720 7032 4803 2100 8.6 interval Yes 4 · Grer Prudhoe Bay Orion V-213i Permit OBf OBCBase T.D. -4760 -481 0 -4833 7083 7147 7176 4843 4893 4915 2116 2137 8.6 8.5 Yes No CasingfTubing Program 48" 20" X 34" 215.5# A53 Welded 80' 34' I 34' 114' I 114' 12-%" 9-%" 40# L-80 BTC 5,750 3,090 3,570' 34' I 34' 3,570' 12,748' ~ 8-3,4" 7" 26# L-80 BTC-M 7,240 5,410 7,176' 34' I 34' 7,176' I 4,915' /' Tubing 4 Y2" 12.60# L-80 TCII 8,430 7,500 6,688' 34' I 34' 6,688' I 4,533' Tubing 3112" 9.30# L-80 TCII 10,160 10,530 268' 7,300' I 3,818' 6,956' I 4,743' Cement Calculations Casing Size I 9-%-in 40-lb/ft L-80 BTC - Single Stage - Basis I 250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost Total Cement Volume: Tam Port collar located at 1,000' (us as contingency only if losses while drilling) S..........p.......acer. 80b b IS~fV..sified.SPace..rweig.hted to 10.6.~ P. ud Push) Lead 427 bbls C sks) 10.7lb/gal ASL (G + adds) - . cuft/sk Tail 73 bbls <4 sks) 15.8 Ib/gal Class G + adds -. cuft/sk T ~'~p'TBHST;;; 68~·Ft;;~··T;~p'L;g:B·HCTî3Ô~·F;~ti~~t~d·byS~hl~~b;;g;;""....... In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Open Hole Abandonment Plug I 8 3,4" hole - 2 each 1,100' plugs volume for each listed below Basis 130% excess - TOC: 165' above Ma Top Ma: 7,083' MD) Total Cement Volume: Tail 106 bbls 15.8 G - 1.16 cuft/sk Temp BHST == 96° F from Temp Log, BHCT 80° F estimated by Schlumberger Casin~ Size 17" 26 Ib/ft L-80 BTC-M - Single Stage ~ Basis I 30% excess - TOC: 600' MD above the Ma sands (planned Top Ma: 6,071' MD) =>(5,4lfMD Total Cement Volume: Wash 20 bbls CW100 c-/ sPacer.....3........5...........b...bl~0.·co s .i.fie.ds.p..a. .c.e r.(M...U.dP USh..II~e..'W eigh t.ed to 10.3. P pg Tail 59 bbl 27 sks) 15.8 Ib/gal G + Gasblok 1.2 uft/sk Temp I BHST~"6~Ff;;~"T;~p'L;~: 'B'HCTâô~"""';st'i~~t;dbyS;hì~~b;;g;';'" 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,570' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (contingency only). c) This centralizer program is subject to change due to actual hole conditions. 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up 5 · G.r Prudhoe Bay Orion V-213i Permit to 5,471' MD (600' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. Bit Recommendations Surface Surface Interm. 12-%" 12-%" 8-% 0' - 1,901' 1,901' - 3,570' 3,570' - 9,118'/7,176' Hughes MXC-1 Hughes MXC-1 Hycalog DS70NPV 18/18/18/16 18/18/18/16 6x14 Motors and Required Doglegs 3&4 9-%" Anadrill A962M3445 Mud Motor, ASH with 12- W' string stabilizer (gyro 6-%" Anadrill A675M4570XP Mud motor, with 1 .15° ASH with 8.75" string stabilizer 400 - 700 60-80 gpm 500 - 600 60-120 gpm 1.5°/100' initial build 3.5°/100' final build 6r Max in Pilot Hole / 56° Tangent in Mainbore 1 & 2 6 . G.r Prudhoe Bay Orion V-213i Permit Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to test pressures not exceeding 5,OOOpsi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for V-213i will be 14 days. / Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 2,167 psi @ 4,905' TVOss - Base of Schrader · Maximum surface pressure: 1,676 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4,000 psi (the 7" casing will be tested to 4,000 psi) ..-- Estimated 9.3 ppg Brine I 6.8 ppg ~iesel 4,000/250 psi Rams & Valves 3,500/250 psi Annular Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I waste to Pad 3 for disposal. . G.r Prudhoe Bay Orion V-213i Permit Drilling Hazards and Continaencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 2 and 2A fault blocks are expected to be normal pressured at 8.5-8.9 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole, however recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-100 and V-111 had to have the mud treated and were able to drill to section TO. In V-1 00 the hydrates came from the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected due to the benign nature of V Pad fault and the second fault in the Ugnu Ma. In addition the faults will be crossed at high angle and move away quickly. . Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerancellntegrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal t l ment to 600' MD above the Ma sand -5,471' MD. C. The Kick Tolerance for the surface casing is 2 bls with 9.3 ppg mud, 12.3 ppg LOT, and an 8.9 ppg pore pressure. If the LOT is 12.7 ppg or rê EMW, then the kick tolerance will be> 50 bbls. D. Integrity Testing 9-%-in shoe 20-ft minimum from 9-%--in shoe LOT 11 .5 minimum V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. ",... VI. Hydrogen Sulfide V Pad is...!}.Q1.designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: o Adjacent producers at Surface: V-115 10 ppm V-1QO 10 ppm o Adjacent producers at TO: I V-103 10 ppm V-106 10 ppm 8 · Ger Prudhoe Bay Orion V-213i Permit VII. Faults A. No faults are expected to be crossed in the injection leg of this well. Both faults are in the plugback leg. Fault 1 is the 'V-Pad Fault' and has been intersected in the surface hole by most wells drilled from V Pad to date. It has been crossed in a similar stratigraphic interval as V-213PB1 in wells V-103 and V-106. Fault #2 is a 45' throw fault and has been previously crossed by V-103 in the lower Ugnu, similar to where V-213PB1 will penetrate the fault. Both faults will be crossed at a high angle and will drilled away from in short order. No losses are expected to be associated with these faults. The fault details are listed below for reference: Fault 1 (SV4): 2,570' MD Fault 2 (Ma): 7,095' MD 2,203' TVD 4,178' TVD 2,120' TVDss 4,095' TVDss Throw: -95' West Throw: 45' Northeast CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 9 · G.r Prudhoe Bay Orion V-213i Permit Drill and Complete Procedure Summary Pre-Rig Work: 1. The V-213i conductor has been set. See As-Built for coordinates. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in V-100 and V-115 and remove well houses as necessary. ***AII pre-rig work should be charged off against the predrill AFE # ORD5M3555*** Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick.~· . 3. MU 12- W' drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,570' MD. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port Collar or stage tool should be /~ on location. Cement was not circulated to surface on V-103 and V-106 1st stage surface cement job. Therefore a port collarlstage tool will be run in the casing string to allow secondary cementing, (in the event cement is not circulated to surface during primary cementing operations). // 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4,000 psi. 6. MU 8-%" drilling assembly with MWD/GR/R~en/Neu(recorded)/PWD and RIH to float collar. Test the 9-%" casing to 3,500 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.3 ppg mud 8. Drill new formation to 20' below 9-%" shoe and perform LOT (If a 12.5 ppg EMW is not obtained contact ODE). 9. Drill ahead to Polygon 2A Pilot Hole TD at 9,118' MD, (150' below base OBf). / 10. Condition the hole for P&A plug. POOH to LD BHA standing back the 4" DP.~ 11. RIH wi 3 1/2" cement stinger and plug catching sub on ~ DP to TO, spot ,1 Oq:balanced 15.8 ppg Class G cement abandonment plug from TD to 8,018'MD. /' c...~~ . 12. POOH to 8,1 08'MD and circulate out drill pipe and cement. Spot second 1~.' /alance 15.8 ppg Class G cement abandonment plug from 8,018'MD to 6,918' MD (164' above Schrade a sand). -- 13. POOH to 3 stands above plug, circulate out drill pipe and contaminated mud, POOH. 14. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH reaming and washing to top /"'" of cement plug. Place "sufficient weight on the plug to confirm its location and to confirm that the plug has set and a competent plug is in place" (AOGCC). 15. POOH to 3,716' MD and lowside existing wellbore to continue with ~g the Polygon 2 Schrader injection mainbore. Drill ahead to 7,176' MD (base of OBd target plus 250'). 16. Circulate and condition hole, make a short trip, TOOH to run casing. 17. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace / the casing with ±8.5 ppg heated seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-%" annulus. 18. PU used bit and scraper and RIH with 4" DP while waiting on cement to PBTD ±7,096' MD. Displace out the mud I seawater with 9.3 ppg brine. POOH and LD BHA. Note: It is not necessary to change to pipe rams for scraper run as casing has been 7d. 19. RU Schlumberger E-line and run a USIT/GR log. USIT will be primary depth control. / 20. RU Schlumberger and perforate OA and OBa/OBb wI 115' of 4.5" Power Jet Guns set at 5 spf in 5 runs. Depths based on USIT/GR logging run. (GR only used on first run if 30-40' guns are used.) 21. PU used bit, junk basket, scraper, and RIH to PBTD to recover any perf debris. Circulate the well with sweeps until clean. (RIH at full speed.) 22. M/U Schlumberger SXAR Gun Drop assembly consisting of 50' of 4-1/2" PowerJet Guns at 5 spf. 10 · Gr. Prudhoe Bay Orion V-213i Permit 23. Run the 4-%" X 3-%", L-80 TCII completion with a 7" x 3-W' straddle packer assembly and injection mandrel~ (torque turn connections). 24. Make GR e-line correlation run, correct gun setting depth and tubing hanger spaceout. 25. Run in the lockdown screws and set the packers. Test the production casingltubing annulus and tubing to 4,000 psi each. Shear the DCK shear valve. / 26. Install FMC TWCV. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 27. Freeze protect the well to -2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-%" annulus valve and secure the well. Assure that IAlOA are both protected with two barriers. 28. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod I RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GLV. 3. Install firing head on SXAR system and fire guns. 4. Pull dummy valves in injection mandrels and replace with injection valves. 5. Pull VR plug. 11 · G.r Prudhoe Bay Orion V-213i Permit Job 1: MIRU Hazards and Contingencies: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W -212i). ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ V-115 and V-100 will have to be shut in and require well house removal before rig can be moved over the well. Job 2: Dril/12J-á" Surface Hole Hazards and Contingencies: ~ At V-Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost and particularly at ± 900-1000'. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. ~ Hydrates: Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole, however recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-1 00 and V-111 had to have the mud treated and were able to drill to section TO. In V-100 the hydrates came from the SV1. ~ Close Approach: The V-115 and V-100 are required to be shut in and have their wellhouses removed due to surface location proximity to the V-213i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder I no-go plot per established procedures. A gyro should be run to at least 900'-1200'. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque I drag in the later hole sections and allow for easier 9 5/8" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the surface hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.83° motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TO to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observed, and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is 12 e Grer Prudhoe Bay Orion V-213i Permit imperative that the surface casing isolates all of the SV1 sands. Job3: Install Surface Casing Hazards and Contingencies: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates are prevalent on V-pad all the way into the SV1. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 9-%" special drift casing is being used (8.835" drift required). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3;4" bit, Le. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MD if losses are encountered or indications are that gravel is running or the whole is washing out. Several V-pad wells with similar directional plans and in this quadrant have required secondary cementing on surface due to losses during the primary job. ~ Losses during cement job: At V-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7-lb/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected EGD's during the entire cement job to help mitigate the potential for breaking down the formations. Job 4: Drill 8%" Production Hole Hazards and Contingencies: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Schrader reservoir pressure of 8.9 ppg and 9.3 ppg mud, a 12.3 ppg leak-off will provide 42 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 12.7 ppg. Based upon off-set drilling data on V-Pad, a minimum leak-off of 13 ppg is expected at the 9-%" shoe. ~ Pilot Hole TD - The TD for the 8 3;4" pilot hole will be determined by depth based on changes in GR/Res curves associated with the base OBf sand. After seeing the base OBf, TD will be called at the point in time that the onsite geologist feels that the zone has been fully penetrated and logged. ~ Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for EGDs not to exceed 0.6ppg above calculated. If EGDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. EGD should not exceed 11.0 ppg once the M sand has been penetrated. ~ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the base OBd sand. After seeing the base OBd, TD will be picked based on drilling 250' MD past this base. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Torque: Modeling indicates that torque values as high as 10,000 ft-Ibs can be expected by pilot hole 13 · Gr. Prudhoe Bay Orion V-213i Permit section TD. Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. y Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the intermediate hole sections. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the OBf and OBd sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. y Faults: No faults are expected to be crossed in the injection leg of this well. Both faults are in the plugback leg. Fault 1 is the 'V-Pad Fault' and has been intersected in the surface hole by most wells drilled from V Pad to date. It has been crossed in a similar stratigraphic interval as V-213PB1 in wells V-103 and V-106. Fault #2 is a 45' throw fault and has been previously crossed by V-1 03 in the lower Ugnu, similar to where V-213PB1 will penetrate the fault. Both faults will be crossed at a high angle and will drilled away from in short order. No losses are expected to be associated with these faults. The fault details are listed below for reference: Fault 1 (SV4): 2,570' MD Fault 2 (Ma): 7,095' MD 2,203' TVD 4,178' TVD 2,120' TVDss Throw: -95' West 4,095' TVDss Throw: 45' Northeast y Directional Constraints: It is important to keep the wellbore smooth and the tangent angle close to plan to facilitate casing running and slickline access. It is important to design a BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to ~1 0 over planned. Dogleg will take priority over angle as long as mainbore tangent angle does not approach 68 degrees. Job 6: Install 7" Production CasinR Hazards and Contingencies: y Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. y Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. y RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: o Pip #1: Top Ma Sand o Pip #2: 40-60' above top OA sand y Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job and height of cement top above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. y Mud Requirements: Thin the mud as per Ml's Mud Program before cementing. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. y Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. 14 · Ger Prudhoe Bay Orion V-213i Permit ~ 7" Casing Specifications: 7", 26#, L-80 BTC 1 00% 80% ID 6.276 6.151 (drift) Collapse 5,410psi 4,328psi Burst 7,240psi 5,792psi Tensile 667,0001bs 533,6001bs ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor for casing running. Job 10: Perforate Well (E-linelSXAR) Hazards and Contingencies ~ The well will be perforated ±130 psi over-balanced. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating guns, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, perforating crew and the Schlumberger hand. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. ~ Contact Schlumberger to prepare for approximately 115' of 4-1/2" Power Jet guns at 5 spf to be run on wire, and 50' of 4 W' Power Jet guns at 5 spf to be run with the completion using the SXAR gun drop system. Exact perforation depths will be provided after reviewing the lWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater on location and be prepared with lCM if necessary. Follow the lCM decision tree for "After Perforating". ~ Perf guns should be logged on depth initially using GR and subsequently only with CCl so as to lessen the stress on the tools and prevent failure. This is especially important when using 40' guns. Position guns by E-line measurement from USIT run for e-line perforating and by utilizing the Schlumberger GR tool in the string and RA tags for SXAR perforating. Reference RP: .:. 'Schlumberger E-line and SXAR Procedures' Job 12: Run Completion Hazards and Contingencies: ~ Dirty Hole: It is critical to have a clean hole to run this completion due to the production packer. Take time to circulate and pump adequate sweeps to clean the hole before coming out to lay down DP. If the packer partially prematurely sets, set it all the way and run in and chemical cut and remove the completion. ~ Torque turn TCII completion connections to help assure that they doesn't leak when the well is put on MI. Reference RP: .:. 'Completion Design and Running' RP 15 .. G.r Prudhoe Bay Orion V-213i Permit Job 13: ND/NU/Re/ease Rig Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. 16 . V-213i PB 1 Pilot Hole Proposed P&A Cellar Elevation = 54.3' Nabors 9ES RKB = 82.8' 9-5/8",40 lIft, L-80, BTC 13,570' MD I a l . TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head w/?" mandrel hanger & packoff 11" x 11", 5M, tbg spool w/ 11" x 4-1/2" tubing hanger 11" X 4-1/16" Adaptor Flange 20" X 34" 215.5Ib/ft, A53 ERW Insulated 1114' MDI 3,716' MD 83/4", Lowside KOP (Injector Mainbore) Date 04/07/04 06/22/04 Rev By TomS Comments Pilot Hole Proposed Abandonment Revisions reflect final well plan and as built 6,918' MD 1/ Top of Cement Abandonment Plug _I 7,083' MD Top Schrader Ma Sand I 8,965' MD Base OBf Sand I 9,118' MD 83/4", TO (PB1 Pilot Hole) G~N~ßv WELL: V-213i API NO: Cellar Eievalion ::: 54.3' Naoors 9ES RKB::: 82.S 1 20" X 34" 215.5Ibffl:, A53 ERW Insulated 9-5/8", 40 #llt, L-80, BTC T' Short Joint & RA Ma sand i 38' T' Short Joint & RA 40-60' above OA RA in 31/2" 04/07/04 06/22104 TomS TomS TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gel'! 5 11", wi?" 'x tbg tubing 6" Adaptor 4-1/2" 'X' with 3.813" sea! bore. Cameo With lift mandrel 4-1/2" J( 1" KBG2 Shear Valve pinned to 2,500 4-1/2" 'X' with 3,813" seal bore. 4-1/2" X 3-1/2" T' x 3-1/2" Baker 'PRM' Production Packer 3-1/2" 'X' with 2,813" seal bore, sand Perfs: TBD Cameo 3-1/2" x 1-112" Injection Mandrels (set above/below OA with 2,813" seal bore, T' x 3-1/2" Baker 'PRM' Production Packer 3-1/2" 'X' with 2,813" seal bore. .... .... .... .... Ba & OBb sand Perfs: TBD Cameo 3-1/2" x 1-1/2" Injection Mandrels (set above/belowOBa 3-1/2" 'X' with 2.813" seal bore. T')( 3-1/2" Baker 'S-3' Packer 'X' with 2.813" seal bore, 3-1/2" WireUne Guide sand Perfs: TBD SXAR Gun sub and 7", PBTD 7", 26 #/ft, BTC-Mod I MD 76' MD MD Revisions reflect final well and as built bp o Report Date: Client: Field: structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: V-213PB1 (P4) Proposal June 21, 2004 Survey I DLS Computation Method: BP Exploration Aiaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA Vertical Section Origin: V-Pad 1 Plan V-213 (S-W) S.udY TVD Reference Datum: Plan V-213 (S-W) -b,-IIt)' '" TVDReferenceElevation: Plan V-213PB1 Feas, Sea Bed I Ground Level Elevation: 50029 Magnetic Declination: V-213PB1 (P4) 1 July 20,2004 Total Field Strength: 87.999· 16878.03 It 16.036 11.353 Magnetic Dip: NAD27 Alaska State Planes. Zone 04, US Feet Declination Date: N 70.32768174, W 149.26373616 Magnetic Declination Model: N 5969968.370 ItUS, E 590785.030 ItUS North Reference: -t{).69329489· Total Corr Mag North .> True North: 0.99990936 Local Coordinates Referenced To: Schlumberger Minimum Curvature 1 Lubinski 45.000· N 0.000 It. E 0.000 It KB 82.80 It relative to MSL 54.30 It relative to MSL 24.904· 57570.714 nT 80.818· July 20, 2004 BGGM 2003 True North +24.904· Well Head e I Comments Measured I Inclination I Azimuth I Su~Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting Latitude Longilude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (deg/100 It) (deg) (deg/100 It) (deg/100 It) (ltUS) (ltUS) RTE 0.00 0.00 0.00 -82.80 0.00 0.00 0.00 0.00 0.00 0.00 O.OOM 0.00 0.00 5969968.37 590785.03 N 70.32768174 W 149.26373616 KOP Bid 1.5/100 300.00 0.00 0.00 217.20 300.00 0.00 0.00 0.00 0.00 0.00 O.OOM 0.00 0.00 5969968.37 590785.03 N 70.32768174 W 149.26373616 Bid 3/100 400.00 1.50 0.00 317.19 399.99 0.93 1.31 1.31 0.00 1.50 O.OOM 1.50 0.00 5969969.68 590785.01 N 70.32768532 W 149.26373616 500.00 4.50 0.00 417.04 499.84 4.63 6.54 6.54 0.00 3.00 O.OOM 3.00 0.00 5969974.91 590784.95 N 70.32769962 W 149.26373616 600.00 7.50 0.00 516.48 599.28 12.02 16.99 16.99 0.00 3.00 O.OOG 3.00 0.00 5969985.36 590784.82 N 70.32772817 W 149.26373616 700.00 10.50 0.00 615.24 698.04 23.08 32.64 32.64 0.00 3.00 O.OOG 3.00 0.00 5970001.00 590784.64 N 70.32777090 W 149.26373616 End Bid 800.00 13.50 0.00 713.04 795.84 37.78 53.42 53.42 0.00 3.00 O.OOG 3.00 0.00 5970021.79 590784.38 N 70.32782769 W 149.26373616 SV6 987.13 13.50 0.00 895.00 977.80 68.67 97.11 97.11 0.00 0.00 O.OOG 0.00 0.00 5970065.46 590783.86 N 70.32794703 W 149.26373616 Cry 3.51100 1000.00 13.50 0.00 907.52 990.32 70.79 100.11 100.11 0.00 0.00 51.30G 0.00 0.00 5970068.47 590783.82 N 70.32795524 W 149.26373616 1100.00 15.92 10.00 1004.25 1087.05 90.29 125.44 125.30 2.38 3.50 41.62G 2.42 10.00 5970093.68 590785.90 N 70.32802405 W 149.26371683 1200.00 18.68 17.28 1099.73 1182.53 115.70 155.14 154.10 9.52 3.50 34.67G 2.76 7.27 5970122.56 590792.69 N 70.32810274 W 149.26365894 1300.00 21.64 22.68 1193.60 1276.40 146.95 189.58 186.42 21.39 3.50 29.60G 2.97 5.40 5970155.02 590804.16 N 70.32819103 W 149.263_ 1400.00 24.75 26.81 1285.51 1368.31 183.90 228.95 222.13 37.95 3.50 25.80G 3.10 4.13 5970190.92 590820.29 N 70.32828858 W 149.263 1500.00 27.94 30.06 1375.12 1457.92 226.43 273.30 261.09 59.13 3.50 22.89G 3.19 3.25 5970230.14 590840.99 N 70.32839503 W 149.2632 1600.00 31.19 32.69 1462.09 1544.89 274.38 322.63 303.17 84.85 3.50 20.60G 3.25 2.63 5970272.52 590866.20 N 70.32850998 W 149.26304804 1700.00 34.48 34.86 1546.11 1628.91 327.56 376.84 348.20 115.03 3.50 18.77G 3.30 2.17 5970317.91 590895.83 N 70.32863301 W 149.26280334 SV5 1723.03 35.25 35.31 1565.00 1647.80 340.52 390.00 358.98 122.60 3.50 18.40G 3.32 1.95 5970328.77 590903.26 N 70.32866243 W 149.26274198 1800.00 37.81 36.70 1626.85 1709.65 385.77 435.81 396.02 149.54 3.50 17.29G 3.33 1.80 5970366.14 590929.76 N 70.32876364 W 149.26252347 1900.00 41.17 38.28 1704.01 1786.81 448.81 499.39 446.45 188.26 3.50 16.07G 3.35 1.58 5970417.03 590967.86 N 70.32890141 W 149.26220946 SV4 1901.31 41.21 38.30 1705.00 1787.80 449.67 500.26 447.13 188.80 3.50 O.OOG 3.36 1.47 5970417.71 590968.38 N 70.32890326 W 149.26220513 Base Perm 1901.32 41.21 38.30 1705.01 1787.81 449.68 500.27 447.14 188.80 3.50 16.05G 3.36 1.47 5970417.72 590968.39 N 70.32890328 W 149.26220508 2000.00 44.54 39.66 1777.32 1860.12 516.43 567.39 499.30 231.04 3.50 15.06G 3.37 1.38 5970470.39 591009.99 N 70.32904579 W 149.26186250 2100.00 47.92 40.88 1846.48 1929.28 588.39 639.59 554.38 277.73 3.50 14.21G 3.39 1.22 5970526.02 591056.01 N 70.32919624 W 149.26148388 2200.00 51.32 41.98 1911.26 1994.06 664.41 715.76 611.47 328.15 3.50 13.50G 3.40 1.10 5970583.71 591105.72 N 70.32935220 W 149.26107500 2300.00 54.73 42.98 1971.40 2054.20 744.21 795.64 670.37 382.11 3.50 12.89G 3.41 1.00 5970643.25 591158.96 N 70.32951310 W 149.26063739 End Cry 2364.96 56.95 43.59 2007.87 2090.67 797.94 849.39 709.49 418.96 3.50 O.OOG 3.41 0.93 5970682.81 591195.34 N 70.32961998 W 149.26033849 SV3 2552.22 56.95 43.59 2110.00 2192.80 954.84 1006.34 823. 17 527.17 0.00 O.OOG 0.00 0.00 5970797.78 591302.16 N 70.32993053 W 149.25946085 Fault Crossing 2570.55 56.95 43.59 2120.00 2202.80 970.20 1021.71 834.30 537.77 0.00 O.OOG 0.00 0.00 5970809.04 591312.62 N 70.32996093 W 149.25937491 WellDesign Ver 3.1 RT-SP3.03-HF4.00 Bld( d031rt-546 ) Plan V-213 (S-W)\Plan V-213 (S-W)\Plan V-213PB1\V-213PB1 (P4) Generated 612112004 3:11 PM Page 1 of 2 Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting Latitude Longnude Depth Section Departure (II) ( deg) (deg) (II) (II) (II) (II) (II) (II) (deg/100 II) (deg) (deg/100 II) (degJ100 II) (IIUS) (IIUS) SV2 2744.73 56.95 43.59 2215.00 2297.80 1116.15 1167.70 940.05 638.43 0.00 O.OOG 0.00 0.00 5970915.99 591411.98 N 70.33024980 W 149.25855851 SV1 3368.12 56.95 43.59 2555.00 2637.80 1638.50 1690.21 1318.51 998.68 0,00 O.OOG 0.00 0.00 5971298.74 591767.59 N 70.33128361 W 149.25563645 9-5/8" Csg pt 3569.81 56.95 43.59 2665.00 2747.80 1807.50 1859.26 1440.95 1115.23 0.00 O.OOG 0.00 0.00 5971422.57 591882.65 N 70.33161807 W 149.25469102 Cry 4/100 3716.49 56.95 43.59 2745.00 2827.80 1930.40 1982.20 1530.00 1200.00 0.00 4.45G 0.00 0.00 5971512.63 591966.32 N 70.33186131 W 149.25400341 3800.00 60.28 43.89 2788.49 2871.29 2001.67 2053.48 1581.50 1249.28 4.00 4.30G 3.99 0.36 5971564.72 592014.97 N 70.33200198 W 149.25360361 3900.00 64.27 44.22 2835.01 2917.81 2090.15 2141.98 1645.10 1310.82 4.00 4.14G 3.99 0.33 5971629.06 592075.73 N 70.33217571 W 149.25310440 End Cry 3963.51 66.80 44.42 2861.31 2944.11 2147.95 2199.78 1686.46 1351.21 4.00 O.OOG 3.99 0.31 5971670.89 592115.61 N 70.33228866 W 149.25277681 UG4 3998.27 66.80 44.42 2875.00 2957.80 2179.90 2231.74 1709.28 1373.57 0.00 O.OOG 0.00 0.00 5971693.98 592137.69 N 70.33235100 W 149.25259537 UG4A 4099.82 66.80 44.42 2915.00 2997.80 2273.23 2325.07 1775.94 1438.89 0.00 O.OOG 0.00 0.00 5971761.43 592202.20 N 70.33253309 W 149.25206545 UG3 5140.64 66.80 44.42 3325.00 3407.80 3229.85 3281.74 2459.24 2108.46 0.00 O.OOG 0.00 0.00 5972452.71 592863.38 N 70.33439937 W 149.246_ UG1 6473.40 66.80 44.42 3850.00 3932.80 4454.79 4506.74 3334.20 2965.82 0.00 O.OOG 0.00 0.00 5973337.90 593710.02 N 70.33678887 W 149.239 Ma 7082.66 66.80 44.42 4090.00 4172.80 5014.76 5066.74 3734.18 3357.76 0.00 O.OOG 0.00 0.00 5973742.55 594097.06 N 70.33788113 W 149.236 Fault Crossing 7095.35 66.80 44.42 4095.00 4177.80 5026.42 5078.40 3742.51 3365.93 0.00 O.OOG 0.00 0.00 5973750.98 594105.12 N 70.33790388 W 149.23642833 Mb1 7336.52 66.80 44.42 4190.00 4272.80 5248.08 5300.07 3900.83 3521.07 0.00 O.OOG 0.00 0.00 5973911.16 594258.32 N 70.33833622 W 149.23516905 Mb2 7526.91 66.80 44.42 4265.00 4347.80 5423.07 5475.07 4025.83 3643.55 0.00 O.OOG 0.00 0.00 5974037.61 594379.27 N 70.33867753 W 149.23417485 Me 7704.62 66.80 44.42 4335.00 4417.80 5586.40 5638.40 4142.49 3757.87 0.00 O.OOG 0.00 0.00 5974155.64 594492. 15 N 70.33899608 W 149.23324689 Na 7869.62 66.80 44.42 4400.00 4482.80 5738.05 5790.07 4250.82 3864.02 0.00 O.OOG 0.00 0.00 5974265.23 594596.98 N 70.33929188 W 149.23238520 Nb 7933.09 66.80 44.42 4425.00 4507.80 5796.38 5848.40 4292.48 3904.84 0.00 O.OOG 0.00 0.00 5974307.38 594637.29 N 70.33940564 W 149.23205377 Ne 8047.33 66.80 44.42 4470.00 4552.80 5901.38 5953.40 4367.48 3978.33 0.00 O.OOG 0.00 0.00 5974383.26 594709.86 N 70.33961042 W 149.23145719 V-213PB1 AprTgt 8275.80 66.80 44.42 4560.00 4642.80 6111.37 6163.40 4517.47 4125.31 0.00 180.00G 0.00 0.00 5974535.00 594855.00 N 70.34001997 W 149.23026399 OA 8275.83 66.80 44.42 4560.01 4642.81 6111.39 6163.43 4517.49 4125.33 2.00 180.00G -2.00 0.00 5974535.02 594855.02 N 70.34002001 W 149.23026385 8300.00 66.32 44.42 4569.63 4652.43 6133.57 6185.61 4533.33 4140.85 2.00 180.00G -2.00 0.00 5974551.05 594870.35 N 70.34006327 W 149.23013783 8400.00 64.32 44.42 4611.38 4694.18 6224.43 6276.47 4598.22 4204.44 2.00 180.00G -2.00 0.00 5974616.70 594933.14 N 70.34024046 W 149.22962156 DBa 8419.74 63.92 44.42 4620.00 4702.80 6242.18 6294.23 4610.91 4216.87 2.00 180.00G -2.00 0.00 5974629.53 594945.42 N 70.34027510 W 149.22952065 8500.00 62.32 44.42 4656.29 4739.09 6313.77 6365.81 4662.04 4266.97 2.00 180.00G -2.00 0.00 5974681.26 594994.89 N 70.34041470 W 149.22911388 OBb 8507.97 62.16 44.42 4660.00 4742.80 6320.82 6372.87 4667.08 4271.91 2.00 180.00G -2.00 0.00 5974686.36 594999.77 N 70.34042846 W 149.22907380 8600.00 60.32 44.42 4704.28 4787.08 6401.49 6453.54 4724.70 4328.37 2.00 180.00G -2.00 0.00 5974744.65 595055.52 N 70.34058578 W 149.22861541 OBe 8621.51 59.89 44.42 4715.00 4797.80 6420.13 6472.18 4738.01 4341.42 2.00 180.00G -2.00 0.00 5974758.13 595068.41 N 70.34062214 W 149.22850946 8700.00 58.32 44.42 4755.31 4838.11 6487.48 6539.53 4786.12 4388.56 2.00 180.00G -2.00 0.00 5974806.79 595114.96 N 70.34075349 W 149.22812674 OBd 8718.36 57.95 44.42 4765.00 4847.80 6503,07 6555.13 4797.26 4399.48 2.00 180.00G -2.00 0.00 5974818.06 595125.73 N 70.34078390 W 149.228. 8800.00 56.32 44.42 4809.30 4892.10 6571.64 6623.70 4846.23 4447.47 2.00 180.00G -2.00 0.00 5974867.61 595173.12 N 70.34091762 W 149.227 OBe 8810.25 56.11 44.42 4815.00 4897.80 6580.16 6632.21 4852.32 4453.43 2.00 180.00G -2.00 0.00 5974873.76 595179.01 N 70.34093423 W 149.22760009 OBf 8889.34 54.53 44.42 4860.00 4942.80 6645.19 6697.25 4898.77 4498.95 2.00 180.00G -2.00 0.00 5974920.76 595223.96 N 70.34106106 W 149.22723049 8900.00 54.32 44.42 4866.20 4949.00 6653.86 6705.92 4904.97 4505.02 2.00 180.00G -2.00 0.00 5974927.03 595229.95 N 70.34107797 W 149.22718123 OBf Base 8965.48 53.01 44.42 4905.00 4987.80 6706.60 6758.67 4942.64 4541.93 2.00 180.00G -2.00 0.00 5974965.14 595266.41 N 70.34118083 W 149.22688149 9000.00 52.32 44.42 4925.94 5008.74 6734.05 6786.12 4962.24 4561.14 2.00 180.00G -2.00 0.00 5974984.97 595285.38 N 70.34123435 W 149.22672553 9100.00 50.32 44.42 4988.43 5071.23 6812.10 6864.17 5017.99 4615.77 2.00 180.00G -2.00 0.00 5975041.38 595339.33 N 70.34138657 W 149.22628195 TO 9118.05--) 49.96 44.42 5000.00 5082.80 6825.95 6878.03 5027.89 4625.4 7 2.00 O.OOG -2.00 0.00 5975051.39 595348.90 N 70.34141358 W 149.22620323 Leqal Description: Northinq (YI ¡ftUS! Eastinq (XI fftUS! Surface; 4718 FSL 1517 FEL S11 T11N R11E UM 5969968.37 590785.03 Target: 3954 FSL 2668 FEL S1 T11 N R11 E UM 5974535.00 594855.00 BHL: 4464 FSL2167 FELS1 T11N R11E UM 5975051.39 595348.90 WeliDesign Ver 3.1 RT-SP3.03-HF4.00 Bld( do31rt-546 ) Plan V-213 (S-W)\Plan V-213 (S-W)\Plan V-213PB1\V-213PB1 (P4) Generated 6/21/2004 3:11 PM Page 2 of 2 tip o V-213 (P6) Proposal Schlumberger Report Date: Client: Field: Structure I Slot: Well: Borehole: UWVAPI#: Survey Name I Date: Tort I AHD / DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid HIE YIX: Grid Convergence Angle: Grid Scale Factor: June 21, 2004 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA Vertical Section Origin: V-Pad/Plan V-213 (S-W) S Udy TVD Reference Datum: Plan V-213 (S-W) - b-I I I'" ~ TVD Reference Elevation: PlanV-213 Feasl.~ Sea Bed I Ground Level Elevation: 50029 Magnetic Declination: V-213 (P6) / June 21, 2004 Total Field Strength: 80.328' /4711.008.00 It /5.742/ 0.958 Magnetic Dip: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: N 70.32768174, W 149.26373616 Magnetic Declination Model: N 5969968.370 ItUS, E 590785.030 ItUS North Reference: -t{).69329489' Total Corr Mag North .> True North: 0.99990936 Local Coordinates Referenced To: Minimum Curvature / Lubinski 45.000' N 0.000 It, E 0.000 It Rotary Table 82.80 It relative to MSL 54.30 It relative to MSL 24.897' 57571.210 nT 80.819' July 26, 2004 BGGM 2003 True North +24.897' Well Head e Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting Latitude Longnude Depth Section Departure (It) ( deg) (deg ) (It) (It) (It) (It) (It) (It) ( deg/100 It ) (deg) (deg/100 It) (deg/100 It) (ltUS) (ltUS) KOP Cry 21100 3716.49 56.95 43.59 2745.00 2827.80 1930.40 1982.20 1530.00 1200.00 0.00 -129.89G 0.00 0.00 5971512.63 591966.32 N 70.33186131 W 149.25400341 End Cry 3775.73 56.19 42.49 2777.64 2860.44 1979.82 2031.64 1566.13 1233.75 2.00 O.OOG -1.27 -1.85 5971549.17 591999.62 N 70.33196001 W 149.25372965 UG4 3941.73 56.19 42.49 2870.00 2952.80 2117.61 2169.57 1667.83 1326.92 0.00 O.OOG 0.00 0.00 5971651.98 592091.55 N 70.33223780 W 149.25297382 UG4A 4010.02 56.19 42.49 2908.00 2990.80 2174.30 2226.32 1709.68 1365.25 0.00 O.OOG 0.00 0.00 5971694.28 592129.37 N 70.33235209 W 149.25266284 UG3 4687.59 56.19 42.49 3285.00 3367.80 2736.76 2789.31 2124.80 1745.56 0.00 O.OOG 0.00 0.00 5972113.94 592504.60 N 70.33348596 W 149.24957742 UG1 5631.15 56.19 42.49 3810.00 3892.80 3520.03 3573.33 2702.89 2275.18 0.00 O.OOG 0.00 0.00 5972698.34 593027.13 N 70.33506487 W 149.24528018 Ma 6071.47 56.19 42.49 4055.00 4137.80 3885.55 3939.20 2972.67 2522.33 0.00 O.OOG 0.00 0.00 5972971.06 593270.97 N 70.33580166 W 149.24327457 Mb1 6152.35 56.19 42.49 4100.00 4182.80 3952.69 4006.40 3022.22 2567.72 0.00 O.OOG 0.00 0.00 5973021.16 593315.76 N 70.33593698 W 149.24290618 Drp 4/100 6247.70 56.19 42.49 4153.05 4235.85 4031.84 4085.63 3080.64 2621.24 0.00 -178.49G 0.00 0.00 5973080.21 593368.57 N 70.33609653 W 149.24247184 Mb2 6277.69 54.99 42.46 4170.00 4252.80 4056.56 4110.37 3098.89 2637.95 4.00 -178.47G -4.00 -0.13 5973098.66 593385.05 N 70.33614637 W 149.24233625 6300.00 54.10 42.43 4182.94 4265.74 4074.71 4128.55 3112.30 2650.21 4.00 -178.45G -4.00 -0.13 5973112.22 593397.15 N 70.33618299 W 149.24223673 Me 6385.33 50.69 42.31 4235.00 4317.80 4142.23 4196.14 3162.24 2695.76 4.00 -178.38G -4.00 -0.14 5973162.70 593442.09 N 70.33631937 W 149.241_ 6400.00 50.10 42.29 4244.35 4327.15 4153.52 4207.44 3170.60 2703.37 4.00 -178.37G -4.00 -0.15 5973171.15 593449.59 N 70.33634221 W 149.241 Na 6483.87 46.75 42.15 4300.00 4382.80 4216.18 4270.18 3217.06 2745.53 4.00 -178.28G -4.00 -0.16 5973218.11 593491.18 N 70.33646909 W 149.2414 6500.00 46.10 42.13 4311.12 4393.92 4227.86 4281.86 3225.72 2753.37 4.00 -178.26G ·4.00 -0.17 5973226.87 593498.91 N 70.33649275 W 149.24139957 Nb 6512.75 45.59 42.11 4320.00 4402.80 4236.99 4291.01 3232.51 2759.50 4.00 -178.25G -4.00 -0.17 5973233.73 593504.97 N 70.33651129 W 149.24134977 Ne 6568.81 43.35 42.01 4360.00 4442.80 4276.21 4330.28 3261.67 2785.81 4.00 -178.18G -4.00 -0.18 5973263.20 593530.92 N 70.33659092 W 149.24113627 6600.00 42.11 41.95 4382.91 4465.71 4297.35 4351.44 3277.40 2799.97 4.00 -178.13G -4.00 -0.19 5973279.10 593544.88 N 70.33663388 W 149.24102140 OA 6688.04 38.59 41.76 4450.00 4532.80 4354.25 4408.44 3319.85 2838.00 4.00 -177.99G -4.00 -0.21 5973322.00 593582.39 N 70.33674981 W 149.24071275 End Drp / TgI 1 6694.43 38.33 41.75 4455.00 4537.80 4358.22 4412.41 3322.81 2840.64 4.00 O.OOG -4.00 -0.23 5973325.00 593585.00 N 70.33675790 W 149.24069129 OBa 6770.92 38.33 41.75 4515.00 4597.80 4405.58 4459.85 3358.20 2872.23 0.00 O.OOG 0.00 0.00 5973360.77 593616.15 N 70.33685456 W 149.24043492 OBb 6821.91 38.33 41.75 4555.00 4637.80 4437.15 4491.47 3381.80 2893.29 0.00 O.OOG 0.00 0.00 5973384.61 593636.92 N 70.33691899 W 149.24026401 OBe 6892.02 38.33 41.75 4610.00 4692.80 4480.57 4534.96 3414.24 2922.24 0.00 O.OOG 0.00 0.00 5973417.40 593665.48 N 70.33700760 W 149.24002900 OBd 6955.76 38.33 41.75 4660.00 4742.80 4520.04 4574.49 3443.74 2948.56 0.00 O.OOG 0.00 0.00 5973447.21 593691.44 N 70.33708814 W 149.23981535 Tgl2 7025.88 38.33 41.75 4715.00 4797.80 4563.46 4617.98 3476.18 2977.52 0.00 O.OOG 0.00 0.00 5973480.00 593720.00 N 70.33717675 W 149.23958034 WellDesign Ver 3.1 RT-SP3.03-HF4.00 Bld( d031rt-546 ) Plan V-213 (S-W)\Plan V-213 (S-W)\Plan V-213\V-213 (P6) Generated 6/21/2004 3:23 PM Page 1 of 2 I Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg ) (It) (It) (It) (It) (It) (It) ( deg/100 It ) (deg) (degJ100 It) (degJ100 It) (ltUS) (ltUS) OBe 7032.25 38.33 41.75 4720.00 4802.80 4567.40 4621.93 3479.13 2980.15 0.00 O.OOG 0.00 0.00 5973482.98 593722.59 N 70.33718480 W 149.23955898 OBf 7083.24 38.33 41.75 4760.00 4842.80 4598.98 4653.56 3502.72 3001.21 0.00 O.OOG 0.00 0.00 5973506.83 593743.36 N 70.33724924 W 149.23938806 OBf Base 7146.98 38.33 41.75 4810.00 4892.80 4638.45 4693.09 3532.22 3027.53 0.00 O.OOG 0.00 0.00 5973536.63 593769.33 N 70.33732978 W 149.23917441 TO / 7" Csg 7175.88 38.33 41.75 4832.67 4915.47 4656.34 4711.01 3545.59 3039.4 7 0.00 O.OOG 0.00 0.00 5973550.14 593781.09 N 70.33736630 W 149.23907756 LeClal Description: Surface: 4718 FSL 1517 FEL S11 T11N R11E UM Target 1: 2760 FSL 3954 FEL S1 T11N R11E UM Target 2 : 2914 FSL 3817 FEL S1 T11N R11E UM BHL: 2983 FSL 3755 FEL S1 T11N R11E UM NorthinCl (YI [ftUS! 5969968.37 5973325.00 5973480.00 5973550.14 EastinCl (XI [ftUS! 590785.03 593585.00 593720.00 593781.09 e . WellOesign Ver 3.1 RT-SP3.03-HF4.00 Bld( do31rt-546 ) Plan V-213 (S-W)\Plan V-213 (S-W)\Plan V-213\V·213 (P6) Generated 6/21/2004 3:23 PM Page 2 of 2 II () -¿¡¡ ü (j) o > I- u¡ V-213PB11V-213 (P4-6) FiELD Prudhoe Bay Unit - WOA STRUCTUHE V...Pa.d MagneticParnmetDl'$ MQdel 8GGM 2003 StJj"œL()cation NlO 1939_654 '011491549.450 NA027 Alaska State Pia""", ZŒ1e 04. US Foot Northing 5969868.3711U5 ->-O.ß9329489c S90!8i'.03itUS 0.9999093626 Misr.ellaneuu$ Plar>V-213 (S-W) V-213(P6) Dip 80.819" MauD"r; +24.897" Jwly26,2004 fVDRel S"'yDat<; o 1000 2000 3000 4000 5000 6000 7000 o o KOP Bid 1.51100 ,-- Bid 31100 - 1000 5000 1000 2000 2000 3000 3000 4000 4000 5000 o 4000 5000 '" 1 (in):10QO(ft) Origin '" 7000 WELL V-213PB1N-213 FIELD Prudhoe Unit - WOA STRUCTURE Ma(Jf1(!tk:ParamelelS MotJ,,1 BGGM 2003 Dip $urf<1ceLOGatiof1 La! N701939.654 Lon W1491549.4~;o. NAD21 AI<1ska State Planes, Zone 04, US Foot N0I1hing ',009968,37 flUS Glid Cony; +0,69329489' Easbng: f)907ß~L03 flUS Sr"ale Fact: 0.9999093626 Mìscellaf100l15 Slot Plan V-213 (S-W) Plan V"213{p6} NORe! SrvyOate o 1000 2000 3000 4000 5000 6000 6000 5000 TO 4000 4000 ^ ^ ^ z £ Õ 0 3000 3000 0 .... ;§: .... II ill ëB ü (f) (f) V 2000 2000 V V 5000 1000 1000 o o RTE KOP Bid 1.5/100 o 1000 2000 3000 «< W Scale == 1 (in):1 OOO(ft) E >>> 4000 5000 . . Schlumberger Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB V Pad Plan V-213 (S-W) Plan V-213PB1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 9118.05 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 8/21/2002 Validated: No Planned From To Survey ft ft 28.50 1500.00 Planned: Plan #4 V1 28.50 9118.05 Planned: Plan #4 V1 Casing Points MD ft 3569.81 9118.05 TVD ft 2747.80 5082.80 Diameter in Hole Size in Name 9.625 8.750 12.250 8.750 95/8" 8-3/4" open Summary <--------------- Offset Wetlpath -----------> Site Well Wetlpath PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad Plan V-01 (S-N) Plan V-01 (S-N) Plan V-01 (S-N) Plan V-01 V11 Plan: PI Plan V-112 (S-A) Plan V-112 V1 Plan: PI Plan V-118 (N-X) Plan V-118 V3 Plan: PI Plan V-203 (N-A) Plan V-203 VO Plan: V Plan V-204 (S-H) Plan V-204 OBd V1 Plan Plan V-204 (S-H) Plan V-204L 1 OBb V1 PI Plan V-204 (S-H) Plan V-204L2 OBa V1 PI Plan V-204 (S-H) Plan V-204L3 OA V1 Pia Plan V-205 (S-P) Plan V-205 V2 Plan: PI Plan V-206 (S-S) Plan V-206 V1 Plan: PI Plan V-21 0 (N-G) - w Plan V-210 V2 Plan: PI Plan V-211 (N-C) - w Plan V-211 V1 Plan: V Plan V-211 (S-Q) - s Plan V-211 V1 Plan: PI Plan V-212 (S-D) Plan V-212 VO Plan: V Plan V-214 (N-R) Plan V-214 V3 Plan: V Plan V-216 (N-T) Plan V-216 V4 Plan: PI Plan V-2a06 (N-M) Plan V-2a06 VO Plan: V Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P V-02 V-02 V10 V-03 V-03 V7 ~100 ~100V7 V-101 V-101 V7 ~1œ ~1œV5 V-103 V-103 V6 V-104 V-104 V13 V-105 V-105 V13 V-106 Plan V-106A V5 Plan: P V-106 V-106 V10 V-107 V-107 V5 V-108 V-108 V7 V-109 V-109 V2 V-109 V-109PB1 V5 V-109 V-109PB2 V2 V-111 V-111 V25 V-111 V-111PB1 V8 V-111 V-111PB2 V2 V-111 V-111PB3 V6 V-113 V-113 V6 V-114 V-114 V5 V-114 V-114A V4 V-114 V-114APB1 V4 V-114 V-114APB2 V2 Date: 6/21/2004 Time: 15:55:26 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan V-213 (S-W), True North V-213 Plan SoW 82.8 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 3 Toolcode Tool Name MWD MWD+IFR+MS MWD - Standard MWD + IFR + Multi Station Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation warniny ft ft ft ft ft 28.70 -54.10 134.98 No Offset Stations 448.28 450.00 136.13 7.72 128.41 Pass: Major Risk 349.12 350.00 370.30 6.43 363.87 Pass: Major Risk 1026.38 1000.00 136.18 18.46 117.72 Pass: Major Risk 403.09 400.00 412.42 8.52 403.90 Pass: Major Risk 640.66 650.00 267.54 11.32 256.22 Pass: Major Risk 640.66 650.00 267.54 11.32 256.22 Pass: Major Risk 640.66 650.00 267.54 11.32 256.22 Pass: Major Risk 640.66 650.00 267.54 11.32 256.22 Pass: Major Risk 399.54 400.00 105.94 7.37 98.56 Pass: Major Risk 399.82 400.00 60.54 7.38 53.16 Pass: Major Risk 561.97 550.00 334.60 9.71 324.89 Pass: Major Risk 508.22 500.00 386.08 10.45 375.63 Pass: Major Risk 1088.16 1100.00 33.38 20.85 12.53 Pass: Major Risk 494.41 500.00 326.62 10.41 316.21 Pass: Major Risk 1155.88 1150.00 1 05.46 23.07 82.40 Pass: Major Risk 888.30 850.00 180.78 15.50 165.28 Pass: Major Risk 981.82 950.00 234.07 21.40 212.68 Pass: Major Risk 697.20 700.00 22.29 13.94 8.35 Pass: Major Risk 904.58 900.00 290.76 16.36 274.40 Pass: Major Risk 1218.87 1200.00 41.30 22.13 19.17 Pass: Major Risk 399.00 400.00 16.29 6.46 9.83 Pass: Major Risk 818.94 800.00 371.77 13.87 357.91 Pass: Major Risk 975.36 950.00 270.65 19.07 251.58 Pass: Major Risk 1339.58 1300.00 159.49 25.13 134.35 Pass: Major Risk 866.53 850.00 318.58 15.15 303.43 Pass: Major Risk 1054.45 1050.00 167.39 18.92 148.47 Pass: Major Risk 1176.59 1150.00 163.13 21.63 141.51 Pass: Major Risk 1221.17 1200.00 167.98 22.69 145.29 Pass: Major Risk 1004.40 1000.00 262.66 17.58 245.08 Pass: Major Risk 150.50 150.00 399.00 2.63 396.37 Pass: Major Risk 399.48 400.00 311.72 6.69 305.02 Pass: Major Risk 399.48 400.00 311.72 6.69 305.02 Pass: Major Risk 399.48 400.00 311.72 6.69 305.02 Pass: Major Risk 1166.16 1150.00 67.27 21.92 45.34 Pass: Major Risk 1166.16 1150.00 67.27 21.92 45.34 Pass: Major Risk 1166.16 1150.00 67.27 21.92 45.34 Pass: Major Risk 1166.16 1150.00 67.27 21.92 45.34 Pass: Major Risk 398.61 400.00 341.70 5.93 335.77 Pass: Major Risk 350.03 350.00 281.39 5.78 275.60 Pass: Major Risk 350.03 350.00 281.39 5.78 275.60 Pass: Major Risk 350.03 350.00 281.39 5.78 275.60 Pass: Major Risk 350.03 350.00 281.39 5.78 275.60 Pass: Major Risk . Schlumberger Anticollision Report . Company: BP Amoco Date: 6/21/2004 Time: 15:55:26 Page: 2 Fietd: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Plan V-213 (S-W). True North Reference Well: Plan V-213 (S-W) Vertical (TVD)Reference: V-213 Plan SoW 82.8 Reference Wellpath: Plan V-213PB1 Db: Sybase Summary < Offset WelIpath "- > Reference Offset Ctr-Ctr No·Go Allowable Site Well WelIpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB V Pad V-115 V-115V5 349.84 350.00 17.72 5.62 12.10 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 349.84 350.00 17.72 5.62 12.10 Pass: Major Risk PB V Pad V-117 V-117V9 545.56 550.00 44.71 8.90 35.81 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 545.56 550.00 44.71 8.90 35.81 Pass: Major Risk PB V Pad V-117 V-117PB2V6 545.56 550.00 44.71 8.90 35.81 Pass: Major Risk PB V Pad V-119 V-119V13 495.42 500.00 297.15 8.46 288.68 Pass: Major Risk PB V Pad V-201 V-201 V8 615.19 600.00 287.92 9.92 278.01 Pass: Major Risk PB V Pad V-202 V-202 V9 1004.81 1000.00 329.93 17.63 312.29 Pass: Major Risk PB V Pad V-202 V-202L 1 V5 1004.81 1000.00 329.93 17.58 312.34 Pass: Major Risk PB V Pad V-202 V-202L2 V5 1004.81 1000.00 329.93 17.58 312.34 Pass: Major Risk Field: Prudhoe Bay Site: PB V Pad Well: Plan V-213 (S-W) Wellpath: Plan V-213PBl -294 100 ~QlJmv.",... Plan V-216 (N-T) (Plan V-216) 200 . -100 Plan V-211 (S-Q) - status unknown (Plan V-211) V-106 (V-106) -0 JO Plao V-II8 (N-X) (Plan V-II8) . 200 -294 21 jJ) Pl~ih-VI-1Ó~(!}J¡Jflplh¥vl11J5) 0 Plan V-Ol (S-N) (Plan V-OI) V-lOO (V-lOO) Plan V-206 (S-S) (Plan V-206) 180 n. Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] e Schlumberger Anticollision Report . Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB V Pad Plan V-213 (S-W) Plan V-213 Date: 6/21/2004 Time: 16:00:03 Page: Co·ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan V-213 (S-W), True North V-213 Plan SoW 82.8 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 3716.00 to 7175.88 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/21/2004 Validated: No Planned From To Survey ft ft 28.50 3716.49 Planned: Plan #4 V1 (0) 3716.49 7175.88 Planned: Plan #6 V1 Version: 3 Toolcode Tool Name MWD+IFR+MS MWD+IFR+MS MWD + IFR + Multi Station MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3569.81 2747.80 9.625 12.250 95/8" 7175.88 4915.47 7.000 8.750 7" Summary < Offset Wellpath --> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation warniny ft ft ft ft ft PB V Pad Plan V-01 (S-N) Plan V-01 (S-N) 3716.00 -54.10 3470.87 No Offset Stations PB V Pad Plan V-01 (S-N) Plan V-01 V11 Plan: PI Out of range PB V Pad Plan V-112 (S-A) PlanV-112V1 Plan: PI Out of range PB V Pad Plan V-118 (N-X) Plan V-118 V3 Plan: PI 3729.17 5100.00 3113.19 109.31 3003.88 Pass: Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 3832.72 8150.00 5411.36 103.98 5307.38 Pass: Major Risk PB V Pad Plan V-204 (S-H) Plan V-204 OBd V1 Plan 6203.77 8650.00 1048.38 140.64 907.74 Pass: Major Risk PB V Pad Plan V-204 (S-H) Plan V-204L 1 OBb V1 PI 6077.62 8550.00 997.54 134.50 863.04 Pass: Major Risk PB V Pad Plan V-204 (S-H) Plan V-204L2 OBa V1 PI 6070.43 8550.00 982.78 135.98 846.80 Pass: Major Risk PB V Pad Plan V-204 (S-H) Plan V-204L3 OA V1 Pia 5963.72 8450.00 946.17 135.17 811.00 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 6808.02 11494.72 1164.43 191.22 973.21 Pass: Major Risk PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI 5562.46 12725.31 4265.46 182.03 4083.42 Pass: Major Risk PB V Pad Plan V-21 0 (N-G) - w Plan V-210 V2 Plan: PI 3790.58 4800.00 2692.24 111.61 2580.63 Pass: Major Risk PB V Pad Plan V-211 (N-C) - w Plan V-211 V1 Plan: V Out of range PB V Pad Plan V-211 (S-Q) - s Plan V-211 V1 Plan: PI 3736.44 3800.00 951.58 86.79 864.79 Pass: Major Risk PB V Pad Plan V-212 (S-D) Plan V-212 VO Plan: V Out of range PB V Pad Plan V-213 (S-W) Plan V-213PB1 V3 Plan: 3749.99 3750.00 0.55 68.46 -67.91 FAIL: Major Risk PB V Pad Plan V-214 (N-R) Plan V-214 V3 Plan: V Out of range PB V Pad Plan V-216 (N-T) Plan V-216 V4 Plan: PI 3731.12 3800.00 1081.76 104.04 977.73 Pass: Major Risk PB V Pad Plan V-2a06 (N-M) Plan V-2a06 VO Plan: V 3729.95 4200.00 1471.36 104.92 1366.45 Pass: Major Risk PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P 3735.22 4050.00 1464.20 105.58 1358.62 Pass: Major Risk PB V Pad V-02 V-02 V10 3775.89 6050.00 3834.92 51.58 3783.34 Pass: Major Risk PB V Pad V-03 V-03 V7 3784.02 4950.00 2381.43 51.76 2329.67 Pass: Major Risk PB V Pad V-100 V-100 V7 3737.81 4900.00 2046.51 88.72 1957.78 Pass: Major Risk PB V Pad V-101 V-101 V7 Out of range PB V Pad V-102 V-102 V5 3800.39 4950.00 2711.00 96.21 2614.79 Pass: Major Risk PB V Pad V-103 V-103 V6 3768.98 3850.00 890.53 93.85 796.68 Pass: Major Risk PB V Pad V-104 V-104 V13 3806.50 7850.00 5967.61 84.66 5882.95 Pass: Major Risk PB V Pad V-105 V-105 V13 3728.48 4300.00 1317.75 80.19 1237.56 Pass: Major Risk PB V Pad V-106 Plan V-106A V5 Plan: P 3768.93 4150.00 1418.70 96.92 1321.78 Pass: Major Risk PB V Pad V-106 V-106 V10 3716.88 3950.00 970.53 90.32 880.20 Pass: Major Risk PB V Pad V-107 V-107 V5 3789.67 6400.00 4265.44 63.55 4201.88 Pass: Major Risk PB V Pad V-108 V-108 V7 Out of range PB V Pad V-109 V-109 V2 3752.93 4750.00 1955.71 64.78 1890.93 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 3752.93 4750.00 1955.71 64.78 1890.94 Pass: Major Risk PB V Pad V-109 V-109PB2 V2 3752.93 4750.00 1955.71 64.78 1890.93 Pass: Major Risk PB V Pad V-111 V-111 V25 7159.35 8350.00 2858.59 64.76 2793.83 Pass: Major Risk PB V Pad V-111 V-111PB1 V8 3766.53 5650.00 3321.93 51.73 3270.19 Pass: Major Risk PB V Pad V-111 V-111PB2 V2 3766.53 5650.00 3321.93 51.74 3270.19 Pass: Major Risk PB V Pad V-111 V-111PB3 V6 3736.01 5550.00 3222.78 50.96 3171.81 Pass: Major Risk PB V Pad V-113 V-113V6 Out of range PB V Pad V-114 V-114 V5 Out of range PB V Pad V-114 V-114A V4 4534.50 11100.00 5588.80 99.03 5489.77 Pass: Major Risk PB V Pad V-114 V-114APB1 V4 Out of range . Schlumberger Anticollision Report . Company: BP Amoco Date: 6/21/2004 Time: 16:00:03 Page: 2 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Plan V-213 (S-W), True North Reference Well: Plan V-213 (S-W) Vertical (TVD) Reference: V-213 Plan SoW 82.8 Reference Wellpath: Plan V-213 Db: Sybase Summary <:---------------- Offset Wellpath ---------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB V Pad V-114 V-114APB2 V2 4238.21 10677.00 5577.72 95.65 5482.07 Pass: Major Risk PB V Pad V-115 V-115V5 3741.94 5000.00 2793.23 83.41 2709.81 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 3741.93 5000.00 2793.23 83.41 2709.82 Pass: Major Risk PB V Pad V-117 V-117V9 3716.49 6800.00 5139.99 104.41 5035.58 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 3716.49 6800.00 5139.99 104.41 5035.58 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 3716.49 6800.00 5139.99 104.41 5035.58 Pass: Major Risk PB V Pad V-119 V-119 V13 Out of range PB V Pad V-201 V-201 V8 Out of range PB V Pad V-202 V-202 V9 3791.73 5350.00 2809.24 83.56 2725.68 Pass: Major Risk PB V Pad V-202 V-202L 1 V5 3797.93 5400.00 2814.36 83.02 2731.34 Pass: Major Risk PB V Pad V-202 V-202L2 V5 3716.87 5450.00 2817.07 81.84 2735.23 Pass: Major Risk . . (Plan V-213PB 10 Field: Prudhoe Bay Site: PB V Pad Well: Plan V-213 (S-W) Wellpath: Plan V-213 0 2?1 ~ --- ~ '------- / ---- 180 2N Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre SeparatIOn [100ft/in] (S-W) 270 -294 200 00 -0 00 200 -294 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 "Mastercard Check" 89-6/1252 120 DATE Olo,;<9-0Lf ¡pee, $ 100.00 7J rJD DOLLARS -({))Ii.e ~ ~. . I: ;¡. 2 5 2000 ¡; 0 I: ~ ~ ;¡. ~ III ¡; 2 2 7 II' ;¡. 5 5 ¡; lie O;¡. 20 . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME {-?t5¿¡ tI~2/3/" PTD# 20~- //b HOLE In accordance with 20 AAC 25.005(f), an records, data and Jogs acquired for tbe piJot bole must be clearJy differentiated In both . Dame ,,(Dame on permit plus PH) ~ ~~~<,) and API number (SO~CJ~- 70/80) from records, data and Jogs acquired for we)) (name on permit). Development ;>< Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dumber last two (2) digits are between 60-69) x PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Exploration Stratigraphic "CLUE" The permit is for a new weHbore segment of existing wen Permit No, API No. Production. should continue to be reponed as a function 'of the original API Dumber. stated above. 2. 3::L8- :::>d' The permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of It conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception thJit may occur. An dry ditcb sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals througb target zones. . . o o Well bore seg Annular Disposal - Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN V-213i ._ Program SER PTD#: 2041160 Company ßP EXPLORATION (ALASKA) INC _ Initial Classrrype SER /1WINJ GeoArea Unit On/Off Shore On Administration 1 Permitfee attaçhe~t · Yes - - - - - - 2 Leasen!Jmber .apRrORriate. . . · Yes 3 .U.n[q!Je WellJ1ame .and lJ~mb.er . . . . . . . . . . . . . . . . . . . . . . . . . ........ Yes - - - - - - - - - - - - - - - - - - -- . .. .. . 4 WellJQcated in.ad.efjned.pool . . - - - - - - - Yes I: WelUQc¡¡¡ted prpper distance from driJling unitbound.acy. . · Yes Well IQcated proper distance. from Qtber welJs Yes - - - - - 7 .S.utfiçient açrea~e.aYailable indJilIiog unit. · Yes 8 ((deviated, Js. weJlbQre platincJuded . Yes 9 Opecator onl)' affected party. . . · Yes 10 .Opecator bas.appropriate.bond inJorce . . . . . . . . . . . . . . . . . . . . . ....____Yes - - - - - - - - - - - - - - - - - - -- . .. .. . 11 Permit c.an be iss~ed wJtbQut co-"Servation order. . Yes Appr Date 12 Permitc.an be iss~ed wjt!JQut ac{ministcatilleappr~>val . Yes RPC 6/29/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQcated within area and. strata .authorized by.lojectioo Order it (puUO# in.CJ:>r:nmeots) (FOL Yes .A.IP2.4. 15 .All welJs.withinJl43uile.area.of reyieW jdelJt[fied (For&ervJcewell onlYL . . . . . . . . . . . . . . Y.es '.O'.J;. . . . . . . . . . . . . . . . .. . '. . 16 PJe-produ~ed injector; duratioRof pre-production les!> than 3 months. (For service well QnJy) . . NA - - - - - ;..;.;;;,. _ _1'7 .AÇMPFJnding .of CQnsi$teOGyh.as beeni&sued. for tbis pr.oiect NA Engineering 18 .C.oodu.ctor stcingpJQvided . . . Yes 20ux34u@114'.. ... 19 S.uct'ace.casing.protec.ts alLknown USDWs . . . Yes 20 .CMT vol adeq~ateJo çirc.ulate. on .conduçtoc 8. surtcsg . · Yes .A.de~uate excess, . 21 CMT vol adeqL!ate. to tie-inJQng .string tos!Jrf çsg. . No - - - - - - 22 .CMTwilJ Gover aU klJownpro.ductiye bQri;zon.s. - - - - . . .Y.es 23 .C.asiog designs ac{eQua.te fpr C,T. B.&p.erroafrost · Yes - - - - - 24 Adequatetankage.oJ re.serve pit. - - - - -- .Yes '.ab.ors.9ES. - - - - 25 JtaJe-drilt basa. 10~4.03 for abandon.me.nt beelJ apPJQved . . . .NA '.ewwell, . 26 AdequateweUbore!>eparatjo.npro-posed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes - - - - - - - - - - - - - - - - - - - * 27 Jfdjver:!er Jeq.\.lired, dQes it meet reguJations. . · Yes Appr Date 28 .DJilliog fJuid Rrogram sGhematic.& eq.uip listadequ¡¡¡te. · Yes Max MW9)~_ RP9· . WGA 6/29/2004 29 .BPPEs, do they meet reguJation . Yes 30 .B.o.PEpress ratiog ap-propriate;.lest to (put PSig in.comments). . · Yes Test tp 4000. RSi. MSfl1676 psi. 31 C.hokell1anifold çompJies w/API Rf>-53 (May 84) . Yes 32 WQrk will pcc.ur without.operatjon .shutdQwn. . . · Ye$ 33 Is Rresence Qf H2S gas. RrQbable. . - - - - - · N.o Nolan H2S pac{. . 34 MeçlJanical.C9lJdit[on of wells wLthin .A.OR yerifiec{ (for. service wel) Qn-'y) . · .Yes '.o well$ wjtbilJ AOR. - Geology 35 P~rmit. c.ao be LSSL!ed wle. hydr.ogen. s.ulfide meaSjJres. . - - - - - - - · Yes 36 .D.ata. PJeseoted on. Rote.ntial overpressure .zone$ . .NA Appr Date 37 .SeLsmicanalys.is. Qf shaJlow gasz.ooes NA - - - - - RPC 38 .SeabedcondjtjolJ survey (if Qff-sh.ore) . NA 39 . çQnta.ct namelp/loneJorweekly prpgressreRorts [exploratocy .only] · NA Geologic Engineering !j Commissioner: Date: Commissioner Date ; ;0o" fi~~ Db ~/<9\/f-