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Home My WebLink About209-1161a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 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: 52.8' 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" X-65 176' 9-5/8" L-80 3028' 7" L-80 5136' 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 9645' / 4755', 9806' / 4839', 9979' / 4933' 5720' - 10130'3-1/2" 9.2# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 422 sx Class G 42" 31' 5417'829 sx AS Lite, 417 sx Class G 260 sx Arctic Set (Approx.) 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 3/26/2022 4900' FSL, 1532' FEL, Sec. 11, T11N, R11E, UM, AK 33' FSL, 1825' FEL, Sec. 36, T12N, R11E, UM, AK 209-116 / 322-079 Schrader Bluff Oil Pool, Orion Dev Area 81.3' 5482' / 3052' Prudhoe Bay Field / HOLE SIZE AMOUNT PULLED 50-029-23417-00-00 PBU V-227 590767 5970150 897' FNL, 1767' FEL, Sec. 01, T11N, R11E, UM, AK CEMENTING RECORD 5974974 SETTING DEPTH TVD 5975904 BOTTOM TOP 8-3/4" 176' 12-1/4"31' CASING WT. PER FT.GRADE 595750 595680 TOP SETTING DEPTH MD 31' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 28' DEPTH SET (MD) 9125' / 4483', 9493' / 4675, PACKER SET (MD/TVD) Packers continued: 129.45# 40# 31' 28' 10332' Gas-Oil Ratio:Choke Size: See Attached 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 N/A DIR / GR, DIR / GR / RES / NEU / AZI DENS, Cement Evaluation Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 11/12/2009 11/1/2009 ADL 028240 & 028238 00-001 1750' (Approx.) N/AN/A None 10340' / 5141' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 2:00 pm, Apr 07, 2022 Abandonded 3/26/2022 MDG RBDMS 4/7/2022 MDG xGDLB 04-27-2022 DSR-4/11/22MGR30AUG2022 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 9228' 4536' 5354' 3005' 8692' 4276' 8775' 4315' 8884' 4365' 9046' 4443' 9178' 4510' 9228' 4536' 9264' 4555' 9285' 4565' 9395' 4623' 9456' 4655' 9579' 4721' 10163' 5036' SBB/CM 10163' 5036' 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 NA Schrader Bluff NB Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Ugnu MC Ugnu MA Ugnu MB1 Ugnu 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. Schrader Bluff NE Formation at total depth: Ugnu MB2 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 NF Schrader Bluff OA Schrader Bluff OB Schrader Bluff Base / Colville Schrader Bluff NC 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 4.7.2022Digitally 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: 2022.04.07 13:21:30 -08'00' Monty M Myers WELL NAME: V-227 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 3073' Pull Tubing 5720' Set CIBP 5592' 12 Bbls Cement 5580' - 5582' Casing Punch 5503' Set Cement Retainer 5500' 20 Bbls Cement 5482' Set Whipstock ACTIVITYDATE SUMMARY 1/11/2022 T/I/O = SI/0/0. Temp = SI. PPPOT-IC (PASS), PPPOT-T (PASS). Pre RWO. PPPOT-IC: Stung into test port (0 psi), bled void to 0 psi. Monitor for 10 min (0 psi). Pressured void to 3550 psi for 30 min test, lost 100 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 3-3/4", all moved freely. Re-torqued gland nuts and LDS to 450 ft/lbs. Pumped hyd oil across test void to opposite port, good returns. Pressured void to 5050 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi, RDMO. 3/21/2022 Set 4" CTSHBPV, Verify 0 psi on THA. N/D tree, (***SBMS stayed in THA***). Clean void, inspect TBG HGR neck and lift threads. Install CTS plug, R/U test sub and test equipment. Test CTS plug to 4000 psi for 10 min. good test. R/D test equipment and bleed off pressure, R/D test sub. Function ULDS. 4 1/2" out. Install new R54. S/B for BOP N/U & Test.... Daily Report of Well Operations PBU V-227 Activity Date Ops Summary 3/20/2022 PJSM Spot, set, shim break shack, enviro vac & warm up shack. Lay Herculite and cutting box. Hook up all interconnects in utilidoors and mud lines in pits. Supply air & steam to pits, pump room and untilidoors. Begin working on rig acceptance checklist. Safe out stairs and walkways. Swap to gen power at 04:00. Daily Disposal to G&I = 61 bbls, total = 61 bbls. Daily H2O from Lake 2 = 0 bbls total = 0 bbls. Daily Metal: 0 lb. Total Metal 0 lb. 3/21/2022 PJSM Cont steam & H2O around rig. Scope up derrick and bridal down. Hang rig tongs & secure derrick. Install cellar grating and safe out well/ walking area around sub. Finish rig acceptance checklist. Spot Beyond MPD system & R/U. Load 4" D.P. in pipe shed. R/U MP's & Pits. Rig accepted at 10:30. PJSM P/U R/U HP hoses and 1502 components to Circ out Diesel FP through 3.5" 9.2# L-80 TCII Tubing out IA back to cutting box. Heat soap pill in pits. Check well Press Tub: 100 psi, IA 0 psi, OA psi. Fill choke line to Gas Buster U Tube. SIMOPS: Cont loading 4" D.P. PJSM Pump through bleeder on rig floor. Shut master valve on tree and test line to 250/1000 psi, good. Line up to pump down tubing and take returns to IA to Gas Buster. Pump 40 bbls heated BaraKlen pill followed by 201 bbls 9.3 ppg QuikDril 2 bpm ICP 34 psi stage up to 4 bpm FCP 88 psi. Shut down monitor well 10 min, Tub 0 psi, IA 0 psi OA 0 psi. Blow down lines. Clean out Gas Buster. PJSM Remove tree cap. Vault rep set BPV. Break flange bolts on tree. Remove tree and aside in cellar. Install CTS and tested to 4,000 psi as per Vault rep. Remove 1502 companion flange F/ choke line. PJSM Install DSA and 2' spacer spool. P/U stack and set on spacer spool. Install and Trq bolts on stack, DSA and spacer spool. Secure stack W/ chains and turn buckles. R/U Choke and kill lines. R/U Beyond 4" hard lines W/ Beyond rep. Install drip pan. SIMOPS Stage 4" handling Equip on rig floor. PJSM Line up on kill line and PT MPD Equip 250/ 1,250 psi, good. Open RCD grey clamp, pull MPD test cap and install RCD riser. Close and tighten grey clamp. Inflate air boot. PJSM R/U test Equip. Vac out stack. Mark Test jnts UPR & LPR. P/U M/U 4" Test jnt, X/O, side entry sub, 4" TIW & Dart. Flood surface Equip and purge air. Perform shell test 250/ 3,000 psi, good. PJSM Perform BOPE test W/ 4" test jnt to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-3,11-15, 4" Dart, 4" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, Super Choke and manual to 2,000 PSI, Upper and lower VRB Rams (2.875" X 5.5") Blind Rams & Annular. Checked PVT sensors and return flow. Witnessed by AOGCC Rep Guy Cook. P/U M/U 3.5” test Jnt. Daily Disposal to G&I =0 bbls, total = 61 bbls. Daily H2O from Lake 2 = 580 bbls total = 580 bbls. Daily Metal: 0 lb. Total Metal 0 lb. 3/22/2022 PJSM Perform BOPE test W/ 3.5" test jnt to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 4-10, 4" Dart, Upper and lower VRB Rams (2.875" X 5.5") Blind Rams & Annular. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Koomey draw drown Initial System 3,000 PSI, Manifold 1,550 PSI, Annular 1,250 PSI, after System 1,500 PSI, Man 1,500 PSI, Annular 1,200 PSI. 200 PSI increase 28 Sec, full charge 99 sec. Nitrogen 6 bottle average 2,325 PSI. Bled down Accumulator to 0 psi and verify bank bottles charged to 1,000 psi. Witnessed by AOGCC Rep Guy Cook. P/D test Equip. L/D 3.5" test jnt. Break out 4" TIW, 4" Dart, Side entry & X/O. Break out test sub to TD. Blow down all surface Equip. Stage Weatherford 3.5" handling Equip on rig floor. C/O elevators to 4" D.P.. PJSM P/U Tee Bar and remove CTS plug. Pull BPV as per Vault rep onsite. P/U 4" XT39 D.P. and M/U XT39 X 4.5" TCII X/O. M/U to hanger and top drive. BOLDS. Open annulus and unseat hanger. Observed no over pull and free with 52k hook load. P/U 5' and line up to Circ. Pump 34 bbls heated soap pill followed by 9.3 ppg brine 295 gpm 340 psi R/F 36%. Observed 646u gas at BU dropping to 49u BGG. SIMOPS Cont P/U R/U Weatherford 3.5" tools and Equip. Shut down and monitor well 10 min, static. Pull tubing hanger to rig floor L/D. Blow down. PJSM POOH L/D 3.5"9.2# L-80 TCII kill string F/ 3,070' to surface. P/U 46k SLK 48k. Lost 4 bbls for trip. PJSM R/D Weatherford tools & Equip. L/D power tongs. C/O Elevators to 4" D.P. Bring up scrapper and BHA components. PJSM P/U M/U 6- 1/8" Bit TirCone, 7" Scraper and Bit Sub (no float). X/O. PJSM Install Wear ring (7" ID, 10.75" OD, 12' Lgt) Single in hole Scrapper BHA W/ 4" 14# S-135 XT39 D.P. F/Surface to 5723' md, Drift 2.346" OD. P/U 90K, S/O 63K. Wash down at 2 bpm from 5710' md to 5723' md. Tag top of 3.5" tubing cut @ 5723' md, set down 5 K to confirm. Circulate out contaminated 9.0 ppg brine, displace well with 9.3 ppg brine. Stage pumps up to 300 gpm, 1180 psi while reciprocating pipe. Reciprocate scraper across CIBP setting depth from 5720' md to 5679' md. R/F = 34%, Max Gas = 548u. Dumped 93 bbl of contaminated 9.0 ppg brine/crude. BGG 89u. No losses while circulating. Monitor well for 10 min prior to pulling out of the hole (static). PJSM. Pump 20 bbl 9.8 ppg dry job. Blow down top drive. Pull out of the hole from 5679'md to 5615' md. P/U 90K, S/O 63K. Cont pull out of the hole from 5615'md to surface. P/U 90K, S/O 63K. Lay down casing scraper BHA. No wear observed on casing scraper. Service rig and perform derrick inspection. PJSM. Spot AK E-line unit. Rig up E-line sheaves to topdrive and beaver slide. Run E-line through sheaves. Make up CCL assembly on E-line. (1.6875" Wt bar, CCL/ TitanPerf 3.13" 11.08' Length) RIH W/ CCL at 350 ft/min to 5,100' ELM 140 ft/min to 5685' ELM. Log up at 80 ft/min 360# to 5,442' ELM. Log down 80 ft/min to 5,712' MD showing collar of 7". POOH. Daily Disposal to G&I =57 bbls, total = 118 bbls. Daily H2O from Lake 2 = 290 bbls total = 870 bbls. Daily Metal: 1 lb. Total Metal 1 lb. 3/23/2022 Cont. to pull out of the hole with CCL log to surface. Break down logging tool and rig down sheaves. P/U CIBP and X/O to 4" dp. RIH with the CIBP at 90 fpm per baker rep from surface to top of 3.5" tubing stub at 5723' md, P/U 84k, S/O 68K. Tag top of tubing stub with 2k. Set CIBP per Baker procedure. P/U stretch plus 5'. Rotate 10 turns to engage CIBP slips. S/O to setting depth at 5722' md. Top of CIBP at 5720' md. P/U 25K over to 109K to set CIBP. S/O 25K under to 40K to confirm set. P/U to 86K and rotate 10 turns to release from CIBP. Set back 1 stand to 5682' md and Pressure test top of CIBP to 500 psi for 5 min (Good). POOH from 5682' md to surface. lay down CIBP running tool. PJSM R/U Weatherford handling Equip. C/O elevators to 3.5" YC 75T. P/U M/U 3.5" L-80 EUE cement stinger Assy to 557' MD. Trq EUE 3,150 ft/lb. M/U X/O and Cont RIH W/ 4" D.P. F/ derrick F/ 557' to CIBP at 5,721' MD W/ 2k tag. P/U 80k SLK 67k. PJSM R/U 1502 & HP line to cement line. P/U string to 5,715' MD. Circ at 4 bpm 300 psi R/F 23%. Mas Gas 481u. P/U 80k SLK 67k. PJSM, Pump balanced plug. Wet lines w/ 5 bbls H2O (HES) and P/T low kick out 938/ 3,925 psi high. Wet cement at 22:50. Cement job as follows: 12 bbls 15.8 ppg Lead cmt, 1.53 yld (63sx) 1.45 bpm ICP 160 psi FCP 138 psi. Displace w/ 5 bbls H2O (HES) 1.7 bpm ICP 67 psi FCP 54 psi. Turn over to rig. Rig disp w/ 50.8 bbls 9.3 ppg Brine 3 bpm ICP 57 psi slowed to 1 bpm last 2 bbls FCP 81 psi. CIP 23:39 hrs. Full returns throughout job. Shut down open string and appears out of balance, bled back about 2.5 bbls. PJSM Verify no flow, static out of string. R/D cement lines & Equip. POOH L/D 2 jnts and rack back 4" D.P. F/ 5,715' to 5,223' MD Pull speed 7 ft/min. String started U Tubing appears to be out of balance. Circ Surf to Surf dumped 13.5 bbl contaminated brine. Break out and drop 4" wiper ball Circ Surf to Surf. 420 gpm 1,150 psi R/F 43%. Monitor well 10 min, static. PJSM POOH racking back 4" D.P. F/ 5,223' MD to 1,565' MD. Went to Phase 2 weather conditions at 03:14. Working at a reduced rate to reduce incident. Went to Phase 3 at 04:51. Shut down all operations due to weather. Daily Disposal to G&I =5 bbls, total = 123 bbls. Daily H2O from Lake 2 = 200 bbls total = 1070 bbls. Daily Metal: 1 lb. Total Metal 1 lb. 50-029-23417-01-00API #: Well Name: Field: County/State: PBW V-227A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska Cement job as follows: 12 bbls 15.8 ppg Lead cmt, 1.53 yld (63sx) 1.45 bpm ICP 160 psi FCP 138 psi. Displace w/ 5 bbls H2O (HES) 1.7 bpm ICP 67 psi FCP 54 psi. Turn over to Top of CIBP at 5720' md. scraper across CIBP setting depth from 5720' m 3/24/2022 Continue to wait on weather due to Phase 3 conditions. Perform hazard hunts. Work on hitchly paperwork/inspections. Phase 3 conditions lifted to Phase 2 field wide at 10:09. Continue to pull out of the hole with 4" DP from 1565' MD to the top of the 3.5" tubing cement stinger at 561' MD. Working at a reduced rate to reduce incident. Rig up Weatherford casing tongs and Lay down 3.5" tubing cement stinger from 561' MD to surface. Hole took proper displacement. R/D Weatherford casing equipment. Demob from floor. R/U 4" dp handling equipment. Clean and clear rig floor. M/U 6-1/8" Milltooth (Smith XR+PS, 3 x 14's), Bit sub (no float), XO sub. Single in with 6x jts 4" HWDP - Total length = 190.94'. Single in F/ 191' - T/ 4445' MD. Continue trip in out of derrick F/ 4445' - T/ 5358' MD. Wash down F/ 5358' to tag depth @ 5380' MD. 2x tags w/ 5k set dn. Drill cmt F/ 5380' - T/ 5600' MD. 300 gpm, 60 rpm, 4-5k torque, 3K WOB. P/U 90K, S/O 64K, ROT 70K. Circulate 1.5X bottoms up with 400 gpm, 1850 psi, 60 rpm, 4-5k torque. Ream up to 5484' MD while circulating. Monitor well for 10 min prior to pulling out of the hole (static). POOH from 5484' MD to surface. Break out bit, bit sub and crossover. Bit grade 1-0-WT-A-E-I-NO-LOG Rig up E-line sheaves and Packoff on 7-5/8" dutch riser. P/U E Line Perf BHA (3 7/8" Roller Boogey 2', Perf Carrier Perf Gun 2' 6 shots per ft 0.5" hole 3 1/8" OD 9', CRCCL 3.13" OD 5.03', 3 7/8" Roller Boogey 2' & Cable Head 1.44" OD 1.05') Shot placement CCL TOS 11.1', BOS 3.3'. PJSM RIH W/ E Line 33'0 ft/min to 4,800', 122 ft min to 5,300 ft/min slow to 60 ft min to TOC @ 5,592.4' ELM. P/U 485# SLK 65#. Correlate pass F/ 5,592' to 5,337.1' ELM 75 ft/min correlation adjustment 2' from prior CCL. RIH to 5,592.4' P/U to 5,568.9' CCL placing TOS at 5,580' BOS 5,582' ELM. P/U 445#. Discharge perf gun, no visual sign at surface. Monitor well 10 min on choke, no press. Open choke and monitor for flow static. 0 pressure observed on the OA. POOH W/ E Line F/ 5,568.9' at 330 ft/min. Lay down perf guns and stand back lubricator with packoff. All Perf guns discharged downhole. Fluid pack lines, close blind rams and open to choke manifold. Perform injection test. Pump at .5 bpm to 700 psi, observed slight breakover at ~450 psi, continue to pressure up to 700 psi. Shut down pump monitored pressure. Pressure decreased to 280 psi in 3 min. Beed pressure to 0. Attempt injection test again with .25 bpm. Observe slight breakover at ~450 psi, continued to pressure up to 800 psi. Shut down pumps and monitored pressure. Pressure decreased to 500 psi in 5 min. Bleed pressure to 0 and monitor well for 10 min (static). 0 Pressure observed on OA during inj tests. Rig down E-line dutch riser, packoff, and sheaves. Make up 7" cement retainer assembly on 4" DP. RIH from surface to 2500' MD. RIH at 90 fpm per Baker procedure. Daily Disposal to G&I =67 bbls, total = 190 bbls. Daily H2O from Lake 2 = 220 bbls total = 1290 bbls. Daily Metal: 0 lb. Total Metal 1 lb. 3/25/2022 RIH from 2500' MD to set depth at 5503' MD. RIH at 90 fpm per Baker procedure. Final P/U 108K, S/O 57K. Set cement retainer per Baker procedure. P/U 4'. Rotate 10 turns to engage retainer slips. S/O to setting depth at 5503' MD. Top of CIBP at 5501' MD. P/U 32K over to 140K to set CIBP. S/O 23K under to 35K. Work pipe between 140k and 35k 2 more times to confirm set. P/U to 78K and rotate 10 turns to release from retainer. Sting out of retainer, circulate at 3 bpm, 140 psi to confirm circulation and fluid pack lines. Pressure test top of retainer to 500 psi for 5 min (Good). Space out and install headpin in DP. Rig up cement lines to headpin. Establish injection with rig pumps. Pump at .25 bpm, observe pressure breakover at 764 psi, inject 1.2 bbl after breakover at .25 bpm max pressure 790 psi. PJSM with HES cementing crew. Unsting from retainer. Fluid pack lines. Pressure test cement lines to 970 psi low and 3900 psi high for 5 min each (test good). Line up to pump cement. Pump 5 bbl fresh water ahead 20 bbl of 15.8 ppg class G cement and 5 bbl fresh water behind 1.75bpm 168psi. Line up with rig pumps and displace with 28 bbl of 9.3 ppg brine at 3 bpm 110 psi. Wet cmt @ 10:29. Sting into cement retainer. Inject 22 bbl (15.2 bbls cement out perfs to open hole) at .25 bpm, observe pressure break over at 500 psi, pressure continued to climb slowly to 1640 psi. Observe hard break at 1640 psi after 5.6 bbls injected and pressure decrease to 1360 psi before stabilizing. Continue pumping @ .4 bpm, 1440 final psi. Shut down and allow psi to drop to 1015 psi before trend slowed over 3 min. P/U and dump psi while shifting retainer closed (well static). CIP @ 12:42. B/D cmt equipment. Pump out of hole @ 1/4 bpm, 6.5 fpm pulling speed laying 1 bbl cmt on top of retainer (~5475') Rack back 1x stand and L/D 10' pup jt to 5428' MD. Drop wiper ball and circulate 1-1/2 Btm's up @ 11.5 bpm, 1640 psi, 15 rpm, 4.5k tq. Observed residual cement back at surface, dumped 21 bbls. B/D top drive, monitor well (static). B/D kill and choke lines. POOH F/ 5428' - T/ surface. L/D retainer running tool. Clean and clear rig floor. Mob BHA tools to floor. M/U Cleanout BHA. 6.125" mill tooth tricone bit, bit sub, watermelon mill, and XO to 4" HWDP. RIH on 4" DP from top of BHA to 5236' MD. P/U 98K, SO 60K. Hold Well control trip drill and AAR with rig crew. Perform rig maintenance and inspections while WOC. Slip and cut drill line. Service rig. Wash down at 1 bpm, 30 psi from 5236' MD to 5463' MD. Tag TOC with 5K at 5463' MD. Increase flow rate to 300 gpm, 1100 psi and engage rotary at 50 rpm, 4.5k torque. Drill cement from 5463' MD to 5500' MD (1' above retainer) with up to 1K WOB. Circulate bottoms up. 415 gpm, 1990 psi. Observe slight amount of cement at shakers during bottoms up. Engage pumps at 1 bpm, Tag TOC with 10k. Line up and Pressure test cement X 7" casing to 2000psi for 30 min (Good test). Pump in 1.6 bbl / Bleed back 1.6 bbl. Tag TOC after pressure test with 10K. AOGCC rep Guy Cook on location to witness tag and test. Displace well to 9.25 ppg Baradril-N. 475 gpm, 2000 psi, 30 rpm, 4K torque. Obtain SPR's. Blow down standpipe and monitor well (static). POOH from 5500' MD to 3600' MD. P/U 97K, S/O 63K. Daily Disposal to G&I = 292 bbls, total = 482 bbls. Daily H2O from Lake 2 = 0 bbls total = 1290 bbls. Daily Metal: 0 lb. Total Metal 1 lb. 3/26/2022 Continue to POOH from 3600' MD to surface. No wear observed on watermelon mill. Bit grade 1-0-WT-A-E-I-NO-BHA Clean and clear rig floor. M/U Whipstock assembly to total BHA length of 370' MD. P/U Joint of HWDP and M/U milling assembly. M/U TM, DM, Float sub and XO and scribe line. M/U whipstock with 25K shear bolt and anchor (11K shear on anchor). Scribe line and measure RFO = 4.25/1.32 = 110.11°. RIH with 7" whipstock and 6-1/8" window milling assembly on 4" DP from 370' MD to 5349' MD. RIH at 90 fpm per Baker rep. Shallow hole test MWD at 190' MD with 250 gpm, 535 psi (test good). Wash down F/ 5349' - T/ 5500' MD. 250 gpm, 930 psi, 30% F/O. 86k up, 60k dn. Orientate TF to 31° ROHS while washing down. Tag and set anchor on depth @ 5500' MD while holding 31° ROHS TF (TOW 5482', BOW 5495'). Saw bobble while slacking of to blk wt, indicate anchor set. Pick up to 100k with no break over to confirm anchor set (set good). Slack off to blk wt and P/U observing lug shear mills from whipstock. Free up wt 85k, 59k dn. Obtain parameters and begin milling operations F/ 5482' - T/ 5417' MD. 300 gpm, 1220 psi, 38% flow out, 100 rpm, 5.2k tq. 3 fpr F/ 5,482' to 5,495' MD observed minimal amount of cement at surface. Ream through BOW 5,495' to TOW 5,482' MD 2X Trq swing 3-8k first pass, smooth the second pass. Pump 25 bbl 9.3 ppg 250 vis sweep surf to surf, on time W/ ~3 lbs metal. Control drilling 8 ft/hr F/ 5,495' to 5,517' MD while milling with second 6.175" upper mill across slide.. Max Gas 208u. BGG 90-150u. Drilled 22' of new hole. Seen crude at surface during drilling. Observe 10 psi on OA. Circulate hole clean with 300 gpm, 1170 psi, Pump 25 bbl 9.3 ppg 250 vis sweep surface to surface, on time. No increase in cuttings and 11lb of metal back at shakers. Drift window 2X at full rotary and pumps with no issues. Shut off rotary and drift window with pump only, observe slight packoff at 5484' MD with full pump rate. Reduce pumps to 84 gpm and drift window with no issues. Appears mill may be balled up. Monitor well (static). R/U to perform FIT to 10.7 ppg EMW. M/U head pin and high pressure hose. Line up down drill string and kill line. Mud weight 9.3 ppg in/out. 3056' TVD, Pump .3 bbl at .25 bpm to 231 psi, hold for 10 min. Bleed off pressure (.3 bbl back) and send test chart with spreadsheet to DE for approval. AOGCC approved original surface casing LOT of 12.7 ppg EMW. Monitor well (static) POOH with 6.125" window milling assembly from 5452' MD to top of BHA at 352' MD. Rack back HWDP and L/D 6.125" Window milling BHA from 352' MD surface. Window mill 3/8" under and balled up with clay and rock, Lower mill 1/4" under no balling, upper mill in gage (6.151") no balling. Daily Disposal to G&I = 413 bbls, total = 895 bbls. Daily H2O from Lake 2 = 0 bbls total = 1290 bbls. Daily Metal: 60 lb. Total Metal 61 lb. Tag TOC after pressure test with 10K. AOGCC rep Guy Cook on location to witness tag and test. Displace well to 9.25 ppg Baradril-N. 475 gpm, 2000 psi, 30 rpm, depth at 5503' MD. Top of CIBP at 5501' MD. 20 bbl of 15.8 ppg class G cement and 5 bbl fresh water behind 1.75bpm Tag TOC with 5K at 5463' MD. test cement X 7" casing to 2000psi for 30 min (Good test). F (TOW 5482', BOW 5495'). STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UN ORIN V-227 JBR 04/01/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 3.5 and 4" test joints were used for testing. Test #2 the HCR Kill failed to hold on the low. The valve was serviced and retested for a pass. The recovery times of the accumulator system were as follows: Annular - 12 seconds, UPR - 10 seconds, Blinds (simulated with the UPR) - 9 seconds, LPR - 4 seconds, HCR Kill - 1 second, HCR Choke - 1 second. The charge bottles precharge was checked and the results were good. Out of 20 bottles none were out of compliance and ranged from 900 psi to 1000 psi. Test Results TEST DATA Rig Rep:M Vanhoose/A LeslieOperator:Hilcorp North Slope, LLC Operator Rep:J Lott/O Amend Contractor/Rig No.:Hilcorp Innovation PTD#:2091160 DATE:3/22/2022 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopGDC220321075808 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 1540 Sundry No: 322-079 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5.5" V P #2 Rams 1 Blinds P #3 Rams 1 2 7/8"x5.5" V P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 FP Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P28 Full Pressure Attained P99 Blind Switch Covers:PAll Stations Nitgn. Bottles (avg):P6@2325 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 9 9 9 9 9 9 9 9 FP Test #2 the HCR Kill failed to hold on the low. Annular - 12 seconds, UPR - 10 seconds, Blinds (simulated with the UPR) - 9 seconds, LPR - 4 seconds, HCR Kill - 1 second, HCR Choke - 1 second. 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: Innovation Rig Elevation: 26.5 ft Total Depth:5500 ft MD Lease No.: ADL 028240 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 176 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 5417 Feet Csg Cut@ Feet Intermediate: 7 " O.D. Shoe@ 8481 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3.5" O.D. Tail@ 10130 Feet Tbg Cut@ 5720 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Perforation Retainer 5503 ft MD 5500 ft MD 15.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing IA 2182 2157 2136 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Casing Removal: Oliver Amend Casing/Tubing Data (depths are MD): First tag was at 5500 ft MD with 10K down on the plug. Approxiamately 1 foot of cement on top of the retainer. Pressure test the 7" casing and it passed the 30 minute charted test. 1.62 bbls were pumped for the pressure test and 1.6 was recovered after the test was complete. Second plug tag produced the same results. March 26, 2022 Guy Cook Well Bore Plug & Abandonment PBU V-227 Hilcorp North Slope LLC PTD 2091160; Sundry 322-079 None Plugging Data: Test Data: P rev. 11-28-18 2022-0326_Plug_Verification_PBU_V-227_gc 9 9 9 999 9 99 9 9 9 9 9 9 9 9 9 9 First tag was at 5500 ft MD with 10K down on the plug. Second plug tag produced the same results. James B. Regg Digitally signed by James B. 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'65 %23(WHVWWRSVL$QQXODUWRSVL $2*&&WRZLWQHVVWDJDQGSUHVVXUHWHVWRIFHPHQWSOXJDW 0'WRSVL 0*50$5 GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.02 15:51:48 -09'00' RBDMS SJC 030322 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗sͲϮϮϳ ĂƚĞ͗ϮͬϭϱͬϮϬϮϮ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ Ϯ͕ϬϯϬƉƐŝΛΕϰϵϬϬ͛ds ;ŽǁŶŚŽůĞŐĂƵŐĞDtсϴ͘ϬϰƉƉŐͿ DĂǆŝŵƵŵǆƉĞĐƚĞĚ,W͗Ϯ͕ϬϯϬƉƐŝΛΕϰϵϬϬ͛ds ;Dtсϴ͘ϬϰƉƉŐͿ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐ͗ ϭ͕ϱϰϬƉƐŝ ;Ϭ͘ϭƉƐŝͬĨƚŐĂƐŐƌĂĚŝĞŶƚͿ DŝŶ/͗ϭ͘ϰϴϮ͟Λϱϳϰϵ͛D DĂǆŶŐůĞ͗ϳϭĞŐΛϯϬϰϴD ZĞĨĞƌĞŶĐĞ>ŽŐ͗>tZd'Z>ŽŐŽŶϭϭͬϭϮͬϮϬϬϵ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ sͲϮϮϳ͕ŝƐĂŶŝŶŽƉĞƌĂďůĞŝŶũĞĐƚŽƌƚŚĂƚƚĂƌŐĞƚĞĚŵƵůƚŝƉůĞůŽďĞƐŽĨ^ĐŚƌĂĚĞƌďůƵĨĨƐĂŶĚƚŚĂƚǁĂƐĚƌŝůůĞĚŝŶϮϬϬϵ͘sͲϮϮϳ͛Ɛ ƌĞƐĞƌǀŽŝƌǁĂƐŝƐŽůĂƚĞĚŝŶϮϬϭϭǁŝƚŚƚƵďŝŶŐƉƵŶĐŚĂŶĚĐĞŵĞŶƚƉƵŵƉĞĚŝŶƚŚĞϰͲϭͬϮƚƵďŝŶŐĂŶĚϰͲϭͬϮ͟ǆϳ͟ĂŶŶƵůƵƐ͕ dKƚĂŐŐĞĚǁŝƚŚĐŽŝůƚƵďŝŶŐĂƚϴϲϳϬ͛D͘ĐŽŝůŵŝůůǁĂƐƐƚƵĐŬŝŶϮϬϭϮĂŶĚůĞĨƚŝŶŚŽůĞ͘dŽƉŽĨĐŽŝůĨŝƐŚŝƐϱϳϰϵ͛D͘ dŚĞϰͲϭͬϮ͟ƚƵďŝŶŐǁĂƐũĞƚĐƵƚĂƚϱϳϮϬ͛DŝŶϮϬϭϵĂŶĚƌĞŵŽǀĞĚĨƌŽŵƚŚĞǁĞůůďŽƌĞ͘ϯͲϭͬϮ͟ŬŝůůƐƚƌŝŶŐǁĂƐƌĂŶ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ sͲϮϮϳŽŵďŽD/dƚĞƐƚĨĂŝůĞĚ;ϳͬϮϯͬϭϵͿǁŝƚŚĂ͘ϱŐĂůůŽŶƉĞƌŵŝŶƵ ƚĞĂƚϮϲϬϬƉƐŝ͘ KďũĞĐƚŝǀĞ͗ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐǁŽƌŬŝƐƚŽƌĞŵŽǀĞƚƵďŝŶŐ͕ƐĞƚ/W͕ƐƉŽƚĐĞŵĞŶƚĂŶĚƉƌĞƉĂƌĞƚŚĞǁĞůůƵƉĐŽŵŝŶŐsͲϮϮϳ ƌŽƚĂƌǇƐŝĚĞƚƌĂĐŬ͘ ^ƵŶĚƌǇWƌŽĐĞĚƵƌĞ ϭ͘Ϭ D/ZhΘdĞƐƚKW x ZĞƐĞƌǀŽŝƌĂďĂŶĚŽŶŵĞŶƚŚĂƐĂůƌĞĂĚǇďĞĞŶĐŽŵƉůĞƚĞĚŝŶϮϬϭϭ͘ ϭ͘ϭ͘ D/Zh/ŶŶŽǀĂƚŝŽŶ͘ŶƐƵƌĞƌŝŐŝƐĐĞŶƚĞƌĞĚŽǀĞƌǁĞůůŚĞĂĚƚŽƉƌĞǀĞŶƚĂŶǇǁĞĂƌƚŽKWŽƌ ǁĞůůŚĞĂĚ͘ ϭ͘Ϯ͘ ZhƚŽƉƵŵƉĚŽǁŶƚƵďŝŶŐĂŶĚƚĂŬĞƌĞƚƵƌŶƐĨƌŽŵ/ƚŽĂƚĂŶŬ͘WƵŵƉĂƚůĞĂƐƚϭƚƌƵĐŬŽĨƐĞĂǁĂƚĞƌ ǁͬƐŽĂƉĨŽůůŽǁĞĚďǇƐƉĂĐĞƌĂŶĚϵ͘ϮƉƉŐďƌŝŶĞ͘ ϭ͘ϯ͘ &ůŽǁĐŚĞĐŬǁĞůůƚŽĞŶƐƵƌĞĨůƵŝĚƐĂƌĞďĂůĂŶĐĞĚ͘ ϭ͘ϰ͘ /ŶƐƚĂůůWs͕EͬƚŚĞƚƌĞĞ͘/ŶƐƚĂůůƚĞƐƚĚĂƌƚŝŶƚŚĞWs͘sĞƌŝĨǇůŝĨƚŝŶŐƚŚƌĞĂĚƐĂƌĞŐŽŽĚĂŶĚĐŚĞĐŬ yKĨŽƌůĂŶĚŝŶŐũŽŝŶƚ͘ŽƵŶƚƚƵƌŶƐŝŶƚŽŚĂŶŐĞƌ͘ ϭ͘ϴ͘EhϭϯͲϱͬϴ͟ǆϱDKWĂƐĨŽůůŽǁƐ͗ x KWĐŽŶĨŝŐƵƌĂƚŝŽŶĨƌŽŵƚŽƉĚŽǁŶ͗ϭϯͲϱͬϴ͟ǆϱDĂŶŶƵůĂƌͬϭϯͲϱͬϴ͟ǆϱDĚŽƵďůĞŐĂƚĞͬϭϯͲ ϱͬϴ͟ǆϱDŵƵĚĐƌŽƐƐͬϭϯͲϱͬϴ͟ǆϱDƐŝŶŐůĞŐĂƚĞ x ŽƵďůĞŐĂƚĞƌĂŵƐŚŽƵůĚďĞĚƌĞƐƐĞĚǁŝƚŚ ϮͲϳͬϴ͟ǆϱͲϭͬϮ͟sZƐ ŝŶƚŽƉĐĂǀŝƚǇ͕ďůŝŶĚƌĂŵŝŶ ďŽƚƚŽŵĐĂǀŝƚǇ͘ x ^ŝŶŐůĞƌĂŵĐĂŶďĞĚƌĞƐƐĞĚǁŝƚŚ ϮͲϳͬϴ͟ǆϱͲϭͬϮ͟sZƐ x EhďĞůůŶŝƉƉůĞ͕ŝŶƐƚĂůůĨůŽǁůŝŶĞ͘ x /ŶƐƚĂůů;ϭͿŵĂŶƵĂůǀĂůǀĞΘ,ZǀĂůǀĞŽŶŬŝůůƐŝĚĞŽĨŵƵĚĐƌŽƐƐ͘;DĂŶƵĂůǀĂůǀĞĐůŽƐĞƐƚƚŽŵƵĚ ĐƌŽƐƐͿ͘ x /ŶƐƚĂůů;ϭͿŵĂŶƵĂůǀĂůǀĞŽŶĐŚŽŬĞƐŝĚĞŽĨŵƵĚĐƌŽƐƐ͘/ŶƐƚĂůůĂŶ,ZŽƵƚƐŝĚĞŽĨƚŚĞŵĂŶƵĂů ǀĂůǀĞ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗sͲϮϮϳ ĂƚĞ͗ϮͬϭϱͬϮϬϮϮ ϭ͘ϵ͘ZhDWZĂŶĚƌĞůĂƚĞĚĞƋƵŝƉŵĞŶƚ ϭ͘ϭϬ͘dĞƐƚKWƚŽϮϱϬͬϯ͕ϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ x dĞƐƚǁŝƚŚϰͲϭͬϮ͟ĂŶĚϯͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ x ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐǁŝƚŚWd x ŶƐƵƌĞƚŽŵŽŶŝƚŽƌƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐĂŶĚĂŶŶƵůƵƐǀĂůǀĞƉƌĞƐƐƵƌĞ ŐĂƵŐĞƐƚŽĞŶƐƵƌĞŶŽ ƉƌĞƐƐƵƌĞŝƐƚƌĂƉƉĞĚƵŶĚĞƌŶĞĂƚŚƚĞƐƚƉůƵŐ x KŶĐĞKWƚĞƐƚŝƐĐŽŵƉůĞƚĞ͕ƐĞŶĚĂĐŽƉǇŽĨƚŚĞƚĞƐƚƌĞƉŽƌƚƚŽƚŽǁŶĞŶŐŝŶĞĞƌĂŶĚĚƌŝůůŝŶŐ ƚĞĐŚ ϭ͘ϭϭ͘ZKWƚĞƐƚĞƋƵŝƉŵĞŶƚ͘WƵůůƚĞƐƚĚĂƌƚĂŶĚWs͘ ϭ͘ϭϮ͘Dŝǆϵ͘ϮƉƉŐĨůƵŝĚ͘ ϭ͘ϭϯ͘^ĞƚǁĞĂƌďƵƐŚŝŶŐŝŶǁĞůůŚĞĂĚ͘ ϭ͘ϭϰ͘/ĨŶĞĞĚĞĚ͕ƌĂĐŬďĂĐŬĂƐŵƵĐŚϰ͟WŝŶĚĞƌƌŝĐŬĂƐƉŽƐƐŝďůĞƚŽďĞƵƐĞĚǁŚŝůĞĚƌŝůůŝŶŐƚŚĞŚŽůĞ ƐĞĐƚŝŽŶ͘ dĞƐƚKWƚŽϮϱϬͬϯ͕ϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗sͲϮϮϳ ĂƚĞ͗ϮͬϭϱͬϮϬϮϮ Ϯ͘Ϭ WƵůůdƵďŝŶŐ^ƚƌŝŶŐ͕^Ğƚ/W Ϯ͘ϭ͘ ZhƚƵďŝŶŐŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚ x dƵďŝŶŐŝƐϯͲϭͬϮ͟ϵ͘Ϯη>ͲϴϬdͲ// x dƵďŝŶŐĚĞƉƚŚ͗ϯϬϳϯ͛D Ϯ͘Ϯ͘ WhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚĞŶŐĂŐĞƚƵďŝŶŐŚĂŶŐĞƌ Ϯ͘ϯ͘ ĂĐŬŽƵƚůŽĐŬĚŽǁŶƐĐƌĞǁƐ Ϯ͘ϰ͘ WƵůůƚƵďŝŶŐŚĂŶŐĞƌǁŝƚŚůĂŶĚŝŶŐũŽŝŶƚͬǆŽƚŽƚŚĞƌŝŐĨůŽŽƌ͕ŚĂǀĞĂƉƉƌŽƉƌŝĂƚĞƉƌŽƚĞĐƚŽƌƐƌĞĂĚǇ͘ Ϯ͘ϱ͘ /ĨŶĞĐĞƐƐĂƌǇ͕ĐŝƌĐƵůĂƚĞĂƚůĞĂƐƚϭ͘ϱǆhĂĨƚĞƌƉƵůůŝŶŐƚŚĞŚĂŶŐĞƌƚŽƚŚĞĨůŽŽƌ͘/ĨĚĞƐŝƌĞĚ͕ĐŝƌĐƵůĂƚĞ ĂƐŽĂƉƐǁĞĞƉƐƵƌĨĂĐĞͲƚŽͲƐƵƌĨĂĐĞƚŽĐůĞĂŶƚŚĞƚƵďŝŶŐ͘ Ϯ͘ϲ͘ WKK,ůĂǇŝŶŐĚŽǁŶϯͲϭͬϮ͟ƚƵďŝŶŐ Ϯ͘ϳ͘ ZĐĂƐŝŶŐĞƋƵŝƉŵĞŶƚ͘ Ϯ͘ϴ͘ dŚĞůĂƐƚsͲϮϮϳŽŵďŽD/dƚĞƐƚĨĂŝůĞĚ;ϳͬϮϯͬϭϵͿǁŝƚŚĂ͘ϱŐĂůůŽŶƉĞƌŵŝŶƵƚĞĂƚϮϲϬϬƉƐŝ͘^ƵƐƉĞĐƚ ůĞĂŬƚŽďĞĂƐƐŽĐŝĂƚĞĚǁŝƚŚƚŚĞƐƚƵĐŬĐŽŝůŵŝůůďŚĂ͘/WǁŝůůďĞƌƵŶƚŽŝƐŽůĂƚĞƚŚĞůĞĂŬ͕ĂŶĚ ĐĞŵĞŶƚƉƵŵƉĞĚŽŶƚŽƉ x ƚƚŚĞƚŝŵĞŽĨƚŚŝƐWdƐƵďŵŝƐƐŝŽŶ͕ϳ͟ƌƵŶƚĂůůǇŚĂƐŶŽƚďĞĞŶůŽĐĂƚĞĚ͘/ŶŽƌĚĞƌƚŽ ĚĞƚĞƌŵŝŶĞĐĂƐŝŶŐĐŽůůĂƌůŽĐĂƚŝŽŶ͕Ă>ǁŝůůďĞŶĞĞĚĞĚ͘ Ϯ͘ϵ͘Z/,ǁŝƚŚĐůĞĂŶŽƵƚĂƐƐĞŵďůǇŽŶϰ͟WĂŶĚĐůĞĂŶŽƵƚƚŽƚŚĞƚƵďŝŶŐƐƚƵď͘ Ϯ͘ϭϬ͘ ƐƐƵŵŝŶŐŶŽ>ŚĂƐďĞĞŶůŽĐĂƚĞĚ͕ZhĞͲůŝŶĞĂŶĚƌƵŶ'Zͬ>ƚŽƚƵďŝŶŐƐƚƵď͘dŚĞ>ĐĂŶďĞ ƌƵŶŽŶƚŚĞƐĂŵĞƌƵŶĂƐƚŚĞ/WŝĨĚĞƐŝƌĞĚ͘ŝƐĐƵƐƐǁŝƚŚĚƌŝůůŝŶŐĞŶŐŝŶĞĞƌ͘ Ϯ͘ϭϭ͘ ZƵŶĂĂŬĞƌ,ƵŐŚĞƐ/WĂŶĚƐĞƚΕϱ͛ĂďŽǀĞĂĐĂƐŝŶŐĐŽůůĂƌ͕ĂƚΕϱϳϬϬ͛D͘ŽŶĨŝƌŵƐĞƚĚĞƉƚŚ ǁŝƚŚĚƌŝůůŝŶŐĞŶŐŝŶĞĞƌĂŶĚǁŚŝƉƐƚŽĐŬĐŽŵƉĂŶǇƌĞƉ͘/WĐĂŶďĞƌƵŶŽŶWŽƌĞͲůŝŶĞ͘ x ϯͲϭͬϮ͟ƚƵďŝŶŐƐƚƵďĂƚϱϳϮϬ͛D Ϯ͘ϭϮ͘ ZĞͲůŝŶĞ͘ Ϯ͘ϭϯ͘ Z/,ǁŝƚŚĐĞŵĞŶƚƐƚŝŶŐĞƌŽŶϰ͟W Ϯ͘ϭϰ͘ WƵŵƉϭϮďďůƐŽĨϭϱ͘ϴĐůĂƐƐŐĐĞŵĞŶƚŽŶƚŽƉŽĨ/W x ϭϮďďůƐŽĨĐĞŵĞŶƚŝƐΕϯϬϬ͛ŽĨϳ͟ĐĂƐŝŶŐǀŽůƵŵĞ x K'ZĞŐƵůĂƚŝŽŶϮϱ͘ϭϭϮ;ĐͿ;ĞͿƌĞƋƵŝƌĞƐϳϱ͛ŽĨĐĞŵĞŶƚŵŝŶŝŵƵŵ x WůĂŶǁŝůůďĞƚŽĚƌŝůůƵƉĐĞŵĞŶƚƚŽǁŝŶĚŽǁĚĞƉƚŚ͕ůĞĂǀŝŶŐϮϬϬ͛ĐĞŵĞŶƚƉůƵŐŽŶƚŽƉŽĨ /W Ϯ͘ϭϱ͘ WKK,ǁŝƚŚĐĞŵĞŶƚƐƚŝŶŐĞƌƚŽĂďŽǀĞdK;ΕϱϰϬϬ͛Ϳ͕ĐŝƌĐƵůĂƚĞĂƚŚŝŐŚƌĂƚĞĂŶĚƉƵŵƉŶĞƌĨďĂůůƚŽ ĐůĞĂŶĚƌŝůůƐƚƌŝŶŐ Ϯ͘ϭϲ͘ WKK,͕ƌĂĐŬŝŶŐďĂĐŬϰ͟ĚƉ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗sͲϮϮϳ ĂƚĞ͗ϮͬϭϱͬϮϬϮϮ Ϯ͘ϭϳ͘ DhĐůĞĂŶŽƵƚ,͕ƚƌŝĐŽŶĞďŝƚ͕Z/,ĂŶĚƚĂŐĐĞŵĞŶƚ Ϯ͘ϭϴ͘ ƌŝůůĐĞŵĞŶƚĂŶĚĚƌĞƐƐŽĨĨƚŽΕϱϱϬϬ͛D Ϯ͘ϭϵ͘ ZhĂŶĚdĞƐƚϳ͟ĐĂƐŝŶŐ x dĞƐƚϳ͟ĐĂƐŝŶŐƚŽϮϬϬϬƉƐŝ͕ĨŽƌϯϬŵŝŶƵƚĞƐ͕ĐŚĂƌƚƚĞƐƚ͘ŶƐƵƌĞƌĂŵƐĂƌĞƵƐĞĚƚŽƚĞƐƚ ĐĂƐŝŶŐĂƐƉĞƌK'/ŶĚƵƐƚƌǇ'ƵŝĚĂŶĐĞƵůůĞƚŝŶϭϳͲϬϬϭ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ $2*&&WRZLWQHVVWDJDQGSUHVVXUHWHVWWRSVLRIFHPHQWSOXJDW 0' tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗sͲϮϮϳ ĂƚĞ͗ϮͬϭϱͬϮϬϮϮ ƐƵŝůƚ^ĐŚĞŵĂƚŝĐ͗ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗sͲϮϮϳ ĂƚĞ͗ϮͬϭϱͬϮϬϮϮ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ͗ tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗sͲϮϮϳ ĂƚĞ͗ϮͬϭϱͬϮϬϮϮ /ŶŶŽǀĂƚŝŽŶKW^ĐŚĞŵĂƚŝĐ͗ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SL1NORv wm I nPPRATIl1Wc 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Subsidence Evaluation 21 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 209-116 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 21 6. API Number: 50-029-23417-00-00 7 Property Designation (Lease Number): ADL 028240 8 028238 8. Well Name and Number: PBU V-227 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth: measured 10340 feet Plugs measured 8670, 10117 feet true vertical 5145 feet Junkmeasured 5749,10245 feet Effective Depth: measured 8670 feet Packer measured 9125, 9493, 9645, 9806, 9979 feet true vertical 4270 feet Packer true vertical 4478, 4671, 4750, 4835, 4928 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 145 20" 31-176 31 -176 Surface 5386 9-5/8" 31 -5417 31 -3032 5750 3090 Intermediate Production 10304 7" 28-10332 28-5141 7240 _` Liner i('i E E�� Perforation Depth: Measured depth: 9226-10032 feet V L ��T 2019 True vertical depth: 4540-4967 feet �1 AOGCC Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 26- 3073 / 5720 - 10130 26 - 2199 / 5141 - 5022 Packers and SSSV (type, measured and 3-1/2" HES Dual Feed Packer x5 9125, 9493, 9645, 9806, 9979 4478, 4671, 4750, 4835, 4928 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-BDI Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In Subsequent to operation: Shut In 14. Attachments (required per20 MC 25.070.25.071, &25 283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if CO. Exempt: 3N,,l33 3(9— Z1 r Authorized Name: Lastufka, Joseph N Contact Name: Ciolkosz, Ryan R Authorized Title: Speci is Contact Email: Ryan.Ciolkosz0bp.com Authonzed Signature: Date: Contact Phone: +1 907 564 5977 Form 10-404 Revised 04/2017 "f't 111f 1 ,.n Z4.ftm RBDMS ff NOV 0 5 2019 Submit Original Only 5/11/2019 T/1/0=500/0/300 LTT Master Valve PASSED ***WELL S/I ON ARRIVAL*** (jet cut) LOGGED 24 ARM PDS CALIPER FROM 5746' ELMD TO SURFACE 7/19/2019 ***CONT. ON 07/20/19 WSR*** ***CONT. FROM 07/19/19 WSR*** (gyro/jet cut) LOG GYRO SURVEY FROM SURFACE TO 5735'. 7/20/2019 ***JOB INCOMPLETE, CALLED OUT TO 02-02*** ***WELL SHUT IN ARRIVAL*** CUT 3-1/2" TBG WITH 2.70" JET CUTTER AT 5720'. VERIFY T/IA PRESSURE WHEN CUTTING, LOST 150 PSI AFTER CUT. 7/22/2019 ***JOB COMPLETE, WELL LEFT S/I*** T/1/0=72/365/335 Temp=Sl (LRS Unit 70 - CMIT-TxIA, Circ Out Post Jet Cut) CMIT TxIA FAILED @ 2608 psi Grease crew service WING valve Target psi 2500 Max applied 2750 Pumped 2.4bbls of 60* diesel down IA to reach test psi Equalize psi @ surface 1st 15mins TxIA lost 155/156 psi 2nd 15 mins TxIA lost 128/127 psi for total loss of 283/283 psi. Callculated LLR = .79 bbls / 60 min x 42 = .5 gpm LLR 7/23/2019 ***Job continued 07/24/19**** ***Job Continued from 07/23/19 *** (LRS Unit 70 - CMIT-TxIA, Circ Out Post Jet Cut) Pumped the following down the Tubing, taking returns out the IA to V -03's Flowline: 5 bbls 50.50 meth spear 294 bbls fresh water Swap to pump down the IA, taking returns up the Tubing to V -03's Flowline: 3 bbls 50/50 meth spacer 88 bbls Diesel freeze protect (T+IA). Let U -Tube for one hour. Freeze Protect V -03's flowline w/ 8 bbls 50/50 meth. Pressured FL to 1000psi. Fluid pack sign and FP/MIT tags hung. MV11A/OA=Open SV/WV/SSV= Closed 7/24/2019 FWHP's= 121/125/0 T/I/0= 0/010 (LRS Unit 46 - Test BPV- from Below) Pumped 1.59 bbls diesel down IA into tbg to achieve a test pressure of 967 psi. Held pressure for 5 min with no visible pressure increase on TBG. (SEE LOG FOR DETAILS) Bled IA to 11 psi recovering —1.3 bbls SV=C MV=O 9/16/2019 CV's=OTG Tags hung FWHP's= -3/101-10 TWO = Tac—/Vac/0. Pre AAO. RU Lubricator and PT to 350/3500. (PASS) Run down and set 4" HP-BPV #4-4. LTT (PASS) Remove upper tree and install Temp #29 as Dry Hole. Torque to API specs. PT against MV Gate to 350/5000psi (PASS) Remove 2" Tapped blind flanges from Working side IA and OA valves. Install 2" Integrol flanges onto IA and OA vavles. Torque to API specs. PT both to 2500psi (PASS). RDMO ***Job Complete*** SEE LOG FOR 9/16/2019 DETAILS Final T/I/O = BPV/0/0. T/I/O = BPV/Vac/0. Temp = SI. WHPs (Pre Rig). No AL, flowline or wellhouse. Dry hole tree. 9/20/2019 SV = C. MV = O. IA, OA = OTG. 02:30 Stand by for Parker 272 move to S -Pad. Then Nabors CDR2 move to DS 14 Then All 9/29/2019 American AAO -111 Stand by for Nabors CDR2 move to DS 14 Then All American AAO -111 - Perform maintinance 9/30/2019 on rig equipment - Clean up location for rig move. 10/1/2019 Continue on Stand by for Nabors CDR2 move to DS 14 Then All American AAO -111 Continue standing by Parker 272/CDR2 rig moves / Load truck and equipment and stage and J Pad access road do to power failure on west side of the field. Start moving operations at 19:00 10/2/2019 hrs from J -Pad to V -Pad - Stage rig mats, spacer spool and BOP'S behind cellar. Continue Rig Move. Install leveling pads to sub. Spot over well - Level derrick. Spot and connnect modules. Set and RU tanks and hardline for circ -out. Pull BPV. Hold a Rig 10/3/2019 Evacuation drill - Have a Pre Workover Meeting and a AAR. Load Silo # 1 with 280 bbls of 9.3 Daily Report of Well Operations PBU V-227 PTSM: Circulating out diesel, Pressure cross check list. Finish loading Silo # 1 with 280 bbls of 9.3 heated brine. Circulate out 88 blots of diesel and 207 bbls of 9.3 ppg heated brine. Set and test TWC from above/below. ND dryhole tree. NU BOPE. Chk, and Kill lines. MU 3-1/2" donut 10/4/2019 test A. Test BO per plan -witnessed by AOGCC rep Adam Earl. Continue BOP test per plan. Rig down test equipment. Blow down surface equipment. Rig up lubricator flange and pull TWC. Monitor well Rig up new riser and center BOP. Prep to trip pipe. Stand back 50 stds, LD the remaining tubing and I-Wire - Clamps. Install wear bushing. 10/5/2019 Rig up Wire line T/I/O=TWC/0/0. Pull plug for All American. Pulled 4" H TWC #294 @ 120". Job Complete. See 10/5/2019 log. Final WHP's 0/0/0. ***ALL AMERICAN III SUPPORT*** (Drift/Caliper/Gyro) DRIFT W/ 5.962" GAUGE RING TO 5710' ELM. RUN READ CALIPER SURVEY FROM 5700' ELM TO SURFACE. RUN GYRO DATA SURVEY FROM 5710' TO SURFACE. 10/6/2019 ***JOB COMPLETE ON 06-OCT-2019*** PTSM = Wire line log - Well control / Continue rigging up wire line. Log # 1 Gauge run to 5,710'. RIH with LOG # 2 and #3 Caliper log then GYRO log to 5710' AAO RKB (5757' Orig RKB). WC Drill w/ wireline in hole. RD EL. Pull wear bushing. Run tbg per plan to 3,073' Land hanger, RILDS, SET TWC and test. Blow down all surface equipment. ND BOPE, NU Dryhole 10/6/2019 tree. test hanger void/seals to 4500 psi 15 mins (PASS) Test tree 5000 psi/ 5 mins (PASS). Nipple down BOP's, Nipple up dry hole tree and test tubing hanger -Secure the tree and cellar / Release AAO-111 off V-227 at 0800 hrs 10/7/2019. Move sub to Peak to remove from trailer 10/7/2019 and remainder to 03-37. T/I/O=Vac/Vac/Vac Temp=S/1 (LRS Unit 46 - Circ in Diesel Freeze Protect) Pump the following down the IA: 87 bbls Diesel Freeze Protect U-Tube TAA for 1 hour. Well S/I upon departure. SV, MV=Closed CV=OTG 10/8/2019 FWHP=230/250/-10 T/I/O=TWC/0/0 Torqued Master valve x THA. RT( lubricator, PT'd against TWC 300/low..5000/high.. pass. see "Field Charted Tests" Pulled 4" CIW "H" TWC #439 through 10/8/2019 1 dryhole tree post AAO. FWP's 0/0/0 T/I/O=SI/0/0 Removed integral flanges from IA/OA instal blind flanges PT'd to 2500 PSI 10/22/2019 1 (PASSED) See log for details FWHP's=Sl/0/0 *** Job completed*** MVI SV=C AI/OA=OTG TREE = CNV WELLHEAD = FMC ACTUATOR= Note: Refer to Rrocimbon DB for historical perf data KB.ELEV= BF. ELEV = KOP= 63G49' Maz le = 71'Datum MD = 59'Datum TVD= 4 129.45#, X-65 \ WELDED, 1 5770 \�jl- 3-12• TBG, 9.2#, 3073' — L-80 TCI, ID = 2.992• 95/8' CSG, 40#, L-80 BTC, ID = 8.635" 5417 JET CUT TBG (0722!19) 5720' 7- CSG, 26#, L-80 TC11 XO TO L-80 BTC $q$1• TOP OF CEMENT (02108112) 8670'CTM- 1.560" TBG PUNCH (11/12111) 8840'- 8842'- 1-11/16' TBG PUNCH (1023111) 8$$8' - 8890' X 3-12" HES DUAL FEED THRU PKR, ID = 2.965" 9125• Minimum ID =1 A82" 5749' TOP OF COIL 3-12" PUP W RA TAG 9479' 342" HES DUAL FEED THRU PKR, O =2.965' 9493' T MARKER PUP w/RA 9632' 7'X3-12'HES DUAL FEED THRU PKR, D=2.965" 9645' - PERFORATION SUMMARY Rff LOG: LWD RT GR LOG ON 11/12/09 ANGLEATTOPFERF: 57° @ 9226' Note: Refer to Rrocimbon DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sgz SHOT SQZ 4-1/2" 5 Nb 9226-9252 O 1120/09 DMY 4-1/2" 5 OBa 9578-9632 O 11/12/09 DMY 4-1/2" 5 OBb 9660-9696 O 11/12/09 OMY 4-1/2" 5 OBd 9873-9960 O 11/12/09 OMY 4-1/2" 5 OBe 9992-10032 O 11/12/09 DMY 3-12" TBG, 92#, L-80 TC9, .0087 bpf, D = 2.992" 10130• - CSG, 26#, L-80 BTC, .0383 bpf, D=6.276• 10387 Vim" / SAFEfYNOTES: WELL REQUIRES A SSSV WHEN ON MI *** WELL ANGLE > 70 @ 3432'*** 3-12' WLEG, D =2.992" TOP OF COL TBG: 1.75" OD / 1.482' D (615/16) 4' X 1.00" E -UNE ANCHOR LOST N COL (1127114) i1 W!/6' I-� WL MLL STUCK N CMf (02/08/12) GAS LIFT MANDRELS ISTI MD 1TVDIDEVI TYPE I VLV LATCH PORT DATE 10 9096 4463 59 MMG OPE4 RK - 04/15/10 WATER NIFrrrrw MAk Y c ST MD TVD DEV TYPE VLV LATCH PORT DOTE 9 9189 4511 59 MMG DMY RK 0 01/31/10 8 9249 4542 59 MAG DMY RK 0 06/07/11 7 9557 4705 58 MMG DMY RK 0 01/31/10 6 9626 4741 59 MMG OMY RK 0 10/12/11 5 9677 4766 59 MNG OMY RK 0 01/31/10 4 9722 4790 59 MMG DMY RK 0 01/31/10 3 9870 4869 57 MMG DMY RK 0 01/31/10 2 9960 4918 57 MMG DMY RK 0 10/12/11 1 110048 4966 56 MNG I OMY I RK 1 0 10/12/11' 9139' J-13-12' NDPG N0.JLTI SU6, D=2.992" 916W 312'HESXNP,D=2.813' 95 J 112" NDPC MULTI SLD, D = 2.992" 952T 3 12' HES X NP, D = 2.813' �"" J 112" NDPG 111171 SIA, D = 2.992" """' _J 1i2'HESXNP,D=2.813' J 7" X 3-12" HES IX1AL FEED THRU R 9819' 3-12" NDPG MLTI SUB, D= 2.992" ""'� _J 112'HESXNP,D=2.813' 9979' 7'X 3-12' HES DUAL FEED THRU PK 9992' 312" NDPG SINGLE SUB, D =2.992" I� 10087172' 10108' 3-12'HESXNP,D=2.813' HES X NIP, D = 2.813" 3-i2• HES XN NP, D=2.750" 10117' 112" BKR QUIKOPoLL CBP(1023/11) 10130' 112"WLEG,D=2.992" DATE I REV BY I COMMENTS DATE REV BY COMMENTS 1123MB NSES ORIGINAL COWLE71ON 02/16RD PJC DRLG DRAFT CORRECTIONS 10N6/19 111 INTERVENTIONS RWO 10!09/19D DRLGCORRECTIONS jJ7NUJMD 11/04/19 CORRECTION TO COND DEPTH 11 ORION UNIT WELL: V 227 PERMrr No:2091160 API No: 50-029-23417-00 T11 N, R71 E, 380' FNL 8 1533 BP Exploration (Alaska) 2091 1s Date: 8/23/2019 3 1 0 p; Transmittal Number: 93703 BPXA WELL DATA TRANSMITTAL Enclosed are two (2) discs containing the information listed below. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendailgbD.com. SW Name API 02-02 500292007400 Date 7/27/2019 Com BPXA an Description COMPOSITED GYROSCOPIC SURVEY Disk Number 1 02-02A 500292007401 7/27/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 1 03-28 500292111400 7/24/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 1 04-01 500292007800 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 04-01A 500292007801 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 09-44 500292208700 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44A 500292208701 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44APB1 500292208770 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 V-227 500292341700 7/20/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 2 Please Sign and Email a copy of this transmittal to. GANCPDQnbp365 onmicrosoftcom Thank you, .viler Xendaff Subsurface Information Management AOGCC Department of Natural Resources ConocoPhillips Alaska, Inc. ExxonMobil, Alaska Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU V-227 Permit to Drill Number: 209-116 Sundry Number: 319-217 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Www. oogcc.alaska.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, oww/ Daniel T. Seamount, Jr. Commissioner 1 ti DATED this Z day of May, 2019. RBDMS±4j MAY 0 Z 2099 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25260 a a`a►'i�i b 6�6./ APR 2 5 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ °❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ®- Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well Cl Alter Casing ❑ Other Subsidence Evaluation 71 - 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 209-116 3_ Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service El 6. API Number: 50-029-23417-00-00 . 7. If perforating: What Regulation or Conservation Omer governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No ® PBU V-227 - 9. Property Designation (Lease Number): 10. Field/Pools ADL 028240 5 028238 PRUDHOE BAY, SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (h): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi)', Plugs (MD): Junk (MD): 10340 5136 8870 4261 1422 8670.10117 5749,10245 Casing Length Slze MD ND Burst Collapse Structural Conductor 145 20" 31-176 31-176 Surface 5386 9-5/8" 31-5417 31-3024 5750 3090 Intermediate Production 10304 7" 28-10332 28 - 5131 7240 15410 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 1 Tubing Size: Tubing Grace: Tubing MD (ft): 9226-10032 4530-4957 3-1/2" 9.2k L-80 1 26-10130 Packers and SSSV Type: 31/2" HES Dual Feed Packer x5 Packers and SSSV MD (ft) and ND (ft): 9125 / 4478, 9493 / 4671, No SSSV Installed 9645 / 4750, 9806 / 4835, 9979/4928 12. Attachments: Proposal Summary 0 Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ® Exploratory ❑ P ry Stratigraphic ❑ Development ❑ Service 0 14, Estimated Date for Commencing Operations: June 1, 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 herein will not Contact Name: Browning, Zachary H be deviated from without prior written approval. Contact Email: Zachary.BrowningLobp.com Authorized Name: MGaughlin, Sean M Contact Phone: +1 907 584 5220 Authorized Title: Engineering Team Lead - CTD Authorized Signature: �1/, Date 7 /2,S/ f q COMMISSION USE ONLY Conditions of approval: Notify Commission W that a representative may witness Sundry Number: -4 2 -1 PlugIntegrity "'-1 r ❑ BOP Test f� Integrity Test ❑ Location Clearance ❑ - Other: Other: �36PE-Te-ST -'"o r540 PS I Post Initial Injection MIT Req'd? Yes No ❑ RBDMS 1?MAY 0 2 2019 Spacing Exception Required? Yes ❑ No 12/ Subsequent Form Required: 10-401f 'A OF APPROVED BYTHE 9 Approved by: COMMISSIONER COMMISSION Date: Form 10-403 Revised 04/2017 ORIGINAL nteR2g,4Pk1J Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission 000 p From: Zach Browning 0 RWO/CTD Engineer Nkow Date: April 23, 2019 Re: V-227 Sundry Approval Well Type: Injector Current Status: The well is non-operable with TxIA communication. Request: Sundry approval is requested to pull tubing and perform subsidence surveillance on V-227. History and current status: V-227 was completed in 2009 but was never brought online due to a failed packer set. The first attempted cement squeeze failed to restore integrity. A second squeeze was attempted, which appeared to fix the integrity issue with a passing MIT -T and MIT -IA, however cement was left inside tubing. When the cement cleanout was attempted, the cleanout bha became stuck and -4500' of coil tubing was left inside the 3.5" tubing. Attempts were made to fish coil, with no ultimate success. No further intervention work is possible, and the best use of this wellbore will be a future sidetrack. Currently V-227 is proposed for subsidence evaluation. The well is currently offline, classified as "Non -Operable', due to TxIA communication. The tubing is filled with 9.6 ppg brine and 60/40 methanol. Proposed plan: The All American Oilfield 111 pulling unit will pull tubing and perform subsidence evaluation logging runs inside the production casing. MASP=1422 psi. AAO 111 BOPE will be configured as follows (BOP schematic attached for reference): • One Annular preventer • One Blind Ram -type preventer✓ • Mud cross with outlets for choke and kill lines • One Ram -type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low for all components. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of both the current and proposed wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to perform a subsidence evaluation of the wellbore with a calliper and logging suite ran inside the production casing. Pre -Ria Prep Work: 1. V: PPPOT-T, PPPOT-IC. Cycle LDS. 2. F: CMIT- TxIA to 3500 psi, OA Integrity test to 1200 psi. 3. E: Cut Tubing at -5700' MD 4. F: CMIT-TxIA. Circulate out well. 5. V: Install BPV. 6. O: Bleed WHP(s) to zero. Remove the well house and flow line. Install wellhead valves as needed. Install dry hole tree. Level the pad as needed for the pulling unit. Proposed RWO Procedure 2•/ i. 4,14--w �.,j�aGGC 1. MIRU. ND tree. NU and test BOPE. c 2. Pull 3-1/2" Tubing. 3. RU Eline and perform Subsidence evaluation logging runs inside z" Production casing. Calliper with GR/CCUTEMP and Gyro planned. CoAtp-e - '+W t wQ.lvd e_ ` CDF'1` C.E'^tMZ!1 f�/� S lg 4. Re -run 3-1/2" tubing to -3100' as a kill string. y 5. Freeze protect well. Set TWC. NO BOPE. NU and test tree. RDMO. Post rig Work: None planned. Zach Browning CC: Well File RWO/CTD Engineer Joe Lastufka 564-5220 TREE= aw I ND DEV WELLHEAD=�� VLV ILATCHIPORT /� SAFETYNOTES: WELL REQUIRES A SSSV WHEN 2 ACTUATOR= CLED 9189 ` ON MI ••• WELL ANGLE > 70 @ 3432"•' 103. BEV = 81.3' DMY RK _528 01131/10 8 992'BF'ELEV 4542 20 CONDUCTOR 14TKDP= 74-wrx3-ir-rxo,1D=2. RK 400 06107/11 X NP, D = 2813'129.45#, 1:4 9557 X-65 58 M G MaxAngle= 71'@3049 WELDED, 18.770 0 574W L TBG: 1.75' OD 11.482 DaWm M)= 59'9131' 4741 59 =7/14) Datum TVD441X7 SS RK Z? +. FISF4' X 1.00' E-LNE ANCHN OR LOST COL (112 9-Sr8' CSG, 400, L-80 BTC, D = 8 835F'l 541 T 8688' COL MLL STUCK N CMf (02f08112) 4766 59 MAG GAS LFT MANDRELS RK 0 01/31/10 ST MD 1 TVD DEV TYPE I VLV ILATCHIPORE DATE 7" CSG, 260, L-80 TC11 XO TO L -BO BTC 8481• 10 9096 4463 58 MMM OPEN RK - 04/15/10 DW RK 0 WATER PLIFI N MANDRB.S 1I.asv TBG PUNCH (11/12/11) H8840' -8842 1-11116" TBG PUNCH (1023111) 8888• - 8890' 2" HES DUAL F® 7HRU PKR D = 2.965' 9125' Minimum ID =1 A82" @ 5749• TOP OF COIL 17- X 3-12" FES DUAL F® THRU F10Z D = 2.965 7' MARKER FIPw/RA TAG ST ASD I ND DEV TYPE VLV ILATCHIPORT KFERVAL DATE 9 9189 4511 59 MAG DMY RK 0 01131/10 8 9249 4542 59 MM3 LAN RK 0 06107/11 7 9557 4705 58 M G DAM RK 0 01/31110 6 9626 4741 59 MAG DA7 RK 0 10/12/11 5 9677 4766 59 MAG CW RK 0 01/31/10 4 9722 4790 59 MAG DW RK 0 01/31/10 3 9870 4869 57 MMS DM RK 0 01/31/10 2 9960 4918 57 MAG DM W 0 10/12/11 1 110048149661 56 M.IG DM I Fd( 0 110112111 IE =:211-1i'� NDPG M/LTt SUB, D = 2.992" HES XHIP. D=2813" 952T 1-j3-12" FES X NP, D= 2813" ® 7'X3-12" FiES DUAL FEED PKR p= 2.985' 994$• f79653' 3-12• NDPG Mln SLAB, D = 2.992' W6431/2'F£S X NP, D = 2.813' PERFORATION SUMMARY Rff LOG: LWD RT GR LOG ON 11/12109 ANGLEAT TOP PERF: 57° Q 9226' Note: Refer to Production DB for historical perf data SIZE SPF ZONE KFERVAL Opn/Sgz SHOT SQZ 4-12' 5 W 9226-9252 O 112ow 01/01/16 TTWILH PKRSET 12/19/15 ( ) 4-12' 5 OBa 9578-9632 O 11/12/09 4-12• 5 OBb 9660-9696 O 11/12/09 4-1/2" 5 OBd 9873-9960 Q 11112(09 4-12" 5 OBe 9992-10032 O 1111209 17' CSC, 280, L-80 BTC, .0383 bpf, D = 6276' 1 9806' H7"X3-12"FESDUALFEEDT1MPKRD= 9819'3-1rr i49 NOPG MLLTI sus, D = 2.992" 9979' T X 3-1/2' FES FJt1AL F®TFRU FI(R D= 9992' H 3-1/2' NDPG SINGLE Sts. D = 2.992- I .992" 1 1002r I 1oo8r 3-12" FM XN►r D= 2.758" 3-12' BKR OUKDRLL CBP(11 3-12" ALEG, D = 2.992' FSI+ MILLED COM POSIT PLUG ORION UNIT VYELL: V-227 P844T ND: 1091160 AR N6: 50-029-23417-00 SEC 11, TI 1K RI IF- 380 FNL 8 1533' FEL DATE REV BY COMMENTS DATE REV BY I COA44NM 11/23109 NOES OTBGINALCOMPLEf10N 01/07/16 LAGJMD CHEMCUTODL FISH(011W16) 02f16110 PJC DRLGDRAITCOWRECTIONIS 05f17/16 CJMJA,D CHEMCUIFIERFTSH PULLED(1/11/16) 07/10/15 DLWJMC CHEM CUT COL. FISH (06119/15) 06IM16 CJNYJA,D PILLED FISH (0&05/16) 01/01/16 TTLYTLH SOOOPGII)ETAG (0922/15) 06109/16 CJWJMD WBS CLEANUP 01/01/16 NLWITLF SOOOPGI/DEPIL1JSET(12/14/15) BP 6rplora8on (Agaka) 01/01/16 TTWILH PKRSET 12/19/15 ( ) TREE = aw WELLHEAD= FIVIC ACRTATOR= 0� KB. E EV = 81.3' BF E -EV 52.8' 20' OOfDUCIOR KOP= 400' 129.450, X-115 N Angle - 71' @ 3049' Datum ND 59" 9131' �® D' 18.770 _-_.Da _ tum N - D= 4400' SS 9-518" CSG, 400, L-80 BTC, D 17" CSG, 260, L-80 TC11 XO TO L-80 BTC I V-227 ON MI * WELL ANGLE REQUIRES: WELL 70 @ 3432' **SSV WHEN i L 3100' 3 112^ TBG, 9 20, I -80 TOS U-2.991" 5749' TOPOFCq-TBG I.7S OD/1.482'D(6I5/16) ?? FISH 4- X 1.00" E -LM ANCHOR LOST N COIL (1127114) GAS LFT -6700 TV TM YM 8481 I /s1 0 9096 63 WATEINEl;TIIMIONENDRELHS1I �n 00/15110 TOP OF CEM34T (02/08/12)�- 8670' CTM 1.56(^ TBG PUNCH (11/12/11) H 8840' - 8842' 1-11/16^ TBG RMW (1023/11) 88 --8890' 2" FES DUAL F® TERN R<R, D= 2.965^ H 9125' Minimum ID =1.482" @ 6749' TOP OF COIL r RJPw/ RA TAG H 947V R< i, D = 2.965 PKR D=2.965^ 1-1 9645' PH1FORAT10N SUMIMRY REF LOG: LWD RT GR LOG ON 11/12/09 ANGLE AT TOP PERF: 57° Q 9226' Note: Refer to Roduction DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sgz SHOT SOZ 4-12" 5 Nb 9226-9252 O 11/20/09 Pot 4-12" 5 OBa 9578-9632 O 11112109 59 4-12' S OBb 9660-9696 O 11/12/09 7 4-12' 5 OBd 9873- 9960 O 11112/09 RK 4-12" 5 OBe 9992-10032 O 11/12109 59 920, L-80 TCI, .0087 bpf, D = 2.997 H 10130' �PB�-{ 10246' ST MD I ND I DEVI TYPE VLV ILATCHIPORT 112" FES X NP, D = 2.813" DATE 9 9189 4511 59 WTI' CMY Pot 0 01/31/10 8 9249 4542 59 NMG MAY RK 0 06/07111 7 9557 4705 58 WIG CAM RK 0 01/31/10 6 9626 4741 59 KM DUN RK 0 10112/11 5 9677 4766 59 NMC' OW RK 0 01131110 4 9722 4790 59 NII' CNN RK 0 01/31/10 3 9870 4869 57 NII' CMf RK 0 01/31/10 2 9960 4918 57 MVI' DW RK 0 10/12111 1 110048149661 56 1 A4V1(" I CMY RK 0 10/12111 91�-13-12" FDPC A.LLTI SUB, D = 2.992" 9159' 312' FES X NP, D ""D" _J 112" FOPC; MLT/ SUB, ID= 2.992" 952T 112" FES X NP, D = 2.813" 96ST H 112" PDPG MLT/ SUB. D = 112" FES X AP. D = 2.813" 9806' H T X 112' FES DUAL FEB) THRU R<R, D= 9819' 112" NDPG MLTI SUB, D = 2.997 9849' 112" FES X W. D = 2.813' LT X 112" FES DUAL F® THRU PKK D = 2.965- 3- irr .965"112" hDPG SINGLE SUB. D = 2.997 1002T -1112" FES X AP, D = 1008T 11/2' FES x M1P, D = 10108' 112" FES XN AP. D I 10260' 1 BKR C A<DF LL CBP WLEG, D = 2.99T OF40N UNFT WELL: V-227 POW No: '2091160 AR No: 50-029-23417-00 SEC 11, T11N, RIIF 380' FNL & 1533' R3- la01/01/16 DATE I REV BY I COWL NTS LATE REV BY ODWIENTS 1123109 NIIE5 JORIGIFALCOMPLEnON 01/07/16 LAC1J CFBVIOJTOOL FISH(01/06116) 02/16110 PJC ORLG DRAFT CORRErTWM 05117116 CIFYJWU CHEM CUTTER FISH PULLED (1/11/16) 07170115 W/J Q6N CUT COL RSH (06/19115) MPCGUIICETAG 06108116 CJMJWD RLL® RSH (06/05/16) 01101116 TrW" (0922/15) 06/09116 CIF4•JND WB.S CLEANUP 0-1/01/16NLWRL SCOOP GLIDE RLUSET(12114115) BP Exploration (Alaska) 01/01116 TTR/R-H PKR SET (12/19115) 1 2 3 4 41.211 G D G D '° A 3,_$15/16" SHENKAI SL 13-5M ANNULAR 6'-103/$' 3,_1„ a o SHENKAI SL 13-5M DOUBLE RAM El- B B 9--17/,61, 1,-4�8„ 11.0-.� 3�-2%'p 5'1/2c 1'-93/„ -�// C ; — G I o 10'-4" V-41/2 1,1/?MINOPEN o 0 D D DID VW 5'-3'/2' CLOSING / OPENNING VOLUME (GAL) 30° ITEMS CLOSING VOL OPENNING VOL ANNULAR 23.59 17.41 D RAM 4.39 3.91 D HCR 0.40 0.40 NOTES. THE CONTEMSOF THISOMWING PR BOP ME INFORMATION IN THIS ARETHE PROPERTY OF WESTERN ENERGY SEWMSCORP.ANY 13-5M BOP STACK DRAWING IS FOR REPRODUCTION OF THIS ElAERODWGNO A-000-15-002 REFERENCE ONLY FOR AND Is NOTCONSTRUCTION. DRAWING WITHOu THE EXPRESS PQtMISSIDNOFWESTERN 4`'^ -I - �U1Wxfen C° DRAWN TY DATE 2B/FGb/2018 SCALE N.T.S. WEIGHT REV 0 INITALREUF E TY MR Ot/Mer2018 CONSTRUCTION. ENERGYSERVICES CORP IS REV DESCRWTION BY APPD WlE APPROVED MJP DATE 01/M8f/2018 SIZE A SHEET i OF1 O STRICTLYPROHIBITED. 1 2 3 4 BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UN ORIN V-227 (209-116) PRUDHOE BAY, SCHRADER BLUF OIL Monthly Injection Rates 1,000,000 Cum. Inj Gas (mcf): L 0 100,000 L CL LL V 10,000 w m l7 w O Y d LL u 1,000 a V m m N 3 O t 100 H 0 --- Cum. Inj Liquid (bbls): 114,989 1,000,000 100,000 10,000 1,000 100 10 -I I 10 Jan -2010 Jan -2011 Jan -2012 Jan -2013 Jan -2014 Jan -2015 Jan -2016 Jan -2017 Jan -2018 Jan -2019 Jan -2020 - e Injected Gas (MCFM) --e— Injected Water (BOPM) S PREADS H E ET_2091160_PBU_V-227_P rod-Inject_Curves_W el I_0i I_V 120_20190429.x1sx 4/29/2019 STATE OF ALAS R ALASKA. AND GAS CONSERVATION COMMISSI110 E'VE REPORT OF SUNDRY WELL OPERATIONS DEC 2 2 2011 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 Other n CEMENT PACKER Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver❑ TirrAla s as COns. GQmfeSSIQf Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well [Anchorage 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ 209 -1160 r 3. Address: P.O. Box 196612 Stratigraphic Service el 6. API Number: • Anchorage, AK 99519 -6612 50- 029 - 23417 -00 -00 8. Property Designation (Lease Number) : , 9. Well Name and Number: ADLO- 028240 & 028238 V -227 10. Field /Pool(s): PRUDHOE BAY FIELD / ORION SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 10340 feet Plugs (measured) 10117 feet true vertical 5135.99 feet Junk (measured) 10245 feet Effective Depth measured 10246 feet Packer (measured) 9125. 9493 9645 9806. 9979 feet true vertical 5080.31 feet (true vertical) 4478 4671 4750 4835 4928 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" 129.45# X -65 30 - 147 30 - 147 Surface 5388' 9 -5/8" 40# L -80 29 - 5417 29 - 3024 5750 3090 Production 10306' 7" 26# L -80 26 - 10332 26 - 10332 7240 5410 Production Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ - True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 24 - 10130 24 - 5012 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" HES DUAL FEED THRU PKR 9125 4478 3 -1/2" HES DUAL FEED THRU PKR 9493 4671 3 -1/2" HES DUAL FEED THRU PKR 9645 4750 3 -1/2" HES DUAL FEED THRU PKR 9806 4835 3 -1/2" HES DUAL FEED THRU PKR 9979 4928 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 455 1,576 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service 151 . Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: _ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG 151 GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -288 Contact Joe Lastufka Printed Nam- se Lastu Title Petrotechnical Data Technologist Signatu Phone 564 -4091 Date 12/22/2011 Mi 1 Form 10-404 Revised 10/2010 RBDMS DEC 2 7 2011 l�L �L Submit Original Only / z /Z V -227 209 -116 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -227 11/20/09 PER 9,226. 9,252. 4,530.23 4,543.73 V -227 11/20/09 PER 9,578. 9,632. 4,715.4 4,743.46 V -227 11/20/09 PER 9,660. 9,696. 4,757.87 4,776.28 V -227 11/20/09 PER 9,873. 9,960. 4,870.93 4,918.04 V -227 11/20/09 PER 9,992. 10,032. 4,935.29 4,957.15 V -227 4/29/10 SQZ 8,947. 9,096. 4,390.82 4,463.04 V -227 6/14/10 BPS 10,108. 10,250. 4,999.71 5,082.66 V -227 6/8/11 BPS 9,527. 10,032. 4,688.58 4,957.15 V -227 6/9/11 BPP 9,527. 10,032. 4,688.58 4,957.15 V -227 10/14/11 BPP 10,108. 10,250. 4,999.71 5,082.66 V -227 10/23/11 BPS 10,117. 10,246. 5,004.86 5,080.31 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • V -227 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/14/2011; * * *WSR CONTINUED FROM 10/13/2011 * ** (cement squeeze) PULLED 3 1/2" PXN PLUG BODY @10,106' SLM/ 10,108' MD. 1 * ** *LEFT WELL SHUT -IN FOR SCHEDULED UPCOMING WELL WORK * * ** 10/22/2011' ** *"'WELL SHUT -IN UPON ARRIVAL * * ** (E -LINE SET PLUG AND SHOOT TUBING PUNCH) INTIAL T /I /O = XXX/150 /0 PSI RIG UP SLB EQUIPMENT AND BAKER PLUG. PT AND START RUNNING IN THE HOLE FINAL T /I /O = 500/150/0 PSI * ** *JOB CONTINUED ON 23 -OCT- 2011 * * ** 10/23/2011 ,****JOB CONTINUED FROM 22 -OCT- 2011 * * ** (E -LINE PLUG AND TUBING PUNCH) INTIAL T /I /O = 500/150/0 PSI SET 3.5" BAKER COMPOSITE PLUG MIDDLE ELEMENT AT 10118'. ;SHOOT TUBING PUNCH FROM 8888' -8890' FINAL T /I /O = 630/150/0 PSI * ** *JOB COMPLETE. NOTIFY DSO. LEAVE LOCATION * * ** 10/27/2011 T /I /0= 400 /440/Vac, Temp= SI Circ out (pre cement squeeze) Pumped 5 bbls neat ;spear followed by 15 bbls diesel down tubing taking returns up IA through jumper loop to well V -207. Unable to get rate. Job postponed. Freeze protect IA with 20 bbls , diesel. Notified Pad Op of well condition. FWHP's= 300/280/0. 11/12/2011 * ** WELL SHUT -IN ON ARRIVAL * ** (SLB E -LINE TUBING PUNCHER RECORD) INITIAL T /I /O = 250/200/0 PSI RIH AND SHOT TUBING PUNCHER FROM 8840' -8842' WITH 1.56" 20 DM PUNCHER CHARGES AT 4SPF. `CORRELATED TO SWS SCMT DATED 19- JUNE -2011. ~FINAL T /I /O = 200/200/0 PSI i * ** WELL SHUT -ON ON DEPARTURE * ** 11/13/2011' T/I/0= 124/100/0 Temp =SI Circ Well (Packer Squeeze) Pumped down Tbg taking 'returns up IA through hardline to well V -207 with 10 bbls MEOH followed by 175 bbls 'diesel followed by 3 bbls MEOH followed by 100 bbls inhibited H2O followed by 3 bbls MEOH followed by 36 bbls diesel. Bled TBGP /IAP back to initial pressures. FP ?jumper line with 10 bbls diesel. FWHP's= 56/100/20. DSO notified of job. WV, SSV, IA jumper, WV shut. IAV & OAV OTG. • • • 11/29 /2011 :Continued from WSR of 11/28/11. CTU 8, 1.75" coil. Job Scope: Cement squeeze packer leak. :Position coil unit. Raise mast. PT double barrier. N/U BOPE. Pick injecter and lubricator. M/U slick cementing nozzle BHA, PT lubricator. RIH w/ 1.75" cold roll CTC. Pull test 20K. M/U 2 stingers and 1.75" cementing nozzle. BHA tools: CTC 1.75 x .12' , Stinger 1.75 x 3.5' , Stinger 1.75 x 3.75, ;Cementing nozzle 1.75 x .58', BHA OAL = 7.96'. RIH, tag plug at 10108' . flag pipe @ 10098. Lay in 11 bbls mud pill to 8840'. Circ 10 bbls chemwash down CT and into IA. Circ well w/ warm diesel down coil returns from CTBS. Pump 6 bbls Squeezecrete :and 6 bbls 15.8 unislurry cmt down coil and lay in tbg. Crack IA and come online w/ ;pump down coil adn circ cmt into IA. pumped 10 bbls down coil shutin IA pumped ;remaining 2 bbls. Recovered 8 bbls in 40 bbls tank. Did not get pressure bump. pooh pumping pipe displacement w/ meth. TOC in 3 -1/2" tubing and annulus calculated at I8570'. «< Job Complete »> *well freeze protected with 37 bbls 60/40 meth* FLUIDS PUMPED BBLS 25 METH 353.3 DIESEL 102 INHIB. H2O 147 1% SKCL 97 60/40 METH 10 CHEMWASH 6 SQUEEZECRETE 6 15.8 UNISLURRY CEMENT 746.3 TOTAL TREE _ CM/ • SAFETY WELL REQUIRES A SSSV WHEN ON WELLHEAD= FMC V -227 M1. WELL GLE >70 @3432'. ACTUATOR = LEO , KB. ELEV = 81.3' BF. ELEV = 52.8' J 25' ,-14-1/2" X 3 -1/2" XO, ID = 2.992 "1 KOP = 400' 1 3927' H 3 -112" HES X NIP, ID = 2.813" I 1) Max Angle = 71 ° @ 3049' 20" CONDUCTOR, —I 147 Datum MD = 59° @ 9131' 129.45 #, X -65 GAS LIFT MANDRELS DatumTVD= 4400' SS WELDED, 18.770 ST MD TVD DEV TYPE VLV LATCH PORT DATE 19-5/8" CSG, 40 #, L -80 BTC, ID = 8.835" H 5417' 10 9096 4463 59 MMG OPEN RK - 04/15/10 WATER INJECTION MANDRELS I EST TOP OF CEMENT (11/29/11) H 8570' • - • ST MD TVD DEV TYPE VLV LATCH PORT DATE 17" CSG, 26 #, L -80 TC11 XO TO L -80 BTC H 8481' H- Oa♦i♦V t4 9 9189 4511 59 MMG -W DMY RK 0 01/31/10 $ ♦ ��4 8 9249 4542 59 MMG -W DMY RK 0 06/07/11 11.56" TBG PUNCH (11112/11) I-( $840' - $842' it ♦ • 7 9557 4705 58 MMG -W DMY RK 0 01/31/10 6 9626 4741 59 MMG -W DMY RK 0 10/12/11 1- 11/16" TBG PUNCH (10/23/11) 1--1 8888' - 8890' 5 9677 4766 59 MMG -W DMY RK 0 01/31/10 4 9722 4790 59 MMG -W DMY RK 0 01/31/10 X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" -9125' 3 9870 4869 57 MMG -W DMY RK 0 01/31/10 10108 ` 2 9960 4918 57 MMG -W DMY RK 0 10/12/11 Minimum ID = 2.75" o1 1 10048 4966 56 MMG -W DMY RK 0 10/12/11 3 -1/2" HES XN NIPPLE 9138' H3-1/2" NDPG MULTI SUB, ID = 2.992" I I3 -1/2" PUPw/ RA TAG 1-1 9479' I-- 9159' I- 13 -1/2" HES X NIP, ID = 2.813" I 17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" H 9493' :/ ►'2� r 9506' — I3 -1/2" NDPG MULTI SUB, ID = 2.992" J 17' MARKER PUP w /RA TAG I---I 9532' I- 4 ' 9527' — 13 -1/2" HES X NIP, ID = 2.813" 1 — 17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" I 9645' �1 ■∎/ II 9653' 1- I3 -1/2" NDPG MULTI SUB, ID = 2.992" ' 9664' I -13 -1/2" HES X NIP, ID = 2.813" RE I SUMMARY —' 9806' -17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" I REF LOG: LWD RT GR LOG ON 11/12/09 �/ ANGLE AT TOP PERF: 57° @ 9226' 1 9819' H3-1/2" NDPG MULTI SUB, ID = 2.992" I Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn /Sqz DATE I I 9849' 1-13 -1/2" HES X NIP, ID = 2,813" 4-1/2" 5 Nb 9226 - 9252 0 11/20/09 M 4 -1/2" 5 OBa 9578 - 9632 0 11/12/09 4 -1/2" 5 OBb 9660 - 9696 0 11/12/09 9979' -17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" I 4 -1/2" 5 OBd 9873 - 9960 0 11/12/09 .M4 4 -1/2" 5 OBe 9992 - 10032 0 11/12/09 il PP 9992' —13-1/2" NDPG SINGLE SUB, ID = 2.992" I I 10027' H3-1/2" HES X NIP, ID = 2.813" I 10087' - I3 -1/2" HES X NIP, ID = 2.813" I 10108' H3 -1/2" HES XN NIP, ID = 2.750" I 13-1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H. 10130' I 10117' 1-13-1/2" BKR QUIKDRILL CBP (101823111) ( PBTD I-1 10246' 10130' - { 3 -1/2" WLEG, ID = 2.992" I 17" CSG, 26 #, L -80 BTC, .0383 bpf, ID = 6.276" 10332' , 10250' H FISH- MILLED COMPOSIT PLUG (05/06/10) I ............ DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT' 11/23/09 N9ES ORIGINAL COMPLETION 12/16/11 SRD/ PJC TBG PUNCH )11/12/11) WELL: V -227 02/16/10 PJC DRLG DRAFT CORRECTIONS 12/16/11 RRWI PJC PKR SQZ (11/29/11) PERMIT No: 2091160 06/26/11 SEC/PJC WFR C/O (06/07/11) AR No: 50- 029 - 23417 -00 10/14/11 SWC/ PJC WFR C/O (10/12/11) SEC 11, T11 N, R11 E, 380' FNL & 1533' FEL 10/16/11 SWC/ PJC PULL PXN (10/14/11) 11/12/11 TTW/ PJC CBP/ TBG PUNCH (10/23/11) BP Exploration (Alaska) • • 8 Ifga taAsq(KA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Matt Brown Petroleum Engineer Y � - BP Exploration (Alaska), Inc. r I lb P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Orion Schrader Bluff Oil Pool, V -227 Sundry Number: 311 -288 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, G, Daniel T. Seamount, Jr. Chair DATED this 2;6 day of September, 2011. Encl. . -I` RECEIVED STATE OF ALASKA ,„ 2 d 2 2011., C2' ALASKA AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JAI & Gas Bans. Commission 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Changiintienigerogram ❑ Suspend ❑ Plug Perforations ❑ Perforate0 Pull Tubing ❑ T1me Extension ❑ ❑ Operation Shutdown ❑ Re - enter Susp. Well ❑ Stimulate Alter Casing l cr Other: PACKER REPAIR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 209 -1160 ^ 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23417- 00 -00. 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: V-227. Spacing Exception Required? Yes ❑ �/�NNoo ❑ 9. Property Designation (Lease Number): y . 10. Field /Pool(s): ADLO- 028240 � 't PRUDHOE BAY Field / ORION SCHRADER BLUFF Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10340 • 5135.99. 10246 • 5080.31' 10108 10245 Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" 129.45# X -65 30 147 30 147 Surface 5388' 9 -5/8" 40# L -80 29 5417 29 3024 5750 3090 Production 10306' 7" 26# L -80 26 10332 26 5131 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3 -1/2" 9.2# L - 80 24 10130 Packers and SSSV Type: 3 -1/2" HES DUAL FEED THRU PKR Packers and SSSV.NID annTVD (ft): 9125 4478 3 -1/2" HES DUAL FEED THRU PKR C M'lr Pac S .�� 9493 4671 3 -1/2" HES DUAL FEED THRU PKR 9645 4750 3 -1/2" HES DUAL FEED THRU PKR y' i,z3.1f 9806 4835 3 -1/2" HES DUAL FEED THRU PKR 9979 4928 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/5/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0- Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact MATT BROWN Printed Name , TT :, _ N Title PE ■ Signature /7,7, Phone Date 564 -5874 9/21/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 1 ' D a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test VI Location Clearance ❑ CO Other: y i . . Pax- ke- i ( TFC ') 7 ie 6 ,--. z 44c ZS 't(Z.. Subsequent Form Required: / O - o9 APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: r Py 4:::7 Jac. 11 � �DAAS P 2 8 2011 y`' -s. Form 10-403 Revised 1/2010 O R I G *,,,,,..71-4bmit in Duplicate I N A L V -227 209 -116 • PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -227 11/20/09 PER 9,226. 9,252. 4,530.23 4,543.73 V -227 11/20/09 PER 9,578. 9,632. 4,715.4 4,743.46 V -227 11/20/09 PER 9,660. 9,696. 4,757.87 4,776.28 V -227 11/20/09 PER 9,873. 9,960. 4,870.93 4,918.04 V -227 11/20/09 PER 9,992. 10,032. 4,935.29 4,957.15 V -227 4/29/10 SQZ 8,947. 9,096. 4,390.82 4,463.04 V -227 6/14/10 BPS 10,108. 10,250. 4,999.71 5,082.66 V -227 6/8/11 BPS 9,527. 10,032. 4,688.58 4,957.15 V -227 6/9/11 BPP 9,527. 10,032. 4,688.58 4,957.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • I • • Memorandum To: Tyler Noreme /Clark Olsen Date: September 6, 2011 GPB Well Ops Team Leaders From: Zach Doran, Petroleum Engineer Code: AORVPDWL27 Matt Brown, Intervention Engineer Subject: V -227 Packer Squeeze IOR: 400 Est. Cost: 1 S Dummy WFRs /Pull PXN/ 2 E Set Composite Plug /Punch Tubing 3 F MITT & Composite Plug 4 F Circulate Tubing & IA 5 C Packer Squeeze 6 D WOC 7 days. MIT -T & MITIA 7 S Drift/Tag 8 CP Mill Cement/Composite Plug- Pending Passing MITIA 9 D MITIA Current Status SI Injector Last Inj: 350 BWPD at 1800 psi WHIP Max Deviation 71° at 3049 ft Min ID 2.75" @ 11727' XN Nipple Last Tag: 10250' CTM 6- May -10 Mill composite plug, push to bottom Last Downhole Op: SCMT 19- Jun -11 Latest H2S value: No data available for well Highest H2S on Pad in 140 ppm on 3- Apr -11 in V -106 the past year SBHP/T @4400 SS 1812 psi / 81° ave for V- Pad from recent statics SBHP /T: 2086 psi / 85.7° at N sand gage at 9138' MD (4403' SS) Note: Sundry required for this work Program Objectives: The objective is to repair the packer and return the well to injection by pumping cement into the IA. Well History: V -227 was drilled in Nov -09 as an injector for the Schrader formation supporting the Nb, Oba, Obb, OBd and OBe sands. It was completed with 3 -1/2" tubing and five packers to provide isolation between the individual sands. I -wires and downhole pressure gages show realtime bottom hole pressure. The completion was run on 11/22- 23/09. While setting the packers, initial set pressure was 4500 psi as normal. Pressure in the annulus indicated a leak. Several attempts were made to reset packers, pressuring up tubing to 4700 psi, however, pressure kept leaking off, indicating a poor set. The top • • packer was determined to have failed. Downhole pressure gages indicate that the other packers are holding. A cement packer squeeze was pumped on 28- Apr -2010 with about 5 bbls circulated into the IA through the mandrel above the packer. The well passed several MITIA's (see attached integrity history), however, the IA pressures up after a day or so on water injection. The liquid leak rate is low enough that LDLs cannot detect where the leak is. The top WFR was dummied off and the well was put on injection. The IA did not pressure up, indicating that the leak path is up through the top packer and not at the cemented up mandrel above the top packer. An SCMT was run on 19- Jun -11 and found the cement top in the IA at 8906' MD, very close to the estimated cement top at 8946' MD. The top packer is at 9125' MD. It is believed that the leak path is along the two i- wires. This procedure includes steps to improve the cement bonding and minimize the chance of a repeat of the slow TxIA communication. A pill of Chemwash will be pumped into the IA before the cement to water wet the pipe. A different type of cement will be pumped that during the original packer squeeze. The procedure calls for SqueezeCrete, which is a micro -fine cement that should seal well around the i- wires. The SqueezeCrete will be followed by Class G cement with an additive (D170) that minimizes shrinkage for better bond. Contacts for this work are: Matt Brown Zach Doran 564 -5874 (w) 564 -5392 (w) 223 -7072 (c) 512 -667 -4308 (c) 344 -1130 (h) cc: Well File A 6 - pry w leek P ''� m1T -IA d I • Job Data Volumes bbls 3 -1/2" tub to 10118 88 3 -1/2" tub FP to 2500 TVD (3924 MD) 34 Mud pill vol: 10118 to 8890 10.7 Cmt vol to pump 8 Cmt vol in IA 8890 to 8662 6 Cmt vol left in tub 2 Total IA vol to top of cement 8906' 234 FP IA to 2500 TVD 3924 MD) 103 Barite /Geovis Pill A heavy mud pill made up of 16.5 ppg Barite & Geovis will be placed with coil on top of the composite plug up to the tubing punch. For details on mixing the mud pill, contact MI Swaco (Judy Means /Roberto Esquitin) at Tel: 907 - 670 - 5260 /Cell: 907 - 943 -1120. 1. Dummy off WFRs at 9626', 9960' and 10048'. 2. Pull PXN plug from XN nipple at 10108'. 3. RDMO. • 1. Punch tubing at 8888' to 8890' MD with oriented punch sub reference SCMT 11-Jun -2011 main pass. 2. Set composite bridge plug at 10118' (middle of 20' pup below XN) 3. Perform MIT - Tubing to 2000 psi to test composite 4. RDMO. 1. Circulate the tubing and IA by pumping the following fluids down the tubing and taking returns up the IA: a. 10 bbls 50/50 McOH water b. 175 bbls diesel c. 100 bbls inhibited water d. 36 bbls diesel Note: the circ will FP the IA down to about 3450' TVD (6640' MD). Up to 70 bbls can be circ'd up the IA during the cement job and still have 2500' TVD (3900' MD) FP in the annulus. • • 1. MIRU 1.75" CT unit. Ensure Tubing & IA are liquid packed. 2. MU cementing nozzle, connector and no check valves. RIH and tag composite @ 10118' Pick -up until full string weight is observed. PUH 10'. Flag CT. 3. Circulate 100 bbls 110 °F 1% KCI water down CT taking returns up backside to warm up well. 4. Mix a mud pill of 16 ppg barite with geovis. Lay in 10.7 bbls of mud pill from composite plug at 10118' to 8890' while taking returns up backside. 5. With CT parked at 8890', pump 10 bbls of Schlumberger's Chemwash with corrosion inhibitor down CT followed by a CT vol of 1%KCI water. Take returns up CT x tub annulus. 6. Once Chemwash reaches the nozzle, shut in backside, open IA and circulate 10 bbls Chemwash up IA. 7. After 10 bbls Chemwash is circulated in IA, shut in IA, open backside and pump 50 bbls + CT vol of warm ( -80 F) diesel down CT. 8. Batch mix 4 pumpable bbls of 15.8 ppg Unislurry cement and 4 bbls of SqueezeCRETE. SBHT is about 85 deg F. Note: at least 7 bbls of each type of cement should be mixed when using the batch mixer. Cement properties: Volume to Pump 8 bbl total Cement Types 15.8 ppg Unislurry (4 bbls) and SqueezeCRETE (4 bbls) Unislurry Thickening Time 4 -6 hours at 100 °F BHCT Unislurry Fluid Loss 30 - 50 cc /30- minutes at 100 °F BHCT SqueezeCRETE Thickening Time at least 10 hrs at 100 °F BHCT Unislurry Fluid Loss N/A Note: the Unislurry should contain D170 additive to minimize shrinkage 9. Park at +/- 8890'. Prior to pumping cement down CT, ensure that IA is still fluid packed. 10. Pump following down the coil taking rtns up CT x tub annulus: • 5 bbl water spacer • 4 bbls SqueezeCRETE Cement • 4 bbls Unislurry Cement • 5 bbl water spacer • MEOH for FP of CT Pump as follows, taking returns up CT x T annulus: a. Pump 5 bbl water spacer. Shut in reel valve. b. Displace surface lines until good SqueezeCRETE cement is achieved. Open the manifold to the reel and pump the cement into the reel. Pump 4 bbls of SqueezeCRETE and 4 bbls Unislurry and shut in reel valve. c. Displace the surface lines to fresh water. Open reel valve and chase cement with fresh water. • • 11. Displace the cement to the nozzle at max rate. Reduce the pump rate when cement is 2 bbls from the nozzle. Nozzle should be at 8890' (tubing punch depth). 12. Pump 1 bbl cement up around coiled tubing and then POOH while laying in cement at 1:1 returns (as best as possible) with IA shut in. Lay in the 8 bbls cement. 13. PUH to safety at 7800. WCTOC is around 7965' MD. 14. Shut in CT x T annulus and line out to take returns from IA to tanks but don't open IA. Come on line with pumps slowly and crack the choke to open IA. Bleed off gas if any but no liquid, and then divert to 40 bbl tank. Keep track of fluid volume pumped in case fluid level in IA is a few bbls low. Ensure that cement is not overdisplaced into IA. Continue pumping until 6 bbls of returns are seen in the 40 bbl tank. Monitor pumps and don't pump more than 6 bbls. Close in IA. Pump at low rate & squeeze cement to 500 psi or 2 bbls additional cement into IA, whichever comes first. Do not over displace cement into IA. SD pumping. 15. POOH replacing pipe voidage, holding squeeze pressure. FP top of well (35 bbls will FP to 2500' TVD, 3925' MD). 16. RDMO CTU. WOC for 7 days before next step .,, �, z?c ,. <,_ iii s: ri g > Y'::':'c:1,, ! ,, ✓i;'r'l °`�; i 1. MIT -T and MITIA to 4000 psi. , 4Y N.! 2. Drift & Tag. 7 . `: ',. 1. RU CTU. MU milling toolstring with 2.7" mill. (use a non - aggressive mill to get fine cuttings). 2. RIH & tag cement top. Mill cement, pumping slugs of slick water and Geovis as needed for good solids transport. yr 3. Mill thru cement until down into mud plug. Once thru all cement, circulate a gel sweep bottoms up. 4. Clean out the mud plug using slickwater & Geovis sweeps. 5. Clean out down to composite plug. Once at plug, pump a large gel sweep and circ bottoms up. 6. Mill composite at 10118' and push to bottom. 7. POOH. FP well. c 1. MITIA to 4000 psi. TREE= CIW WELLHEAD = FMC SAFETY NOTES: WELL REQUIRES A SSSV WHEN ON ACTUATOR= LEO w MI. WELL ANGLE> 70 © 3432'. KB.ELEV= 81.3' BF. ELEV = 52.8' 1 25' H4-1/2" X 3 -112" XO, ID = 2.992"1 KOP= 400' 1 Max Angle = 71` @ 3049' 3927' 1- 13 -1/2" HES X NIP, ID= 2.813" 1 Datum MD = 59` @ 9131' 20" CONDUCTOR -1 147 1 DatumTVD= 4400' SS 129.45 #,X -65 GAS LIFT MANDRELS WELDED, 18.770 ST WD 1 1VDI DEVI TYPE 1 VLV I LATCH PORTI DATE I 10 90964463 59 MMG OPEN RK - 04/15/10 I9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" H 5417' WATER INJECTION MANDRELS ST MD IVD DEV TYPE VLV LATCH PORT DATE 17" CSG, 26 #, L -80 TC11 XO TO L -80 BTC H 8481' 1--» 9 9189 4511 59 MMG -W DMY RK 0 01/31/10 m1 8 9249 4542 59 NY 1G -W DMY RK 0 06/07/11 7 9557 4705 58 ■MG -W DMY RK 0 01/31/10 17" X 3 -1/2" HES DUAL FEED THRU PKR, ID= 2.965" H 9125' 1 %'1 6 9626 4741 59 MMG -W P -15XJR RK 15 07/05/10 ► 5 9677 4766 59 14/1G -W DMY RK 0 01/31/10 4 9722 4790 59 MMG -W DMY RK 0 01/31/10 Minimum ID = 2.75" @ 1010$ 3 9870 4869 57 MMG -W DMY RK 0 01/31/10 3 -1/2" HES XN NIPPLE 2 9960 4918 57 MMG -W P -15XJR RK 9 07/05/10 —1 1 1 10048 4966 56 NIVIG -W _ P -15XJR RK 13 01/31/10 Mil 9138' H3 -1/2" NDPG MULTI SUB, ID = 2.992" 1 13 -1/2" PUP w/ RA TAG 9479' 1---- 9159' 1- 13 -1/2" HES X NIP, ID = 2.813" I 17" X 3 -112" HES DUAL FEED THRU PKR ID = 2.965" 9493' MI gill mw 9506' 3 -1/2" NDPG MULTI SUB, ID = 2.992" 1 17' MARKER PUPw /RA TAG H 9532' 1 - 4 952T -13-1/2" HES X NIP, ID = 2.813" 1 M1 I 17" X 3 -1/2" HES DUAL FEED THRU PKR ID = 2.965" 9645' �11 IMII II 9653' H 3 -1/2" NDPG MULTI SUB, ID = 2.992" 1 ' 9664' 1-13-1/2" HES X NIP, ID = 2.813" 1 M - PERFORATION SUMMARY J806' 1--17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" 1 REF LOG: LWD RT GR LOG ON 11/12/09 Mt ►M1 ANGLE AT TOP PERF: 57° @ 9226' 1 9819' H3 -1/2" NDPG MULTI SUB, ID = 2.992" 1 Note: Refer to Production DB for historical pert data 1 9$49' H 3 -1 /2" HES X NIP, ID = 2.813" 1 SIZE SPF ZONE INTERVAL Opn/Sqz DATE 1 I 4 -1/2" 5 Nb 9226 - 9252 0 11/20/09 _ 4 -112" 5 OBa 9578 - 9632 0 11/12/09 4-1/2" 5 OBb 9660 - 9696 0 11/12/09 MllIl 9979' 1-1 7" X 3-1/2" HES DUAL FEED THRU PKR ID = 2.965" 1 4-1/2" 5 OBd 9873 - 9960 0 11/12/09 MI ►�� 4 -1/2" 5 OBe 9992 - 10032 0 11/12/09 IIINIP 9992' H 3 -112" NDPG SINGLE SUB, ID = 2.992" 1 1 10027' 1 HES X NIP, ID = 2.813" 1 m1 10087' -1 3 -1 /2" HES X NIP, ID = 2.813" 1 10108' H3-1/2" HES XN NIP, ID - 2.750" ( r1670 PXN PLUG (06/14/10) 1 13 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H 10130' 1 ---- --I 10130' 1-13 -1/2" WLEG, ID= 2.992" 1 PBTD 10246' 14.�.�.�.� �.�.�. 10250' H FISH- MILLED COMPOSIT PLUG (05/06/10) 1 17" CSG, 26 #, L -80 BTC. .0383 bpf, ID = 6.276" 1-J 10332' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 11/23/09 N9ES ORIGINAL COMPLETION 06/18/10 RCTPJC SET TTP(06 /14110) WELL: V -227 02/16/10 PJC DRLG DRAFT CORRECTIONS 06/18/10 RCTPJC GLV CIO (06/16/10) PERMIT No: '2091160 03/30/10 TW /PJC FINAL DRLG CORRECTIONS 07/28/10 SWC /AGF WFR C/0 (07/05/10) API No: 50- 029 - 23417 -00 05/03/10 MW /PJC GLV C/O (04/15/10) 02/16/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 11, T11 N, R11 E, 380' FNL & 1533' FEL 05/03/10 SWC /PJC PULL PXN/ SET FDRILL (04/14/1 P6/26/11 SEC/PJC WFR C/0 (06/07/11) 05/31/10 DBMrPJC MILL COMPOSIT(05 /06/10) BP Exploration (Alaska) • • 1 2 Diesel 3 E - Diesel Water - Water . � C , ,- Chemwash 8890' Punch 8890' Punch 10 bbl 8890' Punch (orig sqz) ' A III / y' , 8906' TOC Chemwash 8906' sqz) ® r '; 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IIINIINIII IIIn1111ni11Ii1III11Iu/ IIIII /IIIIIIIl1IIIIa1GaINNIINNNIN � 111111 ti IIINIIIIIIIUI spinnmemmuummmumnearnummnummmuin ' ' , .,� . 9nUr IIIII�NI f _ E 1111111111111111 1 11111111�111111111111111111111111111 111111111111111111111111111 , \.� r ; d ,.. , , cn n111111i111N1111Ni1111I11 1111 11111I1111111111N11I11i11N11I11 /11111111111111111111111111 -s : 1 � ',..t r! :.. -o �IN11�1 NIIIIIIIIIIIIIIi111111111111111111N1111111111N1111111111 111111111111 1 » > i 1 - t. 1 c 1111 NIi111I111IhllliI111Il IIH IIIIIIIIIIIIIIIIIIihllIIIIINIIIIIUIIIIII1/ taminihl/II ..1 = M l!' � i 4 • • Well Integrity History > 11/24/09: New well, packer failed pressure test. Rig moved off well > 01/31/10: Set TTP @ 10108', Set DGLV in Sta# 10, MIT -T Passed to 3120 psi > 02/01/10: DGLV in Sta #2 > 02/02/10: MIT -T Passed to 3000 psi, pull DGLV from Sta# 6 > 04/14/10: Pulled TTP from 10108'; set composite BP @ 10121'; MIT -T Passed to 2500 psi > 04/15/10: Pull DGLV # 10 > 04/29/10: Cmt Pkr squeeze > 05/06/10: MIT -T Failed, MIT -IA Failed > 05/12/10: MIT -IA Passed to 3500 psi > 07/19/10: MIT -IA passed to 1500 psi > 07/22/10: AOGCC MITIA Passed to 1800 psi > 08/18/10: MIT -IA Passed to 3000 psi > 09/18/10: Verbal approval from AOGCC to operate without AA > 12/17/10: TecWel LDL didn't locate tubing leak > 12/24/10: PPPOT -T Passed to 5000 psi > 01/06/11: MIT -IA Passed to 2500 psi > 03/04/11: MIT -IA Passed to 2500 psi > 04/10/11: PPPOT -T Passed > 04/18/11: LDL, no leak found > 04/22/11: LDL, no leak found > 05/25/11: MIT -IA Passed to 3000 psi > 06/08/11: Set TTP @ 9527 MD, MIT -T Passed to 2500 psi > 06/21/1: Performed injectivity test WELLHEA[1= FMC A \I'-227 MI FWELL A IQGLE> 70 @ 3432 A SSSV WHEN ON , CTUATOR = LEO KB. ELEV = 81.3' BE ELEV = 52.8' 25' H4 -112" X 3 -1/2" XO, ID = 2.992" I MaxAngle = 71° @ 3049' I 3927' J - 13 - 1/2" HES X NIP, ID = 2.813" I Datum MD = 59° @ 9131' 20" CONDUCTOR, 147' Datum TVD = 4400' SS 129.45 #, X -65 GAS LIFT MANDRELS WELDED, 18.770 ST MD 1VD DEV TYPE VLV LATCH PORT DATE 10 9096_ 4463 59 MMG OPEN RK _ — 04/15/10 I9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" H 5417' WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE (7" CSG, 26 #, L -80 TC11 XO TO L -80 BTC H 8481' I 9 9189 4511 59 MMG -W DMY RK 0 01/31/10 MP 8 9249 4542 59 MMG -W DMY RK 0 06/07/11 7 9557 4705 58 MMG -W DMY RK 0 01/31/10 (7" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" H 9125' I �� 6 9626 4741 59 MMG -W P -15XJR RK 15 07/05/10 5 9677 4766 59 MMG -W DMY RK 0 01/31/10 Minimum ID = 2.75" @ 10108' 4 3 9722 9870 4869 4790 57 59 MMG -W MMG -W DMY DMY RK RK 0 0 0011/3311 /10 /10 3 -1/2" HES XN NIPPLE , 2 9960 4918 57 MMG -W P -15XJR RK 9 07/05/10 o1 1 10048 4966 56 MMG -W P -15XJR RK 13 01/31/10 NW , 9138' H3-1/2" NDPG MULTI SUB, ID = 2.992" I 13-1/2" PUP w / RA TAG H 9479' I-- 9159' 1 HES X NIP, ID = 2.813" I V 7" X 3-1/2" HES DUAL FEED THRU PKR, ID = 2.965" H 9493' M. IC:11 r 3-1/2" NDPG MULTI SUB, ID = 2.992" I I 7' MARKER PUP w /RA TAG H 9532' HIP — ' 9527' — 13 -1/2" HES X NIP, ID = 2.813" ( — (7" X 3-1/2" HES DUAL FFFD THRU PKR, ID = 2.965" I 9645' 'IA �� 11 I 9653' H3 -112" NDPG MULTI SUB, ID = 2.992" I III 9664' I - 13 - 1/2" HES X NIP, ID = 2.813" I min PERFORATION SUMMARY _ � 9806' —17" X 3 -1/2" HES DUAL FFF11 THRU PKR, ID = 2.965" I REF LOG: LWD RT GR LOG ON 11/12/09 MII, 1� ANGLE AT TOP PERF: 57° @ 9226' I 9819' H3-1/2" NDPG MULTI SUB, ID = 2.992" I Note: Refer to Production DB for historical pert data SIZE SPF ZONE INTERVAL Opn /Sqz DATE I ( 9849' H3-1/2" HES X NIP, ID = 2.813" 4 -1/2" 5 Nb 9226 - 9252 0 11/20/09 1111111P 4 -1/2" 5 OBa 9578 - 9632 0 11/12/09 4 -1/2" 5 OBb 9660 - 9696 0 11/12/09 •111 9979' I--17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" I 4 -1/2" 5 OBd 9873 - 9960 0 11/12/09 M♦ 1∎ 4 -1/2" 5 OBe 9992 - 10032 0 11/12/09 OPP 9992' — - 1/2" NDPG SINGLE SUB, ID = 2.992" I I I 10027' 1 HES X NIP, ID = 2.813" I SIP 10087' —I 3 -1/2" HES X NIP, ID = 2.813" I I 10108' H3 -1/2" HES XN NIP, ID = 2.750" I — I 10108' 1 — I3 - 1/2" PXN PLUG (06/14/10) I 13 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H 10130' I —y 10130' I- 13 -1/2" WLEG, ID = 2.992" ( PBTD H 10246' ∎0` 10250' H FISH- MILLED COMPOSIT PLUG (05/06/10) I (7" CSG, 26 #, L -80 BTC, .0383 bpf, ID = 6.276" H 10332' QA.A.A.A.AWA1 DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 11/23/09 N9ES ORIGINAL COMPLETION 06/18/10 RCTPJC SET TTP (06 /14/10) WELL: V -227 02/16/10 PJC DRLG DRAFT CORRECTIONS 06/18/10 RCTPJC GLV C/O (06/16/10) PERMIT No: 091160 03/30/10 TW /PJC FINAL DRLG CORRECTIONS 07/28/10 SWC/AGF WFR C/O (07/05/10) API No: 50- 029 - 23417 -00 05/03/10 MW /PJC GLV C/O (04/15/10) 02/16/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 11, T11 N, R11 E, 380' FNL & 1533' FEL 05/03/10 SWC/PJC PULL PXN/ SET FDRILL (04/14/1 p6/26/11 SEC /PJC WFR C/O (06/07/11) 05/31/10 DBM/PJC MILL COMPOSIT (05/06/10) BP Exploration (Alaska) Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for June 2... Page 1 of 1 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 12:47 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Daniel, Ryan Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for June 2011 Attachments: AOGCC lnj Report 07- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the June 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 07- 11.zip» rliii JUL 1 1 2Q Notes on wells: Added to Report: U -10 (PTD #1851970): Moved from Quarterly Not Operable injection report to Monthly Injection Report after patch repaired TxIA communication. Currently started water injection and will be receiving AOGCC witnessed MIT -IA once well thermally stable. Taken off Re • _ V -227 (PTD #2091160): eclassified as Not Operable due to IA repressurization. Moved to Quarterly Not Operable Repo . Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/5/2011 2Q2011 Not Operable Injector Re Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 2Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L -223 (PTD #2090990): MIT -IA failed on 05/01/11. MPS -07 (PTD #2020720): MIT -IA failed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 Well V -227 Injection Plot TIO Plot Well: V -2270 ° Pressure vs. Rate ° PTD #: 20911600 ° o ° o el ri Tbg IA TxIA comm post packer • A OA squeeze ° p o El °o O A o AOGCC MITIA Passed N • y N 1 , a 07/22/10 ■ LtZtattpaiS O k ` MITIA Passed on 08/18/10L a I o o 1 \f - , p � r MITIA Passed on 05/25/11E1 o LDL failed to find leak J i 04/22/11 ' I J r I ♦Last 90 days •Last Month -i w n The plan forward is to keep the _ V �, well on water injection and run o r ° further TxIA comm diagnostics 0 1 00 200 300 400 500 800 2/19/11 5/12/11 8/2/11 Injection Rate, MCFPD for repair. • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 07/01/11 0 8 07/01/11 0 120 20 06/30/11 0 5 06/30/11 0 120 20 06/29/11 0 5 06/29/11 0 120 20 06/28/11 0 8 06/28/11 0 120 20 06/27/11 0 11 06/27/11 0 120 20 06/26/11 0 9 06/26/11 0 120 20 06/25/11 0 8 06/25/11 0 120 20 06/24/11 0 7 06/24/11 0 120 20 06/23/11 0 44 06/23/11 0 140 20 06/22/11 0 333 06/22/11 1,150 140 20 06/21/11 0 1,193 06/21/11 1,150 140 20 06/20/11 407 1,802 06/20/11 1,800 700 220 06/19/11 403 1,706 06/19/11 1,600 760 260 06/18/11 455 1,576 06/18/11 1,600 680 200 06/17/11 328 1,583 06/17/11 1,600 500 60 06/16/11 348 1,582 06/16/11 1,620 540 60 • 06/15/11 357 1,590 06/15/11 1,650 1,240 200 06/14/11 367 1,596 06/14/11 1,650 1,240 200 06/13/11 357 1,596 06/13/11 1,650 1,240 0 06/12/11 362 1,603 06/12/11 1,650 1,200 0 06/11/11 362 1,601 06/11/11 1,650 1,200 0 06/10/11 359 1,509 06/10/11 1,650 620 0 06/09/11 111 1,742 06/09/11 1,550 620 0 06/08/11 26 1,964 06/08/11 1,650 1,440 140 06/07/11 380 1,611 06/07/11 1,650 1,440 140 06/06/11 361 1,570 06/06/11 1,650 1,440 140 06/05/11 361 1,598 06/05/11 1,650 1,440 140 06/04/11 354 1,590 06/04/11 1,650 1,440 140 06/03/11 365 1,600 06/03/11 1,650 1,440 140 06/02/11 378 1,604 06/02/11 1,650 1,460 160 06/01/11 369 1,593 06/01/11 1,600 1,460 240 NOT OPERABLE: Injector V -227 (PTD #2091160) IA Repressurization on Water Injecti... Page 1 of( I Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, June 20, 2011 6:23 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, RES GPB Central Prod Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad LV; Cismoski, Doug A; Yeager, Kevin E; Daniel, Ryan Cc: Walker, Greg (D &C); Doran, Zachariah J; Brown, Matt (CONTRACT PROFESSIONALS) Subject: NOT OPERABLE: Injector V -227 (PTD #2091160) IA Repressurization on Water Injection Attachments: V- 227.pdf; V -227 TIO Plot 6- 20- 11.doc All, Injector V -227 (PTD #2091160) has continued to exhibit rapid IA repressurization while on Produced Water Injection into the upper injection interval at 9226'- 9252'. A dummy valve was set on 6/9/2011 in the injection mandrel at 9249' which appears to have significantly reduced the IA repressurization. On 6/15/2011 the IA pressure was bled down with tubing / IA/OA = 1600 /420 /vac. On 6/17/2011 the tubing /IA/OA = 1560/480/20 resulting in an IA build up rate of —30 psi /day. The well is being reclassified as Not Operable while it is evaluated for further operability and repair. The well should be shut in and freeze protected as soon as possible. Attached are welllbore schematic, Injection Plot and TIO Plot for reference. «V- 227.pdf» «V -227 TIO Plot 6- 20- 11.doc» Please call if you have any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells J 'N 2 1 aj D1 Via, Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, May 24, 2011 2:01 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, lames B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwariz @alaska.gov >'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, RES GPB Central Prod Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad LV; Cismoski, Doug A; Yeager, Kevin E Cc: Walker, Greg (D&C); King, Whitney; Doran, Zachariah 3; Brown, Matt (CONTRACT PROFESSIONALS) Subject: UNDER EVALUATION: Injector V -227 (PTD #2091160) IA Repressurization on Water Injection All, Injector V -227 (PTD #2091160) is exhibiting IA repressurization while on Producer Water Injection. The 6/21/2011 NOT OPERABLE: Injector V -227 (PTD #2091160) IA Repressurization on Water Injecti... Page 2 of • CO tubing/IA/OA were equal to 1540/1440/90 on 5/23/2011. The IA pressure was bled on 5/23/11 from 1440 psi to 453 psi. During the post -bleed monitor on 5/24/11 the IA pressure increased 920 psi. The well is being placed Under Evaluation for further diagnostics. The well passed an MIT -IA to 2500 psi on 3/4/2011. An MIT -IA will be repeated to 2500 psi with the well on injection and a liquid leak rate test will be attempted if it fails. Pending these results a plan forward for further diagnostics and repair will be developed. An updated TIO Plot and Injection Plot are attached for reference. « File: V -227 TIO 05- 24- 11.doc » Thank you, Mehreen Vazir (Alternate: Gerald Murphy,) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: Vazir, Mehreen Sent: Friday, April 29, 2011 9:00 PM To: 'Maunder, Thomas E (DOA)' Cc: 'Regg, James B (DOA)' Subject: Injector V -227 (PTD #2091160) AOGCC approval for water injection w/ known IA repressurization Tom, We have attempted two LDLs on injector V -227 to identify the source of IA repressurization. The Togs were run 4/18 and 4/22. Both logs have been unable to locate a leak point. Our plan forward is to leave the well on water injection while we pursue an Administrative Approval for PWI only. « File: V -227 TIO 04- 29- 11.doc » Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AK, D &C Well Integrity Coordinator @BP.com 6/21/2011 • . Injector V -227 (PTD #2091160) TIO Plot 06/20/2011 Mak V -II7 • t 16 k C ma; °1 0 040 + OOOA 000 03/20/12 040241 0/109/11 04/16,1 01/23/11 01/3041 05,0011 054141 0521/11 05/2841 06101/11 0641/11 06/10/1 Injector V -227 (PTD #2091160) Injection Plot W44 V-227 2.100 '.. 2.300 W 500 aW Z100 2000 42 120 1,901 800 ^ 380 � � � Milipriv 310 1,500 • • •� 320 1,am 300 . - NM a 1 300 284 SW -pw • 31203 260 _ 111 1.100 210 - - 00 • 010 30 X 00 200 900 180 803 W TOO 140 600 120 500 iW 100 00 300 W 200 10 100 20 03/220111 0002/11 04/0911 04/1641 01/23/11 04/3011 05/0741 05/14111 05/21/11 05/2811 060141 0671 06/18/11 • • Injector V -227 (PTD #2091160) TIO Plot 04/29/2011 We[V.w • 1000 - R Z.000 t M a— M OOA ■ - On r MW64FIrWMPI. 1 000 01 01029411 02/05/11 02/1211 02/19/11 02/26.i1 03405211 02/12/11 03/19/11 02/26/11 04212/21 0409/11 04/16/11 04/2311 Injector V -227 (PTD #2091160) Injection Plot We[ V -TO —500 2.400 '., 5� 2,330 540 2,200 520 2,100 • / 500 480 2.000 160 1,920 140 HL' 420 1 ro9 am 3 -00 391 1.00 a W11P 1.300 - 74 3 30 — PW 1X10 2901 _ 1,100 2 O 0 — llller ® 240 — On 900 220 200 180 100 f 160 • 912 144 120 400_ 100 ' ,. 90 00 60 230 40 • • 100 20 • • 412211 — 01/29/11 02/66/11 02/12/11 02/19/11 02/26/11 34/34)21 03/12011 03/19/11 0326/11 04/02/11 04/09/11 04/14/11 0423/11 • • • • WELL LOG TRANSMITTAL - PROACriVE DiAgNOSTic SERViCES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road W - MAY 2 3 21W Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 ( 1) Leak Detection - WLD WAF :- _.r -11 run 1 V -227 BL EDE 50 -029- 23417 -00 11- Leak Detection - WLD /WAF 22-Apr-11 (run 2) V-227 BL/ EDE ,A0-02,9 Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E -MAIL: WEBSITE: '.",r , ,r , ;T.e- .dr:'3C ` i; ai 0a , C:\Documents and Settings\Diane Williams \Desktop\BP_Transmit.docx DATA SUBMITTAL COMPLIANCE REPORT 2/2/2011 Permit to Drill 2091160 Well Name /No. PRUDHOE BAY UN ORIN V -227 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23417 -00 -00 MD 10340 TVD 5136 Completion Date 11/24/2009 Completion Status WAGIN Current Status WAGIN 6_11O — Dr REQUIRED INFORMATION u.- ---.. Mud Log No Samples No Directional Survey Y DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, DIR / GR / RES / NEU / AZI DENS, USIT (data taken from Logs Portion of Master Well Data Maint • Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med /Frmt NumberName Scale Media No Start Stop CH Received Comments ED C Lis 19381 Induction /Resistivity 256 10339 Open 2/24/2010 LIS Veri, GR, ROP, FET, RPM, RAM, NPHI, TRPM og Induction /Resistivity 25 Blu 255 10304 Open 2/24/2010 MD Vision Service og Sopic 5 Col 200 10200 Case 1/13/2010 USIT, CCL, GR, GPIT 1 C Pds 19209 Sonic 200 10200 Case 1/13/2010 USIT, CCL, GR, GPIT / •9 Induction /Resistivity 25 Blu 255 10304 Open 2/24/2010 TVD Vision Service ED C Directional Survey 0 10340 Open Rpt Directional Survey 0 10340 Open og Leak 1 Blu 0 10100 Case 1/18/2011 LDL, WLD, XTU, HTU, CCL, Temp ' C Las 20654 "Leak 0 10100 Case 1/18/2011 LDL, WLD, XTU, HTU, • CCL, Temp Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/2/2011 Permit to Drill 2091160 Well NamelNo. PRUDHOE BAY UN ORIN V -227 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23417 -00 -00 MD 10340 TVD 5136 Completion Date 11/24/2009 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y Q Daily History Received? N Chips Received? .YY -FNS Formation Tops 9.„/"N Analysis Y.LN --- Received? Comments: Compliance Reviewed By: , J Date: c� �Y/ r o' L 1 ) • • 0 Irlr WELL LO TRANSMITTAL P Di*gnosnc SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 900 Benson Blvd. Anchorage, Alaska 99508 and z)e) f/40 20 Co5—C( ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 16- Dec -10 V -227 BL / EDE 50-029- 23417 -00 2) ,° . i'L--: r „ ,, , 3,,\, ',1s: Signed Date : e CA Print Name: A n y _ .+ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E-MAIL : Pdsanchoraaeamemorvloq.com WEBSITE : www.memorylog.com C:\Documents and Settings \Diane Williams \Desktop \Transmit_BP.docx OPERABLE: Injector V -227 (PTD #2091160) Passing MITIA - AOGCC approval for wa... Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Friday, September 10, 2010 9:31 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Engel, Harry R; Cismoski, Doug A; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS Prod Controllers; AK, OPS Well Pad LV Cc: Janowski, Carrie; Orlando, Margaret Subject: OPERABLE: Injector V -227 (PTD #2091160) Passing MITIA - AOGCC approval for water injection w/ known IA repressurization Attachments: MIT PBU V -227 08- 18- 10.xls All, Injector V -227 (PTD # 2091160) passed an MITIA on 08/18/10 to evaluate TxIA communication. Though the TIO plot shows IA repressurization, the passing test verifies tubing integrity. Verbal approval has been given by the AOGCC to continue water injection without pursuing an Administrative Approval while diagnostics and repairs are progressed for future MI service. The well has been reclassified as Operable. The MIT form has been included for reference. • «MIT PBU V -227 08- 18- 10.xls» Thank you, Torin Roschinger (alt. Jerry Murphy) �� Well Integrity Coordinator �� JUN 2 Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, August 18, 2010 10:34 AM To: Maunder, Thomas E (DOA); 'Regg, James B (DOA) ; 'Schwartz, Guy (DOA) <guy.schwarh @alaska.gov >'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Engel, Harry R; Cismoski, Doug A; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS Prod Controllers; AK, OPS Well Pad LV Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Orlando, Margaret Subject: UNDER EVALUATION: Injector V -227 (PTD #2091160) Eval IA repressurization post packer squeeze All, V -227 (PTD # 2091160) is a WAG injector that has recently shown signs of IA repressurization post packer squeeze. An AOGCC MIT -IA passed on 07/22/10 after the squeeze verifying two competent barriers. However, on 08/17/10 the IA was bled from 1260 to 0 psi and built up 1560 psi overnight. The well has been reclassified as Under Evaluation for further diagnostics. The plan forward is to monitor the TIO plot for IA pressure stabilization after pad injection is back up and perform an MITIA to confirm two competent barriers. 6/21/2011 • TIO Plot 08 -18 -2010 Well V -227 3 000 - T6p -f IA 2000 - OA 00A 00A r- 000A _ On 1,000 - 05/22/10 05/25/10 06/05 /10 06/12/10 06/19/10 06/26/10 07/03/10 07/10/10 07/17/10 07/24/10 07/31/10 00/07/10 06 /14/10 Injection Plot • Wet V-ZZI 600 • - 550 , 1,200 �t - 450 1,100 ` - 400 1.000 + -WHIP a 500 - 350 SW • FlN . 3 _ MI 700 -250 -O4 603 - On 500 - 150 • - 100 200 - 50 100 05/22/10 05/29/10 06/05/10 06/12/10 06/19/10 0626/10 07/03/10 07/10/10 07/17/10 07/24/10 07/31/10 00/07/10 00 /14/10 • . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq @alaska.aov; doa.aogcc.prudhoe.bay alaska.gov; phoebe.brooksaalaska.gov; tom.maunder(caalaska.aov OPERATOR: BP Exploration (Alaska), Inc. II ( ?VI 10 FIELD / UNIT / PAD: Prudhoe Bay / PBU / V pad i DATE: 08/18/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V -227 ' Type Inj. W TVD 4,478' Tubing 1600 1610 1610 1610 Interval 0 P.T.D. 2091160 -' Type test M Test psi 1500 Casing 1560 3000 ' 2950 2940 / P/F P / Notes: MITIA to evaluate TxIA communication OA 400 600 600 600 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Wet Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) 2010 8 MIT PBU V - 227.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission T Oc Jim Regg DATE: Tuesday, July 27, 2010 P.I. Supervisor � SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -227 FROM: John Crisp PRUDHOE BAY UN ORIN V -227 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry :_j*— NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN ORIN V - 227 API Well Number: 50 029 - 23417 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr100722162809 Permit Number: 209 - 116 - Inspection Date: 7/22/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V -227 ' Type Inj. W TVD 4478 / 1 IA 1200 1810 ! 1765 1755 P. T.D 2091160 "C I ypeTest I SPT i Test psi 1500 ' OA 270 340 330 330 Interval INITAL - P/F P ' Tubing 1450 1350 1340 1400 Notes: Tuesday, July 27, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks@alasCa.gov; tom.maunder @alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / V pad DATE: 0722/10 OPERATOR REP: Torin Roschinger AOGCC REP: John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well V -227 Type Inj. W TVD 4,478' Tubing 1,450 1,350 1,340 1,400 Interval I Lt P.T.D. 2091160 Type test P Test psi 1500 Casing 1,200 1,810 1,765 1,755 P/F P i ›' Notes: AOGCC MITIA post-packer squeeze OA 270 340 330 330 Well Type In'. TVD Tubing Interval P.T.D. Type test I Test psil Casing P/F ii t� °� `� Notes: OA Well Type test I Test psil TCasing Inte l P.T.D. P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D._ Type test I Test psi' Casag P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test I Test psi) Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle 1= Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) I I I MIT Report Form BFL 11/27/07 MIT PBU V -227 07- 22- 10.xls • Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Tuesday, July 20, 2010 11:21 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU V -227 / PTD # 209 -116 Hi Art, Please reference the following well: Well Name: PBU V -227 Permit #: 209 -116 API #: 50- 029 - 23417 -00 -00 Top Perf MD: 9226' Bottom Perf MD: 10032' This well began Injection on July 12, 2010 Method of Operations is: Water Injection There is no well test data 7/20/2010 OPERABLE: Injector V -227 (PTD #2091160) Passed AOGCC MITIA Post Packer Sque... Page 1 of 3 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Friday, July 23, 2010 2:05 PM To: Maunder, Thomas E (DOA) Subject: RE: OPERABLE: Injector V -227 (PTD #2091160) Passed AOGCC MITIA Post Packer Squeeze Attachments: MIT PBU V -227 07- 22- 10.xls Tom, The MITIA passed on 07/22/10. I have attached the MIT Form for your reference. Thank you, Torin From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, July 23, 2010 1:59 PM To: AK, D &C Well Integrity Coordinator Subject: RE: OPERABLE: Injector V -227 (PTD #2091160) Passed AOGCC MITIA Post Packer Squeeze Torin, When did the well pass the MIT? I show having received a series of MITs on May 31 with a 5/12 test for V -227. Looking at the numbers, it is does not appear that the pressure stabilized. There is a 20 psi loss in each 15 minute observation period. It would seem that the test should have been run longer or begun again. Thanks in advance for the information. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, July 23, 2010 9:22 AM To: Regg, James B (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Engel, Harry R; Cismoski, Doug A; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 OSM; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS Prod Controllers; AK, OPS Well Pad LV; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Warren, Mike; Janowski, Carrie; Orlando, Margaret; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Injector V -227 (PTD #2091160) Passed AOGCC MITIA Post Packer Squeeze All, Injector V -227 (PTD #2091160) passed an AOGCC MITIA after the packer was squeezed on 04/29/10. The passing test verifies the squeeze was successful and the TxIA communication has been mitigated. The well has been reclassified as Operable. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 7/23/2010 OPERABLE: Injector V -227 (PTD #2091160) Passed AOGCC MITIA Post Packer Sque... Page 2 of 3 • Pager (907) 659 -5100 Ext. 1154 From: Quy, Tiffany Sent: Wednesday, July 07, 2010 9:27 AM To: AK, D &C Well Integrity Coordinator; NSU, ADW Well Operations Supervisor; Engel, Harry R; Cismoski, Doug A; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 OSM; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS Prod Controllers; AK, OPS Well Pad LV Cc: AK, D &C WL & Completions Coordinator; Warren, Mike; King, Whitney; Orlando, Margaret Subject: UNDER EVALUATION: V -227 (PTD #2091160) Post Packer Squeeze All, Well V -227 (PTD #2091160) was repaired with a packer squeeze on 04/29/10. The well has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC MIT -IA may be conducted for UIC compliance. Please place V -227 on injection when convenient. The 28 -clock will begin when the well is put on injection. The AOGCC will be notified to witness the pressure test when the well is thermally stable. Thanks! Tiffany Tiffany Quy (Filling in for Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer phone: (907) 659 -5098 cell: (253) 576 -6153 tiffg0 @bp.com From: NSU, ADW Well Integrity Engineer Sent: Friday, November 27, 2009 8:59 AM To: NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2 /WRD); GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; GPB, Well Pad LV Cc: Sayers, Zach 3; NSU, ADW WL & Completion Supervisor; NSU, ADW Well Integrity Engineer; Warren, Mike Subject: NOT OPERABLE: V -227 (PTD #2091160) Packer failure during initial completion All, Well V -227 (PTD #2091160) has been reclassified as Not Operable. The packer failed a MITIA during the initial completion. Please continue to monitor this well and record wellhead pressures while options are being worked. Thank you, Anna Ou6e, (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 7/23/2010 P2 -23 (PTD# 1940320), 04 -10 (PTD #1760420), 09 -25 (PTD# 1840280), GC o(PTD# 189068... Page 1 of 1 Regg, James B (DOA) �. From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com]� 6(7-i)1 Sent: Monday, May 31, 2010 4:43 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D &C Well Integrity Coordinator Subject: P2 -23 (PTD# 1940320), 04 -10 (PTD# 1760420), 09 -25 (PTD# 1840280), GC-1E (PTD# 1890680), H -03 (PTD# 1710190), L -214A (PTD# 2060270), NGI -08 (PTD# 1760520), V -224 (PTD# 2081540), V -227 (PTD# 2091160), WGI -04 (PTD# 1790500) Attachments: May 2010 MIT Forms 05- 31- 10.zip Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: P2 -23 (PTD# 1940320) 04 -10 (PTD# 1760420) 09 -25 (PTD# 1840280) GC-1E (PTD# 1890680) H -03 (PTD# 1710190) L -214A (PTD# 2060270) NGI -08 (PTD# 1760520) - - PTD# 2081540) (PTD# 2091 .1 WGI -04 (PTD# • u • i «May 2010 MIT Forms 05- 31- 10.zip» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 6/1/2010 h • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks @alaska.gov; tom.maunder @alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: BP Exploration (Alaska), Inc. 1 `} ,4 fr (CD FIELD / UNIT / PAD: Prudhoe Bay / PBU / V Pad t DATE: 05/12/10 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well V -227 f Type Inj. N '' TVD '4,478' Tubing 0 0 0 0 Interval 0 P.T.D. 2091160 ` Type test P Test psi X 1500 Casing 130 3,540 3,420 3,400 P/F P V Notes: MIT -IA post cement squeeze while shut -in OA 0_ 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU V -227 05- 12- 10.xls MECHANICAL INTEGRITY R!PORT • P.UD DATE: 11/V Z•01 OPER & FIELD ,O P 1 6 4. '" /"oo -( G RELEASE : 1 1/2 4/2aa g i.'rELL NUMBER V Z Z (.; LL DATA T D : / D � .. SI 3 TVD; : BTD : / o Z `f ` MD 5 SO ?"VD Casing: 1 • Shoe: S '+/7, q 3o2Y TVD; DV: - SID .TVD iaer: - 7" Shoe. / 334m $/3/' TVD; TOP: HID TVD Tubing: 3 Packer l6cy5 MD 4/750' TVD; Set at :.ale Size g 7S and ; Perfs q(ZZ6 to /v 032 !SC: MICA -1e INTEGRITY - PART 11 Annulus Press Test: IP L/ 00 ; 15 min g-S-d 0 ; 30 min 3 604 Comments: 1l " PQcha-t... / i 44,e5. " i tic. s a•t'Tr .. ek 'Aro P ! . Pq.d 4Ir ` kcJe.G($ (74.4-10 " :MECHANICAL INTEGRITY - PART #2 a' Cement Volumes: rtmt. Liner Gag 7 . ; DV . Cot vol to cove° per. s 5 ' 13134 •1 - �cs Theoretical roc ` a T = 70Z� i p 3 A s- r.7yod Cement Bond Log de0or No) CCS /T ; In AOGCC File CBL Evaluation, one above perfs 5e vI look P( < - ba..lC spot- a. ' a4 cisre- pear Td C. tab LS + t'�' ! Icl� • c‹ Production Log: Type /...04 //4 ; Evaluation C s r CONCLUSIONS doG. ?irt 11: W'At e / M rT= • ?a t►. J 2: A D / . (// L or REGEV ALA OIL AND GAS CONSERVATION COMMISSION MAY 0 5 fig PORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 PACKER Performed: jask Perforate New Pool ❑ Waiver❑ Time Extension ❑ REPAIR Change Approved PrjOperat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: ". Permit to Drill Number: Name: Development ❑ Exploratory ❑ 209 -1160 3. Address: P.O. Box 196612 Stratigraphic❑ Service El Ng. API Number: Anchorage, AK 99519 -6612 50- 029 - 23417 -00 -00 8. Property Designation (Lease Ngmber) : 9. Well Name and Number \\ ADLO- 028240 PBU V -227 10. Field /Pool(s): r, PRUDHOE BAY FIELD / ORION SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured - 10340 feet Plugs (measured) 10108' 1/31/10 feet true vertical \ 5135.99 feet Junk (measured) None feet Effective Depth measured 10246 feet Packer (measured) 9125 9493 9645 true vertical 5080.31 feet (true vertical) 4478 4671 4750 Casing Length Size MD TVD Burst Collapse Structural Conductor 176 20" 129.45# X65 SURFACE - 176 SURFACE - 176 Surface 5388 9- 5/8 "40# L -80 29 - 5417 29 - 3024 5750 3090 Intermediate Production 10306 7" 26# L -80 26 - 10332 26 - 5131 7240 5410 Liner Liner Perforation depth: Measured depth: 9226 - 9252 9578 - 9632 9660 - 9696 9873 - 9960 9992 - 10032 True Vertical depth: 4530.23 - 4543.73 4715.4 - 4743.46 4757.87 - 4776.28 4870.93 - 4918.04 4935.29 - 4957.15 9873 - 9960 4870.93 - 4918.04 Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 SURFACE - 10130 SURFACE - 5012 Packers and SSSV (type, measured and true vertical depth) 7 "X3 -1/2" HES DUAL FEED THRU PKR 9125 4478 7 "X3 -1/2" HES DUAL FEED THRU PKR 9493 4671 7 "X3 -1/2" HES DUAL FEED THRU PKR 9645 4750 7 "X3 -1/2" HES DUAL FEED THRU PKR 9979 4828 7 "X3 -1/2" HES DUAL FEED THRU PKR 9806 4835 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 3082 54056 288 852 Subsequent to operation: 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service IS Daily Report of Well Operations X N, Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG GINJ ❑ WINJ 12 SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SFl- S • 4 ' t 0 Sundry Number or N/A if C.O. Exempt: 310 -097 Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature !�" P e 564 -4944 Date 5/4/2010 Form 10 101 Rovi�2000 6 20 Submit Original Only 3 - 7 • • V -227 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/28/2010 CTU #9 1.75" CT Job Scope: Packer Repair. MIRU CTU. Pump 1.25" drift ball for coil vol. CT volume= 32 bbls. MU 2" BDN and RIH. Tag_plug at 10,118' PU to up WT and correct depth to 10.118'. Displaced well to hot KCL and pumped a i8.9 bbl Bar Gel Pill and laid in from 10,118' to 9095'. Displace IA through open ipocket @ 9096' with diesel and inhibited water. ...Job continued on WSR 1 4/29/10 4/29/2010CTU #9 1.75" CT Job Scope: Packer Repair...Job continued from WSR 4/28/i 0 V Continue circ inhib KCL & diesel into IA for CMT plug. Pumped 6 bbls 15.8 ppg :CMT and laid in from 9096'. At safety displaced 4.7 bbls of CMT into IA and POOH maintaining IAP (51 psi) filling hole with 23 bbls of diesel. TOC calculated at 8947' 1.3 bbls ( -150') from 9096'. Well FP to 2645' with diesel. At surface shut in well with 194psi on tubing 84psi on IA and 153psi on OA, left a little extra IAP for cooling. RDMO CTU.... Job Complete FLUIDS PUMPED BBLS 60 INHIB 1% KCL 6 15.8PPG CLASS G CMT 138 50/50 METH 45 1% CON QOR INHIBITED 1% KCL WATER 280 DIESEL 529 Total TRE = CM/ • WELLHEAD = FMC , S NOTES: WELL ANGLE> 70 @ 34 ACTUATOR =' LEO V-22 1 B LEA/ = 52.8' ` J 25' 1 - 14 X 3 -1/2" XO, ID = 2.992 "1 KOP = 400' Max Angle = 71° @ 3049' 3927' H3 -1/2" HES X NIP, ID = 2.813" I Datum MD = 59° @ 9131' 20" CONDUCTOR, 147' 1 Datum TV D = 4400' SS 129.45 #, X -65 GAS LIFT MANDRELS WELDED, 18.770 ` ST MD 'ND DEV TYPE VLV LATCH PORT DATE 10 9096 4463 59 MMG DMY RK 0 _01/31/10 I9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" H I 541r cah c.a ellf ER I NJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE I7" CSG, 26 #, L -80 TC11 XO TO L -80 BTC 1--1 8481' I 9 9189 4511 59 MMG -W DMY RK 0 01/31/10 :I 8 9249 4542 59 MMG -W DMY RK 0 01/31/10 7 9557 4705 58 MMG -W DMY RK 0 01/31/10 H �d 7" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" I I 9125' I 6 9626 4741 59 MMG -W RKFS RK -- 02/07/10 5 9677 4766 59 MMG -W DMY RK 0 01/31/10 4 9722 4790 59 MMG -W DMY RK 0 01/31/10 Minimum ID = 2.75" @ 10108' ' 3 9870 4869 57 MMG -W DMY RK 0 01/31/10 3-1/2" HES XN NIPPLE 2 9960 4918 57 MMG -W DMY RK 0 01/31/10 1 1 10048 4966 56 MMG -W DMY RK 0 01/31/10 9138' 1 - 1/2" NDPG MULTI SUB, ID = 2.992" I 3 -1/2" PUPw/ RA TAG H 9479' 1--* 9159' J_I3 -1/2" HES X NIP, ID = 2.813" I 17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" H 9493' Hoz M ■ 9 506' — I3 - 1/2" NDPG MULTI SUB, ID = 2.992" I 17' MARKER PUP w /RA TAG H 9532' I — 4 �' ' 9527' H3-1/2" HES X NIP, ID = 2.813" I 1 17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" H I 9645' I 1 9653' H3-1/2" NDPG MULTI SUB, ID = 2.992" I ' , I 1 9664' 1--I3 - 1/2" HES X NIP, ID = 2.813" I PERFORATION SUMMARY �, 9806' H 7" X 3-1/2" HES DUAL FEED THRU PKR, ID = 2.965" REF LOG: LWD RT GR LOG ON 11/12/09 S ANGLE AT TOP PERF: 57° @ 9226' ■ I 9819' H 3 -1/2" NDPG MULTI SUB, ID = 2.992" I Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn /Sqz DATE ' ' I I 9849' H3_1/2" HES X NIP, ID = 2.813" I 4-1/2" 5 Nb 9226 - 9252 0 11/20/09 4 -1/2" 5 OBa 9578 - 9632 0 11/12/09 4 -1/2" 5 OBb 9660 - 9696 0 11/12/09 owl 9979' I-17" X 3 -1/2" HES DUAL FEED THRU PKR, ID = 2.965" I 4 -1/2" 5 OBd 9873 - 9960 0 11/12/09 g 4-1/2" 5 OBe 9992 - 10032 0 11/12/09 9992' I — I3 - 1/2" NDPG SINGLE SUB, ID = 2.992" I ' ' I I 10027' H3-1/2" HES X NIP, ID = 2.813" I ' ' 10087' m 3 -1/2" HES X NIP, ID = 2.813" I '� I 10108' H3-1/2" HES XN NIP, ID = 2.750" I 10108' H3 -1/2" PXN PLUG (01/31/10) 1 I3 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H 10130' 1 / ` PBTD I — I 10246' 10130' H3-1/2" WLEG, ID = 2.992" I t■■ 1� 1 �1 ■�■■■ 1 I-J ELMD NOT LOGGED 17" CSG, 26 #, L -80 BTC, .0383 bpf, ID = 6.276" H 10332' ..." DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 11/23/09 N9ES ORIGINAL COMPLETION 03/30/10 TW /PJC FINAL DRLG CORRECTIONS WELL: V -227 02/16/10 PJC DRLG DRAFT CORRECTIONS PERMIT No: 2091160 01/31/10 SEW /PJC GLV C/O API No: 50- 029 - 23417 -00 02/07/10 SEW /PJC GLV C/O SEC 11, T11 N, R11 E, 380' FNL & 1533' FEL 02/27/10 RPC/PJC PXN PLUG/ GLV C/O (01/31/10) 02/27/10 SW /PJC GLV CIO (02/07/10) BP Exploration (Alaska) • SUL [E AR3g\SEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Matt Brown Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Orion Schrader Bluff Pool, PBU V -227 Sundry Number: 310 -097 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair 5 DATED this day of April, 2010. Encl. 2 CA'14(4 t • STATE OF ALASKA RECEIVE D .a � � � ALASK OIL AND GAS CONSERVATION COMMISSION .S/•/ n, �,�,I OC'� APPLICATION FOR SUNDRY APPROVALS MAR 3 1 2010 20 AAC 25.280 1. Type of Request: Abandon Plug for Redrill ❑ Perforate New Pool❑ Repair Well El ^i b t, Wi0Q5d P I Suspend 0 Plug Perforations ❑ Perforate❑ Pull Tubing Annxtension❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate0 Alter Casing ❑ Other: Packer Repair 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory 209 -1160 3. Address: P.O. Box 196612 Stratigraphic Li , Service Vok 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23417 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU V -227 Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL028240, ADL028238 Prudhoe Bay Field / Orion Schrader Bluff Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10340 - 5135.99 - 10246 5080.31 10108' 1/31/10 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 176 20" 129.45# X65 SURFACE 176 SURFACE 176 Surface 5388 9 -5/8" 40# L -80 29 5417 29 3024 5750 3090 Intermediate Production 10306 7" 26# L -80 26 10332 26 5131 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 0 9226 - 9252 4530.23 - 4543.73 3 -1/2" 9.2# L -80 SURFACE 10130 0 9578 - 9632 4715.4 - 4743.46 0 9660 - 9696 4757.87 - 4776.28 0 9992 -10032 4935.29 - 4957.15 0 9873 - 9960 4870.93 - 4918.04 Packers and SSSV Type: 7 "x3 -1/2" hes dual feed thru pkr Packers and SSSV MD and TVD (ft): 9125 4478 7 "x3 -1/2" hes dual feed thru pkr 9493 4671 7 "x3 -1/2" hes dual feed thru pkr 9645 4750 7 "x3 -1/2" hes dual feed thru pkr 9806 4835 7 "x3 -1/2" hes dual feed thru pkr 9979 4928 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/6/2010 Oil ❑ Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ El - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Name attIrown Title PE Signature / Phone Date / f 564 -5874 3/30/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: V v — 091 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [f Location Clearance ❑ Other: Subsequent Form Required: I© ` 4 /0 L i 1 AP ► BY / ( i o Approved by COMMISSIONER THE COMMISSION Date: kt (1 .id RS 1 .. A , P R 0 2 20 - i - io R / /G2 Form 10-403 Revised 12/2009 ORIGINAL Submit in Duplicate V -227 Packer Repair History: V -227 was drilled in Nov -09 as an injector for the Schrader formation supporting the Nb, Oba, Obb, OBd and OBe sands. It was completed with 3 -1/2" tubing and five packers to provide isolation between the individual sands. I -wires and downhole pressure gages show realtime bottom hole pressure. The completion was run on 11/22- 23/09. While setting the packers, initial set pressure was 4500 psi as normal. Pressure in the annulus indicated a leak. Several attempts were made to reset packers, pressuring up tubing to 4700 psi, however, pressure kept leaking off, indicating a poor set. An MIT -T to 3000 psi passed on 2/2/2010 but the MIT -IA on the same date failed. The leak was very small during the MIT -IA and no LLR could be established. One bbl of diesel was pumped down the IA to pressure it up to 500 psi. The pressure bled back to 460 psi during the first 15 min, then to 425 psi at 30 min. Only about a bbl of diesel was required to bump IA pressure back to 500 psi. Objective of Procedure The objective of this job is to place a cement plug in the IA to repair TxIA communication via leaking packer at 9125'. Once the packer leak has been repaired & tested, waterflood regulators will be installed in preparation for putting the well on injection. Job Discussion A composite plug will be set in the tubing tail to isolate the liner for the packer squeeze. The composite will be pressure tested with an MIT -T. Then CT will place a heavy mud pill in the tubing from the composite to about 9100'. This mud pill will prevent cement from getting down in the tubing and potentially causing problems with the various injection mandrels and nipples. The cement will be circulated with CT thru the GL mandrel at 9096' MD and into the IA. A total of / 150' of cement will be left above the GLM. Following placement of cement in the IA, the CT unit will rig down to allow the cement time to set up. Due to the low reservoir temperature ( -90F), the cement will take additional setting time. After 3 days WOC, the cement in the tubing will be milled. Using the CT pump, the tubing & IA will be MIT'd to 4000 psi. Following a successful MITIA, the composite will be milled up and pushed to bottom. The GLM at 9096 will become unusable after the cement job, however, punching holes to circ cement is not possible due to the risk of damaging the i -wires in the annulus. . �� ( y �^ " �p � a��2 �1 r r 4 , t� • Steps Slickline Set dummy valve. Pull PXN plug. Set composite plug. Fullbore Pump MIT -T to test composite Slickline Pull dummy from GLM 10 (9096) Coiled Tubing Cement Packer Squeeze. WOC 3 days - e �� ` Coiled Tubing Mill Cement. MITT and MITIA Coiled Tubing Mill composite & push to bottom- Pending MITIA success • • Current Wel !bore Schematic TREE= CIW WELLHEAD - FMC SAFETY NOTES: WELL ANGLE > 70 @ 3432' ACTUATOR = LEO PJC DRAFT V-227 KB ELEV - 81.3 BF. ELEV = 25 1 X 3-1/2 X0, ID - 2.992"j Max Angle = 71@,, 3049 I 392T 1 X NIP ID 2 813" 1 ° ' • Dat top., 59. @ 913i. 20" CONDUCTOR, ?? 1 I Datum TVD - 4400' SS 129,458, GAS LIFT MANDRELS X-65 re4' ST I MD I - ND 1 DEVI TYPE I VLV I LATCH I PORT! DATE WELDED, ID . ???" VIY6 ' 10190961446:31 59 1 MMG 1 DMY 1 RK 1 0 101/31/10 19-6/8" CSG, 40#, L-80 BTC, ID = 8.835' H 5417' WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE I r csG, 268, L-99 TC11 X0 TO L-80 BTC H 8481' 1--Nr,--- 9 9189 4511 59 MVIG-VV DIVIY RK 0 11/21/09 =11 8 9249 4542 59 MMG-W DMY RK 0 11121/09 7 9557 4705 58 MMG-W DMY RK 0 11/21/09 17" X 3-1/2" HES DUAL FEBD THRU PKR, ID = 2.965" H 9125' I 2S —. 6 9628 4741 59 I,*/G-W RKFS RK - 02/07/10 5 9677 4766 59 IVIVIG-W CAW RK 0 11/21/09 4 9722 4790 59 N/MG-W DMY RK 0 11/21/09 Minimum ID =275 @ 10108' I 3 9870 4869 57 IVNIG-W DEW RK 0 11/21/09 3-1/r HES XN NIPPLE 2 9960 4918 57 RIVIG-W DMY RK 0 11/21109 1 10048 4966 56 IVAMG-W DMY RK 0 11/21109 Mil 9138' I-13-1/2" NDPG MJLTI SUB, ID - 2 992" 3 13-1/2" PUP w / RA TAG H 9479' 1 - t 9159' H3-1/2" HES X NIP ID - 2 81r 3 7" X 3-1/2" I-ES DUAL FEED THRU PKR, ID - 2.965 H 9493' 3 lail • I 9506' H3-1/2" NDFG MULTI SUB, ID = 2 992" [ 17' MARKER PUP w /RA TAG 1 - i 9532' Ft 952T H3-112" HES X NIP, ID 2 813" I=1 I 17" X 3-1/2" HES DUAL FEED THRU PKR, ID - 2 965' 9645' ✓ I 9653' H3-112" NDPG IAJLTI SUFI, ID = 2.992" [ • 1, [ 9664' H3-1/2" HES X NIP, ID - 2 813" [ 0 1=0 PERFORATION SUMMARY 9806' H 7" X 3 -1/2" HES DUAL FEED THRU PKR, ID - 2.965 [ REF LOG' LWD RT GR LOG ON 11/12/09 Z ANGLE AT TOP PERE 57" (p, 9226' 1 9819' H3-1/2" NDPG MJLTI SUB, ID = 2.992" [ Note: Refer to FYoduction DB for historical pert data 11 I 9849' H3-1/2" HES X NIP ID = 2 813" SIZE SW ZONE INTERVAL Opn/Sqz DATE I 4-1/2" 5 Nb 9226 - 9252 0 11/20/09 1 4-1/2" 5 OBa 9578 - 9632 0 11/12/09 4-1I2 5 OBb 9660 - 9696 0 11112/09 9979' H 7. X 3- 1/2" HES DUAL FEED THRU PKR ID - 2 965" 3 4-1/2" 5 OBd 9873 - 9960 0 11/12109 4-112 5 OBe 9992 10032 9992' H3 NDPG SINGLE SUB, ID-2 3 ' - 0 11/12/09 I i I 1002T H31 HES X NIP, ID = 2 813" 3 CO • 3 i - - - - hi — — 11 • 3-1/2" HES X NIP, ID = 2813" 1 10108 H3-1/2" HES XN NIP ID - 2 750" [ 10108 H3-1/2" PXN PLUG (01131/10) [ 33.1/2' TBG, 9 2#, L-80 Tal, .0087 bpf ID= 2 992' 1 - 1 10130' [ • s PBTD 10246' , „ ...... "'"1 „ 10130' H3-117 WLEG, ID= 2 992" [ A H ELMD 37" CSG, 268, L-80 BTC, .0383 bpf, ID = 6,276 1 - 1 10332' ' • " ' ' ''' - ''''' I NOT LOGGED [ DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 11/23/09 N9ES ORIGINAL COMPLETION WELL V-227 02/16110 P.M DRLG DRAFT CORRECTIONS PERMIT No $ 2091160 02/27/10 RPGPJC PXN PLUG/ GLV GO (01/31/10) AR No: 50-029-23417-00 02/27/10 SW/PJC GLV ClO (02/07/10) SEC 11, 71 1N, 911E, 380' FNL & 1533' FEL BP Exploration (Alaska) Page 1 of 2 • Schwartz, Guy L (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 03, 2010 2:04 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: V -227i status (PTD 209 -116) I think MI has been approved in such wells before. I'd throw it back to Zack/Taylor to provide a list of cement packer injection wells. I would think that Anna/Torin would be able to put that together. Tom From: Schwartz, Guy L (DOA) Sent: Wednesday, March 03, 2010 1:58 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: FW: V -227i status (PTD 209 -116) Tom and Jim, FYI... this is a new injector well in the Orion Pool. Was drilled in November 2009 and could never pass the MIT - IA on the rig. Looks like the top packer never set properly so their plan for now is to place a cement packer to get the MIT -IA to pass. Do we have any issues with authorized MI after this kind of repair ? ? ?? The tubing will have holes in it for circulating cement (obviously with cement behind them) ..... it still has to pass MIT's on tubing and IA. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Warren, Mike [mailto:Mike.Warren @bp.com] Sent: Wednesday, March 03, 2010 1:51 PM To: Schwartz, Guy L (DOA) Cc: Sayers, Zach 3 Subject: FW: V -2271 status (PTD 209 -116) Per our conversation, the Wells Group is working on a cement packer repair program. Regards, Mike Warren From: West, Taylor Sent: Wednesday, March 03, 2010 1:44 PM To: Warren, Mike Subject: FW: V -2271 status (PTD 209 -116) From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, March 03, 2010 1:42 PM 3/3/2010 • Page 2 of 2 To: West, Taylor; Sayers, Zach J Subject: V -2271 status (PTD 209 -116) Zach, Did the top packer leak seen during the completion ever get fixed. ? ?? It never passed an MIT -IA that I can see. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 3/3/2010 • Page 1 of 1 Schwartz, Guy L (DOA) From: Warren, Mike [Mike.Warren @bp.com] Sent: Wednesday, March 03, 2010 1:51 PM To: Schwartz, Guy L (DOA) Cc: Sayers, Zach J Subject: FW: V -2271 status9'- 9 -416) Per our conversation, the Wells Group is working on a cement packer repair program. Regards, Mike Warren From: West, Taylor Sent: Wednesday, March 03, 2010 1:44 PM To: Warren, Mike Subject: FW: V -2271 status (PTD 209 -116) From: Schwartz, Guy L (DOA) [ mailto :guy.schwartz @alaska.gov} Sent: Wednesday, March 03, 2010 1:42 PM To: West, Taylor; Sayers, Zach J Subject: V -227i status (PTD 209 -116) Zach, Did the top packer leak seen during the completion ever get fixed. ? ?? It never passed an MIT -IA that I can see. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 3/3/2010 RECEIVED • STATE OF ALASKA • `. ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 I 1- WELL COMPLETION OR RECOMPLETION REPOR 1L C ons COI i *' s't l la. Well Status: ❑ 00 ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended lb. Well Class: AcnC i3F'a e 2OAAC 25.105 20AAC 25.110 ❑ Development ❑ Exploratory ❑ GINJ ❑ WINJ ® WAG ❑ WDSPL ❑ Other No. of Completions One ® Service ❑ Stratigraphic 2. Operator Name: a e gyp., Susp., or Aband.: 12. Permit to Drill Number. BP Exploration (Alaska) Inc. 11/24/2009 209 -116 • 3. Address: 6. Date Spudded: 13. API N I ber: E4-0 g r46 *- l ' u • P.O. Box 196612, Anchorage, Alaska 99519 -6612 11/1/2009 50-1' - 23417 -00 -00 ° 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/12/2009 PBU V - 227i _ 4900' FSL, 1532' FEL, SEC. 11, T11 N, R11E, UM 8. KB (ft above MSL): 81 3' 15. Field / Pool(s): Top of Productive Horizon: 4406' FSL, 1789' FEL,SEC. 01, T11 N, R11E, UM GL (ft above MSL): 53.53 Prudhoe Bay Field / Orion Total Depth: 9. Plug Back Depth (MD +TVD): Schrader Bluff 58' FSL, 1848' FEL, SEC. 36, T12N, R11E, UM 10246' 5080' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 590767 y - 5970150 Zone- ASP4 10340' 5136' ADL028240, ADL028238 TPI: x- 595727 y- 5974998 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 595657 y- 5975928 Zone- ASP4 None 18. Directional Survey: n Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1750' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR / GR, DIR / GR / RES / NEU / AZI DENS, USIT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MO SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 129.45# X -65 Surface 176' Surface 176' 42" 7260 sx Arctic Set 9 -5/8" 40# L -80 29' 5417' 29' 3024' _ 12 -1/4" 829 sx ASL. 417 sx Class 'G' 7" 26# L -80 26' 10332' 26' 5131' _ 8 -3/4" 422 sx Class 'G' • 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD vp If Yes, list each interval open SIZE DEPTH S ET ( n'ACKER A S ET ( MO / TVD (MD+TVD of Top & Bottom; Perforation Size and Number): 4 -1/2" Gun Diameter, 5 spf 3 -1/2 ", 9.2 #, L -80 10130' 4478', 9493' / 4670' MD TVD MD TVD Packers - Continued: 9645' / 4750' 9806' / 4834', 9979' / 4928' 9226' - 9252' 4530' - 4544' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9578' - 9632' 4715' - 4743' 9660' - 9696' 4758' - 4776' DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 9873' - 9960' 4871' - 4918' 2500' Freeze Protected w/ 138 Bbls of Diesel 9992' - 10032' 4935' - 4957' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL - BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes : No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. GOMPLEI oil None _ Rii A VI l omit Form 10-407 Revised 07/2009 CONTINUED ON REVERSE ubmit Original Only t-3r 2 -� 3 ` '/6 6J4' a 6 29. GEOLOGIC MARKERS (List all formations and ma .- encountered): 30. • RMATION TESTS { NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top 28.5' 28.5' If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 1983' 1779' results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 5354' 3001' Ugnu MA 8692' 4271' None Ugnu MB1 8775 4310' Ugnu MB2 8884' 4361' Ubnu MC 9046' 4438' Schrader Bluff NA 9178' 4505' Schrader Bluff NB 9228' 4531' Schrader Bluff NC 9264' 4550' Schrader Bluff NE 9285' 4561' Schrader Bluff NF 9395' 4619' Schrader Bluff OA 9456' 4651' Schrader Bluff OBa 9579' 4716' Schrader Bluff OBb 9662' 4759' Schrader Bluff OBc 9778' 4819' Schrader Bluff OBd 9873' 4871' Schrader Bluff OBe 9988' 4933' Schrader Bluff OBf 10081' 4984' Schrader Bluff Base / 10163' 5032' Top Colville Mudstone Formation at Total Depth (Name): Colville Mudstone 10163' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. / A A Signed: Terrie Hubble 11l 11114. 111 t r # Title: Drilling Technologist Date: PBU V - 227i 209 - 116 Prepared By Name/Number: Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Zach Sayers, 564-5790 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123-00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only BP Page 1 of 1 Leak -Off Test Summary Legal Name: V -227 Common Name: V -227 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 11/10/2009 LOT 5,428.0 (ft) 3,024.0 (ft) 8.80 (ppg) 612 (psi) 1,994 (psi) 12.70 (ppg) • Printed: 12/10/2009 11:17:11 AM • BP Page 1 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date, From - To Hours Task Code . NPT Phase Description of Operations 10/26/2009 00:00 - 02:00 2.00 MOB P PRE DSM INSTALL VR PLUGS IN ANNULUS VALVES ON S -218. - SECURE CELLAR & TOP DRIVE. - OFFLOAD FLUID IN PITS. 02:00 - 04:00 2.00 MOB P PRE DISCONNECT HARD LINES & ELECTRICAL LINES. -BLOWN DOWN PITS & PREPARE FOR RIG MOVE. 04:00 - 06:00 2.00 MOB P PRE PJSM W/ PEAK & RIG HANDS ON MOVING PITS. -MOVE PITS AWAY FROM RIG SUBSTRUCTURE TO THE EDGE OF S -PAD. -START GENERATOR #1, FUNCTION TEST MOVING SYSTEM. 06:00 - 10:00 4.00 MOB P PRE RIG DOWN FOR MOVE. -CPS DISCONNECT HIGH LINE POWER. 10:00 - 12:00 2.00 MOB P PRE PJSM ON MOVING RIG. -JACK RIG UP, REMOVE MATS & HERCULITE. 12:00 - 15:30 3.50 MOB P PRE MOVE RIG OFF S -218 TO EDGE OF S -PAD. 15:30 - 00:00 8.50 MOB N RREP PRE DOUBLE MAT RIG ON MAIN BEAMS BEHIND FRONT & REAR TIRES 7 & 8. -CLEAN & CLEAR WHEELHOUSE. - REMOVE CELLAR DOORS, BOP LANDINGS, HOSES AND LINES. 10/27/2009 00:00 - 02:00 2.00 MOB N RREP PRE PJSM, CONTINUE TO REMOVE KILL LINE & SECONDARY KILL LINE. NEAR MISS / DROPPED OBJECT. - WHILE REMOVING THE SECONDARY CHOKE LINE DURING RIG DOWN OPERATIONS, A STUD BOLT APPROXIMATELY 3/4" X 9" WAS DROPPED FROM A MAN LIFT ONTO THE GROUND BELOW. APPROXIMATELY 20'. STOP THE JOB ACTION OCCURED. (SEE REMARKS). TRACTION REPORT # 2009 -IR- 3278069. 02:00 - 12:00 10.00 MOB N RREP PRE RESUME OPERATIONS REMOVING KILL LINE AND SECONDARY KILL LINE. - ATTEMPT TO SECURE BOPE ON NEW CRADLE. - UNABLE TO SET DOWN BOPE ON CRADLE DUE TO POSITION OF HCR STEM. - REMOVE HCR CHOKE & KILL LINE, MUD CROSS & ADAPTER FLANGE FROM BOPE. - SECURE BOPE TO CRADLE, STAGE NEAR PITS. - REMOVE MUD CROSS FROM CELLAR, CONTINE REMOVING KILL & SECONDARY KILL LINE. 12:00 - 18:00 6.00 MOB N RREP PRE PULL PINS & REMOVE CELLAR WALLS. - TROUBLESHOOT & REPAIR SHAKER SWITCHES IN PITS. - CANRIG INSTALL WIRING FOR NEW PIT VOLUME SYSTEM. -PREP & PULL AXLE ASSY & WHEELS OUT OF WHEEL ROOM. - SECURE WHEELS W/ BRIDGE CRANE IN CELLAR AREA. -PJSM W/ RIG HANDS & PEAK TIRE HAND ON BLIND LIFTING OPERATIONS. - REMOVE NUTS FROM STUDS ON TIRE #7. 18:00 - 20:00 2.00 MOB N RREP PRE TUBOSCOPE ON LOCATION FOR FORKLIFT FORK INSPECTION / CERTIFICATION, SECURE CELLAR. - INSTALL CUTTINGS BOX, REPAIR HOLE FILL LINE, MOVE Printed: 12/17/2009 11:56:31 AM • BP Page 2of31 Operations Summary Repor Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operat 10/27/2009 18:00 - 20:00 2.00 MOB N RREP PRE SUBS WHILE WAITING FOR LOADER CERTIFICATION. 20:00 - 00:00 4.00 MOB N RREP PRE TUBOSCOPE INSPECTION COMPLETE. - CONTINUE TO CHANGE OUT TIRE # 7 & 8. 10/28/2009 00:00 - 05:00 5.00 MOB N RREP PRE CHANGE OUT TIRE # 8. - POSITION TIRES IN WHEEL ROOM & SECURE AXLE SADDLES & STEERING ARM. INSTALL CELLAR SPREADER WALL. 05:00 - 10:00 5.00 MOB N RREP PRE INSTALL KILL LINES, SECONDARY KILL LINES & AUXILIARY CHOKE LINES. - INSTALL TRASH PUMP & 2" STEAM LINES IN PITS. - INSTALL CHOKE LINE. 10:00 - 14:00 4.00 MOB N RREP PRE WELDER CUT BOPE STUMP FROM PEDISTAL. -WELD NEW STUMP ON PEDISTAL. REPLACE BRACKET FOR HOLE FILL LINE. 14:00 - 16:30 2.50 MOB N RREP PRE PJSM W/ PEAK CRANE OPERATOR & RIG PERSONNEL. - REMOVE DIVERTER LINES FROM S -218. PEAK TIRE TECHNICIAN TORQUE WHEEL STUDS. CONTINUE WORK ON SHAKERS & INSTALLATION OF CANRIG SYSTEM. 16:30 - 21:30 5.00 MOB N RREP PRE PJSM W/ CH2MHILL TRUCK DRIVER & RIG PERSONNEL. - SECURE BOPE IN CELLAR. - INSTALL CHOKE & KILL HCR'S & 13 5/8" X 11" ADAPTER SPOOL ON BOPE. -SET BOPE ON PEDESTAL, MAKE UP CHOKE & KILL LINES. 21:30 - 00:00 2.50 MOB N RREP PRE INSTALL WIND WALLS, CELLAR BOP LANDINGS, MAKE UP HYDRAULICS. 10/29/2009 00:00 - 03:00 3.00 MOB N RREP PRE CONTINUE WORK IN CELLAR - CHANGE OUT CHOKE HOSE SHACKLE. - INSTALL HOLE FILL LINE & NEW GASKET. 04:00 - 06:00 2.00 MOB N RREP PRE INSTALL ACCUMULATOR LINES & CHOKE HOSE ON BOPE. - SECURE BOPE TO PEDESTAL. 05:30 - 12:00 6.50 MOB N RREP PRE SERVICE RIG BRIDLE UP BLOCKS. - SECURE RIG FLOOR. -RIG UP & LOWER CATTLE CHUTE. -RAISE RIG, REMOVE MATS FROM AROUND RIG. 12:00 - 16:30 4.50 MOB N RREP PRE INSTALL SECONDARY RESTRAINT LINE TO CELLAR DOOR & TAYLOR CAMP LIGHTS. - MODIFY WATER HOSE PLACEMENT ON RIG FLOOR & 3" RETURN LINE TO FLOW LINE. -WELD PAD EYE ON FOR BEAVER SLIDE FALL ARREST. NCITIFIFn AO(,CC a 14.00 I - )I IRS Fl1R I IPCOMIN(=, DIVERTER TEST, CHUCK SCHEVE WAIVED WITNESS. 16:30 - 00:00 7.50 MOB P PRE LOWER DERRICK,STRAIGHTEN BOARD FINGERS, REPAIR BEAVERSLIDE DOOR. -PJSM WITH RIG PERSONNEL & PURCELL SECURITY, ON MOVING RIG. -MOVE RIG FROM S -PAD. -SET RIG DOWN ON S -PAD ACCESS ROAD TO CHECK Printed: 12/17/2009 11:56:31 AM • 1 BP Page3of3l Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 10/29/2009 16:30 - 00:00 7.50 MOB P PRE TIRE LUG NUTS. - PROCEED TO V -227. 10/30/2009 00:00 - 04:00 4.00 MOB P PRE CONTINUE MOVE FROM S -218 TO V -227 04:00 - 09:30 5.50 MOB P PRE CLEAR SNOW AND INSTALL DIVERTER LINE. - PLACE WELLHEAD EQUIP BEHIND WELL. -MOVE SHOPS AND CAMPS FROM S -PAD TO V -PAD. 09:30 - 16:00 6.50 MOB P PRE MOVE IN & SPOT RIG SUBSTRUCTURE ON V -227. -LAY MATS & HERCULITE. -PJSM W/ PEAK & RIG CREW ON SPOTTING PITS -SPOT AND LEVEL PITS. - CONTINUE INSTALLATION OF NEW EPOCH SYSTEM IN PITS. 16:00 - 00:00 8.00 RIGU P PRE PJSM. INSPECT & RAISE, DERRICK & CATTLE CHUTE. - BRIDLE DOWN. RIG UP RIG FLOOR - CONNECT HARD LINES & KELLY HOSE. - CONTINUE INSTALLATION OF NEW EPOCH SYSTEM IN PITS. 10/31/2009 00:00 - 01:00 1.00 RIGU P PRE SAFETY MEETING WITH NEW CREW COMING ON SLOPE TO REVIEW NABORS OPERATIONS SAFETY PLAN. 01:00 - 12:00 11.00 RIGU P PRE REMOVE A -LEG BRACE. -PLACE SUBS ON RACK, HANG RIG TONGS, SECURE WALKWAYS. - CHANGE OUT PUMP LINERS FROM 5" TO 5 -1/2" - MEASURE RKB TO GL DISTANCE. - INSTALL SURFACE RISER & 4" DUMP VALVES. - CHANGE OUT TOP DRIVE QUILL, CLEAR PIPESHED. - CANRIG CONTINUE INSTALLATION OF NEW RIGWATCH SYSTEM. - WELDER INSTALL RADAR SENSOR BRACKETS IN PILL PIT & PIT #2 . -RIG ACCEPT FOR OPERATIONS ON V -227 AT 12:00 HRS ON 10/31/2009.- 12:00 - 17:00 5.00 RIGU P PRE CONTINUE WITH EPOCH INSTALLATION. -LOAD & STRAP 150 JOINTS 4" DP IN PIPE SHED FOR TARGET TD OF 5,440' MD. -TAKE ON 465 BBL OF 8.5 PPG DRILPLEX SPUD MUD TO PITS. TOP OFF BST'S W/ COLD LAKE WATER. - CALIBRATE H2S ALARMS. - COMPLETE INSTALLATION OF DIVERTER LINE. PJSM FUNCTION TFST DIVFRTFR & PERFORM ACCUMULATOR DRAW DOWN TEST. -TEST WITNESSED BY: BP WSL'S BLAIR NEUFELD & NABORS TOOLPUSHER BRUCE SIMONSON. WITNESS OF TEST WAIVED BY AOGCC REP CHUCK SCHEVE. 17:00 - 00:00 7.00 RIGU P PRE MAKE UP 5" HWDP BHA TO DRILL OUT ICE IN CONDUCTOR. -TAG UP ON ICE @ 28', DRILL OUT TO 100' MD. -PRE SPUD CHECKLIST COMPLETE. -PRE SPUD MEETING W/ BP WSL & ALL RIG PERSONNEL 23:00 HOURS. Printed: 12/17/2009 11:56:31 AM • • 4 BP Page 4of31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/1/2009 00:00 - 01:00 1.00 RIGU P PRE LAY DOWN 12 -1/4" CLEANOUT BHA 01:00 - 10:30 9.50 RIGU P PRE INSTALL SECONDARY MOUSE HOLE IN ROTORY TABLE. -PICK UP 4" DP 1X1 FROM PIPE SHED. -RACK BACK 50 STANDS 4" DP, 6 STANDS 4" HWDP. -PULL MOUSE HOLE FROM ROTORY TABLE. 10:30 - 15:00 4.50 RIGU P PRE SLIP / CUT 75' OF DRILLING LINE. - SERVICE TOP DRIVE, SET BLOCK HEIGHT FOR MWD. 15:00 - 16:30 1.50 RIGU P PRE PJSM W/ RIG PERSONNEL, SPERRY & GYRO DATA. -RIG UP GYRO DATA. 16:30 - 18:30 2.00 RIGU P PRE PJSM / PRE -SPUD MEETING W/ WSL'S & RIG PERSONNEL. - REVIEW NABORS SAFE PLAN. 18:30 - 20:00 1.50 RIGU P PRE DIVERTER / RIG EVACUATION DRILL. - REVIEW DRILL W/ WSL, RIG PERSONNEL & ALL THIRD PARTY CONTRACTORS INVOLVED. 20:00 - 22:00 2.00 RIGU P PRE PJSM, PICK UP BHA #1. - 12 -1/4" BIT, 1.83 MOTOR, UBHO, XO'S, 18 JTS. HWDP. - PRESSURE TEST SURFACE LINES TO 3,000 PSI. 22:00 - 00:00 2.00 DRILL P SURF ROTARY DRILL INSIDE CONDUCTOR TO 171'. _ -520 GPM @ 440 PSI, 40 RPM, TQ 800 FT /LB. -@ - 23:05 THE FLOW LINE PLUGGED OFF CAUSING MUD TO FILL UP THE RISER & DRIP PAN. THE DRIP PAN OVERFLOWED INTO THE CELLAR AREA. APPROXIMATELY 2 BBL OF DRILPLEX MUD WAS RELEASED INTO CELLAR CONTAINMENT. 2 GAL OF MUD LEAKED FROM THE CELLAR CONTAINMENT ONTO THE SNOW OUTSIDE OF THE CELLAR. SRT, V -PAD OPERATOR, & RIG SUPERVISORS NOTIFIED. IR #2009 -IR- 3285973 11/2/2009 00:00 - 04:30 4.50 DRILL N FLUD SURF POH W/ BHA #1, STAND BACK BHA. -PJSM W/ RIG PERSONNEL & CH2M HILL. -VAC TRUCK, CLEAN CELLAR & ROTARY TABLE. 04:30 - 05:00 0.50 DRILL P SURF RIH W/ BHA #1 TO 123', WASH DOWN TO 175' MD. -500 GPM @ 494 PSI. 05:00 - 08:00 3.00 DRILL P SURF DRILL AHEAD FROM 175' TO 309' MD, -PUW 53, SOW 50, RWT 50. -167 SPM, 500 GPM @ 540 PSI. 40 RPM, TQ 500. -GYRO SURVEY 190' & 282' MD. AST =0 ART =0.56 08:00 - 09:30 1.50 DRILL P SURF POH FROM 309' MD, LAY DOWN BHA # 1 09:30 - 14:00 4.50 DRILL P SURF PICK UP BHA #2. -12 1/4" BIT, 1.83 MOTOR, NMLC, NM STAB, MWD, UBHO, NM STAB, NM XO, 7" DC'S, SAVER SUB, HWDP, JARS, HWDP. 14:00 - 00:00 10.00 DRILL P SURF DRILL AHEAD FROM 309' TO 1,011' MD. -PUW 77, SOW 68, RWT 71, -40 RPM, 4 -5K TQ ON, 3K TQ OFF. -185 SPM, 550 GPM @ 1,150 PSI ON, 950 PSI OFF. AST =1.84 ART =1.88 Printed: 12/17/2009 11:56:31 AM BP Page 5 of 31 Operat Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/2/2009 14:00 - 00:00 10.00 DRILL P SURF FLUID LOSSES FOR TODAY: 159 BBL 11/3/2009 00:00 - 00:30 0.50 DRILL P SURF RD GYRO UNIT. 00:30 - 03:00 2.50 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 1011' TO 1060' MD. - PUMP AT 550 GPM WITH 1050 PSI ON, 960 PSI OFF - AST 0.48 HRS, ART 0.32 HRS, ADT 0.8 HRS, BIT 4.55 HRS - PUW 95K, SOW 80K, ROTW 80K - 40 RPM, 20K WOB, 5K TORQUE ON, 4K TORQUE OFF - ADDED 25 - 30 OF WATER PER HOUR - MW IN / OUT 8.9 PPG - NO SIGNIFICANT FLUID LOSS NOTED - WIPE 30' ON CONNECTION DIRECTIONAL DRILLER UNABLE TO SLIDE DUE TO STABILIZER HANGING UP. DECISION MADE TO POH AND LD STABILIZER ABOVE THE MOTOR. 03:00 - 03:30 0.50 DRILL P SURF CIRCULATE TWO BOTTOMS UP AT 560 GPM WITH 967 PSI. MONITOR WELL - STATIC. 03:30 - 04:00 0.50 DRILL P SURF POH WITH SURFACE HOLE DRILLING BHA #2 FROM 1060' MD TO 271' MD. MW IN / OUT 8.9 PPG 04:00 - 06:00 2.00 DRILL P SURF LAY DOWN UBHO SUB AND 12 1/4" NM STABILIZER LOCATED AT 43' BEHIND THE BIT. 06:00 - 07:00 1.00 DRILL P SURF PICK UP 12 1/4" DRILLING BHA #3 AS FOLLOWS: 12 1/4" MXL -1X HUGHES, 9 5/8" 1.83 DEG BENT MUD MOTOR, NMLC, MWD, NM STAB, 7" NMDC, NM STAB, 7" NMDC, 5" HWDP, JARS, 5" HWDP. 07:00 - 08:00 1.00 DRILL P SURF RIH WITH 12 1/4" DRILLING BHA #3 FROM 263' MD TO 1003' MD. WASH DOWN FROM 1003' MD TO 1060' MD AT 530 GPM WITH 989 PSI, NO FILL FOUND ON BOTTOM. MW IN / OUT 8.9 PPG 08:00 - 12:00 4.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 1060' TO 1243' MD. - PUMP AT 550 GPM WITH 1210 PSI ON, 1080 PSI OFF - 100% SLIDE, AST 2.03 HRS, ADT 2.03 HRS, BIT 6.58 HRS - PUW 85K, SOW 80K, 20K WOB - ADDED 25 - 30 OF WATER PER HOUR - MW IN / OUT 8.9 PPG - NO SIGNIFICANT FLUID LOSS NOTED - WIPE 30' ON CONNECTION 12:00 - 00:00 12.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 1243' TO 2260' MD. - PUMP AT 600 GPM WITH 1550 PSI ON, 1450 PSI OFF - AST 6.82 HRS, ART 1.28 HRS, ADT 8.1 HRS, BIT 14.68 HRS - PUW 85K, SOW 80K, ROTW 80K - ADDED 25 - 30 BBLS OF WATER PER HOUR - MW IN / OUT 8.9 PPG - NO SIGNIFICANT FLUID LOSS NOTED - WIPE 30' ON CONNECTION OR BACKREAM AS HOLE DICTATES 11/4/2009 00:00 - 00:30 0.50 DRILL P SURF CONTINUE TO DRILL AHEAD FROM 2260' MD TO END OF BUILD SECTION AT 2340' MD. - PUMP AT 650 GPM WITH 1760 PSI OFF, 1850 PSI ON - 40 RPM, 4.5K TORQUE ON, 4K TORQUE OFF Printed: 12/17/2009 11:56:31 AM 41, , BP Page 6of31` Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/4/2009 00:00 - 00:30 0.50 DRILL P SURF - PUW 94K, SOW 73K, ROTW 80K - ART 0.18 HRS, AST 0.39 HRS, ADT 0.57 HRS, BIT 15.25 HRS. - MW IN / OUT 9.0 PPG - NO SIGNIFICANT LOSSES NOTED WHILE DRILLING AHEAD 00:30 - 01:00 0.50 DRILL P SURF CIRCULATE ONE BOTTOMS UP AT 650 GPM WITH 1860 PSI, WHILE RECIPROCATING AND ROTATING DRILL STRING AT 40 RPM WITH 4.9K - 5.8K TORQUE, ROTW 75K, PUW 98K, SOW 74K. SHAKERS CLEAN UP CONSIDERABLY AFTER RETURN OF BOTTOMS UP. MW IN / OUT 9.0 PPG 01:00 - 03:00 2.00 DRILL P SURF POH ON ELEVATORS FROM 2340' MD TO 2160' MD. ENCOUNTERED TIGHT SPOT AT 2160' MD WITH 20K OVERPULL, WIPED SPOT TWICE. CONTINUE TO POH FROM 2160' MD TO 2105' MD. ENCOUNTERED 25K OVERPULL AT 2105' MD, WIPED TIGHT SPOT. CONTINUE TO POH FROM 2105' AND ENCOUNTERED 35K OVERPULL AT 2087 MD, ATTEMPT TO WIPE OUT THREE TIMES WITH NO SUCCESS. KELLY UP AND PUMP OUT OF HOLE FROM 2130' MD TO 1945' MD AT 518 GPM WITH 1215 PSI. POH ON ELEVATORS FROM 1945' MD TO 1723' MD WITH NO OVERPULLS GREATER THAN 20K. ATTEMPT TO WIPE OUT 15' TIGHT SPOT AT 1723' MD WITH 25K OVERPULL WITH NO SUCCESS. KELLY UP AND PUMP OUT OF HOLE FROM 1723' MD TO 1033' MD WITH NO ISSUES. MW IN / OUT 9.0 PPG. 03:00 - 04:00 1.00 DRILL P SURF CONTINUE TO POH FROM 1033' MD TO BHA AT 263' MD. MW IN / OUT 9.0 PPG 04:00 - 05:30 1.50 DRILL P SURF STAND BACK SURFACE DRILLING BHA #3 AND REMOVE BIT. BIT GRADE: 1- 2- WT- A- E -I -SS -BHA. ALL BHA COMPONENTS IN GAUGE. 05:30 - 06:00 0.50 DRILL P SURF MU NEW 12 1/4" HUGHES MXL -1X TO SURFACE DRILLING BHA #4. 06:00 - 06:30 0.50 DRILL P SURF CLEAN AND CLEAR RIG FLOOR. 06:30 - 07:30 1.00 DRILL P SURF ADJUST BENT IN 9 5/8" MUD MOTOR FROM 1.83 DEG TO 1.5 DEG. PICK UP NM STABILIZER WITH 12 1/4" BLADE OD AND PLACE ABOVE MOTOR (43' BEHIND THE BIT). 07:30 - 08:30 1.00 DRILL P SURF SERVICE TOP DRIVE AND DRAWWORKS. 08:30 - 09:00 0.50 DRILL P SURF PICK UP NM COLLARS AND JAR STAND TO MAKE UP SURFACE DRILLING BHA #4 AS FOLLOWS: 12 1/4" MXL -1X HUGHES BIT, 9 5/8" 1.5 DEG BENT MUD MOTOR, NMLC, NM STAB, MWD, NM STAB, 7" NMDC, NM STAB, 7" NMDC, 5" HWDP, JARS, 5" HWDP. 09:00 - 11:00 2.00 DRILL P SURF RIH WITH DRILLING BHA #4 FROM 269' MD TO 1009' MD Printed: 12/17/2009 11:56:31 AM • 0 BP Page 7of31; Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/4/2009 09:00 - 11:00 2.00 DRILL P SURF WITH 6 STDS OF 4" HWDP AND 4" DP TO SURFACE. SHALLOW TEST MWD AT 440 GPM WITH 1088 PSI, GOOD TEST. CONTINUE TO RIH FROM 1009' MD TO 1520' MD. TOOK -15K DOWN WEIGHT AT 1520' MD, WIPED SPOT, NO ISSUES. CONTINUE TO RIH FROM 1520' MD TO 1950' MD. NO FILL ON BOTTOM. MW IN / OUT 9.0 PPG. 11:00 - 12:30 1.50 DRILL P SURF REAM DOWN FROM 1950' MD TO BOTTOM AT 2340' MD AT 513 GPM WITH 1990 PSI, ROTATING AT 60 RPM WITH 4K -5K FT -LBS TORQUE. 12:30 - 13:00 0.50 DRILL P SURF STAGE UP PUMPS AS FOLLOWS: 333 GPM WITH 1055 PSI 514 GPM WITH 1992 PSI 623 GPM WITH 2044 PSI 653 GPM WITH 2083 PSI 13:00 - 15:00 2.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 2340' TO 2540' MD. - PUMP AT 650 GPM WITH 2250 PSI ON, 2140 PSI OFF - 80 RPM, 6K - 8K TORQUE ON, 4K - 5K TORQUE OFF - ADD 25 BBLS OF WATER PER HOUR - MW IN / OUT 9.1 PPG - NO SIGNIFICANT FLUID LOSS NOTED - BACKREAM 30' ON CONNECTION LOST -235 PSI WHILE DRILLING AT 2540' MD WITH 713 GPM. 15:00 - 16:00 1.00 DRILL N DPRB SURF INSPECT ALL SURFACE EQUIPMENT. TROUBLE SHOOT BOTH PUMPS, PUMP NO. 2 CAVITATING. CLEAN PUMP NO. 2 SCREENS, FLUSH SUCTION LINES, NO SIGNIFICANT AMOUNT OF DEBRIS FOUND IN SCREENS OR SUCTION LINES. 16:00 - 22:00 6.00 DRILL P SURF CONTINUE TO DRILL AHEAD IN 12 1/4" HOLE FROM 2540' MD TO 3300' MD. - PUMP AT 650 GPM WITH 2713 PSI ON, 2574 PSI OFF - 90 RPM, 8K - 9K FT -LBS TORQUE ON, 25K WOB. SOME DIFFICULTY SLIDING DUE TO HOLE GEOMETRY, ADD 0.25 % LOTORQ TO MUD SYSTEM. LOST -1000 PSI WHILE DRILLING AT 3300' MD. INSPECT SURFACE EQUIPMENT, GOOD. DRILPLEX MUD AIRED UP DUE TO HYDRATES. MIX NEW MUD FROM PILL PIT INTO ACTIVE SYSTEM PIT, ADD SCREEN KLEEN, ADD DEFOAMER AND ACTIVATE DEGASER WHILE WORKING PIPE IN 30' STROKES AND PUMPING AT 486 GPM WITH 1242 PSI FOR ABOUT 30 MINUTES. MAKE NEXT CONNECTION, BRING PUMPS UP TO 655 GPM WITH PRESSURE FULLY RESTORED (2475 PSI OFF BOTTOM). DRILLING BHA DROPPING APPROXIMATELY 1 - 1.5 DEG /100 FT WHILE ROTATING. 22:00 - 00:00 2.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 3300' TO 3333' MD. - PUMP AT 650 GPM WITH 2710 PSI ON, 2565 PSI OFF - 85 RPM, 7.7K - 8.2K FT -LBS TORQUE ON, 4.5K FT -LBS Printed: 12/17/2009 11:56:31 AM • BP Page 8 of 31' Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/4/2009 22:00 - 00:00 2.00 DRILL P SURF TORQUE OFF, 25K WOB. - AST 3.0 HRS, ART 2.14 HRS, ADT 5.14 HRS, BIT 5.14 HRS - PUW 98K, SOW 65K, ROTW 80K - ADD 25 BBLS OF WATER PER HOUR - MW IN / OUT 9.1 PPG - NO SIGNIFICANT FLUID LOSS NOTED - BACKREAM 30' ON CONNECTION CONTINUE TO ENCOUNTER HYDRATES INTERMITTENTLY. 11/5/2009 00:00 - 12:00 12.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 3333' TO 4670' MD. - PUMP AT 650 GPM WITH 3000 PSI ON, 2800 PSI OFF - 80 RPM, 8K - 9K FT -LBS TORQUE ON, 5K - 6K FT -LBS TORQUE OFF, 30K WOB. - AST 3.63 HRS, ART 3.44 FIRS, ADT 7.07 HRS, BIT 12.21 HRS - PUW 115K, SOW 75K, ROTW 90K - ADD 25 - 40 BBLS OF WATER PER HOUR - MW IN / OUT 9.5 PPG - NO SIGNIFICANT FLUID LOSS NOTED - BACKREAM 30' ON CONNECTION CONTINUE TO ENCOUNTER HYDRATES FROM 3333' MD TO -3600' MD 12:00 - 20:00 8.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE FROM 4670' TO SURFACE CASING POINT AT 5428' MD (3028' TVD) IN A SHALE BED IN THE UG4 FORMATION. - PUMP AT 650 GPM WITH 3300 PSI ON, 3100 PSI OFF - 80 RPM, 8K - 9K FT -LBS TORQUE ON, 5K - 6K FT -LBS TORQUE OFF, 30K WOB. - AST 1.93 HRS, ART 3.05 HRS, ADT 4.98 HRS, BIT 17.19 HRS - PUW 125K, SOW 80K, ROTW 90K - ADD 25 BBLS OF WATER PER HOUR - MW IN / OUT 9.4 PPG - NO SIGNIFICANT FLUID LOSS NOTED - BACKREAM 30' TO FULL STAND ON CONNECTION BASED ON HOLE CONDITIONS ENCOUNTER HYDRATES AT 4926' MD. 20:00 - 22:30 2.50 DRILL P SURF LD 1 4" DP JOINT. CIRCULATE THREE BOTTOMS UP WHILE BACK REAMING FULL STAND WITH THE FOLLOWING PARAMETERS. - 656 GPM, ICP 3148 PSI, FCP 2786 PSI - 86 RPM, 6.2K FT -LBS TORQUE - PUW 115K, SOW 75K, WHILE PUMPING AT 656 GPM. NOTE: 15% - 20% REDUCTION IN CUTTINGS WITH RETURN OF FIRST BOTTOMS UP. 5% - 10% INCREASE IN CUTTINGS WITH RETURN OF SECOND BOTTOMS UP, MOSTLY CLAY AND SAND. 10% REDUCTION IN CUTTINGS WITH RETURN OF THIRD Printed: 12/17/2009 11:56:31 AM Bp Page 9 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/5/2009 20:00 - 22:30 2.50 DRILL P SURF BOTTOMS UP, SHAKERS LOOK CLEAN. 22:30 - 00:00 1.50 DRILL P SURF PICK UP 1 4" DP JOINT AND TAG BOTTOM AT 5428' MD WITH PUMPS OFF WITH NO ISSUES. PUW 125K, SOW 77K. POH FROM 5428' MD TO 5230' MD WITH INTERMITTENT SWABBING. ENCOUNTERED TIGHT SPOT AT 5230' MD AND 5208' MD WITH 25K OVER PULL, WIPED OUT, NO ISSUES. CONTINUE TO POH FROM 5208' MD TO 5197 MD. ENCOUNTERED 35K OVERPULL, STICKY ON DOWN STROKE (LOST -25K DOWN WEIGHT). ATTEMPT TO WIPE OUT SPOT WITHOUT SUCCESS. KELLY UP AND WORK SPOT SEVERAL TIMES WHILE PUMPING AT 566 GPM WITH 2560 PSI. GO THROUGH TIGHT SPOT WITH PUMPS OFF WITH NO ISSUES. CONTINUE TO POH FROM 5197 MD AND ENCOUNTERED 35K OVERPULL AT 5101' MD. DECIDE TO PUMP OUT OF HOLE AT 500 GPM WITH 2086 PSI FROM 5101' MD TO 5000' MD. MW IN / OUT 9.4 PPG. 11/6/2009 00:00 - 01:30 1.50 DRILL P SURF CONTINUE TO POH FROM 5000' MD TO 4729' MD WHILE PUMPING AT 500 GPM WITH 1866 PSI. LOST -5K IN UP WEIGHT AND GAINED -100 PSI AT 4729' MD, SLIGHT PACK OFF. CONTINUE TO POH WHILE PUMPING, ENCOUNTERED SECOND PACK OFF AT 4715' MD. CONTINUE TO TO 4620' MD WHILE PUMPING AT 509 GPM WITH 1878 PSI, SLIGHT PACK OFF. PERIODICALLY ATTEMPT TO PULL ON ELEVATORS, 100% SWABBING. DRILL STRING ROTATING WHILE POH INDICATING STABILIZER HANGING UP. MW IN / OUT 9.4 PPG 01:30 - 14:30 13.00 DRILL P SURF BACKREAM OUT FROM 4620' MD TO 4425' MD WITH FOLLOWING PARAMETERS: - 515 GPM, 2098 PSI - 80 RPM, 6.5K FT -LBS TORQUE CONSIDERABLE INCREASE IN SAND, CLAY AND COAL RETURNS THROUGH SHAKERS. CONTINUE TO BACKREAM OUT FROM 4425' MD TO 2780' MD WITH INCREASED FLOW RATE AS FOLLOWS: - 653 GPM, 2909 PSI - 80 RPM, 6.5K FT -LBS TORQUE SHAKERS CLEAN UP AT -4100' MD. Printed: 12/17/2009 11:56:31 AM • • BP Page 10 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/6/2009 01:30 - 14:30 13.00 DRILL P SURF REDUCE PUMP RATE TO 450 GPM FROM 2780' MD TO 818' MD (BHA LENGTH) AS FOLLOWS: - 450 GPM, 835 PSI - 80 RPM, 2.9K FT -LBS TORQUE MW IN / OUT 9.4 PPG TOTAL OF 92 BBLS OF DRILPLEX LOST TO FORMATION FOR TOH. 14:30 - 19:00 4.50 DRILL P SURF LD SURFACE DRILLING BHA #4, STAND BACK 6 STANDS OF 4" HWDP, JARS AND COLLAR STAND. BIT GRADE: 1- 2- WT- A- E- I- SS -TD. ALL BHA COMPONENTS IN GAUGE. 19:00 - 20:00 1.00 DRILL P SURF CLEAN AND CLEAR RIG FLOOR. 20:00 - 00:00 4.00 CASE P SURF RU TO RUN 9 5/8" 40# L -80 SURFACE CASING. BU FRANK'S FILL -UP TOOL AND 350 TON ELEVATORS, PERFORM DUMMY RUN WITH 9 5/8" MANDREL HANGER AND CONFIRM RKB ELEVATION OF 28.75'. 11/7/2009 00:00 - 02:30 2.50 CASE P SURF CONTINUE TO RU TO RUN 9 5/8" 40# L -80 SURFACE CASING. 02:30 - 00:00 21.50 CASE P SURF MU 9 5/8" 40# L -80 SURFACE CASING SHOE TO 8,500 FT -LBS AND BAKER -LOK. FILL PIPE AND TEST FLOATS - GOOD. RUN IN THE HOLE WITH 9 5/8" 40# L -80 TO 1480' MD,. TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8,500 FT -LBS. FILLED EVERY JOINT USING THE FRANK'S TOOL AND CIRCULATE EVERY 10TH JOINT AT 3 BPM WITH 133 PSI. LOST -30K LBS DOWN WEIGHT AT 1480' MD. WORK PIPE WHILE PUMPING AT 4 BPM WITH 163 PSI, GOOD. BEGIN TO CIRCULATE DOWN EVERY 5TH JOINT AT 4.5 BPM WITH 274 PSI. I ()SING APPROXIMATELY 13 BBLS DRILPLEX MUD PER HOUR WHII F RUNNING 9 5/8" CASING. CONTINUE RUNNING 9 5/8" SURFACE CASING FROM 1480' MD TO 3940' MD. FLUID LOSS RATE TAPERED DOWN TO -5 BBLS PER HOUR AT 3940' MD. CASING RUNNING SPEED REDUCED TO 5 FT /MIN. CONTINUE TO RUN 9 5/8" SURFACE CASING FROM 3940' MD TO 5115' MD, CASING STRING TOOK 25K DOWN WEIGHT AT 4836' MD, WASH DOWN FULL JOINT AT 3.6 BPM WITH 470 PSI, NO FURTHER ISSUES. PUW 190K, SOW 110K AT 4923' MD. MOSTLY SAND COMING ACROSS SHAKERS. MW IN / OUT 9.4 PPG. TOTAL OF 148 BBLS OF DRILPLEX LOST TO FORMATION WHILE RUNNING 9 5/8" SURFACE CASING. 11/8/2009 00:00 - 02:00 2.00 CASE P SURF CONTINUE RUNNING 9 5/8" SURFACE CASING FROM 5115' Printed: 12/17/2009 11:56:31 AM 0' t BP Page 11 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/8/2009 00:00 - 02:00 2.00 CASE P SURF MD TO 5194' MD. FILLED EVERY JOINT USING THE FRANKS TOOL AND CIRCULATE EVERY 5TH JOINT AT 4.5 BPM WITH 190 PSI. LOST -35K LBS DOWN WEIGHT AT 5194' MD WITH NO INCREASE IN PRESSURE OR CHANGES TO RETURN FLOW. WORK SPOT WITH PUMPS OFF AND ON AT 4.5 BPM WITH 500 PSI, OK. CONTINUE TO RUN 9 5/8" CASING WITH NO FUTHER ISSUES FROM 5194' MD TO LAST JOINT DEPTH AT 5385' MD. MW IN / OUT 9.4 PPG. FLUID LOSS: 22 BBLS DRILPLEX MUD LOST TO FORMATION WHILE RIH FROM 5115' MD TO 5385' MD. 02:00 - 03:00 1.00 CEMT P SURF PICK UP THE 9 5/8" MANDREL HANGER AND LANDING JOINT AND RUN TO BOTTOM AT 5417' MD. PUW 215K, SOW 109K. RD CASING RUNNING EQUIPMENT. RU CEMENT HEAD. 03:00 - 08:00 5.00 CEMT P SURF CIRCULATE FOR CEMENT JOB BY STAGGING PUMPS UP AS FOLLOWS: 2 BPM WITH 347 PSI 3 BPM WITH 374 PSI 4 BPM WITH 395 PSI 5 BPM WITH 449 PSI 6 BPM WITH INITIAL CIRC PRESSURE OF 470 PSI, FINAL CIRC PRESSURE OF 350 PSI RECIPROCATE PIPE THROUGHOUT ENTIRE CIRCULATION 10' TO 15' STROKES: INITIAL DRAG 165K PUW, 105K SOW FINAL DRAG 185K PUW, 110K SOW MW IN / OUT 9.4 PPG FLUID LOSS: 15 BBLS DRILPLEX MUD LOST TO FORMATION WHILE CIRCULATING. PJSM WITH SLB CEMENTERS, TRUCK PUSHERS, CREWS AND MUD ENGINEER FOR CEMENT JOB. 08:00 - 12:00 4.00 CEMT P SURF CEMENT 9 5/8" SURFACE CASING WHILE RECIPROCATING CASING 10' - 15' STROKES EXCEPT WHEN MUD PUSH II AND LEAD WENT AROUND THE SHOE. LOST -52K LBS DOWN WEIGHT WHILE RECIPROCATING AT 510 BBL ASL LEAD CEMENT PUMPED WITH 499 PSI. PARKED 9 5/8" MANDREL HANGER ON LANDING RING. 07:41 PUMP 5 BBLS H2O AT 3 BPM, TEST LINES TO 3700 PSI - GOOD. 07:51 PUMP 53 BBL 10.0 PPG MUD PUSH II AT 5 BPM WITH 200 PSI 08:03 DROP BOTTOM PLUG; GOOD INDICATION THAT PLUG LEFT HEAD Printed: 12/17/2009 11:56:31 AM Bp Page 12of31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/8/2009 08:00 - 12:00 4.00 CEMT P SURF 08:07 START PUMPING 10.7 PPG ASL LEAD AT 5 BPM WITH 128 PSI 08:21 79 BBL LEAD CEMENT AWAY, 5.5 BPM, 288 PSI 09:06 357 BBL LEAD CEMENT AWAY, 6.4 BPM, 288 PSI MUD PUSH II AT THE SHOE 09:14 409 BBL LEAD CEMENT AWAY, 6.4 BPM, 329 PSI LEAD CEMENT AT THE SHOE 09:55 666 BBL LEAD CEMENT AWAY, 6.5 BPM, 632 PSI SWAP OVER TO 15.8 PPG TAIL 10:18 87 BBL TAIL CEMENT AWAY, 5 BPM, 810 PSI 10:19 DROPPED TOP PLUG; KICK OUT WITH 5 BBL WATER; POSITIVE INDICATION THAT PLUG LEFT HEAD. ISOLATE SLB AND DISPLACE WITH RIG PUMPS. 10:22 CHASING CEMENT WITH RIG PUMPS, 9.4 PPG DRILPLEX MUD PLUG BUMP AT 5665 STROKES, 402 BBLS DISPLACED. FINAL PUMP PRESSURE AT BUMP 1700 PSI AND HELD FOR 2 MINUTES. BLEED PRESSURE OFF. CHECK FLOATS - HOLDING. PRESSURE UP TO 3500 PSI AND HOLD FOR 5 MINUTES - GOOD. CEMENT IN PLACE AT 12:00 HRS 175 BBLS OF SIDEWALK CEMENT BACK TO SURFACE. FLUID LOSS: 28 BBLS OF FLUID LOST TO FORMATION DURING CEMENT JOB. GOOD FLOW RETURNS THROUGHOUT JOB. CEMENT JOB VOLUME: 666 BBLS ASL LEAD PUMPED; 839 SACKS AT 4.51 CUFT /SX 87 BBLS CLASS G TAIL PUMPED; 437 SACKS AT 1.17 CU FT /SX LEAD COMPRESSIVE STRENGTH: NOT AVAILABLE TAIL COMPRESSIVE STRENGTH: 500 PSI: 14:53 HRS 1000 PSI: 22:40 HRS 12:00 - 16:00 4.00 CEMT P SURF RD SCHLUMBERGER AND CEMENTING EQUIPMENT. RD CEMENT HEAD, RD DIVERTER LINE. FLUSH SURFACE RISER AND SPOOL. LD LANDING JOINT. 16:00 - 00:00 8.00 DIVRTR P SURF PJSM ON NIPPLE DOWN DIVERTER SYSTEM. PJSM ON MOVING SPOOLS INTO CELLAR. PJSM ON PIPE SHED OPERATIONS INCLUDING LOADING 4" DP. PULL RISER EXTENSION, LD RISER. MOVE RISER Printed: 12/17/2009 11:56:31 AM • 0 BP Page 13 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/8/2009 16:00 - 00:00 8.00 DIVRTR P SURF BEHIND CELLAR. PLACE CASING SPOOL AND TUBING SPOOL IN CELLAR. MOVE SURFACE RISER OFF CONDUCTOR, CLEAN TD SPARK ARRESTOR SCREEN. SIMOPS: CHANGE OUT DISC BRAKE PADS, PERFORM PREVENTIVE MAINTENANCE ON DRAW WORKS, WELD TWO PAD EYES BY BEAVER SLIDE, LOAD PIPESHED WITH 4" DP. COMMENCE TO CHANGE PUMP LINERS TO 5" 11/9/2009 00:00 - 00:30 0.50 DIVRTR P SURF SECURE SURFACE HYDRIL IN CELLAR. 00:30 - 04:00 3.50 WHSUR P SURF PJSM ON NIPPLE UP FMC SPOOLS. INSTALL FMC GEN 5 CASING SPOOL AND TORQUE UP TO 350 FT -LBS TO ENERGIZE METAL SEAL. PRESSURE TEST METAL SEAL AGAINST "S" (RUBBER) SEAL TO 1000 PSI FOR 30 MINUTES - GOOD TEST. INSTALL GEN 5 TUBING SPOOL. INSTALL OUTER WORKING VALVES SIMOPS: CONTINUE TO CHANGE OUT PUMP LINERS TO 5 ", LOAD 4" DP INTO PIPE SHED, LD CASING AND CEMENT EQUIPMENT, CHANGE OUT LONG BALES TO SHORT BALES, INSTALL 4" ELEVATORS, CHANGE OUT LUBE OIL ON FILTER TOP DRIVE. 04:00 - 09:00 5.00 BOPSUF P SURF PJSM ON NIPPLE UP BOP. INSTALL 13 5/8" X 11" ADAPTER FLANGE. PLACE BOP ON TUBING SPOOL AND TORQUE BOLTS. ,INSTALL RISER AND FLOWLINE. RU TO TEST BOP. ��1 09:00 - 10:00 1.00 BOPSUF P SURF FUNCTION TEST ALL BOP RAMS. HCR KILL AND CHOKE VALVES. MU TEST PLUG TO 4" TEST JOINT. 11:00 - 17:30 6.50 BOPSUF P SURF TEST BOP EQUIPMENT WITH 4" TEST JOINT TO A LOW t 250 PSI / HIGH 4000 PSI. EACH TEST HELD FOR 5 MINUTES. ANNULAR PREVENTER TEST TO A 250 PSI LOW AND 2500 PSI HIGH. BOB NOBLE OF AOGCC WAIVED WITNESS OF TEST. TEST WITNESSED BY WSL BLAIR NEUFELD AND TOOLPUSHER BILL BIXBY. 17:30 - 18:30 1.00 BOPSUF P SURF RIG DOWN BOP TEST EQUIPMENT. INSTALL 9 7/8" ID WEAR RING. CLEAR AND CLEAN RIG FLOOR. 18:30 - 20:00 1.50 DRILL P PROD1 EXPEDITE BHA EQUIPMENT UP THE BEAVER SLIDE TO RIG FLOOR. MOVE 6 STANDS OF 4" HWDP FROM OFF DRILLER'S SIDE TO DRILLER'S SIDE. 20:00 - 23:00 3.00 DRILL P PROD1 PJSM ON PICKING UP DRILLING BHA. MU 8 3/4" PRODUCTION DRILLING BHA #5 AS FOLLOWS: 8 3/4" DTX- 619M -D2 HYCALOG BIT, 6 3/4" 1.5 DEG BENT MUD MOTOR, ARC, MWD, ADN, 7" NM DC, 9 5/8" STABILIZER, 7" NM DC, 1 JT 5" HWDP, HYDRAULIC JARS, 1 JT 5" HWDP, BAKER CIRC SUB. 23:00 - 00:00 1.00 DRILL P PROD1 INSTALL AIR SLIPS. RIH WITH 8 3/4" DRILLING BHA #5 ON 4" DP SINGLES FROM 287' MD TO 574' MD. 11/10/2009 00:00 - 06:00 6.00 DRILL P PROD1 CONTINUE TO RIH WITH 8 3/4" DRILLING BHA #5 ON 4" DP PICKED UP OUT OF PIPE SHED ONE BY ONE FROM 574' MD TO 1300' MD. Printed: 12/17/2009 11:56:31 AM • BP Page 14 of 31' Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From To Hours Task Code NPT Phase Description of Operations 11/10/2009 00:00 - 06:00 6.00 DRILL P PROD1 SHALLOW TEST MWD AT 1300' MD AT 450 GPM WITH 800 PSI - GOOD. CONTINUE TO RIH ON 4" DP SINGLES FROM 1300' MD TO 2101' MD. PU 8 3/4" GHOST REAMER AND PLACE AT 2101' BEHIND BIT. CONTINUE TO RIH ON 4" DP SINGLES FROM 2101' MD TO 5135' MD. 06:00 - 09:00 3.00 DRILL P PROD1 PRESSURE TEST 9 5/8" SURFACE CASING TO 3500 PSI FOR 30 CHARTED MINUTES - GOOD TEST WITH ZERO BLEED OFF. 09:00 - 10:00 1.00 DRILL P PROD1 CUT AND SLIP 65' OF DRILL LINE. SERVICE TOP DRIVE. 10:00 - 11:00 1.00 DRILL P PROD1 OBTAIN SLOW PUMP RATES AT 5130' MD. WASH DOWN FROM 5135' MD TO 5330' MD AT 450 GPM WITH 1740 PSI. DRILL STRING STARTED TO TAKE 3K - 5K LBS DOWN WEIGHT AT 5309' MD AND TAGGED SOLID BOTTOM AT 5328' MD WITH 7K LBS DOWN WEIGHT (2' ABOVE 9 5/8" FLOAT COLLAR). PICK UP TO 5323' MD. PUW 140K, SOW 63K. MW IN / OUT 9.3 PPG DRILPLEX 11:00 - 13:00 2.00 DRILL P PROD1 DRILL CEMENT AND SHOE TRACK FROM 5328' MD TO 5412' MD (5' ABOVE BOTTOM OF 9 5/8" FLOAT SHOE) WITH THE FOLLOWING PARAMETERS: - 455 GPM WITH 1860 PSI OFF, 1890 PSI ON - ROTATING AT 40 RPM WITH 8.7K FT -LBS TQ OFF, 9.6K FT -LBS TQ ON - 5K WOB, ROP 80 - 100 FPH MW IN / OUT 9.3 PPG DRILPLEX 13:00 - 14:00 1.00 DRILL P PROD1 DISPLACE WELLBORE FROM 9.3 PPG DRILPLEX TO 8.8 PPG LSND AT 506 GPM WITH 1325 PSI WHILE RECIPROCATING DRILL STRING IN 40' STROKES FOR A TOTAL OF 497 BBLS PUMPED. MW IN / OUT 8.8 PPG LSND 14:00 - 14:15 0.25 DRILL P PROD1 DRILL REMAINDER OF SHOE TRACK FROM 5412' MD TO 5415' MD. TAG 9 5/8" FLOAT SHOE RIGHT ON DEPTH AT 5415' MD AND CONTINUE TO DRILL CEMENT TO BOTTOM AT 5428' MD. DRILL 20' OF NEW FORMATION TO 5 448' MD. - 500 GPM, 1150 PSI OFF, 1212 PSI ON - 5K WOB, 40 RPM, 3.6K TORQUE OFF, 4K TORQUE ON 14:15 - 14:30 0.25 DRILL P PROD1 CIRCULATE ONE BOTTOMS UP AT 510 GPM WITH 1398 PSI WHILE RECIPROCATING PIPE IN 10' STROKES AND ROTATING AT 40 RPM WITH 3.8K FT -LBS TORQUE. MW IN / OUT 8.8 PPG LSND 14:30 - 15:30 1.00 DRILL P PROD1 PULL BACK INSIDE 9 5/8" CASING SHOE AT 5415' MD. ij 0 ppp CQNDUCT LOT: MW 8.8 PPG, 3028' TVD. DEVIATE FROM ik it"' STRAIGHT LINE AT 612 PSI FOR EMW 12.68 PPG. 15:30 - 00:00 8.50 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 5448' MD TO 6598' MD. Printed: 12/17/2009 11:56:31 AM • Bp Page 15of31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/10/2009 15:30 - 00:00 8.50 DRILL P PROD1 - PUMP AT 585 GPM WITH 2000 PSI OFF, 2166 PSI ON - 100 RPM, 7.7K TORQUE OFF, 9K TORQUE ON - ART 3.03 HRS, AST 0.65 HRS, ADT 3.68 HRS, BIT 3.68 HRS - PUW 122K, SOW 75K, ROTW 95K - ADD H2O AT 20 BPH - MW IN / OUT 8.9 PPG - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.6 PPG, ACT ECD 9.93 PPG PUMP 50 BBL HIGH VIS SWEEP AT 6026' MD. 15% INCREASE IN CUTTINGS WITH RETURN OF SWEEP, MOSTLY SAND WITH TRACES OF UGNU OIL. DRILLING BHA #5 DROPPING 0.5 - 0.7 DEG /100 FT WHILE ROTATING IN UGNU. 11/11/2009 00:00 - 12:00 12.00 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 6598' MD TO 8126' MD. - PUMP AT 585 GPM WITH 2410 PSI OFF, 2680 PSI ON - 100 RPM, 9.1K TORQUE OFF, 9.9K TORQUE ON, 5K - 20K WOB - ART 3.63 HRS, AST 2.17 HRS, ADT 5.68 HRS, BIT 9.48 HRS - PUW 136K, SOW 79K, ROTW 100K - ADD H2O AT 20 BPH - MW IN / OUT 9.0 PPG - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.87 PPG, ACT ECD 10.37 PPG PUMP 2ND HI VIS SWEEP AT 7315' MD, NO INCREASE IN CUTTINGS WITH RETURN OF SWEEP. INCREASE LUBRICANT'S CONCENTRATION TO 3% WITH ADDITIONS OF LOTORQ, NOTED REDUCTION IN TORQUE OF -2K FT -LBS AT -8700' MD. MW IN / OUT 9.0 PPG 12:00 - 00:00 12.00 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 8126' MD TO 9438' MD. - PUMP AT 585 GPM WITH 3190 PSI OFF, 3280 PSI ON - 100 RPM, 8.3K TORQUE OFF, 9.5K TORQUE ON, 5K - 20K WOB - ART 4.99 HRS, AST 2.48 HRS, ADT 7.47 HRS, BIT 16.95 HRS - PUW 150K, SOW 85K, ROTW 113K - ADD H2O AT 20 BPH -MW IN /OUT 9.1 PPG - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 Printed: 12/17/2009 11:56:31 AM I BP Page 16 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/11/2009 12:00 - 00:00 12.00 DRILL P PROD1 GPM. - CAL ECD 10 PPG, ACT ECD 10.63 PPG PUMP 3RD 50 BBL HIGH VIS SWEEP AT -8400' MD, NO INCREASE IN CUTTINGS WITH RETURN OF SWEEP. PUMP 4RD 50 BBL HIGH VIS SWEEP AT -9400' MD, NO INCREASE IN CUTTINGS WITH RETURN OF SWEEP. RHEOLOGY OF ALL SWEEPS: 22 PV, 60 YP (9.0 PPG LSND MUD, 1.3 PPB FLOWZAN). SLOW DOWN ROP TO A MAXIMUM OF 125 FT /HR FROM 8990' MD TO 9230' MD AS PER GEOLOGIST TO ACQUIRE DESIRED AMOUNT OF DATA (2 DATA POINTS PER FOOT) TO ENSURE GOOD TIE -IN DATA FOR PERFORATIONS. 11/12/2009 00:00 - 07:00 7.00 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 9438' MD TO 10340' MD. TO - PUMP AT 585 GPM WITH 3560 PSI OFF, 3680 PSI ON - 100 RPM, 9.1K TORQUE OFF, 10.1K TORQUE ON, 5K - 15K WOB - ART 4.18 HRS, AST 0.52 HRS, ADT 4.7 HRS, BIT 21.65 HOURS - PUW 163K, SOW 90K, ROTW 118K -ADD H2O AT 20 -30BPH - MW IN / OUT 9.2 PPG LSND. - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 10.38 PPG, ACT ECD 11.13 PPG 07:00 - 09:30 2.50 DRILL P PROD1 PUMP 5TH 50 BBL HIGH VIS SWEEP AT TD WHILE PUMPING AT 575 GPM WITH 3340 PSI, RECIPROCATING FULL STAND, ROTATING AT 100 RPM WITH 9.6K FT -LBS TORQUE. NO INCREASE IN CUTTINGS NOTED WITH RETURN OF SWEEP. TOTAL OF 2 BOTTOMS UP CIRCULATED. MONITOR WELL - STATIC. MW IN / OUT 9.2 PPG. 09:30 - 15:30 6.00 DRILL P PROD1 MAD PASS IN UP DIRECTION FROM 10340' MD TO 8220' MD WITH FOLLOWING PARAMETERS: - 550 GPM, 3145 PSI, 100 RPM, 9.8K TORQUE EXPERIENCED ERRATIC TORQUE (9.1 - 12K FT -LBS) FROM 9448' MD TO 8260' MD. 30% INCREASE IN CUTTINGS RETURNS FROM DEPTH WHERE ERRATIC TORQUE STARTED. SLOW DOWN BACKREAMING SPEED FROM 8260' MD TO 7916' MD TO OBTAIN BOTTOMS UP AND EVALUATE CUTTINGS. SHAKERS CLEAN WITH RETURN OF BOTTOMS UP AS WELL AS STABLE TORQUE OF 7K - 8K FT -LBS WITH 100 RPM, 550 GPM 2750 PSI. MONITOR WELL - STATIC. MW IN / OUT 9.2 PPG. 15:30 - 20:00 4.50 DRILL P PROD1 POH ON ELEVATORS FROM 7916' MD TO 5570' MD. Printed: 12/17/2009 11:56:31 AM • • BP Page 17 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/12/2009 15:30 - 20:00 4.50 DRILL P PROD1 ENCOUNTERED 20K OVERPULL AT 5570' MD (8 5/8" STABILIZER AT SHOE). ROTATE DRILL STRING 180 DEG, PULL THROUGH 9 5/8" SHOE WITH NO FURTHER ISSUES. PUW 135K, SOW 75K. MONITOR WELL - STATIC. CONTINUE TO POH FROM 5570' MD TO 4016' MD. PUW 120K, SOW 75K. MW IN / OUT 9.2 PPG. 20:00 - 21:30 1.50 DRILL P PROD1 RIH WITH 18 JOINTS OF 4" HWDP FROM 4016' MD TO 4530' MD. POH AND LD 18 JOINTS OF 4" HWDP FROM 4530' MD TO 4016' MD. MW IN / OUT 9.2 PPG. 21:30 - 00:00 2.50 DRILL P PROD1 POH FROM 4016' MD TO 2100' MD. LD 8 3/4" GHOST REAMER., CONTINUE TO POH FROM 2100' MD TO 1050' MD. MW IN / OUT 9.2 PPG. 11/13/2009 00:00 - 01:00 1.00 DRILL P PROD1 CONTINUE TO POH FROM 1050' MD TO 190' MD. LD HYDRAULIC JARS STAND. RIH WITH 4 STANDS OF 4" DP FROM 190' MD TO 590' MD. PUMP OUT STACK, FUNCTION UPPER RAMS AND CLEAN. MW IN / OUT 9.2 PPG MONITOR WELL - STATIC 01:00 - 02:30 1.50 DRILL P PROD1 PJSM WITH HALLIBURTON FOR SETTING STORM PACKER. PU 9 5/8" HALLIBURTON STORM PACKER. RIH WITH STORM PACKER ON 1 STAND 4" DP AND SET STORM PACKER AT 96' MD. POH, SET BACK 4" DP STAND AND LD STORM PACKER RUNNING TOOL. PRESSURE TEST 9 5/8" STORM PACKER TO 1000 PSI FOR 10 MINUTES - GOOD. 02:30 - 05:30 3.00 BOPSUF P PROD1 PSJM FOR CHANGING OUT RAMS. CHANGE OUT UPPER VARIABLE RAMS FROM 3 1/2" X 6" TO 7" RAMS. PULL RISER TO CHANGE OUT LEAKING AIR BOOT. 05:30 - 07:00 1.50 BOPSUF N WAIT PROD1 CHANGE OUT CREW UNABLE TO ARRIVE TO V -PAD DUE TO DOYON 16 RIG MOVE. CREWS ABLE TO CHANGE OUT WHEN DOYON 16 STOPPED AT Z -PAD ACCESS ROAD ALLOWING TRAFFIC TO GO BY. 07:00 - 09:30 2.50 BOPSUF P PROD1 INSTALL AIR BOOT AND RISER. PULL WEAR RING, MU 7" TEST ASSEMBLY. PRESSURE TEST 7" RAMS TO 250 PSI LOW / 4000 PSI HIGH. TEST WITNESSED BY WSL JOEY LEBLANC AND TOOL PUSHER BILL BIXBY. RD TEST EQUIPMENT AND INSTALL WEAR RING. 09:30 - 10:30 1.00 DRILL P PROD1 MU TIW ON 1 4" DP STAND AND RIH TO 96' MD, MU TO 9 5/8" STORM PACKER. RELEASE STORM PACKER. WELL TOOK 5 BBLS TO FILL. LD 9 5/8" HALLIBURTON STORM PACKER. Printed: 12/17/2009 11:56:31 AM • i BP Page 18 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/13/2009 10:30 - 14:00 3.50 DRILL P PROD1 LD PRODUCTION DRILLING BHA #5. B IT GRADE: 1- 2- CT- S- 0- I- WT -TD. 14:00 - 15:00 1.00 DRILL P PROD1 CLEAN AND CLEAR FLOOR OF BHA HANDLING EQUIPMENT. 15:00 - 19:30 4.50 CASE P RUNPRD PJSM FOR RIGGING UP TO RUN 7" PRODUCTION LONGSTRING. PULL WEAR RING, MAKE DUMMY RUN WITH 7" CASING MADREL HANGER AND CONFIRM RKB ELEVATION OF, 26.20'. FILL BOP STACK. EXPEDITE CASING RUNNING EQUIPMENT TO RIG FLOOR. RU TO RUN 7" 26# L -80 BTC -M / TCII PRODUCTION LONGSTRING. CHANGE OUT BAILES. 19:30 - 00:00 4.50 CASE P RUNPRD PJSM FOR RUNNING 7" PRODUCTION LONGSTRING. MU 7" 26# L -80 BTC -M PRODUCTION CASING SHOE TO 8,400 FT -LBS AND BAKER -LOK. FILL PIPE AND TEST FLOATS - GOOD. RUN IN THE HOLE WITH 44 JOINTS OF 7" 26# L -80 BTC -M TO 1811' MD, TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8,400 FT -LBS. MAKE UP TCII X BTC -M CROSS OVER. FILLED EVERY JOINT USING THE FRANKS TOOL AND CIRCULATE EVERY 10TH JOINT AT 4 BPM WITH 232 PSI. INITIAL FLUID LOSS RATE OF 2 BPH FROM SURFACE TO 800' MD. REDUCED RUNNING SPEED TO 30 FT /MIN, NO MORE FLUID LOSS NOTED. MW IN / OUT 9.2 PPG. FLUID LOSS: 4 BBLS 9.2 PPG LSND LOST TO FORMATION 11/14/2009 00:00 - 06:30 6.50 CASE P RUNPRD CONTINUE TO RUN IN THE HOLE WITH 7" 26# L -80 TC -II FROM 1850' MD TO 5394' MDIABOVE 9 5/8" CASING SHOE), TORQUE EACH CONNECTION TO AN AVERAGE TORQUE OF 10,100 FT -LBS. PUW 137K, SOW 82. FILLED EVERY JOINT USING THE FRANK'S TOOL AND CIRCULATE EVERY 10TH JOINT AT 5 BPM. MW IN / OUT 9.2 PPG. NO FLUID LOSS NOTED. 06:30 - 07:00 0.50 CASE P RUNPRD CIRCULATE ONE ANNULAR VOLUME STAGGING UP PUMPS AS FOLLOWS: 4 BPM 624 PSI 5 BPM 670 PSI 6 BPM 711PSI INITIAL 6 BPM 648 PSI FINAL FULL RETURNS THROUGHOUT ENTIRE CIRCULATION AT SHOE. PUW 140K, SOW 85K AT 5394' MD. MW IN / OUT 9.2 PPG. MONITOR WELL - STATIC. Printed: 12/17/2009 11:56:31 AM • • BP Page 19 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2009 07:00 - 15:30 8.50 CASE P RUNPRD CONTINUE TO RUN 7" BTC -M / TCII PRODUCTION LONGSTRING IN OPEN HOLE FROM 5394' MD TO 5680' MD. LOST -15K DOWN WEIGHT, BEGIN TO CIRCULATE DOWN EVERY 5TH JOINT STARTING AT 5680' MD, 4 BPM WITH 557 PSI FROM 5680' MD TO 6588' MD, FULL RETURNS. CIRCULATE DOWN EVERY 10TH JOINT FROM 6588' MD TO 7413' MD AT 5 BPM WITH 883 PSI WITH FULL RETURNS. CONTINUE TO RIH FROM 7413' MD TO 7620' MD WITH PUMPS OFF AND WITH NO ISSUES. WASH DOWN FROM 7620' MD TO 7784' MD AT 4 BPM WITH 860 PSI, 15K -20K DRAG OBSERVED WHILE WASHING DOWN. BEGIN TO FXPERIENCE PARTIAL RETURNS AT 7743' MD. LOST FULL RETURNS AT 7867' MD. CONTINUE TO WASH DOWN TO 7991' MD AT 3.5 BPM WITH 650 PSI, PUW 179K, SOW 72K. 15:30 - 16:00 0.50 CASE P RUNPRD RECIPROCATE 7" CASING IN 58' STROKES WHILE CIRCULATING AT 3.4 BPM WITH 645 PSI, NO FLUID RETURNS. 16:00 - 19:30 3.50 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 7991' MD TO 7784' MD (5 JOINTS OF 7" TCII LAID DOWN). 19:30 - 20:30 1.00 CASE N DPRB RUNPRD ATTEMPT TO ESTABLISH CIRCULATION WHILE PUMPING AT 4 BPM WITH 640 PSI AND RECIPROCATING PIPE IN 64' STROKES. PUW 175K, SOW 75K. NO FLUID RETURNS. 20:30 - 21:30 1.00 CASE N DPRB RUNPRD LD FRANKS FILL UP TOOL. BLOW DOWN TOP DRIVE, RU CIRCULATING SWEDGE AND CEMENT HOSE. PUMP AT 22 GPM WITH 476 PSI, NO FLUID RETURNS. 21:30 - 00:00 2.50 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 7784' MD TO 7578' MD (5 JOINTS OF 7" TCII LAID DOWN). 11/15/2009 00:00 - 01:00 1.00 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 7578' MD TO 7372' MD (5 JOINTS OF 7" TCII LAID DOWN)._ 01:00 - 01:30 0.50 CASE N DPRB RUNPRD CIRCULATE AT 30 GPM WITH 350 PSI WHILE RECIPROCATING PIPE IN 38' STROKES. PUW 179K, SOW 60K. SMALL RETURNS NOTED IN THE UPSTROKE, NO RETURNS IN THE DOWNSTROKE. PUMP 40 BBL LCM SWEEP (10 PPB G -SEAL, 15 PPB M -I -X II COARSE, 15 PPB NUTPLUG MEDIUM). MW OUT 9.2 PPG. 01:30 - 02:00 0.50 CASE N DPRB RUNPRD INCREASE PUMP RATE ON UP STROKE TO 46 GPM, 519 PSI, PUW 168K. SOW 58K, PUMPS OFF. SMALL RETURNS OBSERVED ON UP STROKE, NO RETURNS ON DOWN STROKE. 02:00 - 03:00 1.00 CASE N DPRB RUNPRD INCREASE PIPE STROKE RATE TO 2.5 MIN /STROKE AND STOP PUMPING ON DOWN STROKE. 49 GPM, 485 PSI, PUW 172K. SOW 61K, PUMPS OFF. SMALL RETURNS OBSERVED ON UPSTROKE, NO Printed: 12/17/2009 11:56:31 AM • BP Page 20 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/15/2009 02:00 - 03:00 1.00 CASE N DPRB RUNPRD RETURNS ON DOWN STROKE. 03:00 - 10:00 7.00 CASE N DPRB RUNPRD REDUCE UP STROKE RATE TO 5 MIN /STROKE. INCREASE PUMP RATE IN UP STROKE TO 80 GPM, 546 PSI, PUW 180K. CONTINUE TO OBSERVE SMALL RETURNS ON UP STROKE. REDUCE DOWN STROKE RATE TO 3 MIN /STROKE, SOW 59K, PUMPS OFF. NO RETURNS NOTED ON DOWN STROKE. 04:15 HRS, PUMP SECOND 35 BBL LCM SWEEP (10 PPB G -SEAL, 15 PPB M- I -X -II COARSE, 15 PPB NUTPLUG MEDIUM). CIRCULATE BOTH LCM SWEEP OUT OF SHOE PLUS 2 OPEN HOLE VOLUMES. SAW 100 PSI INCREASE IN PUMP PRESSURE TO 700 PSI WHEN FIRST SWEEP WAS 110 BBLS (1900 STROKES) OUT OF SHOE. PUMP PRESSURE DROPPED BACK DOWN TO 600 PSI AFTER 4 STROKES OF THE PIPE. NO INCREASE IN PRESSURE AS SECOND LCM SWEEP EXITED SHOE. MW IN 8.8 PPG / OUT 9.4 PPG PUMPED AND LOST 734 BBLS 8.8 LSND MUD. DISCUSS WITH TOWN AND FIELD SUPERINTENDENT, DECISION MADE TO PULL 25 JOINTS AND ATTEMPT 10:00 - 14:00 4.00 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 7372' MD TO 6753' MD (15 JOINTS OF 7" TCII LAID DOWN FOR A TOTAL OF 30 JOINTS LAID DOWN). PUW 188K, SOW 88K. NOTE: SWABBING FROM 6919' MD TO 6753' MD. 14:00 - 14:30 0.50 CASE N DPRB RUNPRD RIG UP CIRCULATING EQUIPMENT AND PUMP AT 85 GPM WITH 580 PSI. RD CIRCULATING EQUIPMENT AND BLOW DOWN LINE. 14:30 - 16:30 2.00 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 6753' MD TO 6341' MD (10 JOINTS OF 7" TCII LAID DOWN FOR A TOTAL OF 40 JOINTS LAID DOWN). 16:30 - 18:30 2.00 CASE N DPRB RUNPRD RIG UP CIRCULATING EQUIPMENT. ATTEMPT TO ESTABLISH CIRCULATION BY PUMPING AT 124 GPM WITH 575 PSI. PUW 144K, SOW 65K. RD CIRCULATING EQUIPMENT. 18:30 - 20:30 2.00 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 6341' MD TO 6010' MD (8 JOINTS OF 7" TCII LAID DOWN FOR A TOTAL OF 48 JOINTS LAID DOWN). PULL ALL JOINTS WET. SWAB 22.6 BBLS. 20:30 - 21:00 0.50 CASE N DPRB RUNPRD RIG UP CIRCULATING EQUIPMENT. ATTEMPT TO ESTABLISH CIRCULATION BY PUMPING AT 132 GPM WITH 567 PSI ON UPSTROKE, PUMP AT 107 GPM Printed: 12/17/2009 11:56:31 AM • Bp Page 21 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/15/2009 20:30 - 21:00 0.50 CASE N DPRB RUNPRD WITH 573 PSI ON DOWNSTROKE. MINIMAL RETURNS ON UPSTROKE DUE TO SWABBING, NO RETURNS ON DOWNSTROKE. PUW 153K, SOW 65K. PUMP AND LOST 35 BBLS LSND. RD CIRCULATING EQUIPMENT. 21:00 - 00:00 3.00 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 6010' MD TO 5722' MD (7 JOINTS OF 7" TCII LAID DOWN FOR A TOTAL OF 55 JOINTS LAID DOWN). PULL ALL JOINTS WET. SWAB -16.4 BBLS. LOST 250 BBLS FROM 12:00 HRS TO 00:00 HRS. TOTAL OF 1227 BBLS LSND MUD LOST FOR TODAY. 11/16/2009 00:00 - 00:30 0.50 CASE N DPRB RUNPRD RIG UP CIRCULATING EQUIPMENT. ATTEMPT TO ESTABLISH CIRCULATION BY PUMPING AT 109 GPM WITH 546 PSI ON UPSTROKE, PUMP AT 49 GPM WITH 561 PSI ON DOWNSTROKE. MINIMAL RETURNS ON UPSTROKE DUE TO SWABBING, INCREASE FLUID RETURNS ON UPSTROKE WITH INCREASED UPSTROKE SPEED. NO RETURNS ON DOWNSTROKE. INITIAL PUW 133K, FINAL PUW 135, SOW 70K. PUMP AND LOST -33 BBLS LSND. RD CIRCULATING EQUIPMENT. 00:30 - 03:30 3.00 CASE N DPRB RUNPRD POH LAYING DOWN 7" TCII CASING FROM 5722' MD TO 5311' MD (10 JOINTS OF 7" TCII LAID DOWN FOR A TOTAL OF 65 JOINTS LAID DOWN). START TO PULL DRY FROM 5476' MD, SWABBING. MW IN 9.0 PPG / MW OUT 9.8 PPG 03:30 - 05:00 1.50 CASE N DPRB RUNPRD ATTEMPT TO ESTABLISH CIRCULATION BY PUMPING AT 2 - 5 BPM WITH 550 - 600 PSI WHILE RECIPROCATING PIPE IN 50' STROKES. PUW 145K, SOW 60K. NO FLUID RETURNS. 05:00 - 07:00 2.00 CASE N DPRB RUNPRD RD BLOW LINES. RD 350 TON EQUIPMENT. INSTALL SIDE DOOR ELEVATORS. 07:00 - 09:00 2.00 CASE N DPRB RUNPRD PUMP 200 BBLS OF 8.8 PPG LSND DOWN THE BACKSIDE (9 5/8" X 7" ANNULUS) BY STAGGING UP PUMPS AS FOLLOWS: 1 BPM WITH 700 PSI 2 BPM WITH 917 PSI 3 BPM WITH 800 PSI 4 BPM WITH 926 PSI 09:00 - 14:00 5.00 CASE N DPRB RUNPRD CIRCULATE AND CONDITION 7" PRODUCTION LONGSTRING BY STAGGING PUMPS UP AS FOLLOWS: 3 BPM WITH 460 PSI 4 BPM WITH 512 PSI 5.5 BPM WITH 452 PSI 7 BPM WITH 476 PSI LOSING 25 BPH FOR 1ST BOTTOMS UP. STATIC AFTER 2ND BOTTOMS UP. GOOD RETURNS NOTED Printed: 12/17/2009 11:56:31 AM 0 . Bp Page 22 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From -, To Hours Task Code NPT Phase Description of Operations 11/16/2009 09:00 - 14:00 5.00 CASE N DPRB RUNPRD THEREAFTER. LOST 432 BBLS FROM 00:00 HRS TO 12:00 HRS. PUW 135K, SOW 70K. MW IN / OUT 9.0 PPG 14:00 - 14:30 0.50 CASE N DPRB RUNPRD RD CIRCULATING HOSE AND BLOW DOWN. RD 150 TON SIDE DOOR ELEVATORS, RU 350 TON ELEVATORS. 14:30 - 15:30 1.00 CASE N DPRB RUNPRD CONTINUE TO CIRCULATE WITH SAME PARAMETERS: 7 BPM WITH 476 PSI MW IN / OUT 9.0 PPG MUD TEMP: IN 83 DEG F, OUT 70 DEG F SIMOPS: RU LITTLE RED HOT OIL SERVICES BY CUTTINGS TANK BOX AND LINE UP TO SUCTION PIT TO INCREASE LSND MUD TEMPERATURE. 15:30 - 16:00 0.50 CASE N DPRB RUNPRD RD CIRCULATING EQUIPMENT AND BLOW DOWN CIRCULATING HOSE. RU FRANK'S FILL UP TOOL. 16:00 - 00:00 8.00 CASE N DPRB RUNPRD CONTACT TOWN AND AGREED ON FOLLOWING PLAN FORWARD: CIRCULATE 4 MINUTES ON EACH JOINT AT 5 BPM. CIRCULATE A BOTTOMS UP EVERY 10 JOINTS AT 6 j` BPM. MW IN 8.8 - 9.0 PPG, MW OUT 9.0 - 9.2 PPG. MAINTAIN 100 DEGREES LSND MUD. CIRCULATE BOTTOMS UP WHEN DEVIATING FROM PRESSURE, DRAG OR TEMPERATURE TRENDS, RUN 7" BTC -M / TCII PRODUCTION LONGSTRING IN OPEN HOLE FROM 5311' MD TO 6052' MD. LOST -5K DOWN WEIGHT AND 10% OF RETURNS, PUMP PRESSURE INCREASE FROM 400 PSI TO 598 PSI. WASH DOWN THROUGH SPOT AT 2 FT /MIN. CONTINUE TO RUN 7" CASING FROM 5475' MD TO 5694' MD. LOST FULL RETURNS AT 5964' MD, PICK UP, SWABBING. WASH DOWN AS FOLLOWS (GAINED PARTIAL RETURNS WHILE WASHING DOWN AT 5969' MD): 164 GPM 398 PSI PARTIAL RETURNS 188 GPM 425 PSI PARTIAL RETURNS, PACKING OFF STOP MOVING PIPE, CIRCULATE TO CLEAR PACK OFF LOST -10 BBLS LSND MUD 205 GPM 422 PSI FULL RETURNS RESUME CASING RUN 205 GPM 446 PSI 5965' MD, SLIGHT PACK OFF, CIRC CLEAN BOTTOMS UP FROM 1ST PACK OFF SHOWED 20% INCREASE IN LCM MATERIAL. CONTINUE TO RUN 7" CASING FROM 5965' MD TO 6010' MD AS HOLE CONDITIONS ALLOW TO PREVENT PACKING OFF AND LOSS RETURNS WHILE PUMPING AT 206 GPM Printed: 12/17/2009 11:56:31 AM • BP Page 23 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2009 16:00 - 00:00 8.00 CASE N DPRB RUNPRD WITH 434 PSI. RUN 7" CASING FROM 6010' MD TO 6052' MD AS PER PREVIOUSLY DESCRIBED PLAN AND WITH NO FURTHER ISSUES MW IN / OUT 9.0 PPG MUD TEMP: IN 88 DEG F / OUT 78 DEG F INITIAL FLUID LOSS: 13 BBUHR FINAL FLUID LOSS: 6.4 BBUHR TOTAL OF 27 BBL LOST TO FORMATION FROM 12:00 HRS TO 00:00 HRS. 11/17/2009 00:00 - 09:30 9.50 CASE N DPRB RUNPRD CONTINUE TO RUN 7" BTC-M / TCII PRODUCTION LONGSTRING FROM 5,980' MD TO 7,289' MD. CASING STRING PACKED OFF AT 6,588' MD, INCREASE IN PRESSURE OF 100 PSI TOGETHER WITH A REDUCTION OF 6% ON RETURN FLOW. PICK UP, PRESSURE AND RETURN FLOW NORMALIZE IMMEDIATELY, CONTINUE TO CIRCULATE DOWN JOINT WITH NO ISSUES. CIRCULATE 4 MINUTES ON EACH JOINT AT 5 BPM WITH 435 PSI. CIRCULATE A BOTTOMS UP EVERY 10 JOINTS AT 6 BPM WITH 525 PSI. MW IN 8.9 PPG / OUT 9.0 PPG MUD TEMP: IN 98 DEG F / OUT 83 DEG F 09:30 - 11:00 1.50 CASE N DPRB RUNPRD RIG DOWN FRANKS TOOL, RU CEMENT LINE TO CIRCULATE AND CONDITION MUD. - CIRCULATE AND CONDITION MUD 7 BPM @ 590 PSI. -PUW 180K, SOW 90K. -RIG DOWN CEMENT LINE, RIG UP FRANKS TOOL. 11:00 - 12:00 1.00 CASE N DPRB RUNPRD CONTINUE TO RUN 7" BTC -M / TCII PRODUCTION LONGSTRING FROM 7,289' MD TO 7,372' MD. CIRCULATE 4 MINUTES ON EACH JOINT AT 4 BPM WITH 485 PSI. CIRCULATE A BOTTOMS UP @ 7,900' MD. MW IN 8.9 PPG / OUT 9.0 PPG MUD TEMP: IN 99 DEG F / OUT 84 DEG F FLUID LOSS FOR TOUR: 0 BBL. 12:00 - 17:30 5.50 CASE N DPRB RUNPRD CONTINUE TO RUN 7" BTC -M / TCII PRODUCTION LONGSTRING FROM 7,372' MD TO 7,912' MD. - CASING STRING PACKED OFF AT 7,912' MD, LOSING RETURNS. -STAGE PUMPS UP FROM 218 GPM @ 550 PSI TO 298 GPM @ 700 PSI WHILE RECIPROCATING PIPE. -WORK PIPE, ESTABLISH RETURNS. - CIRCULATE BOTTOMS UP, CASING STRING PACKED OFF AGAIN AT 7,912' MD, LOSING RETURNS. - PRESSURE INCREASE FROM 538 TO 700 PSI. 24 BBL LOSS TO FORMATION - NO NOTICABLE CHANGE TO PUW / SOW. Printed: 12/17/2009 11:56:31 AM BP Page 24 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/17/2009 12:00 - 17:30 5.50 CASE N DPRB RUNPRD - REDUCE RATE TO 5 BPM @ 531 PSI. - CONTINUE TO CIRCULATE DOWN JOINT TO 7,950' WITH NO ISSUES. -PUW 180K, SOW 90K. MW IN 8.9 PPG / OUT 9.0 PPG MUD TEMP: IN 98 / OUT 83 DEGREES. 17:30 - 00:00 6.50 CASE P RUNPRD CONTINUE TO RUN 7" BTC -M /TCII PRODUCTION LONGSTRING FROM 7,950' MD TO 8,692' MD. CIRCULATE 6 MINUTES ON EACH JOINT AT 5 BPM WITH 498 PSI. CIRCULATE A BOTTOMS UP EVERY 10 JOINTS AT 5 BPM WITH 498 PSI. MW IN 8.9 PPG / OUT 9.0 PPG MUD TEMP: IN 99 DEG F / OUT 85 DEG F FLUID LOSS FOR TOUR: 30 BBL. 11/18/2009 00:00 - 12:00 12.00 CASE P RUNPRD CONTINUE TO RUN 7" BTC -M / TCII PRODUCTION LONGSTRING FROM 8,692' MD TO 10,054' MD. -PUW 215K, SOW 115K - CIRCULATE 6 MINUTES ON EACH JOINT AT 5 BPM WITH 570 PSI. - CIRCULATE A BOTTOMS UP EVERY 10 JOINTS AT 5 BPM WITH 530 PSI. MW IN 8.9 PPG / OUT 8.9 PPG MUD TEMP: IN 98 DEG F / OUT 82 DEG F 12:00 - 17:00 5.00 CASE P RUNPRD ,CONTINUE TO RUN 7" BTC -M / TCII PRODUCTION , LONGSTRING FROM 10.054' MD TO 10.302' MD. - INTERMITTENT ANNULAR RESTRICTIONS WHILE RIH. -PUW 226K, SOW 115K - CIRCULATE 1.5 HOURS ON EACH JOINT AT 5 BPM WITH 750 PSI. MW IN 8.9 PPG / OUT 8.9 PPG MUD TEMP: IN 95 DEG F / OUT 84 DEG F 17:00 - 19:30 2.50 CEMT P RUNPRD -PICK UP THE 7" MANDREL HANGER AND LANDING JOINT -STAGE PUMPS W/ FRANKS TOOL FROM 5 BPM @ 365 PSI TO 6 BPM @ 615 PSI. -PUW 212K, SOW 108K W / PUMPS OFF, PUW 212K, SOW 116K W/ PUMPS ON. -WASH DOWN TO 10,332' MD. 19:30 - 22:00 2.50 CEMT P RUNPRD -RIG DOWN CASING RUNNING EQUIPMENT. RIG UP CEMENT HEAD. -STAGE PUMPS W/ CEMENT HEAD WHILE RECIPROCATING PIPE FROM 3 BPM @ 365 PSI TO 6 BPM @ 615 PSI. 22:00 - 00:00 2.00 CEMT P RUNPRD PJSM WITH SLB CEMENTERS, TRUCK PUSHER, CREWS, MUD ENGINEER, TOOL PUSHERS AND WSL FOR CEMENT JOB AND SAFETY DISCUSSION CONCERNING INCIDENT ON NGI PAD. Printed: 12/17/2009 11:56:31 AM • BP Page 25 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/18/2009 22:00 - 00:00 2.00 CEMT P RUNPRD CEMENT 7" PROQ r.TION [ aswG WHILE RECIPROCATING CASING 15' -20'. 22:00 PUMP 10 BBL 8.5 PPG TO 15.5 PPG MUD PUSH II PRESSURE TEST CEMENT LINES TO 4,200 PSI. 22:05 PUMP 28 BBL 8.5 PPG TO 15.5 PPG MUD PUSH II, MIXING ON THE FLY. 22:26 DROP BOTTOM PLUG; GOOD INDICATION THAT PLUG LEFT HEAD. PUMP 15.8 PPG TAIL CEMENT AT 5 BPM, 437 PSI. 85.3 BBL CEMENT PUMPED. 23:55 TAIL CEMENT TURNING CORNER @ 304 BBL, @ 323 BBL RESTRICTION OCCURS, PRESSURE INCREASE FROM 582 PSI TO 1,1067 PSI, FLOW DROPS FROM 15% TO 6% RETURNS. - WORK PIPE, PUW 225K, SOW 69K, WHILE REDUCING RATE TO 2 BPM. - 22:55 APPROXIMATELY 20 GALLONS OF DRILLING MUD WAS RELEASED ONTO THE SNOW DUE TO A FROZEN CHUTE LEADING TO THE CUTTINGS BOX ( SEE REMARKS) INCIDENT REPORT # 2009 -IR- 3308731 11/19/2009 00:00 - 01:30 1.50 CEMT P RUNPRD CONTINUE PUMPING CEMENT. 00:05 RETURNS INCREASE TO 11 %, 2 BPM @ 1,122 PSI. -STOP RECIPROCATING @ 342 BBL / 5,860 STROKES. -PUW 220K, SOW 65 K, SET DOWN WITH MANDREL HANGER 14' HIGH. - PRESSURE CONTINUES TO DECREASE DOWN TO 900 PSI WHILE RETURNS INCREASE UP TO 16 %. 00:25 BUMP PLUG @ 389 BBL / 6,678 STROKES, PRESSURE UP TO 1,450 PSI HOLD FOR 5 MINUTES. 00:30 BLEED OFF CASING PRESSURE, LAND MANDREL HANGER ON SPOOL. - PRESSURE UP TO 4000 PSI FOR 30 CHARTED MINUTES. 0 PSI LOST IN FIRST 15 MINUTES, 0 PSI LOST IN SECOND 15 MINUTES - GOOD TEST. CEMENT IN PLACE AT 00:25 HRS 11/18/09 CHECK FLOATS - HOLDING. CEMENT JOB VOLUME: 88 BBLS 15.8 PPG CLASS G TAIL PUMPED; 426 SACKS AT 1.17 CUFT /SX TAIL COMPRESSIVE STRENGTH: 500 PSI: 11:53 HRS 1000 PSI: 14:12 HRS 01:00 - 04:00 3.00 CASE P RUNPRD RIG DOWN CEMENT HEAD & CROSS OVER, CLEAN & Printed: 12/17/2009 11:56:31 AM • BP Page 26of31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/19/2009 01:00 - 04:00 3.00 CASE P RUNPRD CLEAR RIG FLOOR. PERFORM INJECTIVITY TEST ON 7" X 8 -3/4" OH ANNULUS W/ 8.9 PPG LSND MUD. - FORMATION LEAK OFF AT EMW OF 12.7 PPG WITH 594 SURFACE PSI, 3,204' TVD AND 8.9 PPG MW (PREVIOUS LOT WAS EMW 12.69 PPG). INJECT 1 BBL OF 8.9 PPG LSND EVERY HOUR 04:00 - 05:00 1.00 CASE P RUNPRD PJSM ON INSTALLING 7" PACK OFF WITH FMC. -DRAIN BOP STACK, MU LANDING JOINT TO RUNNING TOOL. - INSTALL 9 5/8" X 7" PACK OFF, RILDS. -CLEAR CELLAR AND TEST PACK OFF TO 5000 PSI FOR 30 MINUTES, GOOD TEST. 05:00 - 07:30 2.50 CASE P RUNPRD PSJM ON CHANGING OUT BOP RAMS. - CHANGE OUT UPPER RAMS TO 3 1/2" X 6" 07:30 - 13:30 6.00 BOPSUF P OTHCMP PJSM ON PRESSURE TESTING BOPE. TEST UPPER / LOWER RAMS W/ 3 1/2" & 4" TFST .IT 250 PSI LOW / 4,000 PSI HIGH.; -TEST ANNULAR W/ 3 1/2" TEST JNT. 250 LOW / 2,500 PSI HIGH. -TEST WITNESSED BY AOGCC REP CHUCK SHEVE, WSL JOEY LEBLANC & TOOL PUSHER CLEVE COYNE. 13:30 - 14:00 0.50 EVAL P OTHCMP PJSM WITH LRS ON FREEZE PROTECTING OUTER ANNULUS. - BULLHEAD 170 BBL OF8.9 PPG LSND AT 3 BPM WITH 1,140 ICP, 940 FCP PSI. , -RIG UP U LRS TO FREEZE PROTECT OUTER ANNULUS. - PRESSURE TEST LINES TO 3000 PSI. START AT 2 BPM WITH INITIAL CIRCULATI G PRESSURE OF1300PSI 17 BBLS AWAY, 2 BPM, 980 PSI 34 BBLS AWAY, 2 BPM, 1060 PSI 51 BBLS AWAY, 3 BPM, 1200 PSI FINAL OUTER ANNULUS: PRESSURE 1,200 PSI. RIG DOWN LRS. SECURE CELLAR AND RIG. 14:00 - 14:30 0.50 EVAL P OTHCMP INSTALL 9 1/8" WEAR BUSHING, FILL STACK. 14:30 - 17:00 2.50 EVAL P OTHCMP PJSM ON SLIP / CUT DRILLING LINE -SLIP / CUT 91' OF DRILLING LINE - SERVICE TOP DRIVE, DRAW WORKS & CROWN BLOCK. 17:00 - 00:00 7.00 EVAL P OTHCMP PJSM W/ SLB E -LINE AND RIG PERSONEL ON RIGGING UP E -LINE -RIG UP SLB E -LINE, RIH W/ USIT TO PBTD OF 10,246' MD. t"' 11/20/2009 00:00 - 01:30 1.50 EVAL P OTHCMP SLB E -LINE LOG REPEAT HIGH RESOLUTION PASS FROM PBTD @ 10,246' TO 8,500' MD. -RIH TO 10,246' MD, LOG USIT TO SURFACE. -RIG DOWN SLB E -LINE 01:30 - 12:00 10.50 PERFOB P OTHCMP PJSM W/ SLB TCP AND RIG PERSONEL ON RUNNING TCP GUNS. -PICK UP TCP GUNS, FIRING HEAD, BUMPER SUB, LWD & Printed: 12/17/2009 11:56:31 AM i • BP Page 27 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/20/2009 01:30 - 12:00 10.50 PERFOB P OTHCMP XO. -RIH ON 4" DP WITH 4.5" POWER JET 4505 GUNS TO 2,808' MD. - PERFORM SHALLOW TEST 250 GPM CP 498 PSI. CONTINUE RIH. 12:00 - 15:00 3.00 PERFOB P OTHCMP TAG UP TO PBTD @ 10,246' MD. LOG UP FROM PBTD TO 9,262' MD. -252 GPM @ PSI, PUW 155K, SOW 90K. -RIR TO PBTD FOR SECOND LOG. -PICK UP & SET GUNS @ DEPTH, TOP SHOT CP 9,226' MD BOTTOM SHOT @ 10.032' MD. 15:00 - 15:30 0.50 PERFOB P OTHCMP PJSM W/ SWS & RIG PERSONEL ON FIRING TCP GUNS. -RUN PRE -FIRE TEST, RUN FIRE SEQUENCE AND FIRE GUNS. -GOOD INDICATION @ SURFACE. 15 BBL INITIAL LOSS OF FLUID TO PERFS. 15:30 - 17:30 2.00 PERFOB P OTHCMP POH FROM 10,032 TO 9,114' MD. -PUW 150K, SOW 90K. -12 BBL LOSS TO FORMATION WHILE TRIPPING OUT OF HOLE. - MONITOR WELL 4 BBL LOSS IN 10 MINUTES. - CIRCULATE 2 X BU 6 BPM @ 860 PSI, 50 BBL / HR LOSS TO FORMATION. 17:30 - 20:00 2.50 PERFOB P OTHCMP POH FROM 9,114' TO 6,247' MD. LAYING DOWN SINGLES 1 X 1 TO PIPE SHED. 20:00 - 21:00 1.00 PERFOB P OTHCMP RIH FROM 6,247' TO 8,061' MD. 21:00 - 00:00 3.00 PERFOB P OTHCMP POH FROM 8,061' TO 4,815' MD. LAYING DOWN SINGLES 1 X 1 TO PIPE SHED. FLUID LOSSES TO PERFS FOR TOUR = 233 BBL FLUID LOSS RATE 25 TO 30 BBL / HOUR 11/21/2009 00:00 - 03:00 3.00 PERFOB P OTHCMP CONTINUE TO POH W/ 4 1/2" TCP GUNS FROM 4,815' TO TOP OF BHA. -LAY DOWN DRILL PIPE 1 X 1 TO PIPE SHED. 03:00 - 06:30 3.50 PERFOB P OTHCMP PJSM WITH SLB TCP AND 9 ES RIG PERSONNEL ON LAYING DOWN TCP GUNS. DOWN XO, BUMPER SUB & FIRING HEAD. CHANGE OUT ELEVATORS. -LAY DOWN & INSPECT TCP GUNS, ALL SHOTS FIRED. -309 BBL LOST DURING TRIP OUT OF HOLE. FLUID LOSSES TO PERFS - 40 TO 50 BBL / HR. 06:30 - 08:30 2.00 PERFOB P OTHCMP RIG DOWN TONGS, LAY DOWN SLB TCP TOOLS & EQUIPMENT. -CLEAN & CLEAR RIG FLOOR. 08:30 - 12:00 3.50 EVAL P OTHCMP PJSM W/ SLB SLICKLINE AND 9 ES PERSONEL ON RIGGING UP & RUNNING SLICKLINE. -SPOT SLB SLICKLINE UNIT, RIG UP SLB SLICKLINE. FLUID LOST TO PERFS FOR TOUR = 211 BBL 12:00 - 14:00 2.00 EVAL P OTHCMP SLB SLICKLINE RIH W/ 5.90" GAUGE RING, 5.5" JUNK BASKET & ROLLER STEM. -RIH TO 10,100' SLM, NO RESTRICTIONS NOTICED, POH. Printed: 12/17/2009 11:56:31 AM • BP Page 28 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/21/2009 12:00 - 14:00 2.00 EVAL P OTHCMP -JUNK BASKET RETURNED -1 GAL OF SAND AND GUN POWDER RESIDUE, NO METAL RETURNS. 14:00 - 16:00 2.00 EVAL P OTHCMP $LB RIH W/ 6.05" GAUGE RING, 5.5" JUNK BASKET & ROLLER STEM., -RIH TO 10,100' SLM, NO RESTRICTIONS NOTICED, POH. -JUNK BASKET RETURNED -3 CUPS OF SAND, NO METAL RETURNS. 16:00 - 18:30 2.50 EVAL P OTHCMP SLB RIH W/ 6.120" GAUGE RING, 5.5" JUNK BASKET & ROLLER STEM. -RIH TO 10,100' SLM, NO RESTRICTIONS NOTICED, POH. -JUNK BASKET EMPTY. 18:30 - 19:00 0.50 EVAL P OTHCMP PJSM W/ SLB & 9 ES PERSONEL ON RIGGING DOWN SLICKLINE. -SLB RIG DOWN MOVE OFF. 19:00 - 22:00 3.00 RUNCOMP RUNCMP PJSM W/ SLB I -WIRE, HALLIBURTON & 9 ES RIG PERSONEL ON RIGGING UP TO RUN COMPLETION. -PULL WEAR RING, STAGE I -WIRE SPOOLS & TOOLS ON RIG FLOOR. -RIG UP 4 1/2" CASING EQUIPMENT, STAGE LANDING JT & PUP JTS. ON RIG FLOOR. 22:00 - 00:00 2.00 RUNCOP'P RUNCMP PJSM W/ SLB I -WIRE, HALLIBURTON & 9 ES RIG PERSONEL ON RUNNING COMPLETION. -RIH W/ 3 1/2" 12.6# L -80 TCII TUBING JEWELRY AS PER RUNNING ORDER. - BAKERLOC FIRST 4 JTS. -PICK UP AND FEED I -WIRE THROUGH FIRST PACKER, INSTALL NDPG IN CARRIER. -TEST PACKER VOID TO 5,000 PSI. FLUID LOST TO PERFS FOR TOUR = 179 BBL TOTAL FLUID LOSSES TO PERFS = 623 11/22/2009 00:00 - 12:00 12.00 RUNCOMP RUNCMP CONTINUE RIH W/ 3 1/2 ", 12.6 #, L -80, TCII TUBING & JEWELRY AS PER RUNNING ORDER TO 1,565' MD. -FEED I -WIRE THROUGH EACH PACKER, INSTALL NDPG IN CARRIER. - INSTALL FULL CANNON CLAMP OVER EVERY OTHER JT & HALF CLAMP OVER EACH MANDREL. -TEST ALL PACKER VOIDS TO 5,000 PSI / 10 MIN. -TEST I WIRE CONTINUITY EVERY 20 JTS OR 2 HOURS. FLUID LOST TO PERFS FOR TOUR = 181 BBL 12:00 - 00:00 12.00 RUNCOMP RUNCMP CONTINUE RIH W/ 3 1/2 ", 12.6 #, L -80, TCII TUBING & JEWELRY AS PER RUNNING ORDER FROM 1,565' TO 6,547' MD. - INSTALL FULL CANNON CLAMP OVER EVERY OTHER JT & HALF CLAMP OVER EACH MANDREL. -TEST I WIRE CONTINUITY EVERY 20 JTS OR 2 HOURS. FLUID LOST TO PERFS FOR TOUR = 167 BBL TOTAL FLUID LOSSES TO PERFS = 971 BBL 11/23/2009 00:00 - 08:00 8.00 RUNCOMP RUNCMP CONTINUE RIH W/ 3 1/2 ", 12.6 #, L -80, TCII TUBING & JEWELRY FROM 6,547' TO 10,130' MD. - INSTALL FULL CANNON CLAMP OVER EVERY OTHER JT Printed: 12/17/2009 11:56:31 AM • i BP Page 29 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/23/2009 00:00 - 08:00 8.00 RUNCOMP RUNCMP & HALF CLAMP OVER EACH MANDREL. -TEST I WIRE CONTINUITY EVERY 20 JTS OR 2 HOURS. 08:00 - 09:00 1.00 RUNCOMP RUNCMP PJSM W/ SLB E -LINE AND RIG CREWS ON RUNNING WIRELINE. -RIG UP SLB E -LINE. 09:00 - 12:00 3.00 RUNCOMP RUNCMP RIH WITH GR/CCL LOGGING TOOL TO 10,080' ELM. -LOG UP FROM 10,080' TO 8,950' ELM. FLUID LOST TO PERFS FOR TOUR = 112 BBL 12:00 - 12:30 0.50 RUNCOI IP RUNCMP RIG DOWN SLB E -LINE 12:30 - 14:30 2.00 RUNCOMP RUNCMP MAKE UP HANGER & LANDING JT, TERMINATE I- WIRE, PRESSURE TEST TO 5,000 PSI. -LAY DOWN TUBING JOINTS FOR SPACE OUT. -SPACE OUT TUBING JOINTS USING A 19.78' PUP JOINT. -LAND TUBING W/ WLEG @ 10,130' MD, PUW 110K, SOW 65K, RILDS. - INSTALLED 176 FULL CLAMPS, 27 HALF CLAMPS. -DROP 1- 5/16" BALL AND ROD W/ ROLLER STEM. 14:30 - 19:00 4.50 RUNCOMN DFAL RUNCMP PRESSURE UP TUBING TO 4,500 PSI TO SET PACKERS. .•" - BLEED DOWN TO 4,000 PSI / 30 MIN, FOR TUBING TEST. - PRESSURE LOSS FIRST 15 MIN. 100 PSI, 2ND 15 MN 40 PSI. TEST GOOD. -DROP PRESSURE ON TUBING TO 2,500 PSI, PRESSURE UP ANNULUS TO 4,000 PSI. - ANNULUS LOSING PRESSURE 2,220 PSI FIRST 7 MIN. - PRESSURE UP ANNULUS AGAIN TO 4,000 PSI. - ANNULUS LOSING PRESSURE 600 PSI FIRST 15 MIN. - INSPECT ALL SURFACE EQUIPMENT. - PRESSURE UP TUBING TO 4,700 PSI / 5 MIN, ATTEMPT TO RESET PACKERS. -DROP PRESSURE ON TUBING TO 2,500 PSI, PRESSURE UP ANNULUS TO 4,100 PSI. - ANNULUS LOSING PRESSURE 540 PSI FIRST 15 MIN - ATTEMPT TO SET PRESURE UP SEVERAL MORE TIMES, ANNULUS PRESSURE DROP AROUND 500 PSI / 5 MIN. 19:00 - 20:00 1.00 RUNCOMN DFAL RUNCMP PRESSURE UP ON ANNULUS TO SHEAR DCK SHEAR VALVE, VALVE SHEARED @ 2,250 PSI. - ESTABLISH CIRCULATION / REVERSE CIRCULATION THROUGH SHEAR VALVE. 3 BPM @ 550 PSI. - PRESSURE UP TUBING & ANNULUS TO 4,000 PSI. - TUBING & ANNULUS LOSING PRESSURE TOGETHER. LOST 3,000 PSI IN 8 MIN. -BLEED OFF PRESSURE. 20:00 - 00:00 4.00 RUNCOMN DFAL RUNCMP MONITOR WELL, NO LOSSES @ SURFACE, IA PRESSURE 0 PSI. - DISCUSS PLAN FOWARD WITH ENGINEERING TEAM & DRILLING SUPERINTENDANT. -STAGE CORROSION INHIBITOR WHILE AWAITING SINGLE BARRIER DISPENSATION. FLUID LOST TO PERFS FOR TOUR = 125 BBL TOTAL FLUID LOSSES TO PERFS = 1,208 Printed: 12/17/2009 11:56:31 AM • • BP Page 30 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From To Hours Task Code NPT Phase Description of Operations 11/24/2009 00:00 - 02:30 2.50 RUNCOMP RUNCMP CIRCULATE 136 BBL 9.0 PPG BRINE TREATED W/ CORROSION INHIBITOR. - MAINTAIN 1 BBL / MIN CO 60 PSI PER HALLIBURTON TO PREVENT DAMAGE TO PACKER ELEMENTS. 02:30 - 03:00 0.50 RUNCOMP RUNCMP MONITOR WELL FOR 30 MINUTES FOR STATIC CONDITIONS. STATIC. -CLEAN & CLEAR RIG FLOOR, DRAIN STACK. -FMC DRYROD TWC. -TEST TO 1,000 PSI FROM ABOVE / 10 MIN WHILE MONITORING IA PRESSURE. -PULL AND SECURE MOUSEHOLE, LINE UP SUPER SUCKER. -CLEAN MUD FROM UNDER ROTARY TABLE. 03:00 - 08:00 5.00 BOPSUF P RUNCMP PJSM WITH RIG HANDS ON ND BOP STACK. -PULL RISER & TURN BUCKLES, PULL AND SECURE BOPE. 08:00 - 14:30 6.50 WHSUR P RUNCMP MOVE TREE & ADAPTER FLANGE INTO CELLAR. -SLB PERFORM CONTINUITY TEST ON I -WIRE. - INSTALL ADAPTER FLANGE AND DOUBLE MASTER VALVES. -SLB TERMINATE I -WIRE THROUGH ADAPTER FLANGE. -FMC INSTALL AND TORQUE ADAPTER FLANGE AND TREE. - ENERGIZE SEALS, TEST TO 5,000 PSI FOR 30 MINUTES. -FILL TREE W/ DIESEL. PRESSURE TEST TO 5,000 PSI.. OK. 14:30 - 15:30 1.00 WHSUR P RUNCMP PJSM W/ DSM AND 9 ES RIG PERSONEL ON PULLING TWC. -RIG UP DSM LUBRICATOR. - PRESSURE TEST TO 500 PSI, PULL TWC. -WELL IS ON VAC. 15:30 - 20:00 4.50 BOPSUF P RUNCMP PJSM W/ RIG, SLB & LRS WORKERS ON PUMPING DIESEL. -RU LRS TO TUBING SPOOL ANNULAR VALVE. -SLB I -WIRE TECH CONNECT TO GAUGES TO MONITOR IA PRESSURE WHILE PUMPING FREEZE PROTECT. - PRESSURE TEST LINES TO 3,000 PSI. - FREEZE PROTECT TO 2,500' TVD, 3,924' MD. -PUMP 136 BBL, 70 DEGREE DIESEL DOWN IA, 1 BPM 400 PSI. -I -WIRE NDPG NOTED 50 PSI INCREASE IN ZONE 1 DURING FREEZE PROTECT PUMPING. -ALLOW DIESEL TO U -TUBE INTO TUBING STRING. -103 BBL IN ANNULUS, 35 BBL IN TUBING STRING. - SECURE TOP DRIVE IN SLIPS. FINAL SHUT IN TUBING PRESSURE 0 PSI. 20:00 - 00:00 4.00 WHSUR P RUNCMP DSM INSTALL BPV, LRS PRESSURE TEST FROM BELOW 1,000 PSI. (ROLLING TEST DUE TO FAILED TOP PACKER) -DSM INSTALL VR PLUGS IN ALL 3 ANNULUS VALVES. - SECURE CELLAR - PREPARE RIG TO MOVE TO V -224 Printed: 12/17/2009 11:56:31 AM i • BP Page 31 of 31 Operations Summary Report Legal Well Name: V -227 Common Well Name: V -227 Spud Date: 11/2/2009 Event Name: DRILL +COMPLETE Start: 10/22/2009 End: 11/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/25/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 11/24/2009 20:00 - 00:00 4.00 WHSUR P RUNCMP -T/ IA/ OA PRESSURE 0 / 0 / 0 - RELEASE RIG TO V -224 @ 00:00 HOURS FLUID LOST TO PERFS FOR TOUR = 32 BBL TOTAL FLUID LOSSES TO PERFS = 1,240 Printed: 12/17/2009 11:56:31 AM a by 0 V -227 Survey Report Schlumberger Report Date: 12- Nov -09 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 41.240 Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: V -Pad / Plan V Slot (N -Y) TVD Reference Datum: Rotary Table Well: V -227 drilling TVD Reference Elevation: 81.30 ft relative to MSL Borehole: V -227 Sea Bed 1 Ground Level Elevation: 52.80 ft relative to MSL UWIIAPI #: 500292341700 Magnetic Declination: 22.177° Survey Name I Date: V -227 / November 12, 2009 Total Field Strength: 57658.547 nT Tort 1 AHD 1 DDI I ERD ratio: 200.079° / 8221.88 ft / 6.520 / 1.601 Magnetic Dip: 80.888° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 06, 2009 Location LatlLong: N 70.32817845, W 149.26386090 Magnetic Declination Model: BGGM 2009 Location Grid N/E YIX: N 5970149.970 ftUS, E 590767.450 ftUS North Reference: True North Grid Convergence Angle: +0.69317957 Total Corr Mag North -> True North: +22.177° Grid Scale Factor: 0.99990936 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) (deg) (ft ) (ft ) (ft ) (ft ) (ft ) (ft ) (ft ) (deg/100ft ) (ftUS) (ftUS) RTE 0.00 0.00 0.00 -81.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970149.97 590767.45 N 70.32817845 W 149.26386090 GYD GC SS 100.00 0.21 59.13 18.70 100.00 0.17 0.18 0.18 0.09 0.16 0.21 5970150.07 590767.61 N 70.32817871 W 149.26385962 172.60 0.14 30.73 91.30 172.60 0.39 0.40 0.40 0.24 0.32 0.15 5970150.21 590767.76 N 70.32817910 W 149.26385833 262.70 0.71 29.20 181.40 262.70 1.04 1.07 1.04 0.82 0.65 0.63 5970150.80 590768.09 N 70.32818069 W 149.26385566 368.43 0.58 35.80 287.12 368.42 2.22 2.26 2.23 1.83 1.28 0.14 5970151.81 590768.71 N 70.32818344 W 149.26385053 459.43 2.08 54.92 378.09 459.39 4.28 4.36 4.28 3.15 2.90 1.70 5970153.15 590770.31 N 70.32818705 W 149.26383739 489.33 3.22 55.51 407.96 489.26 5.62 5.74 5.64 3.94 4.04 3.81 5970153.95 590771.44 N 70.32818920 W 149.26382818 550.43 4.43 49.09 468.92 550.22 9.62 9.81 9.69 6.45 7.23 2.10 5970156.51 590774.60 N 70.32819608 W 149.26380224 611.43 4.87 37.24 529.72 611.02 14.54 14.74 14.60 10.06 10.58 1.73 5970160.15 590777.91 N 70.32820593 W 149.26377510 642.43 5.11 30.70 560.61 641.91 17.21 17.43 17.24 12.29 12.08 1.99 5970162.41 590779.38 N 70.32821203 W 149.26376293 734.43 5.46 36.39 652.22 733.52 25.60 25.90 25.60 19.34 16.77 0.68 5970169.51 590783.98 N 70.32823128 W 149.263 830.00 6.22 46.79 747.29 828.59 35.28 35.60 35.28 26.54 23.24 1.36 5970176.79 590790.37 N 70.32825097 W 149.26 1 925.00 7.57 42.64 841.60 922.90 46.66 47.00 46.66 34.67 31.23 1.51 5970185.01 590798.26 N 70.32827317 W 149.263 3 MWD +IFR +MS 947.60 8.45 44.18 863.98 945.28 49.81 50.14 49.81 36.96 33.40 4.01 5970187.33 590800.39 N 70.32827941 W 149.26359007 1042.96 10.33 45.29 958.06 1039.36 65.33 65.70 65.36 48.00 44.36 1.98 5970198.50 590811.22 N 70.32830958 W 149.26350119 1137.98 14.80 49.60 1050.78 1132.08 85.85 86.36 85.95 61.86 59.66 4.80 5970212.55 590826.35 N 70.32834746 W 149.26337708 1234.86 20.77 53.04 1142.99 1224.29 114.93 115.93 115.32 80.23 82.83 6.25 5970231.19 590849.30 N 70.32839763 W 149.26318919 1330.72 26.51 52.23 1230.77 1312.07 152.60 154.35 153.54 103.57 113.35 6.00 5970254.90 590879.53 N 70.32846140 W 149.26294170 1426.50 31.28 50.05 1314.61 1395.91 198.19 200.62 199.74 132.65 149.33 5.10 5970284.40 590915.15 N 70.32854083 W 149.26264992 1521.71 38.06 48.77 1392.87 1474.17 251.77 254.74 253.86 167.90 190.40 7.16 5970320.15 590955.79 N 70.32863714 W 149.26231687 1616.93 42.81 48.81 1465.32 1546.62 312.98 316.48 315.60 208.58 236.85 4.99 5970361.38 591001.74 N 70.32874826 W 149.26194020 1712.44 49.22 45.84 1531.63 1612.93 381.27 385.16 384.25 255.20 287.27 7.07 5970408.60 591051.59 N 70.32887561 W 149.26153129 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (N -Y) \V -227 drilling \V - 227 \V -227 Generated 12/15/2009 1:46 PM Page 1 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub-Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft) (deg) _ (deg) (ft) (ft) (ft) (ft) (ft) _ (ft) (ft) (degl100it) (ftUS) (ttUS) 1808.44 50.46 44.90 1593.54 1674.84 454.45 458.53 457.53 306.74 339.48 1.49 5970460.77 591103.16 N 70.32901642 W 149.26110791 1903.55 53.53 45.55 1652.09 1733.39 529.20 533.46 532.40 359.51 392.68 3.27 5970514.17 591155.71 N 70.32916058 W 149.26067646 1996.55 57.47 44.93 1704.76 1786.06 605.64 610.09 608.97 413.48 447.08 4.27 5970568.79 591209.46 N 70.32930800 W 149.26023524 2093.28 61.35 48.23 1753.98 1835.28 688.51 693.33 692.20 470.65 507.57 4.97 5970626.69 591269.24 N 70.32946419 W 149.25974467 2189.26 63.54 49.96 1798.38 1879.68 772.79 778.42 777.24 526.36 571.88 2.79 5970683.16 591332.87 N 70.32961635 W 149.25922307 2284.98 68.13 51.93 1837.56 1918.86 858.84 865.73 864.39 581.34 639.70 5.15 5970738.95 591400.01 N 70.32976655 W 149.25867310 2381.35 68.63 51.52 1873.07 1954.37 946.93 955.32 953.78 636.84 710.03 0.65 5970795.29 591469.66 N 70.32991814 W 149.25810268 2476.19 68.57 50.22 1907.68 1988.98 1033.99 1043.62 1041.99 692.56 778.52 1.28 5970851.83 591537.47 N 70.33007036 W 149.25754715 2571.15 69.36 53.48 1941.77 2023.07 1121.09 1132.25 1130.45 747.30 848.21 3.31 5970907.40 591606.48 N 70.33021987 W 149.25698191 2666.80 69.79 54.90 1975.15 2056.45 1208.44 1221.88 1219.69 799.74 920.90 1.46 5970960.72 591678.53 N 70.33036311 W 149.25639234 2762.73 68.75 54.99 2009.10 2090.40 1295.61 1311.60 1308.96 851.27 994.35 1.09 5971013.13 591751.33 N 70.33050387 W 149.25579666 2858.51 68.94 54.93 2043.67 2124.97 1382.38 1400.93 1397.90 902.56 1067.48 0.21 5971065.29 591823.84 N 70.33064395 W 149.255 7 2953.69 68.99 54.66 2077.83 2159.13 1468.74 1489.76 1486.42 953.77 1140.07 0.27 5971117.37 591895.79 N 70.33078383 W 149.254 3049.44 70.97 55.50 2110.61 2191.91 1556.09 1579.72 1576.05 1005.26 1213.83 2.23 5971169.75 591968.92 N 70.33092447 W 149.25401639 3145.03 70.22 55.11 2142.37 2223.67 1643.55 1669.88 1665.90 1056.58 1287.96 0.87 5971221.96 592042.42 N 70.33106464 W 149.25341512 3240.55 68.88 54.81 2175.75 2257.05 1730.49 1759.38 1755.15 1107.97 1361.24 1.43 5971274.22 592115.06 N 70.33120498 W 149.25282074 3336.05 69.79 56.69 2209.45 2290.75 1816.99 1848.73 1844.19 1158.25 1435.10 2.07 5971325.39 592188.30 N 70.33134231 W 149.25222165 3431.93 70.03 56.75 2242.38 2323.68 1903.77 1938.78 1933.83 1207.66 1510.38 0.26 5971375.70 592262.97 N 70.33147726 W 149.25161103 3527.30 68.17 56.28 2276.41 2357.71 1989.71 2027.87 2022.57 1256.81 1584.68 2.00 5971425.74 592336.67 N 70.33161149 W 149.25100829 3623.20 69.25 56.68 2311.23 2392.53 2075.92 2117.22 2111.61 1306.15 1659.18 1.19 5971475.98 592410.55 N 70.33174625 W 149.25040402 3718.71 68.55 57.18 2345.61 2426.91 2161.71 2206.33 2200.37 1354.78 1733.85 0.88 5971525.50 592484.62 N 70.33187903 W 149.24979831 3814.51 68.97 57.68 2380.31 2461.61 2247.46 2295.62 2289.28 1402.84 1809.10 0.65 5971574.47 592559.28 N 70.33201030 W 149.24918789 3910.16 70.07 57.96 2413.78 2495.08 2333.34 2385.23 2378.47 1450.56 1884.93 1.18 5971623.10 592634.53 N 70.33214062 W 149.24857269 4005.52 69.21 57.65 2446.96 2528.26 2419.03 2474.63 2467.49 1498.20 1960.59 0.95 5971671.64 592709.59 N 70.33227069 W 149.24795897 4101.35 69.04 56.99 2481.10 2562.40 2505.06 2564.17 2556.74 1546.54 2035.96 0.67 5971720.89 592784.36 N 70.33240272 W 149.24734759 4197.39 69.24 56.66 2515.30 2596.60 2591.51 2653.91 2646.27 1595.65 2111.07 0.38 5971770.89 592858.87 N 70.33253682 W 149.24673822 4292.39 69.60 55.85 2548.70 2630.00 2677.41 2742.85 2735.06 1645.06 2185.02 0.88 5971821.18 592932.21 N 70.33267173 W 149.24613829 4387.64 69.52 55.26 2581.96 2663.26 2763.89 2832.10 2824.23 1695.54 2258.63 0.59 5971872.55 593005.19 N 70.33280958 W 149.24554117 4483.92 69.97 54.67 2615.29 2696.59 2851.63 2922.43 2914.50 1747.39 2332.59 0.74 5971925.29 593078.51 N 70.33295118 W 149.244 4578.75 70.00 54.18 2647.75 2729.05 2938.39 3011.53 3003.59 1799.23 2405.06 0.49 5971977.99 593150.34 N 70.33309273 W 149.244 4674.91 69.82 55.35 2680.78 2762.08 3026.19 3101.84 3093.86 1851.33 2478.82 1.16 5972030.98 593223.46 N 70.33323500 W 149.24375478 4768.42 69.55 56.47 2713.25 2794.55 3111.02 3189.53 3181.46 1900.48 2551.44 1.16 5972081.00 593295.48 N 70.33336921 W 149.24316560 4864.17 68.75 56.33 2747.33 2828.63 3197.39 3279.01 3270.81 1950.00 2625.97 0.85 5972131.41 593369.40 N 70.33350442 W 149.24256093 4960.18 69.40 55.86 2781.62 2862.92 3284.07 3368.69 3360.39 2000.02 2700.40 0.82 5972182.33 593443.21 N 70.33364101 W 149.24195708 5056.07 68.84 56.08 2815.79 2897.09 3370.72 3458.28 3449.90 2050.16 2774.65 0.62 5972233.36 593516.84 N 70.33377791 W 149.24135467 5151.65 69.80 55.72 2849.55 2930.85 3457.23 3547.70 3539.25 2100.29 2848.69 1.06 5972284.38 593590.26 N 70.33391479 W 149.24075391 5247.16 69.97 55.32 2882.39 2963.69 3544.14 3637.39 3628.88 2151.07 2922.62 0.43 5972336.03 593663.57 N 70.33405342 W 149.24015408 5342.57 69.10 55.01 2915.75 2997.05 3630.90 3726.77 3718.24 2202.13 2995.99 0.96 5972387.97 593736.31 N 70.33419283 W 149.23955878 5368.49 68.94 55.11 2925.03 3006.33 3654.40 3750.97 3742.44 2215.99 3015.83 0.71 5972402.07 593755.97 N 70.33423067 W 149.23939781 5485.22 67.49 55.00 2968.35 3049.65 3759.66 3859.36 3850.80 2278.07 3104.68 1.25 5972465.22 593844.06 N 70.33440018 W 149.23867690 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (N -Y) \V -227 drilling \V - 227 \V -227 Generated 12/15/2009 1:46 PM Page 2 of 4 • Measured Azimuth Vertical Along Hole NS EW s Comments Depth Inclination True Sub•Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) (deg) (ft ) (ft ) (ft ) (ft ) (ft) (ft) (ft) (deg/100ft ) (ftUS) _ (ftUS) 5579.85 70.20 56.93 3002.50 3083.80 3844.99 3947.61 3938.97 2327.45 3177.81 3.44 5972515.47 593916.58 N 70.33453499 W 149.23808352 5675.77 69.93 56.65 3035.21 3116.51 3931.87 4037.78 4029.02 2376.83 3253.25 0.39 5972565.76 593991.41 N 70.33466983 W 149.23747136 5770.45 68.81 57.53 3068.57 3149.87 4017.10 4126.39 4117.49 2424.98 3327.64 1.47 5972614.80 594065.20 N 70.33480126 W 149.23686779 5865.37 68.97 56.12 3102.75 3184.05 4102.39 4214.94 4205.92 2473.43 3401.75 1.40 5972664.14 594138.72 N 70.33493354 W 149.23626642 5961.33 69.18 55.32 3137.03 3218.33 4189.18 4304.57 4295.51 2523.92 3475.81 0.81 5972715.51 594212.16 N 70.33507136 W 149.23566546 6057.61 69.73 54.92 3170.82 3252.12 4276.70 4394.72 4385.65 2575.47 3549.77 0.69 5972767.96 594285.48 N 70.33521212 W 149.23506531 6153.45 70.06 54.85 3203.76 3285.06 4364.16 4484.72 4475.64 2627.24 3623.39 0.35 5972820.61 594358.46 N 70.33535345 W 149.23446791 6248.89 69.89 54.27 3236.44 3317.74 4451.42 4574.39 4565.31 2679.24 3696.45 0.60 5972873.48 594430.88 N 70.33549540 W 149.23387507 6344.23 68.93 54.90 3269.97 3351.27 4538.26 4663.64 4654.55 2730.96 3769.18 1.18 5972926.07 594502.97 N 70.33563659 W 149.23328484 6439.59 69.96 54.93 3303.45 3384.75 4625.01 4752.93 4743.83 2782.28 3842.25 1.08 5972978.27 594575.40 N 70.33577670 W 149.23269192 6534.95 69.18 55.66 3336.74 3418.04 4711.70 4842.29 4833.17 2833.16 3915.71 1.09 5973030.03 594648.24 N 70.33591559 W 149.23209577 6630.80 69.95 54.69 3370.20 3451.50 4798.87 4932.11 4922.97 2884.45 3989.44 1.24 5973082.20 594721.33 N 70.33605561 W 149.231 6725.83 69.20 55.04 3403.37 3484.67 4885.42 5021.16 5012.02 2935.70 4062.27 0.86 5973134.33 594793.53 N 70.33619552 W 149.230 6822.03 70.07 55.57 3436.85 3518.15 4972.90 5111.35 5102.19 2987.04 4136.42 1.04 5973186.55 594867.05 N 70.33633565 W 149.23030465 6917.44 69.42 55.58 3469.88 3551.18 5059.63 5200.86 5191.67 3037.64 4210.25 0.68 5973238.03 594940.26 N 70.33647378 W 149.22970545 7012.63 69.24 55.32 3503.48 3584.78 5145.96 5289.92 5280.71 3088.15 4283.61 0.32 5973289.42 595012.99 N 70.33661165 W 149.22911013 7107.72 69.86 55.85 3536.70 3618.00 5232.28 5379.02 5369.78 3138.50 4357.11 0.84 5973340.66 595085.87 N 70.33674910 W 149.22851361 7202.94 69.42 56.16 3569.83 3651.13 5318.60 5468.29 5459.01 31 88.42 4431.12 0.55 5973391.46 595159.27 N 70.33688534 W 149.22791294 7298.45 69.25 56.40 3603.53 3684.83 5404.91 5557.65 5548.32 3238.03 4505.45 0.29 5973441.96 595232.98 N 70.33702075 W 149.22730969 7394.61 68.99 52.66 3637.82 3719.12 5492.33 5647.49 5638.15 3290.15 4578.61 3.64 5973494.96 595305.50 N 70.33716302 W 149.22671593 7489.79 69.41 48.09 3671.63 3752.93 5580.15 5736.46 5726.89 3346.88 4647.11 4.51 5973552.51 595373.31 N 70.33731788 W 149.22615987 7585.77 67.25 43.75 3707.09 3788.39 5669.01 5825.65 5815.13 3408.89 4711.18 4.77 5973615.28 595436.62 N 70.33748718 W 149.22563976 7681.74 65.99 39.45 3745.18 3826.48 5757.07 5913.73 5901.14 3474.73 4769.66 4.32 5973681.82 595494.29 N 70.33766695 W 149.22516500 7776.68 64.62 35.65 3784.86 3866.16 5843.13 5999.98 5983.93 3543.09 4822.23 3.91 5973750.80 595546.02 N 70.33785361 W 149.22473817 7871.75 64.02 31.67 3826.07 3907.37 5928.03 6085.65 6064.47 3614.38 4869.71 3.83 5973822.66 595592.63 N 70.33804829 W 149.22435257 7967.26 63.66 27.29 3868.20 3949.50 6011.93 6171.37 6142.90 3688.98 4911.89 4.13 5973897.75 595633.90 N 70.33825201 W 149.22400998 8061.93 63.70 22.68 3910.19 3991.49 6093.37 6256.22 6217.85 3765.86 4947.72 4.36 5973975.06 595668.79 N 70.33846199 W 149.22371890 8157.58 63.83 18.32 3952.49 4033.79 6173.58 6342.01 6290.57 3846.20 4977.75 4.09 5974055.75 595697.85 N 70.33868141 W 149.22347478 8254.16 64.21 14.04 3994.81 4076.11 6252.20 6428.82 6360.88 3929.56 5001.93 4.00 5974139.38 595721.02 N 70.33890909 W 149.223 8349.61 63.15 10.36 4037.14 4118.44 6326.98 6514.37 6426.98 4013.16 5020.02 3.63 5974223.19 595738.09 N 70.33913744 W 149.223 8445.23 64.27 6.26 4079.51 4160.81 6398.91 6600.09 6489.86 4097.96 5032.39 4.02 5974308.13 595749.44 N 70.33936910 W 149.22303010 8540.90 63.22 2.24 4121.84 4203.14 6467.43 6685.88 6549.11 4183.50 5038.76 3.92 5974393.73 595754.77 N 70.33960276 W 149.22297795 8636.72 63.64 359.04 4164.71 4246.01 6532.48 6771.58 6604.89 4269.18 5039.72 3.02 5974479.40 595754.69 N 70.33983683 W 149.22296975 8732.88 61.57 358.27 4208.96 4290.26 6595.34 6856.95 6658.86 4354.52 5037.72 2.27 5974564.71 595751.66 N 70.34006999 W 149.22298550 8828.19 62.59 357.87 4253.58 4334.88 6656.76 6941.16 6712.08 4438.69 5034.88 1.13 5974648.83 595747.80 N 70.34029994 W 149.22300807 8923.58 61.45 357.57 4298.34 4379.64 6717.85 7025.40 6765.54 4522.86 5031.53 1.23 5974732.95 595743.43 N 70.34052989 W 149.22303479 9019.33 61.60 357.58 4343.99 4425.29 6778.73 7109.57 6819.42 4606.95 5027.97 0.16 5974816.98 595738.85 N 70.34075963 W 149.22306323 9114.74 58.85 357.49 4391.36 4472.66 6838.59 7192.37 6872.98 4689.68 5024.41 2.88 5974899.66 595734.29 N 70.34098564 W 149.22309167 9210.04 58.85 359.76 4440.66 4521.96 6898.61 7273.93 6927.44 4771.21 5022.45 2.04 5974981.15 595731.35 N 70.34120837 W 149.22310710 9305.63 58.46 357.19 4490.40 4571.70 6958.54 7355.57 6982.34 4852.81 5020.28 2.33 5975062.71 595728.20 N 70.34143130 W 149.22312426 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (N -Y) \V -227 drilling \V- 227 \V -227 Generated 12/15/2009 1:46 PM Page 3 of 4 Measured Azimuth Vertical Along Hole NS EW ' • Comments Depth Inclination True Sub-Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) _ (deg) (ft ) (ft ) (ft ) (ft ) (ft ) (ft ) _ (ft ) (deg/100ft ) (ftUS) (ftUS) 9400.96 58.17 356.69 4540.47 4621.77 7016.60 7436.69 7035.79 4933.82 5015.95 0.54 5975143.64 595722.89 N 70.34165260 W 149.22315895 9496.91 57.83 356.93 4591.31 4672.61 7074.70 7518.06 7089.79 5015.06 5011.42 0.41 5975224.82 595717.38 N 70.34187456 W 149.22319525 9592.11 58.59 358.10 4641.47 4722.77 7133.18 7598.97 7144.75 5095.90 5007.92 1.31 5975305.60 595712.89 N 70.34209542 W 149.22322326 9687.44 59.36 356.63 4690.60 4771.90 7192.06 7680.66 7200.56 5177.50 5004.16 1.55 5975387.15 595708.15 N 70.34231835 W 149.22325332 9782.67 57.26 356.16 4740.63 4821.93 7249.51 7761.69 7255.42 5258.37 4999.07 2.24 5975467.94 595702.08 N 70.34253928 W 149.22329420 9878.85 57.02 355.81 4792.81 4874.11 7306.39 7842.48 7310.17 5338.96 4993.41 0.39 5975548.45 595695.45 N 70.34275946 W 149.22333966 9970.13 57.49 355.85 4842.19 4923.49 7360.28 7919.26 7362.50 5415.53 4987.83 0.52 5975624.94 595688.94 N 70.34296866 W 149.22338455 10060.90 56.17 355.54 4891.85 4973.15 7413.50 7995.23 7414.57 5491.29 4982.13 1.48 5975700.62 595682.32 N 70.34317565 W 149.22343041 10152.77 54.21 355.89 4944.29 5025.59 7466.34 8070.66 7466.69 5566.51 4976.49 2.16 5975775.76 595675.78 N 70.34338114 W 149.22347576 10244.68 53.92 355.20 4998.23 5079.53 7518.32 8145.08 7518.34 5640.70 4970.71 0.68 5975849.87 595669.10 N 70.34358383 W 149.22352226 Last Survey 10276.98 53.63 354.62 5017.32 5098.62 7536.31 8171.13 7536.31 5666.65 4968.40 1.70 5975875.79 595666.48 N 70.34365474 W 149.22354088 TD (Projected) 10340.00 53.63 354.62 5054.69 5135.99 7571.16 8221.88 7571.25 5717.18 4963.64 0.00 5975926.24 595661.11 N 70.34379277 W 149.2235 Survey Type: Definitive Survey NOTES: GYD GC SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - (In -field referenced MWD with mult- station analysis and correction applied in post - processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Survey Error Model: BP ISCWSA version 10 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Prog: MD From 1 ft 1 MD To ( ft ) EOU Fret; Survey Tool Type Borehole -> Survey 0.00 27.30 Act -Stns BP_GYD SS -Depth Only V -227 -> V -227 27.30 925.00 Act -Stns BP_GYD SS V -227 -> V -227 925.00 5368.49 Act -Stns BP_MWD +IFR +MS^ ^1 V -227 -> V -227 5368.49 10276.98 Act -Stns BP_MWD +IFR +MS^ ^2 V -227 -> V -227 10276.98 10340.00 Act -Stns BP_BLIND V -227 -> V -227 Legal Description: Northing (V) (ftUS( Easting (X) (ftUS( Surface : 4900 FSL 1533 FEL S11 T11N R11E UM 5970149.97 590767.45 BHL : 55 FSL 1844 FEL S36 T12N R11 E UM 5975926.24 595661.11 • SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (N -Y) \V -227 drilling \V-227W-227 Generated 12/15/2009 1:46 PM Page 4 of 4 TREE= I 4- 1/16" CIW IP WAIT:HEAD = FMC SAF TES: PACKER FAILED PRESSURE TEST A CTUATOR = Electric \(-2 2 7 KB. ELEV = 81.3' DRLG DRAFT BF. = 40000' ' 120" CONDUCTOR H 176' = 5 KOP = ) I I 24' 1 X 3-1/2" XO, ID = 2.992"1 Max Angle = 71° @ 3049' Datum MD = I 3927' 1 HES X NIP, ID = 2.813" I Datum TVD = 4400' SS GAS LIFT MANDRELS ST MD 'TVD DEV TYPE VLV LATCH FORT DATE [9 -5/8" CSG, 40 #, L -80, BTGM, ID = 8.835" H 5417' 1019096 4463 58 MMG I DCR BEK I 0 11/23/09 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE I7" CSC, 26 #, L -80 TCII XO TO L -80 BTGM H $481' 9 9189 4511 58 MMG -W DMY RK 0 11/23/09 Ilirl 8 9249 4542 58 MMG -W DMY RK 0 11/23/09 7 9557 4705 57 MMG -W DMY RK 0 11/23/09 Minimum ID = 2.75 "@ 10,108' 6 9626 4740 59 MMG-W DMY RK 0 11/23/09 5 9677 4766 59 MMG -W DMY RK 0 11/23/09 3 -1/2" HES XN NIPPLE 4 9722 4790 58 MMG-W DMY RK 0 11/23/09 3 9870 4869 57 MMG-W DMY RK 0 11/23/09 2 9960 4918 57 MMG -W DMY RK 0 11/23/09 1 10048 4966 56 MMG -W DMY RK 0 11/23/09 9125' H7" X 3-1/2" AHR, DUAL FEED PKR, ID = 2.965" 9138' H 3 -1/2" NDPG MULTI- SENSOR SUB , ID = 2.992" I 11/ 1 915W j--I3 - 1/2" HES X NIP, ID = 2.813" I 1 1 I 3 -1/2" RA PIP TAG H 94$0' 9493' H7" X 3 -1/2 "AHR, DUAL FEED PKR, D = 2.965" I F I 9506' I -13 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992" I ' I 9527' H 3 -1/2" HES X NP, ID = 2.813" I 7' MARKER JOINT w /RA PIP TAG H 9532' �, I 9645' H 7" X 3 -1/2" AHR, DUAL FEED PKR, ID = 2.965" I 1 9653' H3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2,992" I I 9664' 1--I3 - 1/2" HES X NIP, ID = 2.813" I NWI PERFORATION SUMMARY _ 9806' — 17" X 3 -1/2" AHR, DUAL FEED PKR, ID = 2.965" REF LOG: , 11 I 9819' H3-1/2" NDPG MULTI - SENSOR SUB , ID = 2.992" I ANGLE AT TOP PERF: 59° @ 9226' Note: Refer to Production DB for historical perf data I I 9849' I--I3 -1/2" HES X NIP, ID = 2.813" I SIZE SPF ZONE INTERVAL Opn /Sqz DATE L I 4 -1/2" 5 Nb 9226 -9252 0 11/20/09 4 -1/2" 5 OBa 9578 -9632 0 11/20/09 I 9979' H7" X 3 -1/2" AHR,DUAL FEED PKR, ID = 2.965" I 4 -1/2" 5 OBb 9660 -9696 0 11/20/09 � M 4 -1/2" 5 OBd 9873 -9960 0 11/20/09 ■— I 9992' I--I3 - 1/2" NDPG MULTI - SENSOR SUB , ID = 2.992" I 4 -1/2" 5 Obe 9992 -10032 0 11/20/09 I 1 10027' H3 -1/2" HES X NIP, ID = 2.813" I INVI 10087 ' -{ 3 -1 /2" HES X NIP, ID = 2.813" 1 I 10108' I- 13 -1/2" HES XN NIP, ID = 2.750" I 13-1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H 10130' 10130' I - 1/2" WLEG, ID = 2.992" I I PBTD H 10246' I 17" CSG, 26 #, L -80 BTC-M, ID = 6.276" H 10332' DATE REV BY COMMENTS ® DATE REV BY COMMENTS ORION UNIT 11/24/09 N9ES INITIAL COMPLETION WELL: V -227i 11/27/09 SV DLRG HO CORRECTIONS PERMIT No: 209 -116 API No: 50- 029 - 23417 -00 SEC 11, T11 N, R11 E, 380' FNL & 1,533' FEL Zach Sayers BP Exploration (Alaska) 02/05/10 Scbennberger NO. 5463 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambol! Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Q Date BL Color CD 09-45 AP30 -00077 CROSSFLOW CHECK j j 7j - f/ y j 0 01/28/10 1 1 V -217 B2NJ -00051 MEMORY INJ PROFILE I) 7 jt 0- L 3 113 01/27/10 I 1 C -10A B3S0 -00038 RST .)Q15 - -- !';.f / 12/28/09 1 1 V -227 09AKA0146 OH MWD/LWD EDIT 1 r , ,,� j l (0 , ) 3j 11/12/09 2 1 i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: • BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Bivd. Anchorage, AK 99503 -2838 �'` s F VI t t ' , , , 5 ; R� fit 10 ■ Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -08A B581-00015 PRODUCTION PROFILE / 53 --/a. 1r /059 j A 10/25/09 1 1 3- 27/M -33 88K5 -00012 PRODUCTION PROFILE [I& — / j f 11/18/09 1 1 2- 34/P -14 AWJI -00061 MEM INJECTION PROFILE IL 8QG, --l' - 1,9i 12/01/09 1 1 S -213A B8K5 -00007 GAS LIFT SURVEY )0q - /a3 ',aye 10/26/09 1 1 i-,P V -227 B69K -00036 USIT U'IC°. a ( - S — I / 0 / O 11/19/09 _ 1 1 06 -1 B2NJ -00033 MCNL a(' S -No3 /o 0 / 10/12/09 1 _ 1 , L3 -11 AP30-00065 RST 'z -- -a i3 I'' a 10/31/09 1 1 Q -04B B2NJ -00036 MCNL 0 *A — ap - .. • - 11/04/09 1 1 H-058 B2WY -00033 MCNL 41 _ ! a 0 �q49p1. 10/20/09 1 1 • _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services • Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 \ . ! I�. N 13 2010 V J n0.'& (� �' "zi . G ,(: r : , .. 1 6 ;S` ( "' � '� 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, November 12, 2009 6:26 PM To: Sayers, Zach J Cc: Tirpack, Robert B cie—* — Subject: RE: V -2271 Nb Sand Thanks Zach. I appreciate the information. It appears that you still have sufficient intervals to make a completion. Tom Maunder, PE AOGCC From: Sayers, Zach J [mailto:Zach.Sayers @bp.com] Sent: Thu 11/12/2009 4:25 PM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B Subject: V -227i Nb Sand Tom, As a courtesy, I am informing you that the Nb sand we planned to inject into was faulted out and not developed properly to inject into. We believe that this will risk our injection strategy for this well. We will still be completing the four 0 sands as originally planned. Thank you, Zach Sayers Drilling Engineer GPB Rotary Drilling BP Exploration Alaska (907) 564-5790 — Direct (907) 575 -5189 — Cell 11/13/2009 • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Drlg 9es Toolpusher [NSUADWDrIg9esToolpusher @BP.c Sent: Wednesday, November 04, 2009 11:38 AM ' � ,1 1 ) 1 ( 4 ` J Y [� To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: 9ES Diverter Test F/ 10 -31 -2009 Attachments: Diverter Report Template 10- 31- 09p.xls / _ /1c9 Folks, My apology for the oversight. Looks like I fat fingered the distance. It should have stated 80'. I have amended the form and resubmitted it and updated my files. Respectfully, CZ Coyne From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, November 04, 2009 10:40 AM To: NSU, ADW Drlg 9es Toolpusher Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: 9ES Diverter Test F/ 10 -31 -2009 PBU V -227, PTD 2091160 Reported distance from diverter vent line outlet to closest potential ignition source is 60 feet; 20 AAC 25.035(c)(2) (C)(i) requires distance to be at least 75 feet. Approved permit does not include any departure from the requirement; this must be shown as a Fail ( "F ") and explanation provided. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSU, ADW Drlg 9es Toolpusher [mailto: NSUADWDrIg9esToolpusher @BP.com] Sent: Monday, November 02, 2009 3:43 AM To: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: 9ES Diverter Test F/ 10 -31 -2009 IC I 11/4/2009 Orion Pool /Injection i1 Area Illailm.., i i le #. Well Base Map U iiiiimigitig dlehhu illier Ili- �.. Prudhoe Bay pi N. I 0 .''' I nt :ou •ary iE-j _2 ' ` ga " ' Red O utli ne O ri on L205 mir ii..... _ I iii ' - li 1- TeallFal lit F . II ` > Ea; = Pool /injection Area LPad + � ' 1Y ' t \ N , E } Nik Orion Development Polygon �� ►ear.; : k • ' 213 Orion Production Well r 1 ,�. Completed Pre 811,08 Vi203) S . .. ,; ,,rt so; Pad ' till Orion Production Well T 31 1i Completed between r ` ~ .` °) i Egli 7 L 81008 and 811/09 I Vti a 7 L -7 Orion Production Web 1 a9 ` • Planned for Completion . ,.. ?' between 811100 and 12:31110 ' _ Orion Injection Well ♦ 5l2t)3i lei A. Completed Pre 811108 h ` .,, Orion Injection Well Completed between I za O - i l l 811;08 and 8/1/09 ' " "•+ ______ .•..o, ., -.... Orion Injection Well R ~ ' Planned for 811109 to Ill 12131/2010 °'' 26 Orion ParticipattngArea Boundary .. , Prudhoe Bay Unit Boundary MM. t "A C- P EI SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSIOIQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Robert Tirpack Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519 Re: Prudhoe Bay Field, Orion Schrader Bluff V -227i BP Exploration (Alaska), Inc. Permit No: 209 -116 Surface Location: 4900' FSL, 1532' FEL, SEC. 11, T11N, R11E, UM Bottomhole Location: 33' FSL, 1821' FEL, SEC. 36, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, 9 Daniel T. Seamount, Jr. VV Chair DATED this day of October, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA �'� ALASI�IL AND GAS CONSERVATION COMMI•N E P� V C ' r VG /C ® x,30 -' xt `�� PERMIT TO DRILL G 20 AAC 25.005 S E P 2 9 2009 1 a. Type of work: 1 b. Proposed Well Class: ❑ Development Oil ❑ Service - Winj ❑ Single Zone 1 c. Specify if well is proposed for: Drill ❑ Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone t ns � s kin ❑ Re -Entry ❑ Exploratory IN Service - WAG ❑ Service - Disp S 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Nana'9 er: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU V -227i 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 10307' TVD 5034' (ss) Prudhoe Bay Field / Orion 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Schrader Bluff Surface: ADL028240, ADL028238 4900' FSL, 1532' FEL, SEC. 11, T11 N, R11E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4354' FSL, 1783' FEL,SEC. 01, T11N, R11E, UM October 15, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 33' FSL, 1821' FEL, SEC. 36, T12N, R11E, UM 2560 10500' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: feet 15. Distance to Nearest Well Open Surface: x- 590767 y- 5970150 Zone- ASP4 GL Elevation above MSL: 53.53 feet to Same Pool: 815' 16. Deviated Wells: Kickoff Depth: 0 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 70 degrees Downhole: 2282 Surface: 1775 18. Casing Program: Specifications _ Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 129.45# X -65 WELD 176" Surface Surface 176' 176' —260 sx Arctic Set 12 - 1/4" 9 -5/8" 40# L -80 BTC 4880' Surface Surface 4880' 2843' 682 sx ASL. 407 sx Class 'G' 8 -3/4" 7" 26# L -80 TC -II 6380' Surface Surface 6380' 3368' See Below 8 -3/4" 7" 26# L -80 BTC -M 3927' 6380' 3368' 10307' 5117' 211 sx LiteCrete. 197 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor / Structural , Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: ❑ Property Plat ❑ BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Zach Sayers, 564-5790 Printed Name Robert Tirpack Title Engineering Team Leader �j / Prepared By Name/Number Signature x!97! / /1 Phone 564 -4166 Date 2/o7�'/�'j Sondra Stewman, 564 -4750 Commission Use Only Permit Number: Drill API Number: 50- 4.079.7S4‘1,10000 Permit Appr I See cover letter for `UU Il s e other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed m_ethh, gas hydrates, or gas contained shales: i� / Other: {, " p Sc 5 O P lesf Samples Req'd: ❑ Yes Lie No Mud Log Req'd: ❑ Yes lieNo p /4nI� (ct> �+-.1) H Measures: (Yes ❑ No Directional Survey Req'd: B"Yes ❑ No A- 2$ v psi GU 0per.4'eft. iK tccor.0 L..( AI0 26 A • M?a«... , -P pre' V p Q d,/le. rewLou4. geceptah / < /oAo` CZo AAo ZS. 4 33 ( ) L / /� 4 0,,,, APPROVED BY THE COMMISSION Ct►nei.� Lo� M6 ` o ' ` r p ate // COMMISSIONER Form 10-401 Revised 07/2089 'h is permit is valid for 24 months from the date of appcov 20 AAC 25.005(g)) Submit In Duplicate ORIGINAL //6. %a9 bp 1 0 V -227i Permit to Drill Application Well: V -227i W WAG Injector OTarget Schrader Type: l . e API Number TBD Estimated Spud Date: October 15 2009 Prepared By Zach Sayers Rig: Nabors 9ES BFE: ` 38.3' RTE: 66.8' Surface Northing Easting ; Offsets TRS Location 5,970,150 590,767 380' FNL / 1,533' FEL 11N, 11E, 11 Target Northing Easting TVDss Offsets TRS Locations 5,974,94 595,736 4,430' 4,358' FSL / 1,783' FEL 11N, 11E, 1 5,975,610 595,700 4,845' 5,019' FSL / 1,809' FEL 11N, 11E, 1 r Bottom Northing Easting TVDss Offsets TRS Location 5,975,904 I 595,684 5,034' 33' FSL / 1,821' FEL 12N, 11E, 36 Planned KOP: 400' MD / Planned TD: 10,307 MD / 318' TVDss 5,034' TVDss DIRECTIONAL - PLAN #5 Maximum Hole Angle: 70° in the 8 -3/4' section Close Approach Wells: Reference AC report in directional plan Survey Program: MWD Standard + IIFR / MS Nearest Property L 10,500' South of PBU Boundary Nearest Well within Pool: V - 213PB1 - 815' Contacts: Name: Phone: Email: Drilling Engineer Zach Sayers (907) 564 -5790 Zach.Sayers@bp.com Geologist Mikie Weeks (907) 564 -5635 Laryn.Smith@BP.com Production Engineer Mike Warren (907) 564 -4306 Mike.Warren a bp.com V -227i Permit To Drill Page 1 WELLS WITHIN 1 A MI OF THIS INJECTION WELL Casing am intervet Top Of TOO Met e d Uses to Determine TOC. Name. Tflp Schrader ; Schrader Ala miler "radius 8 - /a" Pilot 7,895' 6,918' Calculated top of lower plug -900' MD above base OBf with 30% excess. Upper plug laid in from 230' below top V -213 PB1 Hole MD MD Na sand, and tagged 950' MD above it. Notosv P &A'd with two plugs. Intersection is 797' from V -227i at the BaseOBf marker. Depth in V- 213PB1 is 9053' M.D. ( -4929' tvdss) 4 - Slotted 8,137' See V -207 Liner MD Notes... Notes - Distances to slotted liner laterals: V -207: 1,245'-, V- 207L1: 1,215' V- 207L2: 1,195' V- 207L3: 1,050', V- 207L4: 1,115'. Distance to cemented heel section is -4,400' Pilot Hole - See V -207 L4 Notes... PB2 Abandoned hole - 1,056' from V- 227wp05. Depth in V- 207L4PB2 is 12,607' M.D. (- w�` 4,422' tvdss). V -227i Permit To Drill Page 2 FORMATION MARKEOlt V -2271 (BASED ON SOR) • ( Est: Commercial Estirnat± d Formation Uncertainty Hydrocarbon Fcrmal T P ops B ear i Pressure ng feet G1 240' +/ -50' No 108 8.7 SV6 900' +/ -50' No 405 8.7 SV5 1,580' +/ -50' No 711 8.7 Base Permafrost _ 1,700' +/ -50' No 765 8.7 _ SV4 1,715' +/ -50' Gas hydrates 772 8.7 Fault 1 (V -Pad FaultL 1,820' +/- 100' M.D. n/a 0, 0.0 SV3 2,055' +/ -50' Gas hydrates 925 8.7 SV2 2,230' +/ -50' Gas hydrates 1,004 8.7 SV1 2,605' +/ -50' Gas hydrates 1,172 8.7 Surf Casing Pt 2,845' 0.0 UG4 2935' +/ -50' Thin Coal, 1,321 8.7 ' Heavy Oil ' UG4A 2,975' +/ -50' Heavy Oil 1,339 8.7 UG3 3,395' +/ -50' 1 Thin Coals; Heavy 1,528 8.7 Oil UG1 3,955' +/ -50' Heavy Oil 1,780 8.7 UG_Ma 4,165' +/- 30' No (wet) 1,874 8.7 UG_Mb1 4,200' +/- 30' No (wet) 1,890 8.7 UG_Mb2 4,270' +/- 30' No (wet) 1,922 ( 8.7 UGMc 4,340' +/- 30' No (wet) 1,953 8.7 SB__Na 4,410' +/- 30' No 1,985 8.7 SB_Nb 4,430' +/- 30' I Yes 1,475 -1,520 6.4 - 6.6 SB_Nc 4,465' +/- 30' 1 No 2,009 8.7 SB_Ne _ 4,475' _ +/- 30' No 2,014 8.7 SB_OA 4,570' +/- 30' No (wet) 2,060 -2,080 8.7 - 8.8 SB_OBa 4,640' +/- 30' _ Yes 1,550 -1,605 6.4 - 6.7 SB_OBb 4,685' _ +/- 30' Yes 1,720 -1,800 7.1 - 7.4 _ SB_OBc 4,745' +/- 30' No 2,115 8.7 SB_OBd 4,790' +/- 30' Yes — 1,905 -1,970 7.6 - 7.9 SB_OBe 4,845' +/- 30' Yes 2,050 -2,100 8.1 - 8.3 SB_OBf 4,900' +/- 30' Yes 2,205 8.7 1 Base _ SB_OBf 4,940' +/- 30' No 2,223 8.7 T.D. in Colville Shale 5,070' No 2,282 8.7 V -227i Permit To Drill Page 3 CASING/TUBING PR RAM Hole Gag 1, Burst Collapse Top `Bottom Wt�/ Ft ..Grade Conn. Length Size < Tbg�!� (psi) (Rs v . MD/YU ©rkb '..MG/'['i/Drkb 42" 20" 129.45# X -65 WELD 2 47 1,500 GL 176'/176' 9 2,473 ,500 176 12 -1/4" 9 -%" 40# L -80 BTC 5,750 3,090 4,880' GL 4,880' / 2,843' 8 -3/4" 7" 26# L -80 TC -II 7,240 5,410 6,380' GL 6,380' / 3,368' 8 - /a" 7" 26# L -80 BTC -M 7,240 5,410 3,927' 6,380' / 3,368' 10,307' / 5,117' Tubing 3 -'h" 9.2# L -80 TC -II 10,160 10,540 10,167' GL 10,167' / 5,042' MUD PROGRAM Surface Hole Mud Properties: DrilPlex (Freshwater Mud) 12 - 1 /4" Hole Section Depth Interval Density (ppg) PV YP API FL PH GL- 4,880' 8.5 — 9.2 ALAP 50 -80 NC 10.8 - 11 Production Hole Mud Properties: LSND Fluid (Freshwater Mud) 8 - Hole Section Depth Interval Density (ppg) PV YP API FL PH MST . Csg Shoe - TD 8.6 - 9.1 8 - 14 18 - 24 <6.0 9 - 10 <15 LOGGING PROGRAM 12 -1/4" Surface: 9 -%" Casing Dr Dir /GR SURF — 9 -%" Shoe Open Hole: , None Cased Holler None 8 - 3 A" Production : 7" Casing Drilling: Dir /GR/Res /Neu/ l g %" Shoe — TD Az Den Open Hole: None Cased Hole: Hole: USIT V - 227i Permit To Drill Page 4 CEMENT PROGRAM 1110 • 9 -%" Surface Casing Section in 'S1ze 9 - %" 40 #, L-80 BTC Lead: Open hole volume with 250% excess in permafrost, and 40% excess below permafrost Port collar used if necessary Basics: Lead TOC: Surface Tail: Open hole volume with 40% excess, and 80' shoe track Tail TOC: 1,000' above 9-%" shoe Spacer 50 bbls of Viscous Spacer weighted to 10.0 ppg (Mud Push 11) Total Cement., Lead 548 bbls, 3,077 ft 682 sks, 4.51 ft /sk, 10.7 lb/gal ASL Voi me =` Tail 84 bbls, 474 ft 409 sks, 1.16 ft /sk, 15.8 lb/gal Class G Temp BHST = 50° F 7" Production Casing Section Casing'Sixe f 7" 26 #, L -80 BTC -M x TC -II Lead: Open hole volume with 30% excess Basics; Lead TOC: 1,000' MD below Surface Casing Shoe Tail: Open hole volume with 40% excess, and 80' shoe track Tail TOC: >500' above the Top of the Kuparuk Spacer 50 bbls of Viscous Spacer weighted to 10.0 lb/gal (Mud Push 11) -.Tatat cements::' Lead 119 bbls, 670 ft3, 228 sks, 2.94 ft 11.5 lb/gal LiteCrete + adds Vtaiume Tail 41 bbls, 228 ft3, 195 sks, 1.17 ft /sk, 15.8 lb/gal Class G + Latex Temp BHST = 97° F SURFACE SHUT -IN WELLS At surface V -120 to the West and V -207 to the East are required to be shut before Nabors 9ES rig can be moved on to the well. Wellhead V -120 is 15' from center to the West and wellhead V -207is 15' from center away to the East from V -227i. The well houses will need to be removed. HYDROGEN SULFIDE Recent H data from the pad is as follows: Well Name HS Level (ppm) Date of Reading #1 Closest SHL Well H Level V -207 0 4/4/2009 #2 Closest SHL Well H Level V -03 30 12/19/2008 #1 Closest BHL Well H Level V -103 38 5/15/2008 #2 Closest BHL Well H2S Level V -207 0 4/4/2009 Max. Recorded H on Pad/Facility V -117 300 4/3/2007 Other Relevant H Data V -117 last reading 150 ppm 1/25/09. (H alarms from rigs, etc.) V -227i Permit To Drill Page 5 WELL CONTROL � The 12 -/a „ surface hole will be drilled with a 16” diverter. The 8 -3/4 intermediate hole will use well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind /shear rams, and an annular preventer will be installed and is capable of handling the maximum potential surface pressures. Annular preven will be tested to 2,500 psi. Based upon calculations below, BOP equipment will be tested to 4,000 psi. BOP regular test frequency for V -227 will be 14 days with a function test every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. 8- Production Interval Maximum Anticipated BHP 2,282 psi c, 5,070' TVD, 8.7 ppg EMW I climunl Surface pressure 1,775 psi (.10 psi /ft gas gradient to surface) (SB_OBf) Kick Tolerance! Infinite with a 12.0 ppg FIT /LOT Planned BOp Ted Pressure R ams test to 4,000 psi /250 psi. Annular test to 2,500 psi /250 psi 9- %'. Casing Test 3,500 psi surface pressure Integrity Test - $la - ".Hole LOT after drilling 20' — 50' of new hole PlannedC plet in:Rinds 9.0 p pg Seawater / 6.8 ppg Diesel VARIANCE REQUESTS; To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, i t i s requested to drill without a flow paddle for the first portion of the surface hole to a depth of 1,000' MD. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. DISPOSAL: • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -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 DS -04 for injection. Haul all Class I waste to Pad 3 for disposal. V -227i Permit To Drill Page 6 Drillincf • Hazards and Continciicies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this fault block is expected to be normally pressured from 6.4 to 8.8 ppg EMW. II. Lost Circulation/Breathing A. Risks of lost circulation for the proposed S - 134i Aurora well are low. III. Kick Tolerance/Integrity Testing 8 - Production Interval iA dteuntAriticipatec#.BHP 2,282 psi @ 5,070' TVD, 8.7 ppg EMW f21111a ctririuntStildice.:Prossure 1,775 psi (.10 psi /ft gas gradient to surface) (SB_OBf) KtckTalerance.. ... Infinite with a 12.0 ppg FIT /LOT Punned 13OP Test Pressure Rams test to 4,000 psi /250 psi. : ., Annular test to 2,500 psi /250 psi G trr t 3,500 psi surface pressure Integrity' est a — 'Hole LOT after drilling 20' – 50' of new hole l fiaitiriecl :C:'p rpietiorifVui fs 9.0 ppg Seawater / 6.8 ppg Diesel IV. Stuck Pipe A. Stuck pipe has not been an issue on past wells drilled from this pad. VI. Hydrogen Sulfide Recent H data from the pad is as follows: Well Name H Level (ppm) Date of Reading #1 Closest SHL Well H Level V -207 0 4/4/2009 #2 Closest SHL Well H Level V -03 30 12/19/2008 #1 Closest BHL Well H Level V -103 38 5/15/2008 #2 Closest BHL Well H Level V -207 0 4/4/2009 Max. Recorded H on Pad/Facility V -117 300 4/3/2007 Other Relevant H Data V -117 last reading 150 ppm 1/25/09. (H alarms from rigs, etc.) VII. Faults Fortnatton Where< MD:::. MOSS , Est. Vertical aufit . Throw Dtrecttctrl cer nt5► .` ., . Enceunter f atilt . lritersect Intersect Offset Dips to the #1 SV4 i 2,227' 1,820' 80' - 110' South-West + /- 100'MD Comments: Penetrated by nearly all wells drilled from V Pad with no losses VIII. Anti - Collision Issues A. Reference Anti - collision report in directional plan CONSULT THE V -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V -227i Permit To Drill Page 7 V -227i - Drill and Complete Procedure Summar p Y Pre -Riq Work: 1. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Remove nearby well houses. Riq Operations: 1. MIRU Nabors 9ES. (Plan to SPUD with DrilPlex) 2. Nipple up and function test diverter. 3. MU 12 -1/4" drilling assembly with MWD /GR and directionally drill surface hole to TD. The surface hole TD will be approximately 700' MD below the top of the SV1. 4. Run and cement 9-%", 40 #, BTC, L -80 surface casing. A TAM port collar may be run at 1,000' as a contingency. Pressure test casing to 3,500 psi for 30 minutes at plug bump. 5. ND diverter and NU casing / tubing head. NU BOPE and test to 4,000psi. 6. Make up 8 -3/4" drilling BHA with MWD /GR/RES /Azi- Den /NEU /PWD and RIH to float collar. Drill out shoe track and displace well to LSND drilling fluid. Drill 20' of new formation and perform LOT. 7. Drill ahead to production hole target TD. Circulate one BU, back -ream out of hole until the ghost reamer is inside the surface shoe, then POOH to run casing. 8. Run and cement the 7" production casing. Displace with 9.0 ppg seawater. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. 9. Install and test 9 -%" x 7" pack -off. 10. Freeze protect the 9 -%" x 7 "annulus. 11. Space out perf guns by utilizing GR and LWD log. PU DPC guns and RIH w/ -225' of 4 -Y2" Power Jet 4505 5 spf, pert guns with Anadrill LWD GR for gun correlation. 12. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate Nb, OBa, OBb, OBd, and OBe. POOH. LD DP and guns. 13. RU Schlumberger E -line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. 14. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 15. Run the 3 -'/2 ", 9.2# completion with a 7" x 3 -'/2" straddle packer assembly, I -wire, gauges, and injection mandrels. Torque Turn TC -II threaded tubing. Space out packers using E -line and USIT. 16. Run in lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing /tubing annulus and tubing to 4,000 psi each. 17. Shear the DCR valve and pump both ways to confirm circulation ability. 18. Install and test TWC. Nipple down the BOPE. Nipple up and test double master valves to 5,000 psi. 19. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u- tube into tubing. 20. Install BPV in tubing hanger. Install all annulus valves and secure the well. Ensure that IA/OA are protected with two barriers. 21. RDMO. Post -Riq Work: 1. Install tree with electric SSV actuator. 2. MIRU slick -line. Pull the ball and rod / RHC plug. 3. Pull shear valve from top mandrel and replace with a dummy GLV. 4. Pull dummy valves from injection mandrels and replace with injection valves. 5. Pull VR plug. 6. Install well house and flow lines. V -227i Permit To Drill Page 8 TREE = 4- 1/16" CM! SAFETY NOTES: *** HES PKR @ 6341' IS "PULL TO ^— WELLHEAD = F • P ro p � e d V 2 2 7 i RELEASE" BUT CAN BE RELEASED BY PRESSURE DO ACTUATOR = Electric N�OEED 4,300 PSI. TEST PRESSURE PKR RATING KB. ELEV 78.6' = 541�'PSI (4332 PSI IS 80% OF PKR RATING)*** BF. ELEV = 48.1' KOP= 400' 120" CONDUCTOR H 108' I - 1 ` J 1j 27' H4-1/2" X 3-1/2" XO, ID= 2.992 "1 Max Angle = 69.49* @ 4,880 ' Datum MD = 1 r - 1 2,500' H3-1/2" HES X NIP, ID = 2.813" 1 DatumTVD - - - 1 4,880' H9-5/8" CSG, 40 #, L -80 BTC, ID = 8.835" 1 GAS LIFT MANDRELS H STI MD T I DEV I TYPE I VLV I LATCH' PORT) DATE 17" CSG, 26 #, L -80 TCII XO TO L -80 BTC-M 6 380' �c 10 MMG WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 MMG-W 8 MMG-W Minimum ID = 2.75" @ 6965' = 7 MMG -W 3 -1/2" HES XN NIPPLE 5 MMG -W 4 MMG -W 3 MMG -W 2 MMG -W 17" X 3 -1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" H 9,312' 1 1 ** MMG -W I3 -1/2" RA PIP TAG H 9,320' 1 111 F ** INSIDE NIPPLE 17' MARKERJOINTw /RA PIP TAG H 9,325' ( * 1 1 - I 9,400' 1 - 1/2" HESX NIP, 1D= 2.813" 1 9,671' 7" X 3 -1/2" SINGLE FEEDTHRU PKR, ID = 2.965" IF 9,682' 3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 �1 1 1-- -1 9,692' H3-1/2" HES X NIP, ID = 2.813" 1 Mr U ►� 1 9,749' H7" X 3 -1/2" SINGLE FEEDTHRU PKR, ID= 2.965" 1 1 9,764' -13 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 1 1 9,768' 3 -1/2" HES X NP, ID = 2.813" 1 IMP [I PERFORATION SUMMARY K1 9,904' — 7" X 3 -1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 9,919' — 3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 Ir SIZE SPF ZONE INTERVAL Opn /Sqz DATE 1 1 1 9,931' H3-1/2" HES X NIP, ID = 2.813" 1 4 -1/2" 5 Nb 4 -1/2" 5 OBa g g 1 10,024' H7" X 3 -1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 1 4 -1/2" 5 OBb -. ( 10,040' H3-1/2" NDPG MULTI - SENSOR SUB , 1D = 2.992 1 4 -1/2" 5 OBd 1 1 10,065' 3 -1/2" HES X NIP, ID = 2.813" 4 -1/2" 5 (Noe �I� I 1 ' ( 10,125' H3-1/2" HES X NIP, ID = 2.813" 1 1 1— 10,146' H3-1/2" HES XN NIP, ID = 2.750" 1 13 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2. 992" H 10,167' f--- -___ 1 10,167'1 WLEG, ID = 2.992" 1 PBTD H 10,302' I , • 4 • � �� • � • � • 4 • � • 17" CSG, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" I — I 10,307' � 1 *1 * *1 * *1 * *1 * * 1 DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 05/19/09 ZJS PROPOSED COM PLETION WELL: V -227i PERMIT No: API No: 50-029 - SEC 11, T11 N, R11 E, 4,900' FSL & 1,533' FEL Zach Sayers BP Exploration (Alaska) bp 0 V -227 P5 Proposal Scblumberger 1 � ) p Report Date: May 19, 2009 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client BP Exploration Alaska Vertical Section Azimuth: 41.210° Field: Prudhoe Bay Unit - WOA �� Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1: V-Pad - Plan V Slot (N -Y) e � 5 b; f TVD Reference Elevation: Well 82.50 ft relative to MSL Well: Plan V -227 (NY) Borehole: Plan V -227 S ea Bed 1 Ground Level Elevation: 54.00 ft relative to MSL UWVAPI#: 50029 Magnetic Declination: 22.217° Survey Name / Date: V -227 (P5) / May 19, 2009 Total Field Strength: 57709.408 nT Tort 1 AHD 1 DDI 1 ERD ratio: 134.815° / 8213.73 ft / 6.348 / 1.605 Magnetic Dip: 80.875° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 05, 2009 Location Let/Long: N 70.32817855, W 149.26386454 Magnetic Declination Model: BGGM 2008 Location Grid N/E Y/X: N 5970150.000 ftUS, E 590767.000 ftUS North Reference: True North Grid Convergence Angle: +0.69317614° Total Corr Mag North -> True North: +22.217° Grid Scale Factor: 0.99990936 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS EW Mag 1 G Directional Comments Inclination Sub-Sea TVD TVD Gray DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ( ft ► de ) (deg) (ft) (ft) (ft) (ft ) (ft ) ) j q) (deg/100ft ) Index (ftUS) (ftUS) RTE 0.00 0.00 45.00 -82.50 0.00 0.00 0.00 0.00 - 0.00 0.00 5970150.00 590767.00 N 70.32817855 W 149.26386454 WRP 28.50 0.00 45.00 -54.00 28.50 0.00 0.00 0.00 - -- 0.00 0.00 5970150.00 590767.00 N 70.32817855 W 149.26386454 G1 322.50 0.00 45.00 240.00 322.50 0.00 0.00 0.00 - -- 0.00 0.00 5970150.00 590767.00 N 70.32817855 W 149.26386454 KOP Bld 1.5/100 400.00 0.00 45.00 317.50 400.00 0.00 0.00 0.00 45.00M 0.00 0.00 5970150.00 590767.00 N 70.32817855 W 149.26386454 Bld 2.25/100 500.00 1.50 45.00 417.49 499.99 1.31 0.93 0.93 45.00M 1.50 0.29 5970150.94 590767.91 N 70.32818107 W 149.26385704 600.00 3.75 45.00 517.38 599.88 5.88 4.16 4.16 45.00M 2.25 1.34 5970154.21 590771.11 N 70.32818992 W 149.26383078 700.00 6.00 45.00 617.01 699.51 14.35 10.17 10.17 HS 2.25 1.94 5970160.29 590777.05 N 70.32820634 W 149.26378205 800.00 8.25 45.00 716.23 798.73 26.73 18.94 18.94 HS 2.25 2.35 5970169.17 590785.71 N 70.32823030 W 149.26371094 900.00 10.50 45.00 814.89 897.39 42.98 30.46 30.46 HS 2.25 2.66 5970180.82 590797.09 N 70.32826176 W 149.26361754 SV6 981.73 12.34 45.00 895.00 977.50 59.13 41.90 41.90 HS 2.25 2.87 5970192.40 590808.39 N 70.32829302 W 149.26352475 Cry 4.5/100 988.89 12.50 45.00 901.99 984.49 60.67 42.99 42.99 HS 2.25 2.88 5970193.50 590809.46 N 70.32829599 W 149. 1592 1000.00 13.00 45.00 912.83 995.33 63.11 44.72 44.72 HS 4.50 2.92 5970195.26 590811.18 N 70.32830073 W 149. 186 1100.00 17.50 45.00 1009.28 1091.78 89.35 63.32 63.32 HS 4.50 3.20 5970214.07 590829.54 N 70.32835153 W 149.26335108 1200.00 22.00 45.00 1103.37 1185.87 123.06 87.21 87.21 HS 4.50 3.44 5970238.25 590853.14 N 70.32841679 W 149.26315736 1300.00 26.50 45.00 1194.53 1277.03 164.03 116.24 116.24 HS 4.50 3.65 5970267.63 590881.82 N 70.32849611 W 149.26292190 1400.00 31.00 45.00 1282.18 1364.68 212.01 150.24 150.24 HS 4.50 3.83 5970302.04 590915.40 N 70.32858900 W 149.26264616 1500.00 35.50 45.00 1365.78 1448.28 266.71 189.00 189.00 HS 4.50 3.99 5970341.26 590953.69 N 70.32869488 W 149.26233184 1600.00 40.00 45.00 1444.83 1527.33 327.78 232.28 232.28 HS 4.50 4.14 5970385.05 590996.44 N 70.32881312 W 149.26198086 1626.56 41.20 45.00 1465.00 1547.50 345.03 244.51 244.51 HS 4.50 4.18 5970397.42 591008.51 N 70.32884650 W 149.26188174 1700.00 44.50 45.00 1518.83 1601.33 394.85 279.81 279.81 HS 4.50 4.27 5970433.15 591043.38 N 70.32894296 W 149.26159539 SV5 1773.88 47.82 45.00 1570.00 1652.50 448.02 317.49 317.49 HS 4.50 4.36 5970471.28 591080.60 N 70.32904589 W 149.26128983 1800.00 49.00 45.00 1587.34 1669.84 467.51 331.31 331.31 HS 4.50 4.39 5970485.26 591094.24 N 70.32908362 W 149.26117782 WellDesign Ver SP 2.1 Bid( users) Plan V Slot (N -Y) \Plan V -227 (NY)1PIan V- 227 \V -227 (P5) Generated 5/19/2009 8:47 AM Page 1 of 3 • I Measured Azimuth Vertical NS EW Ma 1 Grav Directional Comments Inclination Sub -Sea TVD TV D g DLS Northing Easting Latitude Longitude l F Depth True Section True North True North Tool Difficulty I (ft) (deg) (deg) l (ft) (ft) (ft) (ft) (ft) (deg) (deg11O0ft) Index (ftUS) (ftUS) 1900.00 53.50 45.00 1649.91 1732.41 545.31 386.44 386.44 HS 4.50 4.51 5970541.05 591148.70 N 70.32923423 W 149.26073070 End Cry 1988.43 57.48 45.00 1700.00 1782.50 618.00 437.95 437.95 - -- 4.50 4.60 5970593.18 591199.58 N 70.32937496 W 149.26031292 SV4 1997.73 57.48 45.00 1705.00 1787.50 625.83 443.50 443.50 - -- 0.00 4.61 5970598.79 591205.06 N 70.32939010 W 149.26026795 Base Perm 2025.63 57.48 45.00 1720.00 1802.50 649.30 460.13 460.13 - -- 0.00 4.62 5970615.62 591221.49 N 70.32943555 W 149.26013303 Cry 4.5/100 2062.83 57.48 45.00 1740.00 1822.50 680.60 482.31 482.31 41.41R 0.00 4.65 5970638.07 591243.40 N 70.32949614 W 149.25995314 2100.00 58.74 46.29 1759.64 1842.14 712.06 504.37 504.88 40.73R 4.50 4.68 5970660.40 591265.69 N 70.32955640 W 149.25977012 2200.00 62.19 49.61 1808.93 1891.43 798.43 562.59 569.50 39.09R 4.50 4.77 5970719.39 591329.60 N 70.32971544 W 149.25924606 2300.00 65.72 52.72 1852.84 1935.34 886.89 618.88 639.49 37.73R 4.50 4.86 5970776.51 591398.89 N 70.32986920 W 149.25867843 2400.00 69.31 55.67 1891.09 1973.59 976.89 672.89 714.41 36.60R 4.50 4.94 5970831.43 591473.16 N 70.33001674 W 149.25807072 End Cry 2405.02 69.49 55.81 1892.85 1975.35 981.44 675.54 718.30 - -- 4.50 4.94 5970834.12 591477.01 N 70.33002397 W 149.25803922 Fault 2824.96 69.49 55.81 2040.00 2122.50 1362.06 896.57 1043.64 - -- 0.00 5.13 5971059.04 591799.62 N 70.33062769 W 149.49 SV2 3224.51 69.49 55.81 2180.00 2262.50 1724.19 1106.86 1353.18 - -- 0.00 5.26 5971273.04 592106.57 N 70.33120206 W 149. 77 SV1 4209.11 69.49 55.81 2525.00 2607.50 2616.59 1625.08 2115.97 - -- 0.00 5.50 5971800.41 592862.97 N 70.33261730 W 149 .24 02 04 9 -5/8" Csg 4879.78 69.49 55.81 2760.00 2842.50 3224.46 1978.07 2635.56 - -- 0.00 5.62 5972159.62 593378.19 N 70.33358119 W 149.24248672 UG4 5108.09 69.49 55.81 2840.00 2922.50 3431.40 2098.24 2812.44 - -- 0.00 5.65 5972281.91 593553.59 N 70.33390930 W 149.24105162 UG4A 5236.51 69.49 55.81 2885.00 2967.50 3547.80 2165.83 2911.94 -- 0.00 5.67 5972350.70 593652.25 N 70.33409386 W 149.24024436 UG3 6335.27 69.49 55.81 3270.00 3352.50 4543.67 2744.13 3763.17 - -- 0.00 5.81 5972939.20 594496.35 N 70.33567269 W 149.23333721 Cry 5/100 7388.78 69.49 55.81 3639.15 3721.65 5498.53 3298.62 4579.36 108.63L 0.00 5.91 5973503.47 595305.69 N 70.33718627 W 149.22671347 7400.00 69.33 55.30 3643.09 3725.59 5508.70 3304.56 4588.02 108.45L 4.50 5.92 5973509.52 595314.28 N 70.33720249 W 149.22664317 7500.00 67.97 50.69 3679.52 3762.02 5599.84 3360.59 4662.38 106.77L 4.50 5.95 5973566.43 595387.95 N 70.33735541 W 149.22603963 7600.00 66.73 46.00 3718.05 3800.55 5691.37 3421.89 4731.32 104.96L 4.50 5.98 5973628.55 595456.14 N 70.33752275 W 149.22548001 7700.00 65.65 41.23 3758.44 3840.94 5782.75 3488.08 4794.41 103.04L 4.50 6.01 5973695.50 595518.42 N 70.33770349 W 149.22496777 7800.00 64.71 36.38 3800.44 3882.94 5873.39 3558.77 4851.28 101.00L 4.50 6.04 5973766.87 595574.42 N 70.33789651 W 149.22450607 7900.00 63.93 31.46 3843.80 3926.30 5962.75 3633.52 4901.56 98.87L 4.50 6.07 5973842.21 595623.79 N 70.33810062 W 149.22409774 UG1 7914.09 63.83 30.76 3850.00 3932.50 5975.20 3644.35 4908.09 98.56L 4.50 6.08 5973853.12 595630.20 N 70.33813019 W 149.22404467 8000.00 63.32 26.48 3888.24 3970.74 6050.26 3711.86 4944.95 96,66L 4.50 6.10 5973921.06 595666.22 N 70.33831456 W 149.22374532 8100.00 62.89 21.46 3933.50 4016.00 6135.41 3793.31 4981.17 94.38L 4.50 6.12 5974002.94 595701.46 N 70.33853701 W 149.22345097 8200.00 62.64 16.41 3979.29 4061.79 6217.65 3877.37 5010.01 92.07L 4.50 6.15 5974087.33 595729.28 N 70.33876661 W 149.22321651 8300.00 62.57 11.34 4025.33 4107.83 6296.48 3963.52 5031.29 89.73L 4.50 6.17 5974173.73 595749.51 N 70.33900192 W 149.340 8400.00 62.68 6.27 4071.34 4153.84 6371.42 4051.23 5044.88 87.40L 4.50 6.20 5974261.59 595762.04 N 70.33924152 W 149. 268 8500.00 62.97 1.23 4117.04 4199.54 6441.99 4139.97 5050.69 85.10L 4.50 6.22 5974350.38 595766.77 N 70.33948391 W 149.22288506 Drp 0.5/100 8572.92 63.30 357.57 4150.00 4232.50 6490.47 4205.00 5050.00 HS 4.50 6.24 5974415.39 595765.30 N 70.33966158 W 149.22289030 Ma 8572.95 63.30 357.57 4150.01 4232.51 6490.48 4205.02 5050.00 180.00L 0.50 6.24 5974415.41 595765.29 N 70.33966164 W 149.22289031 8600.00 63.17 357.56 4162.19 4244.69 6507.96 4229.15 5048.97 180.00L 0.50 6.24 5974439.53 595763.98 N 70.33972757 W 149.22289850 Mbl 8672.22 62.81 357.56 4195.00 4277.50 6554.52 4293.44 5046.24 180.00L 0.50 6.24 5974503.77 595760.47 N 70.33990319 W 149.22292033 8700.00 62.67 357.56 4207.72 4290.22 6572.39 4318.11 5045.19 180.00L 0.50 6.24 5974528.42 595759.12 N 70.33997059 W 149.22292871 8800.00 62.17 357.56 4254.03 4336.53 6636.53 4406.66 5041.42 180.00L 0.50 6.25 5974616.91 595754.28 N 70.34021252 W 149.22295878 Mb2 8844.76 61.95 357.56 4275.00 4357.50 6665.14 4446.16 5039.74 180.00L 0.50 6.26 5974656.39 595752.12 N 70.34032044 W 149.22297220 8900.00 61.67 357.56 4301.10 4383.60 6700.37 4494.81 5037.68 180.00L 0.50 6.26 5974705.00 595749.47 N 70.34045334 W 149.22298872 Mc 8971.03 61.32 357.56 4335.00 4417.50 6745.54 4557.17 5035.02 180.00L 0.50 6.27 5974767.32 595746.06 N 70.34062371 W 149.22300990 WellDesign Ver SP 2.1 Bld( users) Plan V Slot (N -Y) \Plan V -227 (NY) \Plan V- 227 \V -227 (P5) Generated 5/19/2009 8:47 AM Page 2 of 3 Measured Azimuth Vertical NS EW Mag l Gray Directional Comments Inclination Sub-Sea ND ND DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) l (deg) I (deg) (ft) I (ft) I (ft) (ft) (ft ) (deg) I (deg1100ft ) I Index IftUS) (ftUS) - 9000.00 61.17 357.56 4348.94 4431.44 6763.92 4582.54 5033.94 180.00L 0.50 6.27 5974792.68 595744.68 N 70.34069303 W 149.22301851 9100.00 60.67 357.56 4397.54 4480.04 6827.16 4669.86 5030.23 180.00L 0.50 6.27 5974879.94 595739.91 N 70.34093158 W 149.22304817 Nb 9176.02 60.29 357.56 4434.99 4517.49 6875.03 4735.96 5027.42 HS 0.50 6.28 5974945.99 595736.30 N 70.34111215 W 149.22307061 V -227 Tgt Nb 9176.04 60.29 357.56 4435.00 4517.50 6875.04 4735.97 5027.42 180.00L 0.50 6.28 5974946.00 595736.30 N 70.34111219 W 149.22307062 9200.00 60.17 357.56* 4446.89 4529.39 6890.09 4756.75 5026.54 180.00L 0.50 6.28 5974966.77 595735.16 N 70.34116896 W 149.22307768 Nc 9236.30 59.99 357.56 4465.00 4547.50 6912.86 4788.19 5025.20 180.00L 0.50 6.28 5974998.18 595733.44 N 70.34125485 W 149.22308836 Ne 9256.27 59.89 357.56 4475.00 4557.50 6925.37 4805.46 5024.46 180.00L 0.50 6.28 5975015.44 595732.50 N 70.34130202 W 149.22309422 9300.00 59.68 357.56 4497.01 4579.51 6952.71 4843.21 5022.86 180.00L 0.50 6.29 5975053.17 595730.44 N 70.34140517 W 149.22310704 9400.00 59.18 357.56 4547.87 4630.37 7015.01 4929.23 5019.20 180.00L 0.50 6.29 5975139.13 595725.74 N 70.34164017 W 149.22313626 OA 9443.05 58.96 357.56 4570.00 4652.50 7041.74 4966.13 5017.63 180.00L 0.50 6.30 5975176.00 595723.73 N 70.34174097 W 149.22314879 9500.00 58.68 357.56 4599.48 4681.98 7076.99 5014.81 5015.56 180.00L 0.50 6.30 5975224.65 595721.07 N 70.34187396 W 149.2 533 OBa 9577.51 58.29 357.56 4640.00 4722.50 7124.81 5080.83 5012.75 180.00L 0.50 6.31 5975290.62 595717.46 N 70.34205433 W 149. 75 9600.00 58.18 357.56 4651.84 4734.34 7138.65 5099.93 5011.94 180.00L 0.50 6.31 5975309.71 595716.42 N 70.34210651 W 149.22 9424 OBb 9662.63 57.87 357.56 4685.00 4767.50 7177.09 5153.00 5009.68 180.00L 0.50 6.31 5975362.75 595713.52 N 70.34225151 W 149.22321227 9700.00 57.68 357.56 4704.93 4787.43 7199.97 5184.59 5008.34 180.00L 0.50 6.31 5975394.32 595711.79 N 70.34233781 W 149.22322300 OBc 9774.57 57.31 357.56 4745.00 4827.50 7245.47 5247.42 5005.67 180.00L 0.50 6.32 5975457.11 595708.36 N 70.34250947 W 149.22324435 9800.00 57.18 357.56 4758.76 4841.26 7260.95 5268.79 5004.76 180.00L 0.50 6.32 5975478.46 595707.19 N 70.34256785 W 149.22325161 OBd 9857.42 56.90 357.56 4790.00 4872.50 7295.82 5316.93 5002.71 180.00L 0.50 6.32 5975526.57 595704.56 N 70.34269936 W 149.22326796 9900.00 56.69 357.56 4813.32 4895.82 7321.59 5352.52 5001.20 180.00L 0.50 6.32 5975562.13 595702.62 N 70.34279659 W 149.22328005 OBe 9957.45 56.40 357.56 4844.99 4927.49 7356.28 5400.41 4999.16 HS 0.50 6,33 5975609.98 595700.00 N 70.34292741 W 149.22329632 V -227 Tgt OBe 9957.46 56.40 357.56 4845.00 4927.50 7356.29 5400.42 4999.16 HS 0.50 6.33 5975610.00 595700.00 N 70.34292745 W 149.22329633 10000.00 56.61 357.56 4868.47 4950.97 7381.95 5435.86 4997.65 HS 0.50 6.33 5975645.41 595698.07 N 70.34302427 W 149.22330837 OBf 10057.51 56.90 357.56 4900.00 4982.50 7416.76 5483.91 4995.61 HS 0.50 6.33 5975693.43 595695.44 N 70.34315555 W 149.22332469 10100.00 57.11 357.56 4923.14 5005.64 7442.55 5519.52 4994.09 HS 0.50 6.34 5975729.02 595693.50 N 70.34325283 W 149.22333679 OBf Base 10131.11 57.27 357.56 4940.00 5022.50 7461.47 5545.65 4992.98 HS 0.50 6.34 5975755.13 595692.07 N 70.34332421 W 149.22334567 10200.00 57.61 357.56 4977.07 5059.57 7503.48 5603.65 4990.52 HS 0.50 6.34 5975813.09 595688.90 N 70.34348268 W 149.22336537 10300.00 58.11 357.56 5030.27 5112.77 7564.76 5688.25 4986.92 HS 0.50 6.35 5975897.63 595684.28 N 70.34371380 W 149.22339412 TD / 7" Lnr 10307.46 58.15 357.56 5034.21 5116.71 7569.34 5694.58 4986.65 - -- 0.50 6.35 5975903.96 595683.94 N 70.34373111 W 149.22339627 Legal Description: Northing (Y) (ftUSI Eastinq (X) fftUSI • Surface : 4900 FSL 1533 FEL S11 T11N R11E UM 5970150.00 590767.00 V -227 Tgt Nb : 4358 FSL 1783 FEL S1 T11N R11E UM 5974946.00 595736.30 V -227 Tgt OBe : 5019 FSL 1809 FEL S1 T11N R11E UM 5975610.00 595700.00 BHL : 33 FSL 1821 FEL S36 T12N R11E UM 5975903.96 595683.94 WellDesign Ver SP 2.1 Bld( users) Plan V Slot (N -Y) \Plan V -227 (NY) \Plan V- 227 \V -227 (P5) Generated 5/19/2009 8:47 AM Page 3 of 3 by Schlumberger WELL FIELD STRUCTURE V -227 (P5) I Prudhoe Bay Unit - WOA V -Pad Magnetic Parameters Surface Location NAD27 Alaska State Planes. Zone 04, US Feet Miscellaneous Model: BGGM 2008 Dip: 80.875° Date'. November 05. 2009 Lat N70 19 41 443 No0irg: 5970150008US Grid Conv'. +069317614 5kit. Flan V Sld IN -C) TVD Ret: Rotary 7406 (8250 ft above MSL) Meg Dec: •22.217 FS: 577094 nT Lon: W149 15 49 912 Eastkg: 59076700 ftUS Scale Fad'. 0.9999093589 Plan: V- 227 Srvy Dale: May 19. 2009 0 1000 2000 3000 4000 5000 6000 7000 8000 0 RTE 0 KOP Bld 1.5/100 Bld 2.25/100 • Cry 4.5/100 1000 T :'.T.'!.T .".T.•.• - - T I.T.V.T!! T!!.T! T! :Tl!.T::.Th:T! :T! :T C•. T!hT!MN.T::T.V.T!t.Tl.Nt!Jf¢J.T :•.T.::T! LTN.T :: Tl .•.T::T::.�!!.T!!.TN.T:!.T.•AT :•.T ::T.•.:T!!A.•!.Tt:.T.•.•Jf ::T!AT :•.T::T::T :fT!: 7•AT :•.T:! T!:.T! :T! :T!:.T!I.T.V.T!!.T!.•.T!! tL•.T!!.T.•.:T!.•.T 1000 End Cn. •..•......r.T..-4.ulka..e.. lot I slkla• llelkilka• kk�llskkwrlkk seekekkekk�kk.kk. kk�krgrokkskkskk�Lkmlk�kL�kLskk Akk�kr. kke•k l.kk. al•kk. kk.kkike•kkskkokkakk�kkekknkr�k Pkk�kkwrkwrr.kr.kk .sklska�r �kk �kk�rk�ll �kr�kr�rk�kk� er nl l � End Cry 2000 Fault > 2000 • 3000 -.._.. z..z. ».._.._.._.._.._.._.._.._. _.._.._.._.._.._.._.._.._ ._..- .. :.._.._.._.._.._. ; : ::::. t ..- _::::: 5::::: z:: z::::: z:: z::::: z:: Z::_.._.._.._.._.._.. _.._. ».._.._.._.._.._.._.. -.. -. - •._•• ••_••_••_.._.._.._ 3000 D _.._.._ _.. -.._.. _..- ..- .._.._.._. - ..- ..- .._..- ..- ..- .. -.._ .-. ._.._.._.._.._.._.._.._.._.._.. _.._.._..- ..- ..- ..f..- .._.._.._ B. .. -.._ . *. _.._.._.._•• Cry 51100 ..- ..- ..- .._..- .._..- .. -.. -. - ..- .._.._.._.._.._.._.._ • 4000 -.._..-. ._......- .._.._.._.._.._.._.._. _.._.._.._.._.._.._.._.._ ._.._.._.._.._.._.._..-..-..-.._.._.._.._.._.. _.._..T.._.._.._.._.._.._.._.._ - .._.._.._..- .. -.. -.. 9-.. .._.._.._ . ._.�.�.._.._.._.._.._.._.._.._ 4000 � - ..- .._.. -..�.. ..- .._.._..- .._.._.._ .-.._.._.._.._.. _.._.._.= .._.._.._..- ..- .. -.. -. -.._.._.._.._..-.._.._ ...._..- ..- .._..- .._.._.. - ..i.. .._.._.._.._.._.._..- ._.._.._.._.._.._.._.._.. e _ ._.._....22JJ1 . -. -..�.. -.!_ - - - - - - _ - - - -. -.. �..�..�:. - - - - - - - ..*.._ - _. -. - - - - -• yr• - - -. -. - v.TN.T':T:!.T!!.T!!.T! N1N!.T!!.f.•.•.T!ciai!JT!: !! . Tt!.T!!RX.Tiaimf:T:.•. 5000 •: J!! ! .T! ! J N! .T: Af N.T t: J f: !.T.• • .f 5000 ...-..-.. _;•�.._.._.._.._.._.._.._.._. ;_ .- ..- .._..- ..- ..- .. -..- .-..-.._.._.._.._.._.._.. zt: =.._.._.._.._.._.. _.._.. ;.;_.._.._..- ..- ..- .._.._ . -.._.._.._.._.._.._.._ e .._.. _.._.._.._.._.._..z:•z;;_.._.. .T; _•,_ : 'a i�ase' -227 (P5) TDI7 "Lnr 0 1000 2000 3000 4000 5000 6000 7000 8000 Vertical Section (ft) Azim = 41.21°, Scale = 1(in):1000(ft) Origin = 0 N / -S, 0 E / -V • by • • • Schlumberger WELL V -227 (P5) I FIELD Prudhoe Bay Unit - WOA I STRUCTURE V -Pad Magnetic Parameters Surface LOCaBon NA027 Alaska State Planes. Zone 04. US Feet Miscellaneous Model: BGGM 2008 Dip: 80875° Data: November 05, 2009 I Let N70 19 01 043 Northing : 597015000 SUS Gnd Cony : +089317814° I Slot: Plan V Slot (N Y) TVD Ref: Rotary Table (82.50 ft above MSL) Mag Dec: +22.217° FS 577094 nT Lon: W1491549.912 Easting 5907900 SUS Scats Fad: 09999093589 Plan: V -227 (P5) Srvy Date: May19, 2009 0 1000 2000 3000 4000 5000 6000 { 4 6000 V- 227(P5) TO / r Lnr V -227 Tgt OBe 5000 5000 • • V -227 Tgt N Drp 0.5/100 4000 4000 A A A Z Cry 5/100 0 0 0 3000 3000 m U co Cl) V 9518" Cs V 2000 2000 Fault 1000 1000 End Cry Cry 4.5/100 End Cry 0 0 0 Bld 2.251100 RTE KOP Bld 1.51100 0 1000 2000 3000 4000 5000 «< W Scale = 1(in):1000(ft) E »> Antibollision Report AID Company: North America - ALASKA - BP Local Co-ordinate Reference: Well Plan V -227 (N -Y) Project: Prudhoe Bay TVD Reference: V- 227 Plan NY @ 82.50ft (Nabors 9ES) Refennii.e Site. PB V Pad MD Reference: -- -` - - V-22T Plan g 50ft (Nabuia 9ES- Site Error: 0.00ft North Reference: True Reference We11: =- -Plan V 227 (N-Y ) — -Su fey- Calculation- Method :---- Minimum-Curuaturo Well Error: " 0.00ft Output errors are at 1.00 sigma Reference Welibore Plan V -227 Database: _ T EDM.16 - Anc Prod - WH24P Reference Design: Plan #5 V -227 Offset TVD Reference: Offset Datum Reference Plan #5 V -227 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refen Interpolation Method: MD Interval5 O-0ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Resultstimited -by Ma wm- center - center distance of 1,227.90ft –Error -Surf ace: Surrey TooTFrogram. Date - 5/18/2009 From _ To (ft) (ft) - -Survey (Welibore) — -- T— OOTName Description — 28.50 500.00 Plan #5 V-227 (Plan V -227) GYD -GC -SS Gyrodata gyro single shots 500.00 1,900.00 Plan #5 V -227 (Plan V -227) MWD MWD - Standard 500.00 4,879.00 Plan #5 V -227 (Plan V -227) MWD +IFR +MS MWD + IFR + Multi Station 4,879.00 10,307.47 Plan #5 V -227 (Plan V -227) MWD +IFR *MS MWD + IFR + Multi Staliun — 5If 912009 8:52:19 Page 2 of 5 COMPASS 2003.16 Build 70 1111 At Anticollision Report Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Plan V -227 (N -Y) Project:, Prudhoe Bay 7VD Reference: V-227 PIan NY © 82.50ft (Nabors 9ES) - Reference ' - Site: - PB V Pad - Mf3Reference.- -- V- 22 Plan NY - 82 � `a0ft (Natrors 9Es} Site Error: O.00ft North Reference: True os ne . Well: - Plan -V-227 (N Y) --Su ode Minimum-Curvature- Welt Error: O.00ft Output errors are at 1.00 sigma Reference Welibore V-227 Database: ' EDM .16 - Anc Prod - WH24P Reference Design: " Plan #5 V -227 OffsetTVD Reference: Offset Datum Summary Reference ` Offset Centre to No-Go " Allowable Measured " Measured Centre Distance Deviation Warning Site Name. Depth Depth Distance (ft) from Plan Offs ign-- (ft) - - - fftt - If) --- (ft) PB V Pad Plan V423 - (NP) Ptan V 1223 - Plan #8 V-t23 92.17 495.00 135.1 9.33_25.84 Pass - - Major Risk Plan V -224 (S -Z) - Plan V -224 - Plan #7 V -224 717.74 725.00 168.86 12.69 156.18 Pass - Major Risk Plan V -228 (S -SL -Plan V -228 - Plan #2 V -228 389.99 390.00 202.00 7.36 194.64 Pass - Major Risk____ V-03 - V -03 - V -03 529.60 530.00 26.91 8.64 18.28 Pass - Major Risk V -04 - V -04 - V -04 454.26 455.00 151.22 8.33 142.89 Pass - Major Risk V -07 - V -07 - V -07 506.97 510.00 194.27 10.07 184.20 Pass - Major Risk V -100 - V -100 - V -100 418.25 420.00 188.34 7.10 181.25 Pass - Major Risk V -102 - V -102 - V -102 428.84 430.00 233.37 8.59 224.78 Pass - Major Risk V -103 - V -103 - V -103 448.95 450.00 89.24 7.87 81.39 Pass - Major Risk V -105 - V -105 - V -105 496.43 500.00 165.00 8.51 156.49 Pass - Major Risk V406--- V- 1 -06--V -106 458.14 - 460 -.00 1-16-T1 - -- - --- 7.32 -- 109-39--Pass-Major-Risk V -106 - V -106A - V -106A 495.94 500.00 117.54 11.03 106.50 Pass - Major Risk V -106 - V- 106APB1 - V- 106APB1 495.94 500.00 117.54 11.03 106.50 Pass - Major Risk V:1116- -- YB2 - V- 106APB2 495.94 - 501I00 - 1 - 17.54 11.03 106.50 ass - Major Risk V -106 - V- 106APB3 - V- 106APB3 495.94 500.00 117.54 11.03 106.50 Pass - Major Risk _L -111 - V -l1t-V -119 -_ - 553.33 555.00 - ____ -_ ___5-5.4$_ 19 94 43.24- Pass_ Major Risk V -111 - V -111 PB1 - V -111 PB1 553.33 555.00 55.48 12.24 43.24 Pass - Major Risk V -111 - V -111 PB2 - V -111 PB2 553.33 555.00 55.48 12.24 43.24 Pass - Major Risk V -111 - V -111 PB3 - V -111 PB3 553.33 555.00 55.48 12.24 43.24 Pass - Major Risk V -115 - V -115 - V -115 404.83 405.00 180.59 6.76 173.84 Pass - Major Risk V -115 - V -115L1 - Plan 4 404.83 405.00 180.59 6.76 173.84 Pass - Major Risk V -115 - V -115L1 -V-115L1 404.83 405.00 180.59 6.76 173.84 Pass - Major Risk V -115 - V -115L2 - V -115L2 404.83 405.00 180.59 6.76 173.84 Pass - Major Risk -V 1-1 a - - 1- 15L2PB1 -- Pr n 6 404.83 405.00 - 1-80459 G.7G 1- 73 -Pass-Major-Risk V -115 - V- 115L2PB1 - V- 115L2PB1 404.83 405.00 180.59 6.76 173.84 Pass - Major Risk V -115 - V- 115PB1 - delete me 28.50 28.50 180.71 0.91 179.80 Pass - Major Risk V -115 - V- 115PB1 - V- 115PB1 404.83 405.00 180.59 6.76 173.84 Pass - Major Risk V -117 - V -117 - delete me 28.50 28.50 194.85 0.91 193.94 Pass - Major Risk V -117 - V -117 - V -117 358.69 360.00 196.84 6.34 190.51 Pass - Major Risk V -117 - V- 117PB1 - delete me 28.50 28.50 194.85 0.91 193.94 Pass - Major Risk V -117 - V- 117PB1 -V-117PB1 358.69 360.00 196.84 6.34 190.51 Pass - Major Risk V= 117 = V= 11-7PB2 - V- 117PB2 358 -3 35FtO 1 6.34 1 Pass - ajor is V -120 - V -120 - V -120 474.98 475.00 13.64 9.75 3.89 Pass - Major Risk V- 121 - V- 121 - V- 171 1348.25 1,435.00- 183 95_ 27 53 159 80 -_ Pass - Major Risk V -122 - V -122 - delete me 28.50 28.50 189.58 0.91 188.66 Pass - Major Risk V -122 - V -122 - V -122 795.34 815.00 169.70 13.61 156.27 Pass - Major Risk V= t22 V122PB1 delete me 28.50 28.50 189:58 - 0.91 - 1 - 8&66 - Pass Major V -122 - V- 122PB1 - V- 122PB1 795.34 815.00 169.70 13.61 156.27 Pass - Major Risk V -122 V- 122PB2 - V- 122PB2 795.34 815.00 169.70 13.61 156.27 Pass - Major Risk_ -_ V -205 - V -205 - V -205 466.01 470.00 225.30 8.27 217.03 Pass - Major Risk V -205 - V -205L1 - V -205L1 466.01 470.00 225.30 8.27 217.03 Pass - Major Risk V -205 - V -205L2 - V -205L2 466.01 470.00 225.30 8.27 217.03 Pass - Major Risk V -207 - V -207 - V -207 300.99 300.00 16.21 5.07 11.14 Pass - Major Risk V -207 - V -207 - V -207 OBe field plan 1 300.99 300.00 16.21 5.07 11.14 Pass - Major Risk V -207 - V -207L1 - V -207L1 300.99 300.00 16.21 5.02 11.19 Pass - Major Risk V -207 - V -207L2 - Plan #7 V -207L2 OBb update 300.99 300.00 16.21 5.07 11.14 Pass - Major Risk V 207 V 207L2 V 207E2- - 300.99- 300:00- - 16.21 5,02 - 1-1 9 Pass-- Major -- Risk V -207 - V -207L3 - V -207L3 300.99 300.00 16.21 5.02 11.19 Pass - Major Risk V -207 - V -207L4 - V -207L4 300.99 300.00 16.21 5.07 11.14 Pass - Major Risk 207 - V- 207L4PB1 - Plan #8 V X00.99 300.00 X6.21 5 11.14 Pass - Major Risk V -207 - V- 207L4PB1 - V- 207L4PB1 300.99 300.00 16.21 5.02 11.19 Pass - Major Risk V -207 - V- 207L4PB2 - V- V -2071 4PB2 30f1 A9 3001)0 46 21 5.02 -_ 11.19 Pass= Major_Risk V -207 - V- 207PB1 - V- 207PB1 300.99 300.00 16.21 5.02 11.19 Pass - Major Risk 371972009 8:52T1 Page 3 of 5 COMPASS 2003.16 Build 70 I Anti collision Report Company: North America - ALASKA - BP Local Co- ordinate Reference :" Well Plan V -227 (N -Y) Project: Prudhoe Bay TVD Reference: V- 227 Plan NY © 82.50ft (Nabors 9ES) Refere et " PB NI " -- MD %) : . Oft (Nabors9ES Site Error: 0.00ft North Reference: True Reference -Well: Ptan V 227 (N Y} ed:- --- Minimum - Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore Plan V -227 Database: EDM .16 - Anc Prod - WI 24P Reference Design: Plan #5 V -227 Offset TVD Reference: Offset Datum Summary I Reference Offset Centre to No-Go Allowable Measured. Measured Centre = Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan O Well Welibore - Design -_ (ft) ---•- (ft) (ft) (ft) PB V Pad V-21 - V -212 - - 741.83 750:00 - 104.19 1 92.00 Pass - Major Risk V -213 - V -213 - delete me 28.50 28.50 182.54 0.91 181.63 Pass - Major Risk V -213 - V -213 - V -213 1,300.00 1,3 56.02 25.88 35.14 Pass - Major Risk V -213 - V- 213PB1 - delete me 28.50 28.50 182.54 0.91 181.63 Pass - Major Risk V -213 - V- 213PB1 - V- 213PB1 1,300.00 1,345.00 56.02 25.88 35.14 Pass Major Risk V -216 - V -216 - V -216 508.45 510.00 70.77 9.36 61.40 Pass - Major Risk V -217 - V -217 - V -217 399.54 400.00 215.28 7.94 207.34 Pass - Major Risk V -218 - V -218 - V -218 1,271.56 1,275.00 26.62 25.93 4.88 Pass - Major Risk V -219 - V -219 - V -219 270.49 270.00 181.11 4.68 176.43 Pass - Major Risk V -220 - V -220 - V -220 256.37 255.00 32.29 5.62 26.67 Pass - Major Risk V -221- v-22i - V-221- - 0-00- - - - - - -1 74.1 - - 2- .1 -7- __. _ -__1 -61.98 Pass --- MajorRisk V -222 - V -222 - V -222 673.34 690.00 217.18 12.25 204.95 Pass - Major Risk 3/1972009 8:52 :19AM Page 4 of 5 COMPASS 2003.16 Build 70 • Project: Prudhoe Bay • r ' -- Site PB V Pad Well: Plan V -227 (N -Y) Wellbore: Plan V -227 Design: Plan #5 V -227 From KOP to TD Scan interval 100 ft Scale 1:100 0 V -120N -121 350 24 3V^ 23 30 V -216/V -216 1300 41116 21 16 201 ll \ \\ 19 V - 220N -220 • ►, •_..425' 8 / ',. 15 V- ? -2 ?N- 221. 17 ` _ . r 14 15 16 22 2 1 300 14 60 1 5 21 13 s; 20 l 151 1, 12 - 13 17 11 V -1031 -103 ,, 11 16 / 1+ 1 i3 i 16 1 � - 104 ( 9 1 11 141 s AF-3 , ' / i . 9 2 1 � I _ 10 1 10 � 1 � g1 � �1'1 I' t.. t_ � i 49 fit = • 270 V 1 u4{4ti1 i 1 ,r 1l�'.1 1 11 � 1 .r ' u ...i. ‘ 04 1 10 ` + err. . 1 +'�9! , • AA \ ftr \ \ - "I:1M . *,(- 6 4'.7 0 14 l • . 4 0, 1 V- 213/V -213PB 23 2 \` � � �� . � 9 1' jij 22 2? f ► � ,,, f �� 10 1 2 , W 10. 1 -"1 4., or i,,...„,,,,,,„. 1 + R " 4fi ` ,j j� ` 120 240 13 % t� 1k11 z • '+ F 1 " r4 ' IY ^ - \\ / 1 � , ,,, � Ii V -1051 10 \ 1 : :. ' ` ti ` % +' ► , - cT1 . �i . V- 11P6 • 20 7 �, ' 61 9 7 1 . It*. t 9 g ' s 610 .,r 0' tit, Y p '` ti 10* 4 V 433 • k 2, 'V 9 ( 11 10 9 - • Plan V -224 (SZyPtan #7 V -224 18 \ 22 1 1 ' gyp' , 311 ...- -- 7 V - 212,V - 212 - 1 9 1 , 26 ;3� V -218N -218 I I V -219N -219 V -1001- i „- 16 , n { V- wry- izm82 V -• 1' N- 217J-2Z5 (5- 1; ........;.: -qq a OBb update 180 V- 2071- 207PB'B2 Travelling Cylinder Azimuth (TFO +AZI) [°] vs Centre to Centre Separation [100 ft/in] EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 AEO2 6000000 AEO 1 � I 5950000 V -227 (surface) 5900000 40 CFR 147.102 (b)(3) 5850000 400000 500000 600000 700000 800000 Alaska Department of Natural .ources Land Administration System Page 1 of4 Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28240 Printable Case File Summary See Township, Range, Section and Acreage? O Yes O No New Search LAS Menu I Case Ab stract I Case Detail I Land Abstract File: ADL 28240 Search for Status Plat Updates As of 09/30/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: Ol1N Range: 011E Section: 01 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 011E Section: 02 Section Acres: 640 Meridian: U Township: 011N Range: 011E Section: 11 Section Acres: 640 Meridian: U Township: 011N Range: 011E Section: 12 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -19 011N- 011E -UM 1,2,11,12 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA PRUDHOE BAY UNIT http: / /dnr.alaska.gov /projects /las /Case Summary.cfim ?FileType= ADL &FileNumber = 2824... 9/30/2009 Alaska Department of Natural Sources Land Administration System Page 1 off( Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28238 8 Printable Case File Summary See Township, Range, Section and Acreage? New Search @ Yes O No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28238 ' Search for Status Plat Updates As of 09/30/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/28/2007 Case Subtype: NS NORTH SLOPE Last Transaction: PAXN1 PARTICIPATING AREA EXPANDED Meridian: U Township: 012N Range: 011E Section: 25 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 011E Section: 26 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 35 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 36 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -16 012N- 011E -UM 25,26,35,36 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA PRUDHOE BAY UNIT TRACT 19 OIL RIM AND GAS CAP PARTICIPATING AREAS T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2823... 9/30/2009 • TRANSMITTAL LETTER C HECKLIST WELL NAME , ' ' Y'4 ��• PTD# 709 »6 Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: 73eL/D, / .3.v/ POOL: e /O/✓ �C�. Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN V -227i Program SER Well bore seg ❑ PTD#: 2091160 Company BP EXPLORATION ALA KA INC Initial Class/Type SER / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA - - - 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes Orion - Schrader Bluff. 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, iswellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond #6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 9/30/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes AIO 026.000 Abe 15 All wells within 1/4 mile area of review identified (For service well only) Yes glir 16 Pre - produced injector: duration of pre production Tess than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA Within area AEO No.1 (40 CFR) 20 CMT. vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC planned 1000' below surface shoe. 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel pits. All waste to approved desposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. All drilled wells pass major risk. 27 If diverter required, does it meet regulations Yes Paddle removal approved <1000' Appr Date 28 Drilling fluid program schematic & equip list adequate Yes fm pressure = 2282 psi. (8.7ppg) Drilling with 9.1 ppg mud GLS 10/1/2009 29 BOPEs,dotheymeetregulation - - Yes - - - - - 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 1775 psi . Will test BOP's to 4000 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes III - - 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on V pad. Rig has sensors and alarms. - - 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR complete. Nearest well in pool is V- 213PB1 at 815' (plugged with cement) 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on Pad was 300ppm (4/3/07). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 9/30/2009 38 Seabed condition survey (if off- shore) NA 39 Contaot name /phone for weekly progress reports [exploratory only] - No Geologic Engineering • om c Commissioner: Date: • D iss ate • ♦ Date ioner er 9 `..A - 74 /©- 6)-m I /D-'�--�