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204-003
1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 49.1' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20"x34" A-53 110' 10-3/4" L-80 2,668' 7-5/8" L-80 4,332' 4-1/2" L-80 4,332' 4-1/2" L-80 4,243' 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, Uncemented Tieback LinerTieback TUBING RECORD Uncemented Slotted Liner 3,581' - 7,281'4-1/2" 12.6# 13Cr80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 7,315' 13,044' 515 sx Class 'G' 4,330' 48" 12.6# 31' 2,871'723 sx AS Lite, 338 sx Class 'G' 6-3/4" 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 10/13/2021 2568' FSL, 3704' FEL, Sec. 34, T12N, R11E, UM, AK 236' FSL, 2645' FEL, Sec. 21, T12N, R11E, UM, AK 204-003 Schrader Bluff Oil Pool, Orion Dev Area 77.6' 3,354' / 2,405' HOLE SIZE AMOUNT PULLED 50-029-23191-61-00 PBU L-200L2 583209 5978290 1986' FSL, 3367' FEL, Sec. 27, T12N, R11E, UM, AK CEMENTING RECORD 5982991 SETTING DEPTH TVD 5986471 BOTTOM TOP 9-7/8" 31' 13-1/2"31' CASING WT. PER FT.GRADE 12.6# 583486 578883 TOP SETTING DEPTH MD 31' 7,282' Per 20 AAC 25.283 (i)(2) attach electronic information 29.7# 7,320' 2,502' 4,316' DEPTH SET (MD) 7,092' / 4,243' PACKER SET (MD/TVD) 215.5# 45.5# 110' 3,555' 7,320' Gas-Oil Ratio:Choke Size: 26' - 3,362' Pull 4-1/2" Kill String Water-Bbl: PRODUCTION TEST Not on Production 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 MWD / GR / RES / Azimuthal DEN / NEU / AIM / PWD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 2/17/2004 2/14/2004 ADL 028239 & 047447 00-001 1900' (Approx.) 7,320' / 4,332'N/A None 13,115' / 4,248' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Prudhoe Bay Field / By Samantha Carlisle at 1:46 pm, Nov 02, 2021 RBDMS HEW 11/3/2021 Abandonment Date 10/13/2021 HEW xG DSR-11/3/21SFD 11/4/2021 3,871'SFD MGR17FEB2022 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 7319' 4332' 7319' 4332' SB OBa 7319' 4332' 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 Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top 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. Formation at total depth: 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 OBa 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 11.2.2021Digitally 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: 2021.11.02 08:46:11 -08'00' Monty M Myers Activity Date Ops Summary 10/11/2021 PJSM NES on location at 06:00 for rig move. Move and stage Gen & Mus Mods. Remove matt boards. Jack up pipe shed and Catwalk stage on pad. Jack up Sub and walk sub down well row to L-200A. SIMOPS C/O suction valve and seat on MP #2 Pod #1. PJSM Cont walk sub down well row and center over L-200A. Spot Catwalk, Pipe Shed & Mud Mod. Install inner connects. ODS arm stabilizers on sub. Cover stompers W/ Herculite. Work on test pump, clean steam traps. PJSM Cont spotting Gen Mod. Set matt boards Release NES trucks at 00:30. PJSM R/u inner connects. Pres up Air, steam and H2O though out rig. Assist Electrician going to Gen power through mods. Gen power at 02:00. Set down stompers and prep to scope up derrick. Safe out stairs and landings throughout rig.. Spot break shack and enviro vac. PJSM Scope up derrick and bridle down. Grease crown sheaves and perform full derrick inspection. Hang rig tomgs and unpin weight buckets. Function rig floor Equip as per rig acceptance check list. Lay Herculite and spot cutting box. Cont rig acceptance check list. 10/12/2021 Work rig acceptance checklist. Function test all equipment in mud pits and pump room. Repair and install guards on skate. Rig accepted @ 07:30 hrs. Pull TWC. Spot and rig up flowback tank. Purge line from cellar to tank with air and check for leaks (good). Flood lines with H2O and PT same 1000 psi (no leaks). Circulate down 4.5" tubing taking returns IA to flowback tank. Pump 40 bbls heated Baraklean pill, chase with 330 bbls 9.5 quikdril mill ing fluid @ 6 bpm, 260 psi. ~160 bbls diesel returned to tank, ~210 bbls 9.2 brine. Set BPV, N/D tree. Install CTS and test (TWC) same 5k (test good). Install 18" 11"x13-5/8" spacer spool. N/U 13-5/8" stack - LPR 2-7/8x5-1/2" VBRs, Blinds, UPR 2-7/8x5-1/2". RKB Ann 11.77', UPR 14.66', BLND 16.10', LPR 19.77', ULDS 23.03' LLDS 25.32', Ground 26.56'. Flood stack W/ H2O purge air. Shell test to 2,000 psi, good. Remove RCD cap and install trip nipple. M/U 5" test jnt, X/O 4.5" IF X 4.5 TCII to test sub on hanger. R/U side entry, 2 ea 5" TIW and 5" Dart valve. SIMOPS R/D hard lines and flow back tank. PJSM Perform BOPE test W/ 4.5" & 5" to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 2 ea 5" TIW, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill , Super Choke and manual to 1,600 PSI, 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. Checked PVT sensors and return flow. Koomey draw drown Initial System 2,925 PSI, Manifold 1,425 PSI, Annular 1,375 PSI, after System 1,500 PSI, Man 1,500 PSI, Annular 1,500 PSI. 200 PSI increase 18 Sec, full charge 86 sec. Nitrogen 6 bottle average 2,291 PSI. Witnessed Waived by AOGCC Jeff Jones via phone call. PJSM R/D 4.5" test, break down head pin L/D. P/U 5" test jnt break down TIW, side entry and dart. L/D. Blow down choke manifold and lines. Grease choke manifold. PJSM R/U Weatherboard 4.5" tools & Equip. C/O elevators to YC 75T. R/U power tongs. M/U X/O for TIW. SIMOPS C/O Saver Sub. P/U Tee Bar and remove CTS and BPV as per Vault rep onsite. PJSM M/U 4.5" landing jnt to Hanger, BOLDS as per Vault rep onsite. Unseat Hanger W/ string weight 60K. no issue. POOH L/D 4.5" 126# 13cr-85 VamTop to 2,900' MD.. P/U 58k SLK 56k Extra X/O pup under hanger pup. Hanger pup 2.57' & X/O pup 2.40'. Daily Disposal to G&I = 0 bbls, total = 0 bbls. Daily H2O F/ Lake 2 = 560 bbls total= 560 bbls. Daily Metal: 0 lb. Total Metal 0 lb. 10/13/2021 Continue POOH w/ 4.5" Vam Top kill string from 2900' to surface. L/D mule shoe jt. R/D WOT handling equipment. Calculated displacement from trip. 45k Up/Dn @ 2900' MD. R/U test equipment. Close blinds and test 10-3/4" 45.5# L-80 casing to 2000 psi w/ 30 min hold. Chart and record same. 2 bbls pumped / 1.8 bbls bled back. (Test good). B/D test equipment. R/D same. Install wear bushing. Pick up drift (3.125") and single in the hole with 5" drill pipe to 1468'. POOH racking back drill pipe. Clean and clear rig floor. Mobilize BHA components to rig floor. M/U Baker milling assembly: 9-3/4" starter mill, 9-1/2" lower mill, flex joint, 9.80 upper mill, 15' HWDP pup join, XO, Float sub. (6) jts HWDP, 6 jnts DC to 453'. Tight at 252' with 6K drag work through x 2. Set down with 15K at 284', unable to work through. Establish circulation at 6 bpm, 55 psi. 20 rpms, 1500 ft-lbs worked through x 3. RIH with milling BHA picking up, drifting (3.125") and single in the hole with 5" DP from 453' to 996'. Set down 20K at 559'. Worked through x3 with 6 bpm, 65 psi, 20 rpms 1500ft-lbs. Set down 25K at 980' (Tam Port), with 25K overpull. Work down to 996', setting down 30K with 30K overpull. Discuss options with Engineer. POOH from 996' to surface. L/D upper mill. RIH with dual mill assembly (same BHA without the upper window mill), picking up drill pipe to 1300'. Observe drag at 980', work through x 2 with 25-30K down and 25K overpull. Cont. to RIH with dual mill assembly, picking up 5"DP to 3294', RIH one stand out of derrick and tag whipstock at 3354' (P272 RKB 3375'), on depth. Rack back one stand and pick up single, M/U stand of drill pipe. Establish parameters, 10 bpm, 272 psi, 70 rpms, 4500ft-lbs. PUW 91K, SOW 78K, ROTW 88K Mill window from 3354' to 3360', WOB 1-2K, 460 gpm, 305 psi, 70-80rpms, 6-9Kft-lbs Daily Disposal to G&I = 0 bbls, total = 0 bbls. Daily H2O F/ Lake 2 = 140 bbls total= 700 bbls. Daily Metal: 0 lb. Total Metal 0 lb. 10/14/2021 Cont milling window from 3360' to 3381' at 460 gpm, 310 psi, 80 rpms, 4Kft-lbs off 5.5Kft-lbs on bottom, WOB 2-6K. PUW 95K, SOW 81K, ROTW 88K. TOW 3354'. BOW 3374' Ream up through window without issues. Pump high vis sweep and circulate surface to surface. No increase in cuttings. monitor well, observe slight flow. Rack back stand to 3363'. Circ bottoms up at 450 gpm, 305 psi, 40 rpm 4-5K ft-lbs. Monitor well, static. Pump 10 bbls dry job, B/D top drive. POOH racking back drill pipe from 3363' to 438'. Observe 20K over pull from 1005' to 980'. Calc hole fill. Monitor well - static. Rack back 3 stands of HWDP and 3 stands spiral drill collars. Mills ~1/8 under gauge. L/D milling assembly. M/U milling BHA #3, window mill, bit sub, HW pup, 9.88" OD Upper mill, flex joint, HW pup, XO sub, (1) HWDP. float sub. Pull 9-7/8" wear bushing. RIH with milling assembly with (6) DC, (6) HWDP to 453' working through tight spots at 250' and 400'. RIH with milling assembly on drill pipe from 453' to 1015'. Set down at 985' with 30K. Work pipe down to 1015', rotating pipe 1/8 turn and circulating at 6 bpm, 105 psi with 15-35K down and overpull. Unable to make past 1015'. Monitor well, slight flow. CBU 455 gpm, 195 psi. Monitor well, static POOH from 955' to 80'. Calculated hole fill observed. Cont. to POOH from 80'. L/D 9.88" OD upper mill. M/U 9.80" Upper mill. Set 9-15/16" wear bushing. RIH with milling assembly to TOW at 3354'. Work through tight spots at 547', 616' with 10-15K down. Work through tight spot from 992' to 1015' with 6 bpm, 132 psi setting down 25-35K. Establish rotary at 80 rpms, 6Kft-lbs, circulation at 11 bpm, 330 psi. Dress off window, milling from 3354' to 3384' PUW 98K, SOW 80K, ROTW 88K. Daily Disposal to G&I = 57 bbls, total = 57 bbls. Daily H2O F/ Lake 2 = 140 bbls total= 700 bbls. Daily Metal: 100 lb. Total Metal 100 lb. API #: 50-029-23191-61-00 Well Name: Field: County/State: PBW L-200L2 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 10/15/2021 Continue Milling 9.800" window in 10-3/4" 45.5#, L-80 casing F/ 3384' to 3404' MD. TOW @ 3354', BOW @ 3374' MD. Drilled 30' new formation to allow lower mill to work btm of window and drill 6' of gauge hole outside window. 11 bpm, 330 psi, 80 rpm, 6k tq. P/U 97k, S/O 79k, ROT 89k. Pump 35 bbls spacer pill then displace wellbore over to 9.5 PPG spud mud while Rot/Recip @ 3404' to 3347' MD. 450 gpm, 775 psi, 46% R/F, 40 rpm, 6k tq, P/U 92k, S/O 74k, ROT 85k. Flush choke and kill lines post milling operations. PJSM, B/D TDS. R/U and perform 12 ppg EMW FIT @ 3354' MD (2404' TVD) using upper pipe rams. 1/4 bpm pump rate. .8 bbls in, .6 bbls out. Psi up to 315. Good FIT. Chart and record same. B/D test equipment and R/D same. Monitor well (static). L/D working single. POOH racking back 5" NC50, 19.5#, S-135 drill pipe F/ 3354' - T/ 2402' MD. P/U 89k, S/O 72k. Cont POOH rack back 5" NC50, 19.5#, S-135 DP F/ 2402' - T/ BHA. Rack back 3x stds 5" HWDP, L/D DC"s and mill assy. Gauge mills. Starter mill 1/4" under, upper mill in gauge / 9.800" OD. Hole took proper disp. Slow pulled mills thru @ 1015' w/ 35k drag (3'). Saw 7k bobble @ 550' MD then clean. Clean and clear rig floor. Pull wear bushing and johnny whack the stack to flush metal cuttings from surface. Re-install 9-15/16" ID wear bushing. RILDS (4x). Service traveling equipment and pipe handling equipment. M/U BHA: 9.5" PDC bit, motor with 1.86° bend, GWD, DM, Measure RFO: MWD-MTR=133.13°, MWD-GWD=255.08°. Cont M/U GHA DGR, ADR, PWD, TM, float sub. Plug in and upload MWD. P/U and RIH with (2) DC, 17 jnts HWDP, jars to730'. Pick up, drift (3.125") and RIH with 5" drill pipe from 730' to 1986'. Calculated displacement observed. 5K drag at 985'. PUW 77K, SOW 64K Cont. Pick up, drift (3.125") and RIH with 5" drill pipe from 1986' to 2995'. RIH from derrick from 2995' to 3338'. Calculated displacement observed. PUW 98K, SOW 60K Service rig. Grease and inspect crown sheaves, service iron roughneck, grease an dinspect top drive. Check gear oil level. Pull trip nipple, install MPD. Fill pipe. Pulse test. Orient motor to 42°LOHS. RIH to 3404', no issues through window. Wash down from 3385', no issues. Drill 9.5" hole from 3404' to 3464' (total=64', AROP=43fph) at 450 gpm, 1400 psi, WOB 4-6K, 60 rpms, 8Kft-lbsMax gas 30U, ECD 10.8 ppg EMW with 9.5ppg mud. PUW 110K, SOW 77K. Daily Disposal to G&I = 568 bbls, total = 625 bbls. Daily H2O F/ Lake 2 = 70 bbls total= 770 bbls. Daily Metal: 25 lb. Total Metal 125 lb. bp � Date: 1/20/2020 (� f Transmittal Number: 93730 BPXA WELL DATA TRANSMITTAL Enclosed is one disc containing the information listed below. 204003 32 n5© If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall(?bn com. Please Sign and Email a copy of this transmittal to. GANCPDCna bp365 onmicrosoft com Thank you, .viler XendaCf Subsurface Information Management AOGCC ConocoPhillips Alaska, Inc. ExxonMobil, Alaska JV-2019-USONSHOR-291 RECEIVED FEB 2 12020 I Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Disk SW Name API Run Date Com an Description Number GYROSCOPIC SURVEY DATA AND GyroData / FINAL COMPOSITED GYROSURVEY L-200 500292319100 9/7/2019 Baker Hu hes REPORT 1 L-20OLl 500292319160 2/19/2020 Baker Hughes GYROSCOPIC SURVEY REPORT L-2001-2 1500292319161 2/19/2020 IBaker Hughes IGYROSCOPIC SURVEY REPORT Please Sign and Email a copy of this transmittal to. GANCPDCna bp365 onmicrosoft com Thank you, .viler XendaCf Subsurface Information Management AOGCC ConocoPhillips Alaska, Inc. ExxonMobil, Alaska JV-2019-USONSHOR-291 RECEIVED FEB 2 12020 I Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE ri ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COM N REPORT OF SUNDRY WELL OPERA S dQ 1. Operations Performed JUN 12 2018 Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑I Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change ApA r• Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Suspended Inspection I I 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 204-003 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23191-61-00 7. Property Designation(Lease Number): ADL 028239&047447 8. Well Name and Number: PBU L-200L2 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: I Total Depth: measured 13115 feet Plugs measured 3375,3400,5050,7122 feet true vertical 4245 feet Junk measured None feet Effective Depth: measured 3375 feet Packer measured 7092 feet true vertical 2413 feet Packer true vertical 4240 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"X 34" 31-110 31-110 Surface 3840 10-3/4" 31-3871 31-2668 5210 2480 Intermediate 4317 7-5/8" 3555-7872 2502-4496 6890 4790 Tieback Liner 38 4-1/2" 7282-7320 4313-4329 8430 7500 Liner 5569 4-1/2" 7315-13044 4327-4245 8430 7500 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 26-3362/3581-7281 26-2406/2516-4313 Packers and SSSV(type,measured and 4-1/2"Baker Premier Packer 7092 4240 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JUN 2 0 LUT. 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: Suspended Subsequent to operation: 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 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: N/A Authorized Name: Montgomery,Travis J Contact Name: Montgomery,Travis J Authorized Title: Interventions&Integrity Engineer Contact Email: Travis.Montgomeryi bp.com Authorized Signature: -�/ 6713 Date: Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 / ///` �]BARNS M JUN 1 9 gt11� /f 40/4//'8 0/ Z/ Q� n DM �t ( LY Submit Original Only • • Daily Report of Well Operations L-200L2 ACTIVITYDATE SUMMARY T/I/O = MV/0/0. Temp = SI. Suspended well pre inspection (pre AOGCC). Wellhouse installed and lighted. Dryhole tree installed. Rig on L-118 presently. 3/21/2018 SV= C. MV= LOTO. IA, OA= OTG. 21:30 T/I/O = MV/0/0. Temp = SI. Suspended well pre inspection (pre AOGCC). Wellhouse installed and lighted. Dryhole tree installed. Rig on L-118 presently. Removed pipe insulation and sheet metal from wellhouse floor, and installed current well sign. 3/22/2018 SV= C. MV= LOTO. IA, OA= OTG. 21:30 T/I/O - 0/0/0 Temp - SI AOGCC Suspended Well Inspection (Reg Comp) Walkdown with AOGCC inspector. PTD# incorrect on wellhouse sign. 3/23/2018 SV- C. MV- LOTO. IA, OA- OTG. 10:00 T/I/O = MV/0/0. Temp = SI. Install wellhouse sign (post AOGCC inspection). Dryhole tree installed. Installed current well sign. 3/23/2018 SV= C. MV= LOTO. IA, OA= OTG. 20:30 T/I/O = LOTO/0/0. Temp = SI. Pre AOGCC SU Well Inspection. Wellhouse installed, clean and illuminated. Dryhole tree installed, no flowline. Ice in cellar. Well ID sign is in place and accurate to schematic. 6/1/2018 SV= C. MV= LOTO. IA, OA= OTG. 02:30. AOGCC SU Inspection. Witnessed by Jeff Jones Conducted AOGCC suspended well inspection. Took pictures of well house and well head. 6/9/2018 Verified casing vales were open and WHPs. • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: L--- 2.00 Field/Pool: t,J('0A /LAI OA Oi• ! Permit#(PTD): 204 pQ{0 API Number: 5(:)-02 — 2.319 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: n2./ 'f c I I Surface Location: Section: Twsp: 12 14 Range: 11 E Nearest active pad or road: j. d /,spike_ Rd Take to Location t" Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: C { Pad or location surface: C.1 p, o .1 Gi,'S 4 Location cleanup needed: 0 eto‘ Pits condition: Surrounding area condition: LI CAA Water/fluids on pad: OA t„, 'c t)At( S 4,0 i Ai Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: Cvitibi I Photographs taken (#and description): tide ii , / , f ', f 1 .Ad I Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings, where practicable, I 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: 'INI c,o C w, rp cirl j ,S W.'J Cellar description, condition, fluids: I C..P 5 r , o-_ Rat Hole: NAA mm Wellhouse or protective barriers: We L 1 o!Aft S { t) , 4,-,/". Well identification sign: `f p c Tubing Pressure (or casing if no tubing): I* ' z- ,,.4„. Annulus pressures: t1.49P�, I IA 11.. 6A Wellhead Photos taken (#and description): y e \f to 1 i f4 , ',41 q i )_° .. Work Required: None Operator Rep4 p (name and signature): -JOAN Pro ,t-14 k AOGCC Inspector: Other Observers: Inspection Date: (fPbt1t.0:? CVQ jA AOGCC Notice Date: _;a •:4i . 6/13/i1;.:'; Time of arrival: Time of Departure: ` Site access method: Rtao-d • • Suspended Well Inspection — PBU L-200 1 PTD 2040010 Plat highlighting L-200's wellbore and one-quarter-mile radius buffer: / f IJ.,7 14212P82 ISN E2-0120 21 ' 22 23 L203 I1 L-250L1 L 203L2-01 ) 0 1 L-223 L-200L2 L.200 to -200L1 L 18L1 __ 1 _ —- \ 3 i— i L•11PB1 �, ; . L215PI \ 1. 12 L a50�L 203L `, // 9 I \ ( -211 \ 2 3Pt 20 L3PB -2 -, ' L-12 } L23L3 Lt(x- I I i1 1 i L 2o3L1 29 Bel; -11‘.1 AL1 ' 1 L'A li L-21y' *1,, t 33-29E cb MAfFiFFEN-2 ° L-11�. E ( �' ' �; 4'11-;-1,„ 1� 18 ,1'...„.././I 119%,.' L-203L2, 12 Qril f ( / 11 � l } - L-122 11 � /,�/ ,, L3 1 -- — L- —�2 i r�" L 11PB1 '''--1-421.,_ 02r2t Oz. PBtr9''- /CVO, ,0 L -202 L-O2A L 4, y Q / "_27C412112 a f;s lid .fL_h ---s L-114A '"7. «,I 1 ��°"r' ��� '�.�,—�-�L-if�2a L- 02 " 06257,6.1:9„0-0.3(7,L, `z" L S 32 .. 33 _ ' u9 -: 1 i L-2,1PB2 ' ' CJ1UtP1 ..' L-105 L201L1PB1 L-20 ' 1 94 `' ' , , , L-104 L-201 .L 2011 L 60, .....\7 ............___.....'‘.203L ..203 "x-210 S L. 200 mi. WELL: OWNER Prudhoe Bay Unit OPERATOR BP Exploration (Alaska) Inc. API NUMBER 50-029-23191-00-00 SUR. LOCATION SW 1, 4, Sec. 34, T12N, R11E DRILLING PERMIT 204-001 • • r . 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A* 0,r a T 0. � d;� *414 �� �Y �.. YII ""*0044,„ t ♦( 4., : "4110,4, • • 1M «. A4 ale# Rit, �"' ' a,: it 4„.„,,,,,,,,,, y Gis 84 �!4 1 . ...Av.-". ' ::-.'' ♦ JI! +'gni► .11.4 al 40�► r +o „ Q lib w► ,.. Ai IIIIIIIII 161 k e • '' \ I III ,till roil! I '"IIP" ill, . i k 1, ....„. 11 .... ..,......„_..,, . „_.. ,.,.. ... ...,. . „,,....„. .... ...... .... _. . ..... . .„ „ •t , 411 41 . .. ... .. .. .. . ,...,,.... ... ;lr ''' 41 / . .. al y ...., ;law ...,, •:t', A -- A.; •,.... , _..... . ,..., .. , ,..- ...„..,. Ai lk A . .t. ,......,....: , . 4....,. WELL. L-20C; ; „.. )-. „.„. # . ..,:, ... 4 i tt. ,,,. , ,, ,.,' ,..., •,, ' ,4.,, 7- '--t-,,---- -- ''!'- - ''-''''"' '''''''7' 7'' -- . '" . . -. TREE= 4-1/16"CNV VVELUIEAD= 11'FWC $USP EDLL— Q(� NOTES: WELL ANGLE>700(§6602'. ACTUATOR- BAKER L1 `2 OBSTRUCTIONS SEEN @ 300',420',& TB O .ELEV= 77.6' 1,000'INSIDE THE 10-3/4"CSG+"' REF ELEi/ 77.6' 20#CON) H 114' ----I BF.ELEV= 48.99 986' —110-3/4"TAM PORT DOLLAR KOP= 380 4-112"CUT TBG 3376' H10-3/4"BAKB2 VM-IPSTOCK(_/ /_) Max Angie= 96*@ 11569' (12/08/16) Datum MD= 7515' 3400' —110-3/4"HES EZSV(__//__) Datum TV D= 4400'SS 7-5/8'CSG CUT(_/_/J H 3555' 1----- 4-1/2"CUT TBG(_l_/_) —1 3581' / GAS UFT MANS 10-3/4'CSG,45.5#,L-80,D=9.950' —1 3871' A , ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3448 2436 60 KBG2 DMY BK 0 11/04/15 ESTIMATED TOC PLUG(12/02/16) — —5050' k, 5 3565 2495 60 KBG2 DMY BK 0 11/21/09 Minimum ID = 3.813" @ 2174' )w' `"' *4 5373 3433 58 KBG2 DMY BK 0 07/03/11 �� �= ' *3 5490 3498 56 KBG2 DMY BK 0 11/21/09 4-1/2" HES X NIPPLE ,► *2 6645 4068 69 KBG2 DMY BK 0 11/21/09 7-5/8"X 9-7/8"TOC —1 5800' *�za ' *1 6888 4157 69 KBG2 EMPTY BK - 11/22/16 RA TAG H 6983' *STA 4,3,2,&1=COVERED BY CMT 4-1/2"SGM-NDPG-CA —1 7035' ,'[�+#, _ 7061' -14-112"BKR CND SLDING SLV,D=3.813" MULTI-DROP SW,D=3.958" /� �� �, 7087' H 7-5/8"X 4-1/2"BKRPREM PKR,D=3.875" 4-1/2'SGM-NDPG-CA H7066' z.7. '� 7122' —14-1/2"HES XNIP,ID=3.813" MULTI-DROP SUB,D=3.958" 7 Ili 7122' —14-1/2"PX PLUG(11/05/15) 4-1/2"TBG,12.6#,13080 VAM TOP H 7250' .0158 bpf,D=3.958" 7193' -j4-1/2"HES X NP,13=3.813" RA TAG -1 7270' 'N 7264' —14-1/2"X 5-1/2"XO,ID=3.940" ik g� 4-1/2"TBG,12.6#L-80 BT-M, —1 7296' I ��VI: 7277' 15.75"BKR SEAL STEM .0152 bpf,ID=3.958" .:; �' (SEALS RHIADVED),D=4.83" 5 112"X 4 12"XO,D=3.930" —{ 7301' 1k 7282' H7-5/8"X 4-1/2"BKR ZXP LW w/TEBK,D=5.750" BAKER HOOK HANGER H 7315' # oar L2 (OBa) L2(OBa)LEM WINDOW 65° w/L2 NON-SEALING LEM,D=3.71" Aeri 7320'-7331' CALLA PS®LBM-CAN NOT PASS BY —7315 OBa PBTD —1 13043' OPENING WIDTH=3.33 (SEEN IN D.H.VIDEO)(12/14/12) RA TAG — 7375' 7 31 5'-13044' 6-3/4"OBa LATERAL,ID=3.958" 7-5/8"X 5-112"BKR ZXP LIP,D=4.94" — 7386' � 7368' --14-1/2"MULE SHOE,D=3.958" 5-12"X 4-12"XO,D -Ta=3.930" —I 7405' L1 (OBb)LEM WINDOW 64° BAKER HOOK HANGER —I 7419' I Li (OBb) 7424'-7435' b..§. OPENING WIDTH=3.33" w/L1 NON-SEALING LHM,D=3.71" 'F, \ OBb PBTD -iilfr 12987' wi PERFORATION SUMMARY REF LOG: 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958" ANGLE AT TOP PERF: dIrg Fo Note:Refer to Roduction DB for historical pert data ------ 7537 —I7-5/8"X 5-1/2"BKR ZXP LNR TOP PKR SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLID OBa 7392-13000 0 02/18/04 7548' J- I4-1/2"MULE SHOE,D=3.958" 4-1/2" SLID OBb 7497-12944 0 02/12/04 di 4-1/2' SLID OBd 7870-13008 0 02/04/04 ' 7557 —15-1/2"X 4-1/2"XO,ID=3.930" Ir RA TAG —I 7663' ,, IL-2001 7572'-13052' 6-3/4"OBd LATERAL,ID=3.958" 7-5/8"CSG,29.7#,L-80 BTC-M,D=6.875" — 7872' OBd PBTD — 13050' -___ DATE REV BY COM ENTS DATE REV BY COMNBNTS ORION UNIT 02/22/04 N9ES ORIGINAL COMPLET1ON WCL L-200 11/25/09 D-16 RWO PaRMIT No. 2040010(020)(03p) 02/04/17 P272 SLJSPBMD®ST API MY 50-029-23191-00 460)(61) 02/06/17 JMD DRLG HO CORITCCTION.ti SEC 34,T12N,R11 E,256T FSL&1575'FEL BP Exploration(Alaska) RECEIVED STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMIS MAR 0 6 2017 M WELL PLETION OR RECOMPLETION REPO AND LOG la. Well Status: Oil 0 Gas ❑ SPLUG 0 Other 0 Abandoned 0 Suspended El • 1b.Well CIas I/GEC, 20AAC 25.105 20AAC 25.110 Development ® Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL ❑ No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry _ BP Exploration(Alaska),Inc 2/5/2017• 204-003' 317-068 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 2/14/2004 50-029-23191-61-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/17/2004 L-200L2 • Surface: 2568'FSL,3704'FEL,Sec.34,T12N,R11E,UM 9 Ref Elevations KB 77.6 17. Field/Pool(s): 1990'FSL,3367'FEL,Sec.27,T12N,R11E,UM GL 49.1 •• BF 48.99 •• PRUDHOE BAY/ Top of Productive Interval: SCHRADER BLUFF OIL ' Total Depth: 241'FSL,2640'FEL,Sec.21,T12N,R11 E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 3375'/2413' ADL 028239&047447 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/ND): 19. Land Use Permit: Surface:x- 583209- y- 5978290 ' Zone - ASP 4 ' 13115'/4245' 00-001 TPI: x- 583486 y- 5982994 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20. Thickness of Permafrost MD/ND: Total Depth:x- 578888 y- 5986476 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No IEI 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 7320'/4329' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, 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 MWD/GR/RES/Azimuthal DEN/NEU/AIM/PWD 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20"x34" 215.5# A-53 31' 110' 31' 110' 48" 260 sx Arctic Set(Approx.) 10-3/4" 45.5# L-80 31' 3871' 31' 2668' 13-1/2" 723 sx AS Lite,338 sx Class'G' 7-5/8" 29.7# L-80 3555' 7320' 2502' 4329' 9-7/8" 515 sx Class'G' 3526' 4-1/2" 12.6# L-80 7282' 7320' 4313' 4329' Tieback Uncemented Tieback Liner 4-1/2" 12.6# L-80 7315' 13044' 4327' 4245' 6-3/4" Uncemented Slotted Liner 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 26'-3362'/3581'-7281' 7092'/4240' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 3SCANKV 0 I i N Was hydraulic fracturing used during completion? . ��E�,i _i I Yes 0 No D ' Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ".w► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate 'M Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only ie 7l%g" RBDMS t, {AR - 8 2017 _ -13.r7 \6, 28. CORE DATA Conventional Core(s) Yes ❑ No ® • Sidewall Cores Yes 0 No l * If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No 1 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 7319' 4329' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Schrader Bluff OBa 7319' 4329' Formation at total depth: cz3/v'a - 6V)0,‘ 13It 5- I-42U6--- • 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram 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. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Thompson,Jacob Email: Jacob.Thompson@BP.com Printed Name: Joe Lastufka o Title: Drilling Technologist Signature: A _Phone: +1 907 564 4091 Date: 3a,0-7 +� 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and ND for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records 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. Item 31.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. Form 10-407 Revised 11/2015 Submit ORIGINAL Only i r WELL NAME: L-200L2 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 5050' 66 Bbls Class 'G' 3581' Cut & Pull Tubing 3555' Cut & Pull 7-5/8" Casing 3400' Set EZSV 3375' Set Whipstock • S L-200L2 Well History (Pre-Rig Sidetrack) L-200L2 ACTIVITYDATE SUMMARY T/I/0=350/560/200, Temp=SI. PPPOT-T(PASS), PPPOT-IC (PASS), pre RST. PPPOT-T: Stung into test port(100 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely (1"). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely (1"). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 11/23/2016 min (PASS). Bled void to 0 psi. ***CONT FROM 11-22-16 WSR*** PULLED EMPTY WHIDDON C-SUB FROM 7090' SLM 11/23/2016 ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** ***WELL SHUT IN UPON ARRIVAL*** (SLB E-LINE UNIT 2362 -GYRO SURVEY) INITIAL T/I/O = 450/550/200 PSI. GYRO TOOL ZERO MEASUREMENT= 15.61'AT SWAB. LOG GYRO DATA FROM SURFACE TO 7105' ELMD (6'ABOVE PX PRONG), MAKING STATION STOPS EVERY 10 DEGREE CHANGE IN DEVIATION OR EVERY 20 MIN. LOG GYRO DATA FROM 7105' ELMD (-6' ABOVE PX PRONG) TO SURFACE, MAKING REPEAT STATION STOPS AT THE SAME INTERVALS AS THE DOWN PASS. GYRO TOOL RE-ZERO MEASUREMENT=4.10'AT SWAB FINAL T/I/O = 450/550/200 PSI. WELL SECURE. 11/28/2016 STAND BY ON PAD TO RIG UP ON NEXT WELL. Pumped down TBG through GLM#1 @ 6888' MD up IA leaving cement top @ —5300' MD in TBG/IA Note; two 7" foam balls were launched after pumping 3 bbls of fresh water behind cement stage. Foam balls at—5105' MD. Well freeze protected w/ Diesel to 3579' MD/2500' TVD Cement in place at 18:15 hours Location secured tags hung on Master and IA CSG valve. Valve crew contacted to service tree Note: 10-60 compliance info in fluids tab. Fluids in TBG & IA as follows: Diesel Surface- 3579' MD/2500'TVD 9.4 ppg Brine 3579' MD -5105' MD/3306' TVD Fresh Water-5105' MD -5300' MD/3409'TVD 15.8 ppg G Cement 5300' MD-6888' MD/4147'TVD ***Job Complete*** 12/2/2016 ***WELL S/I ON ARRIVAL***(drift&tag) RIG UP HALLIBURTON 214 12/3/2016 ***CONTINUED TO 12/04/16 WSR*** 12/4/2016 Assist Slickline. Did not rig up/stood by as contingency. • • L-200L2 Well History (Pre-Rig Sidetrack) L-200L2 ***CONTINUED FROM 12/03/16 WSR***(drift&tag) DRIFT 3.75"TO 5050' SLM ( NO SAMPLE ) BRUSHED TREE & BPV PROFILE WITH BLB RAN 3'x 1 7/8" STEM, 2" CENT., 1 3/4" SAMPLE BAILER ( OBTAINED SAMPLE OF CEMENT) RAN 3.7" DUMMY GUN TO 4300' SLM ATTEMPT CMIT x IA TO 3000 PSI;FAIL ATTEMPT MIT x OA;FAIL 12/4/2016 ***CONTINUED TO 12/05/16 WSR*** ***CONTINUED FROM 12/04/16 WSR***(drift&tag) ATTEMPT TO GET PASSING CMIT x IA TO 3000 PSI; FAIL 12/5/2016 ***WELL LEFT S/I ON DEPARTURE*** Initial T/I/O= 17/17/77 psi. (Pre-Rig Testing) CMIT TxIA **PASSED per APE** (2 attempts). Max Applied Pressure=3300 psi, Target Pressure=3000 psi. Used 2.3 bbls of Diesel to pressure TBG/IA from 0/0 psi to 3255/3267 psi. 1st 15 min TxIA lost 83/59 psi, 2nd 15 min TxIA lost 47/52 psi, 3rd 15 min TxIA lost 32/48 psi, 4th 15 min TxIA lost 24/45 psi. total loss of 186/204 psi in 60 min. As per FB WSL, bleed TxIA back to 12/21 psi (2.8 bbls). Attempt 2nd CMIT-TxIA: Pumped 6 bbls of diesel to reach test pressure, 1st 15 min TxIA lost 94/109 psi, 2nd 15 min TxIA lost 41/60 psi, 3rd 15 min TxIA lost 28/50 psi, 4th 15 min TxIA lost 22/45 psi. total loss of 185/264 psi in 60 min.. Bled back 3.5 bbls. Town notifies data is good enough. MIT-OA to 1200 psi ***FAILED*** Pumped 10 bbls of diesel down the OA to establish LLR of.5 bpm at 1250 psi. Hung tags and AFE sign. SV,WV,SSV=closed IA,OA=OTG 12/5/2016 Final T/I/O = 136/48/90 psi. ***JOB STARTED 7-DEC-2016***(SLB ELINE TUBING CUT) ARRIVE ON LOCATION. PROBLEMS WITH UNIT DELAY JOB START. INITIAL T/I/O = 0/0/300 RIH W/ HEAD/WEIGHT(CENTRALIZED)/CCL/WEIGHT/SHOCK SUBS(2 CENTRALIZERS)/FH/3.65" CUTTER; OAL= 33'; OAW= 330 LBS; MAX OD = 2.125" CUT TUBING AT 3556'. LOST APPROX 270 LBS TUBING PRESSURE ON CUTTING. TIED IN TO 4.5"TUBING TALLY DATED 20-NOV-2009. POOH. RIG DOWN. FINAL T/I/O = 0/0/280. 12/8/2016 ***JOB COMPLETE 8-DEC-2016*** ***JOB STARTED 7-DEC-2016***(SLB ELINE TUBING CUT) INITIAL T/I/O = 0/0/300 JET CUT TUBING AT 3556'. LOST APPROX 270 LBS TUBING PRESSURE ON CUTTING. TIED IN TO 4.5"TUBING TALLY DATED 20-NOV-2009. POOH. RIG DOWN. 12/8/2016 FINAL T/I/O = 0/0/280. T/I/O =6/0/280 Temp. =S/I (SIDETRACK) CMIT TxIA**PASSED After reveiw**to 3128/3113 psi, Max applied pressure= 3300/3300 psi. Target pressure= 3000/3000 psi. Pumped 3.72 bbls diesel to achieve test pressure for CMIT TxIA. 1st 15 min TxIA lost 93/92 psi. 2nd 15 min TxIA lost 62/61 psi for a total loss of 155/153 psi in 30 min. Bled TxIAP, bled back —2.8 bbls. Caution and info tags hung on IA and MV. AFE sign on MV. 12/9/2016 RDMO. SV/SSV=Closed, MV=Open, IA/OA=OTG, AL=Closed. FWHPS= 30/8/290 T/I/O = SSVNac/250. Temp = SI. Eval RG-2401 in cellar(Ops call-in). ALP = 0 psi, SI @ CV. Blue Goo is present in the cellat at several locations around wellhead. The outside of the conductor is free of Blue Goo except from the 7 to 11 o'clock position on the lower half. Top of RG 2401 is 12" deep in the conductor void. No activity in conductor 12/11/2016 at this time. • • L-200L2 Well History (Pre-Rig Sidetrack) L-200L2 T/I/O = SSV/Vac/240. Temp = SI. Bleed OAP to 0 psi & hold open bleed for shift. (Pre- Rig). OA FL @ Surface. Bled OAP to 0 psi in 10 minutes (20 gallons of fluid returned), 12/16/2016 Hold open bleed untill end of shift. Continued on WSR 12-17-16. Continued from WSR 12-16-16. T/I/O = SSVNac/0. Temp = SI. Bleed OAP to 0 psi & hold open bleed for shift. (Pre- Rig). OA FL @ Surface. Bled OAP to 0 psi in 10 minutes (20 gallons of fluid returned), Hold open bleed untill end of shift. Held open bleed for 7 hours 10 minutes. SI, rig down 12/17/2016 & monitor for 30 minutes. No change in WHP's during 30 minute monitor. Final WHP's = T/I/O = SSVNac/30. Temp = SI. WHP's. (Post OA bleed). OA FL @ Surface. OAP increased 30 psi overnight. WH removed. 12/18/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 02:40 T/I/O = 200/0/100. Set 4" CIW TWC#438 @ 120", set good. Performed LTT on TWC (Passed). N/D 4-1/8"x 4-1/16" CIW upper tree w/Baker actuator. N/U temp SV#21, dryhole conversion. N/U OA piggyback#11 & IA piggyback#74. See Log for details. 12/20/2016 RDMO ***Job Complete""" FWHP's =TWC/0/100 T/I/O = TWCNac/100. Temp = SI. Bleed OAP to 0 psi (Pre Rig). OA FL @ surface. Bled OAP to BT from 100 psi to 4 psi in 5 min (Fluid, —2 gal). Monitored for 30 min. OAP increased 4 psi. Final WHPs = TWCNac/8. 12/24/2016 SV= C. MV= O. IA, OA= OTG. 14:00 T/I/O = TWCNac/30. Temp = SI. WHPs (post bleed). Well house, Flowline &AL removed. IAP unchanged, OAP increased 22 psi overnight. 12/25/2016 SV= C. MV= O. IA, OA= OTG. 09:30 T/I/O = TWC/VAC/50. Temp = SI. WHPs (post bleed). Well is disconnected from the system, no well house, flowline or AL. Well has a dry hole configuration rigged up, IA& OA have 2nd gate valves rigged up. IAP unchanged, OAP increased 20 psi overnight. Temporary floor being installed around well head @ this time. 12/27/2016 SV= C. MV= O. IA, OA= OTG. 01:45 T/I/O = TWCNac/??. Temp = SI. Install gauges on IA/OA(Ops request). Well is disconnected from the system. Drilling wellhouse installed. IA& OA both have 2nd valves on them and gauges installed. The solid well house floor is in a way where you can't see or get to the OA gauge without removing the grating and snaking under the floor (need confine space permit). Will need lots of tubing or some hard line to make the valve 1/9/2017 an ease to access. • • North America-ALASKA-BP Page 1 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB @95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/24/2017 18:00 - 21:00 3.00 RIGD P PRE BEGIN RON EVENT WITH PARKER RIG 272 AT 18:00 HRS ON 01/24/2017. SKID RIG FLOOR TO RIG MOVE POSITION 1-LOWER PIPECAT AND SKID HAUNCH SKID RIG FLOOR TO CENTER LOWER MAST TO RACK:390K LBS ON RACK -PREP MODULES FOR SEPARATION 21:00 - 22:30 1.50 MOB P PRE SEPARATE MODULES AND MOVE OFF L-03A WELL. ,MOVE MODULES TO OTHER SIDE OF PAD 22:30 - 00:00 1.50 MOB P PRE REMOVE WELLHEAD AND TOOLS FROM WELL L-03A FROM BOP DECK PICK UP AND STAGE WELLHEAD AND TREE FOR L-200A ON BOP DECK PRIOR TO MOVING OVER WELL PERFORM WELDING AND REPAIR PROJECTS ON DRILL MODULE -CUT FLOWLINE AND INSTALL REDUNDANT FLOW METER WORK ON BLIND SHEAR RAM CHAMBERS, REPLACING SEALS. 1/25/2017 00:00 - 02:30 2.50 MOB P PRE MOVE UTILITY MODULE AND STAGE ON FAR END OF PAD. CONTINUE PERFORM WELDING AND REPAIR {PROJECTS ON DRILL MODULE: I-CUT FLOWLINE AND INSTALL REDUNDANT FLOW METER -WORK ON BLIND SHEAR RAM CHAMBERS, REPLACING SEALS. 02:30 - 06:30 4.00 MOB P PRE MOVE AND SPOT DRILL MODULE,MUD MODULE AND UTILITY MODULE OVER L-200A AND SHIM TO LEVEL. 06:30 - 14:30 8.00 RIGU P PRE GENERAL RIG UP OPERATIONS: -HOOK UP INTERCONNECTS AND SECURE MODULES RAISE MAST;554K LBS OFF THE RACK SKID RIG FLOOR AND HAUNCH TO DRILL POSITION -INSTALL MUD,CEMENT AND BLEEDER LINES -BRIDLE DOWN -RIG UP RIG FLOOR EQUIPMENT -TAKE ON FLUIDS AND CALIBRATE PIT SENSORS 14:30 - 15:00 0.50 RIGU P PRE HOLD H2S/RIG EVACUATION DRILL/AARAND PRESPUD MEETINGS WITH RIG CREW. ACCEPT RIG AT 15:00 HRS ON L-200A 15:00 - 16:30 1.50 BOPSUR P PRE PRESSURE TWC WITH DIESEL -TEST FROM BELOW 250/3000 PSI FOR 5 CHARTED MIN EACH;GOOD TEST -TEST FROM ABOVE 250/3500 PSI FOR 5 CHARTED MIN EACH;GOOD TEST Printed 2/22/2017 10:52:30AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 2 of 23 T5 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.1/24/2017 End Date X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM 11Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB @95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 18:00 1.50 BOPSUR P PRE NIPPLE DOWN TREE AND ADAPTER FLANGE PER FMC REP -CLEAN AND INSPECT HANGER THREADS; GOOD. SIMOPS: PREP PIPESHED FOR RIG OPERATIONS AND LOAD DRILL PIPE IN PIPE SHED. 18:00 - 00:00 6.00 BOPSUR P PRE NIPPLE UP BOPE INSTALL HIGH PRESSURE RISERS, REPLACE 30"SPOOL WITH 24"SPOOL -NIPPLE UP BOPE STACK AND TORQUE ALL BOLTS TO SPEC -INSTALL FLOWLINEAND HOLE FILL LINES -INSTALL LOW PRESSURE RISER AND FLOW BOX -INSTALL TURN BUCKLES ON STACKAND AIR UP AIR BOOTS -OBTAIN RKBS SIMOPS: TEST CHOKE MANIFOLD VALVES 6,8,9 AND 12 FROM OPPOSITE DIRECTION OF NORMAL -BOP TEST.ADDED TO PROCEDURE TO CLOSE GAPS IDENTIFIED DURING RECENT AUDIT. 1/26/2017 00:00 - 00:30 0.50 BOPSUR P PRE CLEAN AND CLEAR RIG FLOOR,BOP DECK AND WELL HOUSE BEFORE RIGGING UP TO TEST BOPE 00:30 - 02:00 1.50 BOPSUR P PRE RIG UP TO TEST BOPE -MAKE UP 4"AND 5"TEST JOINTS -FILL SURFACE LINES AND EQUIPMENT AND PURGE AIR 02:00 - 03:00 1.00 BOPSUR P PRE HOLD RIG EVACUATION DRILL/AARAND PRESPUD MEETINGS WITH RIG CREW. 03:00 - 08:30 5.50 BOPSUR P PRE PERFORM INITIAL BOPE TEST ON WELL L-200A;250/3500 PSI FOR 5 CHARTED MIN EACH -PERFORM SHELL AND RE-TORQUE BOLTS ON FLANGES -TEST UPPER AND LOWER VBRS WITH 4" AND 5"TEST JOINTS -TEST ANNULAR WITH 4"AND 5"TEST JOINTS -FINISH TESTING ALL CHOKE MANIFOLD (VALVES -TEST RAM LOCKS ON UPPER,LOWER AND BLIND SHEAR RAMS -TEST GAS,PVTAND FLOW SHOWALARMS -FUNCTION TEST HIGH BYPASS AND ALL BOP COMPONENTS FROM BOTH REMOTE PANELS -TESTED AND VERIFIED ESD FUNCTIONING PROPERLY TEST WITNESS WAIVED BY AOGCC REPRESENTATIVE GUY COOK AT 01/25/2017 AT 20:01 ALL TESTS WITNESSED AND VERIFIED BY WSLAND RIG MANAGER SEE ATTACHED TEST CHARTS Printed 2/22/2017 10.52.30AM `AII depths reported in Drillers Depths" • North America-ALASKA-BP • Page 3 of 23 I Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay ' Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 09:00 0.50 BOPSUR P PRE RIG DOWN BOPE TEST EQUIPMENT -BLOW DOWN AND RIG DOWN ALL TEST LINES -BREAK DOWN AND LAY DOWN TEST JOINT AND TEST MANIFOLD 09:00 - 13:00 4.00 BOPSUR P PRE PULL AND LAY DOWN TWC -RIG UP DUTCH RISER,QUICK TEST SUB AND LUBRICATOR -PRESSURE TEST LUBRICATOR 250/3500 PSI FOR 5/5 MIN LEAK TIGHT TEST;GOOD TEST -PULL TWC AND LAY DOWN -RIG DOWN LUBRICATOR,QUICK TEST SUB AND DUTCH RISER TO PIPE SHED 13:00 - 14:30 1.50 PULL P DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT THROUGH CUT AT 3581'MD(3557'+ DIFFERENCE IN RKB) -RIG UP TO CIRCULATE DIESEL OUT TO FLOWBACK TANK -CIRCULATE DOWN THE IA,TAKING RETURNS FROM THE TUBING:55 BBLS;5 BPM;430 PSI CIRCULATE DOWN THE TUBING,TAKING RETURNS OUT THE IA:95 BBLS;7 BPM;525 PSI -CONTINUE CIRCULATING TO CLEAN UP IA; PUMP TOTAL OF 200 BBLS WITH 200 BBLS RETURNED TO FLOWBACK TANK -MONITOR WELL FOR 10 MIN;STATIC -BLOW DOWN AND RIG DOWN ALL LINES 14.30 - 15:30 1.00 PULL P DECOMP PULL TUBING HANGER TO RIG FLOOR -MAKE UP XO TO HANGER TO LANDING JOINT AND RUN IN THE HOLE -MAKE UP XO TO HANGER WITH 7 TURNS -BACK OUT LOCK DOWN SCREWS PER FMC -PULL HANGER TO FLOOR;70K LBS TO PULL OFF SEAT;PU 66K/SO 62K 15.30 - 16:00 0.50 PULL P DECOMP CIRCULATE WELL CLEAN -PUMP A BARAKLEAN SWEEP,SURFACE TO SURFACE -10 BPM;250 PSI -MONITOR WELL FOR 10 MIN;STATIC SIMOPS: RIG UP CASING EQUIPMENT AND I-WIRE SPOOLER ON RIG FLOOR 16:00 - 20:30 4.50 PULL P DECOMP PULL AND LAY DOWN 4-1/2",VAMTOP TUBING WITH I-WIRE FROM 3581'MD. -PU 65K/SO 62K -MONITOR WELL WITH TRIPTANK;PROPER FILL -LAY DOWN THE FOLLOWING: 83 FULL JOINTS OF 4-1/2"TUBING 2 PUP JOINTS(7' AND 9') 1 X-NIPPLE ASSEMBLY 1 GLM ASSEMBLY 1 CUT JOINT(5.20') 43 CANNON CLAMPS 3 HALF CLAMPS -CUT WAS CLEAN AND EVEN WITH MINIMAL FLARE OBSERVED. Printed 2/22/2017 10:52.30AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 4 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) ' Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor.PARKER DRILLING CO. BPUOI: Active datum:L-200AACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 20:30 - 22:00 1.50 (ft) PULL P DECOMP RIG DOWNAND TUBING HANDLING EQUIPMENT AND TONGS RIG DOWN SLB SPOOLING UNIT CLEAN AND CLEAR RIG FLOOR INSTALL 9"ID WEAR RING AND RUN IN 4 LOCK DOWN SCREWS 22:00 - 22:30 0.50 PULL P DECOMP SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 22:30 - 23:30 1.00 CUT P DECOMP PICKUP AND MAKE UP SLB HYDRAULIC CASING CUTTER DRESSED TO CUT 7-5/8" CASING 23:30 - 00:00 0.50 CUT P DECOMP RUN IN THE HOLE WITH SLB 7-5/8" HYDRAULIC CASING CUTTER,PICKING UP 4" DRILL PIPE SINGLE FROM THE PIPE SHED TO 90'MD -MONITOR WELL WITH TRIPTANK;PROPER DISPLACEMENT 1/27/2017 00:00 - 04:00 4.00 CUT P DECOMP RUN IN THE HOLE WITH SLB 7-5/8" HYDRAULIC CASING CUTTER,PICKING UP 4" DRILL PIPE SINGLES FROM THE PIPE SHED FROM 90'MD AND TAG TUBING STUMP AT 3581'MD -MONITOR WELL WITH TRIP TANK;PROPER DISPLACEMENT 04:00 - 05:30 1.50 CUT P DECOMP CUT 7-5/8"CASING WITH SLB HYDRAULIC CASING CUTTER -ESTABLISH PARAMETERS:PU 72K LBS,SO 66K LBS,1.5 BPM,130 PSI -PUMP AT 1-1.5 BPM TO OPEN KNIVES. SLACK OFF SLOWLY TO LOCATE 7-5/8"BTC-M CASING COLLAR AT 3545'MD -CLOSE KNIVES AND RUN IN HOLE TO CUT DEPTH OF 3555'MD(10'BELOW CASING COLLAR) -CUT 7-5/8"CASING PER SLB FISHING REP: 1-3 BPM;150-570 PSI;70 RPM;2-4K FT-LBS TORQUE -POSITIVE INDICATION OF CUT WITH OA PRESSURE INCREASING FROM 150 TO 330 IPS! -CONTINUE TO ROTATE FOR AN ADDITIONAL 20 MINS Printed 2/22/2017 10:52:30AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 5 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:OOAM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 08:30 3.00 CUT P DECOMP CIRCULATE DEAD CRUDE FROM 7-5/8"X 10-3/4"ANNULUS TO FLOWBACK TANK WITH 9.2 PPG BRINE -FLOW CHECK WELL FOR 10 MIN PRIOR TO CIRCULATING,STATIC LINE UP OA TO FLOWBACK TANK THROUGH CHOKE SKID CLOSE ANNULAR PREVENTER AND CIRCULATE DOWN DRILL STRING AND OUT THROUGH 7-5/8"CUT -PUMP 30 BBL BARAKLEAN PILLAND 170 BBLS 9.2 PPG BRINE AT 3 BPM,700 PSI (SURFACE TO SURFACE VOLUME+40 BBLS) -ATTEMPT TO INCREASE PUMP RATE TO 4-5 BPM BUT SEE PRESSURE INCREASE RAPIDLY TO 900 PSI,PUMP AT 3 BPM FOR REMAINDER OF CIRCULATION -SHUT DOWN PUMPS AND MONITOR WELL FOR 15 MIN,PRESSURE ON IA GAUGE SHOWING MINOR TRAPPED PRESSURE UNDER ANNULAR PREVENTER.CIRCULATE 10 BBLS TWICE MORE WITH PRESSURE DECREASING EACH TIME.SUSPECT BRINE OUT OF BALANCE WITH FREEZE PROTECT FLUID. -DISCUSS TRAPPED PRESSURE WITH WSUP AND ODE,RECEIVE APPROVAL TO OPEN ANNULAR PREVENTER AND MONITOR WELL -FLOW CHECK FOR 30 MIN,STATIC -SIGNS OF DEAD CRUDE ON TOP OF FLUID COLUMN,DECISION MADE TO CIRCULATE AN ADDITIONAL BOTTOMS UP TO CLEAN UP FREEZE PROTECT PRIOR TO INITIAL CIRCULATION,NOTIFY WSUP AND WOM OF THE POTENTIAL OF GAS BREAKING OUT FROM DEAD CRUDE(PER ENTRAINED GAS GLOBAL ACTIONS) 08:30 - 09:30 1.00 CUT P DECOMP CIRCULATE BOTTOMS UP TO CLEAN UP 7-5/8" X 10-3/4"ANNULUS -DUMP RETURNS TO CUTTINGS BOX DUE TO PRESENCE OF DEAD CRUDE IN FLUID -170 GPM,1080 PSI -FLOW CHECK WELL FOR 10 MIN,STATIC 09:30 - 10:00 0.50 CUT P DECOMP FREEZE PROTECT APPEARS TO BE SWAPPING WITH BRINE.MONITOR WELL FOR 30 MIN TO ALLOW FLUIDS TO SWAP. 10:00 - 10:30 0.50 CUT P DECOMP CIRCULATE BOTTOMS UP TO CLEAN UP 7-5/8" X 10-3/4"ANNULUS -DUMP RETURNS TO CUTTINGS BOX DUE TO PRESENCE OF DEAD CRUDE IN FLUID -170 GPM,1080 PSI -FLUID CLEANED UP VERY QUICKLY, DECISION MADE TO PROCEED WITH PULLING OUT OF HOLE WITH HYDRAULIC CUTTER ASSEMBLY -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM,STATIC Printed 2/22/2017 10:52:30AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 6 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 12:00 1.50 CUT P DECOMP PULL OUT OF HOLE WITH 7-5/8"HYDRAULIC CUTTER ASSEMBLY FROM 3555'MD ON ELEVATORS -MONITOR THE WELL WITH THE TRIP TANK, PROPER DISPLACEMENT -MUD WEIGHT 9.2 PPG IN/OUT 12:00 - 13:30 1.50 CUT P DECOMP LAY DOWN 7-5/8"HYDRAULIC CUTTER ASSEMBLY CLEAN AND CLEAR RIG FLOOR 13:30 - 14:30 1.00 BOPSUR P DECOMP CHANGE UPPER RAMS FROM 2-7/8"X 5" VBRS TO 7-5/8"FBRS -CLOSE BLIND SHEAR RAMS,RUN IN RAM LOCKS AND DE-ENERGIZE ACCUMULATOR -MONITOR WELL VIA IAAND OA PRESSURES -RE-ENERGIZE ACCUMULATOR AFTER CHANGING RAMS 14:30 - 16:00 1.50 BOPSUR P DECOMP TEST 7-5/8"UPPER RAMS TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 CHARTED MINUTES (PASS) -SEE ATTACHED PRESSURE TEST CHART 16:00 - 17:30 1.50 FISH P DECOMP PULL 7-5/8"CASING HANGER -MAKE UP 7-5/8"SPEAR ASSEMBLY PER SLB FISHING REP -RUN IN HOLE WITH SPEAR AND ENGAGE HANGER -BACK OUT LDS PER FMC REP -PULL HANGER TO THE FLOOR(HANGER CAME FREE AT 120K LBS,STRING WEIGHT 112K LBS WITH BLOCKS AND TOP DRIVE) 17:30 - 18:30 1.00 FISH P DECOMP CIRCULATE WELL CLEAN WITH 1.5 BOTTOMS UP -5 BPM,220-270 PSI 18:30 - 22:00 3.50 FISH P DECOMP LAY DOWN 7-5/8"BTC-M CASING FROM CUT AT 3555'MD -LAY DOWN 7-5/8"CASING SPEAR AND HANGER -LAY DOWN TOTAL OF 85 FULL JOINTS,2 X 15'PUP JOINTS AND 10.83'CUT JOINT -MONITOR WELL WITH TRIP TANK,PROPER DISPLACEMENT -SEE ATTACHED PICTURE OF CUT JOINT 22:00 - 23:00 1.00 FISH P DECOMP RIG DOWN DOYON CASING,CLEAN AND CLEAR RIG FLOOR,PERFORM RIG SERVICE 23:00 - 23:30 0.50 BOPSUR P DECOMP CHANGE UPPER RAMS FROM 7-5/8"FBRS TO 2-7/8"X 5"VBRS -CLOSE BLIND SHEAR RAMS,RUN IN RAM LOCKS AND DE-ENERGIZE ACCUMULATOR -MONITOR WELL VIA IAAND OA PRESSURES -RE-ENERGIZE ACCUMULATOR AFTER CHANGING RAMS 23:30 - 00.00 0.50 BOPSUR P DECOMP TEST 2-7/8"X 5"UPPER RAMS TO 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED 1 MINUTES TEST WITH 4"AND 5"TEST JOINTS 1/28/2017 00:00 - 02:00 2.00 BOPSUR P DECOMP CONTINUE TESTING 2-7/8"X 5"UPPER RAMS TO 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES(PASS) -TEST WITH 4"AND 5"TEST JOINTS -SEE ATTACHED PRESSURE TEST CHART 02:00 - 04:00 2.00 CLEAN P DECOMP CHANGE OUT SAVER SUB FROM HT-38 TO NC50 Printed 2/22/2017 10:52:30AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 7 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date. 1/24/2017 End Date X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 I Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor.PARKER DRILLING CO. BPUOI: Active datum:L-200AACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth , Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 CLEAN P WEXIT MAKE UP 9-7/8"CLEAN OUT ASSEMBLY FROM SURFACE TO 270'MD WITH USED 8-1/2" 'ROLLER CONE BIT,TWO 9-7/8"SLICK WATERMELON MILLS,DRILLING JARS AND ACCELERATOR JARS 05:00 - 06:30 1.50 CLEAN P WEXIT RUN IN HOLE WITH 9-7/8"CLEANOUT ASSEMBLY FROM 270'TO 428'MD ON 5" NC-50 DRILL PIPE ON ELEVATORS ENCOUNTER OBSTRUCTION AT 428'MD BIT ,DEPTH -ABLE TO WORK THROUGH OBSTRUCTION TWICE WITH 10K LBS DOWN AND NO OVERPULL WHEN PICKING UP -UNABLE TO WORK THROUGH ON THIRD ATTEMPT -CONTACT WSUP AND ODE AND MAKE DECISION TO PULL OUT OF HOLE TO CHANGE CLEANOUT ASSEMBLY 06:30 - 07:00 0.50 CLEAN P WEXIT PULL OUT OF HOLE WITH 9-7/8"CLEANOUT ASSEMBLY FROM 428'TO 270'MD ON ELEVATORS -PERFORM FLOW CHECK PRIOR TO PULLING OFF BOTTOM,STATIC 07:00 - 08:30 1.50 CLEAN P WEXIT RECONFIGURE 9-7/8"CLEANOUT BHAAND RUN IN HOLE FROM SURFACE TO 256'MD -LAY DOWN BOTH 9-7/8"WATERMELON MILLS -NEW BHA IS 8-1/2"BIT WITH JARS 08:30 - 09:30 1.00 CLEAN P WEXIT SINGLE IN THE HOLE WITH 8-1/2"CLEANOUT ASSEMBLY FROM 270'TO 900'MD ON ELEVATORS -NO ISSUES RUNNING TO 900'MD(DEEPEST li EXPECTED SUBSIDENCE DEPTH) 09:30 - 10:00 0.50 CLEAN P WEXIT PULL OUT OF HOLE WITH 8-1/2'CLEANOUT ASSEMBLY FROM 900'TO 270'MD ON ELEVATORS -PERFORM FLOW CHECK PRIOR TO PULLING OFF BOTTOM,STATIC 10:00 - 10:30 0.50 CLEAN P WEXIT SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 10:30 - 11:00 0.50 CLEAN P WEXIT RECONFIGURE 9-7/8"CLEANOUT BHAAND RUN IN HOLE FROM SURFACE TO 265'MD -PICK UP ONE 9-7/8"WATERMELON MILL -NEW BHA IS 8-1/2"BIT WITH ONE 9-7/8" WATERMELON MILL AND JARS 11:00 - 16:00 5.00 CLEAN P WEXIT SINGLE IN THE HOLE WITH 9-7/8"CLEANOUT ASSEMBLY FROM 265'TO 3555'MD ON ELEVATORS NO ISSUES RUNNING TO BOTTOM -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 16:00 - 17.00 1.00 CLEAN P WEXIT TAG 7-5/8"CASING STUB AT 3555'MD AND CIRCULATE BOTTOMS UP TO CLEAN UP WELLBORE -14 BPM,600 PSI,10 RPM,5K FT-LBS TORQUE SPR:3553'MD,3113'TVD,MW 9.2 PPG -MP1 :30/40 SPM 25/42 PSI -MP2:30/40 SPM 26/43 PSI Printed 2/22/2017 10.52:30AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 8 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date X3-017P7(3,319,251 00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) 17:00 - 18:30 1.50 CLEAN P WEXIT PULL OUT OF HOLE WITH 9-7/8"CLEANOUT ASSEMBLY FROM 3555'TO 265'MD ON ELEVATORS -PERFORM FLOW CHECK PRIOR TO PULLING OFF BOTTOM,STATIC 18:30 - 19:30 1.00 CLEAN P WEXIT RACK BACK DRILL COLLARS AND LAY DOWN 9-7/8"CLEANOUT BHA PER SLB REP CLEAN AND CLEAR RIG FLOOR IN PREPERATION TO RIG UP E-LINE 19:30 - 22:00 2.50 CLEAN N WAIT 3,580.6 WEXIT WAIT ON SLB E-LINE -SIMOPS:BUILD STANDS OF 5"NC50 DRILL PIPE OFFLINE 22:00 - 00:00 2.00 DHB P WEXIT RUN EZSV/GR/CCL ON E-LINE -MOBILIZE TOOLS TO RIG FLOOR AND MAKE UP EZSV -RUN IN HOLE ON E-LINE 1/29/2017 00.00 - 02.00 2.00 DHB P WEXIT CONTINUE RIGGING UP SLB E-LINE -HOLD PJSM WITH E-LINE CREWAND RIG TEAM FOR RIG UP AND LOGGING -NO PRESSURE CONTROL,ONLY INTEGRAL LINE WIPER AND CUTTER APPROVED BY WSUP PER 100204 SECTION 5.4.1.5 -LOAD TOOLS TO RIG FLOOR AND MAKE UP TOOLSTRING 02:00 - 06:00 4.00 DHB P WEXIT RUN AND SET EZSV ON E-LINE -TIE INTO PDC LOG AND LOCATE COLLARS -SET EZSV(CENTER ELEMENT)AT 3400'MD IN COMPETENT SV2 SHALE(6'ABOVE COLLAR AT 3406'MD) -POSITIVE INDICATION OF SET AND WEIGHT DROP ON TOOLSTRING OBSERVED -PULL OUT OF HOLE WITH E-LINE IN PREPERATION FOR USIT RUN -MONITOR WELL WITH CONTINUOUS CIRCULATION OVER TOP OF WELL-NO LOSSES 06:00 - 00:00 18.00 EVAL N DPRB 409.6 WEXIT RUN USIT LOG IN CORROSION/CEMENT MODE TO EVALUATE 10-3/4"CASING DAMAGE (SUSPECTED SUBSIDENCE)AND CEMENT QUALITY AT KICK OFF POINT -LOG ENTIRE 10-3/4 CASING INTERVAL FROM EZSV AT 3400'MD TO SURFACE -MAKE REPEAT PASSES PER PETROPHYSICIST FOR IMPROVED DATA QUALITY OVER CERTAIN CRITICAL INTERVALS,INCLUDING OBSTRUCTION SEEN AT 410'MD WITH FIRST CLEANOUT ASSEMBLY AND KICK OFF POINT AT 3375'MD -MONITOR WELL WITH CONTINOUS CIRCULATION OVER TOP OF WELL-NO LOSSES -SEE FULL DETAILS OF TOOLSTRING AND TIME BREAKDOWN IN E-LINEAWGRS REPORT FOR 01/29-01/30 -PRELIMINARY ASSESMENT SUGGESTS CASING DAMAGE AT 410'MD,REPEAT PASSES MADE IN ATTEMPT TO EVALUATE SEVERITY DAMAGE AND RISK OF RUNNING MILLING ASSEMBLY PAST OBSTRUCTION -SEE ATTACHED PETROPHYSICIST INTERPRETATION SLIDES Printed 2/22/2017 10:52 30AM *AII depths reported in Drillers Depths" • North America-ALASKA-BP Page 9 of 23 t .' Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. i BPUOI: Active datum:L-200A ACTUAL RKB @95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/30/2017 00:00 - 06:30 6.50 EVAL N DPRB 409.6 WEXIT CONTINUE RUNNING USIT LOG IN CORROSION/CEMENT MODE TO EVALUATE 10-3/4"CASING DAMAGE(SUSPECTED SUBSIDENCE)AND CEMENT QUALITY AT KICK OFF POINT -MONITOR WELL WITH CONTINOUS CIRCULATION OVER TOP OF WELL-NO LOSSES -SEE FULL DETAILS OF TOOLSTRING AND TIME BREAKDOWN IN E-LINEAWGRS REPORT FOR 01/29-01/30 06:30 - 07:30 1.00 EVAL N DPRB 409.6 WEXIT LAY DOWN WIRELINE TOOLS AND RIG DOWN E-LINE. 07:30 - 10:30 3.00 CLEAN N DPRB 409.6 WEXIT PICKUP SLB TRI-MILL ASSEMBLY PER SLB FISHING REP.TO DRIFT 10-3/4"CASING FOR WHIPSTOCK RUN WITH ACTUAL MILLING ASSEMBLY TO 296'MD -PU 55K/SO 58KAT 296'MD -ENCOUNTERED TIGHT HOLE AT 257'MD, ABLE TO WORK THROUGH WITH 8K LBS DOWN,ROTATING PIPE 1/4 TURN AT TIME WHEN FREE.WORK THROUGH SEVERAL TIMES UNTIL DRAG REDUCED TO AN EVEN 5K. -ENCOUNTERED TIGHT HOLE AT 293'MD ATTEMPT TO WORK DOWN WITH 10K LBS DOWN AND 5K OVERPULL TO PULL OUT. UNABLE TO WORK PAST 296'MD. -PICK UP UNTIL FREE AND CIRCULATE BOTTOMS UP;7 BPM,145 PSI -OBSERVE SCALE,GROUND UP FORMATION SAND AND FREEZE PROTECT SOLIDS ON SHAKERS. 10.30 - 12:00 1.50 CLEAN N DPRB 409.6 WEXIT PULL UP ABOVE TIGHT SPOTS AND MONITOR WELL WHILE DISCUSSING PLAN FORWARD OPTIONS WITH ODE AND WSUP. 12:00 - 13:30 1.50 CLEAN N DPRB 409.6 WEXIT PULL OUT OF THE HOLE AND LAY DOWN THE SLB TRI-MILL ASSEMBLY -MONITOR THE WELL W/TRIPTANK:GOOD HOLE FILL -CLEAN AND CLEAR RIG FLOOR 13:30 - 14:30 1.00 CLEAN N DPRB 409.6 WEXIT PERFORM ASSURANCE PRESSURE TEST ON 10-3/4"CASING AND EZSV:250/1000 PSI FOR 5/15 MIN -1.2 BBLS TO PRESSURE UP;BLED BACK 1.1 BBLS TO TRIP TANK -GOOD TEST -BLOW DOWN AND RIG DOWN TEST EQUIPMENT 14:30 - 16:00 1.50 CLEAN N DPRB 409.6 WEXIT PICKUP AND RUN IN THE HOLE WITH SLB DRIFT ASSEMBLY TO 266'MD ,-PU 55K/SO 57K i-MONITOR DISPLACEMENT W/TRIPTANK; GOOD DISPLACEMENT Printed 2/22/2017 10:52.30AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 10 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB(895.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:00 1.00 CLEAN N DPRB 409.6 WEXIT WASH DOWN WITH DRIFT ASSEMBLY FROM i 266'MD TO 298'MD 7 BPM;50 PSI -OBSERVE 3K DRAG FROM 266'MD TO 298' MD -SET DOWN 10K AT 298'MD AND ATTEMPT TO WORK THROUGH WITH NO SUCCESS DISCUSS OPTIONS WITH ODE AND WSUP 17:00 - 18:00 1.00 CLEAN N DPRB 409.6 WEXIT PULL OUT OF THE HOLE AND LAY DOWN DRIFT ASSEMBLY -MONITOR THE WELL W/TRIPTANK;GOOD HOLE FILL -CLEAN AND CLEAR RIG FLOOR 18:00 - 18:30 0.50 CLEAN P 409.6 WEXIT ,SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 18:30 - 21:00 2.50 CLEAN N DPRB 409.6 WEXIT MOBILIZE TOOLS FROM"SLB DEADHORSE -MONITOR WELL WITH TRIP TANK;STATIC -PERFORM GENERAL MAINTENANCE ON RIG WHILE WAITING. 21:00 - 22:30 1.50 CLEAN N DPRB 409.6 WEXIT PICKUP AND MAKEUP SLB DRIFT ASSEMBLY WITH TWO 9.75"OD STRING STABILIZERS PU 65K/SO 65K AT 367'MD MONITOR WELL W/TRIPTANK;GOOD DISPLACEMENT -MINOR 2K DRAG NOTED AT 290'MD 22:30 - 00:00 1.50 CLEAN N DPRB 409.6 WEXIT CONTINUE TO RUN IN THE HOLE WITH DRIFT ASSEMBLY FROM 367'MD TO 2735'MD -PU 94K/SO 80K AT 2735'MD -FILL PIPE EVERY 20 STANDS -OBSERVED 5K DRAG FROM 1030'MD TO 1050'MD -MONITOR WELL W/TRIPTANK;GOOD DISPLACEMENT 1/31/2017 00:00 - 00:30 0.50 CLEAN N DPRB 409.6 WEXIT RUN IN HOLE WITH 9-3/4"STABILIZER ASSEMBLY FROM 2735'TO 3390'MD ON ELEVATORS -FILL PIPE EVERY 20 STANDS -NO ISSUES RUNNING TO BOTTOM -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT Printed 2/22/2017 10:52:30AM *All depths reported in Drillers Depths* 110 11111 North America-ALASKA-BP Page 11 of 23 fr Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 05:00 4.50 CLEAN N DPRB 409.6 WEXIT CIRCULATE THE WELL CLEAN WITH A TOTAL OF 10 BOTTOMS UP -CIRULATE FIRST 5 BOTTOMS UP AT 550 GPM,770 PSI.SOME SCALE,FORMATION SAND AND FREEZE PROTECT SOLIDS SEEN THROUGHOUT CIRCULATION,WITH 80-100 PSI INCREASE IN PUMP PRESSURE AS SOLIDS WERE COMING UP THE BACKSIDE -CIRCULATE SECOND 5 BOTTOMS UP AT 700 GPM,1150 PSI -PUMP 30 BBL HIGH VIS SWEEP AND DUMP AT SURFACE,NO INCREASE IN CUTTINGS/SCALE NOTED OVER SHAKERS -PUMP 30 BBL EP MUD LUBE SWEEP AND DUMP BACK INTO THE ACTIVE SYSTEM -OBTAIN FREE ROTATING TORQUE BEFORE AND AFTER PUMPING EP MUDLUBE SWEEP I -BEFORE:20 RPM=4.5K FT-LBS,30 RPM =6.2K FT-LBS -AFTER:20 RPM=4.5K FT,30 RPM=5.1K FT-LBS SPRS,3400'MD,MW 9.2 PPG -MP1 :30/40 SPM 30/56 PSI -MP2:30/40 SPM 30/55 PSI 05.00 - 06:00 1.00 CLEAN P 409.6 WEXIT PERFORM KICK WHILE DRILLING(D2)DRILL AND FULL WELL KILL(D5)DRILL,HOLD AAR WITH CREW IN LER 06:00 - 08:00 2.00 CLEAN N DPRB 409.6 WEXIT PULL OUT OF HOLE WITH 9-3/4"STABILIZER ASSEMBLY FROM 3390'TO 367'MD ON ELEVATORS -MONITOR WELL FOR 15 MIN PRIOR TO PULLING OFF BOTTOM,STATIC -TIGHT SPOT NOTED AT 1030'MD WITH 7K LBS OVERPULL -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 08:00 - 09:30 1.50 CLEAN N DPRB 409.6 WEXIT RACK BACK DRILL COLLARS AND LAY DOWN 9-3/4"STABILIZER ASSEMBLY FROM 367'MD TO SURFACE -ENCOUNTER TIGHT SPOT AT 350'MD WITH 7K OVERPULL -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 09:30 - 10:00 0.50 CLEAN N DPRB 409.6 WEXIT CLEAN AND CLEAR RIG FLOOR AND RIG DOWN SLB FISHING 10:00 - 12:00 2.00 CLEAN N DPRB 409.6 WEXIT PERFORM DIAGNOSTIC PRESSURE TEST OF 10-3/4"CASING TO 250 PSI LOW FOR 5 MIN/ 2000 PSI HIGH FOR 30 MIN(PASS) THIS DOES NOT REPLACE THE 2400 PSI PRESSURE TEST REQUIRED PER OCN#3 AND PERMIT TO DRILL,BUT SERVES TO PROVIDE ASSURANCE THAT THE WELL HAS ,ADEQUATE INTEGRITY TO WARRANT CONTINUING WITH OPERATIONS i-LOST 20 PSI IN FIRST 15 MINUTES AND 10 PSI IN SECOND 15 MINUTES. -TEST WITNESSED BY WSLAND RIG MANAGER,AND APPROVED BY WSUP -SEE ATTACHED PRESSURE TEST CHART AND CALCULATOR Printed 2/22/2017 10:52.30AM `AII depths reported in Drillers Depths* • 4111 North America-ALASKA-BP Page 12 of 23 b Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) i Start Date:1/24/2017 End Date X3-017P7(3,319,251 00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. I BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 12:30 0.50 CLEAN P WEXIT LUBRICATE RIG AND SERVICE RIG FLOOR EQUIPMENT 12:30 17:30 5.00 CLEAN N DPRB 409.6 WEXIT WAIT ON BAKER FISHING TOOLS(DECISION MADE TO RUN BAKER WHIPSTOCK AND MILLING ASSEMBLY DUE TO ABILITY TO SPACE OUT MILLS AND INCREASE BHA FLEXIBILITY) SIMOPS:CLEAN AND ORGANIZE RIG, PERFORM PREVENTATIVE MAINTENANCE 17:30 - 19:00 1.50 CLEAN N DPRB 409.6 WEXIT PICKUP BAKER TOOLS TO PIPE SHED. MEASURE,CALIPER,INSPECT AND VERIFY TOOLS. 19:00 - 20:30 1.50 CLEAN N DPRB 409.6 WEXIT MAKE UP 9-7/8"BAKER MILLING BHA FROM SURFACE TO 270'MD TO PERFORM DRIFT RUN -MILLING ASSEMBLY IS 9-3/4"WINDOW MILL, 9-1/2"LOWER STRING MILL,8'FLEX JOINT AND 9-7/8"UPPER STRING MILL -ENCOUNTER DRAG FROM 252'-270'MD WITH 4-10K LBS DOWN 20:30 - 22:30 2.00 CLEAN N DPRB 409.6 WEXIT WORK DOWN WITH 9-7/8"BAKER MILLING ASSEMBLY FROM 270'TO 305'MD -WORK DOWN TO 300'MD WITH MAXIMUM OF 10K LBS DOWN,UNABLE TO MAKE FURTHER PROGRESS -COME ONLINE WITH PUMPS AND WASH DOWN TO 305'MD WITH DIFFICULTY -300 GPM,75 PSI 22:30 - 23:00 0.50 CLEAN N DPRB 409.6 WEXIT PULL OUT OF HOLE WITH 9-7/8"BAKER MILLING ASSEMBLY FROM 305'TO 270'MD ON ELEVATORS AND ADD 15'PUP JOINT BETWEEN LOWER AND UPPER STRING MILLS (TOTAL DISTANCE BETWEEN MILLS=23') -MONITOR WELL FOR 15 MIN PRIOR TO PULLING OFF BOTTOM,STATIC -TIGHT SPOT NOTED AT 295'MD WITH 10K LBS OVERPULL -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 23:00 - 00 00 1.00 CLEAN N DPRB 409.6 WEXIT RUN IN HOLE WITH 9-7/8"INCREASED-FLEX BAKER MILLING ASSEMBLY FROM 270'TO 350'MD ON ELEVATORS -WORK DOWN FROM 285'TO 380'MD WITH 10K LBS DRAG 2/1/2017 00:00 - 02.00 2.00 CLEAN N DPRB 409.6 WEXIT WORK DOWN WITH 9-7/8"INCREASED-FLEX BAKER MILLING ASSEMBLY FROM 350'TO 424'MD -WORK DOWN WITH MAXIMUM OF 10K LBS DOWN,UNABLE TO MAKE FURTHER PROGRESS -WASH DOWN AT 600 GPM,270 PSI-NO FURTHER PROGRESS Printed 2/22/2017 10.52:30AM `AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 13 of 23 Operation Summary Report Common Well Name.L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 , Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO BPUOI: Active datum:L-200AACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 02:30 0.50 CLEAN N DPRB 409.6 WEXIT PULL OUT OF HOLE WITH 9-7/8" INCREASED-FLEX BAKER MILLING ASSEMBLY FROM 350'TO 270'MD ON ELEVATORS TO PICK UP 9-3/4"MILLING BHA -ENCOUNTER 5-7K LBS OVERPULLAT 400' AND 300'MD -LAY DOWN 9-7/8"UPPER STRING MILL AND 15 PUP JOINT -PICK UP 9-3/4"UPPER STRING MILL -NEW MILLING ASSEMBLY IS 9-3/4"WINDOW MILL,9-1/2"LOWER STRING MILL,8'FLEX JOINT AND 9-3/4"UPPER STRING MILL 02:30 - 06:00 3.50 CLEAN N DPRB 409.6 WEXIT RUN IN HOLE WITH 9-3/4"BAKER MILLING ASSEMBLY FROM 270'TO 990'MD ON ELEVATORS -ENCOUNTER OBSTRUCTION AT 300'MD AND WORK DOWN TO 430'MD WITH 5-10K LBS DOWN -NO ISSUES FROM 430'TO 970'MD • -WASH DOWN FROM 975'TO 990'MD AT 500 GPM,280 PSI.ABLE TO MAKE SLOW PROGRESS WITH ERRATIC DRAG AT 5-10K LBS DOWN.NO PROGRESS PAST 990'MD. DECISION MADE TO PULL OUT OF HOLE WITH MILLING ASSEMBLY. 06:00 - 07:30 1.50 CLEAN N DPRB 409.6 WEXIT PULL OUT OF HOLE WITH 9-3/4"BAKER MILLING ASSEMBLY FROM 990'TO 613'MD ON ELEVATORS -DIFFICULTY PULLING FROM 990'TO 975'MD WITH CONSISTENT 5-10KLB OVERPULLS -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT -WHILE PULLING OUT OF HOLE,WELL APPEARED TO BE TAKING A SMALLAMOUNT OF FLUID.TRIP SHEET SHOWED WELL TO BE STATIC,BUT THE DECISION WAS MADE TO MONITOR WELL ON SURFACE TO VERIFY IT WAS STATIC. 07:30 - 08:30 1.00 CLEAN N DPRB 409.6 WEXIT RACK BACK 5"HWDP AND DRILL COLLARS AND LAY DOWN 9-3/4"BAKER MILLING ASSEMBLY FROM 613'MD TO SURFACE -ENCOUNTER 5-10KLB OVERPULLS THROUGHT TIGHT SPOTS AT 550-520'MD AND 420-380'MD -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT Printed 2/22/2017 10:52:30AM *All depths reported in Drillers Depths* North America-ALASKA-BP • Page 14 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. I BPUOI: Active datum:L-200AACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 09:30 1.00 CLEAN N DPRB 409.6 WEXIT PERFORM FLOW CHECK AT SURFACE TO ENSURE WELLBORE IS STATIC.FLUID LEVEL WAS RISING VERY SLOWLY SUCH THAT A TRICKLE OF BRINE WAS FALLING OVER THE EDGE OF THE BELL NIPPLE.SHUT-IN THE WELL WITH BLIND SHEAR RAMS. -MONITOR PRESSURES AT CHOKE:SIDPP= -0 PSI,SICP=0 PSI -FILL MUD GAS SEPERATOR OFFLINE -AFTER BLIND SHEARS WERE SHUT, TRICKLE FROM BELL NIPPLE REMAINED UNCHANGED WITH ZERO PRESSURE BUILDING UNDER BLIND SHEARS -FURTHER INVESTIGATION SHOWED THAT PIT WATCHER HAD BEEN PUMPING OUT TRIP TANK IN PREPERATION FOR UPCOMING TRIP IN HOLE.HOLE FILL LINE WAS ISOLATED FROM PUMP WITH BUTTERFLY VALVE,AND BUTTERFLY VALVE HAD DEVELOPED A SLOW LEAK. -TRANSFER PUMP WAS SHUT DOWN AND FLOW STOPPED COMPLETELY DISCUSSED SITUATION WITH WSUP AND RECEIVED APPROVAL TO OPEN CHOKE TO MUD GAS SEPERATOR AND MONITOR WELL FOR 15 MIN-STATIC -COMMUNICATED RESULTS OF FLOW CHECK TO WSUP AND RECEIVED APPROVAL TO OPEN BLIND SHEARS AND MONITOR WELL FOR 15 MIN-STATIC -APPROVAL TO PROCEED GRANTED FROM WSUP 09.30 - 10:00 0.50 CLEAN N DPRB 409.6 WEXIT MAKE UP 9-3/4"BAKER MILLING ASSEMBLY WITH INCREASED FLEXIBILITY FROM SURFACE TO 627'MD TO PERFORM DRIFT RUN -MILLING ASSEMBLY IS 9-3/4"WINDOW MILL, 9-1/2"LOWER STRING MILL,8'FLEX JOINT, 15'PUP JOINT AND 9-3/4"UPPER STRING MILL -ENCOUNTER TIGHT SPOTS AT 275'AND 395' MD WITH 5-10K LBS DOWN 10:00 - 13.30 3.50 CLEAN N DPRB 409.6 WEXIT RUN IN HOLE WITH 9-3/4"BAKER MILLING ASSEMBLY FROM 627'TO 3400'MD ON ELEVATORS -ENCUNTER TIGHT SPOT FROM 975'-1005' MD AND WASH DOWN AT 500 GPM,280 PSI WITH 5-10K LBS DOWN -WORK THROUGH TIGHT SPOT 3 TIMES -NO ISSUES RUNNING IN HOLE FROM 1005' TO 3400'MD -TAG EZSV ON DEPTH AT 3400'MD -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 13:30 - 14:00 0.50 CLEAN N DPRB 409.6 WEXIT CIRCULATE BOTTOMS UP -550 GPM,460-480 PSI Printed 2/22/2017 10.52.30AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 15 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 1/24/2017 End Date: •X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB c©95.7it(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 15:00 1.00 CLEAN P 409.6 WEXIT DISPLACE WELL FROM 9.2 PPG BRINE TO 9.2 PPG LSND MILLING FLUID -515 GPM,ICP=375 PSI,FCP=400 PSI TAKE SLOW PUMP RATES AFTER DISPLACEMENT:3400'MD,MW 9.2 PPG -MP1:30 SPM=102 PSI,40 SPM=120 PSI MP2:30 SPM=102 PSI,40 SPM=122 PSI 15:00 - 17:00 2.00 CLEAN N DPRB 409.6 WEXIT PULL OUT OF HOLE WITH 9-3/4"BAKER MILLING ASSEMBLY FROM 3400'TO 627'MD ON ELEVATORS -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM-STATIC -FINAL PICK UP/SLACK OFF WEIGHT ON BOTTOM:PU 102K LBS,SO 87K LBS -ENCOUNTER TIGHT SPOT AT 1005'-975'MD WITH 5-10K LBS OVER.ABLE TO WORK THROUGH TWICE. -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 17:00 19:00 2.00 CLEAN N DPRB 409.6 WEXIT RACK BACK 5"HWDPAND DRILL COLLARS AND LAY DOWN 9-3/4"BAKER MILLING ASSEMBLY FROM 613'MD TO SURFACE ENCOUNTER 5-10KLB OVERPULLS THROUGHT TIGHT SPOTS AT 550-520'MD ,AND 420-380'MD -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 19:00 - 21:00 2.00 CLEAN N DPRB 409.6 WEXIT MAKE UP 9-3/4"BAKER WINDOW MILL/ WHIPSTOCK RUNNING DRIFT ASSEMBLY FROM SURFACE TO 860'MD TO PERFORM DRIFT RUN -DUE TO TIGHT SPOTS,DECISION MADE TO RUN BAKER WHIPSTOCK ON PILOT MILL ONLY AND THEN PICK UP REMAINDER OF WINDOW MILLING ASSEMBLY ON SUBSEQUENT TRIP -MILLING ASSEMBLY IS 9-3/4"WINDOW MILL AND MWD FOR ORIENTING WHIPSTOCK -NO DRAG ENCOUNTERED RUNNING IN HOLE 21:00 - 21:30 0.50 CLEAN N DPRB 409.6 WEXIT RUN IN HOLE WITH 9-3/4"BAKER WINDOW 1 MILL/WHIPSTOCK RUNNING DRIFT 'ASSEMBLY FROM 860'TO 1100'MD ON ELEVATORS -NO DRAG ENCOUNTERED RUNNING IN HOLE -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT -SHALLOW HOLE TEST MWD TOOL AT 1100' MD,BAD TEST.MWD WILL BE CHANGED OUT AND RE-TESTED AT SURFACE. 21:30 - 22:30 1.00 CLEAN N DPRB 409.6 WEXIT PULL OUT OF HOLE WITH 9-3/4"BAKER WINDOW MILL/WHIPSTOCK RUNNING DRIFT ASSEMBLY FROM 1100'TO 860'MD NO DRAG ENCOUNTERED PULLING OUT OF HOLE -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT Printed 2/22/2017 10:52:30AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 16 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB @95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 CLEAN N DPRB 409.6 WEXIT RACK BACK 5"HWDP AND DRILL COLLARS AND LAY DOWN 9-3/4"BAKER WINDOW MILL/ WHIPSTOCK RUNNING DRIFT ASSEMBLY FROM 860'MD TO SURFACE -CHANGE OUT MWD AND TEST AT SURFACE, GOOD TEST 2/2/2017 00:00 08:00 8.00 STWHIP P WEXIT MAKE UP 9-3/4"BAKER WHIPSTOCK ASSEMBLY FROM SURFACE TO 1254'MD -WHIPSTOCK WILL BE RUN AND SET ON ' ,WINDOW MILLAND MWD,REMAINDER OF MILLING ASSEMBLY WILL BE PICKED UP ON SUBSEQUENT TRIP -BOTTOM ANCHOR PINNED FOR 19.9K LBS +/-15%(16.9-22.9K LBS),SHEAR BOLT SET AT 51K LBS l i ' -RUN IN HOLE PER BAKER REP AND I PROCEDURE WITH MAXIMUM SLACK OFF I WEIGHT SET AT 3K LBS DOWN TRIPPING LIMITS:30 FPM FROM SURFACE I TO 1100'MD,40 FPM FROM 1100'TO 3400'MD -ENCOUNTER TIGHT SPOT FROM 260'TO 300'MD,ABLE TO WORK THROUGH WITH 1-3K LBS DRAG ENCOUNTER TIGHT SPOT FROM 390'TO ' 399'MD,ABLE TO WORK DOWN WITH 1-3K LBS DRAG BUT FURTHER PROGRESS WAS NOT POSSIBLE -CONTACT ODE AND MAKE DECISION TO ATTEMPT TO WASH DOWN -WASH DOWN FROM 399'TO 440'MD WITH 500 GPM,400-500 PSI.ABLE TO MAKE SLOW, CONSITENT PROGRESS.PUMP PRESSURE IS ERRATIC(NO PACKING OFF),POTENTIALLY VIBRATING TOOLS AND ACTING TO BREAK STATIC FRICTION. -ON INITIAL PUMPS ON,TFO WAS+125°. WHILE WASHING DOWN,TFO GRADUALLY CHANGED TO+70°INDICATING SIGNIFICANT BUCKLING FROM 399'TO 440'MD. NO ISSUES RUNNING IN HOLE FROM 440' TO 545'MD ON ELEVATORS -WASH DOWN FROM 545'TO 555'MD WITH 500 GPM,430-530 PSI, IDENTICAL OBSERVATIONS IN PUMP PRESSURE AS ABOVE ' -NO ISSUES RUNNING IN HOLE FROM 555' TO 1005'MD ON ELEVATORS -WASH DOWN FROM 1005'TO 1030'MD AT 500 GPM,515-600 PSI,IDENTICAL OBSERVATIONS IN PUMP PRESSURE AS ABOVE Printed 2/22/2017 10:52:30AM *All depths reported in Drillers Depths* s North America-ALASKA-BP Page 17 of 23 Operation Summary Report1�'�. Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251 00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI. Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 11:00 3.00 STWHIP P WEXIT RUN IN HOLE WITH 9-3/4"WHIPSTOCK ASSEMBLY FROM 1254'TO EZSV AT 3400'MD -ON ELEVATORS WITH NO ISSUES FROM 1254'TO 1620'MD -ENCOUNTER OBSTRUCTION AT 1620'MD, WASH DOWN TO 1720'MD AT 500 GPM, 600-700 PSI WITH 3-5K LBS DOWN ON ELEVATORS WITH NO ISSUES FROM 1720'TO 3235'MD -WASH DOWN FROM 3235'TO 3400'MD AND ORIENT WHIPSTOCK TO-44°TFO PER BAKER I FISHING REP -TAG EZSV ON DEPTH AT 3400'MD 11.00 - 12:00 1.00 STWHIP P WEXIT SET WHIPSTOCKAT 3400'MD,44°LEFT OF HIGHSIDE(-44°TFO) -SLACK OFF TO SET WHIPSTOCK ANCHOR, POSITIVE INDICATION OF SHEAR AT 20K LBS DOWN -PICK UP TWICE TO 6K LBS OVER TO CONFIRM WHIPSTOCK IS SET AND ANCHOR IS HOLDING -SLACK OFF TO SHEAR MILL OFF WHIPSTOCK,POSITIVE INDICATION OF SHEAR AT 41K LBS DOWN CALCULATED TOWS=3375'MD,BOWS= 3395'MD 12:00 14.00 2.00 STWHIP N J DPRB 410.0 WEXIT PULL OUT OF HOLE WITH 9-3/4"MILL ASSEMBLY FROM 3400'TO 1254'MD ON ELEVATORS -FLOW CHECK WELL FOR 10 MIN PRIOR TO j PULLING OFF BOTTOM,STATIC -NO ISSUES WHILE PULLING OUT OF HOLE -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 14:00 - 16:00 2.00 STWHIP N DPRB 410.0 WEXIT RACK BACK 5"HWDPAND DRILL COLLARS, LAY DOWN 9-3/4"MILLING BHA PER BAKER REP -NO ISSUES WHILE PULLING OUT OF HOLE -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING NON-SHEARABLES THROUGH STACK,STATIC -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT Printed 2/22/2017 10:52.30AM "All depths reported in Drillers Depths* • North America-ALASKA-BP Page 18 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200AACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 00:00 8.00 BOPSUR P WEXIT PERFORM BOPE TEST TO 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MIN EACH -PERFORM SHELL TEST -TEST UPPER AND LOWER VBRS WITH 4" AND 5"TEST JOINTS -TEST ANNULAR WITH 4"AND 5"TEST JOINTS TEST SUPER CHOKE/MANUAL CHOKE TO 2000 PSI -TEST RAM LOCKS ON UPPER,LOWER AND BLIND SHEAR RAMS -TEST GAS,PVT AND FLOW SHOW ALARMS -FUNCTION TEST HIGH BYPASS AND ALL BOP COMPONENTS FROM BOTH REMOTE PANELS -TESTED AND VERIFIED ESD FUNCTIONING PROPERLY -FUNCTION TEST ANNULAR PRESSURE INCREASE/DECREASE TEST WITNESS WAIVED BYAOGCC REPRESENTATIVE MATT HERRERAAT 02/02/2017 AT 15:48 .ALL TESTS WITNESSED AND VERIFIED BY WSL AND RIG MANAGER SEE ATTACHED TEST CHARTS 2/3/2017 00:00 - 02:00 2.00 STWHIP N DPRB 410.0 WEXIT MAKE UP 9-3/4"BAKER WINDOW MILLING ASSEMBLY FROM SURFACE TO 830'MD -MILLING ASSEMBLY IS 9-3/4"WINDOW MILL, 9-1/2"LOWER STRING MILL,8'FLEX JOINT, 15'PUP JOINT,9-3/4"UPPER STRING MILL -THIS ASSEMBLY WAS SUCCESSFULLY RAN TO BOTTOM ON 02/01/17 -ENCOUNTER TIGHT SPOT AT 400'MD WITH 10K LBS DOWN,ABLE TO WORK THROUGH WITHOUT PUMPS -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 02:00 - 03:30 1.50 STWHIP N DPRB 410.0 WEXIT RUN IN HOLE WITH 9-3/4"BAKER WINDOW MILLING ASSEMBLY FROM 830'TO 10-3/4" WHIPSTOCK AT 3375'MD ON ELEVATORS -NO ISSUES FROM 830'TO 1005'MD -ENCOUNTER TIGHT SPOT AT 1005'-1030' MD WITH 10K LBS DOWN,ABLE TO WORK THROUGH WITHOUT PUMPS -NO ISSUES FROM 1030'TO 3375'MD -TAG WHIPSTOCK AT 3375'MD,ON DEPTH -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT Printed 2/22/2017 10:52:30AM "All depths reported in Drillers Depths* • North America-ALASKA-BP Page 19 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12.00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. _ BPUOI: Active datum:L-200AACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 09:00 5.50 STWHIP N DPRB 410.0 WEXIT ATTEMPT TO PRESSURE TEST 10-3/4" CASING TO 250 PSI LOW FOR 5 MIN/2000 PSI HIGH FOR 30 MIN PER OCN#10 -FINAL MECHANICAL INTEGRITY TEST PRIOR TO MILLING WINDOW REQUIRED PER PTD/ AOGCC -ATTEMPT LOW(250 PSI)PRESSURE TEST, PRESSURE BLED OFF FROM 300-200 PSI IN 8 MIN -PRESSURE UP TO 420 PSI,PRESSURE BLED DOWN TO 250 PSI OVER 12 MIN -CHECK SURFACE SYSTEMS,ISOLATE PRESSURE TEST TO PUMP#2 -PRESSURE UP TO 600 PSI,PRESSURE BLED DOWN TO 350 PSI OVER 8 MIN -CONTACT ANCHORAGE TEAM,DECISION MADE TO PICK UP RTTS TO DETERMINE LEAK POINT 09:00 - 10:30 1.50 STWHIP N DPRB 410.0 WEXIT PULL OUT OF HOLE WITH 9-3/4"MILL ASSEMBLY FROM 3375'TO 830'MD ON ELEVATORS -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM,STATIC ENCOUNTER TIGHT SPOT AT 1005'MD WITH 10K LBS OVER -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 10:30 - 11.30 1.00 STWHIP N DPRB 410.0 WEXIT RACK BACK 5"HWDP AND DRILL COLLARS, LAY DOWN 9-3/4"MILLING BHA PER BAKER REP -ENCOUNTER TIGHT SPOT AT 395'MD WITH 5K LBS OVER -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING NON-SHEARABLES THROUGH STACK,STATIC -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 11:30 - 12:00 0.50 STWHIP N DPRB 410.0 WEXIT ATTEMPT TO PERFORM DIAGNOSTIC PRESSURE TEST ON 10-3/4"CASING TO 500 PSI(FAIL) -SHUT BLIND/SHEAR RAMS AND PRESSURE UP ON WELLBORE VIA KILL LINE Printed 2/22/2017 10:52:30AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 20 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB @95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 19:00 7.00 STWHIP N DPRB 410.0 WEXIT SEARCH FOR LEAKS IN 10-3/4"CASING WITH RTTS(PER OCN#11) PICK UP AND MAKE UP 10-3/4"RTTS AND RUN IN HOLE ON 5"DRILL PIPE -SET AT 850'MD,TEST ABOVE TO 250 PSI LOW/2000 PSI HIGH FOR 5 MIN EACH(PASS) -SET AT 1235'MD,ATTEMPT TO TEST. I PRESSURE BROKE OVER AND BLED OFF AT 450 PSI PRESSURE TESTING HAS ESTABLISHED THAT LEAK POINT IS BETWEEN 850'AND 1235'MD -PULL OUT OF HOLE WITH RTTS,LAY DOWN 5"HWDP AND RTTS MONITOR HOLE VIA TRIP TANK WHILE TRIPPING,GOOD DISPLACEMENT 'HOLD MEETING WITH ANCHORAGE TEAM. INTEGRITY IN 10-3/4"CASING ABOVE BASE PERMAFROST(2200'MD)WAS PREVIOUSLY ESTABLISHED AS BOUNDARY CONDITION FOR CONTINUING WITH OPERATIONS.THUS, 'WITH LEAK POINT NOW ESTABLISHED BETWEEN 850'AND 1235'MD,DECISION MADE TO SUSPEND OPERATIONS. 19:00 - 00:00 5.00 STWHIP N DPRB 410.0 WEXIT PREPARE TO RIG DOWN AND MOVE OFF WELL L-200 -LAY DOWN DRILL COLLAR STANDS INSTALL THREAD PROTECTORS ON 7-5/8" CASING AND BEGIN TO OFFLOAD FROM PIPE SHED -CLEAR UNNEEDED TOOLS FROM RIG FLOOR AND PIPE SHED SIMOPS: —LAY DOWN DRILL PIPE OFFLINE SERVICE TOP DRIVE BLOCKS AND RIG FLOOR EQUIPMENT 2030 HRS-RECEIVE CALL FROM ODE ON POTENTIAL OF LEAK IN 10-3/4"BEING FROM ACCIDENTAL SHIFTING OPEN OF TAM PORT COLLAR(LOCATED AT 1001'MD BASED ON PARKER 272 RKB)WHILE WORKING WHIPSTOCK/MILLING ASSEMBLY THROUGH TIGHT SPOT.DECISION MADE TO ATTEMPT TO SHIFT PORT COLLAR CLOSED WITH PESI SHIFTING TOOL 2100 HRS-RECEIVE OCN#12 APPROVING PLAN TO ATTEMPT TO CLOSE TAM PORT COLLAR.CALL OUT PESI WHILE CONTINUING TO PREPARE FOR RDMO. 2/4/2017 00:00 - 01:30 1.50 STWHIP N DPRB 1,001.0 WEXIT RUN IN HOLE WITH TAM PORT COLLAR SHIFTING TOOL FROM SURFACE TO 1010'MD ON ELEVATORS -NO ISSUES WHILE RUNNING IN HOLE -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT Printed 2/22/2017 10:52:30AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 21 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 02:00 0.50 STWHIP N DPRB 1,001.0 WEXIT ENGAGE TAM PORT COLLAR WITH SHIFTING TOOL,PRESSURE TEST(FAIL),SHIFT COLLAR CLOSED,PRESSURE TEST(PASS) -ENGAGE COLLAR WITH 8K LBS DOWN AT 1010'MD -ATTEMPT TO PRESSURE UP AND SEE BREAK OVER AT 460 PSI PICK UP TO 10K LBS OVER TO CLOSE COLLAR AND PRESSURE TEST TO 500 PSI FOR 5 MIN(PASS) -DISENGAGE FROM COLLAR AND PICK UP ABOVE.PRESSURE TEST TO 500 PSI FOR 5 MIN(PASS) 02:00 - 03:00 1.00 STWHIP N DPRB 1,001.0 WEXIT PULLOUT OF HOLE WITH TAM PORT COLLAR SHIFTING TOOL FROM 1010'MD TO SURFACE ON ELEVATORS -MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM,STATIC -NO ISSUES PULLING OUT OF HOLE 03:00 - 04:00 1.00 STWHIP N DPRB 1,001.0 WEXIT PERFORM DIAGNOSTIC PRESSURE TEST OF 10-3/4"CASING TO 250 PSI LOW FOR 5 MIN/ 2000 PSI HIGH FOR 30 MIN(PASS) -LOST 7 PSI IN FIRST 15 MINUTES AND 2 PSI IN SECOND 15 MINUTES -TEST WITNESSED BY WSLAND RIG MANAGER,AND APPROVED BY WSUP -SEE ATTACHED PRESSURE TEST CHART AND CALCULATOR 04:00 - 07:00 3.00 STWHIP N DPRB 1,001.0 WEXIT DISCUSS PLAN FORWARD WITH ANCHORAGE TEAM.DESPITE DISCOVERING THAT THE LEAK IN THE 10-3/4"CASING WAS DUE TO OPEN TAM PORT COLLAR,THE DECISION WAS MADE TO RIG DOWN AND TEMPORARILY SUSPEND OPERATIONS ON L-200A UNTIL FURTHER ENGINEERING WORK IS COMPLETED. 07:00 - 08:30 1.50 TA N DPRB 1,001.0 WEXIT LAY DOWN DRILL PIPE:RUN IN HOLE WITH STACK WASHER ON 5"DRILL PIPE FROM SURFACE TO 3300'MD ON ELEVATORS -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 08:30 - 13:00 4.50 TA N DPRB 1,001.0 SURE LAY DOWN DRILL PIPE:SINGLE OUT OF HOLE WITH 5"DRILL PIPE FROM 3300'MD TO SURFACE ON ELEVATORS AND LAY DOWN TO PIPE SHED -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 13:00 - 14:30 1.50 TA N DPRB 1,001.0 SURE RUN IN HOLE WITH STACK WASHER ON 4" DRILL PIPE FROM SURFACE TO 3390'MD ON ELEVATORS -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 14:30 - 16:00 1.50 TA N DPRB 1,001.0 SURE DISPLACE WELL FROM 9.2 PPG LSND MILLING FLUID TO 9.3 PPG BRINE -600 GPM,ICP=960 PSI,FCP=900 PSI MONITOR WELL FOR 10 MIN AFTER DISPLACEMENT,STATIC TAKE SLOW PUMP RATES AFTER DISPLACEMENT:3390'MD,MW 9.3 PPG -MP1:30/40 SPM 50/80 PSI -MP2:30/40 SPM 52/85 PSI Printed 2/22/2017 10.52:30AM 'All depths reported in Drillers Depths* • 4110 North America-ALASKA-BP Page 22 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB @95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:00 1.00 TA N DPRB 1,001.0 SURE SLIP AND CUT 95'(12 WRAPS)OF DRILLING LINE,CALIBRATE BLOCKS AND AMPHION LSYSTEM _ 17:00 - 20:30 3.50 TA N DPRB 1,001.0 SURE LAY DOWN DRILL PIPE:SINGLE OUT OF HOLE WITH 4"DRILL PIPE FROM 3390'MD TO SURFACE ON ELEVATORS AND LAY DOWN TO PIPE SHED MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 20:30 - 21:00 0.50 TA P 1,001.0 SURE RIG SERVICE:LUBRICATE RIG 21:00 - 00:00 3.00 TA N DPRB 1,001.0 SURE RUN 4-1/2",12.6#,13CR-85,VAM TOP, CONDITION B TUBING(KILL STRING)FROM SURFACE TO 1719'MD AT MIDNIGHT -PULL WEAR RING AND RIG UP DOYON CASING -USE JET LUBE SEAL GUARD PIPE DOPE TORQUE CONNECTIONS TO 4400 FT-LBS, NO TORQUE TURN REQUIRED -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 2/5/2017 00:00 - 01:30 1.50 TA N DPRB 1,010.0 SURE CONTINUE RUNNING 4-1/2",12.6#,13CR-85, VAM TOP,CONDITION B TUBING(KILL STRING)FROM 1719'TO 3362'MD PUW-65,SOW-60K -USE JET LUBE SEAL GUARD PIPE DOPE -TORQUE CONNECTIONS TO 4400 FT-LBS, NO TORQUE TURN REQUIRED -MONITOR WELL VIA TRIP TANK,GOOD DISPLACEMENT 01 30 - 02:30 1.00 TA N DPRB 1,010.0 SURE MAKE UP TUBING HANGER AND LANDING JOINT AND LAND KILL STRING -RUN IN LOCK DOWN SCREWS PER FMC REPRESENTATIVE AND TORQUE GLAND NUTS -BACK OUTAND LAY DOWN LANDING JOINT. -RIG DOWN DOYON CASING 02:30 - 06:00 3.50 TA N DPRB 1,010.0 SURE REVERSE CIRCULATE 229 BBLS DIESEL FREEZE PROTECT TO 2500'MD -2 BPM WITH 250 PSI. MONITORING DISPLACEMENT FOR BBL IN FOR BBL OUT SIM OPS-LAYING DOWN DP OFFLINE,C/O UPPER&LOWER IBOP'S&SAVER SUB _ _ 06:00 - 07:00 1.00 TA N DPRB 1,010.0 SURE ALLOW FOR DIESEL TO U-TUBE AROUND. -CONTINUE TUBULAR HANDLING SIM OPS. 07:00 - 09:30 2.50 TA N DPRB 1,010.0 SURE INSTALL TWC WITH DRY-ROD PER FMC REPRESENTATIVE AND PRESSURE TEST -PJSM WITH FMC FOR DRY ROD OPERATION. RUN AND SET(H)STYLE TWC IN THE HOLE AND SET IN THE TUBING HANGER PROFILE. -PRESSURE TEST TWC AS DIRECTED IN WELL PLAN I-250 PSI LOW 5 MIN,2000 PSI HIGH 5 MIN, BOTH ABOVE AND BELOW THE TWC. -9.3 PPG NACL BRINE USED TO TEST -GOOD TEST -RIG DOWN PRESSURE TEST EQUIPMENT Printed 2/22/2017 10:52:30AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 23 of 23 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: X3-017P7(3,319,251 00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/30/2003 12:00:00AM Rig Release:2/6/2017 Rig Contractor:PARKER DRILLING CO. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 14:30 5.00 TA N DPRB 1,010.0 SURE NIPPLE DOWN BOPE -DRAIN STACK&BLOW DOWN SURFACE LINES.REMOVE BELL NIPPLE,LAY DOWN MOUSEHOLE,BREAK OUT BOP BOLTS AND RACK BACK BOP STACK. -LD HIGH PRESSURE RISER,CLEAN AND INSPECT WELLHEAD. 14:30 - 15:30 1.00 TA N DPRB 1,010.0 SURE 'NIPPLE UPADAPTER FLANGE AND DRY HOLE TREE -CLEAN AND INSPECT CONDITION B ADAPTER FLANGE NIPPLE UPAND TORQUE BOLTS ON ADAPTER FLANGE AND TREE 15:30 - 17:30 2.00 TA N DPRB 1,010.0 SURE PRESSURE TEST ADAPTER AND HANGER VOID WITH HYDRAULIC FLUID PER FMC REPRESENTATIVE 250/4500 PSI FOR 5/15 MIN. CHARTED -GOOD TEST,APPROVED BY ACTING WSUP, • SEE ATTACHED CHART. SIMOPS:UNPIN TOP DRIVE AND BRDAL UP, REMOVE ALL SURFACE LINES. -CUT AND SLIP 153'OF DRILLING LINE. 17:30 - 19:00 1.50 TA N DPRB 1,010.0 SURE PRESSURE TEST TREE 250/5000 PSI FOR 5 MIN EACH LEAK TIGHT TEST WITH DIESEL -GOOD TEST -BLEED OFF PRESSURE AND BLOW DOWN/ RIG DOWN ALL LINES -INSTALL 2 BOTTLES OF HEET IN TREE(TO PREVENT FREEZING). 19:00 - 00:00 5.00 TA N DPRB 1,010.0 SURE SECURE TREE AND CELLAR,CLEAN UP AND PREPARE FOR RIG MOVE TO L-200A SIMOPS: -PRE-SKID CHECK LIST,LOWER PIPE CAT. -SKID FLOOR TO DERRICK OVER POSITION. -LAY OVER DERRICK TO TRAVEL POSITION. RIG RELEASE FROM L-200AAT 00:00 HR ON 2/06/2017 Printed 2/22/2017 10'52:30AM `AII depths reported in Drillers Depths* I HEE= 4-1/16"CNV WELLHEAD= 11'FMC S US P E E DEl—iPL2OBSTRUCTIONS siltyNOTES: WELL ANGLE>70°@ 6602'. ACTUATOR= BAKER SEEN @ 300',420',8 OKB.ELEV= 77.6' 1,000'INSIDE THE 10-314"CSG*** RELEV= 77-6' 120#COM3 --,114' --I ) '� E= 986' H 10-3/4"TAM FORT COLLAR BE ELEV= 48.99' 4-1/2"KLL STRING —13362' KOP= 380' �_---- 3362' —14-1/2'NULESHOE,D=3.958" Max Angle= 96"@ 11569 TBG, 12.6#,13CR 85 Datum MD= 7515' VAM TOP COND B, 3376' 10-314"BKR VVE-DSTOCK(02/02/17) Datum ND= 4400,SS .0152 bpf,D=3.958" " 3400' —1.10-3/4"HES EZSV(01/29/17) 7-5/8"CSG CUT(01/27/17) --{ 3555' ' 4-1/2"CUT TBG(01/26/17) -H 3581' GAS LFT MANDRELS 10-314'CSG,45.5#,L-80,0=9.950" H 3871' ST MD ND DEV TYPE VLV LATCH PORT DATE ESTMATED TOC PLUG(12/02/16) --6060' "4 5373 3433 58 KBG2 DMY BK 0 07/03/11 *3 5490 3498 56 KBG2 DMY BK 0 11/21/09 Minimum ID = 3.813" @ 2174' • *2 6645 4068 69 KBG2 DMY BK 0 11/21/09 4-1/2" HES X NIPPLE : *1 6888 4157 69 KBG2 EMPTY BK - 11/22/16 7-518"X 9-7/8"TOC 5800' A00��IlkI1E *STA 4,3,2,&1 =COVERED BY CMT 41d IRA TAG I 6983' 4-1/2"SGM-NDPG-CA 7035' wsi57061'J--I4-1/2"BKR CMD SLIDING SLV,D=3.813" MULTI DROP SW,I)=3.958" 904/1110, 7087' H7-5/8"X 4-1/2'BKR PREM PKR ID=3.875" 4-1/2"SGMLNDPG-CA 7066' 'lli 7122' —14-112"FSS X NP,D=3.813" MULTI DROP SUB,ID=3.958" 7122' —14-1/2"PX PLUG(11/05/15) I 4-1/2"TBG,12.6#,13CR 80 VAM TOP 7250' 7193' --{4-1/2"FSS X NP,D=3.813" 0158 bpf,D=3 958" RA TAG 7270' t • 7264' H4-112"X 5-1/2'XO,ID=3.940" 4-112"TBG,12.6#L-80 BT-M, 7296' `..." P 7277' —5.75"BKR SEAL STEM ,, .0152 bpf,ID=3.958" , Ao (SEALS REMDVED),ID=4.83" 5-112"X 4-1/2"X0,D=3.930" 7301' 7282' H7-5/8"X 4-1/2"BKR ZXP LTP w fli K,ID=5.750" BAKER HOOK HANGER H 7315' L2 (OBa) L2{OBa)LEM WINDOW 65` w/L2 NON-SEALING LBM,ID=3.71" ` il 7320'-7331' COLLAPSED LEM-CAN NOT PASS BY H ^-7315 OBa PBTD —{ 13043' OPENING WIDTH=3 33" (SEB'I IN D.H.VIDEO)(12/14/12) RA TAG 7375' 7315'-13044' 6-3/4"OBa LATERAL,ID=3.958" 7-5/8"X 5-1/2"BKR ZXP LTP,D=4.94" 7386' 1 /7I 1 t PI 7398' —14-1/2"MULE SHOE,D=3.958" 5-1/2"X 4-1/2"XO,D=3.930" 7405' a L 1 (OBb)LEM WINDOW 64' BAKER HOOK HANGER —1 7419' J § L1 (OBb) 7424'-7435' OPENING WIDTH=3.33" wI L1 NON-SEALNGLEI,0=3.71" OBb PBTD H 12987' PERFORATION SUMMARY REF LOG: 7419'-12988' 6-3/4"0(3b LATERAL,ID=3.958" ANGLE AT TOP PERF: Note:Refer to Production 06 for historical pert data 07537' —17.5/8"X 5-1/2"BKR ZXP LNR TOP PKR SIZE SPF INTERVAL Opn/Sqz DATE MIK 4-1/2" SLID OBa 7392-13000 0 02/18/04 III 7548' —14-1/2"MULE SHOE,D=3.958" 4-1/2" SLID OBb 7497- 12944 0 02/12/04 4-1/2" SLTD OBd 7870- 13008 0 02/04/04 755T 5-1/2"x 4-1/2"XO,ID=3.930" 0 RA TAG 7663' IL-200 7572'-13052' 6-3/4"OBd LATERAL,ID=3.958" 7-5/8"CSG,29.7#,L-80 BTC-M,ID=6.875" H 7872' OBe PBTD — 13050' -- .`_ DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/22/04 N9ES ORIGINAL COMPLETION WE_L: L-200 11/25/09 D-16 RWO PERNTT No: 2040010(020)(030) 02/04/17 P272 SUSPENDED ST AR No: 50-029-23191-00(60)(61) 02/13/17 JMD DRLG HO CORRECTIONS SEC 34,T12N,R11 E,2567'FSL&1575'FEL 02/13/17 JT/JM) FINAL ODE APPROVAL BP Exploration(Alaska) • • v.OF Ty THE STATE ��\I%y �,, Alaska Oil and Gas fLeti Conservation Commission 4•04.7,, e....- -- 1,, ofALASKA i 'lrr: �� 333 West Seventh Avenue — cGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 SP Main: °FA :S Fax: 907.276.7542 WWW.aogcc.alaska.gov Ken Allen Drilling Supervisor SCANNED MAR , ..2017. BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU L-200L2 Permit to Drill Number: 204-003 Sundry Number: 317-068 Dear Mr. Allen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. . Sincerely, Coty ,QCathy Foerster Chair this GA— DATED day of February,2017. RBDIV1S l P' "2 - 1 204,7 • STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMM! APPLICATION FOR SUNDRY APPROV 20 MC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend f . Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-003 • Exploratory 0 Development H 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-23191-61-00 • 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No m PBU L-200L2 ' RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: FEB 0 6• ?017 ADL 028239&047447• PRUDHOE BAY.SCHRADER BLUFF OIL • DT-5 TS z.[,8 t? 11. PRESENT WELL CONDITION SUMMARY 2G CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(Fil 13115 • 4245 - 3375 2413 3375.3400.5050 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"X 34" 31-110 31 -110 Surface 3840 10-3/4" 31 -3871 31 -2668 5210 2480 Intermediate 3765 7-5/8" 3555-7320 2502-4329 6890 4790 Tieback Liner 38 4-1/2" 7282-7320 4313-4329 8430 7500 Liner 5729 4-1/2" 7315-13044 4327-4245 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7392-13000 4344-4225 4-1/2"12.6# 13Cr80 26-3362/3581-7281 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and TVD(ft): 7092/4240 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic B 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 ` Service 0 14.Estimated Date for Commencing Operations: February 4,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended H ' 16.Verbal Approval: Date: 2/4/2017 GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: Victoria Loepp GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Thompson,Jacob be deviated from without prior written approval. Email Jacob.Thompson@BP.com Printed Name Ken Allen��i9sllt-zr=sfC-A6✓�iTitle Drilling Supervisor e4i}vI Signature `G /�• � Phone +1 907 564 4366 Date d L/04407 ll// COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3k-1 — O Le Plug Integrity 0 BOP Test Ikr'-- Mechanical Integrity Test 0 Location Clearance 0i-Y ( Other: ?1 Zi Y -4 B�p fir, t- '.- 3 5-‘) ‘)c P 513 Post Initial Injection MIT Req'd? Yes 0 No CEK; Spacing Exception Required? Yes 0 No IJ Subsequent Form Required: /v — 4 U APPROVED Approved by:Ode*/ COMMISSIONER COMMISSION �HE Date ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. *(ffAttachments in Duplicate • 0 . 0 C . . -0 § 0 c 0 0.0 aic 2 0 k / cu DO CO 0 o . Cu COC § /k \ o > O lc o 0 o _� 2 0 0 oco ( Vi oo c / 0 - 3 / / 0 } e c E / % cu o 0_ —liii 3 . . \. E 2 S \c o 0 c, / 2 d a) 3 2 o \ = c c d q 2g ¥ coto CU ' 2 \ / o k o % CLL V u = ¥ \ / \ ƒ5 f f = / a. 0 a k [ f ƒFg r 5 c ■ o £ / U 0 0 a k ° R Cu ° I— V) _i cC cY U 0 2 ® § - a 0. 2 49_,) › E a) (NI -0 -0 I- 0 J 0 o \ a Z $ e ¢ f I- o # 00 j f k ° ƒ ƒ k - o � CI 3 to en in > > - _ % > 7 . k 4-, k q / k 2 O m / f s R ■ a E ' 2 ¥ o a) "IZ 144 R r. a, 0 7 § E > fID o u k \ k •f § n. ƒ c .0 0_ —I u. VI I— u u ■ 5 / 3 . � m $ It U U. In i CA a k / \ /. • 0 c o a) 0 i'. 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N o � zvocaaQ cnccmaa2a. 222E a � 2maz3 _, aao C O Q) a r-c N M Ln l� 1� 00 a) l. c5 a 1 rr 1 iM-1 N ami ate-' a I o-0 ami N N N N i-4 r4 mi N N N N N a) 3 •— � U > � U of a) _ U O 5 -0 0 va' E H a) • ! 0 2 2n N m m to > U, N w C co Y U 0 ++ 11/ t a c m ai co s •c a' n C .a` 0 cu C 'ZS .- in 0 O CO CU CCI _N aJ 0. 4-, 0. d0 u, co H O w - O U L H c a ma a a 0 .4- a, - f00 ° 0 n . a) -, c� a z � Eoi oa cu s Q0 +_ m s m .� N p I' O 0 Oa) Z 3 ., z i -0U Ci13 co co O 0,0 A U E t0 1-•1 4 U 4 N al N a) W sa. 4-1 m - co a b = M 4.t; � W co 3 Q � U 40. lei N — L 0 r "C.) 04 Q C t C r-I N m U 0 o .cu . N TREE,= ' 4-1/16"CNV .wa.IEAD= 11'FMC SUSPEADEDL,- OO S NOTES: WELL ANGLE>70.@ 6602'. ' ACTUATOR= BAKER L 1 L2 ~• G OBSTRUCTIONS SEEN @ 300',420'.& OKB.ELEV= 77.6' 1,000'INSIDE THE 10-3/4"CSG*" REF ELEV= 77.6' 20#COND -j114'I----I I BE ELEV= 48.99' ....' -y 986' -10-3/4_TAM PORT COLLAR KOP= 380' 4-1/2"CUT TBG H 3362' -1 3376' -110-3/4'BAKER W-tFSTOCK(_/_!_) Max Angle= 96°@ 11569' (12/08/16) Datum MD= 7515' L 3400' H10-3/4"HES EZSV(_I_/_) Datum TVD= 4400'SS 7-5/8"CSG CUT(_/_/_i H 3555' - 4-112"CUT TBG(_/ /_) -1 3581' / GAS LIFT MANDRELS 10-3/4"CSG,45.5#,L-80,D=9.950" H I 3871' 1 t ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3448 2436 60 KBG2 DMY BK 0 11/04/15 ESTIMATED TOC PLUG(12/02116) -5 5 3565 2495 60 KBG2 DMY BK 0 11/21/09 Minimum ID = 3.813" @ 2174' VIAXIIP SI It f4 5373 3433 58 KBG2 DM' BK 0 07/03/11 4-1/2" HES X NIPPLE 3 5490 3498 56 KBG2 DMY BK 0 11/21/09 • •+i �;•♦••+►_� I, +2 6645 4068 69 KBG2 DMY BK 0 11/21/09 7-518"X 9-718"TOC -1 5800' * " * *+~i�' :•;.: �► K. • *1 6888 4157 69 KBG2 EMPTY BK 11/22/16 �, 'STA4 3 2 &1=COVER®BY CMT RA TAG H 6983' •••��ti,"''•:; � � �i , 4-1/2"SGM-MDF G-CA -1 7035' r = {�.`�• _ 7061' -4-1/2"BKR CMD SLIDING SLV,D=3.813" MULTI-DROP SUB,D=3.958" �� .'''X'"::•',.:CNV e. a 7087' --17-5/8"X 4-1/2"BKR PREM PKR D=3.875" 4-1/2"SGM NDFG-CA 7066' % o 7122' -i4-112" X ,D=3.813" MLETLDROP SUB,ID=3.958" a 7122' H4-1/2"PX PLUG(11,05/15) 4-112"TBG,12.6#, 13CR-80 VAM TOP -1 7250' ,# ., 7193' -14-1/2"I-ES X MP,0=3.813" .0158 bpf,D=3.958" 7264' -1.4-1/2"X 5-1/2"XO,D=3.940" 1 RA TAG 7270' 4-1/2'TBG, 12.6#L-80 BT-M, 7296' 1. ; 7277' -5.75"BKR SEAL STEN .0152 bpf,ID=3.958" ; ,0 (SEALS REMOVED),13=4.83" 5-1/2"X4-1/2"XO,D=3.930" -1 7301' % Ai 7282' H7-5/8"X 4-1/2"BKR ZXP LTP w/TEBK,D=5.750' BAKER HOOK HANGER -1 7315' �J l L2 (013a) L2(OBa)LEM WNDOW 65` w/L2 NON-SEALING LEM,D=3.71" j 7320'-7331' \`" OPENING WIDTH=3 33" COLLAPSED LEN-CAN NOT PASS BY -1 ^-7315OBa PBTD -1 13043' r.q (SE$'J IN D.H.VIDEO)(12/14/12) *' RA TAG -1 7375' I---1111 7315'-13044' 6-3/4"OBa LATERAL,ID=3.958" 7-518"X 5-1/2"BKR ZXP LTP,13=4.94" - 7386' Y� '_,MI 7398' -14-1/2"MULE SHOE,D=3.958" 5-1/2'X 4-1/2'XO,D=3.930" -1 7405' 41118 L1 (OBb)LEM WINDOW 64 BAKER HOOK HANGER -1 7419' ii i L1 (OBb) 7424'-7435' - g OPENING WIDTH=3.33" w/L1 NON-SEALING LECA,D=3.71" tie OBb PB113 - 12987' PERFORATION SUMMARY ' , FIEF LOG: I v!. 7419'-12988' 6-3/4"OBb LATERAL,ID=3 958" ANGLE AT TOP PERE: Note:Refer to Production DB for historical pert data `• • 7537. _-17-518"X 5-1/2'BKR ZXP LNR TOP PKR SCE SPF MERVAL Opn/Sqz DATE 4-1/2" SLID OBa 7392-13000 0 02/18/04 iii \ 7548' -14-1/2"MULE SHOE,D=3.958" 4-1/2" SLID OBb 7497- 12944 0 02/12/04 01 4-1/2" SLID (384:i7870- 13008 0 02/04/04 y RA TAG H 7663' 7557' H5-1/2"X 4-1/2"XO,ID=3.930" li' IL-2001 7572'-13052' 6-3/4"OBd LATERAL,ID=3.958" 7-5/8"CSG,29.7#,L-80 BTC-M,ID=6.875" H 7872' OBd I PBTD - 13050' ' ,--_.,l I a DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/22/04 N9B5 ORIGINAL COMPLETION WH L: L-200 11/25/09 D-16 RVYO _ FERMf No: 2040010(020)(030) 02/04/17 P272 SUSPENDED ST API No: 50-029-23191-00(60)(61) 02106/17 JMD DRLG HO CORRECTIONS SEC 34,T12N,R11 E,2567'FSL 8 1575°FEL BP Exploration(Alaska) • SOF Tji gw4\�� I 1/7„. A THE STATE Alaska Oil and Gas Conservation Commission ___ AL ASIc:A r2 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov Ken Allen MR 0 2 Drilling Engineer NNEA ” ' BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU L-200L2 Permit to Drill Number: 204-003 Sundry Number: 316-506 Dear Mr. Allen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, t‘ti7Cath P. Foerster ,, , Chair DATED this 2hay of October, 2016. RBDMS k/1 OCT 2 4 2016 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N Hi:'I 0 3 ?01 APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 'd 1 2...c) ,,- 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate El Repair Well 0 C7 er�at ones shu'down 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill Q• Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-003 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development a• 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23191-61-00. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU L-200L2 • 9. Property Designation(Lease Number): 10. Field/Pools: .,'ejt_„► �4/4's Ck/,� ADL 028239&047447• PRUDHOE BAY,OIDN-OIL• ,c 4./‘.. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13115 • 4234 • 7122 4239 1840 7122 None Casing Length Size MD ND Burst Collapse Structural Conductor 78 20"X 34" 31-110 32-110 Surface 3840 10-3/4" 31 -3871 31-2653 5210 2480 Intermediate 7291 7-5/8" 29-7320 29-4318 6890 4790 Tieback Liner 38 4-1/2" 7282-7320 4302-4318 8430 7500 Liner 5729 4-1/2" 7315-13044 4316-4229 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7392-13000 4344-4225 4-1/2"12.6# 13Cr80 26-7281 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and TVD(ft): 7092/4229 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ® Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ® Exploratory 0 Stratigraphic 0 Development ®• Service 0 14.Estimated Date for Commencing Operations: October 15,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Thompson,Jacob be deviated from without prior written approval. Email Jacob.Thompson@BP.com Printed Name Ken Allen Title Drilling Supervisor I Signature -- Phone +1 907 5644366 Date /I / COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test'Err' Mechanical Integrity Test 0 Location Clearance ❑ Other: HOF, 1--z--,.5 f 1v 3 5-0D r 5 L 6% ,e- 1,�20,��. / f} l ier-�ato ,o l P/a 1 '' C f 6 ) . Post Initial Injection MIT Req'd Yes 0 No L. a/7/'�i o v cc) C►A .Z 4 f�C Z 5-. ) 1 Z ` Spacing Exception Required? Yes 0 NoG'Subsequent Form Required: / " Z C' q a‘et/ APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date:/0..26_/4 VTL- Ic/za/< OR IGINAL ,jio1/g4 RBDMS 1,k/ OCT 2 4 2010 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate /0, S 7,/G b G P6ji giferrillS10e Sir L-2O0L2 Sundry Application Well Type: Producer Current Status: The well is currently shut-in. Request: Approval is requested for the P&A of Prudhoe Bay well L-200 to sidetrack and complete L- 200A. CMIT-TxIA passed to 3500 psi (11/6/15) PPPOT-T Passed to 5000 psi (9/23/15) PPPOT-IC Passed to 3500 psi (9/23/15) Well History: L-200 well was drilled and completed in 2004 as a tri-lateral well.All three lateral were completed with liners with hook hanger junctions. The wells suffered from substantial solids production problems while on production causing multiple fill cleanout runs in the tubing. A video log was run in 2012 and showed the top LEM had collapsed into the tubing, cutting off access to the mainbore below L2. A rock catcher was set in an attempt to catch any large rocks that came into the wellbore through the damaged L2 junction. This was followed by a failed sand consolidation treatment in early 2012 that only lasted —60 days. In 06/15, a coil milling job was carried out in an attempt to mill through the damaged LEM and gain access to the mainbore. Coil got through the top LEM but could not get deeper than 7360'. An a-line video loq following coil operations suggested coil sidetracked out of the junction rendering the well inoperable. - r Scope of Work: The sidetrack plan for the L-200A well includes the following operations. Pre-rig, a cement plug will be - circulated into the tubing and IA, which will bring the top of cement to —5,587 MD. Once the cement has setup, the final top of cement will be determined with a drift run followed by CMIT TxIA. Next, the 4-1/2"tubing will be jet cut. The rig will then move over the well and pull the 4-1/2" tubing and cut the 7-5/8" casing at —3,100' MD. A clean out run will then be performed, followed by the setting of an EZSV bridge plug in preparation of the whipstock exit at—3,000' MD. The objective of the L-200A sidetrack is to drill a slant well near three L-200 laterals, and draulically fractu m to recover their reserves. BP is requesting a deviation from 20 AAC 25.112 We Plugging requirements. The laterals cannot'be accessed due to the tubing restriction, and are not desired to be abandoned with cement. The original laterals will possibly add to L-200A's production. The existing cement around the 7-5/8" casing and the proposed 1,500' cement plug in the tubing and tubing x casing annulus will prevent the migration of hydrocarbons from the Schrader Bluff reservoir to surface and any other permeable zone. MASP: 1,840 psi Cb Estimated Start Date: January 10th, 2017 �z:�� c��/�6a-�. oas"74 /�r , L-200A Sundry 1 9/19/2016 • Pre-Rig Prep Work: Pre Rig Plan for L-200A Step Service Operation 1 F LLR TxIA (potential LDL) 2 S Pull GLV Drift run for gyro. 3 E Run Gyro as deep as possible. 4 F Circ Cement 1500' Plug 5 S D&T TOC. Drift for Jet Cut 6 F CMIT-TxIA to 3,000 psi. 7 E Jet Cut 3500' 8 F Circ out. CMIT-TxIA to 3,000 psi. 9 V Install Dry Hole Tree. Configure TWC. Proposed Drilling Rig Operations: 1. MIRU Parker 272. 2. Test TWC from below to 3,500 psi for 30 minutes. 3. Nipple down tree. Nipple up and test Annular, 7-5/8" Fixed upper rams, blind shear rams, and 2-7/8"x 5" lower rams to 3,500 psi. 4. Pull TWC with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection through choke to tiger tank with clean 8.5 ppg seawater. 6. RU and pull the 4-1/2"tubing from the pre-rig jet cut. 7. MU casing cutter and cut 7-5/8"casing at—3,100' MD. 8. RU and pull 7" casing from cut. 9. RIH with 9-5/8" clean out assembly down to the top of the 7-5/8"casing stub. 10. RU E-line w/GR/CCL log and set EZSV at—3,000' MD and pressure test to 250 psi for 5 min and 3,500 psi for 30 min. Chart both tests. 11. PU 10-3/4"whipstock, bottom trip anchor and 9-7/8"window milling assembly. RIH to the top of the EZSV. Orient and set the whipstock. 12. Swap the well over to 9.5 ppg fresh water LSND milling fluid. End of Sundry: Start of Permit to Drill 13. Mill window in the 10-3/4"casing plus 20'of formation. 14. Perform LOT. POH for drilling BHA. 15. MU 9-7/8"drilling BHA, GR/RES UBHO (Gyro), and RIH. Kick off and drill 9-7/8" intermediate interval. 16. Drill to the end of build section at—3,600' MD. 17. POOH and LD 9-7/8" motor BHA. 18. PU 9-7/8" RSS drilling BHA, GR/RES/PWD/DENS/NEU and RIH. 19. Drill 9-7/8" intermediate interval to section TD at. Weight up drilling fluid using spike fluid maintaining the following density ranges: • KOP—4,000' TVDss: 9.3-9.8 ppg • 4,000'TVDss—TD: 10- 10.2 ppg 20. At TD, CBU until hole is clean (minimum 2x), then perform short trip. L-200A Sundry 2 9/19/2016 ® i 21. RIH to TD and circulate the well clean and POH on elevators. 22. Run and cement 7-5/8", 29.7#, L-80, VAM TOP HC casing to TD. Top of cement will be at 6,959' MD. Bump the plug with 9.9 ppg NaCI brine. (RA tag to be run above the estimated top perforation.) 23. Pressure test the 7-5/8" casing to 250 psi low/3,500 psi high for 5 minutes low/30 minutes 24. Install the 7-5/8" pack-off through the stack and test to 250 psi low/5,000 psi high for 30 minutes. 25. Freeze protect the 9-5/8"x 7"annulus, once the tail cement has reached compressive strength. 26. MU pert assembly with MWD GR. 27. RIH and tag the float collar, PU log guns on depth, and fire. 28. POOH lay down guns. 29. MU cleanout assembly with full gauge string mill and a used mill tooth bit. 30. RIH and ream across perforations. Tag the landing collar and CBU. 31. R/U and run a 4-'/", 12.6#, 13CR, VT tubing completion with GLM's, 6 production packers 5 NCS frac sleeves, 5 NCS screen sleeves, and SLB Gauge on (wire. (RA tag to be run in completion.) 32. With completion spaced out RU e-line and log the RA tags to confirm the completion is on depth. 33. Land the tubing hanger, and run in lock down screws. 34. Reverse circulate 9.9 ppg brine and corrosion inhibitor into the tubing x casing annulus. 35. Drop ball/rod, set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. 36. Hold pressure on the IA and bleed tubing pressure to zero, shearing the DCK shear valve. Pump both ways to confirm circulation ability. 37. Install TWC and test from above to 250 psi low/3,500 psi high for 5 minutes each and from below to 250 psi low/3,500 psi high for 5 minutes low/30 minutes high. 38. Nipple down the BOPE. Nipple up the adaptor flange and double master valves and test to 5,000 psi with diesel. 39. Remove TWC. 40. Reverse circulate diesel freeze protect using rig injection pump. 41. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 42. Dry Rod BPV in and install all annulus valves and secure the well. 43. RDMO. Planned Post-Riq Operations: 1. Change out tree. 2. Pull BPV, Pull Ball, Rod and RHC Plug with slickline. 3. Pull shear valve and dummies, change GLVs. 4. RU coil and individually hydraulically fracture each zone thru the NCS sleeves with coil. 5. RU E-line and run a gravel pack log. 6. RU coil, open up screen sleeves, and top off zones requiring more gravel. 7. Flowback as per ASRC. L-200A Sundry 3 9/19/2016 • • 0 Loepp, Victoria T (DOA) From: Thompson,Jacob <Jacob.Thompson@BP.com> Sent: Wednesday, October 19, 2016 9:16 AM To: Loepp, Victoria T (DOA) Subject: RE: PBU L-200 (PTD 204-001) Plug for Redrill Victoria, Can you please provide some more detail on your request to place cement deeper into the tubing, and alter the tubing/casing cut depth? Placing the cement deeper in the tubing does not reduce risk or improve the abandonment of the three laterals. With the proposed plan there will be a PX plug and 1,535' of cement inside the tubing, and a production packer with 1,500' of cement inside the tubing x 7" annulus. Due to the uncertainty of the integrity of the tubing below the 5.75"Seal stem at 7,277' MD deepest lowest I would recommend setting a plug in the tubing is 7,250' MD.This is only 123' deeper than the existing PX plug placed at 7,122' MD.There is no way to adequately place cement into the 7-5/8" x 4-1/2" annulus below the packer. Extra tubing cement will not improving our abandonment because of the open 7"x 4-1/2" annulus below the production packer. I've attached a snapshot of the vertical section of the well with a little cartoon of BP's proposed cement plug placement.The grey represents the cement that is proposed in the PTD where all annuli are isolated, and the red represents the cement that could add to the tubing. Based on the job records and proposed new cement there would be at least 1,266' of cement across the entire wellbore and annuli isolating the producing zones from surface. Feel free to give me a call if you would like to discuss this further. Thanks, 1 • II Section View -Actual:t-2200(1-20011-204)/ . -0, .4-, , r Imolaa` b. 16V10it it % sx4. Stgb a ( 11E . gl. if 7 KK j _-_._.. ._.. i , , : . : 1 : i _ ___ _ _,_...., __,..._ , --„..„i 1 6 3 k i i * ` R w SKS_.r _«»...r -•_--•-«...... ._...._�*4- ...._-_.-..._ .+t „:.-..w _.._..-........... ._.+«.-"...-.-.-.-.-.- +. ..._-..w .-....... ... «....--.s.. _. x P` 5 6 + I : } _' 0 I 1 I r^'... _ • 8 Ya - 5 1 R a 6 , 9 : she_ . ._ ..__._. ..... _.._.}...«_�___.._ ...z.....,.. .__..<,..._. .._ __.._ _...... __._, ___. .,... + ._. ..._ ., ... .._...,. ..,.._ ...... a 6.44- 11 ? 1 111# : ; 34.14 i -.9-----..-- :-. -.---- : ---.1. ____ , _, f__w 4 1 i . ;;;t. :4s :44c :-ac E1K :*tic )+K 1444 *a; 1K4 rat >: N14 NEI 414 Nib 44C 444 414 i•CG 6:6; YMYYI l41tlan a 3S a2' Jacob Thompson BP Alaska Rotary Drilling Engineer Cell:(907)854-4377 Office:(907)564-5579 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, October 17, 2016 10:41 AM To: Thompson, Jacob Subject: RE: PBU L-200 (PTD 204-001) Plug for Redrill Jacob, We'd like to see cement set deeper in the tubing and the tubing/casing cut deeper to closer meet the State regulations. Thanx, Victoria 2 ! ! From:Thompson,Jacob fmailto:Jacob.Thompson@BP.coml Sent: Friday, October 14,2016 3:18 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: PBU L-200(PTD 204-001) Plug for Redrill Victoria, This is a unique situation where we are planning to preserve the integrity of the three horizontals so that we can access their reserves by hydraulically fracturing into each lateral from the nearby L-200A sidetrack. Squeezing cement into the laterals will reduce our ability to recover the reserves from the laterals.The attached schematic shows that our plan is to place a cement plug from 7,122' MD to 5,587' MD in both the 4.5"tubing and 4.5" x 7" annulus.The drilling records indicate that the top of cement in the 7.625" x 9.875" open hole annulus is at 5,800' MD.This will place cement' 1,322' MD of cement above the top of the Schrader Bluff reservoir and below our planned window exit.At ultimate abandonment the L-200 laterals and L-200A sidetrack will be abandoned by cementing all annuli from the window depth to surface. I have attached both the Pre-rig and Proposed Schematic for the L-200A well. Please feel free to call me if you have any questions. Thanks, Jacob Thompson BP Alaska Rotary Drilling Engineer Cell:(907)854-4377 Office:(907)564-5579 From: Loepp, Victoria T(DOA) [mailto:victoria.loeop©alaska.gov] Sent: Friday, October 14, 2016 2:49 PM To: Thompson, Jacob Subject: PBU L-200 (PTD 204-001) Plug for Redrill Jacob, This does not meet State regulations for plugging. Please refer to 20 AAC 25.112.There are no depths for the plug listed and no wellbore schematic showing the post-job status. Consider setting a cement retainer and squeezing cement below. Please modify. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a.alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 3 • • 8. Install flow lines and well house. Drilling Engineer: Jacob Thompson (907) 564-4649 Production Engineer: Alex Youngmun (907) 564-4864 Geologist: Ben Siks (907) 564-4502 L-200A Sundry 4 9/19/2016 IFtlzh= 4-1/16"CI1N WELLFEAD= 11'FMC • AlkY NOTES: WELL ANGLE>70°@ 6602'. ACTUATOR= BAKER 6-34°1_2 ***4-1/2"CHROME TBG***LEM @ 7315'IS COLLAPSE:1).CAN NOT PASS THRU WITH ANY -6KB.MEV= 77.6' i 1 REF ELEV= 77.6' .... EiF.B 41 _EV= 99. 20#COND — 114' I/ ....- ..- TOOLS. \ 986' —10-3/4"TAM PORT COLLAR Max—Ang le= 96*q.., 11569. 2174' —141/2"FES X NP,ID=3.813' Datum MD= 7515' AGAS LIFT MANDRELS -Datum 7VD= ----4400'SS L ST NO TVD DEV TYPE VLV LATCH PORT DATE 10-3/4'CSG.45.54,L-80,ID=9.95" — 3871' f 6 3448 2436 60 KBG2 DMY BK 0 11/04/15 5 3565 2495 60 KBG2 MY BK 0 11/21/09 Minimum ID = 3.813" @ 2174' 1 4 5373 3433 58 KBG2 DRAY BK 0 07/03/11 9 3 5490 3498 56 KBG2 DMY BK 0 11/21/09 4-1/2" HES X NIPPLE ' '' 2 6645 4068 69 KBG2 IDM( BK 0 11/21/09 7-5/8"X 9-7/8"TOC — 6900' 1 6888 4157 69 KBG2 EMPTY BK - 07/03/11 4 ... RA TAG — 6983' .2 I i F,4 7051' H4-1/7 BKR C ()SLUNG SLV,0 3.813" ..‘ I 4-1/7 SGM-IIDPG-CA — 7035' ..• -as It 708T —75/8 X 4-1/2 BKR PREM FKR,ID=3.875" MIT!-DROP SUB,ID=3 958' .02 11024 7127 .-14.-1/7 FES X INIP,ID=3.813" 1 4-1/7 SGM-M) 3-CA — 7066' - " ; MLLT1-DROP SUB,ID=1958" 71 22* —4-1/2"PX PLUG(11/05/15) 7- 4-1/2"TBG,12.6#, 13CR-80 VAM TOP --f 7250' 4: 7193' —14-1/2"HIES X NIP,ID=3.813" .4, .. .0158 bpf,0=3.9513' RA TAG — 7270' :5 7264' 4-1/2"TBG, 12.6#L-80 ET-M, 7296' 8 1 7277' —5.75"BKR SEAL STEM .0152 bpf,ID=3,953" 11, Ai,r (SEALS FOV )),ID=4.83" ie 5-1/7 X 4-1/2-X0ID-= 3930 — 7301 7282* —75/8"X 4-1/2"BKR ZXP LTP w/I et3K,ID=5.750" , !- " ' ... 1 r• ° BAKER HOOK HANGER —{ 7315' ' : 9 L2 (OBa) L2(0Ba)LEM WNDOW 65 w/L2 NON-SEALING LEM,ID=3.71" 4 Jit i r1.4 7320'-7331' up. ' OPENING WIDT}-4=3,33 " COLLAPSED LEM-CAN NOT PASS BY -7315 7 OBa PBTD — 13043' (SEEN IN 01-1 VICE0)(12/14/12) 'l RA TAG— 7376' 1— 4 re 7315'-13044' 6-3/4'OBa LATERAL,ID=3.958" 7-5/8"X 5-1/2'BKR ZXPLTP,0=494" — 7386' -----.4 01$ Es.. 7398" —4-i/2"MULE SHOE,ID=3.958" 5-1/7 X 4-1/T X0,ID=3,930' — 7405' ---4+— Wil 41111:4 L1 (OBI)) Lai VVINDOVV 64' a% 7424'-7435' BAKER HOOK HANGER — 7419" • V .0 Li (08b) IL OPENING VVIDTH=3.33" ' - - - - - - - - - - - - - - - - w/L1 NON-SEALNG LEM,I)=3_71' OBb FEITD — 12987' PERFORATION Silk/VARY !7" REF LOG: 5, _sf'i 7419'-12988' 6-3/4"06b LAI ERAL,ID=3 958" A NGLE A T TOP FERF- ;ft Ntite:Refer to Roduction DB for historical pert data ------CI ri 7537" --17-5/8"X 5-1/2"BKR ZXP LIVER TOP PKR SIZE SPF NTERVAL Opn/Sqz DATE RI!de 4-1/2" SLID 06a 7392- 13000 0 02/18/04 V' 7 011 I 548' —41/2"MULE SHOE,ID=1958" 4-1/2" SLTD 013b 7497- 12944 0 02/12/04f 4-1/2' SLED 06d 7870- 13008 0 02/04/04 755T —5-1/2"X 4-1/2'XO,ID---3.930" , RA TAG — 7663' 4 N 7-5/3"CSG,29.7#,L-80 BTC-M,ID=6.875" .1-- 7872' 1, L-200 7572'-13052' 6-3/4"OBd LATERAL,ID =3.958" OBd FWD — 13050' — 1:14 TE REV BY COMMNTS DATE REV BY COMMENTS ORION UNT 02/22/04 N9ES ORIGINAL COMPLETION 06/26/15 TFA/A4D RILED ROO<CATCHER(06/20/15) MIL L-200 11/25/09 D-16 RWO 12/03/15 GJI3/.94.43 GLV O0(11/04/15) FERMT No: 2040010(020)(030) 04/09/12 TBID/JMD SET ROCK CATCHER(04/07/'12/03/15 GJB/JIND SET PX R_IJG(11/05/15) AR No: 50-029.-23191-00(60)(61) 04110/12 JFK/JM) GLV C/0(04/08/12) 07/25/16 JUAN) ADDED REF&BF ELEV SEC 34,T12N,RI 1E,256T FSL&1575'FEL 12/18/12 RN/JM)FCVRSH ROCK CATO-ER/COL LEM(12/14/12) ' 01/15/13 GJB/JMD SET ROCK CATO-ER(12J31/12) BP Exploration(Alaska) TREE= 4-1/16"CNV WELLHEAD= 11'FISC 61°192 NOTES: WELL ANGLE>70"@ 6602'. ACTUATOR BAKER PRE-FS "' -1/2"CHROME TBG`•"LEM @ 7315'IS COLLAPSED.CAN NOT PASS THRU WIN ANY OKE.ELEV= 77.6' i i BF. EV 53.80' TOOLS. t3 KOP 20#COND H 114' \'1 985' H10-3/4"TAM PORT COLLAR Ilex Angle= 96'@ 11569' Datum MD= 7515' 2174' -14-1/2"HES X NP,ID=3.813" DatumTVD= 4400'SS • GAS LFT MANDRELS 10-3/4"CSG.45.5#,L-80,ID=9.95" -{ 3871' --,/ ST MD !VD DEV TYLE VLV LATCH PORT DATE 6 3448 2436 60 KBG2 DMY BK 0 11/04/15 Minimum ID = 3.813" @ 2174' __ .4.. 5 3565 2495 60 KBG2 DMY BK 0 11/21/09 4-1/2" HES X NIPPLE " 4 .i 4 5373 3433 58 KBG2 DMY BK 0 07/03/11 ir'. # 3 5490 3498 56 KBG2 DMY BK 0 11/21/09 4-1/2"X 7-5/8"TOC H 5587' -vet' w. k"' fI .o ,!. 2 6645 4068 69 KBG2 DMY BK 0 11/21/09 7-518"X 9-718"TOC 5800' ..,It/� • '* ► 1 6888 4157 69 KBG2 EMPTY BK - 07/03/11 RA TAG -{ 6983' �.+. I I Rii.reill 7051' J-j4-1/2"BKR CM)SLIDING SLV,D=3.813" 4-1/2"SGM-NDPG-CA .�7035' ..4,-**' rCR ID=3.875" 708T H 7-5/8"X 4-1/2"BKR PREM P _ �..t+.t. �/ MULTI-DROPSI�,D-3.958" � ..�c.y..y.. r* = 7122' -14-1/2"FES X NP,ID=3.813" ue 4-1/2"SGlu4 NDPG CA 7066' , 7122' -14-112"PX PLUG(11/05/15) MULTI-DROP SUB,ID=3.958' '* J .+ 7193' H4-112"HES XNP,ID=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP H 7250' .0158 bpf,13=3.958" RA TAG 7270' 7264' -14-1/2"X 5-1/2"XO,D=3.940" 4-112'TBG,12.6#L-80 BT-M, 7296' 40 8 7277' 5.75"BKR SEAL STEM • �� .�' ' (SEALS REhADVED,D=4.83" .0152 bpf,ID=3.958" ) w 5-1/2"X 4-1/2"XO,ID=3.930" -1 7301' ___ 11111 7282' H7-5/8"X 4-112"BKR ZXP LTP w fT33K,D=5.750" BAKER HOOK HANGER -{ 7315' *1. L2 (OBa) L2(OBa)LEM WINDOW 65 w/L2 NON-SEALING LEM,D=3.71" / Iii... 7320'-7331' r COLLAPSED LEM-CAN NOT PASS BY -7315 ';' OBa PBTD H 1 — OPENING WIDTH=3.33"3043' (SEEN IN D.H.VIDEO)(12/14/12) 7315' 13044' 6 314"OBa LATERAL,ID=3.958' RA TAG -1 7375' �- 7-5/8"X 5-1/2"BKR ZXP LTP,D=4.94" H 7386' 1-----117-7�` lt: 7398' --{4-1/2"MULE SHOE,D=3.958" 5-1/2"X 4-1/2"XO,D=3.930" -{ 7405' a L1 (OBb)LEM WINDOW 64' 7424'-7435' BAKER HOOK HANGER -( 7419' I—.+ L1 (OBb) OPENING WIDTH=3.33" w/L1 L ,13=3.71' ~~ r* =;, OBb PBTD -1 12987' PERFORATION SUR/MARY REF LOG: 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958" ANGLE AT TOP FEW: .1' Note:Refer to Roduction DB for historical pert data ,* .--- c i iy SIZE SPF INTERVAL Opn/Sqz DATE -+ ;9AGC 7537' _"I7-5/8"X 5-112"BKR ZXP LNR TOP PKR 4-1/2" SLID OBa 7392- 13000 0 02/18/04 \ Kk 4-1/2" SLTD OBb 7497-12944 0 02/12/04 7548' H4-112"MULE SHOD D=3.958" 4-1/2" SLID OBd 7870- 13008 0 02/04/04 7557' 5-1t2"X 4-112"XO,ID=3.930" RA TAG --1 7663' I I v 7-5/8"CSG,29.7#,L-80 BTC-M,13=6.875" -1 7872' I I I I t IL-2001 7572'-13052' 6-3/4"OBd LATERAL,ID=3.958" OBd PBTD - 13050' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/22/04 N9ES ORIGINAL COMPLETION 06/26/15 TFA/JM) PULLED ROCK CATCHER(06/20/15) \NELL: L-200 11/25/09 D-16 RWO 12/03/15 GJB/JM) GLV CIO(11/04/15) FE} 1T No: 2040010(020)(030) 04/09/12 TBD/JM) SET ROCK CATCHER(04/07/ 12/03/15 GJB/JMD SET PX PLUG(11/05/15) AR No: 50-029-23191-00(60)(61) 04/10/12 JPK/JMD GLV C/O(04/08/12) 12/10/15 JT/JM) PRE-RIG CMT SEC 34,T12N,R11E,2567'FSL&1575'FEL 12/18/12 RRW/JMD FCO/FISH ROCK CATCHER/COL LEN(12/14/12) 01/15/13 GJB/JMD SET ROCK CATCHER(12/31/12) BP Exploration(Alaska) WWEL I-EAD= 11'FMC P R O P O D L-200,/ O O, •IYNOTES: WELLANGLE>70'@ACTUATOR= REV 3 ROMBGE CSG&T "* OKE.ELEV= 77-6' I ._ f.,_11 BF.Hyl/= 53.80' 985' -I 10-3/4"TAM PORT COLLAR KOP= 380' 20#COND H 1 114' I 1 .1(,;;:q'' H4.1/%'"I I f;X N1 3.t)1:'' 1) Mex Angle= _'@ .' I Datum MD= ' Datum TVD= 4400'SS GAS UFT MANDRILS 1f.:Ii,r MWI llPsToGK( / I__) - 3000' ..XST MD ND DEV TYPE VLV LATCH PORT DATE 10-3/4'CSG_45.5#,L-80,D=9.95" - .3000' _ ,.�X '1 3422 1-5/8"CSG,29.7#,L-80 XO TO 13CR 80 H -•8000' ' x 3 6181 2 7241 VAM TOP HC,ID=6.875" 1 8094 Minimum ID =3.725" @ 8874' I 1 8164' -14 -1/:,.i l X NII',1 i: :, ,> 4-1/2" HES XN NIPPLE 8?!8b• t 8235' -14-1/2"SGM-NDPG-CA SNRF.. GLE DROP SAPPH RA TAG 4-1/2"TUBNG COLLAR H GAUGE,D=3.864" zX 8311' _-17-5/8"X 4-1/2"HES TNT PKR,D=3.856" 8316' H4-1/2"NCS FRAC PORT,D=3.958" RA TAG 7-5/8"CASNG COLLAR -I 8320' I---• 11_J..r now ""'--i 8368' H4-1/2"NCS SCREEN SLEEVE,D=3.958" R8396' H 5/8"X 4-1/2"HES TNT PKR,D=3.856" 8407' H4-1/2"NCS FRAC FORT,D=3.958" I I 8412' --I4-1/2"HES X NP,D=3.813" hllll"III`-----_` I 8421' H4-1/2"NCS SCREEN SLEEVE,D=3.958" RC ----I 8449' _-1 7-5/8"X 4-1/2"HES TNT RCR,D=3.856" ` a i i; 8465' -14-1/2"NCS FRAC PORT,13=3.958" I I 8616' -14.It. HES X NI',l3 3.813" PERFORATION SUMMARY ® a 8525' H4-1/2"NCS SCREEN SLEEVE,D =3.958" - REF LOG: ANGLE AT TOP PITT: 8553' H7-5/8"X 4-1/2"HES TNT PKR,D=3.856" Note:Refer to Production DB for historical perf data X 8558' -4_1/2"NCS FRAC PORT,D=3.958" SIZE SPF ,ZONE INTERVAL Opn/Sqz DATE4-3/8" „ OBa 8383-8388 (1 1 1 8629' H4-1/2"HES X MD,D=3.813" 4-3/8" OBb 8452-8557 O3" P 'Hi I i a 8639' H4-1/2"NCS SCREEN SLEEVE,D=3.958" 4-3/8" 1 OBc 8548-8553 O 438" 1 OBd 8658-8663 O C' ---H 8666' H Y-5/8"X 4-1/2"HES TNT FKR,D=3.856" 4-3/8" 7 OBe 8772-8777 O X L_ 4-3/8" 7 OBf 8820-8825 O :T 8672' -14•-1/2"NCS FRAC PORT,D=3.958" I I 8747' -14-1/2"HES X NP,D=3.813" 8757' H 1/2"NCS SCREEN SLEEVE,D=3.458" 8784' -I Y-5/8"X 4-1/2"HES TNT PKR 13=3.856" a 8847 H41/2"I IM X NP,D=3.813" 4-1/2"TBG,12.6#,13CR 80 VAM TOP - €�?s4?-i' I I' I .0152 bpf,D=3.958" N1 1 8874' --14-1/2"HES XN NP,D=3.725" i-5/8"CSG,29.7#, 13CR-80 VAM TOP HC, H V , 8891' H4-1/2"WLEG,D=3.958" ID=6.875" DATE REV BY COMMENTS ' DATE REV BY COMMENTS ORION UNIT 02/22/04 N9ES ORIGINAL COMPLETION 10/05/16 JPT PROPOSAL REV3 WELL: L-200/. 11/25/09 13-16 RWO PERMIT No: / /_ SIDETRACK(L-200A). API No: 50-029-23191-0 12/16/15 JTP/JMD BUILT PROPOSED SEC 34,T12N,R11E,2567'FSL&1575'FEL 05/09/16 JT/JMD PROPOSAL REV 1 . 05/09/16 JT/JMD PROPOSAL REV 2 BP Exploration(Alaska) • 0 v -I z I a to 71 A to y § IS_ 5 hI IH All t$i A PI 'ffiN 1A3 711 ill a. 43 LPdnN ..ANA t'AAA2 §IH„ gAAA tAAA '07%,08 :63� g I P $ -i s ..r , r {1t d"�Y IAN'+i: 5 o . ' -.t.orFl ��1�� ;1��1 9 Iiiii;iiiit a 111/114;1 a. {L ggVi '499-IT it $ I.1/ 131:!!1; s 14 ('m.. 0M113T v . ,23 IE —.VC 4.9 JA 9-.1i -,E/I 01-JL' —� 1 o k z S -- a/1 s-.n .. (3d l nwa331 1 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist / in the upper left corner of Form 10-403 is checked. If the "Abandon" or / "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial the i' it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill"box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 if - 003 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RESCAN DIc;!1AL DATA ~Diskettes, No. I o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: Date 3L;).,4-1 CJ b I Date 3/é1LfI()~ I j... + Q = TOTAL PAGES "CI ~nt does not include cove~ 151 I o Other:: BY: ~ 151 mf 11111111111111 1/11/ MP Project Proofing BY: ~ 151 Scanning Preparation BY: Date: Production Scanning Stage 1 Page Count from Scanned File: 7 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY ~. Date3/a'f/O~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 111I1 NO 151 MP NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111/11/ BY: Maria Date: 151 Comments about this file: Quality Checked "' 111111111111111I 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISN REPORT OF SUNDRY WELL OPERATIONS T t: 5 2009 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re Erv�$bM+iieti 1�ledl ('08'" �1i11tiS$I l ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Sh utdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number. BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 204 -003 3. Address: ❑ Service ❑ Stratigraphic API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 -029- 23191 -61 -00 7. Property Design t� ion: Well Name and Number. ADL 028239 &047447 PBU L - 2001 - 2 9. Field / Pool(s): Prudhoe Bay Field / Orion 10. Present well condition summary Total depth: measured 13115 feet true vertical 4s 234 feet Plugs (measured) None Effective depth: measured 13115 feet Junk (measured) None true vertical 4234 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" x 34" 108' 108' 4260 2590 Surface 3842' 10 -3/4" 3871' 2653' 5210 2480 Intermediate 7293' 7 -5/8" 7320' 4318' 6890 4790 Production Liner 5729' 4 -1/2" 7315'- 13044' 4316'- 4229' 8430 7500 Perforation Depth: Measured Depth: Slotted Section: 7392'- 13000' True Vertical Depth: 4344'- 4225' Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# 13Cr80 7277' 4300' Packers and SSSV (type, measured and true vertical depth): 7 -5/8" x 4-1/2" Baker Premier packer 7087' 4227' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run . Well Class after work: ❑Exploratory ®Development El Service ® Daily Report of Well Operations ® Well Schematic Diagram Well Status after work: ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564 -5444 N/A Printed Name Terrie Hubble Title Drilling Technologist Signature Phone 564 -4628 Date - F - 5 1 Terre Hubble 564 -4628 Form 10-404 Revised 07/2009 / p 6 .S' Submit Original Only L -200 L- 20OL1, L- 2001-2, Well History (Pre Rig Workover) Date Summary 4/30/2009 SET 4 1/2" XX PLUG IN X NIPPLE @ 7238' MD. LRS MIT -OA TO 1,000# (FAIL) AND CMIT TxIA TO 3,500# (PASS). SET 4 1/2" WHIDDON CATCHER ON XX PLUG @ 7211' SLM. PULLED BK -OGLV FROM STA #1 @ 6989' SLM/7002' MD. PULLED 4 -1/2" WHIDDON CATCHER FROM 7211' SLM (EMPTY). WELL TURNED OVER TO DSO. 5/6/2009 T /1 /0= 500/450/400 Circ out TBG & IA (Pre RWO) Pumped 7 bbis neat meth followed by 438 bbis 9.8 ppg brine down TBG, up IA, taking returns to production on well #202. Pumped 25 bbis DSL down TBG and U -Tubed into IA to freeze protect. Tags hung and wellhead valves left in the following positions: SV & WV = C. SSV, MV, IA & OA left open. FWP's = 0/0/240 5/7/2009 T /I /0= VACNAC /220. Temp= SI. Bleed WHPs to 0 psi (pre -rig work). OA FL near surface. Bled OAP from 220 psi to 60 psi in 45 min (fluid to surface). Monitored for 30 min. OAP increased 10 psi . Final WHPs = VACNAC/70. SV, WV = Closed. SSV, MV = Open. IA, OA = OTG. NOVP. 8/4/2009 DRIFT TO TOP OF XX PLUG @ 7230' SLM (7238' MD), W/ KJ, 2'x 1 7/8" STEM, 3.80" CENT. SET 4 1/2" WHIDDON C. SUB @ 7224' SLM. TAPPED FLOW CUT VALVE THROUGH ST# i @ 6999' SLM (7002' MD) (tt pin sheared on pocket poker). MADE 2 ATTEMPTS TO PULL ST# 2 @ 5485' MD. 8/5/2009 PULLED BK -LGLV FROM ST# 2, 5479' SLM (5485' MD). SET DMY -GLV ST# 2 5479' SLM (5485' MD), STA # 1 6999' SLM (7002' MD). MADE 2 ATTEMPTS TO LATCH C -SUB W/ KJ, 4 1/2" GS, 1 ATTEMPT W/ KJ, 4 1/2" GR, B.NOSE, @ 7224' SLM. CURRENTLY RUNNING W/ 3'x 1 7/8" STEM, 3.78" CENT, 3.50" LIB. 8/6/2009 RAN 3.50" LIB TO 7223' SLM, IMPRESSION OF POSSIBLE FLOW CUT 1" VALVE LOOKING UP. PULL WHIDDON C -SUB FROM 7224' SLM (recovered what appears to be seat for check in so -glv). RATTLED ALL GLM's, DRIFTED TO 7200' SLM, W/ KJ, KJ, 2.65" CENT, 3 1/2" BRUSH. PULLED 4 1/2" XX PLUG BODY FROM 7232' SLM (7238' MD). RAN TO 5481' SLM (5485' MD) W/ 2.125" & 2.70" MAGNETS (recovered 5" of broken valve). CURRENTLY RUNNING IN HOLE W/ WHIDDON. 8/7/2009 RAN WHIDDON W/ BRUSH TO 7200' SLM, UNABLE TO SHAKE FREE, POOH W/ HEAVY BIND. CHASE WHIDDON TO 7250' SLM W/ KJ, 2.80" SWAGE, 10'x 1 112" STEM, B.NOSE. RATTLED ALL MANDRELS W/ W/ 2.85" CENT, DBL K JT., 4 1/2" BRUSH. CURRENTLY RUNING IN HOLE W/ 4 1/2" GR TO WHIDDON C -SUB. 8/8/2009 PULLED 4 1/2" WHIDDON FROM 7258' MD. BRUSH & FLUSHED TBG TO 7250' SLM (7258' MD) W/ 4 1/2" BRUSH, 3.70" G. RING. WORKED TIGHT SPOTS FROM 1200 TO 1500' & 1900 TO 2100' SLM. PULLED 4 1/2" x 2 3/8" NIPPLE REDUCER FROM 7250' SLM W/ 4 1/2" GS. WELL LEFT S /I. 8/8/2009 T /1 /0= 300/0/360 Assist Slickline, Brush & Flush. (Pre FCO) Pumped into Tbg with 110 bbis 190 °F crude while Slickline brushed Tbg. Pumped additional 47 bbis 190 °F crude down Tbg followed by 48 bbis 120 °F crude to pump Slickline toolstring down hole. FWHP's= 450/20/400. Casing valves open to gauges, Slickline on location upon departure. 8/26/2009 WELL S/I ON ARRIVAL. DRIFT W/ 3.75" GAUGE RING TO 7245' SLM. RUN 2.50" CENT, PETRADAT GAUGES PER PROGRAM. 8/27/2009 PETRADAT GAUGES DATA GOOD. RIG DOWN SLICKLINE. WELL LEFT S /I, DSO NOTIFIED. 8/27/2009 T /I /O = 330/300/320. Temp =Sl. IA FL (Pre Fullbore, call -in). AL is connected, S1 @ casing valve. IA FL @ surface. SV, WV = Closed. SSV, MV = Open. IA, OA = OTG. NOVP. 8/28/2009 T /l /O = 280/400/360 IA Injectivity test. Established IA injectivity of 1 bpm @ 600psi w/ 5bbl6 meth, 54bbls crude. FW HP's = 280/400/360 Swab, AL, Wing = shut. Master, SSV, IA, OA = open. Page 1 of 3 L -200 L- 20OL1, L- 2001-2, Well History (Pre Rig Workover) Date Summary 9/4/2009 MIRU coil tubing unit. Bullhead 40 bbl KCL for warm up. MU /RIH w/ WOT MHA/wt bars /jars and PDS carrier w/ 2.45' JSN to 7000'. Circ hot KCL down coil, returns up backside, through ASRC to flowline to pre -warm wellbore. Begin establishing steady GL rate and unloading well through ASRC test unit. 9/5/2009 Continue unloading well through ASRC test unit. RIH for dry tag. Sit down hard at 7315' ctmd. Make multiple attempts at different speeds. Hard tag repeats. Attempt to jet through obstruction, no progress. POOH to reconfigure tool string., Possibly sitting down in L2 LEM. UT butt weld in coil at 4490' ctmd and find wall thickness below minimum. Continue to POOH. Download PDS GR/CCL data. Correct log depth to RA markers on wellbore schematic. Blow down reel with N2. RDMO for reel swap. Well flowing through ASRC test seperator on departure. Job Not Complete. 9/6/2009 MIRU coil tubing unit. Pump and recover 1.25" steel ball for coil drift. MU and RIH with 2.37" JSN assy for cleanout. Attempt to pass through 7316' (ctm up) while varying pump rates and running speeds. Multiple attempts but unsuccessful. Flag coil at 7264'. Memory log up to 6950'. POOH. MU /RIH slick w/ 1.75" coil only, 2 stingers, 1.75" DJ nozzle. Tag same @ 7317'. Make multiple attempts to pass obstruction. POOH. 9/7/2009 RIH with Baker venturi and 3.56" cut lip shoe and motor. Engage obstruction at 7306.7' ctmd. Continue working with motor and cut lip shoe at obstruction. Continue slowly working down to 7312. Had 5 separate motor stalls at varying rates. Ran back up hole and established circ pressure at 2bpm. Worked slowly down to 7313' but could not make any more progress. Dry tag at 7313.4, POOH to inspect venturi and shoe. Cut lip burn shoe shows circumfrential wear on leading inside edges and around the outside. Recovered small amount of metal shavings and approximately 1/2 cup of rocks including one rock that was 2" x 1.5" x 1.25 ". While breaking out venturi basket it was noted that the barrel below the venturi had a crack / failure about 2" below the upper threads. Called out for replacement venturi and replacement basket/cage. Make up new Venturi BHA and stopped flowing well. RBIH w/ 3.56 cut lip shoe and venturi BHA. Sit down on obstruction at 7318' ctmd. Work motor and cut lip shoe on obstruction. No progress made. No stalls. Cannot make any hole, saw minimal motor work. POOH. Venturi barrel and cut lip shoe left in hole. Venturi barrel sheared off just below the service connection below the jet sub. Total length of fish = 3.53'. ID of venturi barrel looking up hole is 2.49 ", venturi barrel OD = 3.13 ". Maximum OD of fish in hole is 3.56" at the cut lip shoe. 9/8/2009 MU /RIH with BOT fishing string w/ Jar and 3" GS spear. Running G bait sub crossed to WFD releasable spear. Tag fish @ 7313' (ctm up) twice @ 1.5 & 20. POOH to inspect BHA. No fish. No marks on tools. RIH w/ same fishing string. @ nd run w/ same assmebly, tagged @ 7313, (ctm up) 3x @ 3.5k, 5k, & 10k down weight. POOH, no fish.inspect BHA. No marks on spear. Trace amount of sand on spear, but not enough to cause spear malfunction. Spear still appears to function properly. Inspect GS spear. GS /Bait appears to be fine. Break out spear and make up 3 1/8" venturi with 3.65" OD mule shoe. RIH to clean up area around fish for slickline. Venturi @ 7313' up to 2.3 bpm. Venturi while POOH up to 6900' ctmd. Recovered 1/2 cup of small rocks, and a few small pieces of metal shavings. Freeze protect flowline with 5 Bbls 50/50 McOH. 9/11/2009 WELL S/I ON ARRIVAL. RAN 4 -1/2" DE- CENTRALIZER, 3.5" LIB & STOP IN DEVIATION @ 7304' SLM. LIB INCONCLUSIVE. LEFT WELL S /l, TURNED WELL OVER TO PAD -OP. 9/15/2009 T /I /O= 400/920/380 Temp= SI Assist wireline pump as directed (Fish). Pumped 106 bbls 180 °F diesel down Tbg while slickline brushed. Final WHPs 400/920/400 Slickline still on well at time of departure. 9/15/2009 WELL S/I ON ARRIVAL. BRUSH & FLUSH TO 7093' SLM / 7120' MD (sld slv) CAN'T GET PAST W/ 3.805" G -RING, 3' STEM, 4 1/2" BRUSH. RAN 3.75" CENT, 3' OF STEM, 4 1/2" BRUSH, SD @ 7303' SLM. (fish) LRS PUMPED 105 BBLS HOT DIESEL. RAN 3.25" LIB (PARTIAL IMPRESSION OF VENTURI BARREL). PLANT 4 1/2" BAIT SUB, 3.70" BOX TAP ON FISH @ 7303' SLM. CURRENTLY RUNNING 4 1/2" GS. Page 2 of 3 L -200 L- 20OL1, L- 2001-2, Well History (Pre Rig Workover) Date Summary 9/16/2009 MADE SEVERAL ATTEMPTS TO PULL FISH FROM 7303' SLM. RAN 2.25" PUMP BAILER TO 7303' SLM, RECOVER HANDFUL OF SMALL ROCKS. RIH W/ KJ, 4 1/2" GR, 4 1/2" BAIT SUB, 3.35" RELEASABLE SPEAR W/ 2.50" - 2.624" GRAPPLE. RECOVER VENTURI BARREL FROM 7303' SLM. ATTEMPT TO SET PX PLUG BODY @ 7230' SLM / 7238' MD. 9/17/2009 T /I /O = 450/1000/320. Temp = SI. IA FL for Slick -line. AL shut -in @ casing valve, ALP = 1700 psi. IA FL @ 4258' (sta # 3). Final WHPs = 450/1000/320. Slick -line still as position of well. 9/17/2009 SET 4 1/2" PX PLUG BODY @ 7230' SLM / 7238' MD. PULL BK -DGLV FROM STA #1 @ 6995' SLM / 7002' MD. SET P -PRONG @ 7229' SLM. CURRENTLY BLEEDING DOWN IA. 9/17/2009 T /1 /0= 420/1000/360 Assist Slickline. Pumped 5 bbis 60/40,127 bbls 50 °F diesel for Slickline. 9/18/2009 Assist Slickline with CMIT TxIA to 3500 psi PASSED on 5th attempt. Pumped 290 bbls crude down IA up Tbg and down flowline to Circ out gas. Pumped 5 bbls diesel to pressure up to 3500 psi for CMIT TxIA. T /IA lost 60/50 psi in 1 st 15 min and 10/20 psi in 2nd 15 min for a total loss of 70/70 psi in the 5th 30 minute test. Bled pressures back (aprx -5 bbls). Rig down off of IA and onto Tbg. Pumped 10 bbls crude and 10 bbls 60/40 down flowline to freeze protect. Valve positions = Swab- Closed, Wing - closed, SSV- Open, Master -Open, IA and OA valves open to gauges. FWHP's = 300/300/380. 9/18/2009 LRS PERFORMED A CMIT -TxIA (pass). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 9/19/2009 T /1 10= 250/220/380 Circ -out, CMIT -TxIA passed to 1000 psi (RWO prep) Pumped 5 bbls 60/40 meth followed by 205 bbis FW, 360 bbls 9.8# brine and 20 bbls DSL (U -tubed into IA for a freeze protect) down TBG, up IA, taking returns down the flowline for well # 202. Pressured up TBG & lA to 1000 psi W/.6 bbls DSL. TBG/ IA lost 40/40 psi in 15 minutes and 20/20 psi in the second 15 minutes for a total loss of 60/60 psi. Bled IAP (.8 bbls). Tags hung and wellhead valves left in the following positions: SV& WV = closed. SSV, MV, IA & OA left open. DHD to finish bleeding OAP. FWP's= 0/0/60 9/21/2009 T /1 /0= 0/0/150 Set 4" CIW "H" BPV #145, 1 -2' ext. used, Tag @ 96 ", Pre Nabors 7ES. 11/11/2009 T /1 /0= ?/20/210. Temp =Sl. WHPs (RWO prep). No well house or flow lines connected. No AL connected. No ladder or scaffolding. Unable to verify valve position. IA / OA = OTG. NOVP. 11/12/2009 T /I /O = ?/20/210. Temp = SI. Bleed OAP to 0 psi (pre RWO). OA FL near surface. No well house, flow line or AL. No platform or scaffolding. Unable to verify valve position. Bled OAP to 0 psi in 1 hr, 30 min. Left open bleed for additional 2 hrs. Si, monitored for 30 min. OAP increased to 0+ psi. Final WHPs = ?/20/0 +. IA, OA = OTG. NOVP. Page 3 of 3 BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 11/12/2009 16:00 - 22:00 6.00 MOB P PRE PREP RIG FOR MOVE, LOWERED DERRICK, MOVED OFF WELL, SPOT RIG ON UPPER SECTION OF N -PAD, REMOVED AND CRADDLED BOP STACK, INSTALLED BOOSTER WHEELS 22:00 - 22:30 0.50 MOB P PRE PJSM WITH RIG CREW, TP, SECURITY AND MYSELF, REVIEWED RIG MOVE OPERATIONS, ROAD AND WEATHER CONDITIONS 22:30 - 00:00 1.50 MOB P PRE RIG MOVING FROM N -PAD TO L -200 11/13/2009 00:00-09:00 9.00 MOB P PRE PJSM WITH CHANGE OUT CREW, RIG MOVING FROM N PAD TO L -200 09:00 - 11:00 2.00 RIGU P PRE PJSM. REMOVE REAR BOOSTERS. R AND R SPACER SPOOL ON BOTTOM OF BOP STACK THEN MOUNT BOP ON STUMP IN CELLAR. -ALL THE TREE GAGES SHOWED 0 -PSI WHEN RIG ARRIVED ON LOCATION. 11:00 -12:30 1.50 RIGU P PRE PJSM WITH RIG CREW, TOOLPUSHER, AND WSL. MOVE RIG ONTO RIG MATS AND CENTER OVER WELLBORE. 12:30 - 13:00 0.50 RIGU P PRE PJSM WITH RIG CREW, TIP, AND WSL. RAISE DERRICK, DRIVE IN DERRICK PINS AND TORQUE TUBE PINS. 13:00 -15:00 2.00 RIGU P PRE PJSM WIT RIG CREW AND WSL. REMOVE BRIDLE LINES AND HANG IN DERRICK. -R/U FLOOR EQUIPMENT AND CIRCULATING LINES. -R/U DOUBLE ANNULUS VALVES ON IA AND OA. -R/U CIRCULTING MANIFOLD AND SECONDARY CONTAINMENT IN CELLAR. -TAKE ON HOT SEAWATER TO PITS. - ACCEPT RIG AT 1500 - HOURS. 15:00-17:00 2.00 RIGU P PRE PERFORM DERRICK INSPECTION. CONTINUE R/U FLOOR AND CELLAR. 17:00 -18:00 1.00 WHSUR P DECOMP RU LUBRICATOR, TESTED TO 500 PSI 18:00 -19:00 1.00 WHSUR P DECOMP WAIT ON PAD OPERATOR TO UNLOCK MASTER VALVE AND IA VALVE. 19:00 -19:30 0.50 WHSUR P DECOMP PULL BPV, LD LUBRICATOR 19:30 - 22:00 2.50 WHSUR P DECOMP PJSM WITH RIG CREW, REVIEWED CIRC OUT OPERATIONS, RU CIRC LINE TO TREE, BACK LOADING ON VAC TRK 180 BBLS OF SEAWATER FROM PITS, MAKING ROOM FOR 9.8 PPG BRINE RETURNS, SERVICE TD, IRON ROUGHNECK AND DRAWWORKS, PRESSURE TEST SURFACE LINES FROM 250 PSI TO 3500 PSI - REVERSE CIRC 40 BBLS OF 120 DEGREE SEAWATER AT 5 BPM, 840 PSI, DIESEU SW RETURNS CLEANED UP TO 9.7 PPG BRINE -CIRC 120 DEGREE SEAWATER AT 6 BPM, 575 PSI, DN TBG, DIESEL IN RETURNS AFTER 40 BBLS OF SEAWATER PUMPED, CONTINUED PUMPING ADDITIONAL 40 BBLS BEFORE RETURNS CLEANED UP TO 9.7 PPG BRINE 22:00 - 00:00 2.00 WHSUR P DECOMP DISPLACE 9.7 PPG BRINE FROM WEL' LTO SEAWATER AT 6 BPM, 566 - 442 PSI, MUD WT IN 8.7 PPG, MUD WT OUT 8.7 PPG, RECOVERED 115 BBLS OF 9.7 PPG BRINE 11/14/2009 00:00 - 01:00 1.00 WHSUR P DECOMP MONITOR WELL, STABLE, BLOW DOWN CIRC LINES, DRAIN TREE 01:00 - 04:30 3.50 WHSUR P DECOMP DRY ROD TWC Pdnted: 12/10/2009 11:15:25 AM 0 BP EXPLORATION Page 2 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/14/2009 01:30 - 04:30 3.00 WHSUR P DECOMP TESTING TEST PUMP, NOT HOLDING, TROUBLESHOOT TEST PUMP, CHANGED OUT SENSOR RUBBER, CHECK AND BLOCK VALVES, RU ON ANNULUS, TEST TWC FROM BELOW TO 1000 PSI WITH RIG PUMP, GOOD TEST, TESTED TEST PUMP, GOOD, TEST TWC ABOVE TO 3500 PSI, PRESSURE BLEEDING OFF SLOWLY, CYCLE TREE VALVES, RETEST TO 3500 PSI, GOOD TEST 04:30 - 08:30 4.00 WHSUR P DECOMP HOLD PJSM ON ND TREE AND ADAPTER FLANGE. -2 BARRIERS -- TESTED TWC AND PX PLUG. -BLEED OFF CONTROL LINE PORTS AND PLUG PORTS IN HANGER. -CLEAN HANGER NECK. - INSPECT AND VERIFY TBG HGR THREADS, SCREW IN 4 -1/2" TCII XO FOR 8 -1/2 TURNS. -WSL STOP THE JOB AND ASK CREW TO COVER THE WELL CELLAR WITH 3" X 12" TIMBERS. -SET TREE ON SUPPORT STAND IN CORNER OF RIG CELLAR AND RESTRAIN IT. CLOSE PROXIMITY TO ADJOINING WELLS ELIMINATES ABILITY TO PLACE TREE OUTSIDE. 08:30 - 13:30 5.00 BOPSUF P DECOMP PJSM WITH RIG CREW AND WSL TO N/U BOP. CREW DISCUSSED THE USE OF THE BRIDGE CRANES AND COMMUNICATION REQUIREMENTS. ALSO DISCUSSED THE USE OF THE SWEENEY WRENCH AND BACKUP TO TORQUE THE BOLTS IN THE ADAPTOR SPOOL AND BOP FLANGE. -M/U 13 -3/8" X 11" ADAPTOR SPOOL TO THE TUBING HEAD. - 0930 -HRS, CALL AOGCC WITH 2 -HOUR UPDATE FOR IMPENDING INITIAL BOP TEST. - 1045 -HRS, JEFF JONES, AOGCC INSPECTOR, RETURNED CAL TO WAIVE STATE'S RIGHT TO WITNESS THE BOP TEST. -M/U THE BOP STACK TO THE ADAPTOR SPOOL. - GREASE CHOKE AND KILL MANIFOLD. 13:30 - 17:00 3.50 BOPSUF P DECOMP PJSM WITH RIG CREW, TOOLPUSHER, AND WSL. -TEST BOPE TO 250 -PSI LOW, 3500 -PSI HIGH USING 4" AND 4 -1/2" TEST JOINTS; TEST HYDRIL WITH 4" TEST JOINT; RECORDING ALL TESTS ON CHART RECORDER. 17:00 - 18:00 1.00 WHSUR P DECOMP R/U DUTCH RISER; P/U DSM LUBRICATOR, M/U TO DUTCH RISER AND TEST TO 500 -PSI. -PULL H -TYPE TWC. -R/D DSM LUBRICATOR. 18:00 -19:30 1.50 PERF P DECOMP PJSM. SPOT SCHLUMBERGER EQUIPMENT. - CONDUCT PLANNING MEETING WITH SCHLUMBERGER CREW, TOOL/TOUR PUSHERS, DAY /NIGHT WSLs TO COVER THE WELL CONTROL REQUIREMENTS ASSOCIATED WITH THE PLANNED TUBING PUNCH AND CHEMICAL CUTTER RUNS. DISCUSS THE R/U OF THE WIRELINE ASSEMBLIES TO ASSURE THAT SUFFICIENT LUBRICATOR LENGTH IS AVAILABLE FOR SPACE -OUT OF TOOLS ABOVE RIG BOPE. 19:30 - 21 :00 1.50 PERF P DECOMP PJSM IN DOGHOUSE WITH RIG CREW, SCHLUMBERGER Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2009 19:30 -21:00 1.50 PERF P DECOMP CREW, TOURPUSHER, AND WSL FOR R/U SCHLUMBERGER EQUIPMENT. PU E -LINE EQUIPMENT TO RIG FLOOR -RU CHOKE LINE TO IA 21:00 - 00:00 0.00 PERF P DECOMP PJSM - MU E -LINE TBG PUNCH STRING, LUBRICATOR AND GREASE HD -MU LUBRICATOR AND GREASE HD OFF SKATE, STRIP E -LINE THROUGH HD AND LUBRICATOR, STAB X -0, PUMP -IN -SUB, W/L BOP, HEAD UP 7/16" SINGLE CONDUCTOR E -LINE, STAB LUBRICATOR/GREASE HD, TEST TO 500 PSI -TEST CHOKE LINE TO 250 - 3500 PSI CHART FOR 10 MINUTES WHILE RU E -LINE 11/15/2009 00:00-01:00 1.00 PERF P DECOMP BREAK OUT LUBRICATOR, MU TO TOOL STRING TO E -LINE HEAD, ADAPTER, TWO 6', 2 -1/8" WT BARS, MPD, UPCT, FIRING HD, 5' - 1" TBG PUNCH, 2', 4SPF WITH BOW SPRING = 29.2', STAB LUBRICATOR 01:00 - 03:30 2.50 PERF P DECOMP RIH WITH TBG PUNCH TO 7213', WORKED THRU TBG HGR WITH MINOR DIFFICULTY -RUN TIE -IN STRIP WITH RA TAG AT 6983', + 6' CORRECTION -RIH TO 7213' - REPEAT TIE -IN STRIP TO RA TAG AT 6983', NO CORRECTION, ALL JEWELRY WAS ACCOUNTED FOR BELOW RA TAG FROM THE TBG DETAIL DATED 2 -21 -2004 -RIH TO 7213', PU TO 7167', POSITION AND FIRE TBG PUNCH AT 7176' TO 7178' -FIRE GUN THREE TIMES WITH GOOD VOLTAGE SIGNAL - NO CSG OR DP PRESSURE INCREASE 03:30 -05:30 2.00 PERF P DECOMP POH WITH TBG PUNCH, BREAKOUT LUBRICATOR, LD TBG PUNCH ASSY, ALL SHOTS FIRED 05:30 - 06:00 0.50 PERF P DECOMP PJSM WITH SHCLUMBERGER AND RIG CREW TO COVER ALL ASPECTS OF R/U CHEMICAL CUTTER. WU 3 -3/8" CHEMICAL CUTTER. 06:00 - 08:30 2.50 PERF P DECOMP RIH WITH CHEMICAL CUTTER TO 7200'. CORRELATE TO PREVIOUS TUBING PUNCH RUN AND TO GR/CCL. -BRING CUTTER TO A POSITION IN CENTER OF THE MANDREL/CUTTING WINDOW OF 7172.26'. - 0800 -HRS, FIRE CHEMICAL CUTTER AND GET EXCELLENT SURFACE INDICATION OF SUCCESSFUL FIRING. - SCHLUMBERGER CREW CHANGEOUT. -FILL TUBING WITH 1/2 -Bbl OF 8.7 -PPG BRINE. 08:30 -10:00 1.50 PERF P DECOMP POH TO RIG FLOOR. -PJSM TO B/O AND LID EXPIRED CHEM CUTTER. TOOLPUSHER AND DRILLER DESCRIBED HOW TO SET BACK AND RESTRAIN THE SCHLUMBERGER LUBRICATOR USING THE DERRICK LEG TO TIEBACK TO AND THE DRILLER -SIDE TUGGER TO GET IT OUT OF THE WAY TO PREPARE TO PULL THE HANGER TO THE FLOOR. - SEEING NO PRESSURE ON THE TUBING OR CASING. Printed: 12/1012009 11:15:25 AM BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/15/2009 08:30-10:00 1.50 PERF P DECOMP -PARK CHEM CUTTER ASSEMBLY 200' BELOW TREE. 10:00 - 10:30 0.50 PERF P DECOMP PJSM WITH RIG CREW, SCHLUMBERGER CREW, MI ENGINEER, AND WSL TO DISCUSS THE R/D OF THE CHEM CUTTER ASSEMBLY. - DRILLER TO BE THE ONLY CREW MEMBER ON RIG FLOOR WHEN B/O THE SCHLUMBERGER LUBRICATOR. SCHLUMBERGER WILL HAVE TWO PERSONS REMOVE THE CHEM CUTTER AND CARRY IT OUTSIDE THE RIG WHILE ALL OTHER PERSONNEL STAY OUT OF THE DOGHOUSE AND MEZZANINE ENTRY FROM DOOR 2A. 10 :30 - 12:00 1.50 PERF P DECOMP B/O THE LUBRICATOR FROM THE WIRELINE BOP STACK. SCHLUMBERGER CREWMAN WEARING FULL CHEMICAL PPE BREAK OFF AND L/D DOWN CHEM CUTTER ASSEMBLY. -TWO SCHLUMBERGER CREWMEN CARRY SPENT ASSEMBLY OUT TO THEIR VAN. -M/U LUBRICATOR TO WIRELINE BOPS. B/O WIRELINE BOPS FROM DUTCH RISER; SET BACK SCHLUMBERGER EQUIPMENT TO GET IT OUT OF THE WAY. -RIG CREW CHANGEOUT. -PULL AND L/D DUTCH RISER. 12:00 - 14:00 2.00 CLEAN P DECOMP CIRCULATE BOTTOMS UP TO GET CHEM CUT DEBRIS /FLUIDS AND ANY GAS OUT OF WELL BEFORE ENGAGING HANGER AND PULLING TO THE FLOOR. - CIRCULATE 187 -Bbls, 7 -BPM, 450 -psi. DO NOT SEE ANY GAS OR CHEMICAL DEBRIS OVER SHAKERS. -MN LANDING JOINT TO HT38 X 4 -1/2" IF XO AND TO 4 -1/2" IF X 4 -1/2" TCII XO AND TORQUE TO 18,000 -ft -Ibs and 20,000 -ft -Ibs, RESPECTIVELY. -B /O CHOKE LINE FROM IA AND CONNECT TO MUD CROSS ON BOP STACK AND TEST TO 250 -PSI LOW AND 3500 -PSI HIGH. 14:00 - 14:30 0.50 PULL P DECOMP RIH WITH LANDING JOINT AND M/U TO HANGER 8 -1/2 TURNS. -M/U TOPDRIVE TO LANDING JOINT. P/U AND HANGER COMES FREE WITH -70K -Ibs. - CONTINUE TO PULL AND PACKER PULLS FREE AT 145K -Ibs, DROPPED BACK TO - 135KIbs WHICH INCLUDES 40K -Ibs FOR TOPDRIVE/BLOCKS. 14:30 - 16:30 2.00 PULL P DECOMP BRING HANGER TO RIG FLOOR, CLOSE HYDRIL AND CIRCULATE WHILE R/D SCHLUMBERGER E -LINE EQUIPMENT. - CIRCULATE 8.6 -BPM AT 470 -PSI WHILE R/D SCHLUMBERGER E -LINE EQUIPMENT. HAD NO LOSSES WHILE CIRCULATING. 16:30 - 17:00 0.50 PULL P DECOMP PJSM. BRING SCHLUMBERGER CAMCO SPOOLER AND EQUIPMENT TO RIG FLOOR. -R/U TUBING HANDLING EQUIPMENT TO POH AND L/D THE 4 -1/2 ", 12.6# IBT -M TUBING. - BLOWDOWN TOPDRIVE AND CIRCULATING LINES. 17:00 - 18:30 1.50 PULL P DECOMP PJSM. BREAK OFF HANGER AND L/D. -POH AND L/D 4 -1/2" TUBING AND SPOOL i -WIRE WITH 11 JTS FROM 7295' TO 6840', HOLE SWABBING total of 7 bbis Printed: 12/10/2069 11:15:25 AM BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/15/2009 18:30 - 20:00 1.50 PULL P DECOMP MONITOR WELL, NO FLOW -RU, HD PIN, CIRC BTMS UP AT 5 BPM, 250 PSI - MONITOR WELL, NO FLOW, RD HD PIN 20:00 - 21:00 1.00 PULL P DECOMP POH, UD 4 -1/2" TUBING AND SPOOL i -WIRE FROM 6840' TO 6686', HOLE SWABBED 1.6 BBLS 21:00 - 22:30 1.50 PULL P DECOMP CONSULT WITH RWO ENGINEER, DAY WSL ON CURRENT WELL CONDITIONS, AGREED TO LAND TBG, BULLHEAD 1.5X CSG VOL TO 8024'= - 93BBLS, PULL PX PLUG, THEN CONTINUE WITH OPERATIONS PULLING 4 -112" COMPLETION - NOTIFIED AOGCC, JEFF JONES AND JOHN CRISP OF CURRENT WELL OPERATIONS AND SHUTTING IN WELL TO BULLHEAD 1.5X CSG VOL BELOW PRODUCTION PACKER -FILL AND MONITOR HOLE, STABLE. 22:30 - 00:00 1.50 PULL P DECOMP PJSM, RD CIRC HD, MU TBG HGR, SECURE I -WIRE TO TBG, LAND TBG HGR, RILDS, LD LANDING JT 11/16/2009 00:00 - 00:30 0.50 PULL P DECOMP R/D POWER TONGS AND CONTROL LINE REEL, OFFLOAD POWER TONGS FROM RIG FLOOR - INSTALL DUTCH RISER 00:30 - 01:30 1.00 PULL P DECOMP PJSM WITH RIG CREW ON BULLHD OPS, BLIND RAMS CLOSED, ATTEMPT TO BULLHEAD DOWN TBG THROUGH KILL LINE, PUMPED 5.7 BBLS, PRESSURED UP TO 3250 PSI, HOLDING, BLED PRESSURE OFF TO 0 PSI - CONSULT WITH RWO ENGINEER - AGREED TO PROCEED FORWARD WITH SLICKLINE OPS, PULLING PRONG AND PX PLUG 01:30 - 03:00 1.50 PULL P DECOMP MIRU SLICKLINE UNIT, PU SLICKLINE EQUIPMENT TO RIG FLOOR, LAID OUT TOOL STRING - 1 -7/8' RS, 8' OF 2 -118" ROLLER STEM W/ 2.72" WHEELS, 1 -3/4' OJS, 1 -7/8" LSS, TWO QC'S, , KJ, 3.80" CENT, 3.60" BELL GUIDE, X -O, 3" EXT, 2 -1/2" JDC, DRESSED STUFF BOX 03:00 - 03:30 0.50 PULL P DECOMP HELD PJSM WITH RIG, SLB CREW, SLICKLINE PE, DISCUSSED POTENTIAL HAZARD OF PRESSURE BUILD UP BELOW PX PLUG /PRONG, ALONG WITH HAND SAFETY, OVERHEAD LIFTS, DROPPED OBJECTS AND OVERALL SAFETY. 03:30 - 05:30 2.00 PULL P DECOMP RU SLB WITH FULL PRESSURE CONTROL -PU TOOL STRING, SHEAVES, STUFFING BOX TO RIG FLOOR -STRIP. 125 W/L THROUGH STUFFING BOX, MU RS, ROLLER STEM, STAB ONTO LUBRICATOR, CLAMP OFF W /L, MU W/L BOP, X -O, HANGING SHEAVES, MU TOOL STRING, STAB LUBRICATOR, PT LUBRICATOR AGAINST BLIND RAMS TO 250 - 1000PSI, GOOD TEST 05:30 - 07:00 1.50 PULL P DECOMP RUN # 1, RUN WITH 2 -1/2" JDC PULLING TOOL TO PULL THE PX PRONG. WORK FOR 30- MINUTES ON TOP OF PRONG, BUT DO NOT GET OVER IT. -WELL CURRENTLY LOSING 12.5 -Bph. 07:00 - 08:00 1.00 PULL P DECOMP POH WITH SCHLUMBERGER SLICKLINE. 08:00 - 10:00 2.00 PULL P DECOMP PJSM WITH RIG CREW, SCHLUMBERGER CREW, AND WSL TO DISCUS R/D AND UD SCHLUMBERGER EQPT.. Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/16/2009 08:00-10:00 2.00 PULL P DECOMP R/D SCHLUMBERGER SLICKLINE EQUIPMENT. 10:00 - 10:30 0.50 PULL P DECOMP CLOSE BLINDS AND BRING PUMP ON TO PUMP DOWN TUBING. TAKES 3.6 -BBLS TO BUILD TO 3000 -PSI AND HOLDS TIGHT. BLEED OFF. CALL ADW ENGINEER TO DISCUSS PLAN FORWARD. HOLD SCHLUMBERGER SLICK LINERS ON PAD. TOTAL WELL LOSS FROM MIDNIGHT IS 45 -Bbls. 10:30 -12:00 1.50 PULL P DECOMP M/U LANDING JOINT TO XO; DRAIN STACK, RIH AND SCREW INTO HANGER. PJSM WITH RIG CREW, CAMOC TECH, TOOLPUSHER, AND WSL TO DISCUSS THE PREVIOUS 20 -HOURS OPERATIONS. WELL CONTROL IS OF PARAMOUNT IMPORTANCE. -CREW CHANGE WITH DAY TOUR TO DISCUSS SAME PLAN FORWARD. -PULL TBG AND FLUID LEVEL DROPPED BELOW TUBING HEAD AS THE HANGER CAME UP, THEN FOLLOWED WITH THE TUBING. -RBIH WITH ONE JOINT OF TUBING AND FL DROPPED AS THE TUBING WAS LOWERED. -R/U I -WIRE TO CAMCO SPOOLER. B/O AND L/D HANGER AND LANDING JOINT. 12:00 - 14:00 2.00 PULL P DECOMP POH TO 6222' (PACKER DEPTH 6090) AND L/D 5- JOINTS OF TUBING. P/U WT 106,000 -lbs. STARTING TRIP TANK VOLUME 33.4 -Bbls, ENDING VOLUME 39.3 -Bbls FOR 5.8 -Bbls GAIN. -LET FL IN BOP STACK DROP FOR 15- MINUTES; RE -FILL WITH 1.4 -Bbls. - 1300 -hrs. POH WITH 5 JOINTS AND GET 5.9 -Bbls GAIN. - 1315 -HRS. STOP POH. CALL ADW ENGINEER AND DECIDE TO R/U SLICKLINE TO RIH WITH LIB, THEN ONE OR MORE BAILER RUNS TO GET TO THE PX PRONG. 14:00 - 16:30 2.50 PULL P DECOMP R/U SCHLUMBERGER SLICKLINE EQPT. 16:30 - 19:00 2.50 PULL P DECOMP M/U, RIH WITH 3.5" LIB ASSEMBLY, UNABLE TO WORK PAST TBG HGR, CHANGED OUT TO A 3" LIB, RIH TAGGED UP AT 6159'. -7 -BBLS LOSS TO THE WELL FROM 1430 -HRS TO 1700 -HRS. -4.5 BBLS LOSS TO WELL FROM 1700 - 1830 HRS 19:00 - 20:00 1.00 PULL P DECOMP POH, LD 3.0" LIB, LIB SHOWED IMPRESSION OF PRONG LOOKING UP 20:00 - 21:30 1.50 PULL P DECOMP MU 2 -1/2" JUC PULLING TOOL WITH 3.60" CENTRALIZER, RIH TAGGED UP AT 6159' WLM - SEVERAL MINUTES WORKING THROUGH TBG HGR 21:30 - 22:00 0.50 PULL P DECOMP FISH FOR PRONG, ATTEMPT TO LATCH AND PULL PRONG, SEVERAL BITES, NO EXTRA LINE WEIGHT, NO CHANGE IN HOLE CONDITIONS, LOSSES AT 3 BPH 22 :00 - 22:30 0.50 PULL P DECOMP POH, TIGHT SPOT AT 6050' WLM, LD 2 -1/2" JUC PULLING TOOL, NO RECOVERED, JUC PULLING TOOL WAS SHEARED. 22:30 - 23:30 1.00 PULL P DECOMP REPINNED JUC PULLING TOOL WITH 5/16" SHEAR STOCK, MU 2 -1/2" JUC PULLING TOOL WITH 3.60" CENTRALIZER, RIH TAGGED UP AT 6159' WLM Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2009 22:30-23:30 1.00 PULL P DECOMP -10 MINUTES WORKING THROUGH TBG HGR 23:30 - 00:00 0.50 PULL P DECOMP FISH FOR PRONG, ATTEMPT TO LATCH AND PULL PRONG, SEVERAL BITES, NO EXTRA LINE WEIGHT, NO CHANGE IN HOLE CONDITIONS - LOSSES AT 3 BPH -TOTAL LOSSES LAST 24 HOURS == 72 BBLS - 4 -1/2" TBG TAIL MULE SHOE AT - 6,222' - 4 -1/2" X NIPPLE WITH PX PLUG AND PRONG AT - 6,166' -BAKER PACKER AT - 6,090' - 4 -1/2" SLIDING SLEEVE AT - 5,983' -GLM WITH EMPTY POCKET AT - 5,923' 11/17/2009 00:00 - 00:30 0.50 PULL P DECOMP POH, LD 2 -1/2" JUC PULLING TOOL, NO RECOVERY, JUC PULLING TOOL WAS SHEARED, FOUND TWO UNIDENTIFIED 1/16" INDENTS ON OUTSIDE SKIRT OF PULLING TOOL, MARKS WERE IN A 1/4" OF EACH OTHER. 00:30 - 02:30 2.00 PULL P DECOMP MU, RIH WITH 5' 3 -1/2" BAILER MULE SHOE BALL BOTTOM, TAGGED UP AT 6159', STROKED BAILER FOR 20 MINUTES - SEVERAL MINUTES WORKING THROUGH TBG HGR 02:30 - 03:30 1.00 PULL P DECOMP POH, LD BAILER, MINOR RECOVERY OF PERF GUN DEBRIS AND FINE PARTICLES OF SAND, LESS THAN 1/8TH OF A 10 OUNCE COFFEE CUP - LOSSES AT 4 BPH -LOST A TOTAL OF 7 BBLS SINCE MIDNIGHT 03:30 - 05:00 1.50 PULL P DECOMP MU, RIH WITH 3.80" CENT, 3.60" BELL GUIDE SKIRT WITH 2.50" LIB, SAT DOWN ONCE AT 6159'. -7 MINUTES WORKING THROUGH TBG HGR -HOLE STABLE, NO LOSSES - REPORTED AT 03:45 HRS. 05:00 - 05:30 0.50 PULL P DECOMP POH, LD 2.5" LIB, LIB SHOWED IMPRESSION OF PRONG LOOKING UP. 05:30 - 06:30 1.00 PULL P DECOMP MU, RIH WITH 3.60" BELL GUIDE SKIRT WITH 2 -1/2" JUC PULLING TOOL. SET DOWN AND H/U TO THE PRONG. MAKE TWO STRAIGHT PULLS, WORK SPANGS ONCE AND PRONG PULLS FREE. NO FLUID LOSS OR GAIN WHILE POH WITH CONSTANT HOLE FILL 06:30 - 07:00 0.50 PULL P DECOMP POH WITH SLICKLINE. PRONG IS IN THE RUNNING TOOL. B/O AND L/D PRONG. 07:00 - 07:30 0.50 PULL P DECOMP PJSM TO TRY TO PUMP THROUGH THE PX PLUG BODY. CLOSE BLINDS AND PUMP IN UNDER THE BLINDS. PUMP AT 1 -BPM AND PRESSURE BUIDS TO 500 -PSI THEN DROPS TO 100 -PSI AFTER 4 -Bbls PUMPED. CONTINUE TO PUMP FOR 10 -Bbls TOTAL; FINAL BULLHEAD PRESSURE 160 - 170 -PSI. 07:30 - 08:00 0.50 PULL P DECOMP MONITOR WELL, AND NO FLOW. START CONSTANT HOLE FILL AND CALCULATE LOSS RATE OF 18 -13PH. 08:00 - 08:30 0.50 PULL P DECOMP PJSM TO DISCUSS STAYING IN THE MOMENT BY COMPARING IT TO THE LEVEL OF CONCENTRATION A HUNTER NEEDS TO MAINTAIN IN ORDER TO BE SUCCESSFUL. DISCUSS THE PINCH POINTS REPRESENTED BY THE OVERHEAD LOAD OF THE LUBRICATOR; THE STABBING OF THE LUBRICATOR TO THE BOP STUMP, AND THE SLICKLINE CROSSING THE RIG FLOOR. Printed: 12/10/2009 11:15:25 AM 0 BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/17/2009 08:30 - 11:00 2.50 PULL P DECOMP STOP CONSTANT HOLE FILL. RIH WITH THE GR PLUG PLUCKER. -TALK WITH PAD OPERATOR ABOUT HAVING NORCON FILL OUT A DAILY SIMOPS WITH THE RIG. NORCON CALLED RIGHT AWAY TO FILL OUT SIMOPS CARD. - 1000 -HRS, ATTEMPT TO LATCH INTO PX PLUG BODY NUMEROUS TIMES. -1030 -HRS, STOP AND GREASE WIRE TO ALLOW IT TO SLIDE EASIER THROUGH STUFFING BOWLINE WIPER. CONTINUE ATTEMPTS TO DROP PULLING TOOL INTO PLUG BODY. -GR PLUG PLUCKER TOOL APPEARED TO HAVE LATCHED. DECIDE TO POH TO CHECK. 11:00 -12:00 1.00 PULL P DECOMP POH WITH GR PLUG PLUCKER. -START CONSTANT HOLE FILL AND CALCULATED LOSS INCREASES TO 36 -BPH. -B /O PX -PLUG AND FIND 5 PIECES OF CEMENT UP TO 2" X 1" AND 2 PIECES OF BRASS SHEAR PINS INSIDE THE PX -PLUG BODY. THE CEMENT WOULD HAVE COME FROM INSIDE THE BOP STACK AFTER THE N -15 CASING TIEBACK OPERATION. 12:00 - 13:00 1.00 PULL P DECOMP PJSM WITH RIG CREW, SCHLUMBERGER CREW, EXTRA TOOLPUSHER AND WSL TO RID SCHLUMBERGER SLICKLINE EQUIPMENT. WE PRAISED EACH OTHER'S CREW FOR THE CONTINUOUS IMPROVEMENT IN R/U AND R/D TIME. THE SLB LEAD SAID THAT THEY HAVE ENJOYED LEARNING MORE ABOUT RIG OPERATIONS. 13:00 -14:00 1.00 PULL P DECOMP P/U LANDING JOINT AND RIH TO WU TO HANGER. WU LANDING JOINT TO TOP DRIVE. BOLDS. -P /U AND STRING COMES STEADY AT 100K -Ibs. -LOST 10K -Ibs, PROBABLY DUE TO THE JUNK ON TOP OF THE PACKER LEAKING THROUGH THE SEALS WHILE WE WERE DOWN FOR SLICKLINE OPERATIONS. 14:00 - 14:30 0.50 PULL P DECOMP PJSM WITH RIG CREW, TOOLPUSHER, SCHLUMBERGER CAMCO TECH, AND WSL TO DISCUSS POH AND L/D 4 -1/2' TUBING AND R/U CAMCO SPOOLER. 14:30 - 16:00 1.50 PULL P DECOMP B/O AND L/D HANGER. WU TIW VALVE AND CEMENT LINE TO TUBING STRING AND CIRCULATE OUT CRUDE OIL THAT HAD BEEN PULLED TO THE SURFACE WHEN THE PLUG WAS PULLED UP THROUGH THE TUBING. - CIRCULATE 6 -BPM AT 420 -PSI AND GET LOTS OF CRUDE OIL AND BLACK SLUDGE IN THE RETURNS ACROSS THE SHAKERS. - RETURNS ARE 8.9 -ppg AND LOSS TO THE WELLBORE IS 25 -BPH AT 6 -BPM, 400 -PSI. IT APPEARS THAT WE ARE CIRCULATING DOWN THROUGH THE BOTTOM X- NIPPLE, UP THE ANNULUS AND PAST THE PACKER WHICH IS THE ONLY PLACE THAT THE BLACK SLUDGE CAN COME FROM. - CIRCULATE 399 -Bbls UNTIL RETURNS ARE CLEAN. TOTAL LOSSES DURING THE CIRCULATION 42 -Bbls. 16:00 - 22:00 6.00 PULL P DECOMP B/O AND L/D LANDING JOINT AND XO. -HOLD QUICK PJSM TO B/O AND L/D 4 -1/2" TUBING. Printed: 12/102009 11:15:25 AM BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/17/2009 16:00 - 22:00 6.00 PULL P DECOMP REMEMBER: WELL CONTROL, SWINGING LOADS, AND WELL CONTROL. -PULL FIRST JOINT AND FLUID LEVEL STAYS CONSTANT. - 1725 - HOURS, JOINT #37 POH (63- JOINTS TOTAL) SINCE 1600 -Hrs. USING CONSTANT HOLE FILL. LOST 6.6 -Bbls SINCE 1600 -Hrs. -L/D FROM 6222' TO 120'. - PACKER AND BELOW ARE BAKER LOCKED AND COULD NOT BREAK CONNECTIONS WITH POWER TONGS. - ATTEMPTED STEAMING CONNECTIONS WITHOUT SUCCESS. -RIG UP TO USE RIG TONGS WITHOUT SUCCESS. 22:00 - 22:30 0.50 PULL P DECOMP PJSM FOR USING HAND CUTTER. -MAKE 3 CUTS TO LAY DOWN ALL EQUIPMENT BELOW PACKER. -NO PERF HOLES NOTED IN JT BELOW PACKER. NOTED DIMPLES FROM PERF GUN. -TOTAL FULL JOINTS PULLED = 169,3 GLMS, 3 X- NIPPLES, SLIDING SLEEVE, PUMP SENSOR, AND 90 CANNON CLAMPS. 22:30 - 00:00 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. -L/D CONTROL LINE SPOOLER AND CANNON CLAMPS. -LOSS RATE OF 13 BPH. 11/18/2009 00:00 - 00:30 0.50 CLEAN P CLEAN P/U AND INSTALL WEAR RING. -7" ID WEAR RING. 00:30 - 01:00 0.50 CLEAN P CLEAN PJSM ON M/U PACKER AND P/U DP. -M /U 7 -5/8" CHAMP PACKER. 01:00 - 09:00 8.00 CLEAN P CLEAN RIH. - PICKING UP DRILL PIPE. -LOSS RATE AT 0430 HRS -12 BPH. -RIH to 7200'. GET P/U WEIGHT, 127K -Ibs; S/O WT 78K -Ibs. P/U TO 127K -Ibs, PUT TWO RIGHT -HAND TURNS INTO STRING, S/O TO 63K -Ibs. CENTER OF ELEMENT FOR CHAMP PACKER IS 7208'. -PJSM WITH RIG CREW, HALLIBURTON TECH, TOOLPUSHER, AND WSL TO DISCUSS THE INDIVIDUAL STEPS FOR THE PT OF THE 7 -5/8" CASING. - PRESSURE UP ON THE IA TO 3500 -PSI AND HOLD FOR 30- MINUTES RECORDED FOR AN ABSOLUTELY SOLID TEST. -BLEED OFF PRESSURE; RELEASE CHAMP PACKER FROM 7208'. 09:00 - 10:00 1.00 CLEAN P CLEAN CIRCULATE BOTTOMS UP, 5 -BPM AT 390 -psi; DYNAMIC LOSS RATE IS 25 -13PH. - NATIONAL OILWELL TOPDRIVE TECHNICIAN DOWNLOADING INFORMATION FROM COMPUTER IN TOPDRIVE HOUSE AND ANALYZING SAME FOR SYNCHRONIZING CONTROL FUNCTIONS. - BLOWDOWN TOPDRIVE. MONITOR WELL. 10:00 - 14:30 4.50 CLEAN P CLEAN TROUBLESHOOT TOPDRIVE WITH NATIONAL OILWELL REP AND RIG ELECTRICIAN. -USE CONSTANT HOLE -FILL AND SEE LOSS RATE OF Printed: 12/10/2009 11:15:25 AM 0 BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/18/2009 10:00 - 14:30 4.50 CLEAN P CLEAN 8 -BPH. - PERFORM WORK ORDERS. 14:30 - 15:00 0.50 CLEAN P CLEAN PJSM WITH RIG CREW, HALLIBURTON TECH, WSL AND ADW RWO SUPERINTENDENT. DISCUSS CURRENT OPERATION OF POH AND S/B DP. ALSO DISCUSS SAFETY PERFORMANCE IN NORTH SLOPE OPERATIONS AND RECEIVE PAT -ON- THE -BACK FROM ADW RWO SUPT. 15:00 -18:00 3.00 CLEAN P CLEAN POH AND S/B DP IN DERRICK. - 1700 -Hrs, 60- STANDS IN DERRICK. -8 -13PH LOSS RATE WHILE POH WITH CONSTANT HOLE FILL. 18:00 - 19:30 1.50 CLEAN P CLEAN CLEAN UP CHAMP PKR. - CHANGE OUT HANDLING EQUIPMENT. -RIG UP POWER TONGS. -M /U SAFETY VALVE. - SERVICE RIG FLOOR EQUIPMENT. 19:30 - 20:30 1.00 CLEAN P CLEAN SAFETY STAND DOWN MEETING ABOUT INCIDENT ON NGI WITH RIG CREW, DDI TOOLPUSHERS, WELLSITE LEADERS, BP WORKOVER SUPERINTENDENT, AND BAKER FISHING HAND. - INFORMED RIG TEAM WHAT WAS KNOWN ABOUT THE INCIDENT AT THE TIME. - IDENTIFIED HAZARDS OF THE INCIDENT WITH THE RIG TEAM. - WORKING ALONE, THE FACT OF 3RD PINNING EVENT IN 5 WEEKS, AND CONTROL OF WORK. - DISCUSSED THE MITIGATIONS OF THE HAZARDS FROM THE EVENT. COMMUNICATION WHILE WORKING ALONE. PLANNING OF WORK. - DISCUSSED HOW THE CREW WAS FEELING OVER THE LAST INCIDENT. 20:30 - 22:00 1.50 CLEAN P CLEAN PJSM WITH CREW AND WSL ON CHANGING OUT SAVER SUB ON TOP DRIVE. - CHANGE OUT SUB DUE TO WORN DOWN FACE SEAL AND SHARP THREADS. -WIRE TIE ALL BOLTS, INSPECT GRABBER DIES, AND INSPECT TOP DRIVE. 22:00 - 23:30 1.50 CLEAN P CLEAN PJSM AND M/U BHA FOR CLEAN OUT. P/U AND WU THE FOLLOWING: -FOX 2 -7/8" MULE SHOE, 6 JTS OF 2 -7/8" FOX TUBING, XO, BUMPER SUB, XO, DC. 23:30 - 00:00 0.50 CLEAN P CLEAN RIH WITH DP FROM DERRICK. -FROM 380' TO 784'. 11/19/2009 00:00 - 03:30 3.50 CLEAN P CLEAN CONTINUE RIH. -FROM 784' TO 7203' - ESTABLISH PARAMETERS OF 134K UP, 78K DOWN. -BREAK CIRCULATION TO ENSURE MULE SHOE STILL CLEAR. PUMP AT 2.5 BPM WITH LOSSES AT 72 BPH. - STATIC LOSS RATE OF 6 BPH. 03:30 - 07:00 3.50 CLEAN P CLEAN PJSM FOR CIRCULATING WELL CLEAN. -M /U CIRCULATION HEAD. -BREAK CIRCULATION WHILE REVERSE CIRCULATING AT 1 BPM WITH 16 PSI AND VERY LITTLE RETURNS, Printed: 12/10/2009 11:15:25 AM 0 BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date. 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/19/2009 03:30 - 07:00 3.50 CLEAN P CLEAN INCREASE TO 2 BPM WITH 67 PSI AND -55 BPH LOSSES, INCREASE RATE TO 3 BPM WITH 140 PSI AND -55 BPH LOSSES. INCREASE TO 4 BPM WITH 240 PSI AND 108 BPH LOSS RATE BUT LITTLE SIGNS OVER THE SHAKER. INCREASE TO 6 BPM RATE WITH 144 BPH LOSSES BUT SAW SAND INCREASE AT THE SHAKER SHOWING SIGNS OF HOLE CLEANING. - SINGLE IN HOLE WHILE REVERSE CIRCULATING CLEAN FROM TAG AT 7318' TO 7326'. - STROKE PIPE AND CIRCULATE CLEAN. PUMP 20 BBL HI -VIS SWEEP. - 0630 -Hrs, SWEEP RETURNED, BUT CARRIED VERY LITTLE FINES. - 0652 -Hrs, STOP CIRCULATING AND GET 140 -PSI ON DP. BLEED 3.5 -Bbls OFF DP TO 70 -PSI IN 4- MINUTES. BLEED 10 -Bbls OFF DP AND PRESSURE DROPPED TO 25 -PSI. IA PRESSURE 125 -PSI. - CONFER WITH ADW RWO EGR AND AGREE TO SLOW CIRCULATION RATE TO CIRC -OUT PRESSURE. 07:00 - 09:30 2.50 CLEAN P CLEAN REALIGN VALVES TO TAKE RETURNS THROUGH CHOKE. -START CIRCULATING AT 2.5 -BPM, 160 -PSI AND GET RETURNS IMMEDIATELY, FILL GAS BUSTER. - CONTINUE CIRCULATING 2.5 -BPM AND 170 TO 180 -psi WITH NO LOSSES TO THE WELL UNTIL 180 -Bbls PUMPED, THEN LOSSES SLOWLY INCREASE TO A TOTAL OF 5.1 -Bbls AFTER 250 -Bbls PUMPED. -TOTAL LOSS AFTER 310 -Bbls PUMPED IS 10 -Bbls. 09:30 -11:00 1.50 CLEAN P CLEAN MONITOR WELL, WELL DEAD AFTER 15- MINUTES. - BLOWDOWN CHOKE. - REALIGN VALVES AND BEGIN REVERSE CIRCULATING WITH 8.8 -PPG BRINE; BRING PUMP RATE SLOWLY UP TO 4 -BPM, 225 -psi AT 7324'. SLOWLY RIH TO 7327 AND SEE A SOLID BOTTOM. P/U V TO ENSURE STRING IS FREE; NO PROBLEMS. SLOWLY RIH WHILE REV CIRCING TO 7327' AND SEE A SOLID BOTTOM. - LOSING CALCULATED 108 -BPH WHILE REV CIRCING. -S /D PUMP TO POH TO P/U ANOTHER FULL JOINT. -BLEED OFF THE DP TO GET READY FOR P/U ANOTHER JOINT OF DP. 11:00 -12:30 1.50 CLEAN P CLEAN SAFETY STAND -DOWN WITH BOTH RIG CREWS (CREW TOUR CHANGE), WSL, AND ADW RWO SUPERINTENDENT TO DISCUSS THE MISTRAS TRAGEDY. EACH PERSON RESPONDED TO THE QUESTIONS RAISED IN VERY POSITIVE AND CONSTRUCTIVE TERMS. THEY RECOGNIZED THAT THEIR PERSONAL SAFETY WAS HIGHEST IMPORTANCE -- STAYING FOCUSSED AND IN THE MOMENT ALLOWS THEM TO GO HOME WITHOUT INJURY. 12:30 - 14:30 2.00 CLEAN P CLEAN PJSM WITH TOOLPUSHER AND WSL TO P/U DP JOINT TO RIH TO REVERSE CIRCULATE AND CLEANOUT W ELLBORE. -P /U DP JOINT AND WU TO STRING. GREASE THE TOOL JOINT, CLOSE THE HYDRIL, BREAK CIRCULATION. PUMP Printed: 12110/2009 11:15:25 AM 0 BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/19/2009 12:30 - 14:30 2.00 CLEAN P CLEAN 8.8 -ppg BRINE FROM PITS, RETURNS ARE 8.8 -ppg- HEAVY. - SLOWLY RIH AND INCREASE RATE FROM 2 -BPM AT 220 -psi, TO 4 -BPM AT 93 -psi (correct pres), TO 6 -BPM AT 340 -psi. CALCULATED LOSS RATE IS 105 -BPH WHILE REVERSE CIRCULATING. MAKE IT TO 7328', P/U AND RBIH AND LOSE 2' TO 7326'. - 1330 -hrs, CONTINUE TO REV CIRC 4.5 -BPM AT 200 -PSI AND DO NOT MAKE PROGRESS. P/U TO CHECK, RBIH AND LOSE V TO 7325'. WOB UP TO 17K -Ibs. - CALCULATED LOSS RATE 105 -13PH. STOP PUMPING WITH 290 -Bbls PUMPED. -P /U, RBIH AND STACK OUT AT 7322'. - 1400 -hrs, STOP PUMPING, P/U TO RBIH. STACK OUT AT 7322'. - CONSULT ADW RWO ENGINEER AND DECIDE TO USE A VISCOSIFIED SYSTEM AND CIRCULATION DOWN THE DRILLPIPE TO CLEANOUT WELLBORE. 14:30 -18:00 3.50 CLEAN P CLEAN B/D CHOKE/KILL LINE. L/D WORKING JOINT; R/U TO TOP DRIVE. -START PUMP AND BRING UP TO 7 -BPM AT 840 -psi. RIH AND STACK OUT AT 7322', WORK THROUGH AND STACK OUT AT 7324', WORK THROUGH AND STACK OUT AT 7326', WORK THROUGH AND CONTINUE RIH TO 7330'. -P /U TO CHECK FOR STICKING PIPE. RBIH AND SEE SAME STACK OUT AT 7322'. -P /U AND WORK 1/2 -TURN INTO STRING; CONTINUE RIH AND DO NOT STACK OUT; MARK PIPE FOR FUTURE REFERENCE. WORK ALL THE WAY TO 7331', BUT STOP AND CIRCULATE THERE TO WAIT FOR SWEEP BEFORE MOVING DOWNHOLE - CALCULATE A 45 -BPH LOSS RATE AFTER 150 -Bbls PUMPED. SEE ONLY VISCOUS OIL SHEEN ACROSS THE SHAKERS WITH A FINE SANDY FEEL TO THE FLUID WHEN RUBBED BETWEEN FINGERS. - 1545 -hrs, MIX AND PUMP 40 -Bbl HI -VIS SWEEP. - CALCULATED LOSS RATE DROPS TO 30 -BPH AFTER 250 -Bbls PUMPED DURING THE CIRCULATION OF THE SWEEP. - 1700 -hrs, DO NOT SEE ANY SAND IN EXCESS OF THAT REPORTED DURING THE NON- VISCOSIFIED LONG -WAY CIRCULATION, SO DECIDE TO KEEP MULESHOE PARKED AT 7330' AND WAIT TO VISCOSIFY THE FLUID SYSTEM IN ORDER TO PREVENT STICKING THE DP IN THE DEVIATED WELLBORE.. 18:00 - 20:00 2.00 CLEAN P CLEAN BUILD 8.8 -ppg FLO -PRO SYSTEM. - 1830 -hrs, CALLED AOGCC TO REQUEST WEEKLY BOP TEST FOR TOMORROW, A DAY EARLIER THAN SCHEDULED. - 1831 -hrs, CHUCK SCHEVE, AOGCC INSPECTOR, RETURNED CALL AND WAIVED STATE'S RIGHT TO WITNESS BOP TEST. 20:00 - 21:00 1.00 CLEAN P CLEAN DISPLACE WELL TO 8.8 ppg FLO -PRO. Printed: 12/1012009 11:15:25 AM BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/19/2009 20:00 - 21:00 1.00 CLEAN P CLEAN -PUMP RATE OF 1.4 BPM WITH 240 PSI. INCREASED UP TO 6.8 BPM WITH 660 PSI. -ONCE FLO -PRO HIT SHAKERS, SHAKERS BLINDED OFF. SLOWED PUMPS DOWN TO 1 BPM TO KEEP TOP DRIVE FROM FREEZING. 21:00 - 21:30 0.50 CLEAN P CLEAN LOCK AND TAG OUT SHAKERS. -CLEAN SCREENS AND REMOVE 1 SCREEN ON LOWER DECK OF SHAKERS TO KEEP MUD IN PITS. -80 MESH SCREENS ON TOP DECK. - OBTAINED ABILITY TO CIRCULATE AT 7 BPM. -LOSS RATE DROPPED TO 6 BPH DUE TO FLO -PRO. 21:30 - 00:00 2.50 CLEAN P CLEAN WASH DOWN TO 7331' ADJUST PUMP RATE TO 7 BPM WITH 6 BPH LOSSES AND 5K WOB. -NO FURTHUR PROGRESS. -P /U AND ROTATE STRING 1/4 ROTATION. RIH TO 7331' - CONTINUE TO ADJUST PUMP RATES AND ROTATE STRING 1/4 TURN WITH NO PROGRESS. -P /U AND PULLED ABOVE 7322' ATTEMPT TO RIH BUT KEPT STACKING OUT AT 7322'. - ROTATE AND FINALLY WORKED THROUGH TIGHT SPOT AT 7322'. -RIH TO 7331' AND TAG UP. NO PUMP PRESSURE INCREASE SEEN. ROTATE STRING A 114 ROTATION AT A TIME WITH NO PROGRESS. WITH NO PUMP PSI INCREASE DURING TAG UP AND NO CUTTINGS OR SAND SEEN ON B /U. SEEMS TO BE TAGGING UP ON BOTTOM OF LATERAL WINDOW. - CALLED TOWN ENGINEER AND DISCUSSED OPTIONS AT MIDNIGHT. DECIDE TO WORK AND ROTATE 1/6 ROTATION AT A TIME AND TRY TO WORK THROUGH OBSTRUCTION. 11/20/2009 00:00 - 02:00 2.00 CLEAN P CLEAN CONTINUE TO TRY AND WASH THROUGH TIGHT SPOT AT 7331' - ROTATING STRING 1/8 ROTATION AND ADJUSTING PUMP RATES WITH OUT SUCCESS. -SHUT PUMPS DOWN AND TAG UP DRY AT 7331'. -PUMP 20 BBLS HI -VIS SWEEP TO ENSURE CLEAN HOLE 7BPM WITH OFF BOTTOM PRESSURE OF 580 PSI, AND ON BOTTOM PRESSURE OF 580 PSI. 18 BPH LOSS RATE. - ROTATE STRING 7 TURNS AND PROGRESSED TO CLEAR OBSTACLE AT 7331' AND CONTINUE TO WASH AND CLEAN HOLE DOWN TO 7349'. IN V INCREMENTS. 02:00 - 08:00 6.00 CLEAN P CLEAN CONTINUE TO WASH DOWN FROM 7349'. - WASHING DOWN IN V INCREMENTS AND WIPING THE HOLE BACK UP TO 7335' NOT WANTING TO GET ABOVE TIGHT SPOT. -RATE OF 7 BPM AND 540 PSI WITH LOSSES AT 12 BPH. -AT 7355' CBU AND SAW VERY SMALL AMOUNTS OF SAND. -MAKE CONNECTION AND CONTINUE TO WASH DOWN TO 7420' AT 0500 HRS. - 0700 -hrs, WASH DOWN TO 7430'; 7 -BPM, 600 -PSI, LOSS RATE 18 -13PH. CONTINUE TO WASHDOWN TO 7452'. Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 11/20/2009 08:00 - 09:00 1.00 CLEAN P CLEAN PUMP 40 -Bbls HI -VIS SWEEP, 7 -BPM AT 600 -psi, LOSS RATE 15 -BPH. STOP PUMP AND MONITOR WELL AFTER TOTAL 442 -Bbls IS PUMPED. - CONFER WITH ADW RWO Engrg TEAM LEAD. DECIDE TO POH AND P/U ADDITIONAL 2 -7/8" FOX TO MAKE MORE CLEANOUT HOLE. ALSO DECIDE TO POH TO JUST ABOVE THE 7 -5/8" LINER TIEBACK AT 7282' TO RBIH TO ENSURE WE CAN GET BACK THROUGH BOTH LEMS. 09:00 - 09:30 0.50 CLEAN P CLEAN ALLOW DP TO BLEED DOWN TO BEGIN POH FOR RE -ENTRY THROUGH LEMS AT 7320' AND 7424'. 09:30 - 10:00 0.50 CLEAN P CLEAN PJSM WITH RIG CREW, TOOLPUSHER, AND WSL TO DISCUSS POH AND L/D 5- JOINTS OF DP, HOWEVER WSL STARTED BY ASKING RIG CREW IF THEY RECEIVED ANY MESSAGE FROM THE MISTRAS TRAGEDY INFORMATION- SHARING SAFETY STAND -DOWN YESTERDAY. ONE MAN SAID IT'S THE SMALL THINGS THAT COUNT ". WE DISCUSSED ONE PERSON'S NOT WEARING SEATBELTS FOR A SHORT DRIVE ACROSS THE PAD, AND ANOTHER CREWMAN WHO WAS NOT WEARING A FACE SHIELD WHILE USING A WASHDOWN HOSE: THE SMALL THINGS. 10:00 - 10:30 0.50 CLEAN P CLEAN POH AND LID 5- JOINTS OF DP. 10:30 - 12:00 1.50 CLEAN P CLEAN P/U DP STAND FROM DERRICK AND RIH SLOWLY TO WORK THROUGH OBSTRUCTIONS IN THE LEMS AT 7320' AND 7424'. - 7324', SET DOWN -1 -2K -Ibs, P /U, ROTATE 1 -TURN AND RIH. - 7331', SET DOWN 1 -2K -Ibs, P /U, ROTATE 3/4 -TURN AND RIH. - 7394', SET DOWN 1 -2K -Ibs, P /U, ROTATE 1 -TURN; REPEAT SAME STEPS 1 -TIME AND RIH. - 7423', SET DOWN 1 -6K -Ibs, P/U NUMEROUS TIMES FROM 3' TO 10', ROTATE NUMEROUS TIMES FROM 1/4 -TURN TO 1 -1/2- TURNS. START PUMP AND BRING UP TO 4 -BPM, TRY SEVERAL TIMES USING VARIOUS DEGREES OF ROTATION AND P/U HEIGHT AND CANNOT GET THROUGH OBSTRUCTION AT 7423'. CANNOT GET BACK TO MAX WASHDOWN DEPTH OF 7452'. - CONFER WITH ADW RWO LEAD Egr AND DECIDE TO POH, S/B DP, LID 2 -7/8" FOX TUBING, CHECK AND RE -DRESS MULESHOE. 12:00 - 13:00 1.00 CLEAN P CLEAN BLEED DOWN DP, BUT WELL KEEPS FLOWING AT A VERY LOW RATE AND DOES NOT BLEED OFF AS IN PREVIOUS BLEED -DOWN OPS AFTER CIRCULATING. -S /I WELL AND GET 20 -psi ON DP AND 75 -psi ON IA. PIT GAIN OF 4 -Bbls. -OPEN WELL TO BLEED OFF PRESSURE AND IT DIES. BREAK -OFF HEAD PIN AND WELL STARTS TO FLOW AT A VERY LOW RATE. - CIRCULATE THROUGH CHOKE 2.5 -BPM AT 200 -psi; 3 -BPM AT 260 -psi; 13:00 - 17:00 4.00 CLEAN P CLEAN CIRCULATE THROUGH CHOKE 2.5 -BPM, @ 200 -psi; 3 -BPM ® 260 -psi. Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/20/2009 13:00 - 17:00 4.00 CLEAN P CLEAN - CIRCULATE UNTIL ALL RETURNS ARE 8.8 ppg. -LOSS RATE WHILE CIRCULATING =19 BPH. 17:00 - 17:30 0.50 CLEAN P CLEAN RIG DOWN CIRCULATION EQUIPMENT. -OPEN BAG AND MONITOR WELL. SLIGHT FLOW BACK WAS NOTICED. 17:30 - 20:30 3.00 CLEAN P CLEAN RIG UP CIRCULATION EQUIPMENT. - CIRCULATE AT 3 BPM WITH 160 PSI WITH LOSS RATE OF 10 BPH. - WEIGHT UP SYSTEM TO 9.0 ppg WHILE CIRCULATING. 20:30 - 21:00 0.50 CLEAN P CLEAN MONITOR WELL - WELL STATIC. -PUMP DRY JOB AND RIG DOWN CIRCULATION EQUIPMENT. 21:00 - 00:00 3.00 CLEAN P CLEAN POH FROM 7295' TO 193' - STANDING BACK DP IN DERRICK. 11/21/2009 00:00 - 02:00 2.00 CLEAN P CLEAN C/O PIPE HANDLING EQUIPMENT. -L/D 2 -7/8" FOX TBG. -CLEAN AND CLEAR RIG FLOOR. -PULL WEAR RING. -NOTE: BOTTOM 4 JOINTS OF 2 -7/8" FOX TUBING WERE BENT. -DRAIN STACK AND SET UPPER TEST PLUG. -R/U LINE TO I/A TO KEEP HOLE FULL WHILE TESTING BOPE. 02:00 - 09:30 7.50 CLEAN P CLEAN PJSM WITH RIG CREW, TOOLPUSHER, AND WSL. - 1831 -hrs, 11/19/2009, CHUCK SCHEVE, AOGCC INSPECTOR, WAIVED STATE'S RIGHT TO WITNESS BOP TEST. -TEST BOPE TO 250 -PSI LOW, 3500 -PSI HIGH USING 2-7/8',4", AND 4 -1/2" TEST JOINTS; TEST HYDRIL WITH 2 -7/8" TEST JOINT; RECORDING ALL TESTS ON CHART RECORDER FOR 5 MIN. - FILLING HOLE THROUGH IA. CURRENT LOSS RATE OF 6 BPH AT 0500 hrs. -ALL TESTS WITNESSED BY WSLs AND TOUR/TOOLPUSHER. -GAVE THE WELL A DRINK DOWN THE IA OF 5- 7 -Bbls EVERY 45 TO 60- MINUTES. 09:30 - 10:00 0.50 CLEAN P CLEAN R/D BOPE TEST EQUIPMENT. CLEAR RIG FLOOR AND PREPARE TO WU MULESHOE CLEANOUT BHA. -PULL TEST PLUG. HOLE WAS FULL AND STATIC WHEN TEST PLUG WAS PULLED. - INSTALL WEAR RING. 10:00 - 15:00 5.00 CLEAN P CLEAN R/U FOR RIH WITH 2 -7/8" MULESHOE AND FOX TUBING CLEANOUT BHA. - ESTABLISH PARAMETERS OF 112K UP, 90K DOWN. -PUMP RATE OF 4 BPM WITH 300 PSI AND 15 BPH LOSS RATE. 15:00 - 00:00 9.00 CLEAN P CLEAN RIH FROM 7282' AND WORK THROUGH LEMs. -TIGHT SPOT SEEN AT 7365'. ROTATE 1/4 TURN AND WORKED DOWN. -TIGHT SPOT SEEN AT 7394'. WORKED DOWN. -TIGHT SPOT SEEN AT 7427'. P/U AND TAG AGAIN. ROTATE 1/4 TURN AND WORKED DOWN WHEN IT Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 11/21/2009 15:00 - 00:00 9.00 CLEAN P CLEAN STARTED WASHING OFF. - WASHED DOWN FROM 7427' TO 7438' P/U AND WORK PIPE. -RIH NO SIGNS OF NEEDING TO WASH. RAN DOWN TO 7458' AND TAGGED UP. WORKED UP AND ROTATED 1/2 TURN. WORK DOWN. INCREASE PUMP RATE TO 6 BPM AND WASHED DOWN TO 7458'. -P /U AND CLEAR PIPE AND HOLE CONTINUE TO WASH DOWN FROM 7458' TO 7487' AND TAG AGAIN. - CONTINUE TO WORK PIPE WITH PUMP RATE AND 1/4 TURN ROTATIONS WORKING THROUGH AND WASH DOWN TO 7518' AND TAG. —30 TAG ON EACH OF ABOVE. -TAG AGAIN AT 7531'. P/U 15' AND RIH SHOWING DRAG OF 3K WHILE RIH. PUMP HI -VIS SWEEP AND WORK PIPE 15'. NOTHING SEEN AT SHAKERS BUT SAND. -HOLE SHOW NO DRAG WHILE RIH TO 7531'. BEGIN WASHING DOWN TO 7544' WITH 6 BPM AND 615 PSI. TAG UP AGAIN AT 7544' AND P/U WITH A 10K OVERPULL. WORK PIPE AND CIRCULATE UNTILL NO INCREASE IN WEIGHT WAS, SEEN UP OR DOWN AT 7544' -BEGIN WASHING DOWN FROM 7544' SLOWER WITH ONLY 1 K TO 2K WOB ALLOWING TIME TO WASH OFF 1 K. WORK A MAXIMUM OF 5' OF HOLE BEFORE WIPING. -WASH DOWN TO 7625'. SLOWLY WORKING DOWN AND WIPING HOLE EVERY 5'. -LOSS RATE AT MIDNIGHT - 30 BPH. 11/22/2009 00:00-11:00 11.00 CLEAN P CLEAN CONTINUE TO WASH DOWN FROM 7625'. -WASH DOWN V INCREMENTS THEN WIPE HOLE 15'. -6 BPM AT 625 PSI AND 30 BPH LOSSES. -1 -4 K WOB. ANY INCREASE IN WOB SHOWS A INCREASE IN PUMP PRESSURE AND BECOMES STICKY. - CONTINUE WASHING DOWN @ 0400 HRS 7720'. -EVERY —30' BECOMES TIGHT. WORK THROUGH WITH A 5 -6 K WOB, THEN FALLS OFF WITH NO PRESSURE INCREASE. (COLLAR) -0800 hrs. WASHING DOWN. CURRENTLY AT 7827' WITH 6 BPM AND 700 PSI WITH 12 BPH LOSSES. -EVERY 30' STILL GETTING TIGHT VIA COLLARS. -1100 hrs WASHED DOWN TO 7870' WITH 6 BPM AT 720 PSI AND 12 BPH LOSS RATE. 11:00 -12:00 1.00 CLEAN P CLEAN CIRULATE 20 BBL HI -VIS SWEEP. -7 BPM WITH 850 PSI. 66 BPH LOSSES. - SLOWED RATE TO 6 BPM WITH 730 PSI. 36 BPH LOSSES. -SAND SEEN AT SURFACE. 12:00 - 14:00 2.00 CLEAN P CLEAN -WELL NOTED TO HAVE SLIGHT FLOW. P/U ON STAND AND SWABBING WAS SEEN. PUMP OUT TO GET ABOVE LINER TOP TO 7255' @ 3BPM AND 230 PSI. -BLOW DOWN TOP DRIVE. - MONITOR WELL. NOTED TO HAVE SLIGHT FLOW. 14:00 - 16:00 2.00 CLEAN P CLEAN PJSM. DISPLACE WELL TO 9.0 PPG CLEAN BRINE. -PUMP 20 BBL HI -VIS SWEEP. -CHASE SWEEP WITH 9.0 PPG BRINE. -RATE OF 6 BPM @ 760 PSI. Printed: 12/10/2009 11:15:25 AM i BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/22/2009 16:00 - 16:30 0.50 CLEAN P CLEAN MONITOR WELL. -WELL NOTED TO HAVE SLIGHT FLOW. 16:30 - 18:30 2.00 CLEAN P CLEAN R/U CIRCULATION EQUIPMENT. - WEIGHT UP SYSTEM (WITH NACL) TO 9.1 PPG @ 6 BPM AND 920 PSI. - MONITOR WELL - WELL NOTED TO BE ON A SLIGHT VAC. 18:30 - 00:00 5.50 CLEAN P CLEAN PULL OUT OF HOLE FROM 7255' TO 2640' -LOSS RATE OF 3 BPH. 11/23/2009 00:00 - 00:30 0.50 CLEAN P CLEAN CONTINUE TO POH LAY DOWN DRILL PIPE. -FROM 2640' TO 1474'. 00:30 - 03:00 2.50 CLEAN N WAIT CLEAN STAND DOWN OPERATIONS AS CH2MHILL BED TRUCK CAUGHT ON FIRE AND LEAKED HYDRAULIC FLUIDS. EMS AND FIRE WAS DISPATCHED AND SRT WAS SENT OUT TO CLEAN LOCATION. WITH NO ACCESS TO PAD AS TRUCK WAS ON ACCESS ROAD THE RIG OPERATIONS WHERE STOPPED UNTIL ACCESS TO RIG WAS GRANTED. THE WELL WAS SECURED AND LOSS RATE MONITORED AT 3 BPH. -FIRE SAFETY WAS DICUSSED BETWEEN CREWS. A LIST WAS FORMED AND IT WAS NOTICED THAT VEHICAL FIRE EXTINQUISHERS WHERE IN QUESTION. THE HAND THEN INSPECTED ALL VEHICAL FIRE EXTINQUISHERS. 03:00 - 06:00 3.00 CLEAN P CLEAN CONTINUED TO POH L/D DRILL PIPE. -FROM 1474' TO 810'. -L/D DRILL COLLARS AND BUMPER SUB. -R/U 2 -7/8" TBG HANDLING EQUIPMENT. -L/D 2 -7/8 FOX TUBING FROM 613'. - MONITOR WELL 3 BPH LOSS RATE. 06:00 - 06:30 0.50 CLEAN P CLEAN CLEAN AND CLEAR RIG FLOOR. -PULL WEAR RING. 06:30 - 09:30 3.00 RUNCOMP RUNCMP R/U TO RUN 4.5" 12.6# VAM TOP 13Cr80 COMPLETION. -P /U POWER TONGS, ELEVATORS, ETC. 09:30 - 10:00 0.50 RUNCOMP RUNCMP PJSM FOR RUNNING COMPLETION. -P /U SEAL ASSEMBLY. - NOTICED PROBLEM WITH POWER TONGS. 10:00 -11:00 1.00 RUNCOMP RUNCMP TROUBLE SHOOT POWER TONGS. -DUMP VAVLE WAS THE ISSUE. -L/D AND P/U BACK UP POWER TONGS. -R/U [-WIRE EQUIPMENT. 11:00 - 00:00 13.00 RUNCOPF RUNCMP CONTINUE RIH WITH COMPLETION. -BAKER LOC ALL CONNECTIONS BELOW PACKER. -JET LUBE SEAL GUARD USED ON CONNECTIONS. - TORQUE TURN ALL CONNECTIONS. - SINGLE JOINT COMPENSATOR AND STABBING GUIDE USED THROUGHOUT JOB. -TEST I -WIRE AND SENSOR EVERY 1000' WHILE RIH. 11/24/2009 00:00 - 02:00 2.00 RUNCOMP RUNCMP CONTINUE RIH WITH 4.5" COMPLETION. -FROM 6899' TO 7280' NO GO AND STACK 10K DOWN. -UP WEIGHT OF 102K. DOWN WEIGHT OF 79K WITH BLOCKS. -P /U AND RE TAG AT 7280' - CALCULATE SPACE OUT PUPS. -L/D JT 165, 164, AND 163. Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/24/2009 00:00 - 02:00 2.00 RUNCOhF RUNCMP -M/U 8' PUP AND 10' PUP. -M /U JT 163. -LOSS RATE OF 3 BPH. -SEAL ASSY AT 7277'. TOP OF LINER AT 7270'. NO -GO AT 7280' - CLAMPS USED = 81 FULL CLAMPS AND 18 HALF CLAMPS USED ON I -WIRE. 1 CLAMP USED FOR THE FIRST 10 JTS AND 1 CLAMP EVERY OTHER JT. 02:00 - 05:00 3.00 RUNCOMP RUNCMP PJSM M/U TUBING HANGER. -P /U HANGER ON LANDING JT AND WU TO TUBING STUB. - TERMINATE I WIRE TO HANGER AND TEST. -R/U TO REVERSE CIRCULATE. 05:00 - 08:00 3.00 RUNCOPF RUNCMP PJSM AND REVERSE CIRCULATE 115 BBLS CLEAN 9.1 PPG BRINE (120 F) FOLLOWED BY 200 BBLS 9.1 PPG BRINE AND CORROSION INHIBITOR AT 3 BPM AT 118 PSI. 08:00 - 08:30 0.50 RUNCOMP RUNCMP MONITOR WELL. WELL DEAD. -DRAIN STACK AND LAND TBG HANGER. - RILDS. -BLOW DOWN KILL LINE AND CIRCULATION MANIFOLD. -DROP ROLLER BALL. 08:30 - 12:30 4.00 RUNCOMP RUNCMP PRESSURE UP TUBING TO 4200 PSI AND SET PACKER HOLDING FOR 10 MINUTES. -BLEED TUBING DOWN TO 3500 PSI AND CHART FOR 1 HR. -BLEED DOWN TUBING TO 2800 PSI AND LINE UP TO IA AND PRESSURE UP IA TO 3500 PSI FOR 30 CHARTED MIN. -BLEED OFF PRESSURE AND PUMP DOWN IA TO SHEAR DCK VALVE AT 2400 PSI. - PUMPED DOWN IA AT 3 BPM AND 500 PSI. -LINE UP AND PUMP DOWN TUBING AT 3 BPM AND 750 PSI, -PULL LANDING JOINT. 12:30 - 13:30 1.00 RUNCOMP RUNCMP PJSM AND SUCK OUT STACK. - INSTALL TWC AND TEST FROM ABOVE TO 3500 PSI AND FROM BELOW TO 1000 PSI FOR 10 CHARTED MINUTES. - GOOD TESTS 13:30 -14:00 0.50 RUNCOMP RUNCMP BLEED DOWN LINES AND RIG DOWN CIRCULATION EQUIPMENT. 14:00 -16:30 2.50 BOPSUF P WHDTRE PJSM FOR R/D BOPE. - REMOVE 2 -7/8" X 5" VBR RAMS FOR SERVICE. -N /D BOP STACK. 16:30 - 20:30 4.00 BOPSUF P WHDTRE CLEAN AND PREP WELL HEAD AND TREE. -TEST 1 -WIRE. GOOD TEST, - NIPPLE UP ADAPTER FLANGE AND TREE. 20:30 - 22:00 1.50 BOPSUF P WHDTRE PJSM WITH FMC AND HANDS. - ATTEMPT TO TEST ADAPTER FLANGE AND TEST. - MANIFOLD FAILED. INSTALL BACK UP MANIFOLD. -TEST ADAPTER FLANGE TO 5000 PSI FOR 30 MIN. - GOOD TEST. 22:00 - 00:00 2.00 BOPSUF P WHDTRE PJSM FOR TREE TEST. -FILL TREE WITH DIESEL AND TEST TO 5000 PSI FO 10 CHARTED MIN. - GOOD TEST. Printed: 12/10/2009 11:15:25 AM BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: L -200 Common Well Name: L -200 Spud Date: 1/15/2004 Event Name: WORKOVER Start: 5/10/2009 End: 11/25/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 11/25/2009 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Task Code NPT Phase Description of Operations 11/25/2009 00:00 - 00:30 0.50 BOPSUF P WHDTRE DRAIN TREE. -BLOW DOWN CELLAR MANIFOLD. 00:30 - 01:30 1.00 WHSUR P WHDTRE PJSM -RIG UP DSM LUBRICATOR. -TEST LUBRICATOR TO 500 PSI.- GOOD TEST. -PULL TWC. -LD LUBRICATOR AND TWC. 01:30 - 05:30 4.00 WHSUR P WHDTRE PJSM FOR FREEZE PROTECTING WELL. -R/U LINES AND TEST TO 2000 PSI. - REVERSE CIRCULATE 85 BBL OF 80 DEGREE DIESEL AT 2 BPM WITH 900 PSI. -SWAP LINES AND LET WELL U -TUBE FOR 1 HOUR. LINES STILL NOTED TO BE FLOWING WITH -200 PSI ON GAUGE. ALLOWING TO U -TUBE LONGER. -BLEED OFF 2 BBLS AND PRESSURE DROPPED TO 80 PSI. - MONITOR WELL FOR 15 MINUTES AND PRESSURE INCREASED TO 135 PSI AND STABILIZED. -BLEED ANOTHER 2 BBLS OFF. PRESSURE DROPPED TO 100 PSI THEN INCREASED TO 135 PSI. 05:30 - 07:00 1.50 WHSUR P WHDTRE HOLD PJSM ON SETTING BPV WITH DSM LUBRICATOR. -PU DSM LUBRICATOR & SET BPV. -GAUGE ON LUBRICATOR SHOWS 140 -PSI ON TUBING PRIOR TO SETTING BPV. -BLEED PRESSURE OFF OF TREE. -LD LUBRICATOR. 07:00 - 07:30 0.50 WHSUR P WHDTRE USE LRS TO TEST BPV BELOW TO 1000 -PSI FOR 10- CHARTED MINUTES. -GOOD TEST. 07:30 - 09:00 1.50 WHSUR P WHDTRE RD CIRCULATING LINES. - REMOVE SECONDARY ANNULUS VALVE. - INSTALL ALL GAUGES ON TREE, - TUBING PRESSURE = 140 -PSI PRIOR TO SETTING BPV, IA PRESSURE = 100 -PSI AND OA PRESSURE = 0 -PSI. - SECURE WELL. - RELEASE RIG AT 0900 -HRS ON 11 -25 -2009. I Printed: 12/10/2009 11:15:25 AM i TREE =, 4- 1/16" CNV • L �oo WELLHEAD= 11' FMC S ES: CHROME TUBING ACTUATOR = BAKER L 1 & L2 KB. ELEV = 77.6' BF. ELEV = 53.80' KOP= 380' DRLG DRAFT 985' 10 -3/4 "TAM PORT COLLAR Max Angle = 96 @ 11569' Datum MD = 7515' 2174' 4 -112" HES X NIP, iD = 3.813" Datum TV D = 4400' SS GAS LIFT MANDRELS 20# CONDUCTOR 114 ST MD TVD DEV TYPE VLV LATCH PORT DATE 10 -3/4" CSG. 45.5 #, L -80, ID = 9.95" 3871 6 3448' 2436' 60 KBG -2 DOME BK 16 12/04/09 5 3565' 2495' 59 KBG-2 DMY BK 0 11/21/09 Minimum ID = 3.813" @ 4 5373' 3433' 57 KBG -2 DOME BK 16 12/04/09 3 5490' 3498' 55 KBG-2 DMY I BK 0 11/21/09 4 -1/2" X- NIPPLE 2 6646' 4068' 68 KBG -2 DMY BK 0 11/21/09 G 6983' 1 6888'14157'1 68 KBG -2 SO BK 22 112/04/091 RA TA Sapphire pressure gauge 7035' 7051' 4-1/2" BKR CMD Sliding SLV ID 33.813" II Sapphire pressure gauge 7066' 7087' 7 -5/8" X 4 -1/2" BKR Prennier packer, ID = 3.875 7122' 4 -112" X nipple, ID = 3.813 4.5" 12.6# 13Cr -80 Vam Top tubing 7266' 7193' 4 -1/2" X nipple w/ RHC-M Lock, IF RA TAG 7270' r 7277 5.75" Seal Stem (Seals Removed), ID = 4.83" 7270' M 7 -5/8" X 4 -1 /2" BKR ZXP LTP w /TIEBK, ID = 5.750" 5 -1/2" X 4 -1/2" XO, ID = 3.930" 7301' L2 (OBa) LEM WINDOW 65° BAKER HOOK HANGER 7315 L2 (OBa) 7320'-7331' w /L2 NON -SEALING LEM, ID = 3.71" - - - - - - - - - - - - - - - - OPENING WIDTH = 3.33" OBa PBTD 13043' RA TAG 7375' 7 - 5/8" X 5 - 112" BKR ZXP LTP, ID = 4.94 1 7386' 7315' 13044' 6 - 3/4" OBa LATERAL, ID = 3.958" 5 -1/2" X 4 -1/2" XO, ID = 3.930" 7405 7398' 4 -1/2" MULE SHOE ID = 3.958" L1 (OBb) LEM WINDOW 64° BAKER HOOK HANGER 7419' L1 0613} 7424'- 7435' w/ L1 NON - SEALIN LEM, ID = 3. 71" _ _ _ _ _ _ _ (OBb) _ i L ENING WIDTH = 3.33" PERFORATION SUMMARY OBb PBTD 12987' REF LOG: ANGLEATTOP PERF: 7419' 12988' 6 - 3/4" OBb LATERAL, ID = 3.958" Note: Refer to Production DB for historical pert data SIZE SPF I I INTERVAL I Opn /Sqz 1 4 -1/2" SLTD OBa 7392 - 13000 0 02/18/04 7537 7 -5/8" X 5 -1/2" BKR ZXP LNR TOP PKR 4 -1/2" SLTD OBb 7497 - 12944 O 02/12/04 7548 4 -1/2" MULE SHOE, ID = 3.958" 4 -1/2" SLTD OBd 7870 - 13008 0 02/04/04 7557 5 -1/2" X 4 -1/2" RA TAG 7663' 7 -5/8" CSG, 29.7 #, L -80 BTC-M, ID = 6.875" 7872' I I I I IL -2001 7572'- 13052' 6 -3/4" OBd LATERAL, ID = 3.958" OBd PU 13050' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/22/04 N9ES ORIGINAL COMPLETION WELL: L -200 11/25109 D16 RWO PERMIT No: 2040010 (020) (030) 11/26/09 SV DRLG HO CORRECTIONS API No: 50- 029 - 23191 -00 (60)(61) 12/12/09 ACB /SV GLV C/O (12/04/09) SEC 34, T12N, R1 112, 2567' FSL & 1575' FEL BP Exploration (Alaska) ~ • -~ -_ MICROFILMED 03/01/2008 DO NOT PLACE ~.-- ,~. ~_- :~ ANY NEW MATERIAL UNDER THIS PAGE F: ~I,aserFiche\CvrPgs_Inserts~licrofilm_Marker. doc SclllunlHrger 3 t-\ /c9 .·tt 00 0¡4 ~ \~ 06109/06 NO. 3838 Schlumberger-DCS 2525 Gambell St, SuRe 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Alln: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Borealis Well Job # Log Description Date BL Coior CD e L-200U! 40010090 OH LDWG EDIT OF MWD/LWD 02/18/04 2 1 Z·108· 11225977 SCMT 06/04/06 1 L-214A 11217230 USIT 03/16/06 1 L·215 10913049 USIT 09/26/05 1 PLEASE ACKNOWLEDGE RECEIPT BY SiGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered' CD (11..1/ r){~J Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838~1 ATTN Beth , f) i ReceIVed by (~ ,'. ~ " ,----~ e RECe\VED ,.,. Inn') ,-.. "', ~..l ,\,' ~~. fJ """.,.,,,, ~'-" 'i" !o-','\', r.:.t;' v <.úá .!. ~'~4~\¡~>~ :J_-~ tJUN 1 4 2006 l\1aska Oil & Gas Cons. Commission Anchorage ,. .:z 5 Mo. Y\.lA DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2040030 Well Name/No. PRUDHOE BAY UN ORIN L-200L2 Operator BP EXPLORATION (ALASKA) INC .S/¡ ~¿ I '-I r~t& J.. ~~ C{, API No. 50-029-23191-61-00 MD 13115 / TVD 4234 " Completion Date 2/23/2004- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No ----~. Directional surv(~~ ~ -~,. DATA INFORMATION Types Electric or Other Logs Run: MWD 1 GR 1 RES 1 Azimuthal DEN 1 NEU 1 AIM / PWD Well Log Information: (data taken from Logs Portion of Master Well Data Maint Electr Digital Dataset Med/Frmt Number Log/ Data Type I I t~""D I Rpt ~_~. Log Log Scale Media Run No Interval Start Stop Name t\ ." Ì"u.\ Wfd I" $_ " Directional Survey Directional Survey o 13115 o 13115 Well Cores/Samples Information: . OHI CH Received Comments 3/23/2004 ~~spr"'= 3/23/2004 I Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~~ QN Daily History Received? r".. l:Q/ N Formation Tops Analysis Received? m:¡--' . Comments: e....~ . I r·",. U v\. ßv'^-~ zt::¿~ ~~g;Jo- C ì -:- '~'17 ) N V\~..tw, (-q¡'^Wlt'-l':"" þV. C-l·,.... .,À. Mev\.. M~ G ~ t ill ¡ v t. _.__.__.~.._-- Compliance Reviewed By: Date: ~ ~- ~{~ ~- .. .. STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ ß IkJ ~ ~ ~ Revised:fi)§/1ztVMi ~utò~i~r~d. uction }-.;''''-,:'-'-';:'',',:,,:,-,;. .,,',',. .. , JUN 1 ii 2004 1a. Well Status: ŒI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 ŒI Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 2/23/2004 204-003 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/14/2004 50- 029-23191-61-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2/17/2004 PBU L-200L2 2568' NSL, 3704' WEL, SEC. 34, T12N, R11E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 1998' NSL, 3391' WEL, SEC. 27, T12N, R11 E, UM 77.6' Prudhoe Bay Field I Orion Total Depth: 9. Plug Back Depth (MD+ TVD) 249' NSL, 2669' WEL, SEC. 21, T12N, R11 E, UM 13115 + 4234 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 583209 y- 5978290 Zone- ASP4 13115 + 4234 Ft ADL 047447 TPI: x- 583461 y- 5983003 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 578858 y- 5986483 Zone- ASP4 (Nipple) 2949' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ŒI Yes DNo N/ A MSL 1900' (Approx.) 21. Logs Run: MWD I GR I RES I Azimuthal DEN I NEU I AIM I PWD 22. CASING, LINER AND CEMENTING RECORD ~~r~~~ !i SETTING DËPJ11MD SËT"rING [ EPJ; .{1\ID ~?z1?i .¡. ii ..¡¡. Ç'Þb~~~6' 'w':r,PÊRf:r. I.3RADI:: iI.QRi.i TÔP B()TTQM 1....!5"',,;:,~ ¡'i'ii, 20" x 34" 215.5# A53 Surface 108' Surface 108' 48" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 29' 3871' 29' 2653' 13-1/2" 723 sx AS Lite, 338 sx Class 'G' 7-5/8" 29.7# L-80 27' 7320' 27' 4319' 9-7/8" 515 sx Class 'G' 4-1/2" 12.6# L-80 7315' 13044' 4316' 4229' 6-3/4" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. " ,i 1 JarNG. i, ,,' Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, L-80 7296' 7169' MD TVD MD TVD 7392' - 7434' 4344' - 4355' ~p, ¡'i Aé,l"I _, vEM :I.Ni ¡:T~ 7444' - 13000' 4357' - 4225' ii..· DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 125 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): May 17, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF W A TER-BSl CHOKE SIZE I GAS-Oil RATIO 6/10/2004 12 TEST PERIOD ... 829 828 -0- 70 Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 580 1540 24-HoUR RATE 1,658 1,656 -0- 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RiI.:Ø BFi 1M 1 t~ J,\i~ ..... ...... . __ ." .. A ~ ~ ß .v;:..\ .. . A I <, ".\'('\\'7'.,' ;)U '.? Form 1 0-407 Revised 12/2003 . I~~ f~F\E~~S!~I~E I" <ft ~ ..9 .. ..... GEOLOGIC MARKERS /' -. ~: 29. ~ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Schrader Bluff OBa 7319' 4318' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. ~I'" II flMn Terne Hubble /1 O/IJl1~ tNllll1\J '" PBU L-200L2 ' 204-003 Well Number Title Technical Assistant Date bto "/1· 0'-1 Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Michael Triolo, 564-5774 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 .. STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COMrJI"/!SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD / GR I RES I Azimuthal DEN / NEU I AIM I PWD CASING, LINER AND CEMENTING RECORD :;;>W'N$~I:F"I'fIMD,' .:;;>m!N@JI:ÞtHTVDd<iL..§/· TQp ItroJ'TQM ·1 OF'.6QJ'TOM ..;)1,41: Surface 108' Surface 108' 29' 3871' 29' 2653' 27' 7320' 27' 4319' 7315' 13044' 4316' 4229' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2568' NSL, 3704' WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 1998' NSL, 3391' WEL, SEC. 27, T12N, R11E, UM Total Depth: 334' NSL, 2584' WEL, SEC. 21, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583209 y- 5978290 Zone- ASP4 TPI: x- 583461 y- 5983003 Zone- ASP4 Total Depth: x- 578943 y- 5986569 Zone- ASP4 18. Directional Survey IBI Yes 0 No 22. vsf~ËU WT. PeR FT. 215.5# 45.5# 29.7# 12.6# GRADE A53 L-80 L-80 L-80 20" x 34" 10-3/4" 7-5/8" 4-1/2" 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Slotted Section MD TVD MD TVD 7392' - 7434' 4344' - 4355' 7444' - 13000' 4357' - 4225' 26. Date First Production: Not on Production Yet Date of Test Hours Tested One Other 5. Date Comp., Susp., or Aband. 2/23/2004 6. Date Spudded 2/14/2004 7. Date T.D. Reached 2/1712004 8. KB Elevation (ft): 77.6' 9. Plug Back Depth (MD+ TVD) 13115 + 4234 10. Total Depth (MD+TVD) 13115 + 4234 11. Depth where SSSV set (Nipple) 2949' MD 19. Water depth, if offshore NIA MSL 48" 13-1/2" 9-7/8" 6-3/4" 24. Size 4-1/2", 12.6#, L-80 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-003 13. API Number 50- 029-23191-61-00 14. Well Name and Number: PBU L-200L2 15. Field / Pool(s): Prudhoe Bay Field I Orion Ft Ft 16. Property Designation: ADL 047447 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) . P~~lE~ 260 sx Arctic Set (Approx.) 723 sx AS Lite, 338 sx Class 'G' 515 sx Class 'G' Uncemented Slotted Liner 1 JBING DEPTH SET (MD) 7296' PACKER SET (MD) 7169' 125. ACID, VI:M":I'II r::TI" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 125 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-Bsl GAs-McF WATER-Bsl CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water ~ ,epI!!1lMS/I~rtfv1ecessary). Submit core e'F; ,if n~ne, state "none". r\ I:: V r: I ~ I:: U None ~ f APR - I 2004- ~j 0 RIG I N A L AI"ka Oil & Gas COn.!. Commission ...._-_~...;;..J Anchoraae "bnnl, Wt( U LV.... PRODUCTION FOR TEST PERIOD .. CALCULATED .-a... 24-HoUR RATE""" Oll-Bsl Flow Tubing Casing Pressure Press. 27. Form 10-407 Revised 12/2003 GAs-McF WATER-Bsl CONTINUED ON REVERSE SIDE CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) RßDUS BfL t,ç:: 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Schrader Bluff OBa 7319' 4318' None RECEIVED APR - 1 2004 Alaska Oil & G C ,~ . as ons. Gornml;;'¡¡H.!l1 Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 0 <1 ,0 I.. D I PBU L-200L2 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 A4ichaelTriolo, 564-5774 204-003 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OQIG Legal Name: Common Name: Test Date 1/23/2004 LOT 1/29/2004 FIT 2/5/2004 FIT 2/13/2004 FIT 2/14/2004 FIT BP Leak-Off Test Summary Page 1 of 1 L-200 L-200 Test Ty~__ ,_1._ Test De~~h á-~~U~T~~~ ~~-p'~,h (~D) ... ..~_..~=~~~w .~~'::-=J Surface P~!~~_~~~ ~::) ~~.!~-~_,~ff Pr~;su~~~~t! --=~·..E.M~ --==~ (ft) (ft) (ppg) (psi) (psi) (ppg) 7,872.0 (ft) 4,483.0 (ft) 9.20 (ppg) 670 (psi) 2,813 (psi) 12.08 (ppg) 7,450.0 (ft) 4,371.0 (ft) 9.20 (ppg) 650 (psi) 2,739 (psi) 12.06 (ppg) (ft) (ft) 9.20 (ppg) (psi) (psi) 12.06 (ppg) 7,348,0 (ft) 4,328,0 (ft) 9,20 (ppg) 650 (psi) 2,718 (psi) 12.09 (ppg) Printed: 3/112004 9:51:13 AM e e Page 1 of 28 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/17/2004 1/1812004 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task Code NPT Phase 21 :00 - 22:00 1.00 MOB P PRE 22:00 - 00:00 2.00 MOB P PRE 00:00 - 06:00 6.00 MOB P PRE 06:00 - 10:00 4.00 MOB P PRE 10:00 - 12:00 2.00 MOB P PRE 12:00 - 19:00 7.00 RIGU P PRE 19:00 - 19:30 0.50 RIGU P PRE 19:30 - 20:00 0.50 RIGU P PRE 20:00 - 21 :30 1.50 RIGU N RREP PRE 21 :30 - 22:00 0.50 RIGU P PRE 22:00 - 00:00 2.00 RIGU P PRE 1/19/2004 00:00 - 00:30 0.50 RIGU P PRE 00:30 - 02:30 2.00 RIGU P PRE 02:30 - 03:30 1.00 RIGU P PRE 03:30 - 04:00 0.50 RIGU P PRE 04:00 - 04:30 0.50 RIGU P PRE 04:30 - 05:30 1.00 DRILL P SURF . 05:30 - 06:00 06:00 - 06:30 06:30 - 18:30 0.50 DRILL P 0.50 DRILL P 12.00 DRILL P SURF SURF SURF . . Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 . Description of Operations; Exception Rig Move f/ L-21 Oi to L-200. Move Pit Complex from Rig. PJSM, Move Sub off well L-210i, Spot on Pad, Prep cellar area to change out annular preventer Change out annular preventer while NU diverter line on well L-200 Exception Rig Move Rate Spot Sub Base, Shim up wI 3 x 12 & 2 x 6's, due to uneven location Spot camp and Pits Accept Rig at 12:00 Hrs on 1/18/04 RIU at interconnect, set cuttings tank and swaco unit, take on fresh water, finish RIU Diverter System, Mix Spud mud, Load 5" DP in pipeshed, RIU rig floor, Change top drive quill, saver sub, die blocks and guide plates over for 5" Dp Service top drive MU and stand back 5" DP in derrick, Iron Roughneck spinner wrench quit working Troubleshoot Iron Roughneck, replacing solenoid switch Function test Diverter System, AOGCC John Spaulding waived witnessing test, while replacing solenoid switch on Iron Roughneck MU and stand back 5" DP in derrick MU and stand back 5" DP in derrick MU and stand back 5" HWDP in derrick MU BHA #1, PU 9 5/8" 1.83 degree motor w/13 3/8" stab, 13 1/2" bit, 8" NM lead collar, 137/16" NM stab, MWD, RIH on a std of HWDP Pre-spud meeting with Anadril, MI and all rig personnel Break eire, check for leaks through out circulating system, OK Drill 13 1/2" surface hole from 108' to 255' WOB = 10 klbs RPM = 40 Torque off Btm = 2k FtLb, Torque on Btm = 1 k FtLb GPM = 605 @ 795 psi on Btm, 660 psi off Btm P/U 50k S/O 50k ROT 50k SPUD @ 04:30 hrs. POH w/2 stands of 5" HWDP RIH w/1 stand of 7" DC's, HWDP, Jar, HWDP Drill 13 112" surface hole from 255' to 1657' w/ a 1.83 deg motor, surveyed wI MWD-GR WOB = 42 klbs RPM = 50 Torque off Btm = 3k FtLb, Torque on Btm = 7k FtLb GPM = 750 @ 1920 psi on Btm, 1560 psi off Btm PIU 86k S/O 78k ROT 82k AST = 7.12 Hrs Sliding at 20 to 40 R for build and turn ART = 3.70 Hrs Printed: 3/112004 9:51 :23 AM e e BP Operations Summary Report Page 2 of 28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 1/19/2004 18:30 - 19:30 1.00 DRILL P SURF Circulate hole clean wI 770 gpm 1475 psi 19:30 - 21:00 1.50 DRILL P SURF Monitor well, stable, POH to BHA at 629', up wt 95 k, dn wt 84 k, Worked through tight hole at 1148' - 1133' & 1069 - 1041', had overpulls of 25 k to 35 k. 21 :00 - 22:30 1.50 DRILL P SURF POH wI BHA, LD bit, MWD (partially), String Stabilizers (completely), Motor (partially)/NB Stabilizer and Bit (both were completely balled up) were balled up with formation clay. Cleaned rig floor 22:30 - 00:00 1.50 DRILL P SURF MU new 13 1/2" MX-C1 bit, Adjust motor to 1.5 degrees, orient, RIH wI BHA #2, add 9 7/8" NM stabilizer between 7" DC's, RIH wI 5" HWDP and Jar 1120/2004 00:00 - 00:30 0.50 DRILL P SURF Continued RIH wI BHA #2, Shallow hole test MWD, OK 00:30 - 01 :00 0.50 DRILL P SURF RIH wI BHA # 2 on 5" DP, wash down f/1571' to 1657'. Had several tight spots at 900', 1040', 1133' and 1148' with 20 to 30 K down drag. 01 :00 - 09:00 8.00 DRILL P SURF Drill 13 1/2" surface hole from 1657' to 3128' wI a 1.50 deg motor, surveyed wI MWD-GR WOB = 42 klbs RPM = 80 Torque off Btm = 4.9k FtLb, Torque on Btm = 10.7k FtLb GPM = 800 @ 2564 psi on Btm PIU 99k SIO 72k ROT 83k 09:00 - 10:30 1,50 DRILL N SFAL SURF Clean plugged suction screen on #2 mup pump Rotate and reciprocate with #1 pump. 25 rpm, 188 gpm @ 270 psi 10:30 - 11 :00 0.50 DRILL P SURF Continue drilling 13 1/2" surface hole from 3128' to 3169' wI a 1.50 deg motor, surveyed wI MWD-GR WOB = 42 klbs RPM = 80 Torque off Btm = 4.9k FtLb, Torque on Btm = 10.9k FtLb GPM = 800 @ 2250 psi on Btm P/u 103k SIO 74k ROT 86k 11:00 - 14:30 3.50 DRILL N SFAL SURF Change out valves and seats on #2 pump. Clean suction and discharge screens on #1 pump Rotate and reciprocate. 25 rpm, 188 gpm @ 200 psi. P/u 106k SIO 80k ROT 92k 14:30 - 19:00 4.50 DRILL P SURF Continue drilling 13 1/2" surface hole from 3169' to 3882' wI a 1.50 deg motor, surveyed wI MWD-GR WOB = 45 klbs RPM = 80 Torque off Btm = 6.5k FtLb, Torque on Btm = 10-12k FtLb GPM = 800 @ 2660 psi on Btm, 2260 psi off Btm P/U 112k SIO 80k ROT 97k P/U 125k SIO 85k without pumps Backream 30' on each stand at 80 rpm and 800 gpm, reduce rate to 500 gpm on down stroke. Printed: 31112004 9:51:23 AM - e BP Operations Legal Well Name: L-200 Common Well Name: L-200 Event Name: DRILL+COMPLETE Start: 12/31/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/23/2004 Rig Name: NABORS 9ES Rig Number: __~:_t~,u I._~~~~_-__:~ I ~.~~r~i_~~s~,_¡~O~~._N~T-' ~h:S~__ ._,_ 1/20/2004 14:30 - 19:00 4.50 DRill P SURF AST = 3.12 hrs ART = 4.46 hrs Circulate BU volume X 3. 19:00 - 20:30 1.50 DRILL P SURF 20:30 - 21 :30 1.00 DRILL P SURF 21 :30 - 00:00 2.50 DRILL P SURF 1/2112004 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 04:00 2.00 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 05:00 0.50 DRILL P SURF 05:00 - 06:30 1.50 DRIll P SURF 06:30 - 08:30 2.00 DRILL P SURF 08:30 - 13:30 5.00 DRILL P SURF 13:30 - 14:30 1.00 DRill P SURF 14:30 - 16:00 1.50 DRILL P SURF 16:00 - 16:30 0.50 DRILL P SURF 16:30 - 19:00 2.50 CASE P SURF 19:00 - 00:00 5.00 CASE P SURF of 28 Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations 100-110 rpm 800 gpm @ 2220 psi Torque = 5-7k Ftlb ROT = 97k Monitor well - static. POH to 3542' without any problems. P/U 125k, SIO 86k From 3542' to 3480' started swabbing and pulling over from 25--35k. Backream out from 3480' 100 rpm 800 gpm @ 2140 psi Torque = 6-7k FtLb ROT = 97k Midnight depth 2600' Continue backreaming out of hole to 1600'. 775 gpm @ 1800 psi Attempt to POH from 1600', pulling 25k over. Orient tool face to high side and pump out without rotating to 630'. 750 gpm @ 1650 psi P/U 100k SIO 65k RIH with no problems to 1790'. Work through tight spot from 1790' to 1815'. Unable to work down past 1815'. From 1815' to 1825' pump down, 215 gpm @ 335 psi while rotatating at 60 rpm. Finally dropped through at 1825' Circulate hole clean. 400 gpm @ 680 psi Continue RIH to TO at 3882'. No hole problems below 1825' Stage pumps up to drilling rate and circulate BU volume X 2.5. 100-110 rpm 575 gpm @ 1345 psi Torque = 8k FtLb P/U 113k SIO 82k ROT 97k Monitor well - static. POH to run casing. Pump out, 175 gpm @ 250 psi, through tight spot from 1550' to 1000. Monitor well at BHA - static. Stand back HWDP, jars and collars. LD BHA #2 Clean and clear rig floor. MU landing joint and casing hanger, make dummy run. CO bails, Rig up fill-up tool and csg equipment. Run 92 joints 10-3/4",45.5#, l-80 surface casing as per running orders. Work through tigh spot from 1400' to 1700'. Printed: 3/112004 9:5123 AM e e BP Page 4 of 28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING J NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Date From -To Hours Tàsk Code NPT Phase 1/21/2004 19:00 - 00:00 5.00 CASE P SURF 1/22/2004 00:00 - 02:30 2.50 CASE P SURF 02:30 - 03:00 0.50 CASE P SURF 03:00 - 06:00 3.00 CEMT P SURF 06:00 - 08:15 08:15 - 08:45 2.25 CEMT N WAIT SURF 0.50 CEMT N RREP SURF 08:45 - 11 :00 2.25 CEMT P SURF 11 :00 - 12:00 1.00 CEMT P SURF 12:00 - 12:30 0.50 CEMT P SURF 12:30 - 12:45 0.25 CEMT P SURF 12:45 - 14:10 1.42 CEMT P SURF 14:10 - 14:25 0.25 CEMT P SURF 14:25 - 15:15 0.83 CEMT P SURF 15:15 -16:30 1.25 CEMT P SURF 16:30 - 17:30 1.00 CASE P SURF 17:30 - 21:00 3.50 DIVRTR P SURF 21 :00 - 00:00 3.00 BOPSU P SURF 1/23/2004 00:00 - 03:00 3.00 BOPSU SURF 03:00 - 03:30 0.50 BOPSU SURF 03:30 - 07:30 4.00 BOPSU SURF 07:30 - 08:30 1.00 BOPSU SURF 08:30 - 09:00 0.50 DRILL INT1 09:00 - 11 :00 2.00 DRILL INT1 11:00 - 12:00 1.00 DRILL INT1 Description of Operations Midnight depth 1700' Continue running 92 joints 10-3/4", 45.5#, L-80 surface casing as per running order. Bowspring centralizers on joints #1-25 and 10' above and below the TAM port collar. LD fill-up tool. RD csg equipment. RU cement head. Land casing. Stage up pumps to 500 gpm, Circulate and condition hole to cement. Waiting on trucks delayed due to Nabors 16E rig move from Kuparuk to Deadhorse. Need supersuckers, dirty vacs and mix water trucks from Deadhorse. Wait on trucks for cement job - delayed due to rig move from Kuparuk to Deadhorse. Rig currently broken down on Spine road between M & N Pad access roads. Circulate at 350 gpm. Standpipe washed out at rig floor. Isolate same and rig hoses from secondary kill line up to standpipe manifold. Unable to reciprocate after resuming circulation. Hanger is landed on MLS landing ring - OK. Trucks start arriving from Deadhorse for cement job. Continue conditioning mud to reduce FV to 60 and YP to 20. PJSM with Dowell, MI, Veco and all rig personnel on cementing procedures and hazards. Air up and prime up cement unit. Pump 3 bbls water, test lines to 3500 psi. Pump 70 bbls 10.1 ppg alpha spacer at 5 bpm @ 400 psi. Drop bottom plug, mix and pump 551 bbls (700 sx) 10.7 ppg AS Lite cement at 7 bpm @ 1000 psi Switch to tail cement, mix and pump 70.5 bbls (365 sx) 15.8 ppg Class-G cement at 6 bpm @ 1700 psi. Drop top plug and kick out with 10 bbls water to flush cement lines. Switch to rig pumps and displace with mud at 11 bpm @ 1600 psi. Spacer dye to surface 850 strokes into displacement. Reduced displacement rate to 10 bpm. Good cement to surface 2500 strokes into displacement. Bump plugs on calculated strokes with 2500 psi, floats holding. 140 bbls cement retums to surface. No pipe reciprocation during cement job. CIP @ 15:10 Blow down lines, flush stack and rig down cement head. Back out landing joint. RD casing equipment. NO diverter and riser Move casing head and tubing spool into cellar. NU csg head and tbg spool. NU BOP. NU BOPE MU and install pump-in sub, TIW valve, Dart valve and test plug Test BOPE and Hydril to 3500/250 psi. Witness of BOP test waived by Chuck Scheve with AOGCC Blow down lines. RO test equipment. Install wear bushing Bring BHA #3 to rig floor. PU 5" DP singles from pipe shed, MU stands and stand back, Service top drive. Printed: 3/112004 9:51:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES e Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 1/23/2004 Date FrÒrn1TÓ HOurs Task Gode NPT 12:00 - 15:00 15:00 - 19:00 19:00 - 20:00 20:00 - 20:30 20:30 - 23:00 23:00 - 00:00 1/24/2004 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:30 02:30 - 08:00 08:00 - 09:00 09:00 - 09:30 09:30 - 10:30 3.00 DRILL P 4.00 DRILL P INT1 INT1 1.00 CASE P 0.50 DRILL P 2.50 DRILL P SURF INT1 INT1 1.00 DRILL P INT1 0.50 DRILL P 0.50 DRILL P INT1 INT1 1.50 DRILL P INT1 5.50 DRILL P INT1 1.00 DRILL N FWD INT1 0.50 DRILL P INT1 1.00 DRILL P MU BHA #3. Shallow test MWD. RIH picking up single joints of 5" DP from pipe shed to 1200'. After passing through TAM port collar test csg to 1000 psi. Continue RIH picking up singles Test 10-3/5" surface casing to 3500 psi for 30 minutes Continue RIH. Wash last stand to bottom, tag cement at 3723' Drill cement and float equipment to 3882'. Continue drilling 20' of new hole to 3902'. WOB = 5 klbs RPM = 50 GPM = 550 @ 1286 psi on Btm P/U 145k SIO 60k ROT 95k Circulate BU volume. Displace well to new 9.2 ppg LSND mud 550 GPM @ 800 psi Continue displace well to new 9.2 ppg LSND mud Perform LOT, EMW = 11.4 ppg. 300 psi surface pressure with 9.2 ppg mud at 2658' TVD, Calculated kick tolerance 74 bbls Establish baseline ECD = 10.24 ppg Cut and slip 66' of drilling line. Service top drive, blocks and crown. Drill 9-7/8" intermediate hole from 3902' to 4749' sliding as required to maintain azimuth and inclination WOB = 10-20 klbs RPM = 80 Torque off Btm = 5.5k FtLb, Torque on Btm = 8k FtLb GPM = 650 @ 1780 psi on Btm, 1520 psi off Btm P/U 118k 5/0 84k ROT 100k Backream every stand at 650 gpm and 80 rpm, reducing flow rate to 450 gpm on down stroke. Calculated ECD = 10.31 ppg, Actual ECD = 10.89 ppg Circulate and condition mud. Screen down shakers, screens blinding off due to heavy oil and asphalt. Drill 9-7/8" intermediate hole from 4749' to 4897' sliding as required to maintain azimuth and inclination WOB = 10-20 klbs RPM = 80 Torque off Btm = 5.5k FtLb, Torque on Btm = 8k FtLb GPM = 650 @ 1780 psi on Btm, 1520 psi off Btm P/U 118k 5/0 84k ROT 100k Backream every stand at 650 gpm and 80 rpm, reducing flow rate to 450 gpm on down stroke. INT1 Calculated ECD = 10.31 ppg, Actual ECD = 10.89 ppg Circulate and condition mud at reduced rate, screens blinding off due to heavy oil and asphalt. Printed: 31112004 9:51:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Page 6 of 2.8 BP Operations Summary Report L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 1/2412004 10:30 - 00:00 1/25/2004 00:00 - 08:00 08:00 - 19:30 19:30 - 23:00 23:00 - 23:30 23:30 - 00:00 1/26/2004 00:00 - 00:30 13.50 DRILL P 8.00 DRILL P 11.50 DRILL P 3.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P Descripti INT1 Drill 9-7/8" intermediate hole from 4897' to 6470' sliding as required to maintain azimuth and inclination WOS = 10-20 klbs RPM = 60 Torque off Btm = 8-11k FtLb, Torque on Btm = 11-15k FtLb GPM = 650 @ 2175 psi on Btm, 1814 psi off Btm P/U 156k SIO 97k ROT 119k Backream every stand at 650 gpm and 60 rpm, reducing flow rate to 450 gpm on down stroke. Calculated ECD = 10.16 ppg, Actual ECD = 10.57 ppg INT1 AST = 5.28 hrs. ART = 3.66 hrs. Drill 9-7/8" intermediate hole from 6470' to 7882' sliding as required to maintain azimuth and inclination. WOB = 20-25 klbs RPM = 50 Torque off Stm = 12-14k FtLb, Torque on Btm = 13-20k FtLb GPM = 650 @ 2419 psi on Btm, 2175 psi off Btm P/U 170k SIO 95k ROT 118k No pumps PIU 175k SIO 100k Backream every stand at 650 gpm and 50 rpm, reducing flow rate to 450 gpm on down stroke. Circulate LolHi vis sweep @ 6587' and a hi-vis sweep @ 6815'. Below 6815' circulate Lo/Hi vis sweeps every 300' Calculated ECD = 10.18 ppg, Actual ECD = 10.50 ppg. INT1 AST = 5.35 hrs. ART = 4.23 hrs. Circulate 40 bbl hi-vis sweep around. Circulate BU volume X 2. INT1 650 gpm @ 2029 psi Reciprocate DP at 110 rpm Monitor well - static. Slug DP and POH on short trip to 10-3/4" casing shoe. Intermittent drag of 10-20 klbs over throughout trip. Started swabbing @ 4129. Backream out from 4129' to 4110'. INT1 INT1 90 rpm 650 gpm @ 1530 psi At 4110' hole trying to pack off while backreaming. Slow pumps and free pack off - OK. Stage pumps back up to full circ rate - OK. RIH to 4170', SD pumps and monitor well- static. Total losses = 10 bbl. Continue backreaming out from 4170' to csg shoe at 3871'. INT1 Printed: 31112004 9:51:23 f;M legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/2612004 00:00 - 00:30 00:30 - 01 :00 01 :00 - 03:00 03:00 - 07:00 e e BP Operations'Suml11C1rýReport of 28 l-200 l-200 DRill +COMPlETE NABORS ALASKA DRilLING I NABORS 9ES - To· Hours Task Code NPT Phase 0.50 DRILL P INT1 0.50 DRILL P 2.00 DRILL P 4,00 DRILL P INT1 INT1 INT1 07:00 - 08:30 1.50 DRILL P INT1 08:30 - 14:30 6.00 DRILL P INT1 14:30 - 15:00 0.50 DRILL P INT1 15:00 - 16:00 1.00 DRILL P INT1 16:00 - 17:00 1.00 DRILL P INT1 17:00 - 17:30 0.50 DRILL P INT1 17:30 - 19:00 1.50 DRILL INT1 19:00 - 19:30 0.50 DRILL INT1 19:30 - 20:30 1.00 BOPSU INT1 20:30 - 21 :30 1.00 BOPSU INT1 21 :30 - 22:00 0.50 BOPSU INT1 22:00 - 00:00 2,00 CASE INT1 1/27/2004 00:00 - 19:00 19.00 CASE INT1 Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 2/23/2004 Description of Operations. 90 rpm 600 gpm @ 1200 psi Losses at 16-20 bph Service top drive, blocks and crown RIH to 7782' no problems Stage up pumps and wash last stand to bottom at 7882'. Pump HilLo vis sweep surface to surface. Circulate and condition mud: 9.4 ppg in and out. 110 rpm 650 gpm @ 1966 psi Estimated losses at 5-10 bph Reduced rate to 600 gpm @ 1840 psi - no losses PIU 173k SIO 91k ROT 119k No pumps PIU 180k SIO 95k Calculated ECD = 10.33 ppg. Actual ECD prior to POH = 10.41 ppg. Monitor well - static. POH standing back stands to 6473', monitoring hole fill. Pulled 20 klbs over at 6473', wipe through no problems. Slug DP, blow down top drive. POH to HWDP at 668' laying down DP. Monitor well - static. RIH with stands from derrick. POH laying down DP. Monitor well - static. POH laying down HWDP. PJSM with Anadrill and all rig personnel on LD BHA and unloading RA source. LD Jars and DC's. Unload RA source. LD BHA #3. Clean and clear rig floor. Flush stack with ported sub. Pull wear bushing and install test plug Change top rams from 3.5 X 6 variables to 7-5/8" RU and test door seals to 3500 psi. RD test equipment. MU test joint, make dummy run. RU casing equipment. Run 191 joints 7-5/8" 29.7# L-80 intermediate casing as per running order. Break circulation for 5-10 minutes every 20 jts to the 10-3/4" csg shoe. In open hole reduce running speed to 1.5 minutes per joint. Fill each joint, circulate for 15 minutes every 15 joints and CBU every 30 joints. At 5800' started pushing mud away reduced running speed to 8 minutes per joint. Regained retums at 6300' continued running at 8 minutes per joint. Total mud lost while running casing 55 bbls . RA tags @ 7663', 7375', 7270, 6983'. Run 70 ea 9-1/8" OD rigid straight blade centralizers as per plan. Joints without centralizers for lateral windows: Joint #11 - top at 7415' Printed: 3/112004 9:51:23 AM e e Page 8 of 28 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours Task Code NPT Phase 1/27/2004 00:00 - 19:00 19.00 CASE P 19:00 - 19:30 19:30 - 22:30 0.50 CASE P 3.00 CEMT P 22:30 - 23:00 0.50 CEMT P INT1 23:00 - 00:00 1.00 CEMT P INT1 1/28/2004 00:00 - 00: 15 0.25 CEMT P INT1 00:15 - 00:30 0.25 CEMT P INT1 00:30 - 01 :00 0.50 CEMT P 01 :00 - 02:00 1.00 CEMT P 02:00 - 02:30 0.50 CEMT P INT1 02:30 - 03:30 1.00 CASE P INT1 03:30 - 04:30 1.00 WHSUR P INT1 04:30 - 05:30 1.00 BOPSU PROD1 05:30 - 06:30 1.00 BOPSU PROD1 06:30 - 07:00 0.50 BOPSU PROD1 07:00 - 10:00 3.00 BOPSU PROD1 10:00 - 10:30 0.50 BOPSU PROD1 10:30-11:00 0.50 DRILL P PROD1 11:00 - 12:00 1.00 DRILL P PROD1 12:00 - 13:00 1.00 WHSUR P INT1 INT1 INT1 INT1 INT1 INT1 Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations Joint #13 - top at 7310' Joint #20 - top at 7024' Land casing. LD fill-up tool, blow down top drive, RU cement head. Break circulation at 2 bpm stage pumps to 7 bpm @ 578 psi. Circulate and condition mud while reciprocating DP. Full returns while circulating. PIU 225 klbs SIO 100 klbs PJSM with Schlumberger and all rig personnel on cementing operations. Prime up and air up cement unit. Batch mix 114 bbts 15.8 ppg cement. Pump 5 bbl water to fill lines. Pressure test cement lines to 4000 psi Mix and pump 25 bbls CIW-1 00 chemical wash followed by 45 bbls 10.3 ppg alpha spacer at 4-5 bpm. PIU 265 klbs S/O 96 klbs Drop bottom plug. Pump 110 bbls (515 sxs) 15.8 ppg batch mixed cement at 6 bpm. PIU 265 klbs SIO 96 klbs Drop top plug and kick out with 10 bbls water from cementers to flush lines. Switch to rig pump and displace with seawater, 8 bpm @ 175 psi. Reduced rate to 5 bpm with the spacer at the shoe. Set casing on the ring 4360 strokes into displacement due to decreasing string weight. Reduced rate to 3 bpmat 4900 strokes to bump, FCP = 780 psi. Bumped plugs on calculated strokes with 1000 psi. Bled off pressure and checked floats. Full returns throughout displacement CIP @ 02:00 RD cement head. LD landing joint RD casing equipment, CO bails. Install Packoff, RILDS. Pressure test to 5000 psi. Flush BOP stack with ported sub. Change upper rams. Change top drive quill from 4-1/2" IF to 4" HT40 PU test joint. RU test equipment. Install test plug. Test BOPE and annular to 250/3500 psi. Witness of BOP test waived by John Crisp with AOGCC. RD test equipment and blow down all lines. Install 7.375" ID wear bushing. Service top drive and blocks. PU 4" DP from pipe shed and RIH. RU and inject 150 bbls 9.3 ppg mud down the 10-314" X 7-5/8" annulus. Lot EMW = 12.0 ppg, 375 psi surface pressure and a shoe TVD of 2658'. Injection rates: 1 bpm @ 425 psi 2 bpm @ 470 psi 3 bpm @ 600 psi Printed: 3/112004 9:51:23 AM e e BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING f NABORS 9ES From- To Hours Task Code NPT Phåse 1/28/2004 12:00 - 13:00 1.00 WHSUR P INT1 Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description of Operátions 3bpm ICP = 600 psi FCP = 575 psi PROD1 Continue PU 4" DP from pipe shed and RIH. 13:00 - 17:30 4.50 DRILL P 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 21:00 2.50 DRILL P PROD1 21 :00 - 21 :30 0.50 DRILL P PROD1 21 :00 - 00:00 3.00 DRILL P PROD1 1/29/2004 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 06:30 6.00 DRILL P PROD1 06:30 - 07:30 1.00 CASE P INT1 07:30 - 08:00 0.50 DRILL P PROD1 08:00 - 10:00 2.00 DRILL P PROD1 10:00 - 16:30 6.50 DRILL P PROD1 Freeze protect 10-3/4" X 7-518" annulus with 117 bbls dead crude. ICP = 600 psi, FCP = 775 psi, SIP = 750 psi Cut and slip 65' of drilling line. POH standing back 61 stands in derrick. Start taking on MOBM @ 19:30 hrs PJSM with Anadrill and all rig personnel on picking up BHA and loading RA source. PU and MU BHA #4, 6-3/4" rotary steerable motor and MWD/LWD. Shallow test rotary steerable motor. Load RA source. Continue PU and MU BHA #4, 6-3/4" rotary steerable motor and MWD/LWD. RIH picking up 231 jts DP from pipe shed. Break circulation and circulate long enough to ensure all the air is out of the system. Test casing to 3500 psi for 30 minutes PJSM with MI and all rig personnel on displacing to MOBM. Wash last stand down and tag float collar at 7786'. Pump viscosified oil spacer and displace well to 9.2 ppg MOBM Drill float collar and shoe track to 7872'. Continue drilling rat hole and 20' of new hole to 7902'. WOB = 5-10 klbs RPM = 50 Torque off Btm = 4.5k FtLb, Torque on Btm = 5k FtLb GPM = 255 @ 2370 psi on Btm, 2270 psi off Btm PIU 125k SIO 82k ROT 100k PROD1 Circulate hole clean for FIT test. 16:30 - 17:00 0.50 DRILL P 60 rpm 275 gpm @ 2775 psi Baseline ECD = 10.37 ppg PROD1 Perform FIT test. 17:00 - 17:30 0.50 DRILL P EMW = 12.0 ppg Surface pressure = 670 psi MW = 9.2 ppg TVD = 4483' PROD1 Drill 6-3/4" intermediate hole from 7902' to 8284' with PowerDrive rotary steerable BHA, steering as required to maintain inclination and azimuth taking surveys every 30'. 17:30 - 00:00 6.50 DRILL P WOB = 15 klbs RPM = 120 Torque off Btm = 4.2k FtLb, Torque on Btm = 6-7k FtLb GPM = 275 @ 2881 psi on Btm, 2875 psi off Btm Printed: 3/112004 9:51 :23 AM e e BP Summary Report Page 1 0 of28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Spud Date: 1/15/2004 End: 2/23/2004 Task Code Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: NPTI PhaseJ Description of Operations PROD1 PIU 125k SIO 77k ROT 94k No pumps P/U 130k SIO 82k 1/29/2004 17:30 - 00:00 From - To Hours P 1/30/2004 00:00 - 20:30 20:30 - 00:00 1/31/2004 00:00 - 02:00 02:00 - 00:00 6.50 DRILL NO backreaming or sweeps Calculated ECD = 10.41 ppg, Actual ECD = 10,77 ppg. 20.50 DRILL P ART = 2.35 hrs. PROD1 Drill 6-3/4" intermediate hole from 8284' to 9811' with PowerDrive rotary steerable BHA, steering as required to maintain inclination and azimuth taking surveys every 30'. WOB = 18 klbs RPM = 140 Torque off Btm = 6k FtLb, Torque on Btm = 8k FtLb GPM = 275 @ 2970 psi on Btm, 2970 psi off Btm PIU 143k SIO 64k ROT 98k No pumps PIU 145k SIO 74k NO backreaming or sweeps Calculated ECD = 10.55 ppg, Actual ECD = 10.98 ppg, 3.50 DRILL N ART = 7.63 hrs. DPRB PROD1 Circulate and condition hole while reciprocating DP. Corrected surveys showing 2 to 9 degrees of azimuth correction, normal correction is less than a degree. Conferred with town engineer and sent data in for further analysis to determine if tool is functioning properly, Still waiting on decision at midnight DPRB PROD1 Continue circulating and conditioning. Surveys were rechecked and the azimuth corrections were determined to be valid. The MWD tools appears to be functioning and communicating correctly. The large correction is possibly due to magnetic interferance with the BHA or tools. The corrected surveys moved the well bore -118' to the Southwest. This is -30' inside the Southwest edge of the polygon. The decision was made, with agreement from the ODE and geologist, to continue drilling. PROD1 Drill 6-3/4" intermediate hole from 11304' to 11702' with PowerDrive rotary steerable BHA, steering as required to maintain inclination and azimuth taking surveys every 30'. 2.00 DRILL N 22.00 DRILL P WOB = 15-20 klbs RPM = 140 Torque off Btm = 9.3k FtLb, Torque on Btm = 10.5k FtLb GPM = 275 @ 2785 psi on Btm, 2750 psi off Btm P/U 153k SIO 43k ROT 95k No pumps PIU 164k SIO 54k NO backreaming or sweeps. Lost 12 bbls while crossing a fault at 11150'. Also crossed faults at 11070' and 11200' with no losses. Seepage losses at 2-3 bph. Printed: 31112004 9:51 :23 AM Date From- To Hours Task Code NPT Phase 1/31/2004 02:00 - 00:00 22.00 DRILL P PROD1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/1/2004 00:00 - 05:30 05:30 - 08:00 08:00 - 22:30 - 22:30 - 00:00 21212004 00:00 - 03:30 e e BP Operations Summélry Report Page 1.1 of 28 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 ~ -- , . VI Calculated ECD = 10.95 ppg, Actual ECD = 11.36 ppg. 5.50 DRILL P ART = 6.74 hrs, PROD1 Drill 6-3/4" intermediate hole from 11304' to 11710' with PowerDrive rotary steerable SHA, steering as required to maintain inclination and azimuth taking surveys every 30'. WOB = 15-18 klbs RPM = 140 Torque off Btm = 9.6k FtLb, Torque on Btm = 10.5k FtLb GPM = 275 @ 3170 psi on Btm, 3150 psi off Stm P/U 150k SIO 56k ROT 90k No pumps P/U 160k SIO 66k NO backreaming or sweeps. Seepage losses at 2-3 bph. 2.50 DRILL P Calculated ECD = 11.00 ppg, Actual ECD = 11.57 ppg. PROD1 Circulate and condition mud while geologist interprets samples and logs. 14.50 DRILL P 140 rpm 275 gpm @ 3150 psi PROD1 Drill 6-3/4" intermediate hole from 11710' to 12711' with PowerDrive rotary steerable BHA, steering as required to maintain inclination and azimuth taking surveys every 30'. WOB = 10 klbs RPM:: 140 Torque off Btm = 9.2k FtLb, Torque on Stm = 11 k FtLb GPM :: 275 @ 2940 psi on Btm, 2890 psi off Btm PIU 160k SIO 41k ROT 90k No pumps P/U 168k SIO 61k Circulate hi-vis sweep at 12579' to reduce ECD. Seepage losses at 2-3 bph. Calculated ECD = 10.88 ppg, Actual ECD = 11.66 ppg. 1.50 DRILL P ART = 6.33 hrs. PROD1 Circulate and condition mud to reduce ECD's. Provide updated mud properties to MWD to recalculate ECD. Actual ECD prior to circulating 11.81 ppg 140 RPM 275 gpm @ 2940 psi 3.50 DRILL P After circulating: Calculated ECD = 11.11 ppg, Actual ECD = 11.56 ppg. PROD1 Drill 6-3/4" intermediate hole from 12711' to 12964' with PowerDrive rotary steerable BHA, steering as required to maintain inclination and azimuth taking surveys every 30'. i Printed: 3/1/2004 9:51'23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 21212004 03:30 - 05:00 05:00 - 06:30 06:30 - 10:30 10:30 - 11 :00 11:00 -11:30 11:30 - 14:30 e e BP Operations Summary Report 1 .50 DRILL P 1.50 DRILL P 4.00 DRILL P 0.50 DRILL P 0.50 DRILL P 3.00 DRILL P Phase PROD1 Page 12 of28 Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To~olJrsiTasK Code NPT 00:00 - 03:30 3.50 DRILL P Description of Operations WOB = 10 klbs RPM = 140 Torque off Btm = 9.2k FtLb, Torque on Btm = 11 k FtLb GPM = 275 @ 2940 psi on Btm, 2890 psi off Btm P/U 160k SIO 41k ROT 90k No pumps P/U 168k SIO 61k Seepage losses at 3-4 bph. Calculated ECD = 11.11 ppg, Actual ECD = 12.00 ppg, PROD1 Circulate and condition mud to reduce ECD's. Ciculate a hi-vis sweep around and add base oil to system. PROD1 Drill 6-3/4" intermediate hole from 12964' to 1306T with PowerDrive rotary steerable BHA, steering as required to maintain inclination and azimuth taking surveys every 30'. WOB = 10 klbs RPM = 140 Torque off Btm = 10.4k FtLb, Torque on Btm = 11-12k FtLb GPM = 275 @ 3000 psi on Btm, 2930 psi off Btm PIU 158k SIO top drive ROT 90k No pumps PIU 168k SIO 61k Seepage losses at 3-4 bph, Calculated ECD = 11.14 ppg, Actual ECD = 11.57 ppg. ART = 1.44 hrs. PROD1 Circulate BU volume X 3. Circulate hi-vis sweep around. 150 rpm 275 gpm @ 2950 psi Prior to trip Calculated ECD = 11.37 ppg, Actual ECD = 11.65 ppg. PROD1 Monitor well - static. Attempt to POH. Pulled 2 stands, pulling 20k over and swabbing PROD1 RIH to bottom, work through tight spots. PROD1 Ciculate weighted sweep surface to surface, plus BU volume X 2. 14:30 -15:00 0.50 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 160 rpm 275 gpm @ 2820 psi P/U 145k SIO 52k ROT 93k No pumps P/U 153k SIO 62k Prior to trip Calculated ECD = 11.37 ppg, Actual ECD = 11.55 ppg. Monitorwell- static. POH from 13067 to 12671', pulled 25k over and swabbing, RIH 1 stand. Stage pumps to 275 gpm @ 299- psi. ECD's 0.14 ppg over calculated indicate clean hole. Backream out to 12875'. Pump out slowly from 12875' to 12671'. Printed: 31112004 9:51 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/2/2004 21312004 2/4/2004 BP Operations Summary Report L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations 15:30 -16:30 From - To Hours Task Code NPT Phase PROD1 16:30 - 00:00 00:00 - 04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 07:30 07:30 - 11 :00 11 :00 - 11 :30 11 :30 - 14:00 14:00 - 19:00 19:00 - 19:30 19:30 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 05:00 05:00 - 05:30 05:30 - 07:00 1.00 DRILL P 7.50 DRILL P 275 gpm @ 2940 psi PROD1 Attempt to POH at 12671' pulling 20k over and swabbing. MU top drive and start backreaming to the 10-3/4" csg shoe. 275 gpm @ 2940 psi 4.00 DRILL P Midnight depth: 9847' PROD1 Continue backreaming from 9847' to the 7-5/8" csg shoe @ 7872'. 1.00 DRILL P 100 RPM 230 gpm @ 1700 psi PROD1 CBU at the csg shoe with 275 gpm @ 2330 psi + 120 RPM. 1.50 DRILL P After CBU Calculated ECD = 10.38 ppg, Actual ECD = 10.52 ppg. PROD1 Cut and slip 56' of drilling line. Service top drive, blocks and crown. PROD1 POOH (7 stds) to 7217'. P/U 21 Jts of 4" HWDP & rack in derrick. PROD1 TIH with drill string to 12974'. Encountered tight hole with 20-30k drag at 11300', 11600' & 12300' to 12600'. PROD1 Establish circulation. Stage pumps to 275 gpm wI 3260 psi. Precautionary wash to bottom at 13067' with no problems. Calculated ECD = 10.38 PPG, Actual ECD = 10.76 ppg. PROD1 Pump Hi-vis sweep. Circulated hole clean (3.5 Btm-up) 275 gpm wI 3060 psi FCP. Reciprocate drill string & rotate with 150 rpm while circulating. P/U 167k SIO 63k Rot Wt 98k Note: After circulating hole dean the PWD tool gave a Calculated ECD of 11.38 ppg & Actual ECD of 11.43 ppg PROD1 POOH to 7-518" casing shoe @ 7872'. Encountered tight hole @ the following depths: 12889', 11817', 11774', 10204' & 9460'. Wiped all tight spots with no other problems. PROD1 Monitor well-static. POOH to 7725'. PROD1 MIU TDS. Break circulation. Circulate & logging up with MWD-GR to comfirm RA Tag positions for calculating space-out requirements for whipstocks. ( Circ rate 275 gpm wI 2170 psi). RA Tags confirmed @ 7664', 7376', 7272' & 6982'. PROD1 TIH to 7872'. P/U 127k S/O 82k. PROD1 Drop steel ball down drill string. Pressure up to 2200 psi & shear circ sub. Circulate btms-up from 7872: with 450 gpm @ 2600 psi. Reciprocate drill string & rotate @ 80 RPM while circulating. PROD1 POOH with drill string from 7872' to top of BHA. PROD1 SAFETY- Held PJSM with rig crew & Schlumberger MWD personnel regarding unloading RA source & UD BHA. PROD1 Continue POOH. Unload RA source. UD 6-3/4" BHA. PROD1 Clean rig floor of excess MOBM & excess directional equipment. COMP RIU to run 4.5" slotted liner. 1.00 DRILL P 3.50 DRILL P 0.50 DRILL P 2.50 DRILL P 5.00 DRILL P 0.50 DRILL P 3.00 DRILL P 0.50 DRILL P 1.00 DRILL P 3.00 DRILL P 0.50 DRILL P 1.50 DRILL P 0,50 DRILL P 1.50 CASE P Printed: 3/112004 9:51 :23 AM BP Operations Summary Report Page,14 of 28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/412004 07:00 - 07:30 0.50 CASE P COMP SAFETY- Held PJSM with rig crew on running 4.5" liner. 07:30 - 13:00 5.50 CASE P COMP M/U 4-112" Guide Shoe Jt + 125 Jts of 4-112" 12.6# L-80 IBT-M slotted liner + 7 Jts of 4.5" 12.6# L-80 IBT-M solid liner & BOT "HMC" liner Hanger wI ZXP liner Top Packer. Total length = 5514.84' liner String wt = 60k, 13:00 - 14:30 1.50 CASE P COMP RIH with 4-1/2" 12.6# Slotted liner assembly on 4" DP to 7872'. Circulate 1 x DP volume @ 210 gpm wI 650 psi. 14:30 - 18:30 4.00 CASE P COMP Continue RIH with 4.5" Slotted liner assembly to 13067'. Tagged bottom. P/U to 13052'. Note: At 12570' encountered severe drag. Had difficulty getting liner to slide down hole. Worked string several times & was able to work liner past this interval with no other problems encountered. 18:30 - 19:30 1.00 CASE P COMP Break circulation. Drop 29132" setting ball down DP. Pump on seat @ 3 bpm wI 590 psi. Once ball seated increased pressure to 2500 psi to set HMC liner hanger. S/O 50k on Hanger. Continue pressuring up to 2650 psi to set ZXP Packer. Pressure up to 4000 psi & blow ball seat. Apply 20 RH Tums in drill string to release running tool from hanger. PIU 10' above TBR & release packer setting dogs. Set 65k on ZXP packer to ensure proper setting. The 4.5" Slotted liner set @ 13052' with top of liner @ 7537'. 19:30 - 20:00 0.50 CASE P COMP Monitor well. Well static, POOH 1 std above 4.5" liner Top Packer. 20:00 - 21 :00 1.00 CASE P COMP CBU from 7469' @ 6 bpm wI 960 psi. Flow check. Pump slug, 21 :00 - 00:00 3.00 CASE P COMP POOH with 4" DP. UD BOT Packer setting tool. Clean & clear rig floor of exces MOBM & liner running equipment. 2/512004 00:00 - 04:00 4.00 BOPSU P PROD2 Pull wear bushing. Run and set BOP Test plug. RlU to test BOP's with 4" DP. Test BOP's & all surface related equipment to 250/3500 psi. RID test equipment. Pull test plug and install wear bushing. All test were API. Witness of test waived by John Spaulding-AOGCC. 04:00 - 05:00 1.00 STWHIP P PROD2 Slip & cut drill line. Reset and check C-O-M. 05:00 - 05:30 0.50 STWHIP P PROD2 Bring Whipstock & other related BHA componets to rig floor 05:30 - 06:00 0.50 STWHIP P PROD2 SAFETY- Held PJSM with Rig Crew, Schlumberger MWD & Baker personnel regarding handling & running procedures for Whipstock & BHA. 06:00 - 10:00 4.00 STWHIP P PROD2 MIU Baker 7-5/8" Whipstock assembly #1. Orient MWD with whipstock. 10:00 - 12:30 2.50 STWHIP P PROD2 Service TDS, Drawworks, Iron-Roughneck, Rig's Hydraulic system, Blocks & Crown. 12:30 - 17:00 4.50 STWHIP P PROD2 TIH with 7-5/8" Whipstock assembly on 4" DP t07490'. PIU = 138k S/O = 90k 17:00 -18:00 1.00 STWHIP P PROD2 MIU TDS. Estabish circulation. Orient whipstock 13 deg LHS. Stab dummy seal assembly into tie-back sleeve @ 7544' DPM. Set down 18k to set whipstock anchor. PU 5k over to verify anchor set. Set down 38k to shear whipstock lug. Test 7-5/8" casing to 1000 psi for 10 minutes-OK, 18:00 - 22:30 4.50 STWHIP P PROD2 Mill Window in 7-5/8" casing from 7424' to 7436' and drill 14' of new hole to 7450'. Pump Hi-vis sweeps to help bring metal cuttings to surface. RPM = 85-100 Printed: 311/2004 9:51:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date BP Operations Summary Report L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 2/5/2004 18:00 - 22:30 From - To Hours Task Code NPT Phase PROD2 23:00 - 23:30 0.50 STWHIP P 23:30 - 00:00 0.50 STWHIP P 2/612004 00:00 - 02:30 2.50 STWHIP P 02:30 - 04:00 1.50 STWHIP P 04:00 - 04:30 0.50 DRILL P 04:30 - 05:30 1.00 DRILL P 05:30 - 05:45 0.25 DRILL P 05:45 - 08:30 2.75 DRILL P 08:30 - 09:00 0.50 DRILL P 09:00 - 11 :30 2.50 DRILL P 11 : 30 - 12:00 0.50 DRILL P 22:30 - 23:00 12:00 - 00:00 21712004 00:00 - 00:00 4.50 STWHIP P 0.50 STWHIP P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 12.00 DRILL P PROD2 24.00 DRILL P Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations Torque = 5-1 Ok FtLb GPM = 298-315 @ 2240 psi PIU 138k SIO 90k Rotate Wt = 104k Pump Hi-vis sweep & circulate hole clean from 7450' w/315 gpm @ 2240 psi. Reciprocate & rotate drill string while circulating. Perform FIT. Pressure up on formation to 650 psi with 9.2 ppg MOBM @ 4370' TVD = 12.0 ppg EMW. Flow check. Well static. Pump slug. Blow down TDS & related equipment. POOH with 4" DP to top of BHA. Stand back 4" HWDP. UD 9 x 4.750" DC, MWD tool & whipstock mill assembly. Clean Rig Floor. MIU ported sub. Flush out BOP's. UD sub. SAFETY-- Held PJSM with Anadrill and all rig personnel regarding picking up BHA & loading RA source. M/U 6-3/4" Steerable Drilling assembly. Test MWD-OK. Service TDS. Function test C-O-M. Continue TIH with 6-3/4" Steerable Drilling assembly on 4" DP to 7360'. M/U TDS. Establish circulation. Orient MWD to 13 deg LHS to exit window. Exit window and RIH (L 1 lateral) to 7440' without any problems. Establish baseline ECD of 10.57 ppg @ 275 gpm. Wash & ream from 7440' to 7450'. PIU 138k SIO 90k Drill 6-3/4" directional hole (L 1 lateral) from 7450' to 8471'. Slide as required to maintain inclination & azimuth. WOB = 10-15k RPM = 60 Torque off Btm = 6.5k FtLb, Torque on Btm = 8k FtLb GPM = 275 @ 3110 psi on Btm, 2770 psi off Btm P/U 158k SIO 80k ROT 101k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 8400' = 10.56 ppg, Actual ECD = 10.89 ppg ART = 0.97 Hrs AST = 2.92 Hrs. Survey & Connection time = 8.11 Hrs Drilling Time last 24 Hrs= 3.89 hrs PROD2 Drill 6-3/4" directional hole (L 1 lateral) from 8471' to 11052'. Slide as required to maintain inclination, azimuth & zone contact. Take surveys every 30'. WOB = 10-15k RPM = 60 Torque off Btm = 9.5k FtLb, Torque on Btm = 10.5k FtLb GPM = 282 @ 3400 psi on Btm, 3050 psi off Btm P/U 158k SIO 60k ROT 95k Printed: 311/2004 9:51:23AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Operations Summary Report Page 16 of 28 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 21712004 00:00 - 00:00 2/8/2004 00:00 - 20:30 20:30 - 00:00 21912004 00:00 - 01 :30 01 :30 - 02:00 NPT Phase Description .of Operations 24.00 DRILL P PROD2 Losing an average of 4 bph MOSM due to Fluid retention on drill cuttings. Sackream every stand at 280 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 11000' = 10.75 ppg, Actual ECD = 11.50 ppg ART = 4.96 Hrs AST = 3.26 Hrs. Survey & Connection time = 15.78 Hrs Drilling Time last 24 Hrs= 8.22 hrs 20.50 DRILL P NOTE: Crossed a fault@ 10930'MD I 4323'KBTVD PROD2 Drill 6-3/4" directional hole (L 1 lateral) from 11052' to 13045' TD 14265 KBTVD'. Slide as required to maintain inclination, azimuth & zone contact. Take surveys every 30'. WOB = 10-20k RPM = 60 Torque off Btm = 9.9k FtLb, Torque on Btm = 11 k FtLb GPM = 280 @ 3570 psi on Btm, 3300 psi off Stm PIU 180k SIO 37k ROT 92k Backream every stand at 280 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 13045' = 11.49 ppg, Actual ECD = 12.11 ppg ART = 3.27 Hrs AST = 2.29 Hrs. Survey & Connection time = 14.94 Hrs Drilling Time last 24 Hrs= 5.56 hrs Losing an average of 4 bph MOBM due to Fluid retention on drill cuttings. 3.50 DRILL P PROD2 Pump a 50 bbl Lo-vis sweep. Circulate sweep around. Had a large amount of drill cuttings come over shakers with sweep. Pumped another 50 bbl Lo-vis sweep. Circulate sweep around. Had a fair amount of cutting come over shaker. Continue circulating until shakers cleaned up. Circulated a total of 3.9 annular volumes. Reciprocate & rotate (110 RPM) drill string while circulating. 1.50 DRILL P Calculated ECD @ 13045 after circulating = 11.31 ppg, Actual ECD = 11.88 ppg PROD2 Monitor well. Well static. Blow down TDS. POOH from 13045' TD to 12114' with no problems. Hole taking proper displacement on fill ups. PROD2 Pump slug. After pumping slug continued to POOH. Encountered tight hole @ 12050', M/U TDS. Attempt to circulate. Hole packed off. Rotate, work drill string down to 12114' & regain circulation. Backream from 12114' to 12050'. 0.50 DRILL P Printed: 3/112004 9:51 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP Operations Summary Report L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/9/2004 01 :30 - 02:00 0.50 DRILL P PROD2 Attempt to pull without pumping to 12020'. Hole continue to pull tight. 02:00 - 02:30 0.50 DRILL P PROD2 TIH to 12400', Unable to slide drill string past this depth due to hole geometry & drill string limitations. 02:30 - 03:45 1.25 DRILL PROD2 MIU TDS. Circulate & rotate the drill pipe down from 12400' to 13045' TO. 03:45 - 10:30 6.75 DRILL P PROD2 Pump a 25 bbl Lo-vis sweep. Stage pumps to 290 gpm wI 3562 psi. Circulate & condition mud/hole. Reciprocate & rotate (110 RPM ) while circulating. Large amount of drill cutting came across shakers on bottoms-up. Pump another 25 bbllo-vis sweep. Circulate sweep around with very few cuttings observed once sweep reached surface. Mix & pump a 30 bbl weighted Lo-vis sweep. Circulate sweep around. Sweep brought up very few cuttings, plus there was some CaC03 observed coming across shakers. Calculated ECD @ 13045 after circulating = 11.39ppg, Actual ECD = 11.90 ppg 10:30 - 12:00 1.50 DRILL P PROD2 Monitor well-static. POOH to 12050' with no problems. At 12050' encountered tight hole. Pull & worked two additional stands out to 11863'. Hole conditions not getting any better. TIH to 11976'. 12:00 - 23:30 11.50 DRILL P PROD2 Establish circulation. Start backreaming from 11976' to 7544' ( Pulled 9 stds F/8938'- 8101' without backreaming), At 7544' orient bit @ 13 deg lHS. Stop pumping & pull bit through window @ 7424' with no problems, continue POOH to 7358'. RPM = 80-105 Torque = 10-11 KFtLb GPM = 290 @ 3450 PSI. 23:30 - 00:00 0.50 DRILL P PROD2 Circulate 1.5 x Btms-up from 7358' wI 280 gpm @ 2500 psi + 60 RPM. Reciprocate drill string while circulating, 2/10/2004 00:00 - 00:30 0.50 DRILL P PROD2 Circulate 1.5 x Btms-up from 7358' wI 280 gpm @ 2500 psi + 60 RPM. Reciprocate drill string while circulating. Very small amount of cuttings coming over shakers. 00:30 - 02:00 1.50 DRILL P PROD2 Slip & cut 60' of drill line. Reset & check C-O-M. Inspect & adjust drawworks brakes. Service TDS. 02:00 - 04:30 2.50 DRILL P PROD2 TIH, pass through window with no problems, Continue TIH to 12880' with no problems. At 12880' string taking weight. unable to work past this point. Pull back to 12859'. 04:30 - 05:00 0.50 DRILL P PROD2 MIU TDS. Establish circulation. Wash & ream from 12859' to 13045'TD with little resistance. 05:00 - 08:30 3.50 DRILL P PROD2 Pump a 25 bbllo-vis sweep. Circulate & condition mud/hole. Reciprocate & rotate (110 RPM) while circulating (280 gpm wI 3430 psi). Had a large amount of cuttings come across shakers on btms-up. Total circulation = 1399 bbl. Calculated ECD @ 13045 after circulating = 11.31ppg, Actual ECD = 11.33 ppg P/U 145k SIO 36k Rot Wt 92k while circulating. 08:30 - 12:30 4.00 DRILL P PROD2 POOH to 7514' with no problems, Max drag 10-15k. Orient bit @ 13 deg LHS. Stop pumping & pick up on drill string & place circulation sub at middle of window @ 7430'. 12:30 - 14:00 1,50 DRILL P PROD2 Drop ball-rod, Break circulation. Open circ sub with 2300 psi. Stage pumps to 550 gpm with 3470 psi. Wash whipstock face Printed: 3/112004 9:51:23 AM BP Operations Summary Report Page 18 of 28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Date I-Iou rs Task Code NPT Phase Description of Operations 2/1012004 12:30 - 14:00 1.50 DRILL P PROD2 10 minutes. Stop pumping. Pull bit above whipstock. Pump LV sweep. Reciprocate & rotate (60RPM) while circulating the hole clean from 7358' with 565 gpm @ 3630 psi. 14:00 - 17:00 3.00 DRILL P PROD2 POOH from 7358' to top of BHA. 17:00-17:15 0.25 DRILL P PROD2 SAFETY- Held PJSM with rig crew & Anadrill personnel on removing RA source & UD BHA. 17:15 - 19:30 2.25 DRILL P PROD2 Remove RA source from ADN tool. UD 6-3/4" BHA. 19:30 - 20:00 0.50 DRILL P PROD2 Clean rig floor & remove excess directional equipment. 20:00 - 20:30 0.50 WHIP P COMP SAFETY- Held PJSM with rig crew, Anadrill & Baker personnel regarding MlU Whipstock retrieving tool (WSRT) & BHA. 20:30 - 22:00 1.50 WHIP P COMP MlU WSRT & BHA. Shallow test MWD-OK. 22:00 - 00:00 2.00 WHIP P COMP TIH with WSRT & BHA on 4" DP to 3700' (Midnight depth). 2/1112004 00:00 - 01 :00 1.00 WHIP P COMP Continue TIH with WSRT & BHA on 4" DP from 3700' to 7400'. 01 :00 - 01 :30 0.50 WHIP P COMP Break circulation. Stage pumps to 225 gpm w/1375 psi. Orient WSRT to 13 deg LHS, (P/U Wt 140k SIO Wt 80k). Slack off on drill string to 7429'. PIU & engage whipstock. Pull on whipstock with 55k overpull, no release. Jar on whipstock 4 times to release whipstock with 60k over pull (200k on Wt Indicator) . PIU & pull seals out of bottom tie-back receptacle. Pull whipstock up to 7390' (P/U Wt = 145k). Monitor well-static. 01 :30 - 03:00 1.50 WHIP P COMP CBU from 7390' wI 225 gpm @ 1375 psi. Flow check. Well static. Pump slug. 03:00 - 06:00 3.00 WHIP P COMP POOH with whipstock assembly #1 to top of BHA. 06:00 - 10:00 4.00 WHIP P COMP Stand back 4" HWDP. UD 9 x 4-3/4" DC, MWD, Whipstock retrieving tool, L 1 Whipstock & 3.5" DP space-out assembly, 100% recovery of all Whipstock & downhole tools. Clear & clean rig floor. 10:00 - 15:30 5.50 CASE N WAIT COMP Suspend liner running operations due to Phase II weather conditions. Having problems keeping L- Pad access road open with the rig's Front End Loader & limited snow moving equipment from the Roads & Pad maintenance group. NOTE: Install Upper remote activated IBOP valve on TDS, Work originally scheduled to be done after running liner. 15:30 - 16:00 0.50 CASE P COMP RlU to run 4.5" Slotted liner. 16:00 - 16:15 0.25 CASE P COMP SAFETY- Held PJSM with rig crew & BOT personnel regarding running liner & PIU Hook Hanger assembly. 16:15 - 22:30 6.25 CASE P COMP MlU 4-1/2" Float Shoe (Bent) Jt + 130 Jts of 4-112" 12.6#, L-80, IBT-M slotted liner + 1 Pup Jt + 2 Jts of slotted liner + 1 Pup Jt + 1 Jt of solid liner & BOT Flanged Hook Hanger assembly. Total length = 5569.09' P/U Wt = 90k SIO Wt = 65k Theoretical Liner Wt in mud = 60,315 Lbs 22:30 - 23:00 0.50 CASE P COMP RID 4.5" Liner running equipment. Install DP elevators on TDS, 23:00 - 23:30 0.50 CASE P COMP TIH with 4-1/2"12.6# Slotted liner assembly on 4" DP to 6697'. 23:30 - 00:00 0.50 CASE P COMP P/U 12 x 4-3/4" drill collars & rack in derrick (Collars will be ran in string to add extra push down weight on liner). 2/12/2004 00:00 - 01:00 1.00 CASE P COMP Finish P/U 12 x 4-3/4" drill collars & rack in derrick. 01 :00 - 01 :30 0.50 CASE P COMP Continue TIH with 4-112" 12.6# Slotted liner assembly on 4" DP to 7353'. P/U 110k SIO 75k 01 :30 - 02:00 0.50 CASE P COMP M/U TDS. Rotate string @ 5 rpm, monitor torque readings. I Printed: 3/112004 9:51 :23 AM BP Operations Summary Report Pag~,19 of. 28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Date From '- To Hours Task Code NPT Phase Description of Operations 2/1212004 01 :30 - 02:00 0.50 CASE P COMP Stop rotating. Slack-off on string past window @ 7436'. TIH. Tag up on the "Mother Bore" liner top packer @ 7541'. POOH to 7406' 02:00 - 07:00 5.00 CASE P COMP Apply 1/4 RH turn in string, Reciprocate string to relax torque. TIH with the 4-1/2" slotted liner successfully entering the L 1 lateral @ 7436'. Continue TIH to 12935' (68 stands in) with no problems encountered. 07:00 - 08:00 1.00 CASE P COMP Work pipe down to hook depth (shoe at 12988' MD) - 52' in on std #69 vs calc of 49' in. Hanger appears to be hooked at this depth. PU and rotate string 1/2 tum. Work pipe down (losing almost all pipe wt) back down past hook point to 63' in. 08:00 - 08: 15 0.25 CASE P COMP Pull up and rotate 1/2 tum. Run in and go past hook point. Rotate additional 114 turn. Run in and hook hanger at 52' in - same as before. 08:15 - 08:30 0.25 CASE P COMP Break circ at 3 bpm @ 525 psi. Stack all available pipe wt + 10000# TD wt to keep hook hanger engaged while allowing pipe to relax. 08:30 - 09:00 0.50 CASE P COMP Circ down liner release ball and land on seat. Pressure up to 2900 psi and see ball seat shear - premature. Should have sheared at -4000 psi. PU and appears that running tool did not release from hanger. 09:00 - 10:00 1.00 CASE P COMP Drop secondary release ball and pump down on seat. Pressure up to 3500 psi and PU string. Broke over at 145 klbs - released off hook hanger. Pull up above hanger, wait 10 min and go back down, Found hanger at same depth - OK. Liner Shoe at 12988' MD. Top of hanger at 7419' MD. 10:00 - 16:00 6.00 CASE P COMP POOH with 4" DP (wet) from 7419'. UD BOT Hook Hanger running tool. 16:00 - 17:00 1.00 CASE P COMP Clean up MOBM from rig floor that was generated from wet trip. 17:00 - 17:30 0.50 CASE P COMP RIU 4.5" Liner running equipment. 17:30 - 18:00 0.50 CASE P COMP SAFETY- Held PJSM with Rig Crew & BOT service personnel on picking up & running the ZXP-LEM assembly. 18:00 - 18:30 0.50 CASE P COMP MIU and run 4.5" tail pipe consisting of mule shoe Jt + 1 Jt of 4-1/2", 12,6#, L-80 tubing + 1 each 4.5" Pup Jt. M/U LEM-ZXP Packer assembly. Total length = 162.02'. RID Tubing handling equipment. P/U 44k S/O 43k 18:30 - 23:00 4.50 CASE P COMP TIH with 4.5" tail-pipe + LEM-ZXP packer assembly on 4" DP. Tag up @ 7419'. Apply 1/2 tum RHT in string. Work string. P/U Wt = 132k SIO Wt = 88k 23:00 - 23:30 0.50 CASE P COMP Continue TIH to 7541' with no other problems. Slack off on string to set the lEM into the hook hanger collet @ 7422' with the 4.5" mule shoe at 7547.94'. Land LEM with 30k. PIU 10k to verify set, then slack off 10k on ZXP packer & park pipe. Drop the 29/32" setting ball and pump onto seat @ 4 bpm wI 650 psi. Pressure up to 3000 psi to set ZXP packer. Continue pressuring up to blow ball seat. The ball seat sheared at 3300 psi ( Ball seat was set to shear @ 4000 psi ). PIU 10', verify packer set. Slack back down on packer with 45k. Rotate at 15 rpm for one minute with rotating dogs engaging ZXP Tie back sleeve, Spud packer 2 times with 50k set down wt. P/U to Printed: 3/112004 9:5123 AM BP Operations' Summary Report Page 20 of 28 L-200 L-200 DRILL+COMPLETE Start: 12/31/2003 NABORS ALASKA DRILLING I Rig Release: 2/23/2004 NABORS 9ES Rig Number: From-To HourSITaSk!CÓde! NPT!Phase ______ . __" i . .__..!... ~. ___.__"" j . . . _:..___.._._. . 23:00 - 23:30 0.50 CASE P COMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date .. .., ---- ... 2/12/2004 Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations . . _ ..___..._n.._. . .--- -- .-.- .. .-.. .- .-.--... .. 7350' Note: Top of L 1 ZXP Tie-back sleeve @ 7385.92' PIU 125k SIO 80k 23:30 - 00:00 0.50 CASE COMP CBU from 7350' wI 396 gpm @ 2400 psi. 2/13/2004 00:00 - 00:30 0.50 CASE COMP Finish CBU from 73S0'. 00:30 - 01 :00 O.SO CASE COMP Flow check. Well static. Pump slug. Blow down TDS. 01 :00 - 04:30 3.S0 CASE COMP POOH from 7350' with 4" DP. UD BOT Packer setting tool. 04:30 - 05:00 0.50 BOPSU COMP Monitor well-static. Drain BOP. Pull wear bushing. 05:00 - 07:30 2.S0 BOPSU COMP Complete installation of Upper Remote IBOP valve on TDS. Function test same~K. 07:30 - 08:00 0.50 BOPSU COMP MIU BOP test plug on 4" DP. Seat in wellhead. RlU to test BOP's, 08:00 - 12:00 4.00 BOPSU COMP Test BOP's & all surface related equipment to 250/3500 psi. The BOP test was witnessed by Jeff Jones-AOGCC. All test were API. 12:00 - 12:30 0.50 BOPSU P COMP RID test equipment. Pull test plug. Run wear bushing. Blow down surface equipment. 12:30 - 14:30 2,00 STWHIP P COMP Slip & cut 85' of drill line. Reset & check C-O-M. Inspect & adjust Drawworks brakes. Service TDS. 14:30 - 14:45 0.25 STWHIP P PROD3 Bring Whipstock & other related BHA components to rig floor. 14:45 - 15:00 0.25 STWHIP P PROD3 SAFETY--- Held PJSM with Rig Crew, Schlumberger MWD & Baker personnel regarding handling & running procedures for Whipstock & BHA. 15:00 - 17:30 2.50 STWHIP P PROD3 MIU Baker 7-5/8" Whipstock assembly #2. Orient MWD with whipstock. 17:30 - 20:30 3.00 STWHIP P PROD3 TIH with 7-5/8" Whipstock assembly on 4" DP to 7334'. PIU = 140k SIO = 87k 20:30 - 21 :30 1.00 STWHIP P PROD3 M/U TDS, Estabish circulation. Orient whipstock 15 deg LHS. Stab dummy seal assembly into Top of the (L 1) tie-back sleeve (11' sleeve) @ 7386'. Set down 35k to set whipstock anchor. PU 10k over to verify anchor set. Set down 45k to shear whipstock lug. Test 7-5/8" casing to 1000 psi for 10 minutes-OK. Note: Top of Whipstock Face set @ 7320'. Planned window 7320'-7332'. 21 :30 - 00:00 2.S0 STWHIP P PROD3 Mill Window in 7-S/8" casing from 7320' to 7330.' RPM = 80 Torque = 8.5k FtLb GPM = 250 @ 1670 psi P/U 135k SIO 80k Rotate Wt = 99k 2/14/2004 00:00 - 01 :30 1.S0 STWHIP P PROD3 Finish Milling Window in 7 -S/8" casing from 7330 to 7332' and drill 16' of new hole to 7348'. NOTE: Window cut in 7-5/8" csg F/7320' to 7332' RPM = 80 Torque = 8.5 KFtLb GPM = 250 @ 1670 psi PIU 135k SIO 80k Rotate Wt = 99k 01 :30 - 02:30 1.00 STWHIP P PROD3 Pump Hi-vis sweep & circulate hole clean from 7348' wI 250 I gpm @ 1670 psi. Reciprocate & rotate drill string (110 RPM) : Printed: 3/112004 9:51 :23 AM Page21 of28 BP Operations Summary Report PROD3 while circulating. PROD3 Perform FIT. Pressure up on formation to 650 psi with 9.2 ppg MOBM @ 4318' TVD = 12.1 ppg EMW. Flow check. Well static. Pump slug. Blow down TDS & related equipment. POOH with Mill Assy & 4" DP to top of BHA, POOH with BHA. UD BOT mills & related equipment. Clear rig floor of excess whipstock milling equipment. MIU ported sub. Flush out BOP's. UD sub. P/U an additional 25 jts of rental new 4" HT -40 HWDP from pipe shed + TIH with 23 jts of NAD 4" HWDP from derrick. Circulate through same at 400 gpm for 15 minutes to remove any scale build up from inside the pipe. POOH & rack the 4" HWDP in derrick. Clean rig floor SAFETY-- Held PJSM with Anadrill and all rig personnel regarding picking up BHA & loading RA source. M/U 6-3/4" Steerable Drilling assembly, Test MWD-OK. TIH with 6-3/4" Steerable Drilling assembly on 4" DP to 7270'. MIU TDS. Establish circulation. Orient MWD to 15 deg LHS to exit window. Stop pumps, Slack off & exit window and RIH (L2 lateral) to 7335' without any problems. Establish baseline ECD of 10.57 ppg @ 275 gpm. Wash & ream from 7335' to 7348'. PIU 138k SIO 86k No pump. Benchmark ECD = 10.41 ppg @ 275 gpm. ECD with 275 gpm + 60 rpm = 10.61 ppg. PROD3 Drill 6-3/4" directional hole (L2 lateral) from 7348' to 7606'. Slide as required to maintain inclination & azimuth. WOB = 5-10k RPM = 60 Torque off Btm = 7k FtLb, Torque on Btm = 7.5k FtLb GPM = 275 @ 2900 psi on Btm, 2660 psi off Btm P/U 135k SIO 80k ROT 100k PROD3 Drill 6-3/4" directional hole (L2lateral) from 7606' to 8821'. Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs. RPM = 60 Torque off Btm = 8k ft Ibs, Torque on Btm = 8-9k ft Ibs. GPM = 275 @ 3331 psi on Btm, 3100 psi off Btm PIU 155k SIO 75k Rot 103k. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date Frorn - To Hours Task Code NPT Phase 2/14/2004 01 :30 - 02:30 02:30 - 03:00 1.00 STWHIP P 0.50 STWHIP P 03:00 - 07:00 4.00 STWHIP P PROD3 07:00 - 08:30 1.50 STWHIP P PROD3 08:30 - 09:00 0.50 DRilL P PROD3 09:00 - 13:00 4.00 DRilL P PROD3 13:00 - 13:15 0.25 DRILL P PROD3 13:15 - 13:30 0.25 DRILL P PROD3 13:30 - 15:30 2,00 DRILL P PROD3 15:30 - 19:00 3.50 DRILL P PROD3 19:00 - 20:00 1.00 DRILL P PROD3 20:00 - 00:00 4.00 DRILL P 2/1512004 00:00 - 11 :00 11.00 DRILL P Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Survey every 30'. Calculated ECD @ 7600' = 10.29 ppg, Actual ECD = 10.77 ppg ART = 0.10 Hrs AST = 1.71 Hrs. Survey & Connection time = 2.19 Hrs Drilling Time last 24 Hrs= 1.81 hrs Printed: 3/112004 9:51 :23 AM ~ BP QperationsSummaryRepol't Page 22 of28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Date NPT Phase Descriptîon of Operations 2/15/2004 00:00 - 11 :00 11.00 DRILL P PROD3 Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Survey every 30'. Calculated ECD @ 8821' = 10.79 ppg. Actual ECD = 11.47 ppg. 11 :00 - 12:30 1.50 DRILL P PROD3 Circ hole clean prior to short trip. Total circulation = 590 bbl @ 275 gpm wI 3060 psi. Reciprocate & rotate (60 RPM) while circulating. P/U 160k SIO 80k Rot Wt 103K Calculated ECD after circulating @ 8821' = 10.83 ppg, Actual ECD = 11.06 ppg. 12:30 -14:30 2.00 DRILL P PROD3 Made 16 std wiper from 8821'-7361'. Had one tight spot while POOH @ 7930'. Worked drill string through same with no other problems. Wash last std to bottom (SOP) with no problems. Hole in good condition. 14:30 - 00:00 9.50 DRILL P PROD3 Continue drilling 6-3/4" directional hole (L2 lateral) from 8821' to 10126', Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs. RPM = 60 Torque off Btm = 10k ft Ibs, Torque on Stm = 10-11k ft Ibs. GPM = 275 @ 3230 psi on Btm, 3020 psi off Stm PIU 156k SIO 68k Rot 100k. Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Survey every 30'. Calculated ECD @ 10126' = 11.0 ppg. Actual ECD = 11.45 ppg. Drilling Time last 24 Hrs= 6.39 hrs ART = 3.81 Hrs AST = 2,58 Hrs, Survey & Connection time = 14.11 Hrs 2/16/2004 00:00 - 04:30 4.50 DRILL P PROD3 Drill 6-3/4" directional hole (L2Iateral) from 10126' to 10654'. Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs. RPM = 60 Torque off Btm = 10k ft Ibs, Torque on Btm = 10-11k ft Ibs. GPM = 275 @ 3230 psi on Btm, 3020 psi off Btm P/U 156k SIO 68k Rot 100k. Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Survey every 30'. Calculated ECD @ 10650' = 11.10 ppg. Actual ECD = 11.81 ppg. 04:30 - 06:00 1.50 DRILL P PROD3 Having problems getting drill string to slide. Pump a Hi-vis sweep. Circulate & condition mudlhole wI 280 gpm @ 3125 psi. Reciprocate & rotate (85 RPM) to help aid in hole cleaning. PIU 156k SIO 68k Rot 100k 06:00 - 07:30 1.50 DRILL P PROD3 Continue drilling 6-3/4" directional hole (L2 lateral) from 10654' Printed: 311/2004 9:51 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/16/2004 2/17/2004 Oate 06:00 - 07:30 07:30 - 09:30 09:30 - 12:00 12:00 - 13:00 13:00 - 00:00 00:00 - 11 :30 Page 23 .of 28 BP Operations Summary Report L-200 L-200 ORILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES To Hours Task Code NPT 1.50 DRILL P 2.00 DRILL P 2,50 DRILL P 1.00 DRILL P 11.00 DRILL P 11.50 DRILL P Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 2/23/2004 PROD3 to 10873', Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs. RPM = 60 Torque off Btm = 10k ft Ibs, Torque on Btm = 10-11k ft Ibs. GPM = 275 @ 3370 psi on Btm, 3020 psi off Btm P/U 165k SIO 55k Rot 97k. Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Survey every 30'. Calculated ECD @ 10650' = 11.10 ppg. Actual ECD = 11.60 ppg. PROD3 Circulate & condition mudlhole (Circ 800 bbl) from 10873' wI 290 gpm @ 3230 psi. Reciprocate & rotate (60 RPM) to help aid in hole cleaning, Add 150 bbl of new 9.1 ppg MOBM into mud system. PIU 165k 5/0 55k Rot97k Calculated ECD @ 10650' = 11.10 ppg. Actual ECD = 11.60 ppg, PROD3 Commence 25 Std wiper trip from 10873-8542'. POOH wI 15-25k (normal) intermittent drag from 10200'-9975', At 9975' encountered tight spot. Max over pull 40k. Work through same, Continue POOH with 15-25k drag to 9015', hole slick from 9015'-8542' . PROD3 TIH from 8542' to 10780' with no problems. Establish circulation. Precautionary wash & ream last std to bottom @ 10873'. PROD3 Continue drilling 6-3/4" directional hole (L2 lateral) from 10873' to 11993'. Slide as required to maintain inclination & azimuth, WOB = 10-15 klbs. RPM = 60 Torque off Btm = 10.5k ft tbs, Torque on Btm = 11-12k ft Ibs, GPM = 275 @ 3550 psi on Btm, 3360 psi off Btm PIU 157k SIO 63k Rot 98k. Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Survey every 30'. Calculated ECD @ 11990' = 11.45 ppg. Actual ECD = 11.98 ppg. Drilling Time last 24 Hrs= 5.21 hrs ART = 3.39 Hrs AST = 1.82 Hrs. Survey & Connection time = 11.79 Hrs PROD3 Drill 6-3/4" directional hole (OBa lateral) from 11993' to 13115'. Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs. RPM = 60 Torque offBtm = 10-11k ft Ibs, Torque on Btm = 11.5k ft Ibs. GPM = 275 @ 3410 psi on Btm, 3309 psi off Btm Printed: 31112004 9:51 :23 AM BP ()perationsSummaryReport Page 24 of 28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Date Code NPT Phase Description of Operations 2/17/2004 00:00 - 11 :30 11.50 DRILL P PROD3 P/U 166k SIO 50k Rot 95k, Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Survey every 30', Pump a lo-vis (base oil) sweep every 100' drilled Calculated ECD @ 13115' = 11.43 ppg. Actual ECD = 11.84 ppg. Drilling Time last 24 Hrs= 3.03 hrs ART = 2.17 Hrs AST = 0.86 Hrs. Survey & Connection time = 8.47 Hrs 11 :30 - 14:00 2.50 DRILL P PROD3 Pump lo-vis sweep and circulate BU volume X 3 300 gpm @ 3450 psi RPM = 110 PIU 155k SIO 55k Prior to short trip: Calculated ECD = 11.28 ppg. Actual ECD = 11.99 ppg. 14:00 - 17:00 3.00 DRILL P PROD3 Monitor well -static. POH from 13115' to 12563'. Numerous overpulls to 40 klbs over from 12955' to 12647'. Work through tight spots without pumping. Unable to pull above 12563' with overpulls up to 60 klbs. Run back in hole to 12635' & break circulation slowly at 70-80 gpm initial. Start making progress immediately. Stage pumps up to 300 gpm and POH to 12500'. Able to make progress while circulating. PIU 180k SIO 45k WIO Pumps 17:00 - 21 :30 4.50 DRILL P PROD3 RIH to 12520' and backream out to 10873' without problems. 290 gpm @ 3580 psi RPM = 80 ROT 94k 21 :30 - 22:00 0.50 DRILL P PROD3 POH - no pump, no rotary from 10873' to 10500'. No problems pulling through previously wiped section. PIU 175k S/O 77k 22:00 - 00:00 2.00 DRILL P PROD3 RIH from 10500' to 12533'. Break circ and work through obstruction at 12560' - just past an invert point. PIU 171k S/O 75k 2/1812004 00:00 - 01 :30 1.50 DRILL P PROD3 Wash down from 12553' to 13115', 100 gpm, 40 rpm 01 :30 - 05:00 3.50 DRILL P PROD3 Pump la-vis sweep and circulate BU volume X 3. 300 gpm @ 3840 psi RPM = 80 Calculated ECD = 11.46 ppg, Actual ECD prior to trip = 11.7 ppg 05:00 - 06:30 1.50 DRILL P PROD3 15 stand short trip to 11713'. Work thru tight spots at 12990' 12605'. 180 klbs up. 75 klbs dn - no pump. Printed: 31112004 9:51:23 AM e Page 25 of 2.8 BP Operations Summary Report RIH to bottom. Work thru tight spot 12900-12923', Then OK to bottom. CBU 4X staging pumps up to 300 gpm @ 3875 psi. 110 rpm rotary. ECD 11.42 ppg calc vs final ECD actual of 11.7 ppg. 160 klbs up. 65 klbs dn - pumps on. 183 klbs up. 67 klbs dn - pumps off. PROD3 Monitor well - static. POH from 13115' to window at 7320'. P/U 177k SIO 68k coming off bottom, pumps - off PROD3 Open circ sub and circulate across whipstock face, from 7332' to 7320', to clean retrieval slot. 400 gpm @ 2240 psi. Pull up inside casing at 7300'. pump 15 bbllo-vis sweep around at 450 gpm, 2415 psi and 60 rpm. Monitor well - static. Cut and slip 98' of drilling line Pump dry job and POH Monitor well- static. PJSM with Anadrill and all rig personnel on removing RA source. Remove RA source and LD BHA. Clean and clear rig floor. PJSM with BOT, Anadrill and all rig personnel on making up retrieval BHA and retrieving whipstock. PU and orient whip stock retrieval BHA #10. RIH with HWDP. Shallow test MWD. RIH to retrieve whipstock. Stage up pumps, orient MWD to 17 degrees left of high side, PIU 155 klbs, SIO 80 klbs. PU up and engage hook in retrieval slot. PU to 200 klbs, trip jars, SO to 70 klbs, Repeat picking up to 210 klbs, 220 klbs and 230 klbs. Whipstock released at 230 klbs PU. POH 30', PIU 158 klbs. stage up pumps and CBU, 270 gpm @ 1870 psi. Monitor well - static, Slug DP and POH. legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: l-200 l-200 DRill +COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Date From-To Hours Task Code NPT phase 2/18/2004 06:30 - 07:30 1.00 DRILL P PROD3 07:30 - 12:00 4.50 DRILL P PROD3 12:00 - 16:00 4.00 DRILL P 16:00 - 17:00 1.00 DRILL P 17:00 - 18:00 1.00 DRILL P PROD3 18:00 - 21 :30 3.50 DRILL P PROD3 21 :30 - 00:00 2.50 DRILL P PROD3 2/19/2004 00:00 - 00:30 0.50 DRILL P PROD3 00:30 - 01 :00 0.50 STWHIP P PROD3 01 :00 - 02:30 1.50 STWHIP P PROD3 02:30 - 03:00 0.50 STWHIP P PROD3 03:00 - 05:30 2.50 STWHIP P PROD3 05:30 - 06:00 0,50 STWHIP P PROD3 06:00 - 06:30 0.50 STWHIP P PROD3 06:30 - 10:00 3.50 STWHIP P PROD3 - 10:00 - 12:00 2,00 STWHIP P PROD3 12:00 - 13:30 1.50 STWHIP P PROD3 13:30 -14:30 1.00 STWHIP P PROD3 14:30 -15:00 0.50 CASE P PROD3 15:00 - 15:30 0.50 CASE P COMP 15:30 - 21 :30 6.00 CASE P COMP 21:30 - 22:00 22:00 - 23:00 23:00 - 23:30 0.50 CASE P 1.00 CASE P 0.50 CASE P COMP COMP COMP Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations' PIU 158 klbs. Monitor well at the BHA - static. Continue POH standing back HWDP and DC's LD whipstock retrieval BHA and whipstock. LD Baker tools and clean and clear rig floor. Bring liner equipment to rig floor. PJSM with BOT and all rig personnel on running liner and Hook Hanger assembly. RU to run liner. Run 136 joints of 4-1/2", 12.6#, L-80, IBT-M slotted liner as per running orders. MU 1 joint solid liner and Hook Hanger assembly. PIU 90 klbs S/O 65 klbs RD liner running equipment and RU to RIH with DP. RIH with liner on 4" DP to top of window at 7320' Establish string weights and baseline torque, PIU 110 klbs, S/O 75 klbs, ROT 83 klbs, TQ 3.5 klbs. RIH on first attempt to exit window, tag up on tie back sleeve at 7406'. POH to top of window, rotate DP 1/4 tum and work torque into string. RIH and exit window on second attempt. Printed: 3/112004 9:51:23 AM BP OperatiQns Summary Report Page 26 of 28 Legal Well Name: L-200 Common Well Name: L-200 Spud Date: 1/15/2004 Event Name: DRILL +COMPLETE Start: 12/31/2003 End: 2/23/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/23/2004 Rig Name: NABORS 9ES Rig Number: From~To Hours Task Code NPT Phase Description of Operations 2/19/2004 23:30 - 00:00 0.50 CASE P COMP Continue RIH with liner on 4" DP. Midnight depth = 7689' 2/20/2004 00:00 - 07:30 7.50 CASE P COMP Continue RIH with 4-1/2" slotted liner on 59 stds DP plus 16 stds 4" HWDP and 4 stds 4 3/4" DC's. RIH 10' past hook depth. 195 klbs up, 65 klbs dn - no pump. 07:30 - 07:45 0.25 CASE P COMP PU 20' above hook depth and put 1/2 turn in string. Work torque down and lost all string weight. 07:45 - 08:00 0.25 CASE P COMP Work string and regain 5-10 klbs string wt (35-45 klbs weight indicator). Run in past hook depth 10' again. 08:00 - 08:15 0.25 CASE P COMP PU - now 220 klbs and pull 1 0' above hook depth. Put 1/4 turn in string and work torque down. RIH v. slow and engage hook on lower lip of window. Stack out all available pipe wt + 5-10 klbs TD weight to verify hooked. PU & SO to verify hooked - OK with approx 15 klbs set down weight. 08:15 - 09:15 1.00 CASE P COMP Break circ @ 3 bpm - 500 psi to help pipe relax, still keeping partial TD weight on string. SD and drop 29/32" release ball and pump down on seat at 61.2 bbls away - 4 bpm slowing to 2 bpm. Land ball on seat and pressure up to 3000 psi to release setting tool. Hold for 5 min. Pull up to PUW - now 150 klbs and confirm released off liner. Pull up 15' then run back in and tag up at same depth. Hanger has not moved. PU again and continue pressuring up to 4050 psi and shear ball seat. 09:15 -10:00 0.75 CASE P COMP CBU, 400 gpm @ 2820 psi 10:00 - 13:30 3.50 CASE P COMP Monitor well - static. Slug DP and POH, PIU 150 klbs, SIO 100 klbs. Stand back HWDP and DC's 13:30 - 14:00 0.50 CASE P COMP LD running tool. Clean and clear rig floor. 14:00 - 14:30 0.50 CASE P COMP RU csg equipment to run ZXP, LEM and tbg tail 14:30 - 15:00 0.50 CASE P COMP PJSM with BOT and all rig personnel on making up and running LEM, ZXP assembly. 15:00 -16:00 1.00 CASE P COMP MU mule shoe, pup jts, LEM and ZXP liner top packer 16:00 - 17:30 1.50 CASE P COMP RIH with LEMlZXP assembly on HWDP. MU TDS to each stand to prevent MOBM from running over. 17:30 - 21 :30 4.00 CASE P COMP Continue RIH with LEMIZXP assembly on DP. PIU 140 klbs SIO 85 klbs 21 :30 - 22:00 0.50 CASE P COMP Continue RIH, with mule shoe passing through liner hanger and engaging in L 1 tie back sleeve. Slack off engaging LEM in hook hanger. PU and verify LEM is engaged. 22:00 - 22:30 0.50 CASE P COMP PJSM with BOT and ALL rig personnel on pressuring up to set packer and shear ball seat. 22:30 - 00:00 1.50 CASE P COMP SO 40 klbs on packer. Drop ball and pump on seat. 4 bpm for 1/2 the DP volume, reducing rate to 2 bpm to seat ball. Continue pumping, pressuring up to 3000 psi to set packer, hold for 5 minutes. Continue pressuring up to 3500 psi to release setting tool, hold for 2 minutes. PU and verify setting tool released. SO 40 klbs while rotating at 15 rpm to set rotating dog sub. Pressure up to 4000 psi with rig pump, ball seat did not shear. RU test pump and pressure up to 4700 psi to blow ball seat. 2/21/2004 00:00 - 02:00 2.00 CASE P COMP Displace well to new 9.3 ppg NaCI brine, 225 gpm @ 578 psi. Pump Schedule: Printed: 3/112004 9:5123 AM BP Operations Summary Report Page 27 of 28 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Date From- To Hours Task Code NPT Phase DescriptionofOperatións 2/21/2004 00:00 - 02:00 2.00 CASE P COMP 25 bbls base oil 25 bbls viscosified brine 50 bbls Safe Surf 0 25 bbls viscosified brine 294 bbls 9.3 ppg NaCI brine 02:00 - 03:30 1.50 CASE P COMP Clean MOBM from under shakers, possum belly and rig floor 03:30 - 09:30 6.00 CASE P COMP POH laying down DP. 09:30 - 10:00 0.50 CASE P COMP LD 25 joints of rented 4" HWDP, standback 7 stands of NABORS HWDP. 10:00 - 11 :00 1.00 CASE P COMP LD BOT running tool. Clean and clear rig floor. 11 :00 - 12:30 1.50 BOPSU P COMP Pull wear bushing, RU BOPE test equipment. MU test plug and RIH 12:30 - 16:30 4.00 BOPSU P COMP Test BOPE 250 psi low and 3500 psi high. Pull test plug and install wear bushing. Witness of BOP test waived by John Crisp with AOGCC. 16:30 - 19:00 2.50 CASE P COMP RIH with 4 stands of DC's and 41 stands of DP 19:00 - 20:30 1.50 CASE P COMP PJSM with all hands. Cut and slip 72' of drill line. Service top drive, blocks and crown. 20:30 - 0.00 CASE P COMP Monitor well - static. Slug DP and POH laying down DP and DC's 2/22/2004 00:00 - 00:30 0.50 CASE COMP Move HWDP to ODS. Clean and clear rig floor 00:30 - 01 :00 0.50 BOPSU COMP Pull wear bushing. MU landing joint and make dummy run with tubing hanger. 01 :00 - 03:00 COMP CO bails, RU tbg equipment. RU control line spool for I-wire. 03:00 - 03:30 COMP PJSM with BOT, Centrilift, Cameo, Nabors Casing and all rig personnel on making up and running completion. 03:30 - 04:00 COMP PU and MU 4.5", 12.6#, L-80, IBT-M completion assembly as per running orders. 04:00 - 05:30 COMP MU and test I-wire control line for Phoenix gauge. 05:30 - 14:30 COMP Run 169 joints of 4-1/2", 12.6#, L-80, IBT-M completion tubing with jewelry as per running orders. MU and run I-wire for Phoenix pressure sensor. Check sensor and I-wire every 1000' of tbg run. MU 1 control line clamp per tbg joint for the 1 st 10 joints, then 1 clamp every 2 joints to surface - 90 total clamps run 14:30 - 17:30 COMP RIH to tbg no-go. Space out tbg 2' above no go, placing the mule shoe at 7296'. MU space out pups. Run I-wire through hanger. Land tbg, RILDS and test I-wire. 17:30 - 19:00 COMP Reverse circulate 3 bbls clean brine followed by 4 bbls corrosion inhibited brine, followed by 181 bbls clean brine. Placing corrosion inhibited brine between packer and lower GLM. 3 bpm @ 320 psi. 19:00 - 19:30 COMP Drop rod and ball with roller stem. Pressure up to 4200 psi and hold for 10 minutes to set packer. 19:30 - 20:00 COMP Bleed pressure to 3500 psi and hold for 30 minutes to test tbg. 20:00 - 20:30 COMP Bleed tbg pressure to 2500 psi. Pressure up annulus to 3500 psi and hold for 30 minutes. 20:30 - 21 :00 COMP Bleed tbg and annulus pressure to O. Pressure up annulus to shear DCK valve. DCK sheared at 1800 psi. Circulate through the tbg and the annulus to ensure the DCK is open. 21 :00 - 21 :30 0.50 RUNCO COMP LD landing joint and install TWC valve. 21 :30 - 23:00 1,50 BOPSU P COMP ND BOPE. Clean MOBM from under rotary table 123:00 - 00:00 1,00 WHSUR P COMP Move tree into cellar. I I Printed: 3/112004 9:51:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 28 of 28 BP Operations Summary Report L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task Code NPT Phase 2/2312004 00:00 - 02:00 2.00 WHSUR P COMP 02:00 - 03:00 1.00 WHSUR P COMP 03:00 - 04:00 1.00 WHSUR P COMP 04:00 - 05:30 1.50 WHSUR P COMP 05:30 - 08:00 2.50 WHSUR P COMP 08:00 - 10:00 2.00 WHSUR P COMP 10:00 - 12:00 2.00 WHSUR P COMP Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations NU adapter flange and tree. Terminate I-wire through adapter flange and test. Test adapter flange, tree and metal to metal seal to 5000 psi for 20 minutes. PU and RU DSM lubricator. Pull TWC valve, RU secondary kill line and reverse circulate in 45 bbls corrosion inhibited brine, 3 bpm @ 900 psi RU Little Red. Freeze protect, pump 125 bbls diesel at 3 bpm, FCP = 1100 psi Allow diesel to U-tube. Blow down all lines. RU DSM and istall BPV through lubricator, BPV not holding pressure. PULL and install new BPV. Test to 1000 psi from below. RD DSM Secure cellar. Install gauges on tree. Install VR plugs in tbg spool outlets. RIG RELEASED @ 12:00 Printed: 3/112004 9:51 :23 AM e e bp L-200L2 Survey Report Schlumberger Report Date: 17-FeIr04 Client: BP Exploration Alaska Field: Prudhoe Bay Un~ . WOA Structure I Slot: L·PAD 1 N-M Well: L -200 Borehole: L ·2ooL2 UWVAPI#: 500292319161 Survey Name I Date: L·2ooL21 February 17. 2004 Tort/AHDI DDI 1 ERD ratio: 444.741' 1 11192.92 ft 17.175 1 2.565 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04. US Feet Location LatlLong: N 7021 2.361. W 1491927.914 Location Grid NIE YIX: N 5978289.740 ftUS, E 583209.270 ftUS Grid Convergence Angle: +0.63624271' Grid Scale Factor: 0.99990787 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Vertical Section Azimu1h: 334.150' Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 77.60 ft relative to MSL Sea Bed I Ground Level Elevation: 49.10 ft relative to MSL Magnetic Declination: 25.066' Total Field Strength: 57556.526 nT Magnetic Dip: 80.821' Declination Date: February 15. 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North·> True North: +25.066' Local Coordinates Referenced To: Well Head 570.07 11.80 357.00 567.21 489.61 39.14 41.01 40.29 -6.61 2.51 2.44 3.24 5978329,95 583202.22 N 70 212,757 W 149 1928.107 663.59 13,20 1.32 658.51 580.91 57.45 61.24 60.52 -6.86 1.80 1.50 4.62 5978350.17 583201.74 N70212.956 W1491928.114 757.23 14.52 6.44 749.43 671.83 76.89 83.66 82.87 -5.30 1.92 1.41 5.47 5978372,54 583203.05 N70213,176 W 1491928.068 852.84 15,51 10.58 841.77 764.17 97.31 108.42 107.35 -1.61 1.53 1.04 4.33 5978397.05 583206.47 N 70 21 3.416 W 149 1927.960 948.07 17.14 16,92 933.17 855.57 117.85 135.16 133.29 4,82 2.53 1.71 6.66 5978423.07 583212.61 N 70 21 3,672 W 149 1927.773 1041,74 20,60 22.39 1021.80 944.20 138.97 165.43 161.74 15.11 4.14 3,69 5.84 5978451.63 583222.59 N 70 21 3,951 W 149 1927.472 1133.94 23,17 21.67 1107.35 1029.75 162.03 199.80 193.60 27.99 2.80 2.79 -0.78 5978483.62 583235.11 N 70 214.265 W 149 1927.095 1225.20 26.94 17,94 1190.01 1112.41 189.09 238.43 229.97 41,00 4.48 4,13 -4.09 5978520.13 583247.71 N 70 214,622 W 149 1926.715 1316.93 30.08 18.24 1270.61 1193.01 220.61 282.20 271.58 54,59 3.43 3.42 0.33 5978561.89 583260.84 N 70 21 5.032 W 149 1926.318 1411.64 34,84 18,04 1350.50 1272.90 257.17 333.02 319.88 70.41 5.03 5.03 -0.21 5978610.35 583276,12 N 70 21 5.507 W 149 19 25.856 1506.19 39.85 19.56 1425.64 1348.04 297.93 390,36 374,14 88.93 5.39 5.30 1.61 5978664.81 583294.03 N 70 21 6.040 W 149 1925.314 1599.03 45.79 21.02 1493.71 1416.11 341.60 453.43 433.28 110.84 6.49 6.40 1.57 5978724.18 583315.28 N 70 216.622 W 149 1924.674 1611.13 46.32 21.03 1502,11 1424.51 347.55 462.14 441.41 113.97 4.38 4.38 0,08 5978732.35 583318.32 N 70 216.702 W 149 1924.583 1698.21 51.08 22.41 1559.56 1481.96 391.65 527.54 502.16 138.20 5,59 5.47 1.58 5978793,35 583341.87 N 70 217.299 W 149 1923,874 1756.11 50.03 22.45 1596.35 1518.75 421.41 572.25 543.49 155.26 1.81 -1.81 0.07 5978834,87 583358.47 N 70 217.706 W 149 1923.376 1791.91 51.04 23.53 1619.11 1541.51 439.60 599.89 568.93 166,05 3.66 2.82 3.02 5978860.42 583368,98 N 70 21 7.956 W 149 1923.060 1887.20 56.88 23.21 1675.14 1597.54 489.91 676,91 639.63 196.60 6.13 6.13 -0.34 5978931.45 583398.73 N 70 21 8.651 W 149 1922.167 1981.24 58.Q1 25.12 1725.75 1648.15 540.83 756,17 711.94 229,05 2.09 1.20 2.03 5979004.11 583430,38 N 70 21 9.362 W 149 1921.219 2076.97 62,57 27,10 1773.19 1695.59 592.02 839,29 786.56 265.66 5.09 4.76 2.07 5979079.13 583466.15 N 70 2110.096 W 1491920.149 2171.63 62.72 27.00 1816,68 1739.08 642.74 923.37 861.44 303.89 0,18 0.16 -0,11 5979154.42 583503.55 N 70 21 10.833 W 149 19 19.031 2264.42 62,24 26.73 1859,56 1781.96 692,59 1005.66 934.85 341.08 0.58 -0.52 -0.29 5979228.23 583539.92 N 70 2111.555 W 1491917,944 2359.44 61.59 26.48 1904,29 1826.69 743,67 1089.49 1009.80 378.62 0.72 -0.68 -0.26 5979303,59 583576.62 N 70 2112.292 W 149 19 16,847 2452.62 61.59 26.47 1948.62 1871.02 793.76 1171.45 1083.16 415.16 0.01 0.00 -0.01 5979377.34 583612.34 N 70 2113,013 W 149 19 15.779 2546.39 61.38 26.38 1993.39 1915.79 844.18 1253.84 1156.95 451.83 0.24 -0.22 -0.10 5979451.53 583648.18 N 70 2113.739 W 149 19 14.707 2639.87 60.98 24.82 2038.45 1960.85 895.22 1335.74 1230.81 487.22 1.52 -0.43 -1.67 5979525.76 583682.74 N 70 2114,465 W 149 19 13.672 2733.23 60.75 24.80 2083.91 2006.31 946.91 1417.29 1304.83 521.43 0.25 -0.25 -0.02 5979600.15 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310,16 4239.11 4161.51 8160.87 9990.47 7436,37 -3368.20 3.75 2.33 -2.94 5985687,56 579759,03 N 70 2215.489 W 14921 6.447 11942.07 92.25 311.18 4237.91 4160.31 8189.23 10021.39 7456.52 -3391.65 3.30 0.23 3.30 5985707.44 579735,36 N 70 22 15.687 W 149217.133 11972.63 91.63 309.84 4236.88 4159.28 8217.20 10051.93 7476.36 -3414.87 4.83 -2.03 -4.38 5985727.02 579711.92 N 70 2215.882 W 149 21 7.813 12003.05 92.63 309.49 4235.75 4158.15 8244.87 10082.33 7495.76 -3438.27 3.48 3.29 -1.15 5985746.16 579688.31 N 70 22 16,073 W 149 21 8.497 12035,52 93.52 309.67 4234.01 4156.41 8274.36 10114.75 7516.42 -3463.26 2.80 2.74 0.55 5985766.54 579663.10 N 70 22 16.276 W 149 21 9.229 12065.61 93.28 310.28 4232.22 4154.62 8301.76 10144.79 7535.72 -3486.27 2,18 ·0,80 2.03 5985785.58 579639.87 N 70 22 16.465 W 14921 9.902 12096,89 92,80 309.78 4230,56 4152.96 8330.27 10176.02 7555.81 -3510.19 2,21 -1.53 -1.60 5985805.40 579615.73 N 70 2216.663 W 14921 10.602 12127.83 92,18 309,24 4229.22 4151.62 8358.36 10206,93 7575.48 -3534.04 2,66 -2.00 -1.75 5985824.80 579591.67 N 70 2216.856 W 14921 11.300 12158.81 91.42 309.46 4228.25 4150.65 8386.47 10237.90 7595.11 -3557.98 2,55 -2.45 0.71 5985844.16 579567.51 N 70 2217.049 W 14921 12.001 12190.10 91.49 309,86 4227.45 4149.85 8414.94 10269,18 7615.07 -3582.06 1.30 0.22 1.28 5985863.85 579543.21 N 70 2217.245 W 1492112.706 12221.50 91.25 311.06 4226.70 4149.10 8443.68 10300,57 7635.44 -3605,95 3,90 -0.76 3.82 5985883.96 579519.11 N 70 2217.446 W 1492113.405 12252.57 90.50 310,62 4226.23 4148.63 8472,21 10331.64 7655,76 -3629,45 2.80 -2.41 -1.42 5985904.01 579495.38 N 70 2217.645 W 1492114.093 12284.03 89.81 310,09 4226.14 4148.54 8501.00 10363,10 7676,13 -3653.42 2.77 -2.19 -1.68 5985924.11 579471.18 N 70 2217.846 W 1492114.794 12314.63 89.47 310.60 4226.33 4148.73 8528.99 10393,69 7695.94 -3676,75 2,00 -1.11 1,67 5985943.66 579447.65 N 70 2218.040 W 1492115.477 12346.11 90.02 311.26 4226.47 4148.87 8557,92 10425,17 7716.56 -3700,53 2.73 1.75 2,10 5985964.01 579423.64 N 70 2218.243 W 1492116.173 12376.90 91.05 311.62 4226.19 4148.59 8586.33 10455,96 7736,94 -3723,61 3.54 3.35 1.17 5985984.13 579400.34 N 70 2218.443 W 1492116.848 12408.00 91.05 311.87 4225.62 4148.02 8615.07 10487.06 7757.64 -3746,81 0.80 0.00 0.80 5986004.57 579376.91 N 70 2218.647 W 1492117.528 12438,44 90.77 311.35 4225.13 4147.53 8643.18 10517.49 7777.85 -3769.57 1.94 -0.92 -1.71 5986024.53 579353,93 N 70 2218.845 W 1492118.194 12470.84 89.02 311.84 4225.19 4147.59 8672.92 10549.69 7799.23 -3793.65 5.64 -5.43 1.52 5986045,63 579329,62 N 70 2219.056 W 14921 18.898 12500,67 89,13 311.98 4225,68 4148,08 8700.71 10579.72 7819.29 -3815.99 0.59 0.37 0.47 5986065,44 579307.05 N 70 2219.253 W 1492119.552 12531.76 91.97 313.24 4225.38 4147.78 8729.63 10610.80 7840.33 ·3838.87 9.99 9.13 4.05 5986086,22 579283,95 N 70 2219.460 W 14921 20.222 12562,33 92,39 314.42 4224,22 4146.62 8758.27 10641.35 7861.48 -3860.91 4.09 1.37 3,86 5986107,13 579261.68 N 70 2219.667 W 14921 20.867 12594.76 91.73 313.75 4223,05 4145.45 8788.71 10673.76 7884.03 -3884.18 2.90 -2.04 -2.07 5986129.42 579238,15 N 70 2219,889 W 149 2121.548 12625.58 91.90 311.92 4222.07 4144.47 8817.41 10704.56 7904.97 -3906.77 5.96 0.55 -5.94 5986150.11 579215.33 N 70 22 20,095 W 149 21 22.210 12657.06 93,04 312.27 4220.72 4143.12 8846.56 10736.01 7926.06 -3930.11 3.79 3,62 1.11 5986170.93 579191.77 N 70 22 20,302 W 149 21 22.893 12688.67 93.14 312.23 4219.01 4141.41 8875.84 10767.58 7947.28 -3953.47 0.34 0.32 -0.13 5986191.89 579168.17 N 70 22 20,511 W 149 21 23,577 12719.15 93.11 312.14 4217.35 4139.75 8904.07 10798.01 7967.72 -3976.03 0.31 -0.10 -0.30 5986212.07 579145.40 N 70 22 20.712 W 14921 24.237 SurveyEdilor Ver 3,1 RT-SP3.03-HF4.00 Bld( d031rt-546 ) N-MIL-200IL-200L2IL-200L2 Generated 3/19/2004 3:27 PM Page 4 of 5 ,. . e e ., 12907.00 86.21 314.30 4217.18 4139.58 9079.49 10985.64 8096.59 -4112.36 2.25 0.23 -2.24 5986339.41 579007.65 N 70 22 21.978 W 14921 28.227 12938.15 85.59 314.52 4219.40 4141.80 9108.73 11016,71 8118.33 -4134.56 2,11 -1.99 0.71 5986360.90 578985.22 N 70 22 22.192 W 149 21 28.877 12969.55 85.11 314.39 4221.95 4144.35 9138.20 11048.01 8140.25 -4156.90 1.58 -1.53 -0.41 5986382.56 578962.64 N 70 22 22.407 W 149 21 29.531 13001.13 84.45 314.43 4224.82 4147.22 9167.80 11079.46 8162.26 -4179.36 2.09 -2.09 0.13 5986404.32 578939.93 N 70 22 22,624 W 1492130,189 13032.47 84.29 314.79 4227.90 4150.30 9197.19 11110.65 8184.16 -4201.57 1.25 -0.51 1.15 5986425.97 578917.49 N 70 22 22.839 W 149 21 30.839 13062.96 85.76 314.91 4230.54 4152.94 9225.86 11141.02 8205.58 -4223.10 4.84 4.82 0.39 5986447.15 578895.72 N 70 22 23.050 W 149 21 31.469 13115.00 85.76 314.91 4234.39 4156.79 9274,86 11192.92 8242.22 -4259.85 0.00 0.00 0.00 5988483.38 578858,56 N702223.410 W 1492132.545 Leaal DescriDtion: Northina IYI IftUS1 Eastina (XI IftUS1 Surlace: 2567 FSL 3705 FEL 834 T12N R11E UM 5978289.74 583209.27 BHL: 248 FSL 2669 FEL S21 T12N R11E UM 5988483.38 578858.56 SurveyEditorVer 3.1RT-SP3,03-HF4,OO Bld( d031rt-546) N-M\L-200\L -200L2\L-200L2 Generated 3/19/2004 3:27 PM Page 5 of 5 ~ .. . r=a=YNOTES: TREE = FMC 4-1/6" 5M FROM G - DRAFT L-200 WB.U-EAO = FMCGS\l5 L-200 L 1 ACTUATOR = KB. ELEV = 82.30' L-200 L2 BF. ELEV = 53.80' KOP= 380' Max Angle = 96 @ 11569' Datum MO = 5713' ~ Oatum1VO = 4500' SS 20# CONOJCTOR 114' . 2949' 4-lIZ' I-ES X NP, D = 3.813" J 110-3/4" CSG. 40#, L-80,10 = 9.95" 3871' ~ ~ GAS LIFT M\NORB.S Minimum ID = 3.813" @ 2949' ST I\iÐ 1V0 DB' TYPE VLV LATQ-I PORT [)\ 1£ . 3 4258 2860 59 KBG-2 D\1Y BK-5 0 02l22,Q4 4-1(2" HES X NIPPLE L 2 5485 3495 56 KBG-2 D\1Y BK-5 0 02l22,Q4 ........- 1 7002 4197 69 KBG-2 00<2 BEl< 02l22,Q4 4.5"PHOENX DSQ-IRGE-ffiBSS SUB,IO - 3.8S" 7109' f I I -, 7120' 4-1/2" BKR Crv-D SLEEVE: 10 - 3.813" I 4.5" PI-f\J )( MlJ.. TI-PRBSS SS\lSOR, 10 = 3.833" 7144' r-- 'V' I I :8 7169' 7.62S" X 4,S" BKR PRM A<R. 10 = 3,875" <........:: IRA TAG 6983' ~ 7238' 4-1/Z'I-ESX NP, D =3,813" I 7-5/f!' x 5.5" BKR ZXP PACKER, ID = 5.5" 728X 1--. I 7258' 4-lIZ' I-ES X NP, 10 = 3.813" I 5<'1 Iv 7296' 4-lIZ' MIle Shoe I r l~----------------~ BKR HUGI-ES HOOK HGR, D = 5.64" 7315' I b... 7 5/8" W1NJOW @ 7320' ---------------- r' IRA TAG 7270' ~ I I 7332'.. 13044' 6-3/4" OBa LATERAL, ID = 3.958" 7-5/£!' x 5.5" BKR ZXPPACKER, 10 = 3.95" 7386' ~ 7398' 4-lIZ' MIle Shoe I ~ 'ÿ F ~-----------------~ 1 BKR HUGI-ES HOOK HGR, D = 5.64" 7419' I 7 S/£!' W1NOOW@ 7424' !to.. ----------------- ~ ./ IRA TAG 7375' I IRA TAG 7436' -12988' 6-314" OBb LATERAL, ID = 3.958" 7663' ~ ~ 7537' 7.625" X 5,5" BKRZXPLIIR TOPPKR. 10 = 4.810" ÆRFORA ìlON StJI,1M\ RY REF LOG: 7548' 4-1/2" Mule Shoe I ANGLE A TTOPPERF: xx @ xxxx' 7557' 5-lIZ' X4-1/2"XO, 10- 3.96" I Note: Refer to Production œ for historical perf data SIZE SPF INTERVAL Opn/Saz DATE 4-112" SLTO DBA 7392 - 13000 0 02/18/04 4-112" SLTD OBb 7497 - 12944 0 02/12/04 I I 4-1/2" SLTO OBd 7870 - 13008 0 02/04/04 I I I I I I I 1 I 7872' -13,052' 6-314" OBd LATERAL,ID = 3.958" I 1 ~ 1 1 ~ 175/£!' CSG, 26#, L-80, 10 = 6.276" 787X U ~ 13050' I DATE REV BY COMtÆNTS DATE REV BY COtvflAENTS ORION UNT 02/22104 DMlJC ORIGINAL COMFlETION WELL: L-200. L-200 L1, L-200 12 PERMIT No: 204001 (002) (003) AA No: 50-029-23191-00 (60) (61) SEC 34, T12N, R11E, 2567' NSL & 3705' WB. BP Exploration (Alas ka) - e aO.L/"'L~ Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-200 l2 Date Dispatched: 18-Jan-04 Installation/Rig Nabors 9ES Dispatched By: F. Alabi Data No Of Prints No of Floppies Surveys 2 1 RECE IVED .', ? - ?n04 "- '-. '-.\., ,~-" Co ~$. Commission '~"'''!V,11, J'% i!S. Gæ' . f' i',r-¡"M'~ In.:. -'-~rl\.~L':· ~ ".>., Received By: \''') '- Q i~ ,ð"v""\. Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage. Alaska 99503 nrosel@slb,com Fax: 907-561-8417 LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private ~~b(n ~ SCHLUMBERGER Survey report Client............... ....: BP Exploration Inc. Field..... .... ...........: Orion Well. . . . . . . . . . . . . . . . . . . . .: L-200 L2 API number....... ... ... ..: 50-029-23191-61 Engineer.. ... ........ ....: Mark St. Amour RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions... ..: Minimum curvature Method for DLS......... ..: Mason & Taylor ----- Depth reference ----------------------- Permanent datum....... ...: Mean Sea Level Depth reference....... ...: Driller's Pipe Tally GL above permanent.......: 49.10 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 77.60 ft ----- Vertical section origin---------------- Latitude (+N/S-) .........: 0.00 ft Departure (+E/W-) ... .....: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) ..... ....: -999.25 ft Departure (+E/W-). ... ....: -999.25 ft Azimuth from rotary table to target: 334.15 degrees RECEIVED , 2 :5 2004 ~'. ..... ''';.{'' C '. ,.....~'...,"',:. h ;-:,l,.",~, '/'fl1i.'; omm--n _',-:.~<-,> ,J,,;~- ':_' \: '.. ......>f~"" __:ruSh" _ fOO~'~,," : ';;i1i'age ~~\)'\''(\'~ 17-Feb-2004 14:53:29 Spud date. .... . .... . . . ... : Last survey date...... ...: Total accepted surveys...: MD of first survey.... ...: MD of last survey........: fJOL-1 '-ér~3 Page 1 of 10 19-Jan-04 17-Feb-04 267 0.00 ft 13115.00 ft e ----- Geomagnetic data ---------------------- Magnetic model. ..........: BGGM version 2003 Magnetic date......... ...: 12-Feb-2004 Magnetic field strength..: 1151.15 HCNT Magnetic dec (+E/W-).. ...: 25.07 degrees Magnetic dip... ....... ...: 80.82 degrees ----- MWD survey Reference Reference G..... ...... ...: Reference H. .... ... ... ...: Reference Dip.... ........: Tolerance of G... ........: Tolerance of H... ........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.15 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees e ----- Corrections --------------------------- Magnetic dec (+E/W-).. ...: 25.07 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-). ...: 25.07 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 2 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 199.66 0.66 347.45 199.66 199.66 1.12 1.12 -0.25 1.15 347.45 0.33 MWD GMAG 3 293.20 2.62 338.59 93.54 293.15 3.78 3.64 -1.15 3.82 342.50 2.11 MWD GMAG 4 384.95 6.42 345.43 91.75 384.60 10.90 10.56 -3.20 11.03 343.12 4.18 MWD GMAG 5 477.31 9.54 353.99 92.36 476.06 23.17 23.17 -5.31 23.77 347.10 3.61 MWD GMAG 6 570.07 11. 80 357.00 92.76 567.21 39.14 40.29 -6.61 40.83 350.69 2.51 MWD GMAG e 7 663.59 13 .20 1.32 93.52 658.51 57.45 60.52 -6.86 60.90 353.53 1. 80 MWD GMAG 8 757.23 14.52 6.44 93.64 749.43 76.89 82.87 -5.30 83.04 356.34 1. 92 MWD GMAG 9 852.84 15.51 10.58 95.61 841.77 97.31 107.35 -1.61 107.36 359.14 1. 53 MWD GMAG 10 948.07 17.14 16.92 95.23 933.17 11 7.85 133.29 4.82 133.38 2.07 2.53 MWD GMAG 11 1041.74 20.60 22.39 93.67 1021.80 138.97 161.74 15.11 162.45 5.34 4.14 MWD GMAG 12 1133.94 23.17 21. 67 92.20 1107.35 162.03 193.60 27.99 195.62 8.23 2.80 MWD GMAG 13 1225.20 26.94 17.94 91. 26 1190.01 189.09 229.97 41. 00 233.60 10.11 4.48 MWD GMAG 14 1316.93 30.08 18.24 91.73 1270.61 220.60 271.58 54.59 277.02 11.37 3.43 MWD GMAG 15 1411. 64 34.84 18.04 94.71 1350.50 257.17 319.88 70.41 327.54 12.41 5.03 MWD GMAG 16 1506.19 39.85 19.56 94.55 1425.64 297.93 374.14 88.93 384.56 13 .37 5.39 MWD GMAG 17 1599.03 45.79 21. 02 92.84 1493.71 341. 60 433.28 110.84 447.23 14.35 6.49 MWD GMAG 18 1611.13 46.32 21. 03 12.10 1502.11 347.55 441. 41 113.97 455.89 14.48 4.38 MWD GMAG 19 1698.21 51.08 22.41 87.08 1559.57 391. 65 502.16 138.20 520.83 15.39 5.59 MWD GMAG 20 1756.11 50.03 22.45 57.90 1596.35 421. 41 543.49 155.26 565.23 15.94 1. 81 MWD GMAG 21 1791.91 51. 04 23.53 35.80 1619.11 439.60 568.93 166.05 592.66 16.27 3.66 MWD GMAG e 22 1887.20 56.88 23.21 95.29 1675.15 489.91 639.63 196.60 669.16 17.09 6.13 MWD GMAG 23 1981. 24 58.01 25.12 94.04 1725.75 540.83 711.94 229.05 747.88 17.83 2.09 MWD GMAG 24 2076.97 62.57 27.10 95.73 1773.19 592.02 786.56 265.66 830.21 18.66 5.09 MWD GMAG 25 2171. 63 62.72 27.00 94.66 1816.68 642.74 861. 44 303.89 913.47 19.43 0.18 MWD GMAG 26 2264.42 62.24 26.73 92.79 1859.56 692.59 934.85 341.08 995.12 20.04 0.58 MWD GMAG 27 2359.44 61.59 26.48 95.02 1904.29 743.67 1009.80 378.62 1078.45 20.55 0.72 MWD GMAG 28 2452.62 61. 59 26.47 93.18 1948.62 793.76 1083.16 415.16 1160.00 20.97 0.01 MWD GMAG 29 2546.39 61. 38 26.38 93.77 1993.39 844.18 1156.95 451. 83 1242.05 21.33 0.24 MWD GMAG 30 2639.87 60.98 24.82 93.48 2038.45 895.22 1230.81 487.22 1323.73 21. 60 1. 52 MWD GMAG SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 3 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2733.23 60.75 24.80 93.36 2083.91 946.91 1304.83 521.43 1405.16 21.78 0.25 MWD GMAG 32 2827.79 60.36 21. 64 94.56 2130.40 1000.84 1380.49 553.90 1487.46 21. 86 2.94 MWD GMAG 33 2922.12 59.90 21. 49 94.33 2177.38 1056.20 1456.56 583.96 1569.26 21.85 0.51 MWD GMAG 34 3016.60 59.79 21.10 94.48 2224.84 1111.76 1532.68 613 . 63 1650.95 21.82 0.38 MWD GMAG 35 3109.90 60.32 21. 69 93.30 2271.41 1166.64 1607.95 643.12 1731. 79 21.80 0.79 MWD GMAG 36 3202.72 60.98 20.88 92.82 2316.91 1221. 68 1683.33 672 .49 1812.69 21.78 1. 04 MWD GMAG e 37 3296.64 60.87 21. 35 93.92 2362.55 1277.70 1759.91 702.06 1894.77 21.75 0.45 MWD GMAG 38 3389.27 60.94 21.25 92.63 2407.59 1332.74 1835.32 731. 46 1975.71 21.73 0.12 MWD GMAG 39 3483.60 60.19 22.40 94.33 2453.95 1388.06 1911 . 58 762.00 2057.86 21.73 1.33 MWD GMAG 40 3578.88 59.55 23.93 95.28 2501.78 1442.11 1987.34 794.41 2140.24 21.79 1.54 MWD GMAG 41 3675.27 58.85 24.27 96 .39 2551.14 1495.38 2062.92 828.22 2222.97 21. 87 0.79 MWD GMAG 42 3768.47 58.76 23.95 93.20 2599.41 1546.67 2135.69 860.79 2302.64 21.95 0.31 MWD GMAG 43 3822.64 58.68 24.44 54.17 2627.54 1576.40 2177.92 879.76 2348.90 22.00 0.79 MWD GMAG 44 3968.57 56.45 24.32 145.93 2705.80 1655.19 2290.09 930.60 2471.95 22.11 1. 53 MWD GMAG 45 4061.82 57.86 25.00 93.25 2756.37 1705.00 2361. 29 963.29 2550.22 22.19 1. 63 MWD GMAG 46 4156.78 57.90 25.01 94.96 2806.86 1755.77 2434.18 997.29 2630.55 22.28 0.04 MWD GMAG 47 4251.19 58.19 23.32 94.41 2856.83 1807.25 2507.26 1030.07 2710.61 22.33 1. 55 MWD GMAG 48 4346.29 59.22 23.64 95.10 2906.23 1860.20 2581. 79 1062.45 2791.85 22.37 1.12 MWD GMAG 49 4441.75 58.59 23.64 95.46 2955.53 1913 .30 2656.67 1095.23 2873.58 22.40 0.66 MWD GMAG 50 4534.67 59.74 24.66 92.92 3003.16 1964.58 2729.47 1127.87 2953.32 22.45 1.56 MWD GMAG 51 4627.48 60.80 24.14 92.81 3049.19 2016.12 2802.87 1161.17 3033.87 22.50 1.24 MWD GMAG e 52 4722.40 60.28 24.94 94.92 3095.87 2068.81 2878.05 1195.49 3116.46 22.56 0.92 MWD GMAG 53 4816.87 60.38 23.69 94.47 3142.63 2121.39 2952.85 1229.29 3198.51 22.60 1.15 MWD GMAG 54 4912.5S 59.31 22.34 95.68 3190.70 2175.81 3028.99 1261.64 3281.23 22.61 1.65 MWD GMAG 55 5008.50 57.77 18.47 95.95 3240.79 2232.36 3105.67 1290.18 3362.99 22.56 3.80 MWD GMAG 56 5104.61 58.34 13.86 96.11 3291.66 2292.94 3183.96 1312.87 3444.02 22.41 4.11 MWD GMAG 57 5199.90 57.64 9.39 95.29 3342.19 2357.03 3263.07 1329.16 3523.40 22.16 4.04 MWD GMAG 58 5293.31 58.75 4.11 93.41 3391. 44 2423.88 3341.87 1338.46 3599.94 21.83 4.95 MWD GMAG 59 5382.64 57.50 359.13 89.33 3438.63 2491.14 3417.66 1340.63 3671.19 21. 42 4.94 MWD GMAG 60 5473.11 55.55 354.17 90.47 3488.55 2560.81 3492.95 1336.26 3739.82 20.93 5.05 MWD GMAG SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 4 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5566.34 55.83 348.17 93.23 3541.14 2634.39 3568.99 1324.44 3806.81 20.36 5.32 MWD GMAG 62 5662.13 56.12 342.91 95.79 3594.76 2712.18 3645.82 1304.62 3872.21 19.69 4.56 MWD GMAG 63 5755.61 57.00 338.21 93.48 3646.30 2789.66 3719.34 1278.65 3932.99 18.97 4.30 MWD GMAG 64 5849.72 58.43 334.27 94.11 3696.58 2869.14 3792 .12 1246.59 3991.76 18.20 3.85 MWD GMAG 65 5944.69 59.72 330.25 94.97 3745.40 2950.54 3864.19 1208.66 4048.81 17.37 3.88 MWD GMAG 66 6038.46 59.78 326.28 93.77 3792.65 3031.09 3933.06 1166.07 4102.28 16.51 3.66 MWD GMAG e 67 6131. 99 59.64 323.53 93.53 3839.83 3110.79 3999.14 1119.64 4152.91 15.64 2.54 MWD GMAG 68 6228.13 60.43 319.19 96 .14 3887.87 3191.98 4064.16 1067.65 4202.05 14.72 4.00 MWD GMAG 69 6322.08 61.20 315.37 93.95 3933.69 3270.45 4124.40 1012.01 4246.74 13.79 3.64 MWD GMAG 70 6413 .76 62.81 311. 82 91. 68 3976.74 3346.22 4180.19 953.38 4287.53 12.85 3.84 MWD GMAG 71 6508.94 66.45 309.17 95.18 4017.52 3424.96 4236.00 887.98 4328.07 11.84 4.58 MWD GMAG 72 6602.27 69.53 308.73 93.33 4052.49 3503.24 4290.38 820.70 4368.17 10.83 3.33 MWD GMAG 73 6696 . 22 68.09 309.19 93.95 4086.45 3582.51 4345.46 752.58 4410.15 9.83 1.60 MWD GMAG 74 6788.62 68.74 308.14 92 .40 4120.44 3660.06 4399.14 685.49 4452.23 8.86 1.27 MWD GMAG 75 6882.92 68.49 308.62 94.30 4154.83 3739.14 4453.65 616.66 4496.14 7.88 0.54 MWD GMAG 76 6977.12 69.35 308.67 94.20 4188.71 3818.47 4508.54 548.01 4541.73 6.93 0.91 MWD GMAG 77 7071.71 70.05 309.02 94.59 4221. 52 3898.67 4564.19 478.92 4589.25 5.99 0.82 MWD GMAG 78 7165.20 67.88 310.68 93.49 4255.08 3978.19 4620.09 411.93 4638.42 5.10 2.85 MWD GMAG 79 7259.49 65.27 310.23 94.29 4292.56 4057.41 4676.23 346.10 4689.02 4.23 2.80 MWD GMAG 80 7320.00 64.65 309.40 60.51 4318.17 4107.36 4711.33 303.99 4721.13 3.69 1. 61 MWD GMAG 81 7332.00 66.51 308.85 12.00 4323.13 4117.26 4718.22 295.52 4727.47 3.58 16.05 MWD INC+TREND e 82 7371.20 69.89 309.33 39.20 4337.69 4150.23 4741.17 267.27 4748.70 3.23 8.70 MWD INC+TREND 83 7402.03 73.08 309.68 30.83 4347.48 4176.79 4759.77 244.72 4766.05 2.94 10.40 MWD INC+TREND 84 7432.12 77.49 310.02 30.09 4355.12 4203.31 4778.41 222.38 4783.58 2.66 14.70 MWD INC+TREND 85 7462.87 81.88 310.58 30.75 4360.62 4230.98 4797.97 199.32 4802.11 2.38 14.39 MWD INC+TREND 86 7493.82 86.60 310.69 30.95 4363.73 4259.20 4818.02 175.95 4821. 23 2.09 15.25 MWD INC+TREND 87 7523.99 90.46 311.01 30.17 4364.50 4286.90 4837.75 153.14 4840.17 1. 81 12.84 MWD GMAG 88 7554.91 94.65 309.22 30.92 4363.13 4315.10 4857.64 129.53 4859.37 1. 53 14.73 MWD GMAG 89 7585.49 97.48 309.82 30.58 4359.90 4342.74 4876.99 106.07 4878.15 1.25 9.46 MWD GMAG 90 7617.62 97.86 309.78 32.13 4355.61 4371.75 4897.38 81. 61 4898.05 0.95 1.19 MWD GMAG SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 5 of 10 -------- ------ ------- ------ -----......-...... -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Carr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- -----...... ------- ------ -------- -------- ---------------- --------------- ------ -------- -......_--- ------- ------ -------- -------...... ---------------- --------------- ------ 91 7648.31 96 .61 311.37 30.69 4351.74 4399.66 4917.18 58.49 4917.53 0.68 6.56 MWD GMAG 92 7678.57 93.31 309.96 30.26 4349.13 4427.30 4936.82 35.62 4936.95 0.41 11.85 MWD GMAG 93 7708.83 90.91 305.92 30.26 4348.01 4454.42 4955.40 11.78 4955.42 0.14 15.52 MWD GMAG 94 7739.84 90.98 305.84 31.01 4347.50 4481.73 4973.58 -13.34 4973.59 359.85 0.34 MWD GMAG 95 7770.53 91. 36 306.62 30.69 4346.87 4508.84 4991. 71 -38.09 4991.86 359.56 2.83 MWD GMAG 96 7800.45 90.46 304.35 29.92 4346.40 4535.09 5009.08 -62.45 5009.47 359.29 8.16 MWD GMAG e 97 7830.26 91. 47 303.59 29.81 4345.90 4560.85 5025.73 -87.17 5026.49 359.01 4.24 MWD INC+TREND 98 7860.46 91. 53 302.82 30.20 4345.11 4586.75 5042.26 -112.43 5043.52 358.72 2.56 MWD GMAG 99 7890.49 91. 34 299.03 30.03 4344.35 4611.85 5057.69 -138.18 5059.58 358.44 12.63 MWD INC+TREND 100 7920.25 91.18 295.27 29.76 4343.70 4635.61 5071.26 -164.65 5073.93 358.14 12.64 MWD GMAG 101 7950.58 91. 20 299.77 30.33 4343.07 4659.94 5085.27 -191.53 5088.88 357.84 14.83 MWD INC+TREND 102 7980.04 90.67 304.15 29.46 4342.59 4684.86 5100.86 -216.52 5105.45 357.57 14.97 MWD GMAG 103 8010.38 90.40 308.04 30.34 4342.30 4711.63 5118.73 -241. 03 5124.40 357.30 12.85 MWD GMAG 104 8039.99 91.01 302.29 29.61 4341.94 4737.52 5135.77 -265.22 5142.62 357.04 19.53 MWD GMAG 105 8069.79 92.76 302.77 29.80 4340.96 4762.88 5151.79 -290.33 5159.96 356.77 6.09 MWD GMAG 106 8099.13 93.18 303.88 29.34 4339.44 4788.04 5167.88 -314.81 5177.46 356.51 4.04 MWD GMAG 107 8128.90 91. 22 307.43 29.77 4338.30 4814.18 5185.22 -338.98 5196.29 356.26 13 .61 MWD GMAG 108 8159.25 89.88 303.51 30.35 4338.00 4840.80 5202.83 -363.69 5215.52 356.00 13.65 MWD GMAG 109 8188.56 89.88 304.38 29.31 4338.07 4866.13 5219.19 -388.01 5233.60 355.75 2.97 MWD GMAG 110 8218.95 90.57 306.43 30.39 4337.95 4892.77 5236.80 -412.77 5253.04 355.49 7.12 MWD GMAG 111 8248.88 90.77 305.45 29.93 4337.60 4919.15 5254.37 -437.00 5272.51 355.25 3.34 MWD GMAG e 112 8279.35 91.05 304.42 30.47 4337.11 4945.74 5271.81 -461. 98 5292.02 354.99 3.50 MWD GMAG 113 8308.34 94.55 304.24 28.99 4335.70 4970.85 5288.14 -485.89 5310.41 354.75 12.09 MWD GMAG 114 8338.12 95.16 305.43 29.78 4333.18 4996.73 5305.09 -510.24 5329.57 354.51 4.48 MWD GMAG 115 8367.70 95.65 304 . 77 29.58 4330.39 5022.47 5322.02 -534.34 5348.78 354.27 2.77 MWD GMAG 116 8398.40 95.17 304.62 30.70 4327.50 5049.08 5339.42 -559.47 5368.65 354.02 1.64 MWD GMAG 117 8428.68 93.52 303.94 30.28 4325.20 5075.26 5356.42 -584.41 5388.21 353.77 5.89 MWD GMAG 118 8458.87 92.90 302.47 30.19 4323.51 5101.12 5372.93 -609.63 5407.40 353.53 5.28 MWD GMAG 119 8489.11 92.28 301. 43 30.24 4322.15 5126.68 5388.92 -635.27 5426.23 353.28 4.00 MWD GMAG 120 8520.53 92.32 300.62 31.42 4320.88 5152.97 5405.10 -662.17 5445.51 353.02 2.58 MWD GMAG SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 6 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 8550.79 91. 01 298.49 30.26 4320.00 5177.87 5420.01 -688.48 5463.57 352.76 8.26 MWD GMAG 122 8582.16 91.11 298.34 31.37 4319.42 5203.33 5434.94 -716.06 5481.91 352.49 0.57 MWD GMAG 123 8613.85 91.77 298.18 31.69 4318.63 5228.99 5449.94 -743.97 5500.48 352.23 2.14 MWD GMAG 124 8645.15 91.15 299.90 31.30 4317.83 5254.59 5465.13 -771.32 5519.29 351. 97 5.84 MWD GMAG 125 8676.13 91. 66 300.04 30.98 4317.07 5280.21 5480.60 -798.15 5538.41 351. 71 1. 71 MWD GMAG 126 8706.67 93.10 302.14 30.54 4315.80 5305.78 5496.35 -824.28 5557.82 351.47 8.33 MWD GMAG e 127 8737.92 92.80 306.00 31. 25 4314.19 5332.78 5513 .83 -850.13 5578.99 351. 24 12.37 MWD GMAG 128 8770.05 92.80 307.75 32.13 4312.62 5361.30 5533.09 -875.80 5601.97 351.01 5.44 MWD GMAG 129 8801.17 92.94 307.87 31. 12 4311.07 5389.16 5552.14 -900.35 5624.67 350.79 0.59 MWD GMAG 130 8832.43 91.87 306.40 31. 26 4309.75 5416.98 5571.00 -925.25 5647.31 350.57 5.81 MWD GMAG 131 8863.00 90.81 304.36 30.57 4309.04 5443.77 5588.69 -950.17 5668.89 350.35 7.52 MWD GMAG 132 8894.17 90.57 303.69 31.17 4308.66 5470.73 5606.13 -976.00 5690.46 350.12 2.28 MWD GMAG 133 8924.79 90.36 303.63 30.62 4308.41 5497.11 5623.10 -1001.48 5711.59 349.90 0.71 MWD GMAG 134 8956.09 90.19 304.97 31. 30 4308.26 5524.26 5640.74 -1027.34 5733.53 349.68 4.32 MWD GMAG 135 8986.95 91.39 304.21 30.86 4307.84 5551.10 5658.26 -1052.74 5755.36 349.46 4.60 MWD GMAG 136 9018.13 91.97 306.22 31.18 4306.92 5578.37 5676.23 -1078.20 5777.72 349.24 6.71 MWD GMAG 137 9047.34 91.70 306.21 29.21 4305.99 5604.16 5693.48 -1101.76 5799.10 349.05 0.92 MWD GMAG 138 9078.38 91.56 305.53 31.04 4305.11 5631. 49 5711.66 -1126.90 5821.76 348.84 2.24 MWD GMAG 139 9109.71 90.74 306.74 31. 33 4304.48 5659.14 5730.13 -1152.20 5844.82 348.63 4.66 MWD GMAG 140 9140.57 89.64 305.36 30.86 4304.38 5686.36 5748.29 -1177.15 5867.58 348.43 5.72 MWD GMAG 141 9171. 52 89.61 306.39 30.95 4304.58 5713.62 5766.43 -1202.23 5890.42 348.22 3.33 MWD GMAG - 142 9202.56 89.02 305.61 31.04 4304.95 5740.98 5784.67 -1227.34 5913.44 348.02 3.15 MWD GMAG 143 9233.34 88.65 304.69 30.78 4305.57 5767.90 5802.39 -1252.50 5936.03 347.82 3.22 MWD GMAG 144 9264.47 88.54 305.34 31.13 4306.34 5795.08 5820.24 -1277.98 5958.90 347.62 2.12 MWD GMAG 145 9295.76 88.20 305.97 31. 29 4307.23 5822.57 5838.47 -1303.40 5982.19 347.42 2.29 MWD GMAG 146 9326.51 89.71 306.09 30.75 4307.79 5849.68 5856.56 -1328.26 6005.29 347.22 4.93 MWD GMAG 147 9357.53 92.90 307.08 31. 02 4307.08 5877.17 5875.04 -1353.16 6028.86 347.03 10.77 MWD GMAG 148 9388.47 92.87 307.11 30.94 4305.53 5904.69 5893.68 -1377.81 6052.58 346.84 0.14 MWD GMAG 149 9419.45 92.42 307.87 30.98 4304.10 5932.35 5912.51 -1402.36 6076.54 346.66 2.85 MWD GMAG 150 9450.59 92.08 307.17 31.14 4302.87 5960.16 5931. 46 -1427.04 6100.71 346.47 2.50 MWD GMAG SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 7 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 9481. 84 91.90 306.42 31. 25 4301.79 5987.90 5950.17 -1452.05 6124.78 346.29 2.47 MWD GMAG 152 9513.46 90.22 306.73 31.62 4301.20 6015.93 5969.00 -1477.44 6149.13 346.10 5.40 MWD GMAG 153 9544.61 89.81 307.08 31.15 4301.19 6043.62 5987.71 -1502.35 6173.31 345.92 1. 73 MWD GMAG 154 9575.70 89.50 307.31 31.09 4301. 38 6071.33 6006.50 -1527.11 6197.59 345.74 1.24 MWD GMAG 155 9607.00 90.02 305.37 31. 30 4301.51 6099.01 6025.05 -1552.32 6221.81 345.55 6.42 MWD GMAG 156 9638.50 91.77 305.26 31. 50 4301.02 6126.60 6043.26 -1578.02 6245.89 345.37 5.57 MWD GMAG e 157 9669.14 91. 46 305.59 30.64 4300.16 6153.46 6061.01 -1602.98 6269.40 345.19 1.48 MWD GMAG 158 9700.47 91.05 305.69 31. 33 4299.47 6180.99 6079.26 -1628.44 6293.59 345.00 1. 35 MWD GMAG 159 9731.14 90.50 305.59 30.67 4299.06 6207.94 6097.13 -1653.36 6317.33 344.83 1.82 MWD GMAG 160 9762.33 91. 42 305.39 31.19 4298.53 6235.30 6115.24 -1678.75 6341. 48 344.65 3.02 MWD GMAG 161 9792.96 91.87 305.30 30.63 4297.65 6262.13 6132.95 -1703.73 6365.20 344.47 1.50 MWD GMAG 162 9824.51 91.42 306.57 31.55 4296.75 6289.92 6151.46 -1729.26 6389.89 344.30 4.27 MWD GMAG 163 9855.94 90.94 305.59 31. 43 4296 .10 6317.64 6169.96 -1754.66 6414.61 344.13 3.47 MWD GMAG 164 9887.40 90.46 305.17 31. 46 4295.72 6345.22 6188.18 -1780.30 6439.18 343.95 2.03 MWD GMAG 165 9917.90 90.84 304.57 30.50 4295.37 6371.82 6205.61 -1805.33 6462.88 343.78 2.33 MWD GMAG 166 9949.01 91.15 302.81 31.11 4294.83 6398.63 6222.86 -1831.21 6486.71 343.60 5.74 MWD GMAG 167 9980.12 91. 46 303.48 31.11 4294.12 6425.29 6239.87 -1857.25 6510.40 343.42 2.37 MWD GMAG 168 10011.46 91. 29 304.90 31.34 4293.37 6452.43 6257.48 -1883.16 6534.70 343.25 4.56 MWD GMAG 169 10042.48 91.15 304.88 31. 02 4292.71 6479.49 6275.21 -1908.60 6559.05 343.08 0.46 MWD GMAG 170 10071.23 90.94 305.74 28.75 4292.19 6504.67 6291.83 -1932.06 6581.79 342.93 3.08 MWD GMAG 171 10104.50 91.05 305.84 33.27 4291. 61 6533.94 6311.28 -1959.04 6608.34 342.76 0.45 MWD GMAG e 172 10135.13 89.33 309.15 30.63 4291. 51 6561.31 6329.92 -1983.34 6633.37 342.60 12.18 MWD GMAG 173 10167.01 86.49 308.66 31. 88 4292.67 6590.12 6349.93 -2008.13 6659.89 342.45 9.04 MWD GMAG 174 10198.00 85.66 309.00 30.99 4294.79 6618.07 6369.32 -2032.21 6685.66 342.30 2.89 MWD GMAG 175 10229.64 85.63 310.05 31.64 4297.19 6646.75 6389.39 -2056.55 6712.21 342.16 3.31 MWD GMAG 176 10260.63 85.14 309.81 30.99 4299.69 6674.92 6409.22 -2080.23 6738.36 342.02 1. 76 MWD GMAG 177 10291. 87 85.08 309.69 31. 24 4302.35 6703.27 6429.12 -2104.17 6764.70 341.88 0.43 MWD GMAG 178 10321.81 85.55 310.77 29.94 4304.79 6730.54 6448.40 -2126.95 6790.12 341.75 3.92 MWD GMAG 179 10354.26 86.71 309.58 32.45 4306.98 6760.12 6469.28 -2151.68 6817 . 72 341.60 5.12 MWD GMAG 180 10385.57 87.84 308.44 31.31 4308.47 6788.44 6488.97 -2175.99 6844.09 341.46 5.12 MWD GMAG SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 8 of 10 ---.....---- ------ ------- ------ -----.....-- -------- ---------------- --------------..... ------ -------- ------ ---....._-- ------ ---....._--- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ---.....-- .....------ ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 181 10416.48 90.77 307.32 30.91 4308.85 6816.15 6507.94 -2200.38 6869.86 341.32 10.15 MWD GMAG 182 10447.79 94.41 306.72 31. 31 4307.43 6843.98 6526.77 -2225.35 6895.72 341.17 11.78 MWD GMAG 183 10478.58 94.82 307.63 30.79 4304.96 6871.33 6545.31 -2249.80 6921.18 341. 03 3.23 MWD GMAG 184 10510.02 92.28 306.79 31.44 4303.01 6899.30 6564.29 -2274.79 6947.27 340.89 8.51 MWD GMAG 185 10541.13 91. 39 305.21 31.11 4302.01 6926.72 6582.56 -2299.94 6972.80 340.74 5.83 MWD GMAG 186 10571.94 91.83 307.14 30.81 4301.15 6953.92 6600.74 -2324.80 6998.18 340.60 6.42 MWD GMAG e 187 10602.97 92.56 308.54 31.03 4299.96 6981.71 6619.76 -2349.29 7024.27 340.46 5.09 MWD GMAG 188 10633.91 92.25 310.01 30.94 4298.66 7009.75 6639.33 -2373.22 7050.74 340.33 4.85 MWD GMAG 189 10665.36 91.22 309.39 31.45 4297.71 7038.37 6659.41 -2397.41 7077.80 340.20 3.82 MWD GMAG 190 10696.46 91. 77 309.82 31.10 4296.90 7066.65 6679.23 -2421.36 7104.58 340.07 2.24 MWD GMAG 191 10728.54 93.62 311.24 32.08 4295.39 7096.01 6700.05 -2445.71 7132.48 339.95 7.27 MWD GMAG 192 10758.78 93.49 308.07 30.24 4293.51 7123.47 6719.31 -2468.95 7158.55 339.82 10.47 MWD GMAG 193 10789.80 94.03 307.64 31. 02 4291. 48 7151. 22 6738.31 -2493.39 7184.83 339.69 2.22 MWD GMAG 194 10821.50 93.76 308.58 31.70 4289.33 7179.64 6757.83 -2518.27 7211. 79 339.56 3.08 MWD GMAG 195 10852.95 93.79 309.13 31. 45 4287.26 7208.01 6777.51 -2542.71 7238.79 339.44 1. 75 MWD GMAG 196 10884.40 93.00 309.48 31. 45 4285.39 7236.50 6797.40 -2567.00 7265.96 339.31 2.75 MWD GMAG 197 10916.05 92.90 309.30 31. 65 4283.76 7265.20 6817.46 -2591.43 7293.37 339.19 0.65 MWD GMAG 198 10947.61 92.69 310.19 31.56 4282.23 7293.91 6837.61 -2615.67 7320.84 339.07 2.89 MWD GMAG 199 10978.37 93.31 310.04 30.76 4280.62 7321. 96 6857.40 -2639.16 7347.73 338.95 2.07 MWD GMAG 200 11008.69 93.79 310.64 30.32 4278.74 7349.65 6876.99 -2662.22 7374.31 338.84 2.53 MWD GMAG 201 11039.69 93.38 310.59 31. 00 4276.80 7378.01 6897.13 -2685.71 7401.59 338.72 1.33 MWD GMAG e 202 11070.84 93.93 310.99 31.15 4274.81 7406.55 6917.44 -2709.25 7429.07 338.61 2.18 MWD GMAG 203 11102.17 94.79 312.78 31. 33 4272.43 7435.46 6938.30 -2732.50 7456.98 338.50 6.32 MWD GMAG 204 11133.19 93.79 312.00 31. 02 4270.11 7464.19 6959.15 -2755.35 7484.77 338.40 4.08 MWD GMAG 205 11164.52 94.58 310.58 31. 33 4267.82 7492.98 6979.77 -2778.82 7512.59 338.29 5.18 MWD GMAG 206 11194.95 95.48 309.05 30.43 4265.16 7520.60 6999.18 -2802.11 7539.25 338.18 5.82 MWD GMAG 207 11226.81 94.72 308.59 31. 86 4262.32 7549.28 7019.07 -2826.83 7566.92 338.06 2.79 MWD GMAG 208 11257.90 94.79 308.30 31.09 4259.75 7577.20 7038.34 -2851.10 7593.88 337.95 0.96 MWD GMAG 209 11288.24 94.55 308.07 30.34 4257.28 7604.38 7057.03 -2874.87 7620.14 337.84 1. 09 MWD GMAG 210 11319.41 92.69 306.44 31.17 4255.31 7632.13 7075.86 -2899.63 7646.94 337.72 7.93 MWD GMAG 4 . SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 9 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 211 11350.50 92.32 306.22 31.09 4253.95 7659.59 7094.26 -2924.65 7673.47 337.60 1. 38 MWD GMAG 212 11381.25 92.31 305.61 30.75 4252.71 7686.66 7112.28 -2949.53 7699.63 337.48 1. 98 MWD GMAG 213 11412.55 92.21 306.50 31. 30 4251.47 7714.25 7130.69 -2974.82 7726.34 337.35 2.86 MWD GMAG 214 11444.35 92.14 306.34 31. 80 4250.27 7742.38 7149.56 -3000.39 7753.61 337.23 0.55 MWD GMAG 215 11475.27 91.97 306.12 30.92 4249.16 7769.68 7167.82 -3025.31 7780.11 337.12 0.90 MWD GMAG 216 11505.85 91.84 305.50 30.58 4248.14 7796.58 7185.70 -3050.10 7806.24 337.00 2.07 MWD GMAG e 217 11538.03 91. 63 305.75 32.18 4247.17 7824.84 7204.44 -3076.24 7833.72 336.88 1. 01 MWD GMAG 218 11568.73 91. 66 306.37 30.70 4246.29 7851.92 7222.50 -3101.05 7860.09 336.76 2.02 MWD GMAG 219 11599.98 91. 22 306.39 31. 25 4245.50 7879.56 7241. 03 -3126.20 7887.06 336.65 1.41 MWD GMAG 220 11631. 37 90.33 307.23 31. 39 4245.08 7907.44 7259.84 -3151.33 7914.30 336.54 3.90 MWD GMAG 221 11662.22 91. 29 307.68 30.85 4244.64 7935.00 7278.60 -3175.82 7941.27 336.43 3.44 MWD GMAG 222 11693.42 91. 70 308.41 31. 20 4243.83 7963.01 7297.82 -3200.38 7968.72 336.32 2.68 MWD GMAG 223 11724.57 91.53 308.86 31.15 4242.95 7991.11 7317.26 -3224.70 7996.31 336.22 1. 54 MWD GMAG 224 11755.10 91.05 308.76 30.53 4242.26 8018.69 7336.39 -3248.49 8023.42 336.12 1.61 MWD GMAG 225 11786.23 90.43 308.71 31.13 4241. 86 8046.81 7355.86 -3272.77 8051.07 336.01 2.00 MWD GMAG 226 11817.25 90.57 309.21 31. 02 4241.59 8074.88 7375.37 -3296.89 8078.71 335.91 1. 67 MWD GMAG 227 11849.05 91.70 310.90 31. 80 4240.96 8103.90 7395.83 -3321. 22 8107.33 335.82 6.39 MWD GMAG 228 11880.17 91. 46 311. 07 31. 12 4240.10 8132.50 7416.23 -3344.70 8135.57 335.72 0.94 MWD GMAG 229 11911.13 92.18 310.16 30.96 4239.12 8160.87 7436.37 -3368.19 8163.60 335.63 3.75 MWD GMAG 230 11942.07 92.25 311.18 30.94 4237.92 8189.22 7456.52 -3391.64 8191.64 335.54 3.30 MWD GMAG 231 11972.63 91.63 309.84 30.56 4236.89 8217.20 7476_36 -3414.86 8219.32 335.45 4.83 MWD GMAG e 232 12003.05 92.63 309.49 30.42 4235.76 8244.87 7495.76 -3438.26 8246.70 335.36 3.48 MWD GMAG 233 12035.52 93.52 309.67 32.47 4234.01 8274.35 7516.42 -3463.25 8275.91 335.26 2.80 MWD GMAG 234 12065.61 93.28 310.28 30.09 4232.23 8301.76 7535.72 -3486.27 8303.08 335.17 2.18 MWD GMAG 235 12096.89 92.80 309.78 31. 28 4230.57 8330.26 7555.81 -3510.19 8331.37 335.08 2.21 MWD GMAG 236 12127.83 92.18 309.24 30.94 4229.23 8358.36 7575.48 -3534.04 8359.26 334.99 2.66 MWD GMAG 237 12158.81 91. 42 309.46 30.98 4228.25 8386.47 7595.11 -3557.98 8387.19 334.90 2.55 MWD GMAG 238 12190.10 91. 49 309.86 31. 29 4227.46 8414.94 7615.07 -3582.06 8415.49 334.81 1.30 MWD GMAG 239 12221. 50 91. 25 311. 06 31. 40 4226.71 8443.68 7635.44 -3605.95 8444.10 334.72 3.90 MWD GMAG 240 12252.57 90.50 310.62 31. 07 4226.23 8472.21 7655.76 -3629.45 8472.52 334.64 2.80 MWD GMAG · . SCHLUMBERGER Survey Report 17-Feb-2004 14:53:29 Page 10 of 10 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 241 12284.03 89.81 310.09 31. 46 4226.15 8501.00 7676.13 -3653.42 8501. 20 334.55 2.77 MWD GMAG 242 12314.63 89.47 310.60 30.60 4226.34 8528.99 7695.94 -3676.74 8529.12 334.46 2.00 MWD GMAG 243 12346.11 90.02 311. 26 31. 48 4226.48 8557.92 7716.56 -3700.53 8557.99 334.38 2.73 MWD GMAG 244 12376.90 91. 05 311 . 62 30.79 4226.19 8586.32 7736.94 -3723.61 8586.35 334.30 3.54 MWD GMAG 245 12408.00 91. 05 311.87 31.10 4225.62 8615.07 7757.64 -3746.81 8615.08 334.22 0.80 MWD GMAG 246 12438.44 90.77 311.35 30.44 4225.14 8643.18 7777.85 -3769.56 8643.18 334.14 1. 94 MWD GMAG e 247 12470.64 89.02 311. 84 32.20 4225.20 8672.92 7799.23 -3793.64 8672.93 334.06 5.64 MWD GMAG 248 12500.67 89.13 311. 98 30.03 4225.68 8700.71 7819.28 -3815.99 8700.75 333.99 0.59 MWD GMAG 249 12531.76 91.97 313.24 31.09 4225.39 8729.63 7840.33 -3838.87 8729.70 333.91 9.99 MWD GMAG 250 12562.33 92.39 314.42 30.57 4224.22 8758.27 7861. 48 -3860.90 8758.40 333.84 4.09 MWD GMAG 251 12594.76 91.73 313.75 32.43 4223.06 8788.71 7884.03 -3884.18 8788.90 333.77 2.90 MWD GMAG 252 12625.58 91.90 311. 92 30.82 4222.08 8817.41 7904.97 -3906.77 8817.68 333.70 5.96 MWD GMAG 253 12657.06 93.04 312.27 31. 48 4220.72 8846.56 7926.06 -3930.11 8846.93 333.63 3.79 MWD GMAG 254 12688.67 93.14 312.23 31.61 4219.02 8875.84 7947.28 -3953.47 8876.33 333.55 0.34 MWD GMAG 255 12719.15 93.11 312.14 30.48 4217.36 8904.07 7967.72 -3976.02 8904.68 333.48 0.31 MWD GMAG 256 12750.74 92.70 312.24 31. 59 4215.76 8933.33 7988.91 -3999.40 8934.08 333.41 1.34 MWD GMAG 257 12782.92 93.07 312.67 32.18 4214.14 8963.19 8010.60 -4023.11 8964.10 333.33 1. 76 MWD GMAG 258 12813 .72 90.84 313.37 30.80 4213.09 8991.90 8031.60 -4045.62 8992.97 333.27 7.59 MWD GMAG 259 12844.97 87.76 313.89 31. 25 4213.47 9021.16 8053.16 -4068.23 9022.41 333.20 10.00 MWD GMAG 260 12876.23 86.14 314.99 31. 26 4215.13 9050.55 8075.01 -4090.52 9051.97 333.13 6.26 MWD GMAG 261 12907.00 86.21 314.30 30.77 4217.19 9079.49 8096.59 -4112.36 9081.09 333.07 2.25 MWD GMAG e 262 12938.15 85.59 314.52 31.15 4219.41 9108.73 8118.33 -4134.56 9110.53 333.01 2.11 MWD GMAG 263 12969.55 85.11 314.39 31. 40 4221.96 9138.20 8140.25 -4156.89 9140.21 332.95 1.58 MWD GMAG 264 13001.13 84.45 314.43 31. 58 4224.83 9167.80 8162.25 -4179.36 9170.03 332.89 2.09 MWD GMAG 265 13032.47 84.29 314.79 31. 34 4227.91 9197.19 8184.16 -4201.56 9199.65 332.83 1.25 MWD GMAG 266 13062.96 85.76 314.91 30.49 4230.55 9225.86 8205.58 -4223.10 9228.55 332.77 4.84 MWD GMAG 267 13115.00 85.76 314.91 52.04 4234.40 9274.86 8242.22 -4259.85 9277.96 332.67 0.00 Projected to TD [(c)2004 IDEAL ID8_1C_02J Ie @ fÆ~fÆ - I I FRANK H. MURKOWSKI. GOVERNOR / í 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L-200L2 BP Exploration (Alaska), Inc. Permit No: 204-003 Surface Location: 2567' NSL, 3705' WEL, Sec. 34, T12N, RIlE, UM Bottomhole Location: 334' NSL, 2444' WEL, Sec. 21, T12N, RllE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well PBU L-200, Permit No 204-001, API 50-029-123191. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sarah Palin Chair BY ORDER OF THE COMMISSION DATED thistJ day of January, 2004. cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. Alaska Oil & Ga!t r.nnJ: ,., 1a. Type of work II Drill o Redrill 11 b. Current Well Class o Exploratory II Development ~gc~~~Ple Zone ORe-Entry o Stratigraphic Test o Service o Development Ie Zone 2. Operator Name: 5. Bond: !HI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU L-200L2 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 13011 TVD 4223 Prudhoe Bay Field / Polaris Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 047447 2567' NSL, 3705'WEL, SEC. 34, T12N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 2198' NSL, 3591' WEL, SEC. 27, T12N, R11E, UM January 15, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 334' NSL, 2444' WEL, SEC. 21, T12N, R11E, UM 2560 4550' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool Surface: X-583209 y-5978290 Zone-ASP4 (Height above GL): = 72.6 feet L-117 is 1420' away 16. Deviated Wells: 17. Anticipated pressure (see 20 MC 25.035) Kickoff Depth 7215ft Maximum Hole Angle 97° Max. Downhole Pressure: 1970 psig. Max. Surface Pressure: 1530 psig 18; Casing Program Specifications Setting Depth \:fu(~ntlty of Cement Size TOD Bottom c.f. or sacks) Hole Casino Weiaht Grade CouDlina Lenath MD TVD MD TVD (includina staae data) 6-3/4" 4-1/2" 12.6# L-80 IBT -~ 7163' 4243' 13011 ' 4213' Uncemented Slotted Liner <;ðo.f¡J; i<JG1\- :19. P~ESENTWE;LL CONDITIQN$OMM~R'((,.ºbe.C()mplet~º{or RedrillANºRe..Øt\VY Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): 1 Effective Depth TVD (ft):1 Junk (measured): 13058 4423 None 13058 4423 None Casino I):;") ,) I.···!· )' ¡;; xc'.. l'I\IlL;J,)'): )).~D; Structural Conductor 80' 20" x 34" 260 sx Arctic Set (Approx.) 109' 109' " ..L. 3623' 10-3/4" 692 sx AS Lite, 361 sx Class 'G' 3652' 2573' Intp.r 7844' 7-5/8" 530 sx Class 'G' 7873' 4475' Production I inp.r 5588' 4-1/2" Uncemented Slotted Liner 7462' - 13050' 4352' - 4413' Liner 5668' 4-1/2" Uncemented Slotted Liner 7362' - 13030' 4319' - 4283' Perforation Depth MD (ft): Slotted Liner IPerfOration Depth TVD (ft): Slotted Liner 20. Attachments o Filing Fee o BOP Sketch !HI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report !HI Drilling Fluid Program !HI 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael Triolo, 564-5774 Printed Name Lo~1I Crane Title Senior Drilling Engineer SiQnature~~ ¡ê.¿~ ~7 Prepared By Name/Number: Phone 564- Date I 2- - ?/- (;, J Terrie Hubble, 564-4628 (/ Commission Use Only Permit To Dril~7' I API Number: I Permit Approval. S' 'L~ I See cover letter for Number: Ze> '003 50- 0 ~9 - 2, $ J CY / - 6/ Date: ì other requirements Conditions of Approval: Samples Required DYes ~No Mud Log Required I DYes ~No Hydrogen Sulfide Measures DYes 1:81' No Directional Survey Required ~Yes DNo Other:T est ~opE fa 'SÇo(!) r(·1 ( , Original Signed By Sarah Palin Ð4 BY ORDER OF \ ~ Approved Bv: COMMISSIONER THE COMMISSION Date ,7 Form 10-401 Revised 3/2003 S Jbm,t In Duplicate v.JGA 1/5/2-00'4 _ STATE OF ALASKA a RECEIVED ALASKA _ AND GAS CONSERVATION CO_SSION ' , . PERMIT TO DRILL DEC 3 1 2003 20 MC 25 005 OR(GI~~AI Well Plan Summarv Welil:/Name: IL-200;lL~200 L1 and'L-200iL2 e Greater Prudhoe Bay L-200 ML Permit e ..:..... I Type of Well (producer or injector): I Schrader OBd, OBa and OA Multilateral Producer Surface Location: 2,567' FSL, 3,705' FEL, Sec. 34, T12N, R11E (As-staked) X = 583,209.30 Y = 5,978,289.70 L-200 OBd Target Start: 2,632' FSL, 4,199' FEL, Sec. 27, T12N, R11E X = 582,645.35 Y = 5,983,628.29 Z = 4,415' TVDss L-200 OBd Target End: 313' FSL, 2,477' FEL, Sec. 21, T12N, R11E X = 579,050 Y = 5,986,550 Z = 4,350' TVDss L-200 L 1 OBa Target Start: 2,307' FSL, 3,755' FEL, Sec. 27, T12N, R11E X = 583,093.57 Y = 5,983,308.25 Z = 4,273' TVDss L-200 L 1 OBa Target End: 334' FSL, 2,444' FEL, Sec. 21, T12N, R11 E X = 579,083 Y = 5,986,571 Z = 4,211' TVDss L-200 L2 OA Target Start: 2,198' FSL, 3,591' FEL, Sec. 27, T12N, R11E X = 583,259.48 Y = 5,983,201.10 Z = 4,210' TVDss L-200 L2 OA Target End: 334' FSL, 2,444' FEL, Sec. 21, T12N, R11E X = 579,083 Y = 5,986,571 Z = 4,150' TVDss ~ AFE Number: I ORD5M3540 KBE = 72.60' I Rig: I Nabors 9ES ~ Estimated Start Date: I Jan. 1510 2004 I I Operating days to complete: 134.04 OBd MD 13,058' OBa MD 13,025' OAMD 13,011 ' Well TVDrkb: TD 4,423' Well TVDrkb: TD 4,284' Well TVDrkb: TD 4,223' Max Inc. 93° Max Inc. 98° Max Inc. 97° KOP 300' KOP 7,396' KOP 7,215' Target Estimates: Estimated Reserves OA I OBa IOBd: Expected Initial Rate OA I OBa IOBd: Expected 1 Year avg OA I OBa IOBd: Expected reserves 7.56 mmbbl Production rate: 3,900 bId Production rate: 1,800 bId Current Well Information Distance to Nearest Property: Distance to Nearest Well in Pool: Original Well API #: L-2oo L 1 API OBa #: L-200 L2 API OA #: Well Type: Current Status: H2S: BHP: BHT: 4,550' from top OA to PBU boundary (this is the closest point in the producing well section to any unit boundary) Top OA: 1,420' away from L-117 top OA TO: 3,010' away from NWEILEEN-1 (old exploration well- to be abandoned in February, 2004) 50-029-XXXXX-00 50-029-XXXXX-60 50-029-XXXXX-61 Schrader O-sand Trilateral Producer New well, 20" X 34" insulated conductor to be set o ppm from produced fluids (approximated to be around 10 ppm due to contaminated gas lift gas) OA: 1,870 psi @ 4,180' TVDss (8.60 ppg EMW). Based on L-117 MDT's OBa: 1,895 psi @ 4,250' TVDss (8.60 ppg EMW). Based on L-117 MDT's OBd: 1,970 psi @ 4,400' TVDss (8.60 ppg EMW). Based on L-117 MDT's 84 of @ 4,400' TVDss (Estimated) Final Permit 12/31/03 Mechanical Condition e Greater Prudhoe Bay L-200 ML Permit e Conductor: Cellar Box Height: Nabor 9ES: 20" X 34", 215.5Ib/ft,·A53 ERW set at 109' RKB Above MSL = 44.10' KB I MSL = 72.60' Materials Needed Surface Casina: Amount 4,010' 1 each 25 each 1 assembly 1 lot 1 each DescriDtion 10-3,.4",45.5#, L-80 BTC Casing (Burst: 5,210; Collapse: 2,470) 10-3,.4", BTC Float Shoe and Float Collar 10-3,.4" x 13- %" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 10-3,.4" casing pups 5',10',20'. 1 0-%" TAM Port Collar 1otermediáte:Casin .Amount;:!;~; , 7,600' 1 each 75 each 20 each 2 lots 3 each 2 each jPróductioIÌLine~:';;::!~!:'!!ki;'!:;',::Amoúnt '." 3 x Production Liners: 7,300' 183 each 3 each 3 each 2 assemblies :>;j:':,~¡!!;Des,cri tiôn 7-%" 29.7# L-80 BTC-M Casing (Burst: 6,890; Collapse: 4,790) 7-%" BTC-M Float Shoe and Float Collar 7-%" x 9-%" Rigid Straight Blade Centralizers 7-%" Stop Rings 7-%" casing pups 5',10',20' 7-%" RA Tag 7-%" 29.7# L-80 BTC-M Casin Short Joint ';, 'i'~'i;~¡,¡!;!';!!!'Descri" tion 4 W', 12.6#, L-80, IBT-Mod Slotted Liner 4 %" x 5 %" x 8" Straight Blade Centralizers 7-%" x 4-%" Baker ZXP Liner Top Packer 4-%" Halliburton Float Shoes Baker Level 3 Hookwall Han ers with LEM Completion: Amount 6,900' 1 each" 1 each 1 each 1 each 2 each 1 each 4 each 1 each 6900' 2 each 1 each Surface and Anti-Collision Issues . DescriDtion 4-W', 12.6 Ib/ft, L-80, BTC-M tubing Baker PRM Production Packer 7-%" X 4-W' 11" X 4-%" FMC tubing hanger 4-1/16", 5m Cameron Tree Halliburton XN-Nipple (3.725" 10) Halliburton X-Nipple (3.813" 10) 4-%" Baker CMO Sliding Sleeve Camco 4-%" X 1" KBG-2 Gas Lift Mandrels Phoenix pressure gauge I-wire for the Phoenix gauge Half-muleshoed joint of 4-%" IBT-M tubing 4-%" WLEG Surface Shut-in Wells: L-118 and L-103 do not need to be shut-in for the rig move on and off L-200. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close A roach Well List: ·~Wé".Náme'. ·Ctr.;.Ctr Distãnêe~;¡ ~~r.Referencê,MD·:~<·¡ L-103 91.46-ft 494.22-ft L-115 97.92-ft 543.33-ft L-117 86.60-ft 494.91-ft L-118 55.24-ft 743.33-ft 2 Final Permit 12/31/03 M dP e Greater Prudhoe Bay L-200 ML Permit e u rogram 13-1h" Suñace Hole Mud Properties: I Spud - Freshwater Mud Interval! Density (PPQ) Funnel vis YP Tauo PH Plastic Vis FL 0-1,700 8.6-9.2 250 - 300 50 - 70 10 -18 8.5- 9.0 20-45 NC-8 1,700 - 2,500 9.0-9.5 200 - 250 30-45 8-16 8.5-9.0 20 - 40 8 2,500 - 4,010 9.3-9.5 200 30-40 9-14 8.5-9.0 14 - 20 5.5-8 Interval Specific Maintain Viscosity greater then 250 Ensure fluid loss below permafrost is below 6 Objectives: Maintain mud temperature below 50° F 9-%" Intermediate Hole Mud Properties: I Freshwater Mud (L8ND) PH: 9.0 - 9.5 Interval! Density (PPQ) Funnel vis YP Tauo I PV I API Filtrate MBT 9.0-9.3 45 - 55 26 - 30 I 3-6 12 -18 4-6 <20 Interval Specific TBD Objectives: 6-3A" Production Hole Mud Properties: I LVT-200 MOBM1Versa-PrO) Interval! Density (PPQ) Stability YP I Oil : H20 Ratio I PV I API Filtrate MBT 9.2 650 - 900 18 - 25 I 80:20 I 15-20 I 4-5.5 J <6 Interval Specific TBD Objectives: Well Control- Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Diverter, BOPE and drilling fluid system schematics are on file with the AOGCC. Production Section- · Maximum anticipated BHP: 1,970 psi @ 4,400' TVDss (8.60 ppg EMW). Actual from L-117 MDT's · Maximum suñace pressure: 1,530 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 3,500 psi (7-%" casing has been tested to 3,500 psi) Estimated 9.2 ppg Brine /6.8 ppg ~iesel 5,000 psi Working Pressure entire stack and valves 3,500/250 psi Rams & Valves 3,500/250 si Annular Disposal · NO ANNULAR INJECTION ON THIS WELL. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08-04 for injection. Haul all Class I waste to Pad 3 for disposal. 3 Final Permit 12/31/03 Formation Markers e Greater Prudhoe Bay L-200 ML Permit . 1,;,&;(:j~.'.FormátionTops : '. ·,·,..::Ft.TVDss' .:.·¡'·¡FtMD',· :.~~.' Pore psi t-:!~ ~'! EMW'.u.,tlYJ . . i'ij,i~ Hydrocarbónsil':'! SV6 895 978 405 8.7 No SV5 1 ,480 1,680 675 8.8 No SV4 1,590 1,851 730 8.8 No Base Permafrost 1,680 2,014 770 8.8 No SV3 1,970 2,593 890 8.7 Poss. Gas Hydr. SV2 2,130 2,913 960 8.7 Poss. Gas Hvdr. SV1 2,465 3,582 1,120 8.7 Poss. Gas Hydr. UG4 2,755 4,161 1,255 8.8 Yes - Heavv Oil UG4A 2,785 4,221 1,270 8.8 Yes - Heavy Oil UG3 3,100 4,850 1,420 8.8 Yes - Heavy Oil UG1 3,550 5,706 1,600 8.7 Yes - Heavv Oil Ma 3,930 6,527 1,820 8.9 Yes - Heavy Oil Mb1 3,975 6,646 1,830 8.9 Yes - Heavy Oil Mb2 4,040 6,818 1,820 8.7 Yes - Heavy Oil Mc Faulted Out - - - - Na Faulted Out - - - - Nb 4,050 6,845 1,820 8.6 No - Wtr Nc 4,095 6,964 1,830 8.6 Yes OA 4,180 7,163 1,870 8.6 Yes OBa 4,250 7,362 1,895 8.6 Yes OBb 4,295 7,486 1,915 8.6 Yes OBc 4,350 7,632 1,940 8.6 Yes OBd 4,400 7,874 1,970 8.6 Yes TD (OBd) 4,340 13,050 1,970 8.6 Yes CasinglTubing Program 48" 13- Y:!" 9-%" 6-%" OBd 6-%" OBa 6-%" OA Tubin A53 Welded L-80 BTC L-80 BTC-M L-80 IBT L-80 IBT L-80 IBT L-80 IBT-M 80' 3,623' 7,844' 5,588' 5,668' 3,729' 7,121' ott"o'" ·m·~"IIiiI.III¡" . ,'.', ~., " '.,,~. '~~'Ip,~',,~":' Q;(~I VDrko'¡,:: 109' /109' 3,652' /2,573' 7,873' /4,475' 13,050' / 4,413' 13,030' / 4,283' 13,011' / 4,213' 7,150' /4,238' !¡~·~~~;;;;;¡;~::~!i;;: . Cement Calculations Casing Size 110-% -in 45.5-lblft L-80 BTC surface casing Basis I 250% excess in permafrost. 30% excess below permafrost. Top of tail cement 800' MD above shoe Total Cement Vol: Wash 20-bbl CW Spacer Spacer 70-bbI10.1-lb/aal MudPush spacer Lead 527-bbl, 692-sx 10.7-lb/gal ASL - 4.28 ft"/sx (cement to surface) Tail 75-bbl, 361-sx 15.8-lb/gal Premium G - 1.17 fr'/sx (top of tail at 2.853-ft MD) Temp BHST == 55°F from SOR, BHCT 60°F estimated by Dowell In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. 4 Final Permit 12/31/03 Greater Prudhoe Bay L-200 ML Permit Casin 7-% -in 29.7-lb/ft L~BTC-M intermediate casin .~- Basis Top of tail cement 700-ft MD above top of Schrader Ma-sand. 30% excess over auge. Total Cement Vol: Wash 25-bbl Water S acer 45-bbI10.3-lbl al MudPush S acer Tail 113 bbl, 530-sx 15.8-lb/gal Premium -1.20 ft Isx to of tail at 5,800-ft MD To Ma: 6,527' MD Tem BHST == 120°F from SOA, BHCT 90°F estimated b Halliburton 10-%" Casing Centralizer Placement a) Aun (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,652' MD (1,000' MD above the shoe). b) This centralizer program is subject to change pending actual hole conditions. 7-%" Casing Space Out a) Space 7-%" casing out with pups and long/short joints as required to place the top of a long full joint - 5- 15' above the top of the OBa and OA sands to allow for the window to be milled just below the top of each sand and in the middle of a full joint of casing. b) Place 1 AA tag above the first window, 1 AA tag above the second window, and 1 AA tag above the third window. AA tags to be spaced out -40 - 80' above window depth. c) Emergency 7-%" casing slips can be used instead of the 7-%" mandrel hanger if required for space out. 7-%" String Centralizer Placement a) Centralizer size: 7-%" X 9-Yø" (this is different then the norm of 14" under gauge hole) b) Do not run centralizers on the window joints spaced at the top of each sand. c) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. d) With the exception stated above, alternate 1 rigid straight vane cenralizer floating across a full joint and 2 rigid straight vane centralizers, one floating on the upper half of the joint and one floating on the lower half of the joint separated by a stop collar up to ±6,843' MD (320' MD above the top OA sand). Then continue with 1 rigid straight vane centralizer per joint floating to 5,747' MD (780' MD above Ma sand). Zonal isolation with cement is required between the OA and the Nb sands due to the presence of water in the Nb sand. The centralizer program is subject to change pending modeling and hole conditions. 4 112" Solid Liner Centralizer Placement a) Aun one straight blade rigid centralizer per joint, floating between the collars. If any differential sticking is noticed while drilling, it may be necessary to put another centralizer per joint separated by a stop collar. Do not put any centralization on the first two joints above the bent joint. Survey and Logging Program 13-112" Hole Section: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) Open Hole Drillina: MWD I GR Cased hole: None 9-V." Hole Section: Surveys will need to be IFA + MS corrected real time Open Hole Drilling: MWD I GR I Res I Den I Neu I PWD (Den Neu recorded only) Open Hole: None Cased Hole: USIT Bond Log (only as continQencv if poor cement iob) "". ,''', ' '" ,.~ . . 6-%" Hole Section: Surveys will need to be IFA + MS corrected real time Open Hole Drillina: MWD I GR I Res I Azimuthal Den I Neu (Den/Neu recorded only) I AIM I PWD Cased Hole: None 5 Final Permit 12/31/03 Drilhn Hazards and Contin encies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this fault block is expected to be underpressured based on the MDT samples. a. OA: 1,870 psi @ 4,180' TVDss (8.60 ppg EMW). Based on L-117 MDT's b. OBa: 1,895 psi @ 4,250' TVDss (8.60 ppg EMW). Based on L-117 MDT's c. OBd: 1,970 psi @ 4,400' TVDss (8.60 ppg EMW). Based on L-117 MDT's II. Hydrates and Shallow gas A. Gas hydrates are present below W-pad, but have not been a significant issue thus far during W-Pad drilling. If hydrates are encountered follow the recommended practice and apply good drilling operational practices. III. Lost Circulation/Breathing A. Lost circulation is unlikely within the Schrader interval. B. We do not expect breathing on this well as we are above the more prevalent breathing shale's Le. Seabee. IV. Kick Tolerancellntegrity Testing A. The 10-3,4" casing will be cemented to surface. B. The 7-%" casing will be cemented with 15.8Ib/gal tail cement to 700' MD above the Ma sand -5,800' MD. C. The Kick Tolerance for the surface casing is 78.6 bbls with 9.2 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure (most likely 8.6 ppg based on recent MDT's within the block). If the LOT is less then 10.9 ppg EMW, then the kick tolerance will be < 50 bbls. D. The Kick Tolerance for the production hole laterals is infinite with 9.2 ppg mud, 12.0 ppg FIT, and an 8.6 ppg pore pressure. If the FIT is less then 12.0 ppg EMW notify the ODE to have conversation on how to deal with potential ECD concerns around the casing exit points. E. Integrity Testing V. 10-3,4-in Window 7 -%-in Shoe 7-% -in Window 7-% -in Window 20-ft min new formation below shoe 20-ft min new formation below shoe 20-ft minimum from to window 20-ft minimum from to window LOT FIT FIT FIT 11.5 minimum 12.0 minimum 12.0 minimum 12.0 minimum Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking across the reservoir while running the slotted liners. Keep the liners moving as much as possible and run one centralizer per joint to help with standoff. VI. Hydrogen Sulfide A. L-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recently 10 ppm of H2S has been measured at L-Pad from all wells tested as recently as January 2003 with hand held H2S meters. This is as a result of H2S being transmitted by shared gas lift gas and not produced from L-Pad. There has been no seawater injection at L-Pad to date. VII. Faults There are four visible faults to cross while drilling the well. It is possible to encounter sub-seismic faults along the proposed well path. In the production hole sections, if a fault throws us out of section steer up as fast as possible to determine where we are within the section. This will make it easy to lowside OH sidetrack to get back on course. Fault #1 : SV6 1,050' MD 1 ,000' TVDss 110' West throw Fault #2 UG4A 4,880' MD 3,115' TVDss 40' Southwest throw Fault #3 Mb2/ Na 6,832' MD 4,045' TVDss 120' East throw Fault #4 OBd 11,340' MD 4,375' TVDss 15' East throw CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Final Permit 12/31/03 Greater Prudhoe Bay L-200 ML Permit Drill al Complete Procedure sllmary Pre-Rie: Work: 1. A 34" x 20" insulated conductor has already been set and surveyed. 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. Prepare neighboring wells for the rig move and production simops. Drillina Ria Operations: 1. MIRU Nabors 9ES Nipple up diverter spool and riser. Function test diverter. PU 4,500' of 5" DP as required and stand back in derrick (this will enable both holes to be drilled without changing the DP handling equipment in open hole). 2. MU 13-~" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,652' MD 12,573' TVD. The actual surface hole TO will be +1-100' TVD below the top of the SV1 sand. 3. Run and cement the 10-3,4",45.5# L-80 surface casing back to surface. Will use TAM collar as contingency only. NO drilling spool and riser and NU casing 1 tubing head. NU BOPE and test to 3,500 psi. 4. MU 9-%" directional drilling assembly with MWD/GR/Res/Den/Neu/PWD and a Weatherford Drill-Mill at ±800' from the bit in the HWDP section and RIH PU 4" DP to float collar. Test the 10-3,4" casing to 3,500 psi for 30 minutes. 5. Drill out shoe track. Circulate and condition mud. Displace well to new LSND drilling fluid. Drill 20' of new formation below rathole and perform a LOT. Directionally drill ahead to TO (Topset the OBd) as per directional profile to 7,873' MD 14,475' TVD. 6. Make shor trip as needed, work tight spots as seen. Circulate and condition mud at TO. Make sure hole is clean prior to POOH. POOH laying down the 5" DP and standing back the 4" DP, LD drilling BHA. Retrieve bowl protector. 7. MU and run 7-%" 29.7# L-80 BTC-M long string casing to TO. Cement in one stage to 700' MD above the Schrader Ma sand. Bump plug with seawater. Land casing on mandrel hanger. 8. Clean pits for displacement. Freeze protect 7-%" x 10-3,4" annulus with dead crude to 2,200' TVD. 9. PU 6-3,4" Powerdrive RSS assembly with MWD/GR/Resl Azimuthal Den INeu/PWD and RIH to the float collar picking up 4" DP on the way. Test the 7-%" casing to 3,500 psi for 30 minutes. 10. Displace well over to new Versapro MOBM. Drill out shoe track, circulate and condition mud. Drill 20' of new formation below rathole and perform an FIT to 12.0 ppg EMW. Directionally drill ahead to TO geosteering through the OBd to TD at 13,050' MD 1 4,413' TVD (prognosed). Perform wiper trip, circulate and condition mud. 11. POOH to near OBa window depth, log into top OBa (RA marker) with GR, log across the OA window as well. POOH, LD cleanout assembly. POH LD RSS. 12. MU and run 4-W' 12.6# L-80 BTC-M slotted liner with hanger and liner top packer to TO. Position liner top packer 100' below OBa window. 13. PU the 7-%" whipstock assembly. Set the whipsock on the OBd liner top packer such that the top of the window is near the top of the OBa sand (planned KOP: 7,362' MD). Orient whipstock to highside. Shear off Whipstock & mill window. Perform FIT to 12 ppg EMW. POOH 14. RIH with 6-3,4" drilling assembly (with MWD 1 GR 1 Res 1 Azimuthal Den recorded 1 Neu recorded 1 AIM) to whipstock. Directionally drill to 6-3,4" TO. Planned TO is 13,030' MD. Circulate and condition mud and perform wiper trip. POOH. 15. Pull whipstock #1. Run and set 4-%" slotted liner and hook hanger, POOH and LD liner running string. Run Baker Hook Hanger Lateral Entry Module #1 with ZXP liner top packer, POOH 16. PU the 7-%" whipstock assembly. Set the whipsock on the OBa liner top packer such that the top of the window is near the top of the OA sand (planned KOP: 7,163' MD). Orient whipstock to highside. Shear off of Whipstock and mill window. Perform FIT to 12 ppg EMW. POOH 17. RIH with 6-3,4" drilling assembly (with MWD 1 GR 1 Res 1 Azimuthal Den recorded 1 Neu recorded 1 AIM) to whipstock. Directionally drill to 6-3,4" TO. Planned TO is 13,011' MD. Circulate and condition mud and perform wiper trip. POOH. 18. Pull whipstock #2. Run 4-%" slotted liner and hook hanger, POOH and LD liner running string. Run Baker Hook Hanger Lateral Entry Module #2 with ZXP liner top packer. Clean pits for displacement. Displace over to 9.3 ppg KCL brine. POOH 19. MU 4-%" 12.6# BTM-M, L-80 completion assembly and RIH. See completion schematic for details. Land tubing hanger and run in lockdown screws. Reverse in brine with Corexit to protect the annulus. 20. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK-1 valve. 21. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 22. Pull two-way check. Freeze protect the well to 2,200' TVD. Install VR plug in 7-%" casing annulus valves. 23. Install BPV. Secure the well and rig down 1 move off Nabors-9ES. 7 Final Permit 12/31/03 l.- POST RIG - COMPLETION L-200, L-200 L 1 & L-200 L2 TREE: FMC 4-1116" 5M I WELLHEAD: FMC Gen 5 System Orig KB elev (N-9ES) = 28.5' 11", 5M csg.head wI 7" mandrel hanger & packoff 11" x 11", 5M, tbg spool wI 11" x 4-1/2" tubing hanger with control line ports 11" X 4-1/16" Adaptor Flange 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 109' alliburton X-Nipple (3.813" ID) 12,200' TVD I 4-1/2", 12.61b/ft, L-80, BTC-M Coupling OD: 5.2" DrifUID: 3.833"/3.958" Junction Specifications: Junction ID through LEM Module without diverter: 3.65" 10-3/4",45.5# L-80 BTC Csg @ 3,652' MD "r 7-5/8" X 5-112" Baker PRM Packer Halliburton X-Nipple (3.813" 'D) 4.5"WLEG 1-7,140' I Baker ZXP Liner Top Packer Tie Back Sleeve @ 7,133' MD Baker Hughes Hookwall Hanger @ 7,153' MD Window in 7-5/8" casing@ 7,163' MD Well Inclination @ Window = 68° 9.2 PPG Versapro MOBM below Completion '~ 6-3/4" OALateral 17,163'-13,011'1 ""--::~~'''-''''-==''=--_'_-- ~~._. ...."""""""'.,..':;:::'1 . --------------~~~~ . -::...~.Q~_:.- - ._~_.=-=-.=..=- =..._=-=_..=......:-~=--..:::-~~.~ Baker ZXP Liner Top Packer Tie Back Sleeve @ 7,332' MD 6-3/4" OBa Lateral 17,362'-13,030'1 Baker Hughes Hookwall Hanger@ 7,352' MD Window in 7-5/8" casing@ 7,362' MD Well Inclination @ Window = 68° "Jii\: '<, ~ ":'¡"'~~': ~~~.::,~__ _"..___..__-f::~,~:;; ''';:-r,~ .-- L _ _ _ - - - - - - r~1 "'~. ,,,.,,,,.... .-~~,.~=;;;.-~ - - _:-~-..=--~ ---...1::~:,:::~.J Baker ZXP Liner Top Packer & Hanger @ 7,462' MD 7-5/8",29.7#, L-80, BTC-M Casing Drift: 6.75" 7-5/8" Casing Shoe @ 7,873' MD Casing ID: 6.875" '4 6-3/4" OBd Lateral 17,873'-13,0501 DATE REV. BY COMMENTS GPAIfJ:' 12/3012003 MIK TRIOLO Level 3 Multi-lateral, 4-112" GL Completion ·ORION .- "'~,Pj NO:'50-i);¿9~~::O(¡ SO-029-xxxxx-60 WELL: L-200 ML SO-029-xxxxx-61 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI#: Survey Name I Date: TJrt I AHD / 001/ ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid NIE Y/x: Grid Convergence Angle: Grid Scale Factor: L-200L 1 (P4) Proposal December 19, 2003 Survey / DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA Vertical Section Origin: L-PAD / Plan L-200 (N-M) t 'lIIIjdy TVD Reference Datum: Plan L-200 (N-M) bllllllty S :hil1 TVD Reference Elevation: L-200L 1 OBa 'easl 11II Sea Bed / Ground Level Elevation: 50029 Magnetic Declination: L-200L 1 (P4) OBa / December 19, 2003 Total Field Strength: 189.968' /5869132801.38 fI /12.522/1344214.153 Magnetic Dip: NAD27 Alaska State Planes. Zone 04, US Feet Declination Date: N 70.35065562. W 149.32442018 Magnetic Declination Model: N 5978289.700 flUS, E 583209.300 flUS North Reference: +0.63624294' Total Corr Mag North·) True North: 0.99990787 Local Coordinates Referenced To: Schlumberger Minimum Curvature / Lubinski 309.480' N 0.000 fI, E 0.000 fI Rotary Table 72.6 fI relative to MSL 44.100 fI relative to MSL 25,102' 57554.000 nT 80.819' January 15, 2004 BGGM 2003 True North +25.102' Well Head e I Comr',:,s Top Whipsto,;k Base Whipstock KOP Cry 10/1(,0 7600.00 90.41 306.26 4366.20 4293.60 2991.77 5652.26 4872.88 137.92 10.00 10.00 0.20 1.14G 5983163.35 583293,09 N 70.36396786 W 149.32329980 End Cry 7624,13 92.83 306.30 4365.52 4292.92 3015.85 5676.38 4887.15 118.47 10.00 10.00 0.20 O.OOG 5983177.41 583273.49 N 70.36400686 W 149.32345777 Cry 6/100 8349.57 92.83 306,30 4329.76 4257.16 3739.29 6400.93 5316.14 -465.43 0.00 0.00 0.00 175.66G 5983599.85 582684.92 N 70,36517878 W 149.32820122 L-200L 1 OBi - gt 2 8392.62 90.25 306.50 4328.60 4256.00 3782.27 6443.96 5341,68 -500.07 6.00 -5.98 0.45 90.43G 5983625.00 582650.00 N 70.36524855 W 149.32848264 End Cry 8395.60 90.25 306,68 4328.59 4255.99 3785.24 6446.94 5343.46 -502.46 6.00 -0.05 6.00 O.OOG 5983626.75 582647.59 N 70,36525340 W 149.32850205 Cry 6/100 9772.36 90.25 306.68 4322.61 4250.01 5160.34 7823.69 6165.83 -1606.61 0.00 0.00 0.00 138.31G 5984436.73 581534.48 N 70.36749960 W 149.33747346 L-200L 1 CS, -'gt 3 9777 .91 90.00 306.90 4322.60 4250.00 5165.89 7829.24 6169.15 -1611.05 6.00 -4.48 3.99 139,56G 5984440.00 581530.00 N 70.36750868 W 149.33750957 9800.00 88.99 307.76 4322,79 4250,19 5187.96 6182.54 -1628.62 6.00 -4.57 3.89 139.56G 5984453,20 581512.29 N 70.36754526 W 149.3310 End Cry 9801.85 88.91 307.83 4322.83 4250,23 5189.81 7853.18 6183.68 -1630.08 6.00 -4.57 3.89 O.OOG 5984454.32 581510.82 N 70.36754836 W 149.33 3 Cry 6/100 10303.90 88.91 307,83 4332.41 4259.81 5691.56 8355.14 6491.55 -2026.53 0.00 0.00 0,00 25.36G 5984757.74 581111.00 N 70.36838918 W 149.34 "" L-200L 1 OB,o"gt 4 1 0324.06 90.00 308.35 4332.60 4260.00 5711.72 8375.3 6503.99 -2042.40 6.00 5.42 ,'2.57 15.02G 5984770.00 581095,00 N 70.36842315 W 149.34101492 End Cry 10341.72 91,02 308.62 4332.44 4259.84 5729.37 8392.96 6514.98 -2056.23 6.00 5.79 1.56 O.OOG 5984780.83 581081.06 N 70,36845316 W 149.34112725 Cry 6/100 10863.70 91.02 308.62 4323.12 4250.52 6251.20 8914.85 6840.75 -2463.95 0.00 0.00 0.00 50.77G 5985102.03 580669.78 N 70.36934280 W 149.34444095 10900.00 92.40 310.31 4322.04 4249.44 6287.49 8951.13 6863.82 -2491.96 6.00 3.79 4.65 50.82G 5985124.78 580641.51 N 70.36940579 W 149.34466862 L-200L 1 08a 'gt 5 10968.71 95.00 313.52 4317.60 4245.00 6355.98 9019.7 6909.61 -2542.98 6.00 3.78 4.67 O.OOG 5985170.00 580590.00 N 70,36953085 W 149.34508326 11000,00 96.88 313.52 4314.36 4241.76 6387.02 9050,82 6931,04 -2565.54 6.00 6.00 -0.01 O.OOG 5985191.17 580567,20 N 70.36958937 W 149.34526668 End Cry 11027.63 98.53 313.51 4310.66 4238.06 6414.33 9078.19 6949.89 -2585.40 6.00 6.00 -0.01 O.OOG 5985209.80 580547.14 N 70.36964085 W 149.34542806 Cry 6/100 11102.53 98,53 313.51 4299.54 4226.94 6488.22 9152.27 7000.89 -2639.12 0.00 0.00 0.00 180.00G 5985260.20 580492.86 N 70.36978013 W 149.34586472 L-200L 1 OE'a 'gt 6 11161.45 95.00 313.52 4292.60 4220.00 6546.57 9210.76 7041.17 -2681.54 6.00 -6.00 0.01 -158.50G 5985300.00 580450.00 N 70.36989012 W 149.34620953 11200.00 92.85 312.67 4289.96 4217.36 6584.96 9249.22 7067.45 -2709.62 6,00 -5.58 -2.20 -158.56G 5985325.96 580421.63 N 70.36996188 W 149.34643780 Well Design Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) Plan L-200 (N-M)\Plan L-200 (N-M)\L-200L 1 OBa\L-200L 1 (P4) OBa Generated 12/19/2003 1 :40 PM Page 1 of 2 c=!S End Cry Cry 6/100 L-200L 1 OB, "gt 7 End Cry Cry 6/100 L-200L 1 OB" ·'gt 8 End Cry TD /4-1/2" Lnr Leaal Description: 12557.16 12580.70 13029.68 90.00 90.62 90.62 315.60 316.87 316.87 4287.60 4287.47 4282.60 4215.00 4214.87 4210.00 7940.01 10606.18 7963.39 10629.72 8408.62 11078.68 3urface 2567 F8L 3705 FEL 834 T12N R11 E UM L-200L 1 Oba Tgt 2 2629 FSL 4195 FEL 827 T12N R11 E UM L-200L 1 Of·a Tgt 3 3457 F8L 24 FEL 528 T12N R11E UM L-200L 1 OPa Tgt 4 3791 FSL 455 FEL 828 T12N R11 E UM L-200L1 OLa Tgt 5 4197 F8L 955 FEL 528 T12N R11E UM L-200L 1 O[;a Tgt 6 4328 FSL 1093 FEL 828 T12N R11 E UM L-200L 1 aHa Tgt 7 4915 F8L 1746 FEL 828 T12N R11E UM L-200L 1 OBa Tgt 8 5269 FSL 2121 FEL 828 T12N R11E UM TJ / BHL 334 F8L 2444 FEL 821 T12N R11 E UM Northina IV! rftUSl 5978289.70 5983625.00 5984440.00 5984770.00 5985170.00 5985300.00 5985880.00 5986230.00 5986571.00 WellDesign Ver 3.1 RT-8P3,03-HF2.03 Bld( do31 rt-546 ) 7982.75 7999.75 8327.39 -3711,24 -3727.53 -4034.47 6.00 6.00 0.00 2.66 2.64 0.00 5.38 5.39 0.00 63,88G O.OOG O.OOG 5986230.00 5986246.82 5986571.00 579410.00 579393.53 579083.00 N 70.37246123 W 149.35458040 N 70.37250766 W 149.35471281 N 70.37340230 W 149.35720865 Eastina (X! rftUSl 583209.30 582650.00 581530.00 581095.00 580590.00 580450.00 579790.00 579410.00 579083.00 e e " Plan L-200 (N-M)IPlan L-200 (N-M)IL-200L 1 OBaIL-200L 1 (P4) OBa Generated 12/19/2003 1 :40 PM Page 2 of 2 Schlumberger WELL L-200L 1 (P4) OBa FIElD Prudhoe Bay Unit - WOA STRUC"'RE L-PAD Magnetic Þarametara Model: SOOM 2003 Dip: 80.819" Mag Dee: +25.102' Date: Jar.iary15.2004 FS: 57554.0nT Surface Location Lilt N70212.380 Loti: W,oi91927.913 NAD27 Alaska State Planes, Zone 04, US Feet Northing: ð978289.70 flUS Grid COfW: +0.63824294' Eaating: S83209.30 ftUS Scl!l1e Fact: O.99990786Q MisoellBneou& Slot: PlanL-200(N-M) Plan: L..200L1(p04)oe. TVDRef: RotaryTabIe(72.80ftaboYeMSl) $IVy Date: December 19. 2003 e 2400 3200 4000 4800 5600 6400 7200 8000 8800 Top WhlPstOCkj 4? Base W~ipstOCk 0 4000 4000 0 ~ g ..- " Q) ~ (j) Cry 6/100 Q L·200L 1 OBa Tgt 8 ¡::: 4800 4800 e " 2400 3200 4000 4800 5600 6400 7200 8000 8800 Vertical Section (ft) Azim = 309.48°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-W ^ ^ ^ z :E' o o ~ ~ ..- II Q) !ã u (/) (/) V V V 4000 4800 5600 6400 7200 8000 -4000 L-200L 1 -1600 Scale = 1(in):800(ft) , . · . · . · . · . · . · . ' . · . · . · . · . · . · . · . : r : · . · . ' . · . · . · . · . · . ¡.:IV ¡ · . : .u....-:-.......... · . ......... ..... '," -,,<--.. . ': ,';"".---- : · . cOoOoO> . · -. · --".0. '. . · . · . · . · ·Oor_ . :I.·~..ml·m.. . '. ...¿...,.......... ¡: . '. ; -" ;; Eind Crv ¡ ¡ ~i~,., 'i ··J~;~:;~:t'ml··im : : Crv6l100 :: ! !%m.mm.........I.m.m..m.....¡mm...m···:':r~:·· ..;;;~):-- .L ~.... j j j '~'"'m" ; / I 1 I.J ~~~t' . . . ,,:... : . . -3200 -2400 «< W E »> -800 o 8000 7200 6400 5600 4800 -200 (P10) OBd 4000 Schlumberger WEll L-200L 1 (P4) OBa FielD Prudhoe Bay Unit - WOA STRUC1\JRE L _ PAD - - - - - - - I s:;;;.loaü>o- NAD27 AIBska State PIaoøs.Zone 04, US Feet M"""",,,,", Magnetic Pwamaters ..,.., BGGM 2003 "I" 80.819' D..,,, January 15, 2004 Lat N70 21 2.360 NoIthing: 59782B9.70ftUS Grid Conv; +0.63624294' 1- PlanL-200(N-M) 1VDRef: RQ(aryTabIe(12.60ftaboYeMSl..) MagDec: +25.102" FS: 57554.0nT Lon: W1411927.913 "- 583209.30 !\US Scale Fact: 0.9999078652 ""'" l-2OOL1(p4)0Ba &vyDete: Decernber19,2003 -4000 4-112" Lnr -3200 -2400 -1600 -800 o tit e 94 200 . ¡OC ·¡OO 200 294 Field: Prudhoe Bay Site: PB L Pad Well: Plan L-200 (N-M) Wellpath: Plan L-200Ll OBa 27 e e 180 Tmvelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Sepomtion [100ft/in] e ~<Ç.\) x.V~ 'l~) ~,i,\-$' ~ \., ~ \. cv~~ \)~ ~~~~. ~~~ ~\~,<:¿ ~~ '6- ~~~ ~'tÞ~~ e PERMIT TO DRILL 20 AAC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. e e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /}!é4 ¿- :;;"'00 ¿ 2.. PTD# 20 <7 - Dc:> 3 CHECK WBA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing well ¡p¿ t4, L.. -2..0ð Permit No;2o$-'~ dðlAPI No. .50 -02.9" 2.~1 (If API num ber Productionsbould continue to be reported as last two (2) digits a function of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(f), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) . and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject to full EXCEPTION compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing . exception tbat may occur. DRY DITCH An dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals tbrough target zones. . 9) Rev: 07110/02 C\jody\templates WELL PERMIT CHECKL.IST Field & Pool PRUDHOE BAY, POLARIS OIL - 640160 PTD#: 2040030 Company BP EXPLORATION (ALASKA) INC Initial ClasslType Administration 1 P~rmit fee ~ttaçhe.d Y~s 2 le~s~ _numberappropri<lte _ Yes 3 _U_n[que weILnam~_anQ OUlTJb_er Yes 4 Wellloc<lt~d in a d_efine_d pool Y~s 5 WellJoc<lt~d proper _distance_ from driJling unitbound_ary_ Yes 6 WellJoc<lt~d pr_operd[stance_ from otlJer wel]s_ Y~s 7S_utfiçientaçre~ge_ay<!iI.able indrilliog unjt Y~s 8 J(d~viated, js wellboreplatincJuded Yes 9 _Oper_ator only ~ffeçteQ party _ Y~s 10 _Oper:ator lJas_appropriateJ~ond [nJorce _ . Y~s .. . . 11 P~rlTJit ~an be issued witlJout co_nservaJion order _ Yes 12 p~(IT)it can be issued witlJout ad_lTJinistratilte_approvaJ Y~$ 1/2/2004 13 Can permit be approved before 15-day wait Yes 14 We.ll Joc<lt~d within are~ ~Ild_strata _authorized by_lojectioo Ord_er # (put 10# in_com(11_ents) (For_ _NA 15 AJI welJs_wit.htnJI4J·uile_are.a.of reyiew id~otified (For servjc_ew.ell (mly) _ NA. .. .. 16 Pre-produced injector; .dur.atio_n_of pre-pro.duction I~ss than_ 3 months_ (For_service well onJy) NA 17 AÇMPJ::¡ndjngof Con~istencyha$ bee_nissued_ forJhis pr_ojeçtNA 18 _C_onQu_ctor st(illgprovided NA 19 _Surf~c~ _casing protects_ alLknowll USDWs NA 20 _CMTvoladeQuateJo çircuLate_on_cond_uçtor_& surfC$gNA 21 _CMT v_oj adeQuateJo tie-in Jong string to_surf csg_ NA 22 _CMTwilJ coyer_aU koownproductiye lJorizons_ No 23 Casing de_signs ~d_eQuaJe for c,t. B&perlTJafr_ost Yes 24 A.dequ.atetankage_or re_serve pit Y~$ 25 Jfare-.drill~ oasa 10A03 for .abandOlllTJe_nt be~o <lpproved NA 26 A.dequ.ate-'A1eUbore.separ<ltion-Pfoposed_ _ . Y~$ 27 Jtdivecter req_uired, does it meet regulations_ NA Date 28 _DriUiog fJuid_ progralTJ s~hematic_& eCl-uip Jistadequ<lte _ Yes 1/5/2004 29 _B_OPEs,doJhey meetregulation Yes 30 BOPE_pre.ss ratiog appropriatEUest to (pu_t psig in _commeots}_ Y~s 31 Choke_manifold çOITJPlies_ w/API RP-53 (May 84) Y~s 32 Work will OCC_ur withoutoperatjonsoutdow.n_ Y~s 33 Is presence of H2S gas_ probable _ No 34 MeclJa_nicaLcoodition of wells within AOR yerified (For s_ervice welJ onJy) _ NA Appr RPC Date Engineering Appr WGA Geology Appr RPC Date 1/2/2004 Geologic Commissioner: DTs Well Name: PRUDHOE BAY UN POL L-200L2 DEV 11-01L GeoArea Unit Program DEV On/Off Shore On . - - - - . - Slotted, r-J~bors 9ES, Multilater_aL Sidetraçk. Max MW9>2 ppgc _ Test to_3500_psi.MSP 1530 psi. 35 P~rlTJit c_an be issued wlo_ hydrogen_ sulfide measures _ 36 _D_ata_preseoted on potential oveJ :¡ressurezones_ 37 _S~ismic_analysis of shallow gas_zones 38 _S~abe.dconditioo survey (if off-shore} 39 _ Conta_ct namelp.hOlleJor_weekly progress reports [exploratoryonlYl Yes NA NA _NA NA Date: Engineering Commissioner: Public ~ Commissioner ~ate ~ Date 0ì~ Well bore seg Annular Disposal ~ o . e e - - - - - -
