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204-001
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 4,498' 4-1/2" L-80 4,427' 4-1/2" L-80 4,370' 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 2/2/2004 1/19/2004 ADL 028239 & 047447 00-001 1900' (Approx.) N/AN/A None 13,067' / 4,370' MWD / GR, MWD / GR / RES / DEN / NEU / PWD, MWD / GR / RES / Azimuthal DEN / NEU / AIM / PWD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 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 Pull 4-1/2" Kill String Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing 215.5# 45.5# 110' 3,555' 7,872' Gas-Oil Ratio:Choke Size: 26' - 3,362' Per 20 AAC 25.283 (i)(2) attach electronic information 29.7# 7,548' 2,502' 4,316' DEPTH SET (MD) 7,092' / 4,243' PACKER SET (MD/TVD) 31' CASING WT. PER FT.GRADE 12.6# 583177 579021 TOP SETTING DEPTH MD 31' SETTING DEPTH TVD 5986501 BOTTOM TOP 9-7/8" 31' 13-1/2" HOLE SIZE AMOUNT PULLED 50-029-23191-00-00 PBU L-200 583209 5978290 2212' FSL, 3673' FEL, Sec. 27, T12N, R11E, UM, AK CEMENTING RECORD 5983213 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 10/13/2021 2568' FSL, 3704' FEL, Sec. 34, T12N, R11E, UM, AK 265' FSL, 2506' FEL, Sec. 21, T12N, R11E, UM, AK 204-001 Schrader Bluff Oil Pool, Orion Dev Area 77.6' 3,354' / 2,405' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 48" 12.6# 31' 2,871'723 sx AS Lite, 338 sx Class 'G' 6-3/4" 260 sx Arctic Set (Approx.) 7,537' 13,052' 515 sx Class 'G' 4,423' 7,282' 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): 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 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 xGSFD 11/4/2021 3,871' MGR03NOV2021 DSR-11/3/21 SFD Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 7728' 4476' 4201' 2849' 6787' 4133' 6847' 4155' 6956' 4195' 7186' 4277' 7319' 4332' 7425' 4377' 7549' 4427' 7728' 4476' 12930' 4372' OBc (From Base) 12930' 4372' 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: 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. 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 OBd Schrader Bluff OBc (Invert) Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Schrader Bluff OBc Formation at total depth: SB Schrader Bluff NB 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 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 Schrader Bluff OBb Schrader Bluff NC Ugnu Schrader Bluff NA 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. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Schrader Bluff OA Schrader Bluff OBa Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top 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 08:44:42 -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 milling 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 #: 50-029-23191-00-00 Well Name: Field: County/State: PBW L-200 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska Mill window from 3354' to 3360' BOW 3374' 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. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-001 6.50-029-23191-00-00 PRUDHOE BAY, ORION / SCHRADER BLUFF OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13067 3375 2416 7092 None 4243 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" X 34" 31 - 110 31 - 110 2280 770 Surface 3840 10-3/4" 31 - 3871 31 - 2671 5210 2480 Intermediate 4317 7-5/8" 3555 - 7872 2505 - 4498 6890 4790 Liner 266 4-1/2" 7282 - 7548 4316 - 4427 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 7092 4243Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker Premier Packer Liner 5513 4-1/2" 7537 - 13050 4423 - 4370 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Andy Ogg PBFieldWellIntegrity@hilcorp.co Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)659-5102 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured4370 Sundry Number or N/A if C.O. Exempt: No SSSV installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Inspect Suspended Well Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028239 & 047447 PBU L-200 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3375, 3400, 5050, 7122 26 - 3362 / 3581 - 7281 26 - 2406 / 2519 - 4316 m By Samantha Carlisle at 12:44 pm, Aug 24, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.24 12:34:16 - 08'00' Stan Golis DSR-8/24/2020MGR04SEP2020 RBDMS HEW 8/26/2020 SFD 8/31/2020 ACTIVITY DATE SUMMARY 8/2/2020 T/I/O = 0/0/0. Suspended well inspection by AOGCC rep Matt Herrera. Daily Report of Well Operations PBU L-200 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:L-200 Field/Pool: Prudhoe Bay / Orion Unit Permit # (PTD):2040010 API Number: Operator:Hilcorp North Slope LLC Date Suspended: 2/5/2017 Surface Location:Section: 34 Twsp: 12N Range: 11E Nearest active pad or road:L Pad Take to Location 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: Good. Pad or location surface: Good. Location cleanup needed: No. Pits condition: N/A. Surrounding area condition: Good. Water/fluids on pad: No. Discoloration, Sheens on pad, pits or water: None. Samples taken: None. Access road condition: Access road and pad in good condition. Photographs taken (# and description): No. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Tree - Upper master, Lower master. Wellhead - TBG spool with 2 casing valves, Starting head with 1 casing valve. Cellar description, condition, fluids: Snow/Ice melt. Clean water. Fluid in cellar below lowermost casing valve. Rat Hole: N/A. Wellhouse or protective barriers: Yes, wellhouse. Well identification sign: Yes. Tubing Pressure (or casing if no tubing): 0 psi. Annulus pressures: IA / OA = 0 psi / 0 psi. Wellhead Photos taken (# and description): Yes. (1) wellhouse and sign, (1) wellhead/tree. Work Required: None Operator Rep (name and signature):Eric Dickerman AOGCC Inspector: Matt Herrera Other Observers: Inspection Date: 8/2/2020 AOGCC Notice Date: 7/31/2020 Time of arrival: 9:15am Time of Departure: 9:30am Site access method: Truck/Walk. 500292319100 Re-Inspection |nspectNo: susMFH200804085410 Date inspected: 8/2/20I0 Inspector: Matt Herrera ' VVeUNarne: PRUDHOEBAY UNO0NL,2D0 ---' PennitNumber: - --- 2040010 � Suspension Approval: _ Sundry ' # 317'066 ~ Suspension Date: 2/5/2017 ' | / LucafionYehfied7 141 it' Verified, Flow? Other (specify incomments) � Offshore? El VVe1|Pressures (psi) Tubing: U� r-� ---- iA: 0 _ DA: O Type of Inspection: Subsequent DateA06[Z Notified: 7/31/2020 ' - - Operator: Hi|oorpNorth Slope, LLC Operator Rep: EhcDickennan Wellbore Diagram Avai|? Photos Taken? Fluid in Cellar? W BPVinstaUed? [] VR Plug(s) Installed? LJ VVeUhead[ond�ion Wellhead in good condition. No leaks all valves and gauges functional; SSV removed. Condition ofCellar Some water in cellar but no sheen. Level well below outer annulus casing valve. Operator notified to monitor and address if ° needed prior towinter weather freezing conditions. Surrounding Surface Condition VVeUhuusestill onwell. Surrounding area and gravel were clean with nostains orsubsidence. Laterals disconnected and ~ blinded aithe header. [omments Location Verified with Aerial Photo Map. Supen/|sor[omments Photos (3) mJ > Monday, August l7'2O2O Suspended Well Inspection — PBU L-200 PTD 2040010 AOGCC Inspection # susMFH2O08-04085410 Photos by AOGCC Inspector M. Herrera 8/2/2020 2020-0802_Suspend_PBU_L-200_pho tos_mh. docx Page 1 of 2 w Y" WELL: L-200 ` a OWNER Pryalga e•v Und OPERATOR Hilrarp \arlh .slop,. H ( _ APS NUMBER 50-029-23191-0000 - SUR. LOCATION SW 4. a. Sac. 34. Tt2N. R1E 1181.1JNG POW 204-001 1 r. t 2020-0802_Suspend_PBU_L-200_pho tos_mh. docx Page 1 of 2 41111.11111 F -O I -S k * �.- --* w by Date: 1/20/2020 20 4001 0 Transmittal Number: 93730 32 0 4 8 BPXA WELL DATA TRANSMITTAL Enclosed is one disc containing the information listed below. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendallgbp.com. Please Sign and Email a copy of this transmittal to. GANCPDCna,bv365.onmicrosoft.com Thank you, filer Xendaff Subsurface Information Management AOGCC ConocoPhillips Alaska, Inc. ExxonMobil, Alaska JV-2019-USONSHOR-291 1k Own:0106 FEB 2 1 2020 AOGCC Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Disk SW Name API Run Date Company Description Number GYROSCOPIC SURVEY DATA AND GyroData / FINAL COMPOSITED GYROSURVEY L-200 500292319100 9/7/2019 Baker Hughes REPORT 1 L-2001-1 500292319160 2/19/2020 Baker Hughes GYROSCOPIC SURVEY REPORT L-2001-2 1500292319161 2/19/2020 Baker Hughes IGYROSCOPIC SURVEY REPORT Please Sign and Email a copy of this transmittal to. GANCPDCna,bv365.onmicrosoft.com Thank you, filer Xendaff Subsurface Information Management AOGCC ConocoPhillips Alaska, Inc. ExxonMobil, Alaska JV-2019-USONSHOR-291 1k Own:0106 FEB 2 1 2020 AOGCC Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 'e 1. Operations Performed Length: Size: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 'p Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redriil ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well Q Other: Close TAM Port Collar 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work measured None feet 5. Permit to Drill Number: 204-001 3. Address: P.O. Box 196612 Anchorage, Development RI Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-23191-00-00 7. Property Designation (Lease Number): ADL 028239 8 047447 8. Well Name and Number: PBU L-200 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Packer [rue vertical 4240 feet 7-5/8" 3555-7872 10. Field/Pools: 4790 Liner 266 PRUDHOE BAY, SCHRADER BLUFF OIL 11. Present Well Condition Summary: Length: Size: MD: TVD: Total Depth: measured 13067 feet Plugs measured 3375, 3400, 5050, 7122 feet true vertical 4367 feet Junk measured None feet Effective Depth: measured 3375 feet Packer Daily Report of Well Operations RI Surface 3840 10-3/4" measured 7092 feet true vertical 2413 feet Packer [rue vertical 4240 feet 7-5/8" Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Subsequent to operation: Conductor 78 20" X 34" 31-110 31 -110 Daily Report of Well Operations RI Surface 3840 10-3/4" 31-3871 31 -2668 5210 2480 Intermediate 4317 7-5/8" 3555-7872 2502-4496 6890 4790 Liner 266 4-1/2" 7282-7548 4313-4424 8430 7500 Liner 5515 4-1/2" 7537-13052 4420-4367 8430 7500 Perforation Depth: Measured depth: None feet Form 10.404 Revised 04/2017 / (�/, lry w,R og BCng RBDMS�� ov o 22ovubmit Original Only True vertical depth: feet Tubing (size, grade, measured and two vertical depth) 4-1/2" 12.6# 13Cr85 113C080 Packers and SSSV (type, measured and 4-1/2" Baker Premier Packer true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 0 26 - 3362 / 3581 - 7281 26 - 2406 / 2516 - 4313 7092 4240 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 MC 25.070.25.071, 8262831 15. Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surreys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WIN) ❑ WAG ❑ GIN) ❑ SUSP H SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-058 Authorized Name: Lastufka, Joseph N Contact Name: Hartley, Josephine Authorized Title: SI Specia' Contact Email: Josephine. Hartley@)bp.com Authorized Signature: Date: I�V/ f Contact Phone: +1 9075644570 Form 10.404 Revised 04/2017 / (�/, lry w,R og BCng RBDMS�� ov o 22ovubmit Original Only T/1/0 = SSV/0/0 TEMP = SI, Cycle LDS Pre Rig Stung into Tubing test void, 0 psi on void. Monitored for 10 min, no change in pressure. Function all LDS, all moved freely. Torque all LDS to 450 ft/lbs. R/D bleeder tool. 6/6/2019 Note: No pack off in IC test void, all (LDS) fully out 5-1/2" from last workover. T/l/O = LOTO/130/130. Temp = SI. Bleed IA & OA to 0 psi (pre pulling unit). IA/OA FL @ surface. Bleed IAP/OAP to 0 psi in <5 minutes. Monitored for 30 minutes, IAP/OAP increased 5 psi. Final WHPs = LOTO/5/5. 8/31/2019 SV = C. MV = O. IA, OA = OTG. 14:00 T/I/O = VAC/18/18. Temp = SI. Bleed WHPs (pre -pulling unit). No flowline, scaffolding, AL. IA, OA FL @ surface. Bled IAP/OAP to 0 psi in < 2 minutes. Monitor for 30 minutes. IAP/OAP unchanged during monitor. Final WHPs = VAC/ VAC/ VAC. 9/1/2019 SV, MV = C. IA, OA = OTG. 15:00 Start Job at 08:00 hrs. Pre Job Safety Meeting: Rig down . - Rig Down pulling unit while 9/1/2019 waiting on weather to remove well houses (high wind) Pre Job Safety Meeting: Rig down . Continue to Rig Down pulling unit while waiting on 9/2/2019 weather to remove well houses (high wind) T/1/0 = SI/0/0 TEMP = SI, Set Type HP BPV pre rig DHD bleed well head down to 0 psi monitored for 1 hour, no change in pressure. R/U T -bar with 4-1/2" Type HP BPV on running tool. N/D tree cap, open upper and lower valves. Set BPV through tree. Turn BPV to the right till i get thread jump. turn BPV to the Left 5-3/4 times. back out of BPV. Close in both valves N/U tree cap. 9/2/2019 T/I/0 = Vac/0/0. Temp = SI. WHPs (Post bleed). No AL, Flowline or scaffolding. Dryhole tree installed. 9/2/2019 SV, MV = C. IA, OA = OTG. 09:40 Continue rig move. Stage Equipment at Mobile pad and wait on pad prep on L -200A - Move equipment off Mobile pad, Move and set BOP and choke skid between wells. Set Sub base over L-200. Set and rig up pulling unit equipment. Plan Forward: Finish rigging up, Nipple 9/3/2019 down tree, Nipple up BOP and test. >>>Job in Pro ress..... Continue rig move. Stage Equipment at Mobile pad and wait on pad prep on L -200A -Move equipment off Mobile pad, Move and set BOP and choke skid between wells. Set Sub base over L-200. Set and rig up pulling unit equipment. Plan Forward: Finish rigging up, Nipple 9/3/2019 down tree, Nipple up BOP and test. >>>Job in Progress ..... T/I/0 = 0/0/0 Flow Line Diconnected. Job Scope: Pressure test BPV from under side. Pumped down IA and up kill string to test. Low test of 250 psi High of 2008 psi - 1989 psi 9/3/2019 after 6 min pass....Job Compelte Continue to rig up over L -200A - Hook up all air, water, hydraulic, electrical and mud lines. Nipple down the dry hole tree, inspect hanger. Nipple up BOP equipment. Test BOP Per plan -Witness waiver by Lou Laubenstein Pull TWC -Circulate out diesel from tubing. Accept the AAO -111 at 21:30 hrs 9-4-2019 24 hr Forecast : Finish circulating out the 9/4/2019 diesel - Pull tubing - Rig up and to ***PULLING UNIT SUPPORT*** T/1/0=0/0/0 PSI RIH WITH READ CALIPER, OAL=18 FT, OAW=182*, MAX OD=4" LOG CALIPER FROM 3370' MD TO SURFACE 9/5/2019 IRIG DOWN, WAIT ON GYRO / RIG DRIFT RUN Daily Report of Well Operations PBU L-200A Circ well tbg x IA. Recover diesel and circ to 9.3 brine. FLow check well. TOH and LD 4-1/2 VAM tb2 from 3362'. Rig up SLB Wireline. Log #1 10 ,,Caliper with GR/CCL/TEMP 24 hr forecast: Wait on SLB and Gyro Data - 9/5/2019 RIH with Tam Port tool - function and lock collar- Pull out of the hole. ***JOB CONTINUED FROM 9/5/2019*** ON STANDBY FOR GYRO / PULLING UNIT DRIFT RUN 9/6/2019 ***JOB CONTINUED ON 9/7/2019*** 24 Hr Summary: Complete caliper and received processed log from PDS. Wait on EL and Gyrodata. Decide to run drift assy to simulate TAM collar shifting tool MU BHA. RIH took wt 3-4k at 998' and 986 work through. POOH lay down drift. 9/6/2019 Forecast; Run GYRO to -RIH with Tam Port runningtool and shift collar - test - POOH ***JOB CONTINUED FROM 9/6/2019*** RIG UP RUN GYRO, OAL=15' OAW=120# MAX OD=1.70" WITH 10" CENTRALIZERS LOGGED GYRO FROM 3350' MD TO SURFACE. 9/7/2019 ***ALL AMERICAN PULLING UNIT IN CONTROL OF WELL UPON DEPARTURE*** 24 Hr Summary: Rig up SLB and run Gyrodata log - Rig down - Pick up Tam Port collar lockout tool. TIH on 4-1/2 VAM Tbg. Locate TAM collar at 983'. Stack 6k down to open. Two leak-off tests 500 psi to 290 psi over 5 minutes to prove open. PU to 13k over and close collar. PT to 1000/2000 psi 5 min. Lost 3/5 psi each. Drop ball. Pressure up to 1500 psi to actuate lockout tool @ 1500 psi. Pressure up to 2500 psi to shear and open shear out sub. T to 2000 psi to ensure collar remained closed. Release and TOH. Lay down BHA, inspect Tam running . an test 4 2, psi (Good test) Pull wear bushing. Rig up un and run 4.5" VT T Kill sst rin t g 9/7/2019 24 Hr Forecast: LD work string. PUH and RIH w/ 4-1/2 Kill String 24 Hr Summary: Continue to run 4.5" VT Kill string. Make up FMC hanger and land tbg @ 3371 AAO RKB per program (Up Wt 30k Dn Wt 20k). Set TWC and test. RD Choke line. ND BOPE. NU Dryhole tree. R/U lubricator and pull TWC. R/ U hard line. 24 Hr Forecast: Test lines, pump 230 bbls of diesel for freeze protect - U-Tube - Secure 9/8/2019 cellar and release the unit to J-22 (LRS Unit 76 Assist All American Pulling Unit) LRS arrive on location and standby at edge of 9/8/2019 pad. ***WSR continued on 09-09-2019*** ***WSR Continued from 09-08-2019*** T/I/O= 2/5/0 Temp=Sl Pumped 230 bbls Diesel down IA taking returns up TBG to open top tank. U-tubed TBG/IA. Pumped 3 bbls Diesel down the IA to pressure up to 2000 psi. After 5 minute test, lost 39 psi, passed. Final T/I/O = 0/0/0. All 9/9/2019 American in control of the wellupon departure. Continue R/U hard line and LRS - PT lines. Pump 230 BBL of diesel down the 4.5" X 10 3/4" and U-Tube. Tbg and IA FP'd to 2500' (38 bbls in Tbg and 192 bbls in annulus) Set TWC and test from below to 2,000 psi. Rig down LRS, hardline, rig lines, and secure cellar. Inventory all BP owned equipment and prep to return all non-required equipment. Emptied tanks. Pulling unit releases - on Stby rate @ 12:00 noon. 24 hr Forecast: Prep for move. Next well changed from J-22 to 04-01 due to still no confirmation when J-22 would be ready. Prep for move tonight 9/9/2019 Note: All Worley trucking costs (fluids and base) for well entered on this report 1FWP's T/I/0-TWC/0/0 R/U lubricator, Pulled 4" CIW "H" TWC #439 through dryhole tree. AAO rig freeze protected well. R/U lubricator and set 4" CIW "H" TWC #438 through dryhole tree. 9/9/2019 TWC/0/0 see log for details. TREE= 4-1/16" CW W91tEAD= 11'FMC ACTUATOR= BAKER OK 3. I3.EV = 77.6' REF ELEV = 77.6' BF. ELEV = 48.99 KOP= 380 Max Angie = 96'@ 11569 Datum ND= 7516 Datum TVD = 440( SS SUSPENDED zo# E_ 114' 4-1/2' KILL ST RING 3362' TBG. 12.6#, 13CR-85 VAM TOP COND B. 0152 bof. ID = 3.958" CUT TBG = 9.950' 11 3671' Minimum ID = 3.813" @ 2174' 4-1/2" HES X NIPPLE 7-5/8" X 9-7/8" TOC RA TAG 4-1/2" SGM-PDPC CA MLLTI-DROP SLB, D = 3.958" TAG 1-1 7375' 17-5/8" X 5-1/2' BKR ZXP LTP, D = 4.94" 1 15-12" X 4-12' XO, D = 3.930" 7405' BAKER HOOK HANGER 7419' w / L1 NON -SEALING LEM, D = 3.71' PERFORATION SUMMARY REF LOG: ANGLEATTOP PERF: Note: Refer to Production DB for historical cert data SLTD OBb 7497 - 12144I O I 02/04/04 �02/12(04 04 SLTD OBd 7870 - 13008 L O SAFETY NOTES: WELL ANGLE> 70" @ 6602'. "`CSG OBSTRUCTIONS SEEN @ 300',420', & 7,000' INSIDE THE 10-3/4- CSG --- 985' 10-3/4' TAM PORT COLLAR LOCKED CLOSE (09107/19) ..�_ 3362' F4_1/_2'MULESHOE.D=3958' GAS I FT MA NfWP C ST MD 4-1/2" SGMNDPGCA 7066' 4-12' BKR CMD SLDNG 6LV, D = 3.813' MIATI-DROPSUB, D = 3.958" LATCH 4-12" TBG, 12.6#, 13CR-80 VAM TOP 7250' .0158 bpf, D = 3.958" 343 RA TAG7270' 'HES XNP, D=3.813' 4-7/2" TBG, 12.6# L-80 BT -M,7296' BK 0 .0152 bpf, D = 3.958" "3 5490 15-1/2'X 4-12° XO, ID = 3.930"7301' - BAKER HOOK FLA NGER 7315' - w / L2 NON -SEALING L13K D = 3.71 ° 0 COLLAPSED LEM- CAN NOT PASS BY -7315 (SEEN N D.H. VDEO) (12/14/12) SUSPENDED TAG 1-1 7375' 17-5/8" X 5-1/2' BKR ZXP LTP, D = 4.94" 1 15-12" X 4-12' XO, D = 3.930" 7405' BAKER HOOK HANGER 7419' w / L1 NON -SEALING LEM, D = 3.71' PERFORATION SUMMARY REF LOG: ANGLEATTOP PERF: Note: Refer to Production DB for historical cert data SLTD OBb 7497 - 12144I O I 02/04/04 �02/12(04 04 SLTD OBd 7870 - 13008 L O SAFETY NOTES: WELL ANGLE> 70" @ 6602'. "`CSG OBSTRUCTIONS SEEN @ 300',420', & 7,000' INSIDE THE 10-3/4- CSG --- 985' 10-3/4' TAM PORT COLLAR LOCKED CLOSE (09107/19) ..�_ 3362' F4_1/_2'MULESHOE.D=3958' GAS I FT MA NfWP C ST MD TVrDB/TY COMMENTS 4-12' BKR CMD SLDNG 6LV, D = 3.813' VLV LATCH PORI DATE "4 5373 343 7193'4-12' 'HES XNP, D=3.813' DMY BK 0 07/03/11 "3 5490 349 DRLG HO CORRECTIONS DMY BK 0 11/21/09 '2 6645 406 SUSPENDED OM1' BK 0 11/21/09 "1 6888 415 BWPTY BK - 11/22/16 "STA 4, 3, 2, & 1 = COVERED BY CMT 7061' COMMENTS 4-12' BKR CMD SLDNG 6LV, D = 3.813' 7087' 7-5/e' X 4-i/2' BKR ('F2B,t PKf; D = 3.875 7122' -F4--1/2' HES X NP. D=3.813" 7122' 4-12' PX RUG (11/05/15) 7193'4-12' 'HES XNP, D=3.813' 7264' a-12' x 5-12" XO, D = 3.940' 727- 5.75" BKR SEAL STEW (SEALS REMOVED), D=4.83" Ur K LXP LTP w /TEBK, 0=5_750" L2 (OBa � (OBa) LBW WINDOW65° - - 7320'-7331' oBa PBTD 13043' OPENING WIDTH = 3.33" 7315'- 13044' 6-3/4' OBa LATERAL, ID = 3.958' 7398' 4-1/2' MULE SHOE, D = 3.958' Lt (OBb) LEW WNDOW 64° ::;L1 (OBb)7424'-7435'---------OPENING VW DTH=3.33"298T F7419'- 12988' 6-3/4" OBb LATERAL, ID = 3.958" 17-5/8" X 5-12' BKR ZXP LNR TOP PKR I 14-1/2• MULE SHOE, D=3.958' 872" X 4-72" XO,D0 CSG, 29.7#, L-80 BT M, D=875'G 7 �• �� I L-2 I 7572' - 13052' 6-3/4" OBd LATERAL, PBTD 13050' QB ORION UNIT WELL: L-200 PERMIT No: 2040010 (020) (030) API No: 50-029-23191-00(60)(61 T12N. R11E.2567' FSL 8 1575' FFI BP Exploration (Alaska) REV BY COMMENTS DATE REV BY COMMENTS N9E5 ORIGINAL COMPLETION E D-16 RWO P272 SUSPENDEDST JMD DRLG HO CORRECTIONS 02/13/17 JT/JMD FINAL ODE APPROVAL 09108M9 AAO -111 SUSPENDED ORION UNIT WELL: L-200 PERMIT No: 2040010 (020) (030) API No: 50-029-23191-00(60)(61 T12N. R11E.2567' FSL 8 1575' FFI BP Exploration (Alaska) THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Sean McLaughlin Engineering Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU L-200 Permit to Drill Number: 204-001 Sundry Number: 319-058 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww W . oogcc.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4� Daniel T. Seamount, Jr. Commissioner DATED this � day of February, 2019. MWO&E B 2 0 2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 /,m 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ] Plug for Rednll ❑ Perforate New Pool ❑ Reenter Susp Well ® Alter Casing ❑ Other Close TAM port collar 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development ® . 5. Permit to Drill Number 204-001 - 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ Service ❑ S. API Number: 50-029-23191-00-00 ' 7. If perforating. 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No M PBU L-200 9. Property Designation (Lease Number): 10. FieldZile ADL 026239 & 047447 PRUDHOE BAY, SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (k): Total Depth TVD (it): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13067 - 4367 3375 2413 1840 3375,3400,5050,7122 None Casing Length Sim MD TVD Buret Collapse Structural Conductor 78 20" X 34" 31-110 32-110 Surface 3840 10-3/4" 31-3871 31-2668 5210 2480 Intermediate 4317 7-5/8" 3555-7872 2502-4496 6890 4790 Liner 266 4-1/2" 7282-7548 4313-4424 8430 7500 Liner 5515 4-1/2" 7537-13052 4420-4367 8430 7500 Perforation De�bh AM Perforation Depth TVD (ft): Tubing Size: - Tubing Grace: Tubing MD (ft): None 4-1/2" 12.6# 13Cr85 / 13Cr80 26 - 3362 13581 - 7281 Packers and SSSV Type: a12• Baker Premier Packer Packers and SSSV MD (ft) and TVD (ft): 7092/4240 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary ® Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ® Exploratory ❑ Stratigraphic ❑ Development Ej • Service ❑ 14. Estimated Date for Commencing Operations: May 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended m 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning, Zachary H be deviated from without prior written approval. Contact Email: Zachary.Browningabp.com Authorized Name: McLaughlin, Sean M Contact Phone: +1 907 564 5220 Authorized Title: Engineering T"""ea,mmt Leader CTD Authorized Signature: /t/ 1 ` Date: % `y ZOl q y COMMISSION USE ONLY Conditions of approval: Notify Commission sothata representative may witness Sundry Number: /1 Plug Integrity ❑ BOP Test ml/Mechanical Integrity Test ❑ Location Clearance ❑ Other2 h/.5 ®P�— / 47' r Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 12J Subsequent Form Required: /0— IVO C/ APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 242-09 i r ORIGINAL RBDM202019'00r;��9 Submit Form and Form 10-403 Revised D4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Zach Browning Obp RWO/CTD Engineer Date: May 1, 2019 Re: L-200 Sundry Approval Well Type: Producer Current Status: The well is currently shut-in. Request: Sundry approval is requested to re -access the suspended well L-200. History and current status: L-200 was originally drilled and completed in 2004. However, in 2017 it was no longer online due to solids production. It was prepped for a planned A sidetrack and the parent was abandoned with a cement plug. The tubing was pulled and an EZSV and whipstock were set before downhole problems with a TAM Port collar in the surface casing led to the rig down and suspension of future wellwork. The TAM port collar had been inadvertently opened while tripping in hole and the decision was made to suspend operations until a plan could be made to lock the collar closed. A Kill string was ran in the well to -3362' MD and the well was freeze protected with diesel. The well is currently offline, classified as "Non -Operable", due to the suspension. The tubing and IA are filled with diesel to 2500'. An EZSV is set in the 10-3/4" casing and the casing was pressure tested to 2000 psi prior to the rig moving off the well. Perforations are abandoned by a -2000' cement plug from 7122' MD to -5050' MD. Proposed plan: The All American Oilfield Pulling Unit 111 will pull the kill string to access the TAM Port Collar and lock it closed. The kill string will be re -run and the pulling unit will rig down There will be no change to the wellbore configuration. The MASP�has not changed since the rig operations last year, MASP==1840 psi./ 1'ererrs/�cvl7�GiyeC�-�ie1`/10-,Za tle�rscfC. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to lock closed the TAM Port Collar and verify with an MIT of the casing. Pre -Rig Prep Work: 1. F: CMIT - TxIA -C© 2C� C O5 2. V: Set TWC and test. Pre -Pulling Unit tree work. 3. 0: Bleed WHP(s) to zero. Remove the well house. Level the pad as needed for the pulling unit. Proposed RWO Procedure: > %% % 1. MIRU. ND tree. NU and test HOPE. y4aui /149 r"iC-� G -o 146a_ 2. Pull 4-'/2" Kill string. 3. Run the NS TAM Port Collar Lock Out Tool. MIT Surface Casing. 4. Run 4-'/2" Kill string. 5. Freeze protect. Set TWC. ND HOPE. NU and test tree. RDMO. Post rig Work: None planned. Well is prepped for sidetrack. Zach Browning RWO/CTD Engineer 564-5220 CCWell File Joe Lastufka Loepp Victoria T (DOA) From: Leemhuis, Jacob <Jacob.Leemhuis@bp.com> Sent: Tuesday, June 12, 2018 10:09 AM To: Loepp, Victoria T (DOA) Cc: Browning, Zachary H Subject: RE: AAO #111: BOP Stack Victoria, Apologies for not providing the ram configuration with the Sundry. The All American Oilfield 111 rig will have blind rams. The BOP configuration will be as follows: • One Annular Preventer • One Blind Ram- type preventer • Mud Cross with outlets for choke and kill lines • One ram -type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP Policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low test for all components. Thanks, Jacob C. Leemhuis From: Loepp, Victoria T (DOA) <victoria Ioepp(2alaska.gov> Sent: Tuesday, June 12, 2018 9:06 AM To: Browning, Zachary H <Zachary.Browning @bp.com>; Leemhuis, Jacob <Jacob Leemhuis2bp.com> Subject: AAO 6111: BOP Stack Jacob, Zach, Several Sundries have been submitted using this WO rig. Will there be blind shears or blind rams in the BOP stack to meet BPs internal policy? What will be the ram configuration? Please forward a copy of the BOP test procedure. Thanx, 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 LoeppCdalaska goy 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. It 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 Loe 401aska aov = 4-1/16'CM/ LJfAD- IV Fw SUSPENDED 3ATOR= BAKER E LEV = -- 77.6 B_E3f= 77.V _ T -N = _ _ 48.99 4- W" KILL STRNG 336 Argk 96' �' 126#, 13CR40 = Q 1156'9' 0 7516 VAM'OPODFDB, jr—TVD:;- 4400' 88 .0152 bpf, D = 3.958- 7-5/6' CSG CUT (0127117) 3556 3496 a-frz•curTBG(of26/n) 3581' 103&4' CSG, 45.5#, L-80, D = 9.950' H 3671' '.. Minorum ID = 3.813" @ 2174' 4-112" HES X NIPPLE I7-58' X 9-78' TOC H 5600' RA TAG 6963' 412'SGh4FDPGCA 7035 b11T40R1P SlB,D=3.958' 412' SGA4FDfirGi 7065 Al1hOROP Sl$, D = 3.958' 4-1/7 TBG, 12.6#, 1301-80 VAM TOP 7250' -0158W.[)=3-958' SAFETY NOTES: WELL ANGLE> TV @ 6602•. ***CSG OBSTRUCTIONS S®4 @ 300•, 420•, a 1 W INSIDE THE 10-3f4" CSG"" 10-3/4- TAM PORT COLLAR I .Efc]F•bt:il 0-3/4• GAS LF7 AMNOfE.S ST MD TVD DEV TYPE VLV LATCH FORT DATE •4 5373 3433 58 KBG2 DAN BK 0 07/0:V71 '3 5490 3496 56 KBG2 DIM BK 0 11/21109 '2 6645 4068 69 KBG2 OW BK 0 1121119 '1 6868 4157 69 KBG2 EMPTY BK - 1122/16 'STA 4, 3, 2, 91 = COV6i®BY CMT I4-1? HKR CTD SLUNG SLV, D= 3.813' 7-58' X 4-1? BKR &REM PPR D = 3.875' I4-12' FES X NP, D - 3.813' 4-1/7 PX PL.I1G(11/ w5) RA TAG 72'JO• /4�•r r uc n a-uc nv, u= aww- 4-12- TBG, 12.69 L-80 BT -M, 7296• 7277• 5.75 BIO& SEAL STEM .0152 bpf, D - 3.958' (SEALS REMOVED), D= 4.83' 15- la' X 4-12' XO, D = 3.930' 7301' 17287 7-58' X 4-12' BKR ZXP LTp w nia3K, D = 5.750• BAKER HOOK HANGER 7315 _L2 (OBa) L2 (OBa) LEM WNDOW 65° w / L2 NON SEALNG LEK D = 3.71' _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7320' -7331' COLLAPSED LI3N -CANNOT PASS BY -7315 OBa PBTD 13043• OPS VVIDTH = 3.33' (SEEN N D.H VIDEO) (12/14112) RA TAG 7376' 7315'- 13044' 63/4' OBa LATERAL, D = 3.958' 7-58' X St/2- BKR ZXP LTP, D = 4.94• 7386• 7388' 4-12' MLLE SHOE D = 3.958- 15- XO, D=3.930' 740,5' Ll(OBb) LEM VANDOW 64` _ ---------------- BAKER FUCK HANGER 7419• — L1 (013b) 7424'-7435' L1 NON-SEALNG LB1ti 0=3.71. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ OFEFMJG WIDTH = 3.33" OBbf$D 1288T PERFORATION SUk*KRY REP LOG: F741 W - 12988' 6-3/4' OBb LATERAL, D = 3.958• ANGLEATTOPPERF: Note: Refer to Roductmn DB for tstorical pert data 753T 7-58' X 5-12' BKR ZXP LMR TOP FKR SIZE SPF NTE RVAL Op VSA I DATE 4-12' SLTD O. 7392 - 13000 O 02/18AM 75W 4-12' MIRE SHOE D = 3.956' 4-12 SLTD OBb 7497 - 12944 O 02/12104 4-12' SLTD OBd 7870-1 4104 7567' 5-72' X 4-12' XO, D - 3.930' RA TAG 7663• (� 572' -13052' 8-3/4' OBd LATERAL, l 7-578' CSG, 29.7#, L-90 BTC -K D = 6.875 �'-2(bl I 7 7677 I -20 PBTD 13050• CRON LUT WELL: L-200 FEMU No: 2040010 (020) (030) API No: 50-029-23191-00 (60x61) SEC 34, T12N RI IE, 2567 FSL d 1575' FEL BP Bq*oradon (Alska) 1 2 3 4 41.2,1 L ° ° A A 31.815/8 l SHENKAI SL 13-5M ANNULAR 6-103/6'1 31-111 O O SHENKAI SL 13-5M DOUBLE RAM B B 91_1791-17/161,81-51 41_BIT�g11 1113T�g11 31.25jg11 5'- 1/2 C 1'-93/" ° o C o O o 11�71-41/2"o 2 0 0 ° Olo 51_31211 CLOSING / OPENNING VOLUME (GAL) MIN ITEMS CLOSING VOL OPENNING VOL 300°0 ANNULAR 23.59 17.41 RAM 4.39 3.91 0 0 HCR 0.40 0.40 THE CONIEMSOF THIS DgAWN6 PROJECT TME BOP NOTES' INFORMATIONINTHIS ggETHEPROPEgTYOFNO:STERN ENERGY sFnutcEs cora'. ANr AERO DWGNO 13-5M BOP STACK DRAW NO LS FOR REPROOVCTIou OF TNIa A-000-15-002 _ ORaNN 7Y WTE BLarE 2gIF9EIIU,g N£wM REV REFERENCE ONLY AND IS NOT FOR DRA N WTHOIJTTHEEVRESS PERWa010N OF MSTERN v"""'� NnBtlAm C°, 0 IMTIK RELEASE TY MJP O1Mv4010 APPROVED GATE 9IE 8NEET CONSTRUCTION. ENERGY SERNLEB LOw is REV MWRRTM BY MPo MTE 3T cnY PRO TE, MJP DI/MGN2018 A 1 OF 1 1 121 3 4 TTS= MD WHLHEAD= 1rFn1c PROPOSED L. _ kc TM= -200A REV 6 DIB. fiEl/ = 77.6'53.80' 3432 ORIGINAL COMPLETION T —^380' Avc AnaM = .."— 20X COM 714' TOP HC, ID=6.875" Minimum ID = 3.725" @ 8874' 4-1/2" HES XN NIPPLE 41102" TBG, 12.6X, 13 .0152 hpf, ID = 3.958" 98" CSG. 29.7X, 13CR4 = 6.875' VAM TOP SAFETY NOTES: WELL ANGLE >70° *"*CHROME CSG &TBG'•' MILLOUT WINDOW (L—WA) —34W--3413' GAS LFT MANIRF C ST MD WD DEV TYPE VLV LATCH PORE DATE 4 3432 ORIGINAL COMPLETION 12/12/16 JT/JMD PROPOSAL REV 3 3 6195 RWO 12/12/16 JT/JMD PROPOSAL REV 5 2 7193 SIDETRACK (L -200A) 01/23017 JT PROPOSAL REV 6 WP71 1 8114 BUILT PROPOSED 8240' D = 3.864" X PP, D=3.813" SCFSLEEVED= I/2' HES TNT PKR, D = FRAC PORT, D = 3.951 SCREEN SLEEVED = 2- HES TNT WR, D = = 3.856" ORION UNIT WELL L -200A PERMIT No: API No: 50-02323191-0_ SEC 34, T12N, R11E, 256T FSL 8 1575' OP Explomfim (Aladin) COMMENTS -----7 GWXJWJ04 NSE5 ORIGINAL COMPLETION 12/12/16 JT/JMD PROPOSAL REV 3 11/25M D-16 RWO 12/12/16 JT/JMD PROPOSAL REV 5 /_ SIDETRACK (L -200A) 01/23017 JT PROPOSAL REV 6 WP71 12/16/15 JTP/JMD BUILT PROPOSED 0509/16 SUJMD PROPOSAL REV 05/09/16 JT/JMD PROPOSAL REV 2 D = 3.864" X PP, D=3.813" SCFSLEEVED= I/2' HES TNT PKR, D = FRAC PORT, D = 3.951 SCREEN SLEEVED = 2- HES TNT WR, D = = 3.856" ORION UNIT WELL L -200A PERMIT No: API No: 50-02323191-0_ SEC 34, T12N, R11E, 256T FSL 8 1575' OP Explomfim (Aladin) Rixse, Melvin G (DOA) From: Browning, Zachary H <Zachary.Browning@bp.com> Sent: Monday, February 18, 2019 7:08 AM To: Rixse, Melvin G (DOA) Subject: RE: PTD(204-001) L-200 Sundry 319-058 Attachments: L -200A Appr Revised Permit 1-26-17 1 of 2.pdf, L -200A Appr Revised Permit 1-26-17 2 of 2.pdf, L -200A wp11 Well Plan Report.txt Mel, That is exactly correct. It was closed with the Rotary rig during the last operation, but the fear was it would be opened, and so the operation was suspended. I have attached the previous permit to drill. The plan is to carry on with the original sidetrack plan with a drilling rig once this TamPort collar is locked closed. Let me know if you need anything else. Thanks, Zach From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Friday, February 15, 2019 9:57 AM To: Browning, Zachary H <Zachary.Browning@bp.com> Subject: PTD(204-001) L-200 Sundry 319-058 Zach, Do you currently have a passing MIT on 10-3/4" casing to 2000 psi? If so, is the TAM port collar closed but not 'lock closed'? Also, AOGCC does need more information as to the future of this well and the proposed sidetrack design. I can probably figure out what BPXA is planning if you have a schematic for the proposed sidetrack? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin.Rixsero7alaska.eov). Rixse, Melvin G (DOA) To: 'Browning, Zachary H' Subject: PTD(204-001) L-200 Sundry 319-058 Zach, Do you currently have a passing MIT on 10-3/4" casing to 2000 psi? If so, is the TAM port collar closed but not 'lock closed'? AOGCC does need more information as to the future of this well and the proposed sidetrack design. I can probably figure out what BPXA is planning if you have a schematic for the proposed sidetrack? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin. RixsePalaska.gov). Carlisle, Samantha J (DOA) From: Rixse, Melvin G (DOA) Sent: Tuesday, February 5, 2019 8:20 AM To: Carlisle, Samantha 1 (DOA) Subject: FW: Please cancel sundry #318-211 for L-200 (PTD #204-001) From: Lastufka, Joseph N <Joseph. Lastufka@ bp.com> Sent: Monday, February 4, 2019 4:56 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Browning, Zachary H <Zachary.Browning@bp.com> Subject: Please cancel sundry #318-211 for L-200 (PTD #204-001) Mel, We aren't sure if we'll make the year deadline for approved sundry #318-211 for re-enter suspended well L-200 (PTD #204-001). We will be submitting another sundry tomorrow to replace #318-211. If you have any questions or need additional information, please let me know. Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 1 Office: (907) 564-4091 Suhsurfzwc, Wells BP Exploration Alaska 900 E. Benson Blvd. I Room: 717B I Anchorage, AK RBDMSS EB 1 11015 V®F TFJt IP \� /� �� THE STATE Alaska Oil and Gas ofLAsKA Conservation Commission � Sf{2 ` 333 West Seventh Avenue "�� GOVERNOR BILL WALKER h Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.ao cc.alaska. ov 9 9 John Egbejimba Engineering Team Leader—CTD&RWO SWINE JUN 1 2 Cll1h BP Exploration(Alaska), Inc. P.O Box 199612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU L-200 Permit to Drill Number: 204-001 Sundry Number: 318-211 Dear Mr. Egbejimba: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 622 Hollis S. French Chair DATED this day of June,2018. RBDMAS JUN 13 2018 RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION MAY 21 2018 APPLICATION FOR SUNDRY APPR S ' 20 AAC 25.280 1 (08,3//a?/ 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 •'e Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approve rogram 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well I 1 ' Alter Casing 0 Other Close TAM port collar 121 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-001 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. 6. API Number: 50-029-23191-00-00 . 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 IZI PBU L-200 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028239&047447 PRUDHOE BAY,SCHRADER BLUF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 13067• 4367 • 3375 2413 1840 3375,3400,5050,7122 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"X 34" 31-110 32-110 Surface 3840 10-3/4" 31-3871 31-2668 5210 2480 Intermediate 4317 7-5/8" 3555-7872 2502-4496 6890 4790 Liner 266 4-1/2" 7282-7548 4313-4424 8430 7500 Liner 5515 4-1/2" 7537-13052 4420-4367 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None 4-1/2"12.6# 13Cr85/13Cr80 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 ® Wellbore Schematic El 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch IZI Exploratory 0 Stratigraphic 0 Development El Service 0 14.Estimated Date for Commencing Operations: June 20,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended El • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 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 Name: Browning,Zachary H be deviated from without prior written approval. Contact Email: Zachary.Browning©bp.com Authorized Name: Egbejimba,John Contact Phone: +1 907 564 5220 Authorized Title: Engineering Team Leader-CTD&RWO Authorized Signature: ,./.1"( 1 - Date: 5/2-JP. 0 i t COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: I, 2.1 I Plug Integrity 0 BOP Test Mechanical Integrity Test 0 Location Clearance 0 Other: 6 op 1-CS J-- � ,3,0!'I7 g-t 5 / o ZSo0 psi 41'7 nvlu/ p fie-1/t k,S t ± Post Initial Injection MIT Req'd? Yes 0 No tr Spacing Exception Required? Yes 0 No kg Subsequent Form Required: 1 46 T APPROVED BYTHE // Approved by: 242acc7.............. COMMISSIONER COMMISSION Date: to I I?i 4334( , J v-n- 5/31II f3 RBDMS JUN , 3ZoeRIGINAL -. . Submit Form a Attachments in Duplice Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • • To: Alaska Oil & Gas Conservation Commission N From: Zach Browning ID RWO/CTD Engineer Date: May 21, 2018 Re: L-200 Sundry Approval Well Type: Producer Current Status: The well is currently shut-in. Request: Sundry approval is requested to re-access the suspended well L-200. History and current status: L-200 was originally drilled and completed in 2004. However, in 2017 it was no longer online due to solids production. It was prepped for a planned A sidetrack and the parent was abandoned with a cement plug. The tubing was pulled and an EZSV and whipstock were set before downhole problems with a TAM Port collar in the surface casing led to the rig down and suspension of future wellwork. The TAM port collar had been inadvertently opened while tripping in hole and the decision was made to suspend operations until a plan could be made to lock the collar closed. A Kill string was ran in the well to —3362' MD and the well was freeze protected with diesel. The well is currently offline, classified as"Non-Operable", due to the suspension. The tubing and IA are filled with diesel to 2500'. An EZSV is set in the 10-3/4" casing and the casing was pressure tested to 2000 psi prior to the rig moving off the well. Perforations are abandoned by a —2000' cement plug from 7122' MD to 5050' MD. Proposed plan: The All American Oilfield Pulling Unit 111 will pull the kill string to access the TAM Port Collar and lock it closed. The kill string will be re-run and the pulling unit will rig down. There will be no change to the wellbore configuration. The MASP has not changed since the rig operations last year; MASP=1840 psi. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to lock closed the TAM Port Collar and verify with an MIT of the casing. Pre-Riq Prep Work: 1. F: CMIT—TxIA 2. V: Set TWC and test. Pre-Pulling Unit tree work. 3. 0: Bleed WHP(s) to zero. Remove the well house. Level the pad as needed for the pulling unit. Proposed RWO Procedure: 1. MIRU. ND tree. NU and test BOPE. 2. Pull 4-'/" Kill string. 3. Run the NS TAM Port Collar Lock Out Tool. MIT Surface Casing. 4. Run 4-%2" Kill string. 5. Freeze protect. Set TWC. ND BOPE. NU and test tree. RDMO. Post riq Work: None planned. Well is prepped for sidetrack. Zach Browning RWO/CTD Engineer 564-5220 CC: Well File Joe Lastufka • Loepp, Victoria T (DOA) From: Leemhuis,Jacob <Jacob.Leemhuis@bp.com> Sent: Tuesday,June 12, 2018 10:09 AM To: Loepp,Victoria T(DOA) Cc: Browning,Zachary H Subject: RE:AAO#111: BOP Stack Victoria, Apologies for not providing the ram configuration with the Sundry. The All American Oilfield 111 rig will have blind rams. The BOP configuration will be as follows: • One Annular Preventer • One Blind Ram-type preventer • Mud Cross with outlets for choke and kill lines • One ram-type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP Policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low test for all components. Thanks, Jacob C. Leemhuis From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent:Tuesday,June 12, 2018 9:06 AM To: Browning, Zachary H <7achary.Browning@bp.com>; Leemhuis,Jacob<Jacob.Leemhuis@bp.com> Subject:AAO#111: BOP Stack Jacob, Zach, Several Sundries have been submitted using this WO rig. Will there be blind shears or blind rams in the BOP stack to meet BPs internal policy? What will be the ram configuration? Please forward a copy of the BOP test procedure. Thanx, 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(cr�alaska.gov 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 op ( lsk.a _» 1 iil_L= 4-1/16"CNV WELLHEAD= 11 FMC SUSPE110ED NOTES: WELL ANGLE>70°@ 6602'. ACdUATOR= BAKER 111rOBSTRUCTIONS SEEN @ 300',420',8 OKB.B.EV= 77.6' 6-3,0a 1,000'INSIDE THE 10-3/4"CSG" REF ILEV 77.6' (20#CONO H114'I I 1 -_..- 986' H10-3/4"TAM FORT COLLAR BF BEV= 48.99' 4-1/2"KILL STRING -13362' KOP= 380 12.6#,13C(i 85 3362' H4-1/2"MJLESHOE,D=3.958' 1 113G,Max Angie= 96°@ 11569' VAM TOP COPD B, 3376' H10-3/4"BKR WHFSTOCK(02102/17)J Datum MD= 7515' Datum NO= 4400'SS .0152 bpf,D=3.958" 111111111111111111111111111111111 ' 3400' j-110-3/4'HES EZSV(01/29/17) 7-5/8'CSG CUT(01/27/17) -1 3555' , 4-1/2'CUT TBG(01/26/17) H 3581' GAS LFT MANDRILS 10-3/4'CSG,45.5#,L-80,D=9.950' --I 3871' ST MD Nd DEV TYPE VLV LATCH FORT DATE ESTNA IED TOC PLUG(12/02/16) -6050' II '4 5373 3433 58 KBG2 DMY BK 0 07/03/11 r9rra�a�ar•�f '3 5490 3498 56 KBG2M'DBK 0 11/21/09 IsmMinimum ID = 3.813" @ 2174' #•�'4'��'I!4•� '2 6645 4068 69 KBG2 DMY BK 0 1121109 4-1/2 H E S X NIPPLE X4/4.6•#+,v-- 7 1 6888 4157 69 KBG2 EMPTY BK 1122/16 '�4i•7•4��r�'A FA *STA 4,3,2,81 =COVERED BY CM T 7-5/8"X 9-7/8'TOC 5800' I '441.*4►.4 :'►iia,aka I RA TAG 6983' I AI ' 4-1/2'SGM-PDPG-CA 7035' � . • _ 7061' H4-1/2"BKR CMD SLUING SLV,D=3.813" MULTI-DROP SID,D=3.958' 1�1 �0 Ab a i. 7087' -17-5/8'X 4-1/2"BKR PREM PKR 0=3.875" / rds4-1/2"SGM-POPG CA 7066' 7122' H4-1/2"FES X Imp,D=3.813" MULTI-DROP SUB,ID=3.958' X li 7122' -14-1/2"PX PLUG(11/05/15) 4-1/2"TBG,12.6#,13CR-80 VAM TOP7250' 7193' -14-1/2"HES X NF,D=3.813' .0158 bpf,D=3.958' RA TAG 7270' 7I. 7264' H4-1/2"X 5-1/2'XO,ID=3.940" --..._ * 4-1 7277' 15.75"BKR SEAL STEM 2'TBG,12.6#L-80 BT-M, 7296' '41%� � .0152 bpf,ID=3.958" Via' ', (SEALS REMOVED),0=4.83" vm 5-1/2'X 4-12"XO,D=3-930' 7301' , 7282' H7-5/8"X 4-1/2"BKR ZXP LTP w/TEBK,D=5.750' BAKER HOOK HANGER -1 7315' L2 OBa L2(OBa)LEM WINDOW 65 w/L2 NON-SEALING a G LEM,D=3.71' 11 _,.. ( ) 7320'-7331' COLLAPSED LI3M-CAN NOT PASS BY -7315 R OBa PBTD H 13043' OPENING WIDTH=3 33" (SEEN 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 LW,D Si=4.94" 7386' ��, - �, 7398' i4-112'MULE SHOE,D=3.958" vl 5-1/2"X 4-1/2"XO,D=3.930" 7405' „,:k a 8 _ L1 (OBb)LEM VMNDOW 64' BAKER HOOK HANGER 7419' I. $ L1 (OBb) 7424'-7435 w/L1 NON-SEALING LEI,D=3.71' OPENING WIDTH 3.33" OBb PBTD H 12987' PERFORATION SUMMARY REF LOG: 7419'-12988' 6b-374'113 -3/4'OBb LATERAL,ID=3.958' ANGLE AT TOP PERF: Note.Refer to Roduction DB for historical perf data ►� 7537 7-518'X 5-1/2"BKR ZXP LNR TOP PKR SIZE SPF NTERVAL Opn/Sqz DATE 11111 4-1/2" SLTD OBa 7392-13000 0 02/18/04 O 7548' --I4-1/2'MULE SHOE,D=3.958' 4-1/2' SLTD OBb 7497- 12944 0 02/12/04 4-12" SLTD OBd 7870-13008 0 02/04!04 ii 756T J--I5-1/2"X 4-1/2"X0,ID=3.930" RA TAG -{ 7663' 2� J iL-- I 7572'-13052' 6-3/4'OBd LATERAL,ID=3.958' 7-5/8'CSG,29.7#,L-80 BTC-M,13 -1=6.875' 7872' OBd PBTD H 13050' l DATE REV BY COP MNTS DATE REV BY COMMENTS ORION UNIT 02/22/04 Ni9ES ORIGINAL COMPLET1ON WELL: L-200 11/25/09 D-16 RWO PERMT Nb: 2040010(020)(030) 02/04/17 P272 SUSPENDED ST API No: 50-029-23191-00(60)(61) 02/13/17 JPoD DRLG HO CORRECTIONS SEC 34,T12N,R11E,2567'FSL&1575'FEL 02/13/17 JT/JM) FNAL ODE APPROVAL BP Exploration(Alaska) r I s Q • CO U S o 1 9 J O O Y rc U Q Z , . . U o 0 Z � Ma a. .- %....0Z O ■ I �A J M ui d O J 1 Q 111 rn ,_ u _IIIIIII ^ Z 0inrnOr- h re al �: I--I M 'cT' Z NNctO o 0 ' _ 1 O �r a d O ti �J c o , OL1.1 U o al III < O wN w0- - N 0 " II^^ d O V d -_ b Z CL cC m° a O L G U > J W . . U wZ a g ° ■ ■ � Z � U=ao a ICG 01 W 8 ch r,Q i ,-.5 0z . Z i_Kiz. WW N90: [ § 'a NyON r .- CO L.►V Cr) I. W W W Q K W K 1 F Q W K O a W N (V a o a ch ` CV = t~P.: m N VI ISI \•+/111111 � \•+/� f 1 0 toil" I4 o 0 o I D c D ()-_[ E — ° °I° ° 1 Hf f o Z �I� \ W / CL v 1- o0 z cC Q ' • J Q -JCL J W - r Y Z m \ , CO Z Z __ �� r Z p 1 co w O f- -II. rc I M W W p m M N z >- _1 ,- c-,-) zooa z,_000 ofnWFi5 i-0ZZm gzw ce 1-o¢ILLoz o LLW z z?OrcQo Q CO 0 0 1 STATE OF ALASKA RECEIVED 0 ALASKA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERAIS JUN 1 2 2013 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations s ut n ac d Suspend 0' Perforate 0 Other Stimulate 0 Alter Casing 0 Change ApilAi Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Suspended Inspection 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 204-001 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 -' AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23191-00-00 7. Property Designation(Lease Number): ADL 028239&047447 8. Well Name and Number: PBU L-200 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth: measured 13067 feet Plugs measured 3375,3400,5050,7122 feet true vertical 4367 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 276 4-1/2" 7282-7548 4313-4424 8430 7500 Liner 5515 4-1/2" 7537-13052 4420-4367 8430 7500 Perforation Depth: Measured depth: None feet %Mp JUN 2 0 LUih 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): 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 5AC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ 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 ❑ GSTOR ❑ WINJ 0 WAG 0 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.Montgomeryabp.com :—/t57 Authorized Signature: :—/t57 , /�/ Date:64 7,4e Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 V` t.- ('`i3// RBDM JUN 1 2 2018 , /f �6. 1 Submit Original Only i Daily Report of Well Operations L-200 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: - ppb Field/Pool: Orion ©fi Oct ©i Permit# (PTD): 2,0 4 DO(0 API Number: 50-07 23191 -no Operator: BP EXPLORATION (ALASKA) INC Date Suspended: (*)2/RS/Lo( 7 Surface Location: Section: Twsp: 12 Js{ Range: (1 E Nearest active pad or road: ad I f Spi e lid Take to Location 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: CA pin Good Con 'i Pad or location surface: CA p p,n / tio Location cleanup needed: t`Ip^C. Pits condition: N/A Surrounding area condition: LI tin Water/fluids on pad: ni pn LC p/rl t S A.O t... Discoloration, Sheens on pad, pits or water: Np Samples taken: None Access road condition: 0760d. Photographs taken (#and description): LA/Q /� Ji .ci :, A ;,y'f Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: C a4r. ( odd , ,•r, x�� 1 �. Cellar description, condition, fluids: I c p1 L L1 r f f'k s r . Rat Hole: N�A Wellhouse or protective barriers: W I i }-!.o t rltr,r C Well identification sign: Yr c Tubing Pressure (or casing if no tubing): "1-4*C' f I„,c, Annulus pressures: .»k4. p.s t OA-4 Wellhead Photos taken (#and description): yes /p f 1 f4-ir4 ( / i r, kir'/' Work Required: None Operator Rep(name and signature): J0.4. Pro AOGCC Inspector: Other Observers: Inspection Date: (,/q!A AOGCC Notice Date: ��.r. -Gs= /0/8//C7", Time of arrival: Time of Departure: Site access method: Roar • • Suspended Well Inspection – PBU L-200 PTD 2040010 Plat highlighting L-200's wellbore and one-quarter-mile radius buffer: I — L 12PB2 `t NW E2-01 20 21 C ' n L-203 23 i 1 0* -203L2-01 ti L250L1 t► L223 L-200L2 L 1200 O r• -200L1 f L 18L1 - 6L•11PB1 - ` y L215P1 L212 0 L-203L , i>l2ri +�-rkL3PB' L-12' -211 2 y 2 ( ff t 131 29 0 Q EIL'11 „ { 'L-21 `,L 203L1 NW . EN-2 L 1 ,�. 133-29E C•� -119 L-203L2, X-12,•. f } 1i L-122 ti L-202L3 +r. _ NN /.1 �!/ ll. .: - �' _ i t 0C '-„ PB1(Y” 1 ell ; i e '. 1202 L-02A`` l 4' • { �►tt , L 21 ''''��r4... _.. t. 1. ; '' '..°4°,11110b".711115110111` ;:� L 114A �•i `.. L 102 t ^�.. ... -+es 06 L w. 32 33 �''"'�` ...�"��";t 'k L-201P82 �� .i '`l \TQ7I• . uI I ::,+.�..,,r+,,+L201L1PBL 104 L-2 "�� -04 a�jikt ��-• :,3 L-201L2 L-201 - 10. .1203E r,,V-20 - 210 W. ti: ^ 202L'1 L.200 imL 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, 1311E DRILLING PERMIT 204-001 • • 40000011 wwr wrc � r.,(1,41s, s400 f 4 ,,, i I n d r k t 9 $ , j r• f :: - l L f Rl 'I 41 1'41 c r * ' ' ' •.'r.:fr.,::,,,rrr' ',:,'..:....f......:r;:;,,,.'..rr,,;.r...,.. 0 , ( a - 7:, i I I ' ' 1 I t r 0 . ..-• •, "- ...' .,,;,.:ott,,;••...,,ixi , „„..-., ''. . , ; *4. ::'?;.‘ . ' i,.. ": ,,,";"'07,, ,n'7% ' ,5- , • • . , . . .., :,•A‘,... :',.':,„.,, ,`...,.. 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' :' , 5 k' ftyfy r WELL: L-200 ML 104*C4N 4 P4 1Ma*u s ; ' .�W t+JGRtXx+ 9W t',{4ac 9A�i2N N f % " 5 Zig. { 4.",,,, 1 ,. % . n TREE= 4-1/16"CMI WELLHEAD= 11'FMC SUSPIDEDQNOTES: WELL AN(LE>70*(6602'. ACTUATOR= BAKER ,- L 2 411VOBSTRUCTIONS SEEN @ 300',420',& '0103.ELEV= 77.6' 1,000'INSIDE THE 10-3/4"CSG"** REV 772 20#CON) ---1:1141----J I REFBF.ELEV= 48.99' ".- 986• H10-3/4"TAM PORT COLLAR KOP= 380' 4-1/2'CUT TBG —7-1 3376' H10-3/4"BAKER WHPSTOCK( / , ) Max Angle= 96*@ 11569' (12/08/16) Datum MD= 7515' 3400' H10-3/4"HES EZSV(_/ /_) Datum ND= 4400'SS 1-5/8'CSG CUT(_/_/_J H 3555' I---- 4-1/2"CUT TBG(_!/_J H 3581' ------' GAS LIFT MANa2ELS 10-3/4'CSG,45.5#,L-80,D=9.950' H 3871' 1 1 ST M7 ND DEV TYPE VLV LATCH PORT DATE 6 3448 2436 60 KBG2 DMY BK 0 11/04/15 ESTIMATED TOC PLUG(12/02/16) — ?)I I' '----_-• 5 3565 2495 60 KBG2 DMY BK 0 11121 9 Minimum ID =3.813" aG 2174' *4 5373 3433 58 KBG2 DMY BK 0 07/0 11 '3 5490 3498 56 KBG2 DMY BK 0 11/21 9 4-1/2" HES X NIPPLE ►40, ;•' *2 6645 4068 69 KBG2 DMV BK 0 11/21 9 7-5/8"X 9-7/8"TOC H 5800' ��•4•4� G 1 I6888 4157 69 KBG2 EMPTY BK - 11/22/16 #4,r *STA 4,3,2,8 1=COV B2®BY CMT RA TAG H 6983' E 4-1/2"SGM NDPG CA H 7035' - 7061' H4-1/2"BKR CM)SLIDING SLV,D=3.813' MULD-DROP SIB,C=3.958" A 20 �� 7087' —{7-518"X 4-1/2"BKR PREM I'KR D-3.875' 4-1/2"SGM NDFG CA H 7066' •ttie `9 7122' �4-1/2"HES X NP,D=3.813" MULTI DROP SUB,D=3.958" '•5 7122' H 4-1/2"PX PLUG(11/05115) 4-112"TBG,12-6#,13080 VAM TOP 7250' 7193' 4-1/2'HESXNIP,D=3.813" .0158 bpf,13=3.958" r 7264' H4-1/2"X 5-1/2"XO,ID=3.940" RA TAG H 7270' ' 4-1/2"TBG,12.6#L-80 BT-M, 7296' « �i a 7277' —5.75"BKR SEAL STEM .0152 bpf,ID=3.958" ; (SEALS REMOVED),ID=4.83" 11 5-1/2"X 4-1/2"XO,13=3-930" 7301' 7282' —17-518"X 4-1/2"BKR ZXP LTP w I T1�K,D=5.750" BAKER HOOK HANGER H 7315• ( L2 OBa L2(OBa)LEM WINDOW 65° w/L2 NON-SEALING LEM,D=3.71" � 7320'-7331' ,� OPENING WIDTH 3.33" COLLAPSED LEM-CAN NOT PASS BY H -'7315 OBa�� -1 1 (SEEN IN D.H.VIDEO)(12/14/12) RA TAG H 7375' I 7315'-13044' 6-3/4"OBa LATERAL,ID=3.958" 7-5/8"X 5-1/2"BKR ZXP LTP,D=4.94" { 7386' f 2 / 7398' —{ --------111.4 4-1/2"MULE SHOE,D=3.958' 5-1/2'X 4-112"XO,13=3.930" — 7405' a 1.1 (OE%)LEM WINDOW 64° a le BAKER HOOK HANGER -I 7419' L1 (OBb) 7424'-7435' OPENING WIDTH=3-33" w/L1 NON-SEALING LBM,D=3.71" rYr '� OBb PBTD —{ 12987' PERFORATION SUMMARY .7" ep REF LOG: 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958" ANGLE AT TOP PERF: Note:Refer to Production DB for historical perf data ----- U iolo 75537• —17-5/8"X 5-1/2"BKR ZXP LNR TOP PKR SIZE SPF _ INTERVAL Opn/Sqz DATE 4-1/7 SLTD OBa 7392-13000 0 02/18104 7J4,8' —14-112"MULE SHOE,D=3.958" 4-1/2" SLID OBb 7497-12944 0 02/12/04 A ,4 4-1/2" SLID OBd 7870-13008 0 02/04/04 7557' —15-1/2"X 4-112"XO,IO=3.930" RA TAG —1 7663' 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" —I 7872' OBd PBTD — 13050' ----_ __ I DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/22/04 N9E5 ORIGINAL COMPLETION WELL: L-200 11/25/09 D-16 RWO PERMIT No: 2040010(020)(030) 02/04/17 P272 SUSPENDED ST AR No: 50-029-23191-00(50)(61) 02/06/17 JM) DRLG I-10 CORRECTIONS SEC 34,T12N,R11E,2567'FSL&1575'FH- BP Exploration(Alaska) STATE OF ALASKA WE � C ` •LASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERAT• APR 2 4 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operatio c ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing 0 Change c Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Initial Suspend Inspection 14 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 204-001 3. Address: P.O.Box 196612 Anchorage, Development 10 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23191-00-00 7. Property Designation(Lease Number): ADL 028239&047447 8. Well Name and Number PBU L-200 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth: measured 13067 feet Plugs measured 3375,3400,5050,7122 feet true vertical 4367 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 0 0 Surface 3840 10-3/4" 31-3871 31 -2668 5210 2480 Intermediate 4317 7-5/8" 3555-7872 2502-4496 6890 4790 Liner 266 4-1/2" 7282-7548 4313-4424 8430 7500 Liner 5515 4-1/2" 7537-13052 4420-4367 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 1 12018 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 239 362 994 957 496 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 nnc 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development I? Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP IZI 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.MontgomerY0bp.com Authorized Signature: /1/44/1//4; i %j liVelote47 Date: ii/2 Ild 8 Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 1/7-Z—4f 6`tz52,ei RBDMScSCAPR 2 6 201fubmit Original Only • Daily Report of Well Operations PBU L-200 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 = 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 - 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 • • Suspended Well Site Inspection Form Initial/5 Year/10 Year inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: L-200 Field/Pool: PBU Orion Permit#(PTD): 2040010 API Number: 50-029-23191-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 2/5/2017 Surface Location: Section 34 Twsp T12N Range: R11E Nearest active pad or road: L Pad Take to Location 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: Snow covered Pad or location surface: Snow covered Location cleanup needed: Remove gauges, pipestands and instrumentation stored in well shelter Pits condition: Snow covered Surrounding area condition. Snow covered Water/fluids on pad: Snow covered Discoloration, Sheens on pad, pits or water: Snow covered Samples taken: N/A Access road condition Good Photographs taken (#and description) Yes Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition FMC Typical rusty peeled paint no obvious leaks Dry hole tree Cellar description, condition, fluids Clean/Frozen Rat Hole: N/A Wellhouse or protective barriers: Good Well identification sign: PTD# incorect on wellhouse sign needs to be corrected Tubing Pressure(or casing if no tubing): 0 Annulus pressures: 0 Wellhead Photos taken (#and description): Yes Work Required: Correct PTD#on wellhouse sign Operator Rep (name and signature) Ryan Holt '- CK. AOGCC Inspector: Guy Cook 0 er Observers: / Inspection Date: 3/23/2018 •OGCC Notice Date: 3/22/2018 Time of arrival: 12:00 AM Time of Departure: 12:00 AM Site access method. Drive . I • a rt; .a • An n ro e ...i ; 74( ...1 t JJ �' C -.I , N ' C . 0 JjC N .kpN : 4�_ , J, es• C' ,t, fmJA . r . gJ ;i- J t MoO:1 J t. #' J N II C C. f 0`t ntill 4� 1114411.. a - , i # n9 11116. .';fe.41%./.* " -.. 7 riv 0 • r Q OJ "n. 4111111k . . ,„ ...z,4401,,,,,,,1,4,‘ .. ..t \___..... -...,„,„,„41/4 i: , , .,.„. , T '---:. -.0.21kith...., ..,, , : 1. f j./. U) I ori J �Z+ i '�.. k ./t Ott i N 6 a) \., / ,. 401110- 7,,,,.„ '.,.. iNfort N,11 - -44,..4eiri...i.it, a „I. � cy r _ L or ► sati*-N_. CD 3-C Pr z ' r "dr J O r J.1 \ O 0,o j J N o JN' j /.-w y r r .Ne .. r (7 N V`. J C �CO CO o m J IN '`... J �iM CL N • t W . 2-2 J 1 o J 0 Q. J+� Yr---_ co O d -» O • 01N r (..A07 O d O 0 0 .. U)• 0- 0- f _� _ — — 0 • Photos: '-', ''''-, / f,. le 411Ik - ‘- to ' NA., jt , * :1,4 ,''' ,'.• t - 'tt"a:.' 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' , ; i'llt. . 4 / '' / / / // //a i ,- ' t / , ,ii. i y Y , - . , ., , . . I i , .g.,,,,, , ,„ ... 4 ,_ 9' 0 , • »0 " .. ...;.... .. . ., . , .. 44, 111( ' ' . ''''''71'''" ''''''''' 4-.4„:,,..: g, ,, .." e s: s`i -" -:9 4..:'41111'', '' 3 # v irk t i',j ,1 ,- 0. • • k 1 t illi 11,,k' .. . 1 401111.01P111.414,144. k I 1 III IV,1,111,13' ___ ......„ __ ,....... __ ., ......- ,..,, .. . .., ' s \*,t•„, 'Ar.;'t‘ ; 1 .4, . . b- - . .— —. , , i„1,,i.,,. .. , : ''''''''''''7-''''II-: I'''''''''''i ,,.4...g.'---,,,opplatelP,' '.;,`,,•.1"tr.-.7.-"'""""' '.' _ . ------1.11 ' 1','7"m„j' • .......---------' • ''-' 11101.11011% .., ... ,_.... ( „.,„......,,.........(.... . , • 0 1 s 4ni R — \ 0!h sot i E \ . .,, , r if 1 s: ...,... .. .....,,..., -,1,,....,i,.-,--,-z,„:2,-.- , , „, ,;:,, , , mit f 40, , all , ,:it.....i„.. .._. ., .-,, ,#.,,.,:...*..,,,,,,,„. ,,, , .101 . ,,,,...,,,,s it.:1::-,'if,.' - - • ,'.,..,,. /,),.., . 1, - w..."\\'' 9 4 ' x ' ‘ ii.p41-•-, , 1-4,.. , . .,--,..:.- .. . .__,. ... , . _. , ,e. , r 3 A//I/fl ' . a tli '',4 all ik 1.. , ,,,, . v , , ' '".:1 7--. , .. ,,' --- r:' i: ' ' . . \itai6,...:.: 1 '- - ''' . ;. II 1 klilly , , ,.. / 1 • • • I • N,1 ra,: hf` t ' qy ;)fir. I I , 6 i r & i+ 'it , „ 'f r.. ' WELL: L-200A "'.� 6 OWNER Prudhoe Bay Unit , °"` OPERATOR RP Exploration(Alaska)Int. i Itr 1'` API NUMBER 50-029-23191-07-00 T 3x ii r., a.. .... Ike SUR.LOCATION SW 1.4.Sec-34,T12N 871E ORILUNG PERMIT 216-125 j, P M IF ii 1 f{(j ." tip. i#41IIAA . 4 / t 7 R TREE= 4-1/16"GW 1M3.LI-EAD= "RC S US P E IE D _ O O NOTES: WELL JOE>70*@ 6602'. ACTUATOR= BAKER ti LZ OBSTRUCTIONS SEEN 300',420',& OKB.ELEV= 77.6' LLL 1,000'INSIDE THE 10-314"CSG"' I20#CONK) --111.1' --- .I- .. REQ BEV= 77.6' ... 986' H 10-3/4'TAM FORT COLLAR BF.a.EV= 48.99'... 41/2"KEL STRING -I 3362' --- KOP= 380 3362' -14-1/2"MULESHOE,D=3.958" - TBG, 12.6#,13CR-85 Max Angle= 96°@1-1569' VAM TOP CORD B, '---..--.. 3376' 10-3/4"BKR wHPSTocK(02/02/17) Datum MD= 7515' "�� Datum ND= 4400'SS .0152 bpf,D=3.958" Pi.•-•_rl 3400' --L0-3/4"HES EZSV(01/29/17) 7-5/8"CSG CUT(01/27/17) H 3555' - 4-1/2'CUT TBG(01/26/17) H 3581' GAS LIFT MANDRELS 10-3/4"CSG,45.5#,L-80,D=9.950' HI 3871' A ' ST MD ND DEV TYPE VLV LATCH PORT DATE ESTMATED TOC PLUG(12/02/16) -{ --6050' .---....../-, -�_ 4 55373 3433 58 KBG2 DMY BK 0 07/03/11 ;� .n_�,* *3 5490 3498 56 KBG2 DMY BK 0 11/21/09 Minimum ID =3.813" @ 2174' s,: *"'441 *2 6645 4068 69 KBG2 DMY BK 0 11/21/09 :40Iti 4-1/2" HES X NIPPLE ; �* e,4 • '1 6888 4157 69 KBG2 E TY BK - 11/22/16 7-518"X 9-7/8"TOC H 5800• 11 : *STA 4,3,2,81=COVERED BY CMT RA TAG -I 6983' e:'t r. --.04e4041 ......w A I I NN i; 4-1/2"SGM NEJPGCA -{ 7035' 9.+.-_..,%* 7061' H4-1/2'BKR CMD SLIDING SLV,D=3.813' MULTI-DROP SUB,ID=3.958" 6.6. A/ *• CA 7087' -I7-5/8"X 4-1/2'BKR PREM PKR,D=3.875" 4-1/2"SGM NDPG CA 7066' `K 7122' H4-1/2"FES X NIP,D=3.813" MULTI-DROP SUB,ID=3.958' 7122' -I4-1/2"PX PLUG(11/05/15) 4-1/Z'TBG,12.6#,13CR 80 VAM TOPH 7250' 7193' 4-1/2"HES X NP,D=3.813" _0158 bpf,D=3.958" 4 RA TAG 7270• II 7264' H4-1/2"X 5-1/2"XO,ID=3.940" 4-1/2'TBG,12.6#L-80 BT-M, 7296' „ ,* 71 7277' -5.75"BKR SEAL STEM i .0152 bpf,ID=3.958" '�; �' (SEALS REMOVED),D=4.83" 5-1/2"X4-1/2"XO,D=3.930" -1 7301' 1115 7282' -I 7-518"X 4-1/2"BKR ZXP LTP w/TEEM,D=5.750" BAKER HOOK HANGER 7315' L2 (OBa) L2(08a)LEM WNDOW 65° w/L2 NON-SEALING LE3M,D=3.71" . 7320'-7331} COLLAPSED LEM-CAN NOT PASS BY -I -7315 OBa PBTD -I 13043'-.N".• OPENING WIDTH=3.33" (SEEN IN D.H.VIDEO)(12/14/12) RA TAG 7375' 7315'-13044' 6-3M'OBa LATERAL,ID=3.958" i 7-5/8"X 5-1/2"BKRZXP LIP,D=4.94" 7386' ! �^ �: 7398' -I4-1/2"MULE SHOE,D=3.958" 5-1/2"X 4-1/2"XO,D=3.930" -{ 7405' k.lir: a L1 (OBb)LEM WINDOW 64° J; 7424'-7435' BAKER HOOK HANGER 7419' ;� L1 (OBb) OPENING WIDTH=3.33" w/L1 NON-SEALING LEI,D=3.71" i'' OBb PBTD -i 12987' PERFORATION SUM/ARV RR LOG= 4' 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958' ANGLE AT TOP PERE: X Note:Refer to Roduction DB for historical pert data 1 7537• -I7-5/8"X 5-1/2'BKR ZXP LNR TOP PKR SIZE SPF INTERVAL Opn/Sqz _ DATE I .IP 4-1/2" SLID OBa 7392-13000 0 02/18/04 I 7548' -14-112"MULE SHOE,D=3.958" 4-1/2" SLTD OBb 7497-12944 0 02/12/04 i 4-1/2" SLID OBd 7870-13008 0 02/04/04 7557• --I 5-1/2"X 4-1/2"XO,D=3.930" RA TAG - 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" -I 7872' OBd I PBTD - 13050' ---__ DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/22/04 N9ES ORIGINAL COMPLETION WELL: L-200 11125/09 D-16 MO FERMI No: 2040010(020)(030) 02/04/17 P272 SUSPENDED ST API No: 50-029-23191-00(60)(61) 02/13/17 Al) DRLG 110 CORRECTIONS SEC 34,T12N,R11E,2567'FSL&1575'Fa 02/13/17 JT/JIRD FINAL ODE APPROVAL BP Exploration(Alaska) • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 03/23/18 Inspector: Guy Cook Operator: BP Exploration Alaska - Well Name: PBU L-200 Oper.Rep: Ryan Holt PTD No.: 2040010 Oper.Phone: 907-659-5297 Location Verified? Yes Oper.Email: rvan.holtObp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 02/05/17 Date AOGCC Notified: 03/22/18 - Sundry No.: 317-066 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: The condition of the wellhead was good. It is a FMC wellhead and shows no signs of leakeage. Typical of an older wellhead,it has some rust and missing paint,but otherwise in good condition. The tree installed on this wellhead was a double swab or otherwise known as a dry-hole tree. Condition of Surrounding Surface The surrounding location was in good condition with no signs of hydrocarbons,but with the location being covered in snow it is Location: impossible to know if there is any hydrocarbons on the actual pad surface. There was some trash and debris in the wellhouse that needs to be removed. Follow Up Actions While the wellhouse sign was present,it had an incorrect PTD#on it. A new well identification sign needs to be installed with the Needed: correct PTD. The trash that was present in the wellhouse needs to be removed. The location should be reinspected once the snow ✓ has melted away to look for signs of hydrocarbons or debris that may be currently buried. Comments: Well location was verified by an existing PBU L-pad map. Attachments: Photos(2) gate REVIEWED BY: Well Schematic ,/ Insp.Supry iff7` 2— )3c'j I Comm PLB 12/2015 2018-0323_Suspend_PBU_L-200_gc,docx • oil - ,'Ifir '__ i It / ,-, -7, 1 j... •r i - ` „. .4 .11++,,C44,"+1-; Iii i s -} . z; i i 11. �_ to �I o ' li o .. al 114 k• 111 cl k..r_'''--.:,,:'' ...'e'iles.":.. GO 0-1N • t CA ' '''.S . -' 4 ,.., • f N 4 • � O N w 1 (D , 1,;., , ......„ 4,..,, . ,,, a ; ,..: ...,,,Ltivi_.,' ,ite7......,14'.,...,..„,........,''.‘,.'_'e .:',7.:. „_, 1., ... . ..„...1.0 .. . . ._,F.1 . _ 0 V N F•.'''•' ••••''' '' - - ' _ • ' n K ' • \` ... RI 0 FH U .414E;:':•,•'•;,.:4}\ y } il G, N 5O N §s f 0.1c:) N ' V1 :1•4a M ,, � . r • LLHEAD= 11'FMC brUbl-itNULI) 49 U _N .. .....„I W. II I I1J1...P1811%.1.1..11.., I..1 ;Lae 1.11JU . G • :TUATOR= BAKER t.1- a L2 --cs •.;..MUG-110MS S- @ 300',420',& B.B_EV= 77.6' , '1,0 0 0'INSIDE THE 10-314"CSG*** F(3.B/= 77.6 I 20#CONO141 1 41----3 985 H10-3/4"TAM FORT COLLAR 8.EV' 4899'._ 4-1/2'KLL STRM H 3362' +3= 380' T12.6413CR-85 ...._____ _ 3362' 4-1/2"MULESHOE,ID=3.958' 1 BG, , x Angle= 96"@ 11569' tum M)= 7515, VAM TOP COND B, _ , 3376' -+°- ' '34BKR wHFSToCK(02302/17) 1 umTv') ..._ 4400.ss .0152 bpf,ID=3,958" —.......---- 3400' 10-3/4'HES EZSV(01/29/17) 7-5/8'CSG CUT(01/27/17) H 3555' 0 4-1/2"CUT TBG(01/26/17) 1— 3581' GAS LFT MANDRELS 10-3/4"CSG,45.54,L-80,D=9,950' H 3871' ST AU 1VD DEV TYPE VLV LATCH PORT DATE *4 5373 3433 58 KBG2 DMY BK 0 07/03/11 ESTSAA TED TOC PLUG(12/02/16) -5050' _ ,,h dui *3 5490 3498 56 KBG2 DMY BK 0 11/21/09 Minimum ID = 3.813" @ 2174' 709 tigipiiliiifjole, '2 6645 4068 69 KBG2 DMY BK 0 11/21/09 4-112" HES X NIPPLE 6888 4157 69 KBG2 ( PWBK - 11/22/16 .4,. 0 421674tik.,,jj 7-518.X 9-718.,TOG H—se--.00. •*NI *STA 4,3,2,&1 ,--COVERS)BY CMT 4%•-N •41;44?•44to 5; ket,,,4 0 .4 itifri. RA TAG 6983' :Al tot,nil Pts:+t, 4-1/2'SGM-NDPG- A 7035' 7061' -t4-1/2 BKR CMD SLIDING SLV,ID=3.813' MULT1-DODPSU3,0=3.958" .1 ri i,9i a al rIt or MA A mg Ai 7087' I-17-5/8'X 4-1/2'BKR FREM PIM,ID=3.875' 4-1/2"SGM-NDPG-CA 7066' A -- _ 7122* —14-1/2"I IM X NP,ID=3.813' 1 MULT1-DROP SUB,ID=3.958" b_4 A 7122' --I 4-1/2"PX PLUG(11/05/15)j 4-1/2'TBG,12,6#,13CR-80 VAM TOP 7250' flA 4. tiOtij 7193' —1±1/2'HES X NP.ID=3.813"j .0158 bpf,ID=3.958" kA, RA TAG 7270' X 0 7264' —14-1/2"X 5-1/2-XO,ID=3.940' 1 ; " K 4-1/2'TBG,12.6#L-80 I3T-M, 7296' 14 i MEM—5.75"BKR SEAL STEM Akur...1, ... alP (SEALS fTiVOVED),ID=4,83' .0152 bpf,ID=3.958' ,;P.'4 iii to,-, sol 13 5-1/2'X 4-1/2"XO,ID=3,930" 7301' 7282' 7-5/8"X 4-1/2"BKR ZXP LTP w/TEBK,ID=5.750' ykil -1 - - L2 (0Ba) _ - - - _ - - - - - - — L2(0Ba)LEM VVNDOVV 6! BAKER HOOK HANGER 7315' e; ,, P •,1: ,4 . w 7320'-7331' w 1 L2 NON-SEALING LEM,ID=3 71" COLLA PSED LOA-CAN NOT PASS BY -7315 2 ,. , .. . otia PBTD — OPENING WIDTH-7 3 33 13043' (SEEN IN D.H.VIDEO)(12/14/12) _,,5; •;1 v 6 RA TAG 7375* 7 3 1 5'-1 3 044' 6-3/4"OBa LATERAL,ID=3.958' ..• 0 7-5/8"X 5-1/2'BKR ZXP LTF',ID=4.94' 7386' ' I olii ii?;,. MEM--I4-1/2"MULESHOE,ID=3.958' i ) 5-1/2"X 4-1/2"X0,ID=3,930' 7405' 0 illerg L1 (OBb)LEM WNDOW 6, kAti 7424'-7435' BAKER HOOK HANGER 7419' 4 9 Ll (OBb) ,..,, ,,,, _ _ _ _ _ _ _ _ _ _ _ _ OPENING WIDTH=3.33" w/L1 NON-SEALING LEM,ID=3 71" . :A A OBb PBTD --I 12987' 4 0 A PERFORATION SUMMARY X 5; REF LOG: 11 0 7 4 1 9'-12988' 6-3/4"OBb LA I ERAL,ID=3.958" 4 ANGLE AT TOP PEFF: X I* to 1,' k• Note:Refer to Production DB for historical pert data *di W IA 24 _7.: 7637= -17-5/8'X 5-1/2"BKR ZXP LNR TOP PKR SIZE SPF INTERVAL Opn/Sqz DATE til IIIII 414 -1/7 SLTD OBa 7392-13000 0 02/18/04 * 7548' —4-1/2"MULE SHOE,D=3.958" -1/2" SLTD OBb 7497- 12944 0 02/12/04 5, P. -1/2' SLTD OBd 7870- 13008 0 02/04/04 i re 755T H 5-1/2'X 4-1/2"X0,ID=3.930' RA TAG 7663' if iL-200; 7 5 72'-1 3 05 2' 6-3/4'OBd LATERAL,ID=3.9 5 8" 5/8'CSG,29.7#,L-80 BTC-M,13=6.875' —1 7872' OBd PBTD — 13050' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02/22104 . N9E6 ORIGINAL COMPLETION WELL L-200 11/25/09 0-16 IMO PBRMI Na: 2040010(020)(030) 02/04117 P272 SUSPENDED ST API Na: 50-029-23191-00(60)(61 02/13/17 AID DRLG 1-10 COWECT1ONS SEC 34,T12N,R11E.2567 FSL&1575'FE1. 02/13/17 JT/JPA) PNAL ODE APPROVAL CID ForkInr-a4inft • • PTD �a4--0v ) Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Wednesday, March 21, 2018 2:07 PM To: Regg,James B(DOA) Cc: Loepp,Victoria T(DOA);AK, GWO SUPT Well Integrity Subject: BPXA PBU L-200(PTD 2040010) is overdue for its initial inspection Follow Up Flag: Follow up Flag Status: Flagged Good afternoon Jim, + Rfra°y _ ; ; I left a message on your office phone this afternoon. BPXA has identified a suspended well PBU L-200(PTD 2040010)that is overdue for it's initial inspection.We are investigating the gap but at this stage it looks like it was attributed to internal communication& handover,following an unusual filing post drilling(i.e No Operations shut-down period after drilling difficulties-well went directly to SU status post aborted drilling plans) I have since verified our records against the AOGCC's and find no other anomalies. Apologies for the oversight. I have requested the Slope WI team to request/schedule an inspection at the first available opportunity. Sincerely Ryan Ryan J C Daniel Well Engineering Team Leader GWO Alaska Wells Integrity&Compliance BP Exploration(Alaska)Inc. Office+1907 564 5430 Mobile+1907 7481140 4 . Pr I rd true PROUD ,..„. Pioneering MePost FuIAN AlosAohFuture 1 Schiumberger il Cementing )o•Report CemCATv1.7 Well NK-26A ' Client BP Field GPB SIR No. Engineer Dylan Waugh Job Type 7in Intermediate Liner Country United States Job Date 03-20-2018 Time 0/20/1013.101 1 Treating Pressor Rate Density WHP Messages 1_ 03:10:13 ; Started Acquisition On loc 0230 Rigged up 0300 03:35:00 \ Started Acquisition I Reset Total,Vol=2.34 bbl Started Acquisition 04:00:00 Started Acquisition Reset Total,Vol=2.14 bbl I . h head rate checks 3bpm Iii g head rate checks 3 bpm 04:25:00 Reset Total,Vol=3.10 bbl Rate checks good Reset Total,Vol=3.18 bbl Having issues writing to wits-shL • 04:50:00 05:15:00 05:40:00 CMT line blown down , �� PJSM Complete PXcheck w/pumper '.. Line up to pump 5 bbls FW to blee Uned up to pump across to pits On 5 bbls FW 06:05:00 11 Low PT Iron leak tight High PT 4000 psi 7.4 gal D177 added to MW Trips verified 4000 psi Trips verified 2100 psi Batch 12 ppg MP L Reset Total,Vol=5.8 bbl 06:30:00 Uned up to well 1 / On 30 bbls 12 ppg MP MP sample taken MixH2O Sample taken FW sample taken Drop bottom dart Reset Total,Vol=30.3 bbl 06:55:00 F Vac out tub for CMT CMT wet Kicked out dart 2 bpm Dart dropped On 96.6 bbls 15.8 cmt Swap to 18826 ABT Mudscale verified 15.8 07:20:00 MW tracking with CMT ABT bottle swap MW still tracking . Finished mixing CMT Reset Total,Vol=96.6 bbl Finished cmt Top dart dropped 07:45:00 Finish 10 bbls H2O 10 bbls FW away Line up rig for disp Reset Total,Vol=10.0 bbl CMT line blown down Bot plug latched 327 stks-37 stk Rig displacing 7 bpm 08:11:19 Slow 3 bpm at 1250 stks away Top dart latch 1280 stks away Slow 2 bpm for bottom plug bump hh:mm:ss 0.00 1000 2000 3000 4000 5000 0.00 2.0 4.0 6.0 8.0 10.0 5.0 7.6 10.2 12.0 15.4 16.0 0.00 1000 2000 3000 4000 5000 o0/10/20111 ocII:,s PSI B/M LB/G PSI 03/20/2018 11:35:30 • Cementing p Serer, Re ort Schlumberger Customer Sob Number BP r well Location(legal) Schlumberger Location lab Start NK-26A NK-26A Niakuk Prudhoe Other Mar/20/2018 Field Formation Name/Type Deviation 1 Bit Size Well MD Weil IVO GPB deg in 12965.0 ft 9071.0 ft County Beechey Point Mate/Province Alaska BHP BHST BMC► Pore Press.Gradient well Master API/uWI psi 181 degF 136 degF lb/gal Rig Name DrWed For Service Vla Casino/Liner Parker 272 Oil&Gas Land Depth,ft Size,In Weight,lb/ft Grade Thread Offshore Zone Was Chas Well Type New Development Drilling Bund Type Max.Density Plastic Viscosity -..__... Tubing/Drip Pipe - Ib/gal cP T/D Depth,ft Size,in Weight.lb/ft Grade Thread Service Line Jeb Type ..-- Cementing 7in Intermediate Liner Max.Allowed Tub.Press Max.Allowed Ann.Press WN Connection Perforations/Open Hole PSI ini Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions - ft ft ft Pump . Batch Mixer ft R' Diameter ABT x2 ft ft In Treat Dawn Displacement Packer Type Packer Depth Dri Well Mel. lob Start Customer• lob Number NK-26A NK-26A GPB Mar/20/2018 BP baba Tim. Treating Dondty Rets Stage Total WISP Massage 24-hr Pressure L8/6 S/N Volume Volume PSI dock PSI SSL SSL 03/20/2018 04:16:53 -20 8.34 0.0 3.2 3.2 54 03/20/2018 04:16:58 -20 8.21 0.0 3.2 3.2 56 Reset Total,Vol m 3.10 bbl 03/20/2018 04:18:33 -56 8.34 0.0 3.3 3.3 -13 03/20/2018 04:19:13 14 8.34 0.0 3.3 3.3 34 Rate checks good 03/20/2018 04:19:18 14 8.34 0.0 3.3 3.3 7 Reset Total,Vol @ 3.18 bbl 03/20/2018 04:20:13 14 8.34 0.0 0.0 0.0 47 03/20/2018 04:21:53 14 8.34 0.0 0.0 0.0 29 03/20/2018 04:23:33 14 8.34 0.0 0.0 0.0 61 03/20/2018 04:24:32 14 8.34 0.0 0.0 0.0 -17 Having issues writing to wits-shuts down CemCAT 03/20/2018 04:25:13 15 8.34 0.0 0.0 0.0 -117 03/20/2018 04:26:53 15 8.34 0.0 0.0 0.0 -31 03/20/2018 04:28:33 15 8.34 0.0 0.0 0.0 -19 03/20/2018 04:30:13 15 8.34 0.0 0.0 0.0 -70 03/20/2018 04:31:53 14 8.34 0.0 0.0 0.0 -19 03/20/2018 04:33:33 15 8.34 0.0 0.0 0.0 -38 03/20/2018 04:35:13 14 8.34 0.0 0.0 0.0 -18 03/20/2018 04:36:53 15 8.34 0.0 0.0 0.0 -56 03/20/2018 04:38:33 15 8.34 0.0 0.0 0.0 -68 03/20/2018 04:40:13 15 8.34 0.0 0.0 0.0 -18 03/20/2018 04:41:53 14 8.34 0.0 0.0 0.0 -54 03/20/2018 04:43:33 15 8.34 0.0 0.0 0.0 -14 03/20/2018 04:45:13 15 8.34 0.0 0.0 0.0 -34 03/20/2018 04:46:53 15 8.34 0.0 0.0 0.0 -65 03/20/2018 04:48:33 15 8.34 0.0 0.0 0.0 , 48 03/20/2018 04:50:13 15 8.34 0.0 0.0 0.0 -48 03/20/2018 04:51:53 15 8.34 0.0 0.0 0.0 -14 03/20/2018 04:53:33 14 8.34 0.0 0.0 0.0 -19 03/20/2018 04:55:13 15 8.34 0.0 0.0 0.0 -57 03/20/2018 04:56:53 15 8.34 0.0 0.0 0.0 -13 03/20/2018 04:58:33 16 8.34 0.0 0.0 0.0 -47 03/20/2018 05:00:13 15 8.34 0.0 0.0 0.0 -8 03/20/2018 05:01:53 15 8.34 0.0 0.0 0.0 -16 03/20/2018 05:03:33 15 8.34 0.0 0.0 0.0 -54 03/20/2018 05:05:13 15 8.34 0.0 0.0 0.0 -13 03/20/2018 05:06:53 15 8.34 0.0 0.0 0.0 -36 03/20/2018 05:08:33 15 8.34 0.0 0.0 0.0 -53 03/20/2018 05:10:13 15 8.34 0.0 0.0 0.0 -14 03/20/2018 05:11:53 15 8,34 0.0 0.0 0.0 -50 03/20/2018 05:13:33 14 8.34 0.0 0.0 0.0 -10 03/20/2018 05:15:13 13 8.34 0.0 0.0 0.0 -40 ' 03/20/2018 05:16:53 15 8.29 0.0 0.0 0.0 -61 03/20/2018 05:18:33 14 8.29 0.0 0.0 0.0 -14 03/20/2018 05:20:13 14 8.29 0.0 0.0 0.0 -45 03/20/2018 05:21:53 14 8.29 0.0 0.0 0.0 -8 03/20/2018 05:23:33 14 8.28 0.0 0.0 0.0 -12 03/20/2018 05:25:13 14 8.28 0.0 0.0 0.0 -56 03/20/2018 05:26:53 14 8.28 0.0 0.0 0.0 -12 03/20/2018 05:28:33 14 8.28 0.0 0.0 0.0 -39 03/20/2018 05:30:13 14 8.28 0.0 0.0 0.0 -11 03/20/2018 05:31:53 14 8.28 0.0 0.0 0.0 -17 03/20/2018 05:33:33 14 8.28 0.0 0.0 0.0 -53 03/20/2018 05:35:13 14 8.28 0.0 0.0 0.0 -12 03/20/2018 05:36:53 14 8.27 0.0 0.0 0.0 -39 03/20/2018 05:38:33 14 8.27 0.0 0.0 0.0 -55 Page 2af5 • • Well Rel. lob Start Customer• lob Number NK-26A NK-26A GPB Mar/20/2018 BP Data Time Treating Density Rate Stage Total WNP Message 24-hr Pressure LB/A B/M Volume Volume PSI Mock PSI B81. 881. 03/20/2018 05:39:12 14 8.27 0.0 0.0 0.0 -50 P SM Complete 03/20/2018 05:39:23 14 8.27 0.0 0.0 0.0 -35 PXchedc w/pumper 03/20/2018 05:40:13 15 8.27 0.0 0.0 0.0 -14 03/20/2018 05:41:53 14 8.27 0.0 0.0 0.0 -51 03/20/2018 05:43:33 15 8.27 0.0 0.0 0.0 -12 03/20/2018 05:44:12 14 8.27 0.0 0.0 0.0 -59 Line up to pump 5 bbls FW to bleeder/pats 03/20/2018 05:45:13 15 8.27 0.0 0.0 0.0 -4 03/20/2018 05:46:53 23 8.31 0.0 0.0 0.0 -207 03/20/2018 05:48:33 38 8.33 0.0 0.0 0.0 -225 03/20/2018 05:49:59 26 8.34 0.0 0.0 0.0 -214 Lined up to pump aCioes to pits 03/20/2018 05:50:13 25 8.34 0.0 0.0 0.0 -217 03/20/2018 05:50:58 54 8.33 1.8 0.4 0.4 -212 On 5 bbls FW 03/20/2018 05:51:53 125 8.34 3.2 3.3 3.3 -172 03/20/2018 05:53:33 21 8.34 0.0 5.2 5.2 -222 03/20/2018 05:55:00 21 8.40 0.0 5.2 5.2 -17 Low PT 03/20/2018 05:55:13 40 8.33 0.9 5.3 5.3 -13 03/20/2018 05:56:24 555 8.31 0.0 5.5 5.5 473 Iron leak tight 03/20/2018 05:56:53 548 8.31 0.0 5.5 5.5 464 03/20/2018 05:57:00 546 8.31 0.0 5.5 5.5 462 High PT 4000 psi 03/20/2018 05:58:33 4118 8.30 0.0 5.6 5.6 3869 03/20/2018 06:00:13 4051 8.14 0.0 5.6 5.6 3981 03/20/2018 06:01:53 4010 8.10 0.0 5.6 5.6 3941 03/20/2018 06:01:54 4010 8.10 0.0 5.6 5.6 3941 7.4 gal 0177 added to MW 03/20/2018 06:03:33 3974 8.08 0.0 5.6 5.6 3909 03/20/2018 06:03:44 3970 8.08 0.0 5.6 5.6 3905 Trips verified 4000 psi 03/20/2018 06:05:13 88 8.08 0.0 5.6 5.6 564 03/20/2018 06:06:15 71 7.98 0.0 5.6 5.6 514 Trips verified 2100 psi 03/20/2018 06:06:44 -5 7.95 0.0 5.6 5.6 -46 Batch 12 ppg MP 03/20/2018 06:06:53 -2 7.94 0.0 5.6 5.6 -47 03/20/2018 06:07:12 -0 7.96 0.0 5.6 5.6 -48 Reset Total,Vol m 5.8 bbl 03/20/2018 06:08:33 281 7.86 0.0 0.0 0.0 -46 03/20/2018 06:10:13 291 3.36 0.0 0.0 0.0 228 03/20/2018 06:11:53 297 11.15 0.0 0.0 0.0 174 03/20/2018 06:13:33 301 12.03 0.0 0.0 0.0 129 03/20/2018 06:14:22 309 11.96 0.2 0.0 0.0 174 Lined up to well 03/20/2018 06:14:32 59 11.96 1.7 0.0 0.0 176 On 30 bbls 12 ppg MP 03/20/2018 06:15:13 709 11.95 4.9 24 2.1 673 03/20/2018 06:16:53 682 12.08 5.0 10.5 10.5 688 03/20/2018 06:18:29 626 12.05 5.0 18.5 18.5 646 MPm sa pie taken 03/20/2018 06:18:33 634 12.06 5.0 18.8 18.8 647 03/20/2018 06:18:40 636 12.06 5.0 19.4 19.4 643 MixH2O Sample taken 03/20/2018 06:19:05 617 12.11 5.0 21.5 21.5 635 FW sample taken 03/20/2018 06:20:13 592 12.13 5.0 27.2 27.2 563 03/20/2018 06:21:34 62 12.09 0.0 30.3 30.3 191 Drop bottom dart 03/20/2018 06:21:53 62 12.09 0.0 30.3 30.3 193 03/20/2018 06:22:19 62 12.09 0.0 30.3 30.3 17 Reset Total,Vol mm 30.3 bbl 03/20/2018 06:23:33 62 12.08 0.0 0.0 30.3 18 03/20/2018 06:24:29 62 12.08 0.0 0.0 30.3 19 Vac out tub for CMT 03/20/2018 06:25:13 63 12.08 0.0 0.0 30.3 18 03/20/2018 06:26:16 63 12.08 0.0 0.0 30.3 17 CMT wet 03/20/2018 06:26:53 63 12.08 0.0 0.0 30.3 20 03/20/2018 06:28:33 63 0.26 0.0 0.0 30.3 17 03/20/2018 06:30:13 63 15.45 0.0 0.0 30.3 18 • 03/20/2018 06:31:53 64 15.66 0.0 0.0 30.3 16 Page 3of5 411 + Waft Fleld• lob Start Customer Job Number NK-26A NK-26A GPS Mar/20/2018 BP Data Time Treating Density Rate Stage Total WHP Message 24-hr Pressure to/a a/M Volume Volume PSI dock PSI pal. Sai. 03/20/2018 06:33:33 965 15.69 5.0 2.7 33.0 616 03/20/2018 06:33:40 938 15.68 5.0 3.3 33.6 694 Dart dropped 03/20/2018 06:34:15 848 15.71 5.0 6.2 36.5 629 On 96.6 bbls 15.8 ant 03/20/2018 06;34;39 524 15.65 3.9 7.9 38.2 424 Swap to 18826 ABT 03/20/2018 06:35:13 492 15.61 3.7 10.1 40.3 379 03/20/2018 06:36:08 725 15.61 4.8 14.2 44.5 491 Mudscale verified 15.8 03/20/2018 06:36:53 624 15.65 4.8 17.9 48.2 469 03/20/2018 06:38:33 661 15.87 4.9 26.3 56.6 449 03/20/2018 06:39:05 640 15.86 5.0 29.0 59.3 394 MW tradcing with CMT 03/20/2018 06:40:13 632 15.73 5.0 34.7 65.0 405 03/20/2018 06:41:53 632 15.70 5.0 43.1 73.4 374 03/20/2018 06:43:33 639 15.73 5.1 51.6 81.8 379 03/20/2018 06:43:49 640 15.70 5.1 52.9 83.2 366 ABT bottle swap 03/20/2018 06:45:13 492 15.69 4,4 59.7 90.0 312 03/20/2018 06:46:53 655 15.73 5.1 68.0 98.3 403 03/20/2018 06:47:33 637 15.73 5.1 71.4 101.7 404 MW still tracking 03/20/2018 06:48:33 650 15.71 5.1 76.4 106.7 363 03/20/2018 06:50:13 646 15.69 5.1 84.9 115.1 391 03/20/2018 06:51:52 638 15.72 5.1 93.2 123.5 396 Finished mixing CMT 03/20/2018 06:51:53 649 15.72 5.1 93.3 123.6 396 03/20/2018 06:52:57 79 15.63 0.0 96.6 126.8 144 Reset Total,Vol=96.6 bbl 03/20/2018 06:53:09 79 15.59 0.0 0.0 126.8 103 Finished ant 03/20/2018 06:53:33 78 15.57 0.0 0.0 126.8 18 03/20/2018 06:54:55 477 10.52 4.4 1.3 128.1 87 Top dart dropped 03/20/2018 06:55:06 342 9.58 5.1 2.2 129.0 181 Finish 10 bbls H2O 03/20/2018 06:55:13 287 9.07 5.0 2.8 129.6 118 03/20/2018 06:56:53 43 8.35 0.0 10.0 136.9 -6 03/20/2018 06:56:59 41 8.35 0.0 10.0 136.9 -3 10 bbls FW away 03/20/2018 06:57:08 41 8.36 0.0 10.0 136.9 -4 tine up rig for disp 03/20/2018 06:58:33 34 8.34 0.0 10.0 136.9 232 03/20/2018 07:00:13 19 8.32 0.0 10.0 136.9 328 03/20/2018 07:01:04 14 8.32 0.0 10.0 136.9 318 Reset Total,Vol=10.0 bbl 03/20/2018 07:01:12 14 8.32 0.0 0.0 136.9 303 CMT line blown down 03/20/2018 07:01:53 14 8.32 0.0 0.0 136.9 338 03/20/2018 07:03:33 14 8.30 0.0 0.0 136.9 315 03/20/2018 07:04:05 14 8.30 0.0 0.0 136.9 194 Sot plug latched 327 stks-37 stks late 03/20/2018 07:04:55 14 8.30 0.0 0.0 136.9 348 Rig displacing 7 bpm 03/20/2018 07:05:13 14 8.30 0.0 0.0 136.9 308 03/20/2018 07:06:53 13 8.30 0.0 0.0 136.9 502 03/20/2018 07:08:33 13 8.30 0.0 0.0 136.9 551 03/20/2018 07:10:13 13 8.30 0.0 0.0 136.9 583 03/20/2018 07:11:53 13 8.30 0.0 0.0 136.9 610 03/20/2018 07:13:33 13 8.30 0.0 0.0 136.9 595 03/20/2018 07:15:13 13 8.29 0.0 0.0 136.9 622 03/20/2018 07:16:34 13 8.29 0.0 0.0 136.9 143 Slow 3 bpm at 1250 stks away 03/20/2018 07:16:53 13 8.29 0.0 0.0 136.9 52 03/20/2018 07:17:49 13 8.29 0.0 0.0 136.9 239 Top dart latch 1280 stks away 03/20/2018 07:18:33 13 8.29 0.0 0.0 136.9 649 03/20/2018 07:20:13 13 8.29 0.0 0.0 136.9 690 03/20/2018 07:21:53 13 8.29 0.0 0.0 136.9 675 03/20/2018 07:23:33 13 8.29 0.0 0.0 136.9 694 03/20/2018 07:25:13 13 8.29 0.0 0.0 136.9 715 03/20/2018 07:26:53 14 8.29 0.0 0.0 136.9 565 03/20/2018 07:28:33 14 8.29 0.0 0.0 136.9 577 Page 4 of 5 r ' • Well Field. Job Start Customer Job Number NK-26A NK-26A GPB Mar/20/2018 BP Date lime Treating f Density Rah Stage Total WWI Message 24-hr Pressure LB/G B/M Volume Volume PSI dock PSI BBL SRL 03/20/2018 07:30:13 13 8.29 0.0 0.0 136.9 46 03/20/2018 07:31:53 13 8.27 0.0 0.0 136.9 46 03/20/2018 07:33:33 14 8.24 0.0 0.0 136.9 45 03/20/2018 07:35:13 13 8.34 0.0 0.0 136.9 66 , 03/20/2018 07:36:18 13 8.34 0.0 0.0 136.9 786 Bottom plug 2324 stks away 03/20/2018 07:36:53 13 8.34 0.0 0.0 136.9 89 03/20/2018 07:36:59 14 8.34 0.0 0.0 136.9 98 Disp 7 bpm 03/20/2018 07:37:40 13 8.34 0.0 0.0 136.9 896 Lift press-Reciprocate pipe 03/20/2018 07:38:33 13 8.34 0.0 0.0 136.9 956 03/20/2018 07:40:13 13 8.34 0.0 0.0 136.9 1072 03/20/2018 07:41:53 13 8.33 0.0 0.0 136.9 1251 03/20/2018 07:43:33 13 8.34 0.0 0.0 136.9 1362 03/20/2018 07:45:13 13 8.34 0.0 0.0 136.9 1472 03/20/2018 07:46:53 13 8.35 0.0 0.0 136.9 1568 03/20/2018 07:48:33 14 8.34 0.0 0.0 136.9 1636 03/20/2018 07:49:58 14 8.34 0.0 0.0 136.9 1005 Slow to 2 bpm for bump 03/20/2018 07:50:13 14 8.34 0.0 0.0 136.9 1395 03/20/2018 07:50:34 14 8.34 0.0 0.0 136.9 1559 Bump 3296 stks away 03/20/2018 07:51:16 14 8.34 0.0 0.0 136.9 1537 Hold pressure S min 03/20/2018 07:51:53 14 8.34 0.0 0.0 136.9 1541 03/20/2018 07:53:33 12 8.34 0.0 0.0 136.9 1549 03/20/2018 07:55:10 12 8.17 0.0 0.0 136.9 1544 Bleed off check floats 03/20/2018 07:55:13 12 8.13 0.0 0.0 136.9 1546 03/20/2018 07:56:53 14 7.94 0.0 0.0 136.9 96 03/20/2018 07:58:33 14 7.90 0.0 0.0 136.9 -2 03/20/2018 08:00:13. 14 7.87 0.0 0.0 136.9 -17 03/20/2018 08:01:53 104 7.87 0.0 0.0 136.9 -55 03/20/2018 08:03:33 102 8.30 0.0 0.0 136.9 -55 03/20/2018 08:04:03 103 8.27 0.0 0.0 136.9 -55 Floats holding 03/20/2018 08:05:13 101 8.34 0.0 0.0 136.9 -56 03/20/2018 08:06:53 99 8.34 0.0 0.0 136.9 -56 03/20/2018 08:07:12 99 8.24 0.0 0.0 136.9 -56 Wash up/Rig down 03/20/2018 08:07:28 99 8.18 0.0 0.0 136.9 -56 CMT in place 0755 03/20/2018 08:08:28 99 8.13 0.0 0.0 136.9 -56 Rig to set liner packer and release from DP 03/20/2018 08:08:33 99 8.13 0.0 0.0 136.9 -56 03/20/2018 08:10:13 87 8.13 0.0 0.0 136.9 -56 Post Job Summary Average Pump Rates,bbl/min Volume of Fluid Injected,bbl Slurry 112 Mud Maximum Rate Total Slurry Mud Spacer 112 4.4 0.0 5.4 96.6 0.0 30.3 Treating Pressure Summary,pal Breakdown Fluid _ Maximum Final Average Bump Plug to Breakdown Type Volume Density 4123 143 235 1500 bbl Ib/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? El Volume bbl % 96.6 bbl 314.9 bbl 80 degF Washed Thru Parts El To ft Customer or Authorized Representative Schlumberger Supervisor Circulation toot 111 Job Completed 0 loss Hartley Dylan Waugh - - Page 5 of 5 WI"W • • OiW ~ > Qpm r x � .,, co -0-o t6 N0 OC a- c6 )• ;...• O +`�-+ QJ O U a Q c c 4 f6 -, "0 C y , -6 C -o Q@ v 0 o It r U Y Q 02 Q W (. 7 E * c - O In Q 0 c 6 N 16 _ c J O C C U N 2 c1 I- M 0 @ 4-, i C U v> Z Q 0 v -o v m 6 'u O C L 0 a) QJ '6 N U O c L v p `- J °° c 4- U O W 0 Cl.) 'L LLa) Q a) > t v _ C +-+ . t) Q Q N N 4- L Z 0s) Q Z U ro aJ O E ro• ° ° o U o M Z 0 L) v O CO6 ti4 > ,.-, U @ U Y U C O I- > U N # O U K a a) a a o Cl CC z U . cr > 0 W N . w 0 .- J 1— V cc • r�o�Z m U N op mdS KC -.7-_-_ A N 1 OaO c Z CI x c0 a1 t-, W O U.1 g al - 0000 t — a Z g (0 ooMc > oe 3 I Z z a r � �, dt W1" ; Qd P W 2 z Q O z 0IT 4 c...J. 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Well Status: Oil ❑ Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0. 1b.Well Clasg �4" '' 20AAC 25.105 20AAC 25.110 4 5.��,r Development 0 Exploratory GINJ 0 WINJ ❑ WAG ❑ WDSPL 0 No.of Completions: Zero Service ❑ 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 . 204-001 • 317-066 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 1/19/2004. 5042943191-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/2/2004 PBU L-200 • Surface: 2568'FSL,3704'FEL,Sec.34,T12N,R11E,UM ' 9 Ref Elevations KB 77 6 17. Field/Pool(s): 2215'FSL,3673'FEL,Sec.27,T12N,R11E,UM GL 49.1 BF 48,99 PRUDHOE BAY/ • Top of Productive Interval: SCHRADER BLUFF OIL Total Depth: 270'FSL,2501'FEL,Sec.21,T12N,R11E,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/TVD): 19. Land Use Permit: Surface:x- 583209• y- 5978290 • Zone - ASP 4 . 13067'/4367'• 00-001 TPI: x- 583177 y- 5983216 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 579026 y- 5986506 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 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) N/A 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,MWD/GR/RES/DEN/NEU/PWD,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 TOP BOTTOM TOP BOTTOM PULLED 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' 7872' 2502' 4496' 9-7/8" 515 sx Class'G' 3526' 4-1/2" 12.6# L-80 7282' 7548' 4313' 4424' Tieback Uncemented Tieback Liner 4-1/2" 12.6# L-80 7537' 13052' 4420' 4367' 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. Was hydraulic fracturing used during completion? Yes 0 No 0 • Per 20 AAC 25.283(i)(2)attach electronic and printed information Z 4 ;,' .ji‘,I! 3 F ;if j/i 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 ....► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate "". Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only V7`L '/2//g ,/tf B®i�S L - 2017 ,'-''"b (7-(3,/7 28. CORE DATA 110 Conventional Core(s) Yes 0 No 0 • • Sidewall Cores Yes 0 No t 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 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 7728' 4424' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 4201' 2847' Schrader Bluff NA 6787' 4130' Schrader Bluff NB 6847' 4152' Schrader Bluff NC 6956' 4192' Schrader Bluff OA 7186' 4274' Schrader Bluff OBa 7319' 4329' Schrader Bluff OBb 7425' 4374' Schrader Bluff OBc 7549' 4424' Schrader Bluff OBd 7728' 4474' Schrader Bluff OBc(Invert) 12930' 4369' • Formation at total depth: z t&G�f Cd 1U`QC" o�� (x04.1 1 C9a 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 //�► Title: Drilling Technologist Signature: J ne: +1 907 564 4091 Date: 3/6`+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 lb.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 TVD 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 • • WELL NAME: L-200 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-200 Well History (Pre-Rig Sidetrack) L-200 ACTIVITYDATE SUMMARY T/I/0=350/560/200, Temp=Sl. 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-200 Well History (Pre-Rig Sidetrack) L-200 ***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-200 Well History (Pre-Rig Sidetrack) L-200 T/I/0 = SSVNac/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/0 = 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 until) 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/0 = 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/0 = 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/0 = TWC/Vac/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/0 = 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/0 = 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. • S North America-ALASKA-BP Page 1 of 23 Operation Summary Report Common Wet 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. BPUOI: Active datum:L-200A ACTUAL RKB(095.7ft(above Mean Sea Level) Date From-To I Hrs ' Task Code i NPT NPT Depth I Phase j Description of Operations (hr) (ft) 1/24/2017 18:00 - 21:00 3.00 1 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 i -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 i ON DRILL MODULE: j-CUT LOWLIINEANDINSTALLREDUNDANT FLOW -WORK ON BLIND SHEAR RAM CHAMBERS, REPLACING SEALS. 1/25/2017 00:00 - 02:30 2.50 I MOB I P I PRE MOVE UTILITY MODULE AND STAGE ON FAR END OF PAD. CONTINUE PERFORM WELDING AND REPAIR PROJECTS ON DRILL MODULE: -CUT FLOWLINE AND INSTALL REDUNDANT FLOW METER -WORK ON BLIND SHEAR RAM CHAMBERS, REPLACING SEALS. 02:30 - 06:30 4.00 1 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 *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 2 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) 16:30 - 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 FLOWLINE AND HOLE FILL LINES INSTALL LOW PRESSURE RISER AND FLOW BOX INSTALL TURN BUCKLES ON STACK AND AIR UP AIR BOOTS 1I-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 I 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,PVT AND 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 Operation Summary Report Common Well Name:L-200 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/24/2017 End Date: 1X3-017P7(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 @95.7f1(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 I 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-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 22:00 1.50 PULL P DECOMP RIG DOWN AND 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 PSI -CONTINUE TO ROTATE FOR AN ADDITIONAL 20 MINS Printed 2/22/2017 10.52.30AM `AII depths reported in Drillers Depths* 110 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 I 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) 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 PILL AND 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 1 REMAINDER OF CIRCULATION I-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 1 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 *All 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 I 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 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 *All depths reported in Drillers Depths* . S 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 i 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) 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 1-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 I ASSEMBLY FROM 270'TO 900'MD ON ELEVATORS -NO ISSUES RUNNING TO 900'MD(DEEPEST 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 I RUN IN HOLE FROM SURFACE TO 265'MD -PICKUP 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 *All 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©J95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 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 CREW AND 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* i • North America-ALASKA-BP Page 9 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) 1/30/2017 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 -PU55K/S057K -MONITOR DISPLACEMENT W/TRIPTANK; GOOD DISPLACEMENT Printed 2/22/2017 10:52:30AM *All depths reported in Drillers Depths* • S 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 I 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 I Phase Description of Operations (hr) (ft) 16:00 - 17:00 1.00 CLEAN N DPRB 409.6 WEXIT WASH DOWN WITH DRIFT ASSEMBLY FROM 266'MD TO 298'MD -7 BPM;50 PSI -OBSERVE 3K DRAG FROM 266'MD TO 298' MD -SET DOWN 10KAT 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 PICK UP AND MAKE UP SLB DRIFT ASSEMBLY WITH TWO 9.75"OD STRING STABILIZERS -PU65K1SO65KAT367'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 I 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 I DISPLACEMENT Printed 2/22/2017 10:52:30AM `AII depths reported in Drillers Depths' • • North America-ALASKA-BP Page 11 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 I 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 i 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 I 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 I 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 -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 IAND CALCULATOR Printed 2/22/2017 10.52.30AM `All depths reported in Drillers Depths* • North America-ALASKA-BP Page 12 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 - 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 WHIPSTOCKAND 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 PICK UP 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: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) 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"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 Printed 2/22/2017 10:52:30AM *AII 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. BPUOI: Active datum:L-200A ACTUAL RKB©95.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 09:30 1.00 CLEAN N DPRB 409.6 WEXIT PERFORM FLOW CHECKAT SURFACE TO ENSURE WELLBORE IS STATIC.FLUID LEVEL WAS RISING VERY SLOWLY SUCH THATA 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 @95.7ft(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 j 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 - 409.6 WEXIT MAKE UP 9-3/4"BAKER WINDOW MILL/ 19:00 21:00 2.00 CLEAN N DPRB 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 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* 1110 • 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"HWDPAND DRILL COLLARS AND LAY DOWN 9-3/4"BAKER WINDOW MILL/ WHIPSTOCK RUNNING DRIFT ASSEMBLY FROM 860'MD TO SURFACE -CHANGE OUT MWD AND TESTAT 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 -RUN IN HOLE PER BAKER REP AND PROCEDURE WITH MAXIMUM SLACK OFF WEIGHT SET AT 3K LBS DOWN -TRIPPING LIMITS:30 FPM FROM SURFACE 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 `AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 17 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) 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 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 SETAND 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 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 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"HWDP AND 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 *AII 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-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 - 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 SHOWALARMS -FUNCTION TEST HIGH BYPASS AND ALL BOP COMPONENTS FROM BOTH REMOTE PANELS -TESTED AND VERIFIED ESD FUNCTIONING PROPERLY -FUNCTION TESTANNULAR 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 1-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 `AII 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-200A ACTUAL 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 I 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"HWDPAND DRILL COLLARS, I 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 I 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 *All depths reported in Drillers Depths* North America-ALASKA-BP Page 20 of 23 v $ Operation Summary Report Common Well Name:L200 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 I 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) j-PICKUP 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. 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 l 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 I 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 *AII 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 PICKUP ABOVE.PRESSURE TEST TO 500 PSI FOR 5 MIN(PASS) 02:00 - 03:00 1.00 STWHIP N DPRB 1,001.0 WEXIT PULL OUT 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 *AII depths reported in Drillers Depths* • • 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 Firs Task Code NPT NPT Depth Phase Description of Operations (hr) I (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 SYSTEM 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 1- 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 I 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 -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 1-RIG DOWN PRESSURE TEST EQUIPMENT Printed 2/22/2017 10:52:30AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 23 of 23 s5 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 I Task Code NPT NPT Depth Phase Description of Operations (hr) (6) 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 UP ADAPTER FLANGE AND DRY HOLE TREE -CLEAN AND INSPECT CONDITION B ADAPTER FLANGE -NIPPLE UP AND 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 5230A 'All depths reported in Drillers Depths* I11L= 4-1/16"CIN ACCU•£AD= 11'FMC S US P E A D LL-3,00 silt NOTES: WELL ANGLE>70*@ 6602'. ACTUATOR= BAKER 1L2 *'* OBSTRUCTIONS SEEN @ 300',420',& OKB.BEV= 77.6' LL1,000'INSIDE THE 10-3/4"CSG** I ... I REf 1311/= 77.6' 20#GOND-._------_._-_j�114'--__-_-_-J I I 986' -10-3/4"TAM PORT COLLAR BF.ELEV= 48.99' 4-1/2"KILL STRING J 3362' --- KOP= 380' --� J 3362' -4-1/2"MULESHOE,D=3.958" Max Angle= 96°@ 11569 ' 12.6#,13CR 85 Datum MD= 7515' VAM TOP COND B, ``---- *---'1 3376' J--11.9-3/4"BKR WHPSTOCK(02102/17) 1 Datum TVD= 4400'SS 0152 bpf,D=3.958" +.� 3400' j-[10-3/4"HES EZSV(01/29/17)] 7-5/8"CSG CUT(01/27/17) ----- 1-----" 4-1/2" --- 4-1/2'CUT TBG(01/26/17) H 3581' GAS LFT MANDRELS 10-314'CSG,45.5#,L-80,D 3871' =9.950" - , k ST MD TVD DEV TYPE VLV LATCH PORT DATE *4 5373 3433 58 KBG2 DMY BK 0 07/03/11 ESTMA if U TOC PLUG(12/02/16) - -6060' - *3 5490 3498 56 KBG2 DMY BK 0 11/21/09 Minimum ID = 3.813" @ 2174' ::'•4 : ; *2 6645 4068 69 143G2 DMY BK 0 11/21/09 • ."_ .> y. *1 6888 4157 69 KBG2 EMPTY BK - 11/22/16 4-1/2 HES X NIPPLE . #. - - : R - ' • STA 4,3,2,&1 -COVERI�BY CMT 7-518"X 9-718"TOC -� 5800' :y``,.; �*.�� RA TAG -1 6983' "'�/':' I I 1►. \' ..:•.!, 1. .".::'/*.. 4-1/2"SGtv4NDF"G CA -1 7035' `Ni',..• :: •'''x' ''1.4 7061' _-14-1/2"BKR CMD SLUNG SLV,'D=3.813"J MULTI-DROP SIB,D=3.958" 2•,',"..:*: i 7087' j--17-5/9^X 4-1/2"BKR PREM PKR,ID=3.875" I 4-112"SGMNDFG CA H 7066' :f 7122' J-{4-1/2"HES X NF,D=3.813" j MULTI DROP SUB,ID=3.958" r '� 7122' H4-1/2"PX PLUG(11/05/15) 4-1/2"TBG,12.6#,13CR-80 VAM TOP H 7250' \ .0158 bpf,ID=3.958" \r: 4;. 7193' I-�4-112"HES X tom,ID=3.813" RA TAG 7270' '�/ 7264' J-{4-1/2"X 5-1/2"XO,ID=3.940" 4-1/2"TBG,12.6#L-80 BT-M, 7296' 7277' -5.75"BKR SEAL STEM .0152 bpf,ID=3.958" �' • (SEALS RFAADVED),D=4.83" 5-1/2"X 4-1/2"X0,D=3.930" -I 7301' �w 7282' 7-5/8"X 4-1/2"BKR ZXP LTP w TWBK,D=5.750" BAKER HOOK HANGER -1 7315' :• >, L2 (OBa) L2(OBa)LEM WNDOW 65 w/L2 NON-SEALING LEM,D=3.71" 7320'-7331' COLLAPSED LPl-CAN NOT PASS BY -1 -7315 'w C4.4a PBTD -1 13043' OPENING WIDTH=3.33" (SEEN IN D.H.VIDEO)(12/14112) •* 4• i RA TAG 7375' '' .,e -I, 7315'-13044' 6-3/4"OBa LATERAL,ID=3.958" 4.1 7-5/8"X 5-1/2"BKR ZXP LIP,D=4.94" H 7386' 7398. 7-14-1/2"MULE SHOE,D=3.958" :y lam_ 5-1/2"X 4-1/2"XO,D=3.930" J 7405' "....) Z.,„i'.14, L1 (OBb)LEM WINDOW 64° + �'1 7424'-7435' BAKER HOOK HANGER - 7419' }--.-,1 L1 (OBb) +._ OPENING WIDTH=3.33" w/L1 NON-SEALING LEM,D=3.71" ',i. ,.• 1..t1 ;i4 OBb PBTD H 12987' PERFORATION SUWMARY .* FRIT LOG: +; 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958' ANGLE ATTOPPEW: ' 4. Note:Refer to Production DB for historical perf data '�,i�' SIZE SR NiS2VAL Opn/Sqz DATE r1;:: "- >� 1 7537' 1-17-5/8"X 5-1/2"BKR ZXP LNR TOP PKR 4-1/2" SLTD OBa 7392-13000 0 02/18/04 =.. \ /'`..,*. 7548• J4-1/2"MULE SHOE,D=3.958" 4-1/2" SLID OBb 7497- 12944 0 02/12/04 4-1/2" SLID OBd 7870- 13008 0 02/04/04 V7557' J-i 5-1/2"X 4-112'XO,ID=3.930" RA TAG - 7663' A L L-ZOOj 7572'-13052' 6-3/4"OBd LATERAL,ID=3.958" 7-5/8'CSG,29.7#,L-80 BTC-M,D=6.875" -j 7872' OBd PBTD - 13050' I DATE REV BY COMMENTS DATE REV BY COMMENTS ORION INT 02/22/04 N9ES ORIGINAL COMPLETION WELL: L-200 11/25/09 D-16 RENO PBRMT No. 2040010(020)(030) 02/04/17 P272 SUSPENDED ST AR No: 50-029-23191-00(60)(61) 02/13/17 JM3 DRLG HD CORRECTIONS SEC 34,T12N,R11 E,2567'FSL&1575'FEL 02/13/17 JT/JMD FINAL ODE APPROVAL BP Exploration(Alaska) • • ti OF 7.4J ,41.-•; � - . THE STATE Alaska Oil and Gas !,.41�►;,"� � Of l l Conservation Commissi®n sKA _,,,,..„.._ __=____:. ._,,_ ____:__.__,_ t t,- 333 West Seventh Avenue ' " *,,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 °FALASl‘ts' Fax: 907.276.7542 www.aogcc.alaska.gov Ken Allen %AIMED MAR 2 0 2017, Drilling Supervisor BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool,PBU L-200 Permit to Drill Number: 204-001 Sundry Number: 317-066 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, 2e( Cathy . Foerster Chair DATED this 2.6-lay of February, 2017. RBDPJMS L`' PR - 1 207 STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMI . APPLICATION FOR SUNDRY APPROVA 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend lI • Perforate ❑ 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: 204-001 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ®' 6. API Number: 50-029-23191-00-00 99519-6612 Stratigraphic 0 Service ❑ • 7. If perforating: 8. Well Name and Number: What Regulationor Conservation Order governs wospacing in this pool? Will planned perforations require a spacing exception? Yes 0 No D PBU L-200 RECEIVED VED 9. Property Designation(Lease Number): 10. Field/Pools: FEBp ` ADL 028239&047447- PRUDHOE BAY,SCHRADER BLUFF OIL ' e - 6 117 _.,.es, 1 7 11. PRESENT WELL CONDITION SUMMARY D� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Ju. 13067 . 4367 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 4317 7-5/8" 3555-7872 2502-4496 6890 4790 Tieback Liner 266 4-1/2" 7282-7548 4313-4424 8430 7500 Liner 5515 4-1/2" 7537-13052 4420-4367 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7870-13008 4495-4366 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 ND(ft): 7092/4240 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 0 Exploratory ❑ Stratigraphic 0 Development EL - Service 0 14.Estimated Date for Commencing Operations: February 4,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended El • 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.ThompsoniBP.com Printed Name Ken Allen r/< �ZAP y_ Title Drilling Supervisor Signature ` /y� - Phone +1 907 564 4366 Date O Z/0 6/r�_/T ����' VVVV((//�r�_ COMMISSION USE ONLY Gam/ Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3\--t— CAR (Q Plug Integrity 0 BOP Test L7 Mechanical Integrity Test 0 Location Clearance 0 t362P t-..,..5.,-/- 7/--,,, 35 ) o/2S L7 Other: Post Initial Injection MIT Req'd? Yes 0 No dv Spacing Exception Required? Yes 0 No Cd Subsequent Form Required: /0 •— 4-P7--"" d n APPROVED BYTHE Approved by: / , 6 — COMMISSIONER COMMISSION Date:2 8�/7 VTI-- 2/ q,/ f- - 0RIGINAL RBDMMS Vi . : - 1 2017 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 • o t -0 0 $ C 0 OA CLi . . C 5. 0_ 2 . � 3 c \ 0 oco C \ 0 . to @ 2 > KC CO 2ws a o a I a) O 0 0 co m ° a) ( •2 c Oa) w Cl)CL £ / 9 A Tu V) E 0 § k § q \ 2 e I / / Tr 3. k - . _ \ 2 7 E a 0 c 6 _c cc § f E o vi o / k E 2 k 0 —, u c o / 2 d ) / .15 � � � / D C C -C S vs o = ® C � CO CO Vi ■ £ 0 2 £ � � _le as § 0 0 0 / o ° ƒ5 / 0 = 2 a a -, 2a ^ 0 k > c ° z / d / § 2 k � k � 2 E I— U , 0 ,(73 m _ E a / < � a c § 'Cr'. S I O t § 2 « 2 7 a) R m 2 7 1.. ._ R / 2 # al o $ S o "0 C \ ■ u k a ns a •° ° 5 % � � � § � » �^ � c f # = Cs In 2 4-, § q _ % -, k 2 0 CD E \ = 0 2 ¥ sN o k 41 % 2 / @ E SI _ © \ c > O C1.2 § e 0 \ ® § ° 9 2 . 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OD v, OD C cf0 N O , ia .O U L coif c a . a Q. a 4 a -0 o rn 3 co n a +J a) • N a Z ++, +' an L O n v Z 3 ++ Z L -oU '47. 15 J C f0 CD O dA C E o Q U a) n 0 N aJ p_ u lG= 00 of "0 vN-I 01 fC0 N LJ Of PL. 7 t *' 0 0 = ^ O ro C Q- . +f3 CO O VI e .* `^ o CC• Et N c "O ro ` p t "Q O C O • O r-I cV m 4 VO�. 4,1NU a t 11 } I HEE= 4-1/16"CM/ WELL •D= 11 FMC SUSPEIED - s NOTES: WELL ANGLE 70'@ 6602'. 00 ... ACTUATOR= BAKER �OBSTRIlCT10NS SEEN 300' 420', L 2 � L1 & L2 .* OKB.ELEV= 77.6' 1,x00'IMIDE THE 10-3/4"CSG ELEv= 77.6' L0# ONO H 114' ---I BF.ELEV= 48.99 l 986' -110-3/4"TAM PORT COLLAR I KOP= 380' 4-1/2"CUT TBG H 3362' , Max Angle= 96"@ 11569 (12108116) 3376' _H 10-3/4'BAKER VIA-IPSTOCK(_/_/ ) Datum MD= 7515' 3400' -j O-314"HES EZSV( 1I_) 1 Datum TVD= 4400'SS 7-5/8"CSG CUT(__!_/,_,) 3555' ' 4-112"CUT TBG( _/�/ ) H 3581' GAS LIFT MANDRELS II 10-3/4`CSG,45.5#,L-80,D=9.950" 3871' ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3448 2436 60 KBG2 DMY BK 0 11/04/15 ESTIMATED TOC PLUG12/02/16 -5050` 5 3565 2495 60 KBG2 DMY BK 0 11/21/09 witmMinimum ID = 3.813" @ 2174' '4 5373 3433 58 KBG2 DMY BK 0 07/03/11 4-1/2" HES X N I P P L E k-`i*# I 114r �- *3 5490 3498 56 KBG2 DMY BK 0 11/21/09 , 414 0 '2 6645 4068 69 KBG2 DMY BK 0 11/21/09 7-5/8"X 9-7/8"TOC 5800' 04,',4 14/�i+�i �+ .4 6.64 *1 6888 4157 69 KBG2 EMPTY BK 11/22/16 RA TAG 6983' + ' ' frc 'STA 4,3,2,&1 =COVERLD BY CMT 4-1/2"SGM-NDPG-CA 7035' : S ''US7061' 1-14-1/2"BKR CMD SLIDING SLV,D=3.813" MULTI-DROP SUB,D=3.958" `:.•.? �1':�RN ____-7087' HI 7-5/Er X 4-1/2'BKR PREM R(R,D=3.875' 1 4-112"SGM NDFG CA 7066' Nitloc 7122' -{4-1/2"HES X tom,D=3.813" MULTI-DROP SUB,ID=3.958" 7G 7122' H4-1/2"PX PLUG(11/05/15) 4-1/7113G,12.6#,13CR-80 VAM TOP 7250' y�° 7193' -�4-1/2"HES X PP,D=3.813" .0158 bpf,D=3.958" 9!: yy�� 7264' -4-112"X 5-1!2"XO,ID=3.940" RA TAG 7270' - y6 727T -5.75"BKR SEAL STEM 4-1/2"TBG,12.6#L-80 BT-M, 7296' yI" ,-+ + .0152 bpf,ID=3.958" �], (SEALS REMOVED),D=4.83" 5 112"X 4-1/2"XO,13=3.930" 7301' 81 tg: 7282' H7-518*X 4-1/2"BKR ZXP LTP w IT1 K,D=5.750' BAKER HOOK HANGER 7315' i AL2 (OBa) L2{OBa}LEM WINDOW 65" w/L2 NON-SEALING LEM,U '3.71' itb.... lil7320'-7331' 0 COLLAPSED LEM-CAN NOT PASS BY (--I -7315 OBa PB7DH 13043'\_ OPENING WIDTH 3 3 (SEEN IN D.H.VIDEO)(12/14/12) I 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' it 111 7398' -14-1/2"MULE SHOE,D=3.958" 5-1/2"X 4-1/2"XO,D 118=3.930" 7405' L1 (OBb)LEM WINDOW 64` BAKER HOOK HAHANGER - 7419' 1 ',',' § 7424'-7435`L1 (OBb) OBb R3TD H I OPENING WIDTH=3.33" w/L1 NON-SEALING LE34,D=3.71" \ 12987' PERFORATION SUMMARY REF LOG. 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958" ANGLE AT TOP PE31F: Note:Refer to Production D8 for historical perf data C,it 7537' -I 7-5/8'X 5-1/2"BKR ZXP LNR TOP R(R SIZE SPF INTERVAL Opn/Sqz DATE :A IIIIK 4-1/2" SLID OBa 7392-13000 0 02/18/04 1,1 I 7548' -14-112"MULE SHOE,ID=3.958" 4-1/2" SLTD OBb 7497- 12944 0 02/12/04 to 4-1/2" SLID OBd 7870- 13008 0 02/04/04 7557' 5-1/2"X 4-1J2"XO,ID=3.930" RA TAG 7663' 0 1. IL"-2001 7572'-13052' 6-3/4'OBd LATERAL,ID=3.958" 7-5/8"CSG,29.7#,L-80 BTC-M,13=6.875" H 7872' OBd PBTD - 13050' -�..._ I I DATE REV BY CM/VENTS DATE REV BY COMMENTS ORION UNIT 02/22/04 N9ES ORIGINAL COMPLETION WH-L. L-200 11/25/09 D-16 RWO PERMIT No; 2040010(020)(030) 02/04/17 P272 SUSPENDED ST AR No: 50-029-23191-00(60)(61) 02/06/17 JMD DRLG HO CORRECTIONS SEC 34,T12N,R11 E,2567'FSL&1575'FEL BP Exploration(Alaska) • • PTl) av4-- vvl Loepp, Victoria T (DOA) From: Thompson,Jacob <Jacob.Thompson@BP.com> Sent: Saturday, February 04, 2017 9:03 AM To: Loepp,Victoria T(DOA) Cc: Lastufka,Joseph N; Roach, Frank;Allen, Kenneth W Subject: L-200 Status Update and Request for Suspenson of Operations Attachments: L-200 Suspention.pdf Follow Up Flag: Follow up Flag Status: Flagged ' ] ?�?7. Victoria, scOMED As we spoke about last night we have been experiencing difficulties during the decomplete on L-200. Last night when I spoke with you,we believed that there was a shallow leak in the casing between 870' MD and 1230' MD. I then realized that that depth corresponds to the location of the 10-3/4"TAM Port Collar. Last night we went in the hole with the port collar shifting tool and shifted the port collar closed and were successful in obtaining a 2,000 psi pressure test on the 10- 3/4"casing test.Although the well currently has adequate integrity we are electing to move off of L-200 to assess the different risks and hazards associated with the subsidence we have seen,as well as the implication of having the TAM Port Collar in the well. Below is an abbreviated synopsis of the operations. 1. Move in rig up.Test TWC. 2. ND tree NU BOP and test. 3. Circulate out freeze protect pull 4-1/2"tubing 4. RIH and cut 7-5/8" casing,circulate out freeze protect from OA. 5. POOH and lay down casing cutter. 6. Pull 7-5/8 casing hanger and lay down 7-5/8"casing 7. Attempt a drift run to confirm the window mill and whipstock could be run. • Tag up on shallow casing obstruction at 400' 8. Successfully drift with a less stiff assembly. 9. RU eline and set EZSV at 3,400'MD. 10. Run USIT log to interpret the shallow casing obstructions. Multiple obstructions seen on log. 11. Perform multiple drift runs with varying results.Successfully RIH with 9-3/4"stabilized assembly. 12. POOH LD drift assembly. RU and pressure test well to 2,000 psi.good test. 13. Muliple drift runs with different configurations of whipstock milling assembly.Successfully run 9-3/4"window milling assembly. 14. POOH and lay down window mills, 15. MU whipstock without window mills. 16. RIH and set whipstock. 17. POOH and MU window mills. 18. RIH and pressure test casing to 2,000 psi.Test Failed. 19. POOH with milling assembly. 20. MU RTTS packer and RIH pressure test casing determine leak is between 870'MD and 1230' MD 21. Make decision to move off of well. 22. POOH lay down RTTS. 23. Realize TAM Port Collar is in between the leaking interval. 24. MU TAM combo tool and RIH. 25. Latch into TAM Collar. Pressure test collar. Collar leaking off. PU and shift collar closed. Pressure test collar again with no leaks. 26. POOH and lay down combo tool. 1 1111 27. Pressure test 10-3/4"casing2,000 psi.Test Passed. 28. Decision made to continue to move off of well and assess newfound risks. Here is an abbreviated plan forward for suspending the well. 1. Run 4-1/2" 12.6#condition B vamtop tubing to just above the whipstock and EZSV at 3,375' MD. 2. Displace out 9.2 ppg LSND with 9.2—9.4 PPG completion brine. 3. Set tubing hanger and freeze protect well. 4. Install and test TWC and ND BOP, NU adapter flange and tree. Attached is a wellbore schematic with the the proposed suspension plan. Jacob Thompson BP Alaska Rotary Drilling Engineer Cell:(907)854-4377 Office:(907)564-5579 2 TREE= 4-1/16"OW WELLHEAD= 11'FMC L-200 silly NOTES: WELL ANGLE>70°a 6602'. ACTUATOR= BAKER, SUSPEN D LI & L2 "`=CASING OBSTRUCTIONS HAVE BEEN SEEN AT 0103.ELEV= 77.6' I i 300',420',AND 1,000'INSIDE THE 10-3/4"CASING BF.H..EV= 53.80' / KOP= 380' 20#COND H 114' Max Angle= 96°(11569' ---1 885' -1 10-3/4"TAM PORT COLLAR Datum M)= 7515' -4-1/2'12.6#VAMTOP Datum TVD= 4400'SS1111111111111116.- 3350' CONDIT1ONB TUBING /-5/8`29.7#CASING CUT H 3555" 3375' -1103/4'BAKER WHIPSTOCK 4-1/2" 17.(V 111F1ING CM. H 3r;g1' 3400' H10-3/4"HES EZSV 10-3/4"CSG_45.5#,L-80,D=9.95" - 3871' GAS LIFT MANDRELS it ►ri't ieg. '�-- ST MD ND DEV TYPE VLV LATCH PORT DATE 4-1/2"X 7-5/8'TOCH 5587' Ate,If'1' ii i'1s 1.1 5 3565 2495 60 KBG2 DMY BK 0 11/21/09 1 %.4‘A ,i w� /i.++���v��1� 4 5373 3433 58 KBG2 DMY BK 0 07/03/11 7-5/8"X 9-7/8"TOC 1---1 5800' f441.eii ti#ifs # 3 5490 3498 56 KBG2 DMY BK 0 11/21/09 RA TAG 6983' ' w2 6645 4068 69 KBG2 DMY BK 0 11/21/09 ev ,11 w 1 6888 4157 69 KBG2 EMPTY BK - 07/03/11 41/2"SGMNDPG CA 7035' r �,+ . .• ti iiw�ie.; :I; 7051' -14-112"BKR CMD SLDNIC'SLV,13=3.813" MULTI-DROP SUB,13=3.958" 4.10;;,11e 4 �le"1;2 4, 7087' -17-5/8"X 4-1/2"BKR PREM PKR,13=3-875" 4-1/2"SGM-NDFG-CA 7066' I\ '1 #. 7122' -141/2"HES X NP,ID=3.813" MULTFDROP SUB,ID=3.958" 7122' -14-1/T PX PLUG(11/05/15) 41/2"TBG,12.6#>13CR 80 VAM TOP 7250' V. 7193' - 41/2"HES X NP,ID=3.813" .0158 bpf,ID=1958" V kl RA TAG 1 7270' 7264' -141/2"X 5-1/2"XO,D=3.940" i9 7277' L 5.75"BKR SEAL STEN 4-1/2"TBG,12.6#L-80 BT-M, --1 7296' ,` J 0152 bpf,ID=3.958" �� l (SEALS REMOVED),13=4.83" , \ 4 Ei 7282' -7-518"X 4-1/2"BKR ZXP LTP w REEK D=5.750" 5-1/2'X 4-1/2"XO,D=3.930" -1 7301' BAKER HOOK HANGER -1 7315' 4) .,... 4 L2 (OBa) 7 L2(OBa)LEM WINDOW 65° w/L2 NON-SEALNG LBM,13=3.71" ► IX 7320'-7331' COLLAPS®LEN-CAN NOT PASS BY -7315 , OBa PBTD -1 13043' OPENING WIDTH=3.33" (SEEN IN DR VIDEO)(12/14/12) #i 1- 7315' 13044' 6-3/4"OBa LATERAL,ID=3.958" RA TAG -1 7375' 7-5/8"X 5-1/2"BKR ZXP LTP,D=4.94" 7386' 0 el •�I 7398'1-14-1/2"MULE SHOE,D=3.958" 5-1/2"X 4-1/2"XO,ID=3.930" H 7405' --a L1 (OBb)LEM WINDOW 64° ri 7424'-7435' BAKE2 HOOK HANGER 7419' L1 (OBb)dp 1. OPENING WIDTH=3.33" w/L1 NON-SEALING LBM,D=3.71" 9 OBb PBTD -I 12987' PERFORATION SUMMARY AARY V REF LOG: 7 � 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958" ANGLE AT TOP PERF: ei i Note:Refer to Roduction DB for historical perf data $g F2;'i 7537' -I7-5/8"X 5-1/2"BKR ZXP LNR TOP PKR SIZE SPF NTERVAL Opn/Sqz DATE III;11 4-1/2" SLID OBa 7392-13000 0 02/18/04 \ Y 4-1/2" SLID OBb 7497-12944 0 02/12/04 •i 7548' --i4 1/2"MULE SHOE D=3.958" �i 4-1/2" SLID OBd 7870-13008 0 02/04/04 9 7557' -15-1/2"X 4-1/2"XO,D=3.930" RA TAG -1 7663' I I 1 I 7-5/8"CSG,29.7#,L-80 BTC-M,13=6.875" H 7872' I 1 1 I I I ISI -2001 7572'-13052' 6-3/4"OBd LATERAL,ID=3.958" C)Bd PBTD -1 13050' ---.-___ DATE REV BY COMMENTS DATE REV BY COMMENTS ORION INT 02122/04 NOES ORIGINAL COMPLETION 06/26/15 TFA/JMD PULL®ROCK CATCHER(06/20/15) WELL: L-200 11/25/09 D-16 MO 12/03/15 GJB/JMD GLV C/O(11/04/15) FE RMT No: 2040010(020)(030) 04/09/12 TBD/JMD SET ROCK CATCHI32(04/07/ 12/03/15 GJB/JMD SET PX PLUG(11/05/15) AR No: 50-029-23191-00(60)(61) 04/10/12 JFK/JM) GLV C/O(04/08/12) 12/10/15 JT/JM) PRE-RIG CMT SEC 34,T12N,R11 E,256T FSL&1575'FEL 12/18/12 RRW/JM)FCO/FISH ROCK CATCHER/COL LBM(12/14/12) 01/15/13 GJB/JM) SET ROCK CATCHER(12/31/12) BP Exploration(Alaska) ADate: 12/01/2016 2-7 "CZJ Transmittal Number:0134 glirr°1 data RIGHT PLACE FIRST TIME DATA LOGGED n0/2011 Ivi. K.BENDER GYRODATA SURVEY TRANSMITTAL State of Alaska- AOGCC REC' `` Attn: Makana Bender DECi 9 201 f, - 333 W 7t'Avenue, Suite 100 Anchorage, AK 99501 s ' C Enclosed are the materials listed below. If you have any questions,please contact Steve Thompson: 907-250-1200; Stevet@gyrodata.com or Jamie McCrimmon: 403-640-7755; Jamiem@gyrodata.com. Drill Site SW Name Date Description L PAD L-200 12/01/2016 SURVEY REPORT: 1 Hard Copy; 1 Disk Please Sign and Return one opy of this transmittal to BPXA,PDC: gancpdc@bp.com Thank You, Steve Thompson SCM41" `1 ' ` '`` Gyrodata Inc. Gyrodata Incorporated 23000 Northwest Lake Drive Houston,TX 77095 '2-04-op\ 2.713 Mr/0*W littP \)•`<--c ( O0 I SCI4* BP Exploration (Alaska) Inc. L - PAD L-200 N.Slope Borough / Prudhoe Bay Unit 1 OF 9 AK1116GCM145 • • WO/Clara A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) INC. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 Run Date: 28 Nov 2016 Surveyor: Joshua Camacho,Jeff Patrick Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350709 deg. N Longitude: 149.324419 deg. W Azimuth Correction: None Gyro: Bearings are Relative to True North Depth Reference: Rotary Table Air Gap ( RKB to MSL): 77.60 Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location 2 OF 9 AK1116GCM145 • • . gYrcOata A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.0 0.0 0.00 0.00 FT. - 7109 FT.CONTINUOUS GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 4 1/2"TUBING. ALL MEASURED DEPTHS&COORDINATES REFERENCED TO R.K.B. ELEVATION OF 77.6 FT.ABOVE MSL. BF TO MSL: 48.99 FT. / BF TO SWAB : 9 FT. / SWAB TO GYRO SENSOR: 4 FT. /ZERO TOOL ON SWAB : +15.61 FT. 100.00 0.56 353.79 100.00 0.48 N 0.05 W 0.5 353.8 0.56 200.00 0.68 352.38 199.99 1.55 N 0.18 W 1.6 353.3 0.12 300.00 3.10 345.09 299.93 4.75 N 0.96 W 4.9 348.6 2.43 400.00 6.24 350.62 399.59 12.74 N 2.54 W 13.0 348.7 3.17 500.00 9.76 356.03 498.60 26.56 N 4.01 W 26.9 351.4 3.59 525.00 10.42 357.92 523.21 30.94 N 4.24 W 31.2 352.2 2.95 550.00 11.10 358.54 547.77 35.60 N 4.39 W 35.9 353.0 2.76 575.00 11.51 358.57 572.29 40.50 N 4.51 W 40.8 353.6 1.64 600.00 11.65 358.94 596.78 45.52 N 4.62 W 45.8 354.2 0.63 625.00 12.05 0.17 621.25 50.65 N 4.66 W 50.9 354.7 1.89 650.00 12.31 0.57 645.68 55.93 N 4.62 W 56.1 355.3 1.09 675.00 13.05 1.42 670.07 61.41 N 4.53 W 61.6 355.8 3.05 700.00 13.60 3.20 694.40 67.17 N 4.29 W 67.3 356.3 2.74 725.00 13.81 4.96 718.69 73.08 N 3.87 W 73.2 357.0 1.87 750.00 14.06 5.93 742.95 79.07 N 3.30 W 79.1 357.6 1.37 775.00 14.32 6.60 767.19 85.16 N 2.63 W 85.2 358.2 1.23' 800.00 14.51 7.57 791.40 91.34 N 1.86 W 91.4 358.8 1.23 825.00 14.82 9.31 815.59 97.60 N 0.93 W 97.6 359.5 2.15. 850.00 15.40 10.76 839.72 104.01 N 0.20 E 104.0 0.1 2.77 875.00 15.74 11.96 863.81 110.59 N 1.53 E 110.6 0.8 1.87 900.00 16.10 13.52 887.85 117.28 N 3.04 E 117.3 1.5 2.24 925.00 16.75 14.72 911.83 124.13 N 4.77 E 124.2 2.2 2.93 950.00 17.23 15.32 935.74 131.19 N 6.66 E 131.4 2.9 2.04 975.00 17.64 18.40 959.59 138.35 N 8.83 E 138.6 3.7 4.04 1000.00 18.47 20.48 983.36 145.66 N 11.41 E 146.1 4.5 4.20 1025.00 19.73 20.73 1006.98 153.32 N 14.29 E 154.0 5.3 5.05 1050.00 20.60 22.99 1030.45 161.31 N 17.51 E 162.3 6.2 4.67 1075.00 21.08 23.47 1053.81 169.48 N 21.01 E 170.8 7.1 2.04 1100.00 21.99 22.88 1077.07 177.92 N 24.62 E 179.6 7.9 3.74 1125.00 22.70 22.36 1100.19 186.69 N 28.28 E 188.8 8.6 2.95 1150.00 23.47 21.62 1123.19 195.78 N 31.95 E 198.4 9.3 3.29 1175.00 24.58 20.35 1146.02 205.29 N 35.59 E 208.3 9.8 4.90 1200.00 25.51 19.40 1168.67 215.24 N 39.19 E 218.8 10.3 4.05 1225.00 26.98 18.68 1191.09 225.69 N 42.79 E 229.7 10.7 6.02 3 OF 9 AK1116GCM145 • • . gyro/data A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 1250.00 27.86 18.17 1213.28 236.61 N 46.43 E 241.1 11.1 3.64 1275.00 28.64 17.80 1235.31 247.87 N 50.08 E 252.9 11.4 3.20 1300.00 29.61 17.90 1257.15 259.45 N 53.81 E 265.0 11.7 3.88 1325.00 30.21 18.03 1278.82 271.31 N 57.66 E 277.4 12.0 2.41 1350.00 30.96 18.12 1300.34 283.40 N 61.60 E 290.0 12.3 3.01 1375.00 31.93 18.31 1321.67 295.79 N 65.68 E 303.0 12.5 3.90 1400.00 33.86 18.52 1342.66 308.67 N 69.97 E 316.5 12.8 7.73 1425.00 35.62 18.66 1363.20 322.17 N 74.51 E 330.7 13.0 7.05 1450.00 36.29 18.75 1383.44 336.08 N 79.22 E 345.3 13.3 2.69 1475.00 37.66 19.18 1403.41 350.30 N 84.11 E 360.3 13.5 5.58 1500.00 39.10 19.70 1423.00 364.93 N 89.27 E 375.7 13.7 5.90 1525.00 40.86 20.21 1442.16 380.03 N 94.76 E 391.7 14.0 7.16 1550.00 41.99 20.48 1460.91 395.54 N 100.51 E 408.1 14.3 4.58 1575.00 43.13 20.68 1479.32 411.37 N 106.45 E 424.9 14.5 4.59 1600.00 45.84 21.09 1497.15 427.73 N 112.70 E 442.3 14.8 10.90 1625.00 48.02 21.67 1514.23 444.74 N 119.36 E 460.5 15.0 8.88 1650.00 49.29 21.94 1530.74 462.16 N 126.33 E 479.1 15.3 5.14 1675.00 49.82 22.02 1546.96 479.80 N 133.45 E 498.0 15.5 2.13 1700.00 50.12 22.21 1563.04 497.54 N 140.66 E 517.0 15.8 1.33 1725.00 49.73 23.09 1579.13 515.19 N 148.02 E 536.0 16.0 3.11 1750.00 50.34 23.19 1595.19 532.81 N 155.55 E 555.1 16.3 2.46'. 1775.00 50.97 23.25 1611.04 550.58 N 163.18 E 574.3 16.5 2.53 1800.00 51.52 23.39 1626.69 568.48 N 170.89 E 593.6 16.7 2.24 1825.00 52.47 23.42 1642.08 586.56 N 178.72 E 613.2 16.9 3.80 1850.00 54.14 23.36 1657.02 604.96 N 186.68 E 633.1 17.1 6.68 1875.00 56.00 23.57 1671.34 623.76 N 194.84 E 653.5 17.3 7.47 1900.00 57.26 23.68 1685.09 642.89 N 203.20 E 674.2 17.5 5.05 1925.00 57.86 23.73 1698.50 662.21 N 211.69 E 695.2 17.7 2.41. 1950.00 57.92 24.12 1711.78 681.56 N 220.27 E 716.3 17.9 1.34. 1975.00 57.60 24.83 1725.12 700.81 N 229.03 E 737.3 18.1 2.72 2000.00 58.40 25.33 1738.37 720.01 N 238.02 E 758.3 18.3 3.62 2025.00 59.26 25.80 1751.31 739.31 N 247.25 E 779.6 18.5 3.80 2050.00 60.94 26.54 1763.77 758.75 N 256.81 E 801.0 18.7 7.19 2075.00 62.03 26.86 1775.71 778.38 N 266.68 E 822.8 18.9 4.50 2100.00 62.54 27.01 1787.33 798.11 N 276.71 E 844.7 19.1 2.11 2125.00 62.44 27.32 1798.88 817.84 N 286.83 E 866.7 19.3 1.17 2150.00 62.46 27.28 1810.44 837.53 N 297.00 E 888.6 19.5 0.16 2175.00 62.05 26.85 1822.08 857.24 N 307.06 E 910.6 19.7 2.24 2200.00 61.92 27.04 1833.82 876.91 N 317.07 E 932.5 19.9 0.85 2225.00 61.89 27.26 1845.60 896.54 N 327.13 E 954.4 20.0 0.79 4 OF 9 AK1116GCM145 • • we/data A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 2250.00 61.75 26.93 1857.40 916.15 N 337.17 E 976.2 20.2 1.29. 2275.00 61.71 26.91 1869.24 935.79 N 347.13 E 998.1 20.4 0.17 2300.00 61.60 27.17 1881.11 955.38 N 357.14 E 1020.0 20.5 1.02 2325.00 61.28 26.80 1893.07 974.95 N 367.10 E 1041.8 20.6 1.82 2350.00 61.37 26.68 1905.06 994.54 N 376.97 E 1063.6 20.8 0.55 2375.00 60.77 27.14 1917.16 1014.05 N 386.87 E 1085.3 20.9 2.89 2400.00 60.87 27.11 1929.34 1033.48 N 396.82 E 1107.0 21.0 0.41 2425.00 61.07 26.96 1941.48 1052.95 N 406.76 E 1128.8 21.1 0.96 2450.00 61.19 27.05 1953.55 1072.45 N 416.70 E 1150.6 21.2 0.57 2475.00 61.21 27.08 1965.59 1091.96 N 426.67 E 1172.4 21.3 0.13 2500.00 61.17 26.80 1977.64 1111.49 N 436.59 E 1194.2 21.4 0.99 2525.00 60.96 26.98 1989.73 1131.00 N 446.49 E 1215.9 21.5 1.05 2550.00 61.02 27.20 2001.86 1150.47 N 456.45 E 1237.7 21.6 0.81 2575.00 60.99 26.77 2013.98 1169.95 N 466.37 E 1259.5 21.7 1.51 2600.00 60.98 26.28 2026.10 1189.51 N 476.13 E 1281.3 21.8 1.71 2625.00 60.88 25.37 2038.25 1209.18 N 485.65 E 1303.1 21.9 3.21 2650.00 60.61 24.84 2050.47 1228.93 N 494.90 E 1324.8 21.9 2.14 2675.00 60.05 24.69 2062.84 1248.66 N 504.00 E 1346.5 22.0 2.30 2700.00 59.63 25.12 2075.40 1268.26 N 513.11 E 1368.1 22.0 2.24 2725.00 60.20 25.17 2087.93 1287.85 N 522.30 E 1389.7 22.1 2.29 2750.00 60.88 25.11 2100.23 1307.55 N 531.54 E 1411.5 22.1 2.73` 2775.00 60.90 24.66 2112.39 1327.36 N 540.74 E 1433.3 22.2 1.57 2800.00 60.57 23.69 2124.61 1347.26 N 549.67 E 1455.1 22.2 3.63 2825.00 59.69 22.18 2137.06 1367.22 N 558.12 E 1476.8 22.2 6.31 2850.00 59.76 21.61 2149.67 1387.26 N 566.17 E 1498.3 22.2 1.99 2875.00 59.69 21.41 2162.27 1407.34 N 574.08 E 1519.9 22.2 0.75 2900.00 59.64 21.74 2174.90 1427.41 N 582.02 E 1541.5 22.2 1.16 2925.00 59.59 21.82 2187.54 1447.44 N 590.02 E 1563.1 22.2 0.34 2950.00 59.35 21.61 2200.24 1467.44 N 597.99 E 1584.6 22.2 1.20 2975.00 59.55 21.58 2212.95 1487.46 N 605.91 E 1606.1 22.2 0.81 3000.00 59.53 21.59 2225.62 1507.50 N 613.84 E 1627.7 22.2 0.09 3025.00 59.07 21.99 2238.39 1527.46 N 621.82 E 1649.2 22.2 2.30 3050.00 58.51 21.91 2251.34 1547.29 N 629.81 E 1670.6 22.1 2.26 3075.00 58.78 21.64 2264.35 1567.12 N 637.73 E 1691.9 22.1 1.42 3100.00 59.53 21.59 2277.17 1587.07 N 645.64 E 1713.4 22.1 3.00 3125.00 60.08 21.64 2289.74 1607.16 N 653.60 E 1735.0 22.1 2.21 3150.00 60.37 21.56 2302.16 1627.34 N 661.58 E 1756.7 22.1 1.19 3175.00 60.51 21.40 2314.49 1647.57 N 669.55 E 1778.4 22.1 0.79 3200.00 60.66 21.28 2326.77 1667.86 N 677.47 E 1800.2 22.1 0.73 3225.00 60.87 21.43 2338.98 1688.17 N 685.42 E 1822.0 22.1 0.99 5 OF 9 AK1116GCM145 • • gyro/da ► A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 3250.00 60.63 21.55 2351.19 1708.47 N 693.41 E 1843.8 22.1 1.05. 3275.00 60.38 21.31 2363.50 1728.72 N 701.36 E 1865.6 22.1 1.30 3300.00 60.67 21.29 2375.80 1749.00 N 709.26 E 1887.3 22.1 1.16 3325.00 60.58 21.54 2388.07 1769.28 N 717.22 E 1909.1 22.1 0.94 3350.00 60.41 21.41 2400.38 1789.53 N 725.18 E 1930.9 22.1 0.82 3375.00 60.52 21.27 2412.70 1809.79 N 733.10 E 1952.6 22.1 0.66 3400.00 60.65 21.20 2424.98 1830.09 N 740.99 E 1974.4 22.0 0.57 3425.00 60.62 21.61 2437.24 1850.37 N 748.94 E 1996.2 22.0 1.43 3450.00 59.96 22.05 2449.63 1870.53 N 757.01 E 2017.9 22.0 3.05 3475.00 59.65 22.64 2462.20 1890.52 N 765.23 E 2039.5 22.0 2.39 3500.00 59.96 22.82 2474.78 1910.45 N 773.57 E 2061.1 22.0 1.39 3525.00 60.05 23.09 2487.28 1930.38 N 782.02 E 2082.8 22.1 1.00 3550.00 59.48 23.75 2499.86 1950.20 N 790.60 E 2104.4 22.1 3.23 3575.00 58.97 24.35 2512.66 1969.82 N 799.36 E 2125.8 22.1 2.90 3600.00 59.39 24.31 2525.47 1989.38 N 808.20 E 2147.3 22.1 1.69 3625.00 58.99 24.28 2538.27 2008.95 N 817.04 E 2168.7 22.1 1.60 3650.00 58.16 24.67 2551.30 2028.37 N 825.87 E 2190.1 22.2 3.58 3675.00 58.30 24.61 2564.47 2047.69 N 834.74 E 2211.3 22.2 0.60 3700.00 58.34 24.49 2577.60 2067.04 N 843.57 E 2232.5 22.2 0.44 3725.00 58.33 24.43 2590.72 2086.41 N 852.39 E 2253.8 22.2 0.21 3750.00 58.23 24.47 2603.86 2105.76 N 861.19 E 2275.1 22.2 0.42 3775.00 58.21 24.53 2617.03 2125.10 N 870.00 E 2296.3 22.3 0.22 3800.00 58.21 24.46 2630.20 2144.44 N 878.81 E 2317.5 22.3 0.24 3825.00 58.26 24.53 2643.36 2163.78 N 887.62 E 2338.8 22.3 0.31 3850.00 58.32 24.52 2656.50 2183.13 N 896.45 E 2360.0 22.3 0.24 3875.00 56.66 24.67 2669.94 2202.30 N 905.23 E 2381.1 22.3 6.66 3900.00 56.65 24.74 2683.68 2221.27 N 913.95 E 2402.0 22.4 0.24 3925.00 56.74 24.63 2697.41 2240.26 N 922.68 E 2422.8 22.4 0.51 3950.00 56.64 24.54 2711.14 2259.26 N 931.37 E 2443.7 22.4 0.50 3975.00 56.48 24.52 2724.91 2278.24 N 940.03 E 2464.6 22.4 0.64 4000.00 55.99 24.52 2738.81 2297.14 N 948.66 E 2485.3 22.4 1.96 4025.00 56.13 24.65 2752.77 2316.00 N 957.29 E 2506.0 22.5 0.71 4050.00 56.97 24.93 2766.55 2334.94 N 966.03 E 2526.9 22.5 3.49 4075.00 58.11 25.06 2779.96 2354.06 N 974.95 E 2548.0 22.5 4.58 4100.00 58.54 25.09 2793.09 2373.33 N 983.96 E 2569.2 22.5 1.72 4125.00 57.97 25.16 2806.24 2392.58 N 992.99 E 2590.5 22.5 2.29 4150.00 58.26 25.25 2819.45 2411.78 N 1002.03 E 2611.7 22.6 1.20 4175.00 57.71 25.24 2832.70 2430.96 N 1011.07 E 2632.8 22.6 2.20 4200.00 57.79 25.15 2846.04 2450.09 N 1020.07 E 2654.0 22.6 0.44 4225.00 57.53 24.95 2859.42 2469.23 N 1029.02 E 2675.1 22.6 1.24 6 OF 9 AK1116GCM145 • • . gyr*data • A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 4250.00 58.16 24.67 2872.72 2488.44 N 1037.90 E 2696.2 22.6 2.69, 4275.00 59.09 24.37 2885.74 2507.86 N 1046.75 E 2717.5 22.7 3.86 4300.00 59.47 24.15 2898.51 2527.45 N 1055.58 E 2739.0 22.7 1.70 4325.00 59.38 23.78 2911.23 2547.12 N 1064.33 E 2760.5 22.7 1.32 4350.00 59.39 23.76 2923.96 2566.81 N 1073.00 E 2782.1 22.7 0.08 4375.00 59.07 23.72 2936.75 2586.47 N 1081.65 E 2803.5 22.7 1.29 4400.00 59.01 23.70 2949.61 2606.10 N 1090.27 E 2825.0 22.7 0.25 4425.00 58.67 23.77 2962.54 2625.68 N 1098.88 E 2846.4 22.7 1.38 4450.00 58.66 23.93 2975.55 2645.21 N 1107.51 E 2867.7 22.7 0.55 4475.00 58.46 24.01 2988.59 2664.70 N 1116.18 E 2889.0 22.7 0.85 4500.00 58.37 24.07 3001.68 2684.15 N 1124.85 E 2910.3 22.7 0.41 4525.00 59.13 24.42 3014.65 2703.64 N 1133.63 E 2931.7 22.7 3.27 4550.00 60.56 24.62 3027.21 2723.31 N 1142.60 E 2953.3 22.8 5.76 4575.00 61.18 24.71 3039.38 2743.15 N 1151.71 E 2975.1 22.8 2.50 4600.00 60.92 24.62 3051.48 2763.03 N 1160.84 E 2997.0 22.8 1.09 4625.00 60.80 24.39 3063.65 2782.90 N 1169.90 E 3018.8 22.8 0.94 4650.00 61.13 24.35 3075.79 2802.81 N 1178.92 E 3040.7 22.8 1.33 4675.00 60.98 24.26 3087.88 2822.75 N 1187.92 E 3062.5 22.8 0.68 4700.00 60.48 24.38 3100.11 2842.62 N 1196.91 E 3084.3 22.8 2.04 4725.00 60.43 24.45 3112.44 2862.43 N 1205.90 E 3106.1 22.8 0.32 4750.00 60.60 24.44 3124.74 2882.24 N 1214.90 E 3127.8 22.9 0.68 4775.00 60.55 24.49 3137.02 2902.06 N 1223.92 E 3149.6 22.9 0.27 4800.00 60.38 24.39 3149.35 2921.86 N 1232.92 E 3171.3 22.9 0.76 4825.00 60.46 24.35 3161.69 2941.67 N 1241.89 E 3193.1 22.9 0.35 4850.00 60.49 24.40 3174.01 2961.48 N 1250.87 E 3214.8 22.9 0.21 4875.00 60.37 24.25 3186.34 2981.29 N 1259.82 E 3236.6 22.9 0.71 4900.00 60.02 23.48 3198.77 3001.13 N 1268.60 E 3258.2 22.9 3.02 4925.00 58.79 21.95 3211.50 3020.98 N 1276.91 E 3279.8 22.9 7.21, 4950.00 58.21 20.94 3224.56 3040.82 N 1284.71 E 3301.1 22.9 4.15 4975.00 58.28 20.52 3237.72 3060.70 N 1292.23 E 3322.3 22.9 1.46 5000.00 57.82 19.35 3250.95 3080.64 N 1299.46 E 3343.5 22.9 4.38 5025.00 58.14 18.05 3264.20 3100.72 N 1306.26 E 3364.6 22.8 4.59 5050.00 58.06 16.92 3277.41 3120.96 N 1312.63 E 3385.8 22.8 3.85 5075.00 57.95 16.17 3290.66 3141.29 N 1318.67 E 3406.8 22.8 2.58 5100.00 58.44 14.95 3303.83 3161.75 N 1324.37 E 3427.9 22.7 4.59 5125.00 58.66 13.08 3316.88 3182.44 N 1329.53 E 3449.0 22.7 6.44 5150.00 58.57 12.13 3329.90 3203.27 N 1334.19 E 3470.0 22.6 3.26 5175.00 58.29 11.41 3342.99 3224.12 N 1338.54 E 3490.9 22.5 2.70 5200.00 57.73 9.65 3356.23 3244.97 N 1342.41 E 3511.7 22.5 6.38 5225.00 58.00 8.35 3369.53 3265.88 N 1345.72 E 3532.3 22.4 4.53 7 OF 9 AK1116GCM145 • le ` Q A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 5250.00 58.18 7.76 3382.75 3286.89 N 1348.70 E 3552.8 22.3 2.13 5275.00 58.70 6.37 3395.83 3308.03 N 1351.32 E 3573.4 22.2 5.17 5300.00 58.69 4.16 3408.82 3329.30 N 1353.28 E 3593.8 22.1 7.55 5325.00 58.04 1.77 3421.94 3350.55 N 1354.38 E 3613.9 22.0 8.54 5350.00 58.03 0.16 3435.17 3371.76 N 1354.74 E 3633.7 21.9 5.46 5375.00 57.76 359.61 3448.46 3392.93 N 1354.69 E 3653.4 21.8 2.15 5400.00 56.90 358.35 3461.95 3413.97 N 1354.32 E 3672.8 21.6 5.46 5425.00 56.90 356.64 3475.61 3434.90 N 1353.41 E 3691.9 21.5 5.73 5450.00 56.33 355.55 3489.36 3455.72 N 1351.98 E 3710.8 21.4 4.30 5475.00 55.80 354.07 3503.32 3476.38 N 1350.11 E 3729.3 21.2 5.35 5500.00 55.52 352.80 3517.42 3496.88 N 1347.75 E 3747.6 21.1 4.34 5525.00 55.66 351.35 3531.55 3517.31 N 1344.91 E 3765.7 20.9 4.82 5550.00 55.78 349.97 3545.63 3537.69 N 1341.55 E 3783.5 20.8 4.59 5575.00 56.32 348.31 3559.60 3558.06 N 1337.65 E 3801.2 20.6 5.92 5600.00 56.50 346.82 3573.43 3578.40 N 1333.16 E 3818.7 20.4 5.02 5625.00 56.42 345.57 3587.24 3598.63 N 1328.19 E 3835.9 20.3 4.18 5650.00 56.21 344.36 3601.11 3618.72 N 1322.79 E 3852.9 20.1 4.11 5675.00 56.61 342.47 3614.94 3638.68 N 1316.85 E 3869.6 19.9 6.50 5700.00 56.94 341.32 3628.64 3658.56 N 1310.35 E 3886.1 19.7 4.07 5725.00 56.79 340.86 3642.30 3678.36 N 1303.56 E 3902.5 19.5 1.65 5750.00 57.17 339.46 3655.93 3698.08 N 1296.45 E 3918.7 19.3 4.94` 5775.00 57.55 337.87 3669.41 3717.68 N 1288.79 E 3934.7 19.1 5.57 5800.00 57.87 337.11 3682.77 3737.21 N 1280.70 E 3950.6 18.9 2.87 5825.00 57.89 336.50 3696.06 3756.67 N 1272.36 E 3966.3 18.7 2.07 5850.00 58.60 334.78 3709.22 3776.03 N 1263.59 E 3981.8 18.5 6.50 5875.00 59.53 333.45 3722.07 3795.32 N 1254.23 E 3997.2 18.3 5.89 5900.00 59.37 333.21 3734.78 3814.56 N 1244.57 E 4012.5 18.1 1.05 5925.00 59.54 331.90 3747.48 3833.67 N 1234.64 E 4027.6 17.9 4.56 5950.00 59.80 330.24 3760.11 3852.55 N 1224.20 E 4042.4 17.6 5.82 5975.00 59.73 329.62 3772.70 3871.25 N 1213.38 E 4057.0 17.4 2.16 6000.00 59.68 329.41 3785.31 3889.85 N 1202.43 E 4071.5 17.2 0.75 6025.00 59.72 327.96 3797.92 3908.29 N 1191.21 E 4085.8 17.0 5.01 6050.00 59.81 326.40 3810.51 3926.44 N 1179.51 E 4099.8 16.7 5.40 6075.00 59.87 325.76 3823.07 3944.38 N 1167.44 E 4113.5 16.5 2.23 6100.00 59.65 325.55 3835.66 3962.21 N 1155.26 E 4127.2 16.3 1.14 6125.00 59.70 324.42 3848.28 3979.88 N 1142.88 E 4140.7 16.0 3.91 6150.00 59.83 323.00 3860.87 3997.29 N 1130.09 E 4154.0 15.8 4.93 6175.00 59.79 322.46 3873.44 4014.49 N 1117.01 E 4167.0 15.5 1.87 6200.00 60.09 321.73 3885.97 4031.56 N 1103.72 E 4179.9 15.3 2.80 6225.00 60.33 320.29 3898.39 4048.42 N 1090.06 E 4192.6 15.1 5.09 8 OF 9 AK1116GCM145 • S . gill*Ciata A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L- PAD Well: L-200 Location: Wellhead, N.Slope Borough/ Prudhoe Bay Unit Job Number: AK1116GCM145 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 6250.00 60.77 318.57 3910.68 4064.96 N 1075.91 E 4204.9 14.8 6.24 6275.00 61.09 317.54 3922.83 4081.21 N 1061.30 E 4216.9 14.6 3.82 6300.00 61.10 316.77 3934.91 4097.25 N 1046.42 E 4228.8 14.3 2.70 6325.00 61.41 315.83 3946.93 4113.10 N 1031.28 E 4240.4 14.1 3.52 6350.00 61.77 314.70 3958.83 4128.72 N 1015.80 E 4251.8 13.8 4.23 6375.00 62.22 313.99 3970.57 4144.15 N 1000.01 E 4263.1 13.6 3.09 6400.00 62.57 313.49 3982.15 4159.47 N 984.01 E 4274.3 13.3 2.26 6425.00 63.19 312.21 3993.55 4174.60 N 967.69 E 4285.3 13.1 5.19 6450.00 64.05 311.04 4004.66 4189.47 N 950.95 E 4296.0 12.8 5.42 6475.00 64.69 310.89 4015.47 4204.25 N 933.93 E 4306.7 12.5 2.62 6500.00 66.19 310.72 4025.86 4219.11 N 916.72 E 4317.6 12.3 6.03 6525.00 67.83 310.36 4035.63 4234.07 N 899.23 E 4328.5 12.0 6.69 6550.00 69.20 309.77 4044.78 4249.04 N 881.43 E 4339.5 11.7 5.90 6575.00 69.61 309.28 4053.58 4263.93 N 863.38 E 4350.5 11.4 2.46 6600.00 69.53 309.09 4062.30 4278.73 N 845.22 E 4361.4 11.2 0.78 6625.00 69.96 308.84 4070.96 4293.48 N 826.98 E 4372.4 10.9 1.96 6650.00 69.91 308.82 4079.54 4308.21 N 808.69 E 4383.4 10.6 0.21 6675.00 69.07 308.97 4088.29 4322.91 N 790.47 E 4394.6 10.4 3.41 6700.00 68.17 309.30 4097.41 4337.60 N 772.41 E 4405.8 10.1 3.80 6725.00 67.67 309.03 4106.81 4352.23 N 754.45 E 4417.1 9.8 2.24 6750.00 67.57 309.01 4116.32 4366.79 N 736.49 E 4428.5 9.6 0.41 6775.00 68.09 309.00 4125.76 4381.36 N 718.50 E 4439.9 9.3 2.08 6800.00 68.84 308.97 4134.93 4395.99 N 700.42 E 4451.4 9.1 3.00 6825.00 68.96 308.95 4143.93 4410.65 N 682.28 E 4463.1 8.8 0.49 6850.00 68.49 308.77 4153.01 4425.27 N 664.14 E 4474.8 8.5 2.00 6875.00 68.87 308.68 4162.10 4439.84 N 645.97 E 4486.6 8.3 1.56 6900.00 68.08 308.78 4171.27 4454.39 N 627.83 E 4498.4 8.0 3.18 6925.00 68.16 308.67 4180.58 4468.90 N 609.73 E 4510.3 7.8 0.52 6950.00 68.46 308.82 4189.82 4483.44 N 591.61 E 4522.3 7.5 1.32 6975.00 69.22 309.08 4198.85 4498.10 N 573.48 E 4534.5 7.3 3.19 7000.00 69.18 309.18 4207.73 4512.85 N 555.35 E 4546.9 7.0 0.41 7025.00 69.32 309.09 4216.58 4527.60 N 537.22 E 4559.4 6.8 0.65 7050.00 69.59 309.54 4225.36 4542.43 N 519.11 E 4572.0 6.5 2.00 7075.00 70.25 309.35 4233.94 4557.35 N 500.98 E 4584.8 6.3 2.73 7100.00 69.61 309.33 4242.52 4572.24 N 482.82 E 4597.7 6.0 2.56 7109.00 69.68 309.31 4245.65 4577.58 N 476.29 E 4602.3 5.9 0.81 Final Station Closure: Distance: 4602.30 ft Az: 5.94 deg. 9 OF 9 AK1116GCM145 • • ofr, i/7 mss; THE STATE Alaska Oil and Gas of e ee cc KA. Conservation Commission }�z � 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �� ... ' Main: 907.279.1433 OF g1i�e` Fax: 907.276.7542 www.aogcc.alaska.gov . '''ED MAR 0 `2'2.017 Ken Allen Drilling Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU L-200 Permit to Drill Number: 204-001 Sundry Number: 316-508 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, CathyFoerster Chair DATED this Gty day of October, 2016. RBDMS OCT 2 4 2016 STATE OF ALASKA WALASKA OIL AND GAS CONSERVATION COMMION 5 C, { 0 3 2016 APPLICATION FOR SUNDRY APPROVALS /a 401/4 • 20 AAC 25.280 �iy" � C A 4..� 1. Type of Request: Abandon El Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ® • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing El Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-001 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23191-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 Nom PBU L-200 • 9. Property Designation(Lease Number): 10. Field/Pools�"�1-11 �J`[e!"� (:11./ tie) ADL 028239&047447 • PRUDHOE BAY,,ORIOrl OIL A/p,6-,/,‘,, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 13067 • 4356 • 7122 4239 1840 7122 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"X 34" 31 -110 32-110 Surface 3840 10-3/4" 31 -3871 31-2653 5210 2480 Intermediate 7843 7-5/8" 29-7872 29-4485 6890 4790 Tieback Liner 266 4-1/2" 7282-7548 4302-4413 8430 7500 Liner 5515 4-1/2" 7537-13052 4409-4356 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7870-13008 4484-4355 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 RI Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch IZI Exploratory ❑ Stratigraphic El Development RI • Service 0 14.Estimated Date for Commencing Operations: October 15,2016 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ® • 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned El 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 Signature k--,r....- Phone +1 907 564 4366 Date < j /7 f COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31 -‘3 08' Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 50 /-- f t2 3 Jr- )C 0- /'1/tfZvla✓ pr� v-i-r4 � /---f /_,,, z,5-00 ,CJS 1_ Post Initial Injection MIT Req'd? Yes 0 No ' G( Y(pro!J ✓CGl 1)-c. t% 2-b '=f C Z J- Spacing Exception Required? Yes 0 No CH Subsequent9" Form Required: /el 6 F (tq I t 4. /9 APPROVED BYTHE — Approved by: /y' , COMMISSIONER COMMISSION Date:10- 20 V77._ /O/2 a// ORIGtNALr ta��c6 RBDMS OCT 1 4 2016 4- 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 i GP6Is ewer Izith19w hJ L-200 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 e-line video log following coil operations suggested coil sidetracked out of the junction rendering the well inoperable. . 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 latera ri • - _ ._- "k-■•4111i - . • - o recover their reserves. BP is re ing a evia ion rom 20 AAC 25.112 Well Plugging requirements. The laera s 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 .3 gbh Cur- re, / 4.4 Estimated Start Date: January 10th, 2017 gfeL Z-2.41 , ‘'---41-1 —7744.-)' 4) Al-i-'"A'*'' .-"f".. e"c1/4e e--'4'kz):-.74-4-4°--*6 .3-7(..- 6 4-'6). z/Z, is J( 4_ . . s b '"e.. 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. pow z t-7051 7 E Jet Cut 3500' v i P 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 • r 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 perf 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-Rig 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 • • 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 • • • 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 . • y� . 3� :S eMc6:ro-i Vie.. - - :i' i.-,.._r1 1 .„l` 'i .'ltl? I allial to, It. Vint' itlStS St 4, :t ,bC1 114I.�4m mi. $ 1 wc�-- i S 1 ICAC _-...-... '..,<,...,....a a_ ....L... ay.�...w... -r_+-..a. .rr.rr-.u.._...a._w. !..r.....r._..._._wa.._.....i,....a.....wr ..w-.r _..:c.a -....._�....»..+-s.a..r.a 3 , i • d 4 : YOC 3 .. t # , i p{ 7 } i { I i j It 1 014.4 s i i 6 t i f ..,..-. } I H6 4 :'aC =ft bolt ^JIC me 746 sot ma mara :' 1444 VIC 11-1t •414 44)64 .MO 466 +YC 46C 044 SACC ICK Vent*bra a S7 S7 lag 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.loepp@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(ilalaska.qov 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 Victorialoem@alaska.gov 3 IFILE= 4-1/16"CM/ VELLI-E_A D= 11'RAO • ES: WELANGI_ . , '1111YNOTL E>70°@ 6602' /2"CHROME TBG""LEM @ 7315'IS ACTLINTOR= BAKER L2iCOLLAPSED.CAN NOT PASS 1HRU WIN AM' OKB.EIEV= 77.6 1 i r I REF TOOLS.ELEA/= 77.6' -... 48.99' 20#cow) --I 114' ' \ 985' H 10-3/4"TAM PORT COLLAR ! KOP= 380' AsixAngle= - 96°6 11569 , ......„--, I I 2174' —14-1/2"HES X NIP,113=3.813" 41 Datum MD= 7515' Gp/'' e.) k GAS uE1 IVANDHELS .. ..., . _ V 7i Datum TVD= 4400'53 / I ST WO TVD CV TY FE VLV LATCH FORT DATE 10-3/4"CSG 45.5#,L-80,C"9_95" — 3871' 6 3448 2436 60 KBG2Miff BK 0 11/04/15 A I,' . , . 5 3565 2495 60 KBG2 MY BK 0 11/21/09 Minimum ID = 3.813" @ 2174' IKI%*-"CS +4, 4 5373 34.33 58 KBG2 DAY BK 0 07103/11 /,'• 57 3 5490 3498 56 KBG2 DMY BK 0 11/21/09 4-1/2" HES X NIPPLE / 2 4 6645 4068 69 KBG2 DMY BK 0 11/211091 7-5/8"X 9-7/8-TOC — 5800' 1 6888 4157 69 I KBG2 EMPTY BK - 07/03/111 ,41. RA TAG H 6983' ..=11111 MIR 7051' H4-1/2"BKR CM)SLCING SLV,ID=3.813" ,v!:;•"1;7—------..;.4--2.4 te, 4-1/2'SGM-ICIPG-G4 — 7035' olp".. 18111:%• — 70er —7-5/8'X 4-1/2"BKR PREM FKR,ID=3.875" kilLT1-DROP SUB,C"3.958" • 14 074$ .6., . '.•,‹ Elm 71 27 H4-1/2"HES X NIP,10=3.813" 4-1/2"SGM-IsOFG-GA H 7066' ,... .......- ....nz ,:i.,: ...o.... --.:K. $ 7122' —4-112"PX PLUG(11/05/15) MIJLTI-CROP SW,t)=3.958' .7,‹ 'A 7193' _H4-1/2"I-ES X MP,E)=3_813" N. 4-1/2"TBG, 12.6#,13CR-80 VAM TOP H 7250' 'ftr . RA TAG — 7270' .0158 bpf,0=3.958' .- , • 7264' H4-1/2"X 5-1/2'XO,ID=3.940" 3.958" ...r.4 4-1/2'TBG, 12.6#L-80 13T-M, — 7296' v , g 727T —5.75'BKR SEAL STEM _ .0152 bpf,ID • 4 4. r' ..., . (SEALS REM)VED),ID=4.83-] = IR A 5-1/2-X 4-1/2"XO,ID=3.930" — 7301' 7282' I—7-5/8'X 4-1/2"BKR ZXP LTP w TTEBK,I)"5.750' if 1 BA KER HOOK HA NGBR — 7315' - "1 12 (0 _8a'$ L2(0Ba LEN1 VONDOVii 65' w/L2 NON-SEALING LEM,ID=3.71" 7320'-7331' y ---s'N. OPENING WIDTH=3.33" COLLAPSED LEM-CAN NOT PASS BY — -7315 ..,"' N. C6a PBTD H 13043' (SEEN IN D.H.VIDEO)(12/14/12) 35 RA TAG — 7375' III 7315'-13044' 6-3/4"OBa LATERAL,ID=3.958' .. 13' 7-5/8'X 5-1/2'BKR ZXP LTP,ID=4.94" 7386' m' 7398' —4-1/2'MILE SHOE,0=3.958" 4.: 5-1/2"X 4-1/7 XO,E)=,3.930' —I 7405' ----"*.--1 MIK Ll (OBIo)LEM WINDOW 64' ,„ Li (OS b) 7424'-7435' BAKER HOOK.HANGER — 7419' Wi yi OPENING WIDTH=333 w/L1 NON-SEALING LEM,ID=3.71" .:, ...1.0'' V -..., ICEib PBTD --1 1298T PERFORATION SUMMARY REF LOG: ',.'. 7419'-12988' 6-3/4"OBb LA I ERAL,ID=3.958" ANGLE AT TOP PERF: , Note:Refer to Production 136 for historical perf data ' .-------. 7537' 1-17-5/8"X 5-1/2"BKR ZXP LM TOP PKR SIZE SFF 1 INTERVAL Opn/Sqz DATE 1111 17 4-1/2" SLID OBa 7392-13000 0 02/18/04 54 \ ic 7548' —4-1/2^MILE SHOE,ID=3.958" 4-1/2' SLTD OBb 7497-12944 0 02/12/04 4-1/2' SLTD 013d 7870-13008 0 02/04/04 3 755T H5-1/2"X 4-1/2"XO,li=3_930" RA TAG H 7663' : i t 1 7-5/8'CSG,29.7#,L-80 BTC-P4 ID=6.875' H 7872' 1 1 L-2001 7572'-13052' 6-3/4"OBd LATERAL,ID=3.958" Oeiri MID --, 13050' -----____ DATE REV BY COMMENTS DATE REV BY CO?JU'1TS ORION UNIT 02/22/04, N9ES ORIGINAL COMPLETION 06/26/15 TFAIJAD PILLED ROCK CATChER(06/20/15) WELL: L-200 11/25/09 D-16 IO 12/03/15 G.13/.11.1) GLV C/O(11/04/15) FIT No: 2040010(020)(030) 04/09/12 TBC/JM) SET ROCK CRTC (04/07/ 12/03/15 GJB/JM) SET PX PLUG(11/05/15) AFIND: 50-029-23191-00(60X61) 04/10/12 JFK/JM) GLV CIO(04/08/12) 07/25/16 JNJJMD ACCED REF&BF ELEV SEC 34,T12N,R11E,2567'FSL&1575'FEL 12/18/12 RRW/JR4)FCX)/FISH ROO<CATChER/COL LEM(12/14/12) - 01/15/13 GJB/JMD SET ROCK CATCHER(12/31/12) I _ BP Egploration(Alaska) TREE= 4-1/16"CIW WELD-CAD= 11'FMC -'3S NOTES: WELLANGLE>7703 "i@5.6602'. ACTUATOR= BAKER PRE-RIP �,� oo /2"CHROME TBG"'LEM(m 7315'IS L COLLAPSED.CAN NOT PASS THRU WITH ANY OKB.ELEV= 77.6' I TOOLS. BF.ELEV= 53.80' KOP= 380' 20#COND H 114' v Max Angle= 96°@ 11569' I 985' -110-3/4"TAM PORT COLLAR Datum MD= 7515' 2174' -14-1/2"HES X NP,ID=3.813" Datum TVD= 4400'SS GAS LFT MANDRELS 10-3/4"CSG.45.5#,L-80,ID=9.95" H 3871' ST MD ND DEV TY FE VLV LATCH PORT DATE 6 3448 2436 60 KBG2 DMY BK 0 11/04/15 Minimum ID = 3.813" @ 2174' 5 3565 2495 60 KBG2 DMY BK 0 11/21/09 4-1/2" H E S X NIPPLE tl�l�l! 4 5373 3433 58 KBG2 DMY BK 0 07/03/11 Z liir►1111 3 5490 3498 56 KBG2 DMY BK 0 11/21/09 4-112"X 7-5/8'TOC -1 5587' '.tf l�l�'' /'4�i`ttlb. k'1 2 6645 4068 69 KBG2 DMY BK 0 11/21/09 7-5/8"X 9-7/8"TOC - 5800' if,/, : 1 6888 4157 69 KBG2 EMPTY BK 07/03/11 RA TAG H 6,983' . 1 ( All 7051' H4-1/2"BKR CMD SLDNGSLV,D=3.813" 1-.919 ' �-I 4-112"SGM NDPG CA 7035' '0S-164919' 7087' 7-5/8"X 4-1/2"BKR PREM F'ICR D=3.875" MULTI-DROP SW,D=3.958" .4411114,4"� `I It��4 it; y, •` 9e� 7122' H 4-112"I-ES X NP,ID=3.813" 4-1/2"SGM-NDPG-CA 7066' w 4E `' t 7122' -14-1/2"PX PLUG(11/05/15) MULTI-DROP SLB,ID=3.958" .71.: 4-1/2"TBG,12.6#,13CR-80 VAM TOP -1 7250' 7193' 14112"I ES X NP,ID=3.813" .0158 bpf,D=3.958" -- "iii.> RA TAG I 7270' i;!� 7264' -14-1/2"X 5-1/2"XO,D=3.940" 4-1/2"TBG,12.6#L-80 BT-M, 7296' *1,,. �� 7277' -5.75'BKR SEAL STEM 0152 bpf,ID=3.958' �� ." (SEALS REMOVED),D=4.83 5-1/2"X 4-1/2"XO,D=3.930" - l 7301' 16 7282' 17-518"X 4-1/2"BKR ZXP LTP w/TRK,D=5.750" BAKER HOOK HANGER H 7315' .... ) L2 (OBa) L2(OBa)LEM WINDOW 65 w/L2 NON-SEALING LEM,D=3.71" / 1-.= 7320'-7331' COLLAPSED LEM-CAN NOT PASS BY - -7315 1� *" OBa FBTD H 13043' OPENING WIDTH=3.33" (SEEN IN D.H.VIDEO)(12/14/12) RA TAG -1 7375' I--:� 7315'-13044' 6-3/4'OBa LATERAL,ID=3.958" r- 7-5/8"X 5-1/2"BKR ZXP LTP,D=4.94" - 7386' 1 �� 7398' -14-112"MULE SHOE,D=3.958' 5-1/2"X 4-1/2"XO,D=3.930" 7405' , L1 (OBb)LEM WINDOW 64' BAKER HOOK HANGER H 7419' I---4= 7424'-7435'L1 (OBb) OPENING WIDTH=3.33" w I L1 NON-SEALING LEMID=3.71" -0--- OBb PBTD H 12987' PERFORATION SUM 4A RY REF LOG: 1 7419'-12988' 6-3/4"OBb LATERAL,ID=3.958" ANGLE AT TOP PERF: Note:Refer to Roduction DB for historical perf data y.''--------►�i4t + :9YCE. 7537' -17-5/8"X 5-112'BKR ZXP LNR TOP PKR I SIZE SPF INTERVAL Opn/Sqz DATE r• 4-1/2" SLID OBa 7392-13000 0 02/18/04 \ 4-1/2' SLID OBb 7497-12944 0 02/12/04 hit 7548' �4-112"MULE SHOE,D=3.95$' 4-112" SLTD OBd 7870-13008 0 02/04/04 7557' -15-1/2"X 4-1/2"XO,ID=3.930' RA TAG - 7663' I 7-5/8"CSG,29.7#,L-80 BTC-M,D=6.875" H 7872' I I I IL-2001 7572'-13052' 6-3/4'OBd LATERAL,ID=3.958" OBd FBTD - 13050' -_,__ DATE REV BY COMMENTS DATE REV BY COMMENTS ORION INT 02/22/04 N9ES ORIGINAL COMPLETION 06/26/15 TFA/JMD PULLED ROCK CATCHER(06/20/15) WELL: L-200 11/25/09 D-16 RWO 12/03/15 GJB/JMD GLV C/O(11/04/15) PERMIT No: 2040010(020)(030) 04/09/12 TBD/JMD SET ROCK CATCHIER(04/07/ 12/03/15 GJB/JMD SET PX PLUG(11/05/15) API No: 50-029-23191-00(60)(61) 04/10/12 JPK/JMD GLV C/O(04/08/12) 112/10/15 JT/JMD PRE-RIG CMT SEC 34,T12N,R11E,2567'FSL 8 1575'FEL 12118/12 RRW/JMD FCO/FISH ROCK CATCHER/COL LEM(12/14/12) 01/15/13 GJB/JMD SET ROCK CATCHER(12/31/12) BP Exploration(Alaska) WELLHEAD= 11'FMC P R O P O ® L-200A MECSGBTBG"" y� NOTES: WELL ANGLE>70° EVACTUATOR= - R� OKB.B_EV= 77.6' I I 985' H i 0-3/4"TAM FORT COLLAR BF.BBV= 53.80' ,(1;q',' -I, 1/2"HES X NP,D=3.813" KOP= 380' 20#COM) H 114' I I Max Angle= _" Datum MD= Datum TVD= 4400'SS GAS UFT MANDRELS 1(7-s/' WIIII'SIOCK(_/ t ) - 3000' STI MD TVD DEV TY FE VLV LATCH PORT DATE 10-3/4'CSG.45.5#,L-80,D=9.95" - -3000■ 4 3422 7-5/8"CSG,29.7#,L-80 XO TO 13CR-80 -I • 2 728000' 7C 3 7241 41 VAMTOPHC,D=6.875" 1 8094 Minimum ID =3.725" o@3 8874' 1 1 8164' HA. Ir:,.,i 1 t;x IA ,t„ , to 4-1/2" HES XN NIPPLE t 8235' -14-1/2"SGM1-NDPG-CA SWGLE DROP SAPPHIRE RA TAG 4-1/2"T BNG COLLAR H 8266' N GAUGE,D=3.864" 8311' --I 7.5/8"X 4-112"HES TNT PKR,13=3.856" RA TAG 7-518"CASNG COLLAR H 8320' I-"-• 8316° -i4-112"NCS FRAC PORT,D=3.958" t ^ 8368' H4-1/2"NCS SCREEN SLEEVE,D=3.958" LJ'----'--1 8396' -j 7-5/8"X 4-1/2"HES TNT PKR,D=3.856" L 8402° -14 1/2"NCS FRAC PORT,D=3.958" I 1 8412' -I4-1/2"HES X MP,D=3.813" 8421' H4-1/2"NCS SCREEN SLEEVE,D=3.958" ' 1 S. -----I8449' H7-5/8"X 4-1/2"HES TNT PKR,D=3.856" t: i • i 8456' H/1.1/2"NCS FRAC PORT,D=3.958" I I 861W -14.1/2"HE'S X NW,D=3.813" PERFORATION SUMMARY IIIEBEr- �"� 8525' H4-1/2"NCS SCREEN SLEEVE,D=3.958" REF LOG: ANGLE AT TOP FERF: \`� X 8563' -17-5/8"X 4-1/2"HES TNT PKR,D=3.856" Note:Refer to Production DB for historical perf data ^ 8558" H4-1/2"NCS FRAC PORT,D=3.958" SIZE SPF ZONE INTERVAL Opn/Sqz DATE LL& ' 4-3/8" i OBa 8383-8388 ) I I 8629' H4-1/2"I ICS X NP,D=3.813" 4-3/8" 1 OBb 8452-8557 0 i i i i um iii 8639' H4-1/2"NCS SCREEN SLEEVE,D=3.958" 4-3/8" 7 OBc 8548-8553 0 4-318" 7 OBd 8658-8663 0 IV 8666' -17-5/8"X 4-112"HESS TNT PKR,D=3.856" 4-3/8" 7 013e 8772-8777 0 V e:' 4-3/8" 7 OBf 8820-8825 0 =I 8672' H4-1/2"NCS FRAC FORT,D=3.958" I I 8747' -4-1/2"FES X NP,D=3.813" ® 8757' J---I4-1/7"NCS SC ITN SI.E 1/E,D=3.958" 1 L 8784' H 1-5/8"X 4-1/2'HES 1IYT PKR,D=3.856" 4-1/2"TBG,12.6#,13CR-80 VAM TOP - 6991' I if-----18847" -11.1/2"HI X NP,D=3.81.1" .0152 bpf,D=3.958" I In--I 8874' H4-1/2"HES XN NP,ID=3.725" 7-518"CSG,29.7#, 13CR-80 VAM TOP HC, - 9114' , 8891' _-I4-1/2"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: t /_ 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) • e • = al 1 CO S 1a3 'I' _ ''d g 1 H72 1 4 J. 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(is o to 9 �lo O _ 1 d41 O 90G<i: S 10 O' it/l ds o o 0 0 0 0 0 �P / o o to o o o to to rt N N ,- .-1 Aea aad siaiie8 0 a • • • 16EE.. 4-1/16'CM/ IINELLHAD s 11RC - IR i0 0 ; SAFFTY NOTES:WEILL ANGLE>70 ACIUATER‘. BAKEP R E-R IG I ""4-1/2"CHROME TBG?"*LEP1 93 7315'IS I-- 1 12 I 1 COLIAPSED,CAN NOT PASS new WITH AMY 0KB REV- 7.7 6' 1BE REV= 5180ITOOLS. ' . *OP s 3817 [209 COPE)H 114' ii 11, / I,MIX Angie s 96"4,4 11569' 11111110. ,_ 985' i0-i'TAM POITT 03t LA R kW=M3= 7515 3cP ,° I -. --.- :-"1,--- 2174' 1-Fin-7ick£S NP.ID=1813" 1 roal-tartIVO=----4466.95 GAS UFTIAVCRELS [1()314-CSG 45 5a.I,60,ic,776-iiiy--Filial. _.] ST MD'IVO CIEV TYPE VLV LATarl PORT DATE 6 3448 1 2436 80 KBG2 OW BK 0 1004/15 Minimum ID=3.813 tg 2174' rat' VICAX:-gat 5 3565 2495 60 ICBM OW BK 0 11121/09 4L.If Te./.1tVelt 4 5373 3433 58 1(802 CAW BK 0 07/03/11 4-1/2"HES X NIPPLE i t,-• ,K1,',s,tketeX„/ 3 5490 G2 ---- , - —,----- 3496 56 103OMY BK 0 11/21/09 It 1 IT X 7-5/8"TOC I 5587' i- A4 v.-N.:4°41.1N, .A! ,049,?.:, 2 6645 4068 69 K8G2 CM( BK 0 11/21/09 17-5d8'X 9-7/13'TOC' 5800' .01frX...„4,,,,"It....174;,..41.1....421 1 6888 4157 89 103G2 EMPTY BK - 07E13/11 4 Item"TAG-t 8983' . to.nu •4-, 4,04:ft 7051' 4-1/T SKR CND SLUNG SLV,13..3 813" I Wel/•dr e•111"P 4-1/2*SGM-NOMCA --I 7036' i to:t 0'-'...VW AN r i; ?oar -1.7581'X4112'BKR FREAA RIR ID=3.875:_j 'e,'in••;krit‘i r4 li 1.41.11-0170PSL8.ID=3-958" ..,. ..%..\05:44Z le 7122' -4-I!?HES X 91.,0=3.613" 1 4-lir SGM tore-co, TM. :41 — . r. ---7122' ' 4-1/7 iii'Fill a i iTioitis3 1 MULTFOROP SUB,ID s 3958" • 4 Tel 7193" -{4-1/2"HES X MP 0=3 813'1 41/2'IBG,12 IR,13CR80 VAIN TOP 7250" 49 .015814)1,0.3958' .1, Ir RA TAG 270 - ..,:• 7264' 4-112'X 5,172"XO,Ds 3$40' : -7 ' l• ,.4 /1 ••5 72 '1-575'BIM SEAL STBA 4-112-TBG,1244 1-8013T-M, 7296' Iii,..,.... 77 I•,•• K40 AC 0; (SEALS RRADV133),ID=483' .0152 bp(,ID s 3.958- et 1.1. , f5-1/2"X4-VT X0,Ds 3 930' 7301' 1-320/1?, 7282' /-518^X 4-1/2'SKR ZXP LlPtv rtE8K,ID--,5750" I.2 0013. ii3#704E4HOOK IIANGen 7315' \ 12(08*) 1E27 .f L2 NON-SEALING LEIA El s 371' ., ). ts. 7320-733t X 4' rO(AAD11- ' ,FSED Ceti:.CANiicr PASS BY -7315 •,, 08a P8113 1304T 04#K ,..%e, (SB3i INH.D. 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F7419'-12988'6-3/4'080 LATERAL.ID=3.95r AMSLE A T TONERE Note:Refer to Ftoducbon 08 f or*tone&pert Belamu ri...—---tli A 15 7537' -17-5/8"X 5-1/2'BKR ZXPost TOP ROT I SEE SPF INTERVAL 0en/Sq2TIME 14 IN$ 4-1/2' dib EiBa- 7392 "13000 ii - iltiiiikm 51 li 7548" -{41/2'MULESHOE,ID=3.9511'j 40 41/2' SLID OE* 7497-12944 0 I 02/12704 7567'j---15.1/2"X 4 1 Ir XO.ID=3.930'I 4-1/2' SLID 013d 7870-13008 0 _117./04/04_ ' if 1=0 7563---- 1 , l!-5ter CSG,29.70,t.-aosit-ht 0.6.875'1-1., nor L-200 7572'-1 3052'6-3/4'OM LATERAL,ID=3 958' OBd 1113TD GATE REV BY COMENTS (LIE REV BY 0098.ENTS ORM 0141 02/22404 P OF8G8(4AL COMPLETION 06/26115 TFAIJIAD P.1L133 ROCK CATCFEFT(osizos) AELL 1 200 11125109 0-16 MVO 12/03/15 GB/3M)GLV C/0(11/0415) PEEWIT Pb 2040010(020)(030) 047119/I27607.893 6EF120-&EkTEittO iciiicgiiiiiiiiicdisia—b—git PX MISS(1l40511 -- ARM, 50-029-73191-00(60)(61) 04/10/12 .FKJJ1,43 GLV 00(04/08/12) 12/10/15 MJ143'PRE-P13 am -r SEC 34,TIN RI 1E.2567'FSI&1576 EEL 12/18112 R8AVJA43 FOD/FSH ROCK CATCHFRK:01 LEM(12/14/12) 01/15113 5-831.80 SET ROCK CATC1ER 112731(12) I OP Esc plorabon(Alaska) L-200A PTD 13 9/1 9/20 1 6 S • 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 Responsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist l 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 11 work)the initial reviewer will cross out that erroneous entry and initial then 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. ~Q if - D.o 1 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 7 ~ (Count does include cover sheet) Page Count Matches Number in Scanning freparation: V YES BY"é?0 Dateak/Db If NO in stage 1, page(s) discrepancies were found: Organizing (done) o Two-sided 11111111111111 II III RES CAN DIGITAL DATA t.i'Diskettes, No. , o Other, Norrype: o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: Date:4-4ðfo Date 3 /~ Db ~ X 30 ,= (I () + Date ? t~¡f) (p BY: ~ Project Proofing BY: ~ Scanning Preparation BY: C Maria ) Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 111111/1/11111111/1 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: vwP 151 11111111111111" 1/1 151 rnP I' = TOTAL PAGES Z/ (Count does not include cover sh et) V\J1f 151 r ft 11I11111111111 ,,1/1 151 NO -W/P YES NO 151 11111111/11I11 "III 11111111111111 "III 151 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS '`" I,F 5 Z009 1. Operations Performed: �+ ❑ Abandon ® Repair Well 13 Plug Perforations ❑ Stimulate ❑ Re- Entpdi> ud eeit W65 00%. GOIT96 1 0 ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other pr r.r°!E(8 ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 204 - 001 3. Address: ❑ Service ❑ Stratigraphic . API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 -029- 23191 -00 -00 7. Property Designation: \ Well Name and Number: ADL 047447 PBU L -200 9. Field / Pool(s): Prudhoe Bay Field / Orion 10. Present well condition summary 1358 5Yh qq Total depth: measured � 13W feetl� true vertical 4356 feet Plugs (measured) None Effective depth: measured 13067 feet Junk (measured) None true vertical 4356 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 7845' 7 -5/8" 7872' 4485' 6890 4790 Production Liner 5515' 4 -1/2" 7537'- 13052' 4409'- 4356' 8430 7500 Liner 162' 7 -5/8" x 4 -1/2" 7386'- 7548' 4347'- 4413' 6890 4790 Perforation Depth: Measured Depth: Slotted Section: 7870'- 13008' True Vertical Depth: 4484'- 4355' 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 Baker Premier packer 7087' 4227' 11. Stimulation or cement squeeze summary: Intervals treated (measured): &AMED DES 2009 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 ❑Service ® Daily Report of Well Operations ® Well Schematic Diagram N ell Status after work: ® Oil [I Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of 'm knowledge. Sundry Number or WA if C.O. Exempt: Contact Hank Baca, 564 -5444 N/A Printed Name Terrie Hubble Title Drilling Technologist Signature * Phone -4628 Date c Prepared B' Nw* Number �9 t J Terris Hubble 564 -4628 Form 10-404 Revised 07/2009 J q Su 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' M D. LRS MIT -OA TO 1,000# (FAIL) AND CMIT TAA 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 bbls neat meth followed by 438 bbls 9.8 ppg brine down TBG, up IA, taking returns to production on well #202. Pumped 25 bbls 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. FW P's = 0/0/240 5/7/2009 T /I /0= VAC /VAC /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 = VAC/VAC /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# 1 @ 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 1/2" 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 bbls 190 °F crude while Slickline brushed Tbg. Pumped additional 47 bbls 190 °F crude down Tbg followed by 48 bbls 120 °F crude to pump Slickline toolstring down hole. FW HP'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, SI @ casing valve. IA FL @ surface. SV, WV = Closed. SSV, MV = Open. IA, OA = OTG. NOVP. 8/28/2009 T /I /O = 280/400/360 IA Injectivity test. Established IA injectivity of 1 bpm @ 600psi w/ 5bbls meth, 54bbls crude. FWHP'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. S 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 & 2k #. 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 /I, TURNED WELL OVER TO PAD -OP. 9/15/2009 T /1 /0= 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, & 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 0 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 bbls 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 TAX 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 /0= 250/220/380 Circ -out, CMIT -TxIA passed to 1000 psi (RWO prep) Pumped 5 bbls 60/40 meth followed by 205 bbls 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 & IA 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. FW P'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, T /P, 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, LID 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, DIESEL/ 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 WELLTO 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 Printed: 12/10/2009 11:15:25 AM 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, 4EFF JONES AOr a r . INSP CM13 RETURNED CAL TO WAIVE STATE'S RIGHT TO WITNESS THE BOP TEST. BOP STACK To THE ADAPTOR SPOOL. - GREASE 0 1 8KE ANE) 1 4 1 66 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 ROPE. 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. M/U 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 MANDREU 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 L/D 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 UD 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 UD DUTCH RISER. 12:00 - 14:00 2.00 CLEAN P DECOMP CIRCULATE BOTTOMS UP TO GET CHEM CUT DEBRISIFLUIDS 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. -WU 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 UD 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 UD 4 -1/2" TUBING AND SPOOL i - WIRE WITH 11 JTS FROM 7295' TO 6840', HOLE SWABBING total of 7 bbls Printed: 12/10/2009 11:15:25 AM i • 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 -1/2" COMPLETION - NOTIFIED AOGCC, JEFF JONES AND JOHN CRISP O 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, LID 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 -1/8" 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 L/D 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 [-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-RhIs 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 W 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 HR 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 0 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 i 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 -13PH. -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 R/D 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: 12/10/2009 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. O 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 -BPH. - 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 OILW ELL REP AND RIG ELECTRICIAN. -USE CONSTANT HOLE -FILL AND SEE LOSS RATE OF Printed: 12/10/2009 11:15:25 AM • 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 -BPH 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 WU BHA FOR CLEAN OUT. P/U AND M/U 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 I 0 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 5' 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 WELLBORE. -P /U DP JOINT AND WU TO STRING. GREASE THE TOOL JOINT, CLOSE THE HYDRIL, BREAK CIRCULATION. PUMP Printed: 12/10/2009 11:15:25 AM 0 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 1' TO 7325'. WOB UP TO 17K -lbs. - CALCULATED LOSS RATE 105 -BPH. 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: 12110/2009 11:15:25 AM 0 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 1/8 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 5' 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 -BPH. CONTINUE TO WASHDOWN TO 7452'. Printed: 12/10!2009 11:15:25 AM • M I 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 L/D 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, L/D 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 /1 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 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 M/U 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 5' 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 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 ri tion of Operations P P 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 I -WIRE EQUIPMENT. 11:00 - 00:00 13.00 RUNCOMP 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 0 • 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 RUNCO RUNCMP -M /U 8' PUP AND 10' PUP. -M/U JT 163. -L OSS 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 WU TUBING HANGER. P/U HANGER ON LANDING JT AND M/U TO TUBING STUB. - TERMINATE I WIRE TO HANGER AND TEST. -R/U TO REVERSE CIRCULATE. 05:00 - 08:00 3.00 RUNCOMP 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 I -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 BOPSU 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 BOPSUP 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. Printed: 12/10/2009 11:15:25 AM TREE 4- 1/16" CIW L�e�oo SAFErv*ES: CHROME TUBING WELLHEAD = 11' FMC L` ACTUATOR= BAKER L1 & L2 KB. R EV = 77.6' BF. ELEV = 53.80' KOP = 380' DRLG DRA Max Angle = 96 @ 11569 985 10 3/4" TAM PORT COLLAR Datum MD = 7515' Datum TV = 4400' SS 2174' 4 -1/2" HES X NIP. ID = 3.813" 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 BK 0 11/21/09 4 -1/2" X- NIPPLE 2 6646' 4068' 68 KBG -2 DN1Y BK 0 11/21/09 RA TAG 6983 1 16888'14157 68 1 KBG -2 SO I BK 1 22 12/04/09 Sapphire pressure gauge 1035' 7051' 4 -112" BKR CMD Sliding SLV ID Sapphire pressure gauge 1066' _0 70$1' 1 7-5/8"X 4 -1,2" BKR Premier packer, ID = 3.875 7122' 4 -1/2" X nipple, ID = 3.813 4.5" 12.6# 13Cr -80 Vam Top tubing 7266 7193` 4 -1/2" X nipple w / RHGM Lack, ID =3.813 RA TAG 7270' 7277' 5.75" Seal Stem (Seals Removed), ID = 4.83" 7270' 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° 1 BAKER HOOK HANGER 7315 L2 (013a) 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 - 1/2" BKR ZXP LTP, ID = 4.94" 7386' 7315' 13044' 6 - 3/4" OBa LATERAL, ID = 3.958" 5 -1/2" X 4 -1/2" XO, ID = 3.930" 7405' 7398 472" MULE SHOE, ID 7 3.9 - 5 - 89 L1 (OBb) LEM WINDOW 64° w L 1 N KHANGER 7419' - - - - - - - - - - - - - - - - S EALIN G LE M, ID = 3. 71' L1 (013b) 7424'- 7435' - - - - - - - - - - - - - - - - OPENING WIDTH = 3.33' PERFORATION SUMMARY OBb PBTD 12987' REF LOG: ANGLE AT TOP PERF: F7419' 12988' 6 - 3/4" OBb LATERAL, ID = 3.958" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 4 -1/2" SLTD OBa 7392 - 13000 O 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 4 -1/2" SLTD OBd 7870 13008 O 02/04/04 7548` 4 -1/2" MULE SHOE, ID = 3.958" 7557 — f5-_1/2 -_ X_4-_ 1_ 1 2 ' XO, ID = 3.930" A R TAG 7663' 7 -5/8" CSG, 29.7 #, L -80 BTC- ID = 6.875" 7872' I I I I L -2001 7572'- 13052' 6 -3/4" OBd LATERAL, ID = 3.958" OBd PBTD 13050' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 02122/04 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, R11E, 2567' FSL & 1575' FEL BP Exploration (Alaska) ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 -~~`~~'~~~~ `~''1 ~' ~ ~~"~`~` ~ bp ~.~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 4~ 2009 b~as~C~ ~ii ~ Gas Cons. Camn~is~ion Anchoraga o`~ ~ r..~- -' DO ~ ~ ~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploretion (Alaska ) I~c. ~ Surface Casing by Conductor Mnulus Cement, Corcosion inhibitor, Sealant Top-off Report of Sundry Operetions (10-404) Date L pad S/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibftor Corrosion inhibitoN sealant date ft bbls ft na al L-Ot 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 IVA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580700 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 20115t0 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 !.-t 12 2022290 50029231290000 NA 5,5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA S NA 54.4 6/28/2009 1-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 1.-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA t NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 102 5/6/2009 L•215 2Q5127Q 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L421 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 • • T -~_ ~~- --. r r.~ ~' _ ~-~" b ~.- ~- -_ MICROFILMED 03/01/2008 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE F:\La~rFiche\CvrPgs_Inserts\Microfilm_Marker.doc . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and lor Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 ] 2] 3] 4] 5] 6] 7] Leak Detection - WLD EDE Disk L - 200 1 2..Jun-07 ,......J\Ý\,\}. \ . ~\þ~j jU~ 2: f¡ 20D7 S~,¡,~ () at..( -{)O { :t1 i 2> d3.f./ Print Name: (Ld --- CJt (~+-t lÁQ... {V1(À1Lv\ ~ Date: Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ?~SÀ;.jCH<::R.".J.G~fŒ¡vIE~¥JR~./l-:::G~<.>OfVì WEBSITE : '¡lJ1h1j'\J.iV~EMORYLCz3.(:;Or\il C.\Documents and Settings\PDS Anchorage - MPL\Desktop\TransmÌt__OriginaLdoc 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: ~ . STATE OF ALASKA ~.~ APR 2 6 7007 AlA~ Oil AND GAS CONSERVATION COM ION .. REPORT OF SUNDRY WELL OPERA1\IØfI.IS & Gas Cons. Commission D StimulateD on ~ TUBING PATCH D Waiver D Time Extension D D Re-enter Suspended Well D 5. Permit to Drill Number: 204-0010 / . "\....\..,....1 V....U 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory Service 6. API Number: 50-029-23191-00-00 / P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 77.6 KB j L -200 ~ ADLO-047447 ) 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ ORION SCHR BL OIL Pool / 8. Property Designation: Effective Depth measured 13067 / feet true vertical 4355.91 / feet measured 13067 I feet true vertical 4355.91 / feet Plugs (measured) Junk (measured) None None Total Depth Casing Conductor Surface Production Liner Liner Length Size MD TVD Burst Collapse 80' 20" 101.1# H-40 34' - 114' 34' - 114' 1650 650 3842' 10-3/4" 45.5 L-80 29' - 3871' 29' - 2653' 5210 2480 7845' 7-5/8" 29.7# L-80 27' - 7872' 27' - 4485' 6890 4790 5515' 4-1/2" 12.6# 1-80 7537' - 13052' 4409' - 4356' 8430 7500 162' 7-5/8"X4-1/2" 29.7# 12.6# 7386' - 7548' 4347' - 4413' Perforation depth: Measured depth: 7392' - 13008' True Vertical depth: 4349' - 4355' - ..:..sICANNED MAY 0 2 2007 - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 7269' Packers and SSSV (type and measured depth) 4-1/2" Baker PRM Packer o o o 7169 o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl SHUT IN SHUT IN Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure o o 13. Service x Contact Gary Preble WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Title Data Management Engineer Printed Name Phone 564-4944 Date 4/25/2007 RBDMS BFL MAY 0 2 2007 ~r"> Submit Original Only . . L-200 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 35' BAKER PATCH SET OVER GLM #3 FROM 4239'-4274' ELMD PATCH CONTAINS WEATHERFORD SMR-1 B GAS LIFT MANDREL. MINIMUM ID THROUGH PATCH IS 1.91". OVERALL LENGTH OF PATCH AFTER SETTING IS 41.2. WLEG IS 4.2' BELOW BOTTOM ELEMENT, AT 4278.2' *** JOB COMPLETE*** FLUIDS PUMPED BBLS I 1 DIESEL 1 TOTAL 12/27/06 Schlumberger NO. 4087 Schrumberger~DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~JAN 0 ß2üG7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # <t> ) 'Ii.... L~g Description . . ,~"~~àte . ",-_ .~<,t.~.::.;~"" Orion Prudhoe Bay BL Color CD . 10/28/06 1 l-14B 11414770 SCMT - V-211 10919914 CH EDIT USIT POC-GRI . 11/19/04 1 1 V-221 10919949 CH EDIT USIT (PDC-GR) (Prints sent 3/16106) 03/07/05 1 -- L-200 11555032 LDL 12/21/06 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 . ill 1\1 ¿\ V 'Jt\I\1 ~I np Date Delivered Received by ¿x¡../--DO ( ~ . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIONS D D D ~,lJb I'?·~-' 1. Operations Abandon D Performed: Alter Casing D Change Approved Program D 2. Operator BP Exploration (Alaska), Inc. Name: Repai0ell Pull1[]ng Opera!. ShuDwn Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic Stimulate D Other D Patch Liner WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 204-0010 3. Address: Exploratory Service 6. API Number: 50-029-23191-00-00 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 9. Well Name and Number: 77.6 KB PBU L-200 10. Field/Pool(s): PRUDHOE BAY Fieldl ORION SCHR BL OIL Pool 8. Property Designation: ADLO-047447 11. Present Well Condition Summary: Total Depth measured true vertical 13067 4355.91 feet feet Plugs (measured) Junk (measured) Effective Depth measured 13067 feet true vertical 4355.91 feet Casing Length Size MD TVD Conductor 80' 20" 101.1 # H-40 34' - 114' 34' - 114' Surface 3842' 10-314" 45.5# L-80 29' - 3871' 29' - 2653' Production 7845' 7-5/8" 29.7# L-80 27' - 7872' 27' - 4485' Liner 5515' 4-1/2" 12.6# L -80 7537' - 13052' 4409' - 4356' Liner 162' 7-5/8"x4-1/2" 29.7# 12.6# 7386' - 7548' 4347' - 4413' Perforation depth: Measured depth: 7392' - 13008' True Vertical depth: 4349' - 4355' - - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Packers and SSSV (type and measured depth) 4-1/2" Baker PRM Packer., I\M 1\ ~ 2007 o 5~ J~r'+ \f &. . o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVED DE C 2 8 2006 4/aska Oil & G as Cons. C . Anchorage ih71mlssi Collapse 650 2480 4790 7500 None None Burst 1650 5210 6890 8430 Surface - 7296' 7169' o o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 000 15. Well Class after Droposed work: Exploratory Development P Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o none x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Title Data Engineer Phone 564-4944 Signature ",... Form 10-404 Revised 04/2004 'RIG t~AL Þ'-{vt., Tubing pressure 255 o Service WINJ WDSPL Date 12/22/2006 Submit Original Only ~.. . . L-200 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY -¡"!!'I'I'" ......?+...?......... @'----::::::·-.:1:1\ ;', ': _co' m:: :," ,::' - :.~~ ,~·---:b V _', .,t:.:~.~:;;L::t::I::::::ib::';;~å:::~..~jlc.;:::::f¡L~'_ <iÚI 12/12/2006T/I/O=2230/2250/520 Assist slickline with CMIT Tubing x IA to 3000 psi. (TBG x IA ICOMM) PASSED TBG & IA Loss 50 psi 1st 15 min, loss 30 psi 2nd 15 min. Pumped 1.1 bbls diesel to test. Bled well down. FWHP's=880/880/500 'mrN.'.- n_N'mw-n 12/12/2006 *** JOB CO NT FROM 12-11-06*** PULLED 2 7/8 XX PLUG @ 7241' SLM PULLED NIPPLE REDUCER @ 7234' SLM SET 4.5 XX PLUG (4-1/4 PORTS) @ 7236' SLM CMIT TUBING & IA TO 3000 PSI PASSED *** JOB COMPLETE*** 12/21/2006 TIIIO = 100011000/520 - Assist E-Line (Eva I possible problem at GLM#3) - Pumped 367 bbls 180* diesel down lA, assisting E-line wI LDL. *** Job continued on 12/22/06 *** »r....._._...._._.·._._._._._.·._.·,',·.'.',','._._.'.'.'.'.,.,_.__________.____ ·mmA_._._._._._._._._._._._._._._".'.wm__'______________________._.___._.__.,om""__'_______________________-________._.,...'.'.'.'.'.'.'.'.'.'.'...'...............-.....-.-...-...-..,.....,.,',__.',',','.'.'.'...'.'.'.-.-g.-.-.-.-__._________.___"....'..".,,,'.'.'.'.. 12/21/2006 **** WELL SHUTIN ON ARRIVAL **** ATTEMPT TO LOG LEAK DETECT LOG FROM SURFACE TO 7230'. LEAK IFOUND IN GLM #3 AT 4259'. NO OTHER LEAKS FOUND. JOB INCOMPLETE. CONTINUED ON 22-DEC-2006 AWGRS. 12/22/2006;.*** Job continued from 12/21/06 WSR *** Assist E-Line (Eval possible problem at GLM#3) - Pumped 146 bbls (513 total) 180* diesel down IA while E-line runs LDL. Freeze protect TBG w/5 bbls meth, plug in hole and fluid packed, unable to freeze protect (notified FO), freeze protect flowline w/15 bbls meth. FWP's = 180/320/540 -A- """HV^···..n- _N'oW' 12/22/2006 CONTINUED FROM PREVIOUS DAY ATTEMPT TO LOG LEAK DETECT LOG FROM SURFACE TO 7230'. LEAK I FOUND IN GLM #3 AT 4259'. NO OTHER LEAKS FOUND. I ,JOB COMPLETE. WELL TURNED OVER TO DSO. FINAL TI 110 = 300/300/600. I ! *** Job complete*** FLUIDS PUMPED BBLS I 514 DIESEL 514 TOTAL . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey (~f'!..¡,..~k~¥:::. ~¥~'" ~'WÍ''1,¡'¡¡þ ~U 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ~. '[.rlf' e Co -'~·L EDE Disk L - 200 Caliper Report 25-Nov-06 1) 2) 3) 4) 5) 6) 7) Signed: (lit ~ (I./h n -) h lfi P /1/1 Q (A,IA it 0'" 1 ; i , OQ:t¡ç;<õ, .···Ii 'J,' '."4 ~·c . ,c, .~. "f"''''!''''':;' ...., Print Name: ;)tJ./-oo I 1Þ IL...{ ~1-G PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ;~OS;1.,¡\¡~:;HOP:..~~'3:'={êD;V¡E¡V10;q·/LGG.C:J¡¡n WEBSITE : V\}V1j\i\j.}J1E¡;Jl0FlY~t)G.cortiJ D:\OO _ PDSANC-2006\Z _ W ord\Distribution\Transmittal_ Sheets\Transmit_ Original. doc Scblumbel'gel' 0) )/D 0 ~/&fJ "ß\¡ 05/01/06 NO. 3776 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Artn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Borealis Well Job # Log Description Date BL Color CD V-204 10687698 MDT 08/05/04 1 L-200 40010090 OH LDWG EDIT OF MWD/LWD 02102104 2 1 L-200 L1 40010090 OH LDWG EDIT OF MWD/LWD 02/09/04 2 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 Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Date Oelivered: Received by: . 3 fV\0\.r~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 \- \ I C( JCA ~ '-1 /~Q~ API No. 50-029-23191-00-00 Permit to Drill 2040010 Well Name/No. PRUDHOE BAY UN ORIN L-200 Operator BP EXPLORATION (ALASKA) INC MD 13067 /" TVD 4356 / Completion Date 2/23/2004 ./ UIC N --- - --~---~-- ------ -- ---------- REQUIRED INFORMATION -- -- ------------ ------------ Completion Status 1-01L Current Status 1-01L Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD 1 GR, MWD / GR / RES 1 DEN / NEW / PWD, MWD 1 GR / RES Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name --------------- ~ L i·(D 0 Wrd LRpt Directional Survey Directional Survey ---- ----------- Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? yrtti) Chips Received? ~ Y / ~~ Analysis Received? ~ ---------------- -------_._-~--- --- Comments: (\1/<,() ~ r: .,( l [:' ~il\ \ l. ~ ---~- Compliance Reviewed By: (data taken from Logs Portion of Master Well Data Maint -~ Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 0 13067 3/23/2004 Also an Excel spreadsheet 0 13067 3/23/2004 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? .~"-'.. ry N N Formation Tops -....,.;.-:..! iJh¿\ (};-v'"~ ~ .7/-;'? 2¡yr~ 7~~0 a. v\ ¿. iflw, f1rIVVtL \:v ~ tv." I COVVt Date: RE" E"'" æ\, IE" [) , " ':, '.,:, (j '~' I''':, ,,,.\ ) STATE OF ALASKA ) ALASKA ulL AND GAS CONSERVATION COMMI~SION JUN 1 42004- WELL COMPLETION OR RECOMPLETION REPORT AND LOG , " ," r" ,', Ala$ka 011 B~,.Am;~~, Revised: 06/1 ~~~~MffY~li~n Production 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-001 13. API Number 50- 029-23191-00-00 14. Well Name and Number: No. of Completions 1a. Well Status: aD Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD / GR, MWD / GR / RES / DEN / NEU / PWD, MWD / GR / RES / Azimuthal DEN / NEU / AIM / PWD CASING, LINER AND CEMENTING RECORD Ii: §1;'ÇI"1~,~'::QE~JI;:!!!:ME>:li":I:$I;:r:r;INß'Q¡;~~ ;¡,:,'WQ,11 1il:";';IIJj0RIII,:I'¡I,:!'BOW~OMI',~III::'I:[()þl;,¡,::" : B~¡rtÖM"1 Surface 1 08' Surface 1 08' 29' 3871' 29' 2653' 27' 7872' 27' 4485' 7537' 13052' 4409' 4356' 7386' 7548' 4347' 4413' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2568' NSL, 3704' WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2223' NSL, 3698' WEL, SEC. 27, T12N, R11E, UM Total Depth: 277' NSL, 2530' WEL, SEC. 21, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583209 y- 5978290 Zone- ASP4 TPI: x- 583152 y- 5983224 Zone- ASP4 Total Depth: x- 578997 y- 5986513 Zone- ASP4 18. Directional Survey aD Yes 0 No 22. :, '::I~'. "I;<¡)ÁSII·~.JG :\:,,'; ":1' I'¡:: ::::"I$I;Z;, .'11,," 'II:: 20" X 34" 10-3/4" 7-5/8" 4-1/2" 7-5/8" x 4-1/2" 215.5# 45.5# 29.7# 12.6# 29.7# /12.6# A53 L-80 L-80 L-80 L-80 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 7870' - 13008' 4484' - 4355' One Other 5. Date Comp., Susp., or Aband. 2/23/2004 6. Date Spudded 1/19/2004 7. Date T.D. Reached 2/2/2004 8. KB Elevation (ft): 77.6' 9. Plug Back Depth (MD+ TVD) 13067 + 4356 10. Total Depth (MD+ TVD) 13067 + 4356 11. Depth where SSSV set (Nipple) 2949' MD 19. Water depth, if offshore N/A MSL PBU L-200 15. Field / Pool(s): Prudhoe Bay Field / Orion Ft Ft 16. Property Designation: ADL 047447 17. Land Use Perm it: 20. Thickness of Permafrost 1900' (Approx.) 111,:IØ~9~~t:I:;" ill:,'::~Ð.I:.Le¡;j'I:11 48" 13-1/2" 9-7/8" 6-3/4" N/A 24·;,:" .,', SIZE 4-1/2", 12.6#, L-80 260 sx Arctic Set (Approx.) 723 sx AS Lite, 338 sx Class 'G' 515 sx Class 'G' Uncemented Slotted Liner Uncemented Tieback Liner DEPTH SET (MD) 7296' PACKER SET (MD) 7169' ~5~ "I . ,I " 'AClp".'FRAc:~~~E::,'CE~E~J"SQ~E~E/:E7 "C;':1 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 125 Bbls of Diesel None OqfGfNAL GAs-McF 828 W A TER-Bsl -0- 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-BBl 6/10/2004 12 TEST PERIOD .. 829 Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl Press. 58C 1540 24-HoUR RATE 1,658 GAs-McF 1,656 W A TER-Bsl -0- CHOKE SIZE GAS-Oil RATIO 70 999 Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ,-SfL .jU" 1 (~ / (g\' 2ß··· NAME Ugnu Ugna Ma Ugnu MB 1 Ugnu MB2 Ugnu MC Schrader Bluff NA NB NC OA OBa OBb OBc OBd OBd GEOLOGIC MARKERS ') 29. MD TVD ') T ¡"ORMATION ESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 4201' 6466' 2830' 4000' None 6556' 4036' 6631' 4063' 6681' 4081' 6787' 6847' 6956' 4120' 4142' 4181' 7186' 4263' 7319' 4318' 7425' 4363' 7549' 4413' 7728' 4463' 4358' 12930' 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 ~JI ~ IJ 11 /J/J d_ T'tl T h IA' t t D t D/- _(I Ou Terrie Hubble ~ AO)v~ ~ I e ec nica SSIS an a e \9 ,. 1 PBU L-200 204-001 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: 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 t , f, ' ') STATE OF ALASKA) ALASKA "irL AND GAS CONSERVATION COMI\lHdSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD / GR, MWD / GR / RES / DEN / NEU / PWD, MWD / GR / RES / Azimuthal DEN / NEU / AIM / PWD CASING, LINER AND CEMENTING RECORD SErrlt\J~'OE~rHMD.' 'SËTTINß,Ði;PTHrYb' ': ::80LE.':'< ,Top I ;~Ö1i¡OM: "'I'1'op ,:' . BOJT0MII,'!,ISIZi:i.,> ' Surface 108' Surface 108' 48" 260 sx Arctic Set (Approx.) 29' 3871' 29' 2653' 13-1/2" 723 sx AS Lite, 338 sx Class 'G' 27' 7872' 27' 4485' 9-7/8" 515 sx Class 'G' 7537' 13052' 4409' 4356' 6-3/4" Uncemented Slotted Liner 7386' 7548' 4347' 4413' N/A Uncemented Tieback Liner 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: 2223' NSL, 3698' WEL, SEC. 27, T12N, R11E, UM Total Depth: 277' NSL, 2530' WEL, SEC. 21, T12N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583209 y- 5978290 Zone- ASP4 TPI: x- 583152 y- 5983224 Zone- ASP4 Total Depth: x- 578997 y- 5986513 Zone- ASP4 18. Directional Survey 1m Yes 0 No 22. WT.'PËRft.' 215.5# 45.5# 29.7# 12.6# 29.7# /12.6# " 11','1', , ,GAADE,' A53 L-80 L-80 L-80 L-80 20" X 34" 10-3/4" 7-5/8" 4-1/2" 7-5/8" x 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 7870' -13008' 4484' - 4355' 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 1/19/2004 7. Date T. D. Reached 2/2/2004 8. KB Elevation (ft): 77.6' 9. Plug Back Depth (MD+ TVD) 13067 + 4356 10. Total Depth (MD+ TVD) 13067 + 4356 11. Depth where SSSV set (Nipple) 2949' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: 1m Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-001 13. API Number 50- 029-23191-00-00 14. Well Name and Number: PBU L-200 15. Field / Pool(s): Prudhoe Bay Field / Orion Ft Ft 16. Property Designation: ADL 047447 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AXM'OQNJ: : I ",I!",, "":'I: .."1" Rl.Il!.lED'.' SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 7296' PACKER SET (MD) 7169' I, ' '~SI~,:,F~sm~~Ê.~çEfI.1ENT SQUEEZE, ETC. ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 125 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-Bsl Press. 24-HoUR RATE GAs-McF CHOKE SIZE GAS-Oil RATIO WATER-BSl GAs-McF WATER-Bsl OIL GRAVITY-API (CORR) 27. CORE DATA nr-r"r-I\ Ir::r"'\ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attckAi.Iip\œ~I1t¥t~ssary). Submit c,ore'chißs;if nene, state "none". None ~~~~ L?¿- Form 10-407 Revised 12/2003 APR - 1 2004 ORIGINAL Alaska Oil & Gas Cons. Commission Anchorage APR 6 D 1mJ~' ~ " \./ G CONTINUED ON REVERSE SIDE RBOMS Bft -28. NAME Ugnu Ugna Ma Ugnu MB 1 Ugnu MB2 Ugnu MC Schrader Bluff NA NB NC OA OBa OBb OBc OBd OBd ') GEOLOGIC MARKERS MD TVD 4201' 2830' 6466' 4000' 6556' 4036' 6631' 4063' 6681' 4081' 6787' 4120' 6847' 4142' 6956' 4181' 7186' 4263' 7319' 4318' 7425' 4363' 7549' 4413' 7728' 4463' 12930' 4358' 29. ') FORMATION TESTS Include and briefly summarize test results, List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEIVED APR - 1 2004 Alaska Oil & Gas Cons. Commission 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 ~.M2.e ~ Title Technical Assistant Date Ol{ -Ò / -Ol( PBU L-200 204-001 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments, ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00), ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain), ITEM 27: If no cores taken, indicate "None". ORIGINAL ITEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Page Legal Name: L-200 Common Name: L-200 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) 1/23/2004 LOT (ft) (ft) (ppg) (psi) (psi) (ppg) 1/29/2004 FIT 7,872.0 (ft) 4,483.0 (ft) 9.20 (ppg) 670 (psi) 2,813 (psi) 12.08 (ppg) 2/5/2004 FIT 7,450.0 (ft) 4,371.0 (ft) 9.20 (ppg) 650 (psi) 2,739 (psi) 12.06 (ppg) 2/13/2004 FIT (ft) (ft) 9.20 (ppg) (psi) (psi) 12.06 (ppg) 2/14/2004 FIT 7,348.0 (ft) 4,328.0 (ft) 9.20 (ppg) 650 (psi) 2,718 (psi) 12.09 (ppg) _/ --' Printed: 3/1/2004 9:51:13AM ~ , "\ , ) BP OperatiónsSummarlReport 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 1/17/2004 From - To Hours Task Code NPT 21 :00 - 22:00 1.00 MOB P 22:00 - 00:00 2.00 MOB P 00:00 - 06:00 6.00 MOB P PRE Phase PRE PRE 1/18/2004 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 SURF SURF SURF 0.50 DRILL P 0.50 DRILL P 12.00 DRILL P ") Page 1 of 28 . Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Exception Rig Move f/ L-21 Oi to L-200. Move Pit Complex from Rig. PJSM, Move Sub off well L-21 Oi, 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 w/ 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 R/U at interconnect, set cuttings tank and swaco unit, take on fresh water, finish R/U Diverter System, Mix Spud mud, Load 5" DP in pipeshed, R/U 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 1/2" surface hole from 255' to 1657' w/ a 1.83 deg motor, surveyed w/ 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 P/U 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: 3/1/2004 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 Page 2 of 28 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·. Ç.ode NPT 1/19/2004 18:30 - 19:30 1.00 DRILL P SURF 19:30 - 21 :00 1.50 DRILL P SURF 21 :00 - 22:30 1.50 DRILL P SURF 22:30 - 00:00 1.50 DRILL P SURF 1/20/2004 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 01 :00 0.50 DRILL P SURF 01 :00 - 09:00 8.00 DRILL P SURF 09:00 - 10:30 10:30 - 11 :00 11 :00 - 14:30 14:30 - 19:00 1.50 DRILL N SFAL SURF 0.50 DRILL P SURF 3.50 DRILL N SFAL SURF 4.50 DRILL P SURF Descri ptionof dperatipns Circulate hole clean wI 770 gpm 1475 psi 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. 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 MU new 131/2" 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 Continued RIH wI BHA #2, Shallow hole test MWD, OK 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. Drill 131/2" 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 = 1 0.7k FtLb GPM = 800 @ 2564 psi on Btm P/U 99k SIO 72k ROT 83k Clean plugged suction screen on #2 mup pump Rotate and reciprocate with #1 pump. 25 rpm, 188 gpm @ 270 psi 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 = 1 0.9k FtLb GPM = 800 @ 2250 psi on Btm PIU 103k S/O 74k ROT 86k 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 S/O 80k ROT 92k 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 PIU 112k S/O 80k ROT 97k P/U 125k S/O 85k without pumps Backream 30' on each stand at 80 rpm and 800 gpm, reduce rate to 500 gpm on down stroke. Printed 3/1/20049:51:23AM ~. , ) ) BP Operations Summary..Report Page 3. 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 -Tö Hours Task, Code NPT Phase Description of Operations 1/20/2004 14:30 - 19:00 4.50 DRILL P SURF AST = 3.12 hrs ART = 4.46 hrs 19:00 - 20:30 1.50 DRILL P SURF Circulate BU volume X 3. 1 00-110 rpm 800 gpm @ 2220 psi Torque = 5-7k FtLb ROT = 97k 20:30 - 21 :30 1.00 DRILL P SURF Monitor well - static. POH to 3542' without any problems. P/U 125k, S/O 86k From 3542' to 3480' started swabbing and pulling over from 25-35k. 21 :30 - 00:00 2.50 DRILL P SURF Backream out from 3480' 1 00 rpm 800 gpm @ 2140 psi Torque = 6-7k FtLb ROT = 97k Midnight depth 2600' 1/21/2004 00:00 - 02:00 2.00 DRILL P SURF Continue backreaming out of hole to 1600'. 775 gpm @ 1800 psi 02:00 - 04:00 2.00 DRILL P SURF 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 S/O 65k 04:00 - 04:30 0.50 DRILL P SURF 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' 04:30 - 05:00 0.50 DRILL P SURF Circulate hole clean. 400 gpm @ 680 psi 05:00 - 06:30 1.50 DRILL P SURF Continue RIH to TO at 3882'. No hole problems below 1825' 06:30 - 08:30 2.00 DRILL P SURF Stage pumps up to drilling rate and circulate BU volume X 2.5. 100-11 0 rpm 575 gpm @ 1345 psi Torque = 8k FtLb P/U 113k S/O 82k ROT 97k 08:30 - 13:30 5.00 DRILL P SURF Monitor well - static. POH to run casing. Pump out, 175 gpm @ 250 psi, through tight spot from 1550' to 1000. 13:30 - 14:30 1.00 DRILL P SURF Monitor well at BHA - static. Stand back HWDP, jars and collars. 14:30 - 16:00 1.50 DRILL P SURF LD BHA #2 16:00 - 16:30 0.50 DRILL P SURF Clean and clear rig floor. 16:30 - 19:00 2.50 CASE P SURF MU landing joint and casing hanger, make dummy run. CO bails, Rig up fill-up tool and csg equipment. 19:00 - 00:00 5.00 CASE P SURF 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: 3/1/2004 9:51:23 AM ~ . ) ) Page 4.of 28 BP Operation$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 . Date From -To Hours Task.· Code NPT 1/21/2004 19:00 - 00:00 5.00 CASE P 1/22/2004 00:00 - 02:30 2.50 CASE P 02:30 - 03:00 0.50 CASE P 03:00 - 06:00 3.00 CEMT P Phase SURF SURF SURF SURF 06:00 - 08:15 2.25 CEMT N WAIT SURF 08: 15 - 08:45 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 BOPSUR P SURF 1/23/2004 00:00 - 03:00 3.00 BOPSURP SURF 03:00 - 03:30 0.50 BOPSUR P SURF 03:30 - 07:30 4.00 BOPSUR P SURF 07:30 - 08:30 1.00 BOPSURP SURF 08:30 - 09:00 0.50 DRILL P INT1 09:00 - 11 :00 2.00 DRILL P INT1 11 :00 - 12:00 1.00 DRILL P INT1 Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 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 returns 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. RD 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 3/1/2004 9:51:23 AM 1 , ) ') Page 5 of 28 BP Operations SurnmaryReport 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 1/23/2004 12:00 - 15:00 3.00 DRILL P INT1 15:00 - 19:00 4.00 DRILL P INT1 19:00 - 20:00 1.00 CASE P SURF 20:00 - 20:30 0.50 DRILL P INT1 20:30 - 23:00 2.50 DRILL P INT1 23:00 - 00:00 1.00 DRILL P INT1 1/24/2004 00:00 - 00:30 0.50 DRILL P INT1 00:30 - 01 :00 0.50 DRILL P INT1 01 :00 - 02:30 INT1 1.50 DRILL P 02:30 - 08:00 5.50 DRILL P INT1 08:00 - 09:00 1.00 DRILL N FLUD INT1 09:00 - 09:30 0.50 DRILL P INT1 09:30 - 10:30 INT1 1.00 DRILL P Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description of dperatiOhs 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 PIU 118k SIO 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 PIU 118k SIO 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 at reduced rate, screens blinding off due to heavy oil and asphalt. Printed: 3/1/2004 9:51 :23 AM ~ , .. , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/24/2004 1/25/2004 1/26/2004 ) ') Page 6 .of28 BP Operations Summary Report L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 10:30 - 00:00 From- To Hours· Task Code NPT 13.50 DRILL P 00:00 - 08:00 08:00 - 19:30 19:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 00:30 8.00 DRILL P 11,50 DRILL P 3.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Description·of Operati()rïs INT1 Drill 9-7/8" intermediate hole from 4897' to 6470' sliding as required to maintain azimuth and inclination WOB = 10-20 klbs RPM = 60 Torque off Btm = 8-11 k FtLb, Torque on Btm = 11-15k FtLb GPM = 650 @ 2175 psi on Btm, 1814 psi off Btm P/U 156k S/O 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 Btm = 12-14k FtLb, Torque on Btm = 13-20k FtLb GPM = 650 @ 2419 psi on Btm, 2175 psi off Btm P/U 170k S/O 95k ROT 118k No pumps P/U 175k S/O 100k Backream every stand at 650 gpm and 50 rpm, reducing flow rate to 450 gpm on down stroke. Circulate Lo/Hi 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 1 0-20 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', SO pumps and monitor well- static. Total losses = 10 bbl. Continue backreaming out from 4170' to csg shoe at 3871'. INT1 Printed: 3/1/2004 9:51 :23 AM , , ) ') Page 7 of 28 BP Operatio~.!).·Sumrnary 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 Date From;"To Hours Task Code NPT· Phase 1/26/2004 00:00 - 00:30 0.50 DRILL P 00:30 - 01 :00 01 :00 - 03:00 03:00 - 07:00 0.50 DRILL P 2.00 DRILL P 4.00 DRILL P 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 P INT1 19:00 - 19:30 0.50 DRILL P INT1 19:30 - 20:30 1.00 BOPSURP INT1 20:30 - 21 :30 1.00 BOPSUR P INT1 21 :30 - 22:00 0.50 BOPSUR P INT1 22:00 - 00:00 2.00 CASE P INT1 1/27/2004 00:00 - 19:00 19.00 CASE P 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 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. 11 0 rpm 650 gpm @ 1966 psi Estimated losses at 5-10 bph Reduced rate to 600 gpm @ 1840 psi - no losses P/U 173k S/O 91k ROT 119k No pumps P/U 180k S/O 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 returns 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" 00 rigid straight blade centralizers as per plan. Joints without centralizers for lateral windows: Joint #11 - top at 7415' Printed: 3/1/2004 9:51 :23 AM ) ') Page 8 of 28 BP Operations Sum mary.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 Date From- To Hou rs Task Code NPT Phåse 1/27/2004 00:00 - 19:00 19.00 CASE P INT1 19:00 - 19:30 0.50 CASE P INT1 19:30 - 22:30 3.00 CEMT P INT1 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 INT1 01 :00 - 02:00 1.00 CEMT P INT1 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 BOPSURP PROD1 05:30 - 06:30 1.00 BOPSUR P PROD1 06:30 - 07:00 0.50 BOPSUR P PROD1 07:00 - 10:00 3.00 BOPSURP PROD1 10:00 - 10:30 0.50 BOPSUR P 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 Start: 12/31/2003 Rig Release: 2/23/2004 Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 Descripticmof ()pératiQns . 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. P/U 225 klbs S/O 100 klbs PJSM with Schlumberger and all rig personnel on cementing operations. Prime up and air up cement unit. Batch mix 114 bbls 15.8 ppg cement. Pump 5 bbl water to fill lines. Pressure test cement lines to 4000 psi Mix and pump 25 bbls CIW-100 chemical wash followed by 45 bbls 10.3 ppg alpha spacer at 4-5 bpm. P/U 265 klbs S/O 96 klbs Drop bottom plug. Pump 110 bbls (515 sxs) 15.8 ppg batch mixed cement at 6 bpm. P/U 265 klbs S/O 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" 10 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 10-3/4" 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: 3/1/2004 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 I NABORS 9ES Date From - To : Hours: Task' Code NPT Phase 1/28/2004 12:00 - 13:00 1.00 WHSUR P INT1 Page 9 of 28 Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 2123/2004 Description of Operations -----..--....... 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 7-5/8" 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 P/U 125k S/O 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 3/1/2004 9:51:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date e e BP Operations Summary Report Page 10 of 28 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Start: Rig Release: Rig Number: 1/29/2004 17:30 - 00:00 From - To Hours' Task Code NPT Phase 6.50 DRILL P PROD1 P/U 125k S/O 77k ROT 94k No pumps P/U 130k S/O 82k 1/30/2004 00:00 - 20:30 20:30 - 00:00 1/31/2004 00:00 - 02:00 02:00 - 00:00 Description of Operations 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 P/U 143k S/O 64k ROT 98k No pumps P/U 145k S/O 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 S/O 43k ROT 95k No pumps P/U 164k S/O 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 3/1/2004 9:51 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/31/2004 2/1/2004 2/2/2004 00:00 - 05:30 05:30 - 08:00 08:00 - 22:30 22:30 - 00:00 00:00 - 03:30 e e BP Operations Summary Report 5.50 DRILL P 2.50 DRILL P 14.50 DRILL P 1.50 DRILL P 3.50 DRILL P Page 11 of 28 Start: Rig Release: Rig Number: Phase ¡ Spud Date: 1/15/2004 End: 2/23/2004 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Fro~- To l~ours Task Code NPT 02:00 - 00:00 22.00 DRILL P 12/31/2003 2123/2004 Description of Operations PROD1 Calculated ECD = 10.95 ppg, Actual ECD = 11.36 ppg. ART = 6.74 hrs. PROD1 Drill 6-3/4" intermediate hole from 11304' to 11710' with PowerDrive rotary steerable BHA, 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 = 1 0.5k FtLb GPM = 275 @ 3170 psi on Btm, 3150 psi offBtm P/U 150k S/O 56k ROT 90k No pumps P/U 160k S/O 66k NO backreaming or sweeps. Seepage losses at 2-3 bph. Calculated ECD = 11.00 ppg, Actual ECD = 11.57 ppg. PROD1 Circulate and condition mud while geologist interprets samples and logs. 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 Btm = 11 k FtLb GPM = 275 @ 2940 psi on Btm, 2890 psi off Btm P/U 160k S/O 41 k ROT 90k No pumps P/U 168k S/O 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. 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 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'. Printed: 3/1/2004 9:51 :23 AM e e BP Operations Summary Report Page 12 of 28 Legal Well Name: L-200 Common Well Name: L-200 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES I I Date I From - To ! Hours; Task Code NPT Start: Rig Release: Rig Number: Phase 12/31/2003 212312004 Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations -..-----.....-.-...--.----- 2/2/2004 00:00 - 03:30 3.50 DRILL P PROD1 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 S/O 41 k ROT 90k No pumps P/U 168k S/O 61k Seepage losses at 3-4 bph. 05:00 - 06:30 1.50 DRILL P 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 13067' with PowerDrive rotary steerable BHA, steering as required to maintain inclination and azimuth taking surveys every 30'. 03:30 - 05:00 1.50 DRILL P 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 P/U 158k S/O top drive ROT 90k No pumps P/U 168k S/O 61 k Seepage losses at 3-4 bph. Calculated ECD = 11.14 ppg, Actual ECD = 11.57 ppg. 06:30 - 10:30 4.00 DRILL P ART = 1.44 hrs. PROD1 Circulate BU volume X 3. Circulate hi-vis sweep around. 150 rpm 275 gpm @ 2950 psi 10:30 - 11 :00 0.50 DRILL P 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. 11:00 -11:30 11 :30 - 14:30 0.50 DRILL P 3.00 DRILL P 160 rpm 275 gpm @ 2820 psi P/U 145k S/O 52k ROT 93k No pumps P/U 153k S/O 62k 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 Prior to trip Calculated ECD = 11.37 ppg, Actual ECD = 11.55 ppg. Monitor well- 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:· 3/1/2004 9:51:23AM e e BP Operations Summary Report Page 13 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 From - To ¡ Hours Task! Code NPT Phase Description of Operations 2/212004 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 00:00 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 Midnight depth: 9847' 2/312004 00:00 - 04:00 4.00 DRILL P PROD1 Continue backreaming from 9847' to the 7-5/8" csg shoe @ 7872'. 100 RPM 230 gpm @ 1700 psi 04:00 - 05:00 1.00 DRILL P PROD1 CBU at the csg shoe with 275 gpm @ 2330 psi + 120 RPM. After CBU Calculated ECD = 10.38 ppg, Actual ECD = 10.52 ppg. 05:00 - 06:30 1.50 DRILL P PROD1 Cut and slip 56' of drilling line. Service top drive, blocks and crown. 06:30 - 07:30 1.00 DRILL P PROD1 POOH ( 7 stds ) to 7217'. P/U 21 Jts of 4" HWDP & rack in derrick. 07:30 - 11 :00 3.50 DRILL P PROD1 TIH with drill string to 12974'. Encountered tight hole with 20-30k d rag at 11300', 11600' & 12300' to 12600'. 11 :00 - 11 :30 0.50 DRILL P 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. 11 :30 - 14:00 2.50 DRILL P 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 clean the PWD tool gave a Calculated ECD of 11.38 ppg & Actual ECD of 11.43 ppg 14:00 - 19:00 5.00 DRILL P PROD1 POOH to 7-5/8" casing shoe @ 7872'. Encountered tight hole @ the following depths: 12889', 11817', 11774', 10204' & 9460'. Wiped all tight spots with no other problems. 19:00 - 19:30 0.50 DRILL P PROD1 Monitor well-static. POOH to 7725'. 19:30 - 22:30 3.00 DRILL P PROD1 M/U 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'. 22:30 - 23:00 0.50 DRILL P PROD1 TIH to 7872'. P/U 127k S/O 82k. 23:00 - 00:00 1.00 DRILL P 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. 2/4/2004 00:00 - 03:00 3.00 DRILL P PROD1 POOH with drill string from 7872' to top of BHA. 03:00 - 03:30 0.50 DRILL P PROD1 SAFETY--- Held PJSM with rig crew & Schlumberger MWD personnel regarding unloading RA source & UD BHA. 03:30 - 05:00 1.50 DRILL P PROD1 Continue POOH. Unload RA source. UD 6-3/4" BHA. 05:00 - 05:30 0.50 DRILL P PROD1 Clean rig floor of excess MOBM & excess directional equipment. 05:30 - 07:00 1.50 CASE P COMP R/U to run 4.5" slotted liner. Printed: 3/112004 9:51:23 AM e e Page 14 of 28 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/4/2004 COMP SAFETY--- Held PJSM with rig crew on running 4.5" liner. COMP M/U 4-1/2" Guide Shoe Jt + 125 Jts of 4-1/2" 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. COMP RIH with 4-112" 12.6# Slotted liner assembly on 4" DP to 7872'. Circulate 1 x DP volume @ 210 gpm wI 650 psi. 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. COMP Break circulation. Drop 29/32" 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 Turns in drill string to release running tool from hanger. P/U 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'. Monitor well. Well static. POOH 1 std above 4.5" Liner Top Packer. CBU from 7469' @ 6 bpm wI 960 psi. Flow check. Pump slug. POOH with 4" DP. LID BOT Packer setting tool. Clean & clear rig floor of exces MOBM & liner running equipment. Pull wear bushing. Run and set BOP Test plug. R/U 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. Slip & cut drill line. Reset and check C-O-M. Bring Whipstock & other related BHA componets to rig floor SAFETY--- Held PJSM with Rig Crew, Schlumberger MWD & Baker personnel regarding handling & running procedures for Whipstock & BHA. M/U Baker 7-5/8" Whipstock assembly #1. Orient MWD with whipstock. Service TDS, Drawworks, Iron-Roughneck, Rig's Hydraulic system, Blocks & Crown. TIH with 7-5/8" Whipstock assembly on 4" DP to7490'. P/U = 138k S/O = 90k M/U 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. 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. L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES I : . I ¡From - To Hours! Task; Code ¡ NPT! Phase I.. 07:00 - 07:30 07:30 - 13:00 0.50 CASE P 5.50 CASE P 13:00 -14:30 1.50 CASE P 14:30 - 18:30 4.00 CASE P 18:30 - 19:30 1.00 CASE P 19:30 - 20:00 0.50 CASE P COMP 20:00 - 21 :00 1.00 CASE P COMP 21 :00 - 00:00 3.00 CASE P COMP 2/5/2004 00:00 - 04:00 4.00 BOPSURP PROD2 04:00 - 05:00 1.00 S1WHIP P PROD2 05:00 - 05:30 0.50 S1WHIP P PROD2 05:30 - 06:00 0.50 S1WHIP P PROD2 06:00 - 10:00 4.00 S1WHIP P PROD2 10:00 - 12:30 2.50 S1WHIP P PROD2 12:30 - 17:00 4.50 S1WHIP P PROD2 17:00 - 18:00 1.00 S1WHIP P PROD2 18:00 - 22:30 4.50 S1WHIP P Start: Rig Release: Rig Number: i I Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 2/23/2004 Description of Operations .. -.. .- .....----. RPM = 85-100 Printed: 3/1/2004 9:5123 AM e e Page 15 of 28 BP Operations Summary Report Torque = 5-10k FtLb GPM = 298-315 @ 2240 psi P/U 138k S/O 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. LID 9 x 4.750" DC, MWD tool & whipstock mill assembly. Clean Rig Floor. M/U ported sub. Flush out BOP's. LID 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'. P/U 138k S/O 90k PROD2 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 S/O 80k ROT 101 k 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 S/O 60k ROT 95k 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 ...-.... . ._-"- ....---......-.--. ------..----.--... 2/5/2004 18:00 - 22:30 4.50 STWHIP P PROD2 22:30 - 23:00 0.50 STWHIP P PROD2 23:00 - 23:30 0.50 STWHIP P PROD2 23:30 - 00:00 0.50 STWHIP P PROD2 2/6/2004 00:00 - 02:30 2.50 STWHIP P PROD2 02:30 - 04:00 1.50 STWHIP P PROD2 04:00 - 04:30 0.50 DRILL P PROD2 04:30 - 05:30 1.00 DRILL P PROD2 05:30 - 05:45 0.25 DRILL P PROD2 05:45 - 08:30 2.75 DRILL P PROD2 08:30 - 09:00 0.50 DRILL P PROD2 09:00 - 11 :30 2.50 DRILL P PROD2 11:30-12:00 0.50 DRILL P PROD2 12:00 - 00:00 12.00 DRILL P 2/7/2004 00:00 - 00:00 24.00 DRILL P Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 212312004 Description of Operations . ~. _u____ ----.---..-.... 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 Printed: 3/1/2004 9:51:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e -- BP Operations Summary Report Page 16 of 28 L-200 L-200 DRILL +COMPlETE NABORS ALASKA DRilLING I NABORS 9ES 12/31/2003 2123/2004 Spud Date: 1/15/2004 End: 2/23/2004 Start: Rig Release: Rig Number: Date From - To : Hours Task ICode NPT Phase Description of Operations 2/7/2004 00:00 - 00:00 2/8/2004 00:00 - 20:30 20:30 - 00:00 2/9/2004 00:00 - 01 :30 01 :30 - 02:00 24.00 DRILL P PROD2 Losing an average of 4 bph MOBM due to Fluid retention on drill cuttings. Backream 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 14323'KBTVD PROD2 Drill 6-3/4" directional hole (L 1 lateral) from 11052' to 13045' TO 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 Btm P/U 180k S/O 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' TO 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: 3/1/2004 9:51:23 AM e e Page 17 of 28 BP Operations Summary Report Start: Rig Release: Rig Number: I Code NPT I Phase . , ; Calculated ECD @ 13045 after circulating = 11.39ppg, Actual ECD = 11.90 ppg 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'. 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. Circulate 1.5 x Btms-up from 7358' w/ 280 gpm @ 2500 psi + 60 RPM. Reciprocate drill string while circulating. Circulate 1.5 x Btms-up from 7358' w/280 gpm @ 2500 psi + 60 RPM. Reciprocate drill string while circulating. Very small amount of cuttings coming over shakers. Slip & cut 60' of drill line. Reset & check C-O-M. Inspect & adjust drawworks brakes. Service TDS. 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'. M/U TDS. Establish circulation. Wash & ream from 12859' to 13045'TD with little resistance. Pump a 25 bbl Lo-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 = 11.31 ppg, Actual ECD = 11.33 ppg P/U 145k S/O 36k Rot Wt 92k while circulating. 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'. PROD2 Drop ball-rod. Break circulation. Open circ sub with 2300 psi. Stage pumps to 550 gpm with 3470 psi. Wash whipstock face 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 2/9/2004 - n___.. ______..__________.0_____ 01 :30 - 02:00 0.50 DRILL P PROD2 02:00 - 02:30 0.50 DRILL P PROD2 02:30 - 03:45 1.25 DRILL PROD2 03:45 - 10:30 6.75 DRILL P PROD2 10:30 - 12:00 1.50 DRILL P 12:00 - 23:30 11.50 DRILL P 23:30 - 00:00 0.50 DRILL P PROD2 2/10/2004 00:00 - 00:30 0.50 DRILL P PROD2 00:30 - 02:00 1.50 DRILL P PROD2 02:00 - 04:30 2.50 DRILL P PROD2 04:30 - 05:00 0.50 DRILL P PROD2 05:00 - 08:30 3.50 DRILL P PROD2 08:30 - 12:30 4.00 DRILL P 12:30 - 14:00 1.50 DRILL P 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations Attempt to pull without pumping to 12020'. Hole continue to pull tight. TIH to 12400'. Unable to slide drill string past this depth due to hole geometry & drill string limitations. M/U TDS. Circulate & rotate the drill pipe down from 12400' to 13045' TD. Pump a 25 bbl Lo-vis sweep. Stage pumps to 290 gpm w/ 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 bbl Lo-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. Printed: 3/1/2004 9:51 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/10/2004 2/11/2004 2/12/2004 - e Page 18 of 28 BP Operations Summary Report L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES I i From - To : Hours Task Code NPT Start: Rig Release: Rig Number: Phase -...-.----- 12:30 - 14:00 14:00 - 17:00 17:00-17:15 17:15 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 03:00 03:00 - 06:00 06:00 - 10:00 10:00 - 15:30 15:30 - 16:00 16:00 - 16:15 16:15 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:00 ______._0___ _. 1.50 DRILL P 3.00 DRILL P 0.25 DRILL P 2.25 DRILL P 0.50 DRILL P 0.50 WHIP P 1.50 WHIP P 2.00 WHIP P 1.00 WHIP P 0.50 WHIP P 1.50 WHIP P 3.00 WHIP P 4.00 WHIP P 5.50 CASE N PROD2 PROD2 PROD2 PROD2 PROD2 COMP COMP COMP COMP COMP COMP COMP COMP WAIT COMP 0.50 CASE P 0.25 CASE P 6.25 CASE P 0.50 CASE P 0.50 CASE P 0.50 CASE P 1.00 CASE P 0.50 CASE P 0.50 CASE P COMP COMP COMP COMP COMP COMP COMP COMP COMP 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations ... .._n ___.__.____ 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. POOH from 7358' to top of BHA. SAFETY---- Held PJSM with rig crew & Anadrill personnel on removing RA source & LID BHA. Remove RA source from ADN tool. LID 6-3/4" BHA. Clean rig floor & remove excess directional equipment. SAFETY--- Held PJSM with rig crew, Anadrill & Baker personnel regarding M/U Whipstock retrieving tool (WSRT) & BHA. M/U WSRT & BHA. Shallow test MWD-OK. TIH with WSRT & BHA on 4" DP to 3700' (Midnight depth). Continue TIH with WSRT & BHA on 4" DP from 3700' to 7400'. Break circulation. Stage pumps to 225 gpm w/1375 psi. Orient WSRT to 13 deg LHS. (P/U Wt 140k S/O Wt 80k). Slack off on drill string to 7429'. P/U & 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) . P/U & pull seals out of bottom tie-back receptacle. Pull whipstock up to 7390' (P/U Wt = 145k). Monitor well-static. CBU from 7390' wI 225 gpm @ 1375 psi. Flow check. Well static. Pump slug. POOH with whipstock assembly #1 to top of BHA. Stand back 4" HWDP. LID 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. 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. RlU to run 4.5" Slotted liner. SAFETY--- Held PJSM with rig crew & BOT personnel regarding running liner & P/U Hook Hanger assembly. M/U 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 S/O Wt = 65k Theoretical Liner Wt in mud = 60,315 Lbs RID 4.5" Liner running equipment. Install DP elevators on TDS. TIH with 4-1/2" 12.6# Slotted liner assembly on 4" DP to 6697'. 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). Finish P/U 12 x 4-3/4" drill collars & rack in derrick. Continue TIH with 4-1/2" 12.6# Slotted liner assembly on 4" DP to 7353'. P/U 11 Ok S/O 75k M/U TDS. Rotate string @ 5 rpm, monitor torque readings. Printed: 311/2004 9: 51 : 23 AM e e BP Operations Summary Report Page 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: Rig Release: Rig Number: 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Date From - To ; Hours Task . Code NPT· Phase Description of Operations -----.. --------...-. --.-. 2/12/2004 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 4-112" 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 turn. 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 turn. Run in and go past hook point. Rotate additional 1/4 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'. LID 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 RlU 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 M/U and run 4.5" tail pipe consisting of mule shoe Jt + 1 Jt of 4-112",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 turn RHT in string. Work string. P/U Wt = 132k S/O 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. P/U 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 w/ 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). P/U 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: 3/1/2004 9:51:23 AM > , e e Page 20 of 28 BP Operations Summary Report legal Well Name: l-200 Common Well Name: l-200 Event Name: DRilL +COMPlETE Contractor Name: NABORS ALASKA DRilLING I Rig Name: NABORS 9ES Date I From - To I Hours Task ¡ Code NPT ! I 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Start: Rig Release: Rig Number: Phase P/U 125k S/O 80k CBU from 7350' w/ 396 gpm @ 2400 psi. Finish CBU from 7350'. Flow check. Well static. Pump slug. Blow down TDS. POOH from 7350' with 4" DP. LID BOT Packer setting tool. Monitor well-static. Drain BOP. Pull wear bushing. Complete installation of Upper Remote IBOP valve on TDS. Function test same-OK. M/U BOP test plug on 4" DP. Seat in wellhead. R/U to test BOP's. Test BOP's & all surface related equipment to 250/3500 psi. The BOP test was witnessed by Jeff Jones-AOGCC. All test were API. RID test equipment. Pull test plug. Run wear bushing. Blow down surface equipment. Slip & cut 85' of drill line. Reset & check C-O-M. Inspect & adjust Drawworks brakes. Service TDS. Bring Whipstock & other related BHA components to rig floor. SAFETY--- Held PJSM with Rig Crew, Schlumberger MWD & Baker personnel regarding handling & running procedures for Whipstock & BHA. M/U Baker 7-5/8" Whipstock assembly #2. Orient MWD with whipstock. TIH with 7-5/8" Whipstock assembly on 4" DP to 7334'. P/U = 140k S/O = 87k 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 1 Ok 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' . PROD3 Mill Window in 7-5/8" casing from 7320' to 7330.' RPM = 80 Torque = 8.5k FtLb GPM = 250 @ 1670 psi P/U 135k S/O 80k Rotate Wt = 99k PROD3 Finish Milling Window in 7-5/8" 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' 2/12/2004 0.50 CASE P COMP 23:00 - 23:30 23:30 - 00:00 0.50 CASE P COMP 2/13/2004 00:00 - 00:30 0.50 CASE P COMP 00:30 - 01 :00 0.50 CASE P COMP 01 :00 - 04:30 3.50 CASE P COMP 04:30 - 05:00 0.50 BOPSURP COMP 05:00 - 07:30 2.50 BOPSURP COMP 07:30 - 08:00 0.50 BOPSURP COMP 08:00 - 12:00 4.00 BOPSUR P COMP 12:00 - 12:30 0.50 BOPSUR P COMP 12:30 - 14:30 2.00 STWHIP P COMP 14:30 - 14:45 0.25 STWHIP P PROD3 14:45 - 15:00 0.25 STWHIP P PROD3 15:00 - 17:30 2.50 STWHIP P PROD3 17:30 - 20:30 3.00 STWHIP P PROD3 20:30 - 21 :30 1.00 STWHIP P PROD3 21 :30 - 00:00 2.50 STWHIP P 2/14/2004 00:00 - 01 :30 1.50 STWHIP P Description of Operations u..__.____ .._ .__.. 7350' Note: Top of L 1 ZXP Tie-back sleeve @ 7385.92' RPM = 80 Torque = 8.5 KFtLb GPM = 250 @ 1670 psi P/U 135k S/O 80k Rotate Wt = 99k PROD3 Pump Hi-vis sweep & circulate hole clean from 7348' w/ 250 gpm @ 1670 psi. Reciprocate & rotate drill string (110 RPM) 01 :30 - 02:30 1.00 STWHIP P Printed: 3/1/2004 9:51 :23 AM e e 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. LID BOT mills & related equipment. Clear rig floor of excess whipstock milling equipment. M/U ported sub. Flush out BOP's. LID 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'. M/U 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'. P/U 138k S/O 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 S/O 80k ROT 100k PROD3 Drill 6-3/4" directional hole (L2 lateral) 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 P/U 155k S/O 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 i From - To Hours Task: Code i 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 2/15/2004 00:00 - 11 :00 11.00 DRILL P Page 21 of 28 Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 2/23/2004 Description of Operations 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: 3/1/2004 9:51 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/15/2004 2/16/2004 e e BP Operations Summary Report Page 22 of 28 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To I Hours I Task 00:00 - 11 :00 11 :00 - 12:30 12:30 - 14:30 14:30 - 00:00 00:00 - 04:30 04:30 - 06:00 06:00 - 07:30 I .._u__n _.__.. ....... 11.00 DRILL 1.50 DRILL P 2.00 DRILL P 9.50 DRILL P 4.50 DRILL P 1.50 DRILL P 1.50 DRILL P Start: Rig Release: Rig Number: : Code NPT I Phase I I P PROD3 Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 212312004 Description of Operations --. -.-----------..---------.--------.. 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. PROD3 Circ hole clean prior to short trip. Total circulation = 590 bbl @ 275 gpm w/ 3060 psi. Reciprocate & rotate (60 RPM) while circulating. P/U 160k S/O 80k Rot Wt 103K Calculated ECD after circulating @ 8821' = 10.83 ppg. Actual ECD = 11.06 ppg. 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. 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 = 1 Ok ft Ibs, Torque on Btm = 10-11 k ft Ibs. GPM = 275 @ 3230 psi on Btm, 3020 psi off Btm P/U 156k S/O 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 = 14.11Hrs PROD3 Drill 6-3/4" directional hole (L2 lateral) from 10126' to 10654'. Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs. RPM = 60 Torque offBtm = 10k ft Ibs, Torque on Btm = 10-11k ft Ibs. GPM = 275 @ 3230 psi on Btm, 3020 psi off Btm P/U 156k S/O 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. PROD3 Having problems getting drill string to slide. Pump a Hi-vis sweep. Circulate & condition mud/hole w/280 gpm @ 3125 psi. Reciprocate & rotate (85 RPM) to help aid in hole cleaning. P/U 156k S/O 68k Rot 100k PROD3 Continue drilling 6-3/4" directional hole (L2 lateral) from 10654' Printed 3/1/2004 9:5123 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/16/2004 2/17/2004 e e Page 23 of 28 BP Operations Summary Report l-200 l-200 DRill +COMPlETE NABORS ALASKA DRilLING I NABORS 9ES From - To I Hours Task ¡Code NPT Start: Rig Release: Rig Number: Phase Spud Date: 1/15/2004 End: 2/23/2004 06:00 - 07:30 07:30 - 09:30 09:30 - 12:00 12:00 -13:00 13:00 - 00:00 00:00 - 11 :30 1.50 DRILL P 2.00 DRILL P 2.50 DRILL P 1.00 DRILL P 11.00 DRILL P 11.50 DRILL P 12/31/2003 2123/2004 Description of Operations . .-----.-----.----.--...----- --- - PROD3 to 10873'. Slide as required to maintain inclination & azimuth. WOB = 10-15 klbs. RPM = 60 Torque off Btm = 1 Ok ft Ibs, Torque on Btm = 10-11 k ft Ibs. GPM = 275 @ 3370 psi on Btm, 3020 psi off Btm P/U 165k S/O 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 mud/hole (Circ 800 bbl) from 10873' w/ 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. P/U 165k S/O 55k Rot 97k Calculated ECD @ 10650' = 11.10 ppg. Actual ECD = 11.60 ppg. PROD3 Commence 25 Std wiper trip from 10873-8542'. POOH w/ 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 = 1 0.5k ft Ibs, Torque on Btm = 11-12k ft Ibs. GPM = 275 @ 3550 psi on Btm, 3360 psi off Btm P/U 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 off Btm = 10-11 k ft Ibs, Torque on Btm = 11.5k ft Ibs. GPM = 275 @ 3410 psi on Btm, 3309 psi off Btm Printed: 3/1/2004 9:51 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e BP Operations Summary Report Page 24 of 28 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 12/31/2003 212312004 Spud Date: 1/15/2004 End: 2/23/2004 Start: Rig Release: Rig Number: Phase I I Date From - To ¡ Hours Task' Code NPT 2/17/2004 00:00 - 11 :30 11:30-14:00 14:00 - 17:00 17:00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 2/18/2004 00:00 - 01 :30 01 :30 - 05:00 05:00 - 06:30 Description of Operations __n____.O__O. ___.. .__ .__ ._. ...__.. 11.50 DRILL P PROD3 P/U 166k S/O 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. 2.50 DRILL P Drilling Time last 24 Hrs= 3.03 hrs ART = 2.17 Hrs AST = 0.86 Hrs. Survey & Connection time = 8.47 Hrs PROD3 Pump lo-vis sweep and circulate BU volume X 3 300 gpm @ 3450 psi RPM = 110 P/U 155k S/O 55k 3.00 DRILL P Prior to short trip: Calculated ECD = 11.28 ppg. Actual ECD = 11.99 ppg. 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. 4.50 DRILL P P/U 180k S/O 45k W/O Pumps PROD3 RIH to 12520' and backream out to 10873' without problems. 0.50 DRILL P 290 gpm @ 3580 psi RPM = 80 ROT 94k PROD3 POH - no pump, no rotary from 10873' to 10500'. No problems pulling through previously wiped section. 2.00 DRILL P P/U 175k S/O 77k PROD3 RIH from 10500' to 12533'. Break circ and work through obstruction at 12560' - just past an invert point. 1.50 DRILL P 3.50 DRILL P P/U 171 k S/O 75k PROD3 Wash down from 12553' to 13115', 100 gpm, 40 rpm PROD3 Pump lo-vis sweep and circulate BU volume X 3. 1.50 DRILL P 300 gpm @ 3840 psi RPM = 80 Calculated ECD = 11.46 ppg, Actual ECD prior to trip = 11.7 ppg PROD3 15 stand short trip to 11713'. Work thru tight spots at 12990' 12605'. 180 klbs up. 75 klbs dn - no pump. Printed: 3/1/2004 9:51:23 AM e e Page 25 of 28 BP Operations Summary Report Date L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES I I ' From - To I Hours! Task: Code Start: Rig Release: Rig Number: NPT I Phase I PROD3 RIH to bottom. Work thru tight spot 12900-12923'. Then OK to bottom. PROD3 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 S/O 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, P/U 155 klbs, S/O 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', P/U 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: 2/18/2004 1.00 DRILL P 06:30 - 07:30 07:30 - 12:00 4.50 DRILL P 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 12/31/2003 2/23/2004 Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations .............--- P/U 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. P/U 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, P/U 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 turn and work torque into string. RIH and exit window on second attempt. Printed: 3/1/2004 9:51:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date __u____... 2/19/2004 2/20/2004 2/21/2004 e e BP Operations Summary Report Page 26 of 28 L-200 L-200 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To I Hours; Task Code NPT; Phase 23:30 - 00:00 00:00 - 07:30 07:30 - 07:45 07:45 - 08:00 08:00 - 08:15 08:15 - 09:15 09:15 -10:00 10:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 -16:00 16:00 - 17:30 17:30 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 02:00 0.50 CASE P COMP 7.50 CASE P COMP 0.25 CASE P COMP 0.25 CASE P COMP 0.25 CASE P COMP 1.00 CASE P COMP 0.75 CASE P 3.50 CASE P COMP COMP 0.50 CASE P 0.50 CASE P 0.50 CASE P COMP COMP COMP 1.00 CASE P 1.50 CASE P COMP COMP 4.00 CASE P COMP 0.50 CASE P COMP 0.50 CASE P COMP 1.50 CASE P COMP 2.00 CASE P COMP Start: Rig Release: Rig Number: Spud Date: 1/15/2004 End: 2/23/2004 12/31/2003 2/2312004 Description of Operations Continue RIH with liner on 4" DP. Midnight depth = 7689' 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. PU 20' above hook depth and put 1/2 turn in string. Work torque down and lost all string weight. Work string and regain 5-10 klbs string wt (35-45 klbs weight indicator). Run in past hook depth 10' again. PU - now 220 klbs and pull 10' 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. 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. CBU, 400 gpm @ 2820 psi Monitor well - static. Slug DP and POH, P/U 150 klbs, S/O 100 klbs. Stand back HWDP and DC's LD running tool. Clean and clear rig floor. RU csg equipment to run ZXP, LEM and tbg tail PJSM with BOT and all rig personnel on making up and running LEM, ZXP assembly. MU mule shoe, pup jts, LEM and ZXP liner top packer RIH with LEM/ZXP assembly on HWDP. MU TDS to each stand to prevent MOBM from running over. Continue RIH with LEM/ZXP assembly on DP. P/U 140 klbs S/O 85 klbs 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. PJSM with BOT and ALL rig personnel on pressuring up to set packer and shear ball seat. 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. Displace well to new 9.3 ppg NaCI brine, 225 gpm @ 578 psi. Pump Schedule: Printed; 3/1/2004 9;51:23 AM e e Page 27 of 28 BP Operations Summary Report 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: 2123/2004 Rig Name: NABORS 9ES Rig Number: Date I From - To I Hours! Task I Code ¡ NPT I Phase I --..--.-- .-..-,----.. ...un______o..O 2/21/2004 00:00 - 02:00 2.00 CASE P COMP 02:00 - 03:30 1.50 CASE P COMP 03:30 - 09:30 6.00 CASE P COMP 09:30 - 10:00 0.50 CASE P COMP 10:00 - 11 :00 1.00 CASE P COMP 11 :00 - 12:30 1.50 BOPSURP COMP 12:30 - 16:30 4.00 BOPSURP COMP 16:30 - 19:00 2.50 CASE P COMP 19:00 - 20:30 1.50 CASE P COMP 20:30 - 0.00 CASE P COMP 2/22/2004 00:00 - 00:30 0.50 CASE P COMP 00:30 - 01 :00 0.50 BOPSURP COMP 01 :00 - 03:00 2.00 RUNCOI\IP COMP 03:00 - 03:30 0.50 RUNCOI\IP COMP 03:30 - 04:00 0.50 RUNCOI\IP COMP 04:00 - 05:30 1.50 RUN COM COMP 05:30 - 14:30 9.00 RUNCOI\IP COMP 14:30 - 17:30 3.00 RUNCOI\IP COMP 17:30 - 19:00 1.50 RUNCOI\IP COMP 19:00 - 19:30 0.50 RUNCOI\IP COMP 19:30 - 20:00 0.50 RUNCOI\IP COMP 20:00 - 20:30 0.50 RUNCOI\IP COMP 20:30 - 21 :00 0.50 RUNCOI\IP COMP 21 :00 - 21 :30 0.50 RUNCOI\IP COMP 21 :30 - 23:00 1.50 BOPSURP COMP 23:00 - 00:00 1.00 WHSUR P COMP Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations ......---...... ---.---..- -...--------..-- ....--.---- 25 bbls base oil 25 bbls viscosified brine 50 bbls Safe Surf 0 25 bbls viscosified brine 294 bbls 9.3 ppg NaCI brine Clean MOBM from under shakers, possum belly and rig floor POH laying down DP. LD 25 joints of rented 4" HWDP, standback 7 stands of NABORS HWDP. LD BOT running tool. Clean and clear rig floor. Pull wear bushing, RU BOPE test equipment. MU test plug and RIH 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. RIH with 4 stands of DC's and 41 stands of DP PJSM with all hands. Cut and slip 72' of drill line. Service top drive, blocks and crown. Monitor well - static. Slug DP and POH laying down DP and DC's Move HWDP to ODS. Clean and clear rig floor Pull wear bushing. MU landing joint and make dummy run with tubing hanger. CO bails, RU tbg equipment. RU control line spool for I-wire. PJSM with BOT, Centrilift, Cameo, Nabors Casing and all rig personnel on making up and running completion. PU and MU 4.5",12.6#, L-80, IBT-M completion assembly as per running orders. MU and test I-wire control line for Phoenix gauge. 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 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. 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. Drop rod and ball with roller stem. Pressure up to 4200 psi and hold for 10 minutes to set packer. Bleed pressure to 3500 psi and hold for 30 minutes to test tbg. Bleed tbg pressure to 2500 psi. Pressure up annulus to 3500 psi and hold for 30 minutes. 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. LD landing joint and install TWC valve. ND BOPE. Clean MOBM from under rotary table Move tree into cellar. Printed: 3/1/2004 9:51 :23 AM e e Page 28 of 28 BP Operations Summary Report legal Well Name: l-200 Common Well Name: l-200 Event Name: DRill +COMPlETE Contractor Name: NABORS ALASKA DRilLING I Rig Name: NABORS 9ES Date I From - To '; Hours Task Code i NPT 2/23/2004 00:00 - 02:00 2.00 WHSUR P 02:00 - 03:00 1.00 WHSUR P 03:00 - 04:00 1.00 WHSUR P 04:00 - 05:30 1.50 WHSUR P 05:30 - 08:00 2.50 WHSUR P 08:00 - 10:00 2.00 WHSUR P 10:00 - 12:00 2.00 WHSUR P COMP COMP COMP COMP COMP COMP COMP Start: Rig Release: Rig Number: Phase I 12/31/2003 2123/2004 Spud Date: 1/15/2004 End: 2/23/2004 Description of Operations ___1 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. Slow down all lines. RU DSM and istall SPV through lubricator, SPV not holding pressure. PULL and install new SPV. 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: 3/1/2004 9:51 :23 AM e e Ö L-200 Survey Report Schlumberger Report Date: 2·Feb-04 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 334.150' Field: Prudhoe Bay Unü - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: L-PAD / N·M TVD Reference Datum: Rotary Table Well: L-2oo TVD Reference Elevation: 77.60 ft relative to MSL Borehole: L-2oo Sea Bed f Ground Level Elevation: 49.10 ft relative to MSL UWVAPI#: 500292319100 Magnetic Declination: 25.071' Survey Name I Date: L-200 / February 2, 2004 Total Field Strength: 57556.194 nT Tort I AHD I DDII ERD ratio: 421.500' 111121.96 ft /7.134/2.474 Magnetic Dip: 80.820' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 11. 2004 Location LatlLong: N 70 212.361, W 14919 27.914 Magnetic Declination Model: BGGM 2003 Location Grid NfE YIX: N 5978289.740 ftUS, E 583209.270 ftUS North Reference: True North Grid Convergence Angle: +0.63624271' Total Corr Mag North -> True North: +25.071' Grid Scale Factor: 0.99990787 Local Coordinates Referenced To: Well Head Measured I Inclination I Azimuth I TVD I Su~~ TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing easting Lathude Longüude Depth Section Departure (ft) ( deg) ( dog) (ft) (ft) (ft) (ft) (ft) (ft) ( deg/100 ft) ( deg/100 ft ) ( deg/100 ft ) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 -77.60 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978289.74 583209.27 N 70 212.361 W 149 1927.914 199.66 0.66 347.45 199.66 122.06 1.12 1.15 1.12 -0.25 0.33 0.33 0.00 5978290.86 583209.01 N 70 21 2.372 W 149 19 27.921 293.20 2.62 338.59 293.15 215.55 3.78 3.82 3.64 -1.15 2.11 2.10 -9.47 5978293.37 583208.08 N 70 21 2.396 W 149 1927.947 384.95 6.42 345.43 384.60 307.00 10.90 11.05 10.56 -3.20 4.18 4.14 7.46 5978300.26 583205.95 N 7021 2.464 W 149 1928.007 477.31 9.54 353.99 476.06 398.46 23.17 23.84 23.17 -5.31 3.61 3.38 9.27 5978312.85 583203.71 N 70 21 2.589 W 149 1928.069 570.07 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 1491928.107 663.59 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 N 70 21 2.956 W 149 1928.114 757.23 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 N 70213.176 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 70214.265 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 70 215.507 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 70 216.040 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 21 6.702 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 21 7.299 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 21 7.706 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 19 23.060 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 70 218.651 W 149 19 22.167 1981.24 58.01 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 70 219.362 W 1491921.219 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 N702111.555 W1491917.944 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 21 12.292 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 1491913.672 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 583716.13 N 70 2115.193 W 1491912.672 2827.79 60.36 21.84 2130.40 2052.80 1000.85 1499.63 1380.49 553.90 2.94 -0.41 -3.34 5979676.16 583747.75 N 70 2115.937 W 149 1911.723 2922.12 59.90 21.49 2177.38 2099.78 1056.20 1581.43 1456.56 583.96 0.51 -0.49 -0.16 5979752.56 583776.97 N 70 21 16.685 W 149 19 10.844 3016.60 59.79 21.10 2224.84 2147.24 1111.76 1663.12 1532.68 613.63 0.38 -0.12 -0.41 5979828.99 583805.79 N 70 21 17.434 W 149 199.976 3109.90 60.32 21.69 2271.41 2193.81 1166.84 1743.97 1607.95 643.12 0.79 0.57 0.63 5979904.58 583834.44 N702118.174 W149199.114 3202.72 60.98 20.88 2316.91 2239.31 1221.68 1824.87 1683.33 672.49 1.04 0.71 -0.87 5979980.28 583862.97 N 70 2118.916 W 149198.255 3296.64 60.87 21.35 2362.55 2284.95 1277.70 1906.95 1759.91 702.06 0.45 -0.12 0.50 5980057.17 583891.68 N 70 2119.669 W 149 197.391 3389.27 60.94 21.25 2407.59 2329.99 1332.74 1987.90 1835.32 731.46 0.12 0.08 -0.11 5980132.90 583920.24 N 70 2120.410 W 149 196.531 3483.60 60.19 22.40 2453.95 2376.35 1388.06 2070.05 1911.58 762.00 1.33 -0.80 1.22 5980209.49 583949.93 N702121.160 W 149 195.638 3578.88 59.55 23.93 2501.78 2424.18 1442.11 2152.45 1987.34 794.41 1.54 -0.67 1.61 5980285.59 583981.49 N 70 2121.905 W 149 194.691 3675.27 58.85 24.27 2551.14 2473.54 1495.38 2235.25 2062.92 828.22 0.79 -0.73 0.35 5980361.54 584014.46 N 70 21 22.649 W 149 19 3.702 3768.47 58.76 23.95 2599.41 2521.81 1546.67 2314.97 2135.69 860.79 0.31 -0.10 -0.34 5980434.66 584046.21 N 70 21 23.364 W 149 192.750 3822.84 58.68 24.44 2627.54 2549.94 1576.40 2361.27 2177.92 879.76 0.79 -0.15 0.90 5980477.09 584084.71 N 70 21 23.780 W 149 192.195 3968.57 56.45 24.32 2705.80 2628.20 1655.19 2484.43 2290.09 930.60 1.53 -1.53 -0.08 5980589.81 584114.30 N 70 21 24.883 W 149 19 0.708 4061 .82 57.86 25.00 2756.37 2678.77 1705.00 2562.77 2361.29 963.29 1.63 1.51 0.73 5980661.36 584146.19 N 70 21 25.583 W 149 18 59.752 4156.78 57.90 25.01 2806.86 2729.26 1755.77 2643.19 2434.18 997.29 0.04 0.04 0.01 5980734.61 584179.37 N 70 2126.300 W 149 1858.758 4251.19 58.19 23.32 2856.83 2779.23 1807.25 2723.29 2507.26 1030.07 1.55 0.31 -1.79 5980808.04 584211.34 N 70 2127.018 W 149 1857.799 4346.29 59.22 23.84 2906.23 2828.63 1860.20 2804.56 2581.79 1062.45 1.12 1.08 0.34 5980882.92 584242.89 N 70 21 27.751 W 149 1856.853 4441.75 58.59 23.84 2955.53 2877.93 1913.30 2886.30 2656.67 1095.23 0.66 -0.66 0.00 5980958.16 584274.83 N 70 21 28.488 W 149 1855.894 4534.67 59.74 24.66 3003.16 2925.56 1964.58 2966.08 2729.47 1127.88 1.56 1.24 1.10 5981031.31 584306.66 N 70 21 29.204 W 149 1854.939 SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) N-MIL-200IL-200lL-200 Generated 3/19/2004 1 :34 PM Page 1 of 5 e e Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Easling Latilude Longilude Depth Section Departure (ft) ( deg) ( deg) (ft) (ft) (ft) (ft) (ft) (ft) ( deg/100 ft) ( deg/100 ft) ( deg/100 ft) (ftUS) (ftUS) 4627.48 60.80 24.14 3049.19 2971.59 2016.12 3046.67 2802.87 1161.17 1.24 1.14 -0.56 5981105.06 584339.13 N 70 21 29.926 W 149 1853.966 4722.40 60.28 24.94 3095.87 3018.27 2068.81 3129.32 2878.05 1195.49 0.92 -0.55 0.84 5981180.61 584372.62 N 7021 30.665 W 149 1852.962 4816.87 60.38 23.69 3142.63 3065.03 2121.39 3211.40 2952.85 1229.29 1.15 0.11 -1.32 5981255.78 584405.58 N702131.400 W1491851.973 4912.55 59.31 22.34 3190.70 3113.10 2175.81 3294.13 3028.99 1261.64 1.65 -1.12 -1.41 5981332.26 584437.08 N702132.149 W1491851.027 5008.50 57.77 18.47 3240.79 3163.19 2232.37 3375.97 3105.66 1290.18 3.80 -1.61 -4.03 5981409.25 584464.77 N 70 2132.903 W 1491850.192 5104.61 58.34 13.86 3291.66 3214.06 2292.94 3457.51 3183.96 1312.87 4.11 0.59 -4.80 5981487.79 584486.58 N 70 21 33.673 W 149 18 49.528 5199.90 57.64 9.39 3342.19 3264.59 2357.03 3538.30 3263.07 1329.16 4.04 -0.73 -4.69 5981567.06 584501.99 N 70 21 34.451 W 149 1849.052 5293.31 58.75 4.11 3391.44 3313.64 2423.88 3617.67 3341.87 1338.46 4.95 1.19 -5.65 5981645.95 584510.42 N 70 21 35.226 W 149 1848.779 5382.64 57.50 359.13 3438.63 3361.03 2491.15 3693.51 3417.66 1340.63 4.94 -1.40 -5.57 5981721.75 584511.74 N 7021 35.972 W 149 1848.716 5473.11 55.55 354.17 3488.55 3410.95 2560.81 3768.96 3492.95 1336.26 5.05 -2.16 -5.48 5981796.98 584506.53 N 70 21 36.712 W 149 1848.843 5566.34 55.83 348.17 3541.14 3463.54 2634.39 3845.94 3568.99 1324.44 5.32 0.30 -6.44 5981872.88 584493.87 N 70 21 37.460 W 149 1849.188 5662.13 56.12 342.91 3594.76 3517.16 2712.18 3925.31 3645.82 1304.62 4.56 0.30 -5.49 5981949.48 584473.20 N 70 21 38.216 W 149 1849.767 5755.61 57.00 338.21 3646.30 3568.70 2789.66 4003.31 3719.34 1278.65 4.30 0.94 -5.03 5982022.70 584446.43 N 70 21 38.939 W 149 1850.526 5849.72 58.43 334.27 3696.58 3618.98 2869.14 4082.86 3792.12 1246.59 3.85 1.52 -4.19 5982095.11 584413.56 N 70 21 39.655 W 149 1851.463 5944.69 59.72 330.25 3745.40 3667.80 2950.54 4164.31 3864.19 1208.66 3.88 1.36 -4.23 5982166.75 584374.84 N 70 21 40.363 W 149 1852.572 6038.46 59.78 326.28 3792.65 3715.05 3031.09 4245.31 3933.06 1166.07 3.66 0.06 -4.23 5982235.14 564331 .49 N702141.041 W1491853.817 6131.99 59.64 323.53 3839.83 3762.23 3110.79 4326.07 3999.13 1119.64 2.54 -0.15 -2.94 5982300.68 584284.34 N 70 2141.691 W 1491855.174 6228.13 60.43 319.19 3887.87 3810.27 3191.98 4409.34 4064.16 1067.65 4.00 0.82 -4.51 5982365.12 584231.62 N 70 21 42.330 W 149 18 56.695 6322.08 61.20 315.37 3933.69 3856.09 3270.45 4491.36 4124.40 1012.01 3.64 0.82 -4.07 5982424.73 584175.33 N 70 21 42.923 W 149 18 58.321 6413.76 62.81 311.82 3976.74 3899.14 3346.22 4572.30 4180.19 953.38 3.84 1.76 -3.87 5982479.86 584116.09 N 70 21 43.472 W 149 190.035 6508.94 66.45 309.17 4017.52 3939.92 3424.96 4658.29 4236.00 887.98 4.58 3.82 -2.78 5982534.94 584050.08 N 70 21 44.021 W 149191.947 6602.27 69.53 308.73 4052.49 3974.89 3503.24 4744.80 4290.38 820.70 3.33 3.30 -0.47 5982588.57 583982.20 N 70 21 44.555 W 149 19 3.915 6696.22 68.09 309.19 4086.45 4008.85 3582.51 4832.40 4345.46 752.58 1.60 -1.53 0.49 5982642.88 583913.49 N 70 21 45.097 W 149 195.906 6788.62 68.74 308.14 4120.44 4042.84 3660.07 4918.32 4399.14 685.49 1.27 0.70 -1.14 5982695.80 583845.81 N 70 21 45.625 W 149 197.868 6882.92 68.49 308.62 4154.83 4077.23 3739.14 5006.13 4453.65 616.66 0.54 -0.27 0.51 5982749.55 583776.39 N 70 2146.161 W 149 199.881 6977.12 69.35 308.67 4188.71 4111.11 3818.47 5094.02 4508.54 548.01 0.91 0.91 0.05 5982803.67 583707.14 N 702146.701 W 1491911.888 7071.71 70.05 309.02 4221.52 4143.92 3898.67 5182.74 4564.19 478.92 0.82 0.74 0.37 5982858.53 583637.44 N 70 2147.249 W 149 19 13.909 7165.20 67.88 310.68 4255.08 4177.48 3978.19 5269.99 4620.09 411.93 2.85 -2.32 1.78 5982913.68 583569.84 N 70 2147.798 W 149 19 15.867 7259.49 65.27 310.23 4292.56 4214.96 4057.41 5356.50 4676.22 346.10 2.80 -2.77 -0.48 5982969.08 583503.40 N 70 21 48.351 W 149 19 17.792 7353.09 64.32 308.94 4332.42 4254.82 4134.43 5441.19 4730.19 280.64 1.61 -1.01 -1.38 5983022.31 583437.55 N 70 2148.881 W 149 19 19.701 7447.35 64.54 307.41 4373.11 4295.51 4210.86 5526.22 4782.74 214.00 1.48 0.23 -1.62 5983074.11 583370.13 N 70 21 49.398 W 149 1921.655 7539.92 68.32 305.92 4410.12 4332.52 4286.11 5611.05 4833.38 145.95 4.34 4.08 -1.61 5983123.99 583301.53 N 702149.896 W 149 1923.645 7634.03 73.67 304.90 4440.76 4363.16 4364.09 5699.99 4884.91 73.44 5.78 5.68 -1.08 5983174.70 583228.46 N 70 2150.403 W 149 1925.766 7729.26 79.19 303.22 4463.09 4385.49 4444.15 5792.53 4936.72 -3.22 6.04 5.80 -1.76 5983225.65 583151.23 N 70 2150.913 W 1491928.008 7803.19 81.68 305.16 4475.38 4397.78 4507.30 5865.43 4977.68 -63.52 4.25 3.37 2.62 5983265.94 583090.50 N 70 2151.315 W 1491929.771 7900.98 83.22 303.26 4488.23 4410.63 4591.30 5962.36 5032.18 -143.68 2.49 1.57 -1.94 5983319.54 583009.74 N702151.851 W1491932.115 7931.42 85.02 303.33 4491.35 4413.75 4617.29 5992.64 5048.80 -168.99 5.92 5.91 0.23 5983335.88 582964.25 N 70 21 52.015 W 149 19 32.855 7962.34 86.32 302.33 4493.68 4416.08 4643.63 6023.47 5065.52 -194.90 5.30 4.20 -3.23 5983352.30 582958.16 N 70 2152.179 W 14919 33.613 7993.86 88.55 301.07 4495.09 4417.49 4670.20 6054.96 5082.06 -221.68 8.12 7.07 -4.00 5983368.55 582931.19 N 70 21 52.342 W 149 19 34.397 8024.42 90.27 298.93 4495.41 4417.81 4695.49 6085.52 5097.34 -248.15 8.98 5.63 -7.00 5983383.53 582904.57 N 7021 52.492 W 149 1935.170 8056.01 91.50 299.88 4494.92 4417.32 4721.44 6117.10 5112.85 -275.66 4.92 3.89 3.01 5983398.73 582876.88 N 70 2152.645 W 149 19 35.975 8086.73 91.02 299.23 4494.24 4416.64 4746.72 6147.82 5128.00 -302.38 2.63 -1.56 -2.12 5983413.58 582850.00 N 70 21 52.794 W 149 19 36.757 8118.07 91.40 299.13 4493.58 4415.98 4772.40 6179.15 5143.27 -329.74 1.25 1.21 -0.32 5983428.55 582822.48 N 70 21 52.944 W 149 1937.557 8149.11 92.05 300.56 4492.65 4415.05 4798.03 6210.17 5158.71 -356.65 5.06 2.09 4.61 5983443.69 582795.40 N 70 21 53.096 W 149 1938.344 8180.15 91.30 300.49 4491.74 4414.14 4823.86 6241.20 5174.47 -383.37 2.43 -2.42 -0.23 5983459.15 582768.50 N 70 2153.251 W 1491939.125 8210.98 90.54 300.95 4491.24 4413.64 4849.59 6272.03 5190.22 -409.87 2.88 -2.47 1.49 5983474.60 582741.83 N 70 21 53.406 W 149 19 39.900 8242.51 90.27 301.08 4491.02 4413.42 4875.99 6303.56 5206.46 -436.89 0.95 -0.86 0.41 5983490.54 582714.64 N 7021 53.565 W 149 1940.691 8272.55 90.06 302.39 4490.93 4413.33 4901.35 6333.60 5222.26 -462.44 4.42 -0.70 4.36 5983506.06 582688.92 N702153.721 W1491941.438 8303.76 89.82 303.84 4490.97 4413.37 4928.09 6364.81 5239.31 -488.58 4.71 -0.77 4.65 5983522.81 582662.59 N 70 21 53.888 W 149 19 42.202 8334.72 90.99 306.85 4490.75 4413.15 4955.22 6395.76 5257.22 -513.83 10.43 3.78 9.72 5983540.44 582637.15 N 70 2154.064 W 1491942.941 8366.12 90.82 310.30 4490.25 4412.65 4983.53 6427.16 5276.80 -538.37 11.00 -0.54 10.99 5983559.74 582612.39 N 7021 54.257 W 149 1943.658 8397.94 89.99 311.74 4490.03 4412.43 5012.79 6458.98 5297.68 -562.38 5.22 -2.61 4.53 5983580.35 582588.16 N 70 21 54.462 W 149 1944.361 8430.29 88.69 311.98 4490.40 4412.80 5042.72 6491.33 5319.26 -586.47 4.09 -4.02 0.74 5983601.66 582563.83 N 70 21 54.675 W 149 19 45.065 8459.96 89.20 311.10 4490.95 4413.35 5070.11 6520.99 5338.94 -608.67 3.43 1.72 -2.97 5983621.09 582541.41 N 70 2154.868 W 149 1945.715 8491.26 88.72 310.72 4491.51 4413.91 5098.86 6552.29 5359.43 -632.32 1.96 -1.53 -1.21 5983641.31 582517.54 N 70 2155.070 W 149 1946.406 8522.91 88.90 311.07 4492.17 4414.57 5127.93 6583.93 5380.15 -656.24 1.24 0.57 1.11 5983661.76 582493.39 N 70 21 55.273 W 149 1947.106 8553.96 88.96 310.31 4492.75 4415.15 5156.41 6614.97 5400.39 -679.78 2.45 0.19 -2.45 5983681.74 582469.63 N 70 21 55.472 W 149 1947.794 8585.17 90.95 312.49 4492.78 4415.18 5185.19 6646.18 5421.02 -703.19 9.46 6.38 6.98 5983702.11 582446.00 N 70 21 55.675 W 149 1948.479 8617.09 91.71 313.66 4492.04 4414.44 5214.97 6678.09 5442.82 -726.50 4.37 2.38 3.67 5983723.64 582422.45 N 70 2155.890 W 1491949.161 8647.04 91.78 313.13 4491.12 4413.52 5242.96 6708.03 5463.38 -748.25 1.78 0.23 -1.77 5983743.96 582400.47 N 70 2156.092 W 149 1949.797 8678.41 91.19 312.80 4490.31 4412.71 5272.20 6739.39 5484.76 -771.20 2.15 -1.88 -1.05 5983765.08 582377.29 N 7021 56.302 W 149 1950.468 8710.23 90.78 312.32 4489.76 4412.16 5301.78 6771.21 5506.28 -794.64 1.98 -1.29 -1.51 5983786.33 582353.62 N 70 2156.514 W 1491951.154 8740.61 90.92 312.40 4489.31 4411.71 5329.99 6801.58 5526.74 -817.08 0.53 0.46 0.26 5983806.55 582330.95 N 70 21 56.715 W 149 1951.810 8772.08 91.16 312.24 4488.74 4411.14 5359.20 6833.05 5547.93 -840.35 0.92 0.76 -0.51 5983827.47 582307.45 N 70 21 56.923 W 149 19 52.491 8803.52 90.47 310.35 4488.29 4410.69 5388.16 6864.48 5568.67 -863.96 6.40 -2.19 -6.01 5983647.95 582283.61 N 70 2157.127 W 1491953.182 8834.68 89.99 308.31 4488.17 4410.57 5416.45 6895.64 5588.42 -888.07 6.73 -1.54 -6.55 5983867.43 582259.29 N 7021 57.321 W 149 1953.887 8866.05 89.82 308.80 4488.22 4410.62 5444.74 6927.01 5607.97 -912.60 1.65 -0.54 1.56 5983886.70 582234.55 N 70 21 57.514 W 149 1954.604 8897.31 90.40 307.61 4488.16 4410.56 5472.85 6958.27 5627.30 -937.16 4.23 1.86 -3.81 5983905.76 582209.77 N 70 21 57.704 W 149 1955.323 8927.58 90.16 307.87 4488.01 4410.41 5499.96 6988.54 5645.83 -961.10 1.17 -0.79 0.86 5983924.02 582185.63 N 70 2157.886 W 149 1956.023 SurveyEditorVer 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) N-M\L-200\L-200lL-200 Generated 3/19/2004 1 :34 PM Page 2 of 5 · e e Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Venical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Nonhing Eastlng Lathude Longitude Depth Section Departure (ft) ( deg) ( deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100ft) (deg/100ft) (deg/100ft) (ftUS) (ftUS) 8959.06 90.54 306.45 4487.82 4410.22 5528.01 7020.02 5664.85 -986.18 4.67 1.21 -4.51 5983942.75 582160.34 N 70 21 58.073 W 149 1956.757 8990.33 91.30 306.81 4487.32 4409.72 5555.73 7051 .29 5683.50 -1011.28 2.69 2.43 1.15 5983961.13 582135.05 N 70 21 58.256 W 149 1957.490 9021.17 90.30 304.99 4486.89 4409.29 5582.90 7082.12 5701.58 -1036.25 6.73 -3.24 -5.90 5983978.93 582109.87 N 70 21 58.434 W 149 1958.221 9051.91 90.99 303.50 4486.54 4408.94 5609.54 7112.86 5718.88 -1061.66 5.34 2.24 -4.85 5983995.94 582084.28 N 70 21 58.604 W 149 19 58.964 9083.26 91.60 302.08 4485.83 4408.23 5636.30 7144.20 5735.85 -1088.01 4.93 1.95 -4.53 5984012.62 582057.74 N 70 2158.771 W 149 1959.735 9114.50 93.08 301.84 4484.56 4406.96 5662.72 7175.42 5752.37 -1114.49 4.80 4.74 -0.77 5964028.84 582031.08 N 70 21 58.934 W 149200.509 9145.08 94.49 301.38 4482.54 4404.94 5688.44 7205.93 5768.37 -1140.48 4.85 4.61 -1.50 5984044.54 582004.92 N 70 21 59.091 W 149201.270 9176.30 94.83 302.14 4480.00 4402.40 5714.72 7237.05 5784.74 -1166.93 2.66 1.09 2.43 5984060.63 581978.29 N 70 21 59.252 W 149202.043 9206.86 95.11 302.13 4477.36 4399.76 5740.53 7267.49 5800.94 -1192.71 0.92 0.92 -0.03 5964076.53 581952.33 N 70 2159.411 W 149202.798 9238.25 94.56 302.45 4474.71 4397.11 5767.10 7298.77 5817.65 -1219.16 2.03 -1.75 1.02 5984092.94 581925.71 N 70 21 59.575 W 149203.571 9269.79 93.97 303.60 4472.36 4394.76 5794.02 7330.22 5834.79 -1245.53 4.09 -1.87 3.65 5984109.79 581899.15 N 70 21 59.744 W 149204.342 9300.03 93.36 303.35 4470.43 4392.83 5819.98 7360.40 5851.43 -1270.70 2.18 -2.02 -0.83 5984126.15 581873.80 N 70 21 59.908 W 149205.079 9330.99 93.18 305.18 4468.66 4391.06 5846.78 7391.31 5868.84 -1296.24 5.93 -0.58 5.91 5984143.27 581848.07 N 70 22 0.079 W 149205.826 9362.66 92.77 305.24 4467.02 4389.42 5874.45 7422.94 5887.07 -1322.08 1.31 -1.29 0.19 5984161.22 581822.03 N 70 22 0.258 W 149206.582 9394.07 92.15 305.62 4465.67 4388.07 5901.97 7454.32 5905.26 -1347.65 2.31 -1.97 1.21 5984179.12 581796.26 N 70 22 0.437 W 149207.330 9424.41 91.91 306.17 4464.60 4387.00 5928.68 7484.64 5923.04 -1372.22 1.98 -0.79 1.81 5984196.62 581771.50 N 70 22 0.612 W 149208.048 9456.34 92.84 305.96 4463.28 4385.68 5956.83 7516.54 5941 .82 -1398.00 2.99 2.91 -0.66 5984215.11 581745.51 N 70 22 0.796 W 149208.803 9488.12 95.21 304.36 4461.04 4383.44 5984.55 7548.24 5960.08 -1423.92 8.99 7.46 -5.03 5984233.08 581719.40 N 70 22 0.976 W 149209.561 9519.32 95.18 304.81 4458.22 4380.62 6011.58 7579.31 5977.71 -1449.50 1.44 -0.10 1.44 5984250.43 581693.62 N 70 221.149 W 1492010.309 9549.92 94.11 305.05 4455.74 4378.14 6038.20 7609.81 5995.18 -1474.50 3.58 -3.50 0.78 5984267.61 581668.43 N 70 221.321 W 1492011.040 9580.74 93.49 304.83 4453.70 4376.10 6065.04 7640.56 6012.79 -1499.71 2.13 -2.01 -0.71 5984284.94 581643.03 N 70 221.494 W 1492011.778 9611.64 93.04 303.35 4451.94 4374.34 6091.74 7671.41 6030.08 -1525.26 5.00 -1.46 -4.79 5984301.94 581617.29 N 70 221.664 W 1492012.525 9643.64 92.84 303.86 4450.30 4372.70 6119.26 7703.37 6047.77 -1551.88 1.71 -0.63 1.59 5984319.33 581590.49 N 70 221.838 W 1492013.304 9674.28 92.63 303.51 4448.84 4371.24 6145.64 7733.98 6064.74 -1577.34 1.33 -0.69 -1.14 5984336.02 581564.83 N 70 22 2.005 W 14920 14.049 9705.51 92.70 302.99 4447.38 4369.78 6172.41 7765.17 6081.85 -1603.43 1.68 0.22 -1.67 5984352.83 581538.56 N 70 22 2.173 W 1492014.812 9736.95 92.22 303.95 4446.03 4368.43 6199.42 7796.58 6099.17 -1629.63 3.41 -1.53 3.05 5984369.86 581512.17 N 70 22 2.343 W 1492015.578 9768.87 91.26 304.88 4445.06 4367.46 6227.13 7828.49 6117.20 -1655.95 4.19 -3.01 2.91 5984387.60 581485.65 N 70 22 2.521 W 149 20 16.348 9799.72 90.61 306.87 4444.56 4366.96 6254.29 7859.33 6135.28 -1680.95 6.79 -2.11 6.45 5984405.40 581460.46 N 70 22 2.698 W 1492017.079 9830.67 89.72 307.24 4444.47 4366.87 6281.85 7890.28 6153.93 -1705.65 3.11 -2.88 1.20 5984423.77 581435.56 N 70 22 2.882 W 1492017.802 9860.94 90.85 309.09 4444.32 4366.72 6309.05 7920.55 6172.63 -1729.44 7.16 3.73 6.11 5984442.20 581411.56 N 70 22 3.066 W 14920 18.498 9891.96 91.91 312.33 4443.57 4365.97 6337.50 7951.56 6192.85 -1752.95 10.99 3.42 10.45 5984462.16 581387.83 N 70 22 3.264 W 1492019.186 9924.78 89.68 312.94 4443.12 4365.52 6368.03 7984.38 6215.08 -1777.09 7.04 -6.79 1.86 5984484.12 581363.45 N 70 22 3.483 W 1492019.892 9954.80 87.18 312.73 4443.94 4366.34 6395.98 8014.38 6235.48 -1799.09 8.36 -8.33 -0.70 5984504.27 581341.22 N 70 22 3.684 W 1492020.536 9986.84 86.87 314.41 4445.60 4368.00 6425.94 8046.38 6257.53 -1822.27 5.32 -0.97 5.24 5984526.06 581317.80 N 70 22 3.900 W 1492021.214 10018.16 88.04 317.33 4447.00 4369.40 6455.64 8077.67 6279.99 -1844.06 10.03 3.74 9.32 5984548.27 581295.77 N 70 22 4.121 W 1492021.851 10048.54 88.04 318.47 4448.03 4370.43 6484.79 8108.03 6302.52 -1864.41 3.75 0.00 3.75 5984570.57 581275.17 N 70 22 4.343 W 1492022.447 10079.98 87.49 318.50 4449.26 4371.66 6515.04 8139.45 6326.04 -1885.24 1.75 -1.75 0.10 5984593.86 581254.09 N 70 22 4.574 W 1492023.056 10111.23 87.56 319.92 4450.61 4373.01 6545.21 8170.67 6349.68 -1905.63 4.55 0.22 4.54 5984617.27 581233.43 N 70 22 4.806 W 1492023.653 10142.45 89.20 323.34 4451.49 4373.89 6575.67 8201.87 6374.14 -1925.00 12.14 5.25 10.95 5984641.51 581213.80 N 70 22 5.047 W 1492024.220 10173.29 89.34 324.22 4451 .89 4374.29 6606.00 8232.71 6399.02 -1943.22 2.89 0.45 2.85 5984666.18 581195.30 N 70 22 5.292 W 1492024.753 10204.90 89.34 323.97 4452.25 4374.65 6637.12 8264.32 6424.62 -1961.76 0.79 0.00 -0.79 5984691.58 581176.48 N 70 22 5.543 W 1492025.295 10235.49 89.14 324.28 4452.66 4375.06 6667.24 8294.91 6449.40 -1979.68 1.21 -0.65 1.01 5984716.16 581158.29 N 70 22 5.787 W 1492025.820 10266.22 88.76 324.10 4453.22 4375.62 6697.50 8325.63 6474.32 -1997.66 1.37 -1.24 -0.59 5984740.87 581140.04 N 70 22 6.032 W 1492026.346 10298.03 88.24 325.05 4454.05 4376.45 6728.86 8357.43 6500.23 -2016.09 3.40 -1.63 2.99 5984766.57 581121.32 N 70 22 6.287 W 149 20 26.885 10328.08 87.73 324.22 4455.11 4377.51 6758.48 8387.46 6524.72 -2033.47 3.24 -1.70 -2.76 5984790.87 581103.67 N 70 22 6.528 W 1492027.394 10359.45 87.45 325.04 4456.43 4378.83 6789.39 8418.80 6550.28 -2051.62 2.76 -0.89 2.61 5984816.22 581085.25 N 70 22 6.779 W 1492027.924 10386.59 87.32 325.66 4457.67 4380.07 6816.18 8445.92 6572.58 -2067.03 2.33 -0.48 2.28 5984838.35 581069.59 N 70 22 6.998 W 1492028.375 10418.26 87.04 326.25 4459.22 4381.62 6847.49 8477.55 6598.79 -2084.74 2.06 -0.88 1.86 5984864.36 581051.59 N 70 22 7.256 W 1492028.894 10449.19 87.42 325.70 4460.72 4383.12 6878.07 8508.44 6624.40 -2102.03 2.16 1.23 -1.78 5984889.77 581034.02 N 70 22 7.508 W 1492029.400 10480.30 88.01 324.46 4461.96 4384.36 6908.76 8539.53 6649.88 -2119.82 4.41 1.90 -3.99 5984915.05 581015.95 N 70 22 7.758 W 1492029.920 10511.10 89.00 323.17 4462.76 4385.16 6939.05 8570.32 6674.73 -2138.00 5.28 3.21 -4.19 5984939.70 580997.50 N 70 22 8.003 W 1492030.452 10543.35 89.89 321.09 4463.07 4385.47 6970.59 8602.56 6700.19 -2157.79 7.01 2.76 -6.45 5984964.93 580977.42 N 70 22 8.253 W 149 20 31.031 10574.49 90.23 319.01 4463.04 4385.44 7000.79 8633.70 6724.06 -2177.79 6.77 1.09 -6.68 5984988.57 580957.16 N 70 22 8.488 W 1492031.616 10605.40 90.78 316.50 4462.77 4385.17 7030.44 8664.61 6746.94 -2198.56 8.31 1.78 -8.12 5985011.22 580936.13 N 70 22 8.713 W 1492032.224 10637.15 91.50 315.56 4462.14 4384.54 7060.61 8696.36 6769.79 -2220.60 3.73 2.27 -2.96 5985033.81 580913.85 N 70 22 8.937 W 1492032.869 10670.03 91.57 311.88 4461.26 4383.66 7091.41 8729.22 6792.50 -2244.35 11.19 0.21 -11.19 5985056.26 580889.85 N 70 22 9.161 W 1492033.564 10699.75 92.02 308.82 4460.33 4382.73 7118.58 8758.93 6811.73 -2266.99 10.40 1.51 -10.30 5985075.24 580867.00 N 70 22 9.350 W 1492034.227 10731.35 91.88 306.99 4459.25 4381.65 7146.91 8790.51 6831.13 -2291.91 5.80 -0.44 -5.79 5985094.36 580841.87 N 70 22 9.540 W 1492034.956 10762.99 93.01 308.49 4457.90 4380.30 7175.22 8822.12 6850.48 -2316.90 5.93 3.57 4.74 5985113.42 580816.66 N 70 22 9.731 W 1492035.687 10793.31 93.42 308.66 4456.20 4378.60 7202.52 8852.39 6869.35 -2340.57 1.46 1.35 0.56 5985132.03 580792.79 N 70 22 9.916 W 1492036.379 10825.47 93.73 309.72 4454.19 4376.59 7231.62 8884.49 6889.63 -2365.45 3.43 0.96 3.30 5985152.04 580767.69 N702210.116 W1492037.107 10856.50 93.29 308.97 4452.30 4374.70 7259.74 8915.46 6909.27 -2389.40 2.80 -1.42 -2.42 5985171.40 580743.53 N 70 2210.309 W 1492037.808 10888.23 92.87 309.36 4450.59 4372.99 7288.46 8947.15 6929.28 -2413.97 1.81 -1.32 1.23 5985191.14 580718.74 N 70 22 10.505 W 149 20 38.527 10919.28 92.67 309.05 4449.09 4371.49 7316.58 8978.16 6948.88 -2438.00 1.19 -0.64 -1.00 5985210.47 580694.50 N 70 22 10.698 W 1492039.230 10951.17 93.22 309.78 4447.45 4369.85 7345.50 9010.01 6969.11 -2462.60 2.86 1.72 2.29 5985230.42 580669.67 N 70 2210.897 W 1492039.950 10981.32 94.52 312.03 4445.42 4367.82 7373.14 9040.09 6988.80 -2485.34 8.60 4.31 7.46 5985249.86 580646.72 N 70 22 11.090 W 1492040.615 11011.99 94.39 312.08 4443.03 4365.43 7401.47 9070.67 7009.28 -2508.04 0.45 -0.42 0.16 5985270.08 580623.80 N 70 2211.292 W 1492041.280 11041.38 94.18 311.65 4440.84 4363.24 7428.59 9099.97 7028.84 -2529.86 1.62 -0.71 -1.46 5985289.40 580601.76 N 70 2211.484 W 1492041.918 SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031rt-546 } N-MIL -200lL -200IL-200 Generated 3/19/2004 1 :34 PM Page 3 of 5 " .. e e Measured I Inclination I Azimuth I TVD I Su~SU TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Northing Eastlng Lathude Longhude Depth Section Departure (ft) ( deg) ( deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) ( deg/100 ft) ( deg/100 ft ) (ftUS) (ftUS) 11072.41 92.53 309.04 4439.02 4361 .42 7456.93 9130.95 7048.89 -2553.47 9.94 -5.32 -8.41 5985309.18 580577.93 N 70 2211.681 W 149 20 42.609 11102.57 92.81 307.40 4437.62 4360.02 7484.02 9161.08 7067.53 -2577.14 5.51 0.93 -5.44 5985327.56 580554.06 N 70 2211.864 W 149 20 43.302 11132.04 93.66 306.56 4435.95 4358.35 7510.20 9190.50 7085.23 -2600.64 4.05 2.88 -2.85 5985344.99 580530.36 N 70 2212.038 W 1492043.989 11168.13 94.28 304.98 4433.45 4355.85 7541.87 9226.50 7106.28 -2629.85 4.69 1.72 -4.38 5985365.71 580500.92 N 70 22 12.245 W 149 20 44.844 11195.33 94.73 305.23 4431.32 4353.72 7565.58 9253.62 7121.87 -2652.04 1.89 1.65 0.92 5985381.05 580478.57 N 70 22 12.399 W 149 20 45.493 11218.81 95.21 303.45 4429.28 4351.68 7585.87 9277.01 7135.06 -2671.35 7.82 2.04 -7.58 5985394.03 580459.11 N 702212.528 W 149 2046.058 11259.33 95.73 304.80 4425.42 4347.82 7620.79 9317.35 7157.69 -2704.74 3.56 1.28 3.33 5985416.28 580425.48 N 70 2212.751 W 1492047.035 11291.41 95.56 305.49 4422.27 4344.67 7648.72 9349.27 7176.07 -2730.85 2.21 -0.53 2.15 5985434.37 580399.17 N 70 22 12.931 W 1492047.799 11325.29 93.46 307.10 4419.60 4342.00 7678.57 9383.04 7196.06 -2758.07 7.80 -6.20 4.75 5985454.06 580371.73 N 70 2213.128 W 149 20 48.595 11355.84 94.04 306.31 4417.60 4340.00 7705.63 9413.53 7214.28 -2782.50 3.20 1.90 -2.59 5985472.00 580347.10 N 70 2213.307 W 1492049.311 11387.22 94.11 306.91 4415.37 4337.77 7733.38 9444.83 7232.95 -2807.63 1.92 0.22 1.91 5985490.39 580321.77 N 70 22 13.490 W 1492050.046 11418.24 93.46 307.09 4413.33 4335.73 7760.92 9475.78 7251 .57 -2832.35 2.17 -2.10 0.58 5985508.74 580296.85 N 70 2213.674 W 1492050.769 11448.89 93.18 306.83 4411.55 4333.95 7788.14 9506.38 7269.97 -2856.80 1.25 -0.91 -0.85 5985526.86 580272.20 N 70 2213.854 W 149 20 51.485 11480.82 93.15 307.30 4409.79 4332.19 7816.53 9538.26 7289.19 -2882.24 1.47 -0.09 1.47 5985545.79 580246.55 N 70 22 14.043 W 1492052.229 11506.45 94.32 306.62 4408.12 4330.52 7839.27 9563.84 7304.56 -2902.68 5.28 4.56 -2.65 5985560.94 580225.94 N 70 2214.194 W 1492052.827 11537.39 95.93 306.33 4405.35 4327.75 7866.56 9594.65 7322.88 -2927.45 5.29 5.20 -0.94 5985578.98 580200.96 N 70 2214.375 W 149 20 53.552 11569.11 95.83 306.09 4402.10 4324.50 7894.44 9626.20 7341.52 -2952.91 0.82 -0.32 -0.76 5985597.33 580175.30 N 70 22 14.558 W 1492054.297 11599.17 94.97 305.79 4399.28 4321.68 7920.81 9656.13 7359.09 -2977.14 3.03 -2.86 -1.00 5985614.63 580150.88 N 70 22 14.730 W 1492055.006 11632.45 95.25 305.77 4396.31 4318.71 7949.98 9689.28 7378.47 -3004.03 0.84 0.84 -0.06 5985633.70 580123.78 N 70 22 14.921 W 149 20 55.793 11666.76 91.98 307.32 4394.15 4316.55 7980.32 9723.52 7398.86 -3031.54 10.54 -9.53 4.52 5985653.78 580096.05 N 70 2215.121 W 1492056.598 11697.85 88.21 306.93 4394.10 4316.50 8008.01 9754.60 7417.62 -3056.32 12.19 -12.13 -1.25 5985672.27 580071.06 N 70 22 15.306 W 1492057.323 11728.44 87.25 307.71 4395.31 4317.71 8035.28 9785.17 7436.15 -3080.63 4.04 -3.14 2.55 5985690.52 580046.55 N 70 22 15.488 W 149 20 58.034 11759.81 86.70 308.37 4396.96 4319.36 8063.41 9816.49 7455.45 -3105.30 2.74 -1.75 2.10 5985709.55 580021.67 N 70 22 15.678 W 149 20 58.756 11791.59 86.60 309.25 4398.82 4321.22 8092.08 9848.22 7475.33 -3130.02 2.78 -0.31 2.77 5985729.16 579996.73 N 70 2215.873 W 1492059.480 11822.04 88.00 308.96 4400.26 4322.66 8119.64 9878.63 7494.52 -3153.63 4.70 4.60 -0.95 5985748.08 579972.92 N 70 22 16.062 W14921 0.170 11852.88 88.96 309.65 4401.07 4323.47 8147.61 9909.46 7514.05 -3177.48 3.83 3.11 2.24 5985767.34 579948.85 N 70 22 16.254 W 149 21 0.869 11883.12 88.76 309.07 4401.68 4324.08 8175.06 9939.70 7533.22 -3200.86 2.03 -0.66 -1.92 5985786.25 579925.27 N 70 22 16.442 W 149211.553 11913.99 88.59 309.41 4402.39 4324.79 8203.05 9970.56 7552.74 -3224.76 1.23 -0.55 1.10 5985805.50 579901.15 N 70 22 16.634 W 14921 2.252 11945.40 88.62 309.53 4403.15 4325.55 8231.59 10001.96 7572. 70 -3249.00 0.39 0.10 0.38 5985825.19 579876.70 N 70 22 16.830 W 149 21 2.962 11975.84 88.76 310.28 4403.85 4326.25 8259.33 10032.39 7592.23 -3272.34 2.51 0.46 2.46 5985844.45 579853.14 N 70 22 17.022 W 14921 3.645 12006.67 88.24 308.74 4404.66 4327.06 8287.35 10063.21 7611.83 -3296.12 5.27 -1.69 -5.00 5985863.79 579829.15 N 70 2217.215 W 149214.341 12037.84 89.20 309.56 4405.35 4327.75 8315.59 10094.37 7631.51 -3320.29 4.05 3.08 2.63 5985883.19 579804.77 N 70 2217.408 W 14921 5.048 12068.66 89.75 308.57 4405.64 4328.04 8343.50 10125.19 7650.93 -3344.21 3.67 1.78 -3.21 5985902.35 579780.63 N 70 2217.599 W 149 21 5.748 12099.05 91.37 307.54 4405.34 4327.74 8370.79 10155.58 7669.66 -3368.14 6.32 5.33 -3.39 5985920.81 579756.50 N 70 2217.783 W 14921 6.448 12130.72 91.50 305.31 4404.55 4326.95 8398.81 10187.24 7688.46 -3393.61 7.05 0.41 -7.04 5985939.32 579730.82 N 70 22 17.968 W 149217.194 12162.76 91.40 302.71 4403.73 4326.13 8426.51 10219.27 7706.37 -3420.16 8.12 -0.31 -8.11 5985956.94 579704.07 N 70 2218.144 W 14921 7.971 12193.59 92.22 300.96 4402.76 4325.16 8452.55 10250.08 7722.62 -3446.34 6.27 2.66 -5.68 5985972.90 579677.72 N 70 22 18.304 W 149 21 8.737 12225.54 93.25 300.39 4401.24 4323.64 8479.17 10281.99 7738.91 -3473.79 3.68 3.22 -1.78 5985988.87 579650.10 N 70 22 18.464 W 149 21 9.540 12256.50 94.42 299.91 4399.17 4321.57 8504.78 10312.88 7754.42 -3500.50 4.08 3.78 -1.55 5986004.09 579623.22 N 702218.616 W 14921 10.322 12287.13 96.18 299.36 4396.34 4318.74 8529.91 10343.38 7769.50 -3527.01 6.02 5.75 -1.80 5986018.87 579596.55 N702218.784 W 1492111.097 12319.06 95.45 301.63 4393.10 4315.50 8556.35 10375.15 7785.62 -3554.38 7.43 -2.29 7.11 5986034.68 579569.00 N 70 2218.923 W 1492111.898 12349.68 93.59 302.85 4390.69 4313.09 8582.26 10405.67 7801.90 -3580.19 7.26 -6.07 3.98 5986050.68 579543.01 N 70 2219.083 W 1492112.654 12380.59 93.56 304.45 4388.76 4311.16 8608.84 10436.52 7819.00 -3605.87 5.17 -0.10 5.18 5986067.48 579517.14 N 70 2219.251 W 149 2113.405 12411.82 93.67 306.04 4386.79 4309.19 8636.12 10467.69 7836.98 -3631.33 5.09 0.35 5.09 5986085.18 579491.49 N 70 2219.428 W 1492114.150 12440.80 93.97 307.83 4384.86 4307.26 8661.84 10496.60 7854.36 -3654.44 6.25 1.04 6.18 5986102.30 579468.19 N 70 22 19.598 W 14921 14.827 12472.88 93.97 309.21 4382.84 4305.04 8690.69 10528.61 7874.29 -3679.48 4.29 0.00 4.30 5986121.95 579442.94 N 70 2219.794 W 1492115.559 12504.22 94.39 311.45 4380.35 4302.75 8719.28 10559.86 7894.52 -3703.30 7.25 1.34 7.15 5986141.91 579418.89 N 70 22 19.993 W 149 21 16.257 12534.62 94.28 312.60 4378.06 4300.46 8747.36 10590.18 7914.81 -3725.82 3.79 -0.36 3.78 5986161.95 579396.15 N 70 22 20.193 W 149 2116.916 12565.23 93.49 311.78 4375.98 4298.38 8775.69 10620.72 7935.32 -3748.45 3.72 -2.58 -2.68 5986182.20 579373.30 N 70 22 20.394 W 14921 17.578 12596.67 92.87 312.21 4374.24 4296.84 8804.76 10652.11 7956.32 -3771.78 2.40 -1.97 1.37 5986202.94 579349.74 N 70 22 20.601 W 14921 18.261 12630.44 92.67 313.18 4372.61 4295.01 8836.15 10685.84 7979.19 -3796.57 2.93 -0.59 2.87 5986225.54 579324.70 N 70 22 20.825 W 1492118.987 12660.85 92.15 312.66 4371.33 4293.73 8864.47 10716.22 7999.88 -3818.82 2.42 -1.71 -1.71 5986245.98 579302.22 N 70 22 21.029 W 149 2119.638 12693.09 92.94 313.54 4369.90 4292.30 8894.53 10748.43 8021.89 -3842.34 3.67 2.45 2.73 5986267.72 579278.46 N 70 22 21.245 W 149 21 20.326 12723.63 93.42 314.33 4368.20 4290.60 8923.15 10778.92 8043.05 -3864.29 3.02 1.57 2.59 5986288.63 579256.27 N 70 22 21.453 W 14921 20.969 12755.09 91.50 313.13 4366.85 4289.25 8952.60 10810.35 8064.77 -3887.01 7.19 -6.10 -3.81 5986310.10 579233.33 N 70 22 21.667 W 14921 21.634 12786.38 92.91 312.57 4365.65 4288.05 8981.73 10841.62 8086.04 -3909.93 4.85 4.51 -1.79 5986331.10 579210.17 N 70 22 21.876 W 14921 22.305 12815.01 92.15 309.89 4364.38 4286.78 9008.07 10870.22 8104.89 -3931 .44 9.72 -2.65 -9.36 5986349.71 579188.46 N 70 22 22.061 W 14921 22.934 12848.97 93.36 310.37 4362.75 4285.15 9039.05 10904.14 8126.75 -3957.37 3.83 3.56 1.41 5986371.28 579162.28 N 70 22 22.276 W 149 21 23.693 12881.51 93.49 310.96 4360.81 4283.21 9068.84 10936.62 8147.91 -3982.01 1.85 0.40 1.81 5986392.17 579137.41 N 70 22 22.484 W 149 21 24.414 12912.00 93.77 310.84 4358.88 4281.28 9096.78 10967.05 8167.80 -4005.04 1.39 0.92 -1.05 5988411.80 579114.16 N 70 22 22.679 W 14921 25.089 12941.85 92.74 311.72 4357.18 4279.58 9124.22 10996.85 8187.42 -4027.47 5.00 -3.45 3.62 5986431.16 579091.52 N 70 22 22.872 W 14921 25.745 12973.58 92.12 311.62 4355.84 4278.24 9153.51 11028.55 8208.50 -4051.15 1.98 -1.95 -0.32 5986451.98 579067.61 N 70 22 23.079 W 14921 26.438 13004.01 90.54 311.71 4355.13 4277.53 9181.62 11058.97 8228.72 -4073.88 5.20 -5.19 0.30 5986471.94 579044.66 N702223.278 W 1492127.104 13025.53 89.03 311.88 4355.21 4277.61 9201.52 11080.49 8243.06 -4089.92 7.06 -7.02 0.79 5986486.10 579028.46 N 70 22 23.419 W 1492127.573 13067.00 89.03 311.88 4355.91 4278.31 9239.89 11121.96 8270.74 -4120.79 0.00 0.00 0.00 5986513.44 578997.29 N 70 22 23.691 W 149 21 28.477 Leaal Description: Northina IYI IflUS! Eastina IX} IflUS! Surlaee: 2567 FSL 3705 FEL S34 T12N R 11 E UM 5978289.74 583209.27 SurveyEditorVer 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) N-MIL-200lL -200lL -200 Generated 3/19/2004 1 :34 PM Page 4 of 5 . .. . M:~~ed Ilnclinallon I Azimuth I TVD I Sub-Sea TVD I (ft) (deg) (deg) (ft) (ft) BHL: 277 FSL 2530 FEL 521 T12N R 11 E UM . Vertical Section (ft) I Along Hole I Departure (ft) 5986513.44 SurveyEditorVer 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) e NS (ft) EW I DLS I Build Rate I Walk Rate I (ft) (deg/1ooft) (deg/1ooft) (degf1ooft) 578997.29 N-M\L-200lL -200lL -200 Northing (ftUS) Eastlng (ftUS) Lathude Longhude Generated 3/19/2004 1 :34 PM Page 5 of 5 L 7109' (11 7144' r-- :g 6983' ~ 7282' ~_ 7315' r-I VI' ;) .. FROM DR_- DRAFT TREE = FMC4-1/6" 5M WB..U-EAD = FMC GEN 5 A crUA TOR = ^KS:äEV = -S2.3Ô" -BF. ELEV = 53.80" R^öP = 380' ~aJ<_Erigl~~=:~~~~1~~~~ Datum MD = 5713' '·A^"'_~ . ,~.~~'n.A.'~~~'."''''~~, DatumTVD = 4500' SS 120# OONOUcrOR H 110-3/4" CSG. 40#, L-80, ID = 9.95" H 3871' ~ I Minimum ID = 3.813" @ 2949' 4-112" HES X NIPPLE 4.5"PHOENIX DSa-JRGE-FRESS SUB,ID = 3.85" H H 14.5" PI-f\JIX MLL TI-PRESS SENSOR, ID = 3.833" IRA TAG H 17-5/8" x 5.5" BKR ZXP PACKER, ID = 5.5" H IBKR HUGHES HOOKHGR, 0 =5.64" H L-200 L-200 L 1 L-200 L2 114' 2949' H4-1/Z' HESX NIP, 0 =3.813" I GAS LIFT MANDRB..S DBI TYPE VL V LA Ta-J 59 KBG-2 [)MY BK-5 56 KBG-2 [)MY BK-5 69 KBG-2 D0<2 BEK II. ~ ST rvo 3 4258 2 5485 1 7002 ~NOTES: TVD 2860 3495 4197 PORT o o DAlE 02/22/04 02/22/04 02/22/04 I 7120' H4-1/2"BKRCMDSLEBlE,ID=3.813" Z --f 7169' H 7.625" X 4.5" BKR PRM A<R. ID = 3.875" I 7238' H4-1/Z' HESX NIP, 0 =3.813" 1 I 7258' H4-1/2"HESXNIP,ID=3.813" 1 ~_I_ _7~~~ _ ~~1~~~I~~h~ 1 ~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ] 7 5/8" WINDOW @ 7320' IRA TAG H 7270' I--tI 17-5/8" x 5.5" BKR ZXP PACKER, ID = 3.95" H 7386' IBKR HUGHES HOOK HGR, 0 =5.64" H 7419' ~ IRA TAG H 7375' 7663' ÆRFORA llON SUMMARY RB= LOG: ANGLEA TTOPPERF: xx @ xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 4-1/2" SLTD OBA 7392 -13000 0 02/18/04 4-1/2" SLTD OBb 7497 - 12944 0 02/12/04 4-1/2" SLTD OBd 7870 - 13008 0 02/04/04 175/8" CSG, 26#, L-80, ID = 6.276" H 7872' ~ 13050' DATE REV BY COMrvENTS 02/22/04 DM/JC ORIGINAL OOMR...EIlON 7332' - 13044' 6-3/4" OBa LATERAL, 10 = 3.958" ~ 1 7398' H4-1/Z'M.Jleshoe -----~-----------------J ~----------------- ~ :g µ I I I I I I I I U DATE REV BY 75/8" WINDOW @ 7424' 7436' -12988' 6-3/4" OBb LATERAL, 10 = 3.958" -~ r 7537' I 7548' 1 7557' H7.625" X 5.5" BKRZXPLNR TOPPKR. ID = 4.810" H4-1/2" Mule Shoe I H5-1/Z' X 4-1/2" XO, ID = 3.96" ~ 7872' -13,052' 6-3/4" OBd LATERAL, 10 = 3.958" OOM'v1ENTS ORION UNIT WELL: L-2oo, L-2oo L1, L-200 L2 PERMrT No: 204001 (002) (003) AA No: 50-029-23191-00 (60) (61) SEC 34, T12N, R11E, 2567' NSL & 3705' WB.. BP Exploration (Alaska) SCRLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: L-200 API number...... .., ......: 50-029-23191-00 Engineer. . . . . . . . . . . . . . . . .: 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 f·1'.!) 2 -:: L.0lf\.04 ¡ ¡/ì¡ \ . ,_I ¡ J i'¡'¡'-;1¡!--" ^~I í) G "1"*_... C " , "<{CH,¡fj V!c Pi as WIIS. omntJSak:In iJ¡'ihorage ~,~,' "~.\---:.\\\~ 2-Feb-2004 19:47:10 Spud date............ ....: Last survey date....... ..: Total accepted surveys...: MD of first survey. ......: MD of last survey........: 8 C:if -CCJ I Page 1 of 10 19-Jan-04 02-Feb-04 252 0.00 ft 13067.00 ft e ----- Geomagnetic data ---------------------- Magnetic model..... ... ...: BGGM version 2003 Magnetic date. ......... ..: 18-Jan-2004 Magnetic field strength..: 1151.11 RCNT Magnetic dec (+E/W-) .....: 25.10 degrees Magnetic dip... ..........: 80.82 degrees ----- MWD survey Reference Reference G.... ..........: Reference R......... .....: Reference Dip. ....... ....: Tolerance of G. ..........: Tolerance of R...... .....: Tolerance of Dip.. .......: Criteria --------- 1002.68 mGal 1151.11 RCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ~ ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.10 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.10 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 2-Feb-2004 19:47:10 Page 2 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 IFR 3 293.20 2.62 338.59 93.54 293.15 3.78 3.64 -1.15 3.82 342.50 2.11 MWD IFR 4 384.95 6.42 345.43 91.75 384.60 10.90 10.56 -3.20 11.03 343.12 4.18 MWD IFR 5 477.31 9.54 353.99 92.36 476.06 23.17 23.17 -5.31 23.77 347.10 3.61 MWD IFR 6 570.07 11.80 357.00 92.76 567.21 39.14 40.29 -6.61 40.83 350.69 2.51 MWD IFR 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 IFR 8 757.23 14.52 6.44 93.64 749.43 76.89 82.87 -5.30 83.04 356.34 1. 92 MWD IFR 9 852.84 15.51 10.58 95.61 841.77 97.31 107.35 -1. 61 107.36 359.14 1. 53 MWD IFR 10 948.07 17.14 16.92 95.23 933.17 117.85 133.29 4.82 133.38 2.07 2.53 MWD IFR 11 1041.74 20.60 22.39 93.67 1021.80 13 8.97 161.74 15.11 162.45 5.34 4.14 MWD IFR 12 1133.94 23.17 21.67 92.20 1107.35 162.03 193.60 27.99 195.62 8.23 2.80 MWD IFR 13 1225.20 26.94 17.94 91. 26 1190.01 189.09 229.97 41. 00 233.60 10.11 4.48 MWD IFR 14 1316.93 30.08 18.24 91.73 1270.61 220.60 271.58 54.59 277.02 11.37 3.43 MWD IFR 15 1411.64 34.84 18.04 94.71 1350.50 257.17 319.88 70.41 327.54 12.41 5.03 MWD IFR 16 1506.19 39.85 19.56 94.55 1425.64 297.93 374.14 88.93 384.56 13 .37 5.39 MWD IFR 17 1599.03 45.79 21. 02 92.84 1493.71 341.60 433.28 110.84 447.23 14.35 6.49 MWD IFR 18 1611.13 46.32 21. 03 12.10 1502.11 347.55 441. 41 113.97 455.89 14.48 4.38 MWD IFR 19 1698.21 51.08 22.41 87.08 1559.57 391.65 502.16 138.20 520.83 15.39 5.59 MWD IFR 20 1756.11 50.03 22.45 57.90 1596.35 421. 41 543.49 155.26 565.23 15.94 1. 81 MWD IFR 21 1791.91 51.04 23.53 35.80 1619.11 439.60 568.93 166.05 592.66 16.27 3.66 MWD IFR 4t 22 1887.20 56.88 23.21 95.29 1675.15 489.91 639.63 196.60 669.16 17.09 6.13 MWD IFR 23 1981. 24 58.01 25.12 94.04 1725.75 540.83 711.94 229.05 747.88 17.83 2.09 MWD IFR 24 2076.97 62.57 27.10 95.73 1773.19 592.02 786.56 265.66 830.21 18.66 5.09 MWD IFR 25 2171.63 62.72 27.00 94.66 1816.68 642.74 861. 44 303.89 913.47 19.43 0.18 MWD IFR 26 2264.42 62.24 26.73 92.79 1859.56 692.59 934.85 341.08 995.12 20.04 0.58 MWD IFR 27 2359.44 61.59 26.48 95.02 1904.29 743.67 1009.80 378.62 1078.45 20.55 0.72 MWD IFR 28 2452.62 61.59 26.47 93.18 1948.62 793.76 1083.16 415.16 1160.00 20.97 0.01 MWD IFR 29 2546.39 61. 38 26.38 93.77 1993.39 844.18 1156.95 451. 83 1242.05 21. 33 0.24 MWD IFR 30 2639.87 60.98 24.82 93.48 2038.45 895.22 1230.81 487.22 1323.73 21.60 1.52 MWD IFR SCHLUMBERGER Survey Report 2-Feb-2004 19:47:10 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 IFR 32 2827.79 60.36 21.64 94.56 2130.40 1000.84 1380.49 553.90 1487.46 21. 86 2.94 MWD IFR 33 2922.12 59.90 21. 49 94.33 2177.38 1056.20 1456.56 583.96 1569.26 21.85 0.51 MWD IFR 34 3016.60 59.79 21.10 94.48 2224.84 1111. 76 1532.68 613 .63 1650.95 21. 82 0.38 MWD IFR 35 3109.90 60.32 21.69 93.30 2271. 41 1166.64 1607.95 643.12 1731. 79 21.80 0.79 MWD IFR 36 3202.72 60.98 20.88 92.82 2316.91 1221.68 1683.33 672.49 1812.69 21.78 1. 04 MWD IFR .- 37 3296.64 60.87 21.35 93.92 2362.55 1277.70 1759.91 702.06 1894.77 21.75 0.45 MWD IFR 38 3389.27 60.94 21. 25 92.63 2407.59 1332.74 1835.32 731.46 1975.71 21.73 0.12 MWD IFR 39 3483.60 60.19 22.40 94.33 2453.95 1388.06 1911.58 762.00 2057.86 21.73 1. 33 MWD IFR 40 3578.88 59.55 23.93 95.28 2501.78 1442.11 1987.34 794.41 2140.24 21.79 1.54 MWD IFR 41 3675.27 58.85 24.27 96 .39 2551.14 1495.38 2062.92 828.22 2222.97 21.87 0.79 MWD IFR 42 3768.47 58.76 23.95 93.20 2599.41 1546.67 2135.69 860.79 2302.64 21.95 0.31 MWD IFR 43 3822.64 58.68 24.44 54.17 2627.54 1576.40 2177.92 879.76 2348.90 22.00 0.79 MWD IFR 44 3968.57 56.45 24.32 145.93 2705.80 1655.19 2290.09 930.60 2471.95 22.11 1. 53 MWD IFR 45 4061. 82 57.86 25.00 93.25 2756.37 1705.00 2361.29 963.29 2550.22 22.19 1. 63 MWD IFR 46 4156.78 57.90 25.01 94.96 2806.86 1755.77 2434.18 997.29 2630.55 22.28 0.04 MWD IFR 47 4251.19 58.19 23.32 94.41 2856.83 1807.25 2507.26 1030.07 2710.61 22.33 1. 55 MWD IFR 48 4346.29 59.22 23.64 95.10 2906.23 1860.20 2581.79 1062.45 2791.85 22.37 1.12 MWD IFR 49 4441.75 58.59 23.64 95.46 2955.53 1913.30 2656.67 1095.23 2873.58 22.40 0.66 MWD IFR 50 4534.67 59.74 24.66 92.92 3003.16 1964.58 2729.47 1127.87 2953.32 22.45 1.56 MWD IFR 51 4627.48 60.80 24.14 92.81 3049.19 2016.12 2802.87 1161.17 3033.87 22.50 1.24 MWD IFR - 52 4722.40 60.28 24.94 94.92 3095.87 2068.81 2878.05 1195.49 3116.46 22.56 0.92 MWD IFR 53 4816.87 60.38 23.69 94.47 3142.63 2121.39 2952.85 1229.29 3198.51 22.60 1.15 MWD IFR 54 4912.55 59.31 22.34 95.68 3190.70 2175.81 3028.99 1261. 64 3281.23 22.61 1. 65 MWD IFR 55 5008.50 57.77 18.47 95.95 3240.79 2232.36 3105.67 1290.18 3362.99 22.56 3.80 MWD IFR 56 5104.61 58.34 13.86 96.11 3291.66 2292.94 3183.96 1312.87 3444.02 22.41 4.11 MWD IFR 57 5199.90 57.64 9.39 95.29 3342.19 2357.03 3263.07 1329.16 3523.40 22.16 4.04 MWD IFR 58 5293.31 58.75 4.11 93.41 3391.44 2423.88 3341.87 1338.46 3599.94 21.83 4.95 MWD IFR 59 5382.64 57.50 359.13 89.33 3438.63 2491.14 3417.66 1340.63 3671.19 21. 42 4.94 MWD IFR 60 5473.11 55.55 354.17 90.47 3488.55 2560.81 3492.95 1336.26 3739.82 20.93 5.05 MWD IFR SCHLUMBERGER Survey Report 2-Feb-2004 19:47:10 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 IFR 62 5662.13 56.12 342.91 95.79 3594.76 2712.18 3645.82 1304.62 3872.21 19.69 4.56 MWD IFR 63 5755.61 57.00 338.21 93.48 3646.30 2789.66 3719.34 1278.65 3932.99 18.97 4.30 MWD IFR 64 5849.72 58.43 334.27 94.11 3696.58 2869.14 3792.12 1246.59 3991.76 18.20 3.85 MWD IFR 65 5944.69 59.72 330.25 94.97 3745.40 2950.54 3864.19 1208.66 4048.81 17.37 3.88 MWD IFR 66 6038.46 59.78 326.28 93.77 3792.65 3031.09 3933.06 1166.07 4102.28 16.51 3.66 MWD IFR 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 IFR 68 6228.13 60.43 319.19 96.14 3887.87 3191.98 4064.16 1067.65 4202.05 14.72 4.00 MWD IFR 69 6322.08 61. 20 315.37 93.95 3933.69 3270.45 4124.40 1012.01 4246.74 13.79 3.64 MWD IFR 70 6413 .76 62.81 311.82 91. 68 3976.74 3346.22 4180.19 953.38 4287.53 12.85 3.84 MWD IFR 71 6508.94 66.45 309.17 95.18 4017.52 3424.96 4236.00 887.98 4328.07 11.84 4.58 MWD IFR 72 6602.27 69.53 308.73 93.33 4052.49 3503.24 4290.38 820.70 4368.17 10.83 3.33 MWD IFR 73 6696.22 68.09 309.19 93.95 4086.45 3582.51 4345.46 752.58 4410.15 9.83 1. 60 MWD IFR 74 6788.62 68.74 308.14 92.40 4120.44 3660.06 4399.14 685.49 4452.23 8.86 1.27 MWD IFR 75 6882.92 68.49 308.62 94.30 4154.83 3739.14 4453.65 616.66 4496.14 7.88 0.54 MWD IFR 76 6977.12 69.35 308.67 94.20 4188.71 3818.47 4508.54 548.01 4541.73 6.93 0.91 MWD IFR 77 7071.71 70.05 309.02 94.59 4221.52 3898.67 4564.19 478.92 4589.25 5.99 0.82 MWD IFR 78 7165.20 67.88 310.68 93.49 4255.08 3978.19 4620.09 411. 93 4638.42 5.10 2.85 MWD IFR 79 7259.49 65.27 310.23 94.29 4292.56 4057.41 4676.23 346.10 4689.02 4.23 2.80 MWD IFR 80 7353.09 64.32 308.94 93.60 4332.42 4134.43 4730.19 280.84 4738.52 3.40 1. 61 MWD IFR 81 7447.35 64.54 307.41 94.26 4373.11 4210.86 4782.74 214.00 4787.53 2.56 1. 48 MWD IFR e 82 7539.92 68.32 305.92 92.57 4410.12 4286.11 4833.38 145.95 4835.59 1. 73 4.34 MWD IFR 83 7634.03 73.67 304.90 94.11 4440.76 4364.09 4884.91 73.44 4885.46 0.86 5.78 MWD IFR 84 7729.26 79.19 303.22 95.23 4463.09 4444.15 4936.72 -3.22 4936.72 359.96 6.04 MWD IFR 85 7803.19 81.68 305.16 73.93 4475.38 4507.30 4977.69 -63.52 4978.09 359.27 4.25 MWD IFR 86 7900.98 83.22 303.26 97.79 4488.23 4591.30 5032.18 -143.68 5034.23 358.36 2.49 MWD IFR 87 7931. 42 85.02 303.33 30.44 4491.35 4617.29 5048.80 -168.99 5051.63 358.08 5.92 MWD IFR 88 7962.34 86.32 302.33 30.92 4493.68 4643.63 5065.52 -194.90 5069.27 357.80 5.30 MWD IFR 89 7993.86 88.55 301.07 31.52 4495.09 4670.20 5082.06 -221.68 5086.90 357.50 8.12 MWD IFR 90 8024.42 90.27 298.93 30.56 4495.41 4695.49 5097.34 -248.15 5103.38 357.21 8.98 MWD IFR SCHLUMBERGER Survey Report 2-Feb-2004 19:47:10 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 Corr (ft) (de g) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8056.01 91. 50 299.88 31.59 4494.92 4721.44 5112.85 -275.66 5120.27 356.91 4.92 MWD IFR 92 8086.73 91.02 299.23 30.72 4494.24 4746.72 5128.00 -302.38 5136.91 356.63 2.63 MWD IFR 93 8118.07 91.40 299.13 31.34 4493.58 4772.40 5143.27 -329.74 5153.83 356.33 1.25 MWD IFR 94 8149.11 92.05 300.56 31. 04 4492.65 4798.03 5158.71 -356.65 5171. 03 356.05 5.06 MWD IFR 95 8180.15 91.30 300.49 31.04 4491. 74 4823.86 5174.47 -383.37 5188.66 355.76 2.43 MWD IFR 96 8210.98 90.54 300.95 30.83 4491. 24 4849.59 5190.22 -409.87 5206.38 355.48 2.88 MWD IFR e 97 8242.51 90.27 301.08 31.53 4491. 02 4875.99 5206.47 -436.89 5224.76 355.20 0.95 MWD IFR 98 8272.55 90.06 302.39 30.04 4490.94 4901.35 5222.27 -462.44 5242.70 354.94 4.42 MWD IFR 99 8303.76 89.82 303.84 31. 21 4490.97 4928.09 5239.32 -488.58 5262.05 354.67 4.71 MWD IFR 100 8334.72 90.99 306.85 30.96 4490.75 4955.22 5257.22 -513.83 5282.27 354.42 10.43 MWD IFR 101 8366.12 90.82 310.30 31. 40 4490.25 4983.53 5276.80 -538.37 5304.19 354.17 11.00 MWD IFR 102 8397.94 89.99 311.74 31.82 4490.03 5012.79 5297.68 -562.38 5327.45 353.94 5.22 MWD IFR 103 8430.29 88.69 311.98 32.35 4490.40 5042.72 5319.27 -586.47 5351.50 353.71 4.09 MWD IFR 104 8459.96 89.20 311.10 29.67 4490.95 5070.11 5338.94 -608.67 5373.52 353.50 3.43 MWD IFR 105 8491. 26 88.72 310.72 31.30 4491.52 5098.86 5359.43 -632.32 5396.60 353.27 1. 96 MWD IFR 106 8522.91 88.90 311.07 31.65 4492.17 5127.94 5380.15 -656.24 5420.02 353.05 1.24 MWD IFR 107 8553.96 88.96 310.31 31.05 4492.75 5156.41 5400.39 -679.78 5443.00 352.83 2.45 MWD IFR 108 8585.17 90.95 312.49 31.21 4492.78 5185.19 5421.03 -703.19 5466.44 352.61 9.46 MWD IFR 109 8617.09 91.71 313.66 31.92 4492.04 5214.97 5442.82 -726.50 5491. 09 352.40 4.37 MWD IFR 110 8647.04 91.78 313.13 29.95 4491.12 5242.96 5463.39 -748.25 5514.39 352.20 1. 78 MWD IFR 111 8678.41 91.19 312.80 31.37 4490.31 5272.20 5484.76 -771.20 5538.71 352.00 2.15 MWD IFR e 112 8710.23 90.78 312.32 31.82 4489.76 5301.79 5506.28 -794.64 5563.32 351.79 1. 98 MWD IFR 113 8740.61 90.92 312.40 30.38 4489.31 5329.99 5526.74 -817.08 5586.82 351.59 0.53 MWD IFR 114 8772.08 91.16 312.24 31.47 4488.74 5359.20 5547.93 -840.35 5611.21 351.39 0.92 MWD IFR 115 8803.52 90.47 310.35 31. 44 4488.29 5388.17 5568.67 -863.96 5635.30 351.18 6.40 MWD IFR 116 8834.68 89.99 308.31 31.16 4488.17 5416.45 5588.42 -888.07 5658.54 350.97 6.73 MWD IFR 117 8866.05 89.82 308.80 31.37 4488.22 5444.74 5607.97 -912.60 5681.74 350.76 1. 65 MWD IFR 118 8897.31 90.40 307.61 31. 26 4488.16 5472.85 5627.31 -937.16 5704.81 350.54 4.23 MWD IFR 119 8927.58 90.16 307.87 30.27 4488.01 5499.96 5645.83 -961.10 5727.05 350.34 1.17 MWD IFR 120 8959.06 90.54 306.45 31. 48 4487.82 5528.01 5664.85 -986.18 5750.05 350.12 4.67 MWD IFR SCHLUMBERGER Survey Report 2-Feb-2004 19:47:10 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 8990.33 91. 30 306.81 31. 27 4487.32 5555.74 5683.50 -1011.28 5772.77 349.91 2.69 MWD IFR 122 9021.17 90.30 304.99 30.84 4486.89 5582.90 5701.58 -1036.25 5794.99 349.70 6.73 MWD IFR 123 9051.91 90.99 303.50 30.74 4486.54 5609.54 5718.88 -1061.66 5816.59 349.48 5.34 MWD IFR 124 9083.26 91.60 302.08 31. 35 4485.83 5636.30 5735.85 -1088.01 5838.13 349.26 4.93 MWD IFR 125 9114.50 93.08 301.84 31. 24 4484.56 5662.72 5752.38 -1114.49 5859.34 349.04 4.80 MWD IFR 126 9145.08 94.49 301.38 30.58 4482.54 5688.44 5768.37 -1140.48 5880.03 348.82 4.85 MWD IFR e 127 9176.30 94.83 302.14 31. 22 4480.00 5714.72 5784.75 -1166.93 5901. 27 348.60 2.66 MWD IFR 128 9206.86 95.11 302.13 30.56 4477.36 5740.53 5800.94 -1192.71 5922.29 348.38 0.92 MWD IFR 129 9238.25 94.56 302.45 31. 39 4474.71 5767.10 5817.65 -1219.16 5944.02 348.16 2.03 MWD IFR 130 9269.79 93.97 303.60 31. 54 4472.36 5794.02 5834.79 -1245.53 5966.25 347.95 4.09 MWD IFR 131 9300.03 93.36 303.35 30.24 4470.43 5819.98 5851. 44 -1270.70 5987.82 347.75 2.18 MWD IFR 132 9330.99 93.18 305.18 30.96 4468.67 5846.78 5868.84 -1296.24 6010.28 347.55 5.93 MWD IFR 133 9362.66 92.77 305.24 31. 67 4467.02 5874.45 5887.07 -1322.08 6033.70 347.34 1.31 MWD IFR 134 9394.07 92.15 305.62 31. 41 4465.67 5901. 97 5905.27 -1347.65 6057.09 347.14 2.31 MWD IFR 135 9424.41 91.91 306.17 30.34 4464.60 5928.68 5923.04 -1372.22 6079.92 346.96 1. 98 MWD IFR 136 9456.34 92.84 305.96 31.93 4463.28 5956.83 5941. 82 -1398.00 6104.07 346.76 2.99 MWD IFR 137 9488.12 95.21 304.36 31.78 4461.05 5984.56 5960.08 -1423.92 6127.81 346.56 8.99 MWD IFR 138 9519.32 95.18 304.81 31. 20 4458.22 6011.58 5977.72 -1449.50 6150.95 346.37 1.44 MWD IFR 139 9549.92 94.11 305.05 30.60 4455.74 6038.20 5995.18 -1474.50 6173.84 346.18 3.58 MWD IFR 140 9580.74 93.49 304.83 30.82 4453.70 6065.04 6012.79 -1499.71 6197.00 346.00 2.13 MWD IFR 141 9611.64 93.04 303.35 30.90 4451.94 6091.74 6030.08 -1525.26 6219.99 345.81 5.00 MWD IFR e 142 9643.64 92.84 303.86 32.00 4450.30 6119.26 6047.77 -1551.88 6243.70 345.61 1. 71 MWD IFR 143 9674.28 92.63 303.51 30.64 4448.84 6145.64 6064.74 -1577.34 6266.51 345.42 1. 33 MWD IFR 144 9705.51 92.70 302.99 31. 23 4447.38 6172.41 6081.85 -1603.43 6289.66 345.23 1. 68 MWD IFR 145 9736.95 92.22 303.95 31. 44 4446.04 6199.43 6099.17 -1629.63 6313 .13 345.04 3.41 MWD IFR 146 9768.87 91. 26 304.88 31.92 4445.07 6227.13 6117.20 -1655.95 6337.38 344.85 4.19 MWD IFR 147 9799.72 90.61 306.87 30.85 4444.56 6254.29 6135.28 -1680.95 6361.38 344.68 6.79 MWD IFR 148 9830.67 89.72 307.24 30.95 4444.47 6281.85 6153.93 -1705.65 6385.93 344.51 3.11 MWD IFR 149 9860.94 90.85 309.09 30.27 4444.32 6309.05 6172.63 -1729.44 6410.33 344.35 7.16 MWD IFR 150 9891.96 91.91 312.33 31.02 4443.58 6337.50 6192.85 -1752.95 6436.17 344.20 10.99 MWD IFR SCHLUMBERGER Survey Report 2-Feb-2004 19:47:10 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 9924.78 89.68 312.94 32.82 4443.12 6368.03 6215.08 -1777.09 6464.15 344.04 7.04 MWD IFR 152 9954.80 87.18 312.73 30.02 4443.94 6395.98 6235.48 -1799.09 6489.83 343.91 8.36 MWD IFR 153 9986.84 86.87 314.41 32.04 4445.61 6425.94 6257.53 -1822.27 6517.47 343.76 5.32 MWD IFR 154 10018.16 88.04 317.33 31. 32 4447.00 6455.64 6279.99 -1844.06 6545.14 343.64 10.03 MWD IFR 155 10048.54 88.04 318.47 30.38 4448.04 6484.79 6302.52 -1864.41 6572.50 343.52 3.75 MWD IFR 156 10079.98 87.49 318.50 31. 44 4449.26 6515.04 6326.04 -1885.24 6600.98 343.41 1. 75 MWD IFR e 157 10111.23 87.56 319.92 31. 25 4450.61 6545.21 6349.68 -1905.63 6629.47 343.29 4.55 MWD IFR 158 10142.45 89.20 323.34 31. 22 4451. 49 6575.67 6374.14 -1925.00 6658.48 343.20 12.14 MWD IFR 159 10173.29 89.34 324.22 30.84 4451.89 6606.00 6399.02 -1943.22 6687.57 343.11 2.89 MWD IFR 160 10204.90 89.34 323.97 31.61 4452.25 6637.12 6424.62 -1961.76 6717.46 343.02 0.79 MWD IFR 161 10235.49 89.14 324.28 30.59 4452.66 6667.24 6449.41 -1979.68 6746.40 342.94 1.21 MWD IFR 162 10266.22 88.76 324.10 30.73 4453.22 6697.50 6474.32 -1997.66 6775.51 342.85 1. 37 MWD IFR 163 10298.03 88.24 325.05 31.81 4454.05 6728.86 6500.23 -2016.09 6805.71 342.77 3.40 MWD IFR 164 10328.08 87.73 324.22 30.05 4455.11 6758.48 6524.72 -2033.47 6834.25 342.69 3.24 MWD IFR 165 10359.45 87.45 325.04 31.37 4456.43 6789.39 6550.28 -2051.61 6864.06 342.61 2.76 MWD IFR 166 10386.59 87.32 325.66 27.14 4457.67 6816.18 6572.58 -2067.03 6889.95 342.54 2.33 MWD IFR 167 10418.26 87.04 326.25 31.67 4459.23 6847.49 6598.79 -2084.74 6920.27 342.47 2.06 MWD IFR 168 10449.19 87.42 325.70 30.93 4460.72 6878.07 6624.40 -2102.02 6949.90 342.40 2.16 MWD IFR 169 10480.30 88.01 324.46 31.11 4461. 96 6908.76 6649.89 -2119.82 6979.58 342.32 4.41 MWD IFR 170 10511.10 89.00 323.17 30.80 4462.76 6939.05 6674.73 -2138.00 7008.79 342.24 5.28 MWD IFR 171 10543.35 89.89 321.09 32.25 4463.08 6970.59 6700.19 -2157.79 7039.08 342.15 7.01 MWD IFR e 172 10574.49 90.23 319.01 31. 14 4463.04 7000.79 6724.06 -2177.79 7067.94 342.05 6.77 MWD IFR 173 10605.40 90.78 316.50 30.91 4462.77 7030.44 6746.94 -2198.56 7096 .12 341.95 8.31 MWD IFR 174 10637.15 91.50 315.56 31.75 4462.14 7060.61 6769.79 -2220.60 7124.68 341.84 3.73 MWD IFR 175 10670.03 91. 57 311.88 32.88 4461.26 7091.41 6792.50 -2244.35 7153.68 341.72 11.19 MWD IFR 176 10699.75 92.02 308.82 29.72 4460.33 7118.58 6811.73 -2266.99 7179.06 341. 59 10.40 MWD IFR 177 10731.35 91.88 306.99 31.60 4459.25 7146.91 6831.13 -2291.91 7205.36 341. 45 5.80 MWD IFR 178 10762.99 93.01 308.49 31.64 4457.90 7175.22 6850.48 -2316.90 7231.67 341.31 5.93 MWD IFR 179 10793.31 93.42 308.66 30.32 4456.20 7202.52 6869.35 -2340.57 7257.15 341.18 1.46 MWD IFR 180 10825.47 93.73 309.72 32.16 4454.20 7231.62 6889.64 -2365.45 7284.40 341.05 3.43 MWD IFR SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- ------ ------- ------ Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) 2-Feb-2004 19:47:10 -------- -------- -------- -------- TVD depth (ft) Vertical section (ft) ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Page 8 of 10 --------------- --------------- 7310.76 7337.72 7364.16 7391.40 7417.56 7444.48 7470.26 7497.14 7522.74 7547.44 7577.29 7599.63 7618.74 7651.68 7678.12 7706.50 7732.28 7758.76 7785.09 7811.13 7838.34 7860.17 7886.36 7913 .13 7938.49 7966.56 7995.83 8022.60 8049.01 8076.30 At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 93.29 92.87 92.67 93.22 94.52 94.39 94.18 92.53 92.81 93.66 94.28 94.73 95.21 95.73 95.56 93.46 94.04 94.11 93.46 93.18 93.15 94.32 95.93 95.83 94.97 95.25 91. 98 88.21 87.25 86.70 308.97 309.36 309.05 309.78 312.03 312.08 311.65 309.04 307.40 306.56 304.98 305.23 303.45 304.80 305.49 307.10 306.31 306.91 307.09 306.83 307.30 306.62 306.33 306.09 305.79 305.77 307.32 306.93 307.71 308.37 31.03 31. 73 31.05 31.89 30.15 30.67 29.39 31.03 30.16 29.47 36.09 27.20 23.48 40.52 32.08 33.88 30.55 31. 38 31.02 30.65 31.93 25.63 30.94 31.72 30.06 33.28 34.31 31. 09 30.59 31.37 4452.30 4450.59 4449.09 4447.45 4445.42 4443.04 4440.84 4439.02 4437.62 4435.95 4433.46 4431.32 4429.29 4425.42 4422.27 4419.60 4417.60 4415.37 4413.33 4411.55 4409.79 4408.12 4405.36 4402.11 4399.28 4396.31 4394.15 4394.10 4395.31 4396.96 7259.74 7288.46 7316.58 7345.50 7373.14 7401.47 7428.59 7456.93 7484.02 7510.20 7541.87 7565.58 7585.87 7620.80 7648.72 7678.57 7705.63 7733.38 7760.92 7788.14 7816.53 7839.27 7866.56 7894.44 7920.81 7949.98 7980.32 8008.01 8035.28 8063.41 6909.27 -2389.40 6929.28 -2413.96 6948.89 -2438.00 6969.11 -2462.60 6988.80 -2485.33 7009.28 -2508.04 7028.84 -2529.86 7048.90 -2553.47 7067.53 -2577.14 7085.23 -2600.64 7106.28 -2629.85 7121.87 -2652.04 7135.06 -2671.35 7157.69 -2704.74 7176.07 -2730.84 7196.06 -2758.06 7214.28 -2782.50 7232.95 -2807.63 7251.58 -2832.35 7269.97 -2856.80 7289.19 -2882.24 7304.57 -2902.67 7322.88 -2927.45 7341.52 -2952.91 7359.09 -2977.14 7378.47 -3004.03 7398.86 -3031.54 7417.62 -3056.32 7436.15 -3080.63 7455.45 -3105.30 Total displ (ft) 340.92 340.79 340.67 340.54 340.42 340.31 340.20 340.09 339.97 339.84 339.69 339.58 339.47 339.30 339.17 339.03 338.91 338.79 338.67 338.55 338.43 338.33 338.21 338.09 337.97 337.85 337.72 337.61 337.50 337.39 DLS (deg/ 100f) 2.80 1. 81 1.19 2.86 8.60 0.45 1. 62 9.94 5.51 4.05 4.69 1. 89 7.82 3.56 2.21 7.80 3.20 1. 92 2.17 1.25 1.47 5.28 5.29 0.82 3.03 0.84 10.54 12.19 4.04 2.74 ------ ------ Srvy Tool tool Corr type (deg) MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR e 181 182 183 184 185 10856.50 10888.23 10919.28 10951.17 10981.32 186 187 188 189 190 11011.99 11041.38 11072.41 11102.57 11132.04 191 192 193 194 195 11168.13 11195.33 11218.81 11259.33 11291.41 196 197 198 199 200 11325.29 11355.84 11387.22 11418.24 11448.89 201 202 203 204 205 11480.82 11506.45 11537.39 11569.11 11599.17 206 207 208 209 210 11632.45 11666.76 11697.85 11728.44 11759.81 IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR - IFR IFR IFR IFR IFR SCHLUMBERGER Survey Report 2-Feb-2004 19:47:10 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 11791. 59 86.60 309.25 31.78 4398.82 8092.08 7475.33 -3130.02 8104.18 337.28 2.78 MWD IFR 212 11822.04 88.00 308.96 30.45 4400.26 8119.64 7494.52 -3153.62 8131.00 337.18 4.70 MWD IFR 213 11852.88 88.96 309.65 30.84 4401.07 8147.61 7514.05 -3177.48 8158.26 337.08 3.83 MWD IFR 214 11883.12 88.76 309.07 30.24 4401.68 8175.06 7533.22 -3200.85 8185.04 336.98 2.03 MWD IFR 215 11913.99 88.59 309.41 30.87 4402.39 8203.05 7552.74 -3224.76 8212.37 336.88 1. 23 MWD IFR 216 11945.40 88.62 309.53 31. 41 4403.15 8231.59 7572.71 -3249.00 8240.26 336.78 0.39 MWD IFR - 217 11975.84 88.76 310.28 30.44 4403.85 8259.33 7592.23 -3272.34 8267.41 336.68 2.51 MWD IFR 218 12006.67 88.24 308.74 30.83 4404.66 8287.35 7611.83 -3296 .12 8294.84 336.59 5.27 MWD IFR 219 12037.84 89.20 309.56 31.17 4405.35 8315.59 7631.51 -3320.28 8322.51 336.49 4.05 MWD IFR 220 12068.66 89.75 308.57 30.82 4405.64 8343.50 7650.93 -3344.21 8349.88 336.39 3.67 MWD IFR 221 12099.05 91.37 307.54 30.39 4405.34 8370.79 7669.66 -3368.14 8376.64 336.29 6.32 MWD IFR 222 12130.72 91.50 305.31 31. 67 4404.55 8398.81 7688.46 -3393.61 8404.11 336.18 7.05 MWD IFR 223 12162.76 91. 40 302.71 32.04 4403.73 8426.51 7706.37 -3420.16 8431. 23 336.07 8.12 MWD IFR 224 12193.59 92.22 300.96 30.83 4402.76 8452.55 7722.63 -3446.34 8456.72 335.95 6.27 MWD IFR 225 12225.54 93.25 300.39 31.95 4401. 24 8479.17 7738.91 -3473.79 8482.80 335.83 3.68 MWD IFR 226 12256.50 94.42 299.91 30.96 4399.17 8504.78 7754.42 -3500.50 8507.91 335.70 4.08 MWD IFR 227 12287.13 96 .18 299.36 30.63 4396.34 8529.91 7769.50 -3527.01 8532.58 335.58 6.02 MWD IFR 228 12319.06 95.45 301.63 31.93 4393.10 8556.35 7785.62 -3554.38 8558.59 335.46 7.43 MWD IFR 229 12349.68 93.59 302.85 30.62 4390.69 8582.26 7801.90 -3580.19 8584.14 335.35 7.26 MWD IFR 230 12380.59 93.56 304.45 30.91 4388.76 8608.84 7819.00 -3605.87 8610.40 335.24 5.17 MWD IFR 231 12411. 82 93.67 306.04 31. 23 4386.79 8636.12 7836.98 -3631.33 8637.41 335.14 5.09 MWD IFR - 232 12440.80 93.97 307.83 28.98 4384.86 8661.84 7854.36 -3654.44 8662.90 335.05 6.25 MWD IFR 233 12472.88 93.97 309.21 32.08 4382.64 8690.69 7874.29 -3679.48 8691.55 334.95 4.29 MWD IFR 234 12504.22 94.39 311. 45 31.34 4380.35 8719.28 7894.52 -3703.30 8719.97 334.87 7.25 MWD IFR 235 12534.62 94.28 312.60 30.40 4378.06 8747.36 7914.81 -3725.82 8747.91 334.79 3.79 MWD IFR 236 12565.23 93.49 311. 78 30.61 4375.98 8775.69 7935.32 -3748.45 8776.11 334.72 3.72 MWD IFR 237 12596.67 92.87 312.21 31. 44 4374.24 8804.76 7956.32 -3771.78 8805.08 334.64 2.40 MWD IFR 238 12630.44 92.67 313 .18 33.77 4372.61 8836.15 7979.20 -3796.57 8836.37 334.55 2.93 MWD IFR 239 12660.85 92.15 312.66 30.41 4371.33 8864.47 7999.88 -3818.82 8864.62 334.48 2.42 MWD IFR 240 12693.09 92.94 313 . 54 32.24 4369.90 8894.53 8021.89 -3842.33 8894.62 334.41 3.67 MWD IFR · ~ . SCHLUMBERGER Survey Report 2-Feb-2004 19:47:10 Page 10 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 Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 241 12723.63 93.42 314.33 30.54 4368.20 8923.15 8043.05 -3864.29 8923.19 334.34 3.02 MWD IFR 242 12755.09 91. 50 313.13 31. 46 4366.85 8952.60 8064.77 -3887.00 8952.62 334.27 7.19 MWD IFR 243 12786.38 92.91 312.57 31. 29 4365.65 8981.73 8086.04 -3909.93 8981.73 334.19 4.85 MWD IFR 244 12815.01 92.15 309.89 28.63 4364.38 9008.07 8104.89 -3931.43 9008.07 334.12 9.72 MWD IFR 245 12848.97 93.36 310.37 33.96 4362.75 9039.05 8126.75 -3957.37 9039.07 334.04 3.83 MWD IFR 246 12881.51 93.49 310.96 32.54 4360.81 9068.85 8147.92 -3982.01 9068.90 333.95 1. 85 MWD IFR e· 247 12912.00 93.77 310.64 30.49 4358.88 9096.78 8167.80 -4005.04 9096.88 333.88 1.39 MWD IFR 248 12941. 85 92.74 311.72 29.85 4357.18 9124.22 8187.42 -4027.47 9124.38 333.81 5.00 MWD IFR 249 12973.58 92.12 311.62 31.73 4355.84 9153.51 8208.50 -4051.15 9153.76 333.73 1. 98 MWD IFR 250 13004.01 90.54 311.71 30.43 4355.13 9181. 62 8228.72 -4073.88 9181. 96 333.66 5.20 MWD IFR 251 13025.53 89.03 311.88 21. 52 4355.21 9201.52 8243.06 -4089.92 9201.93 333.61 7.06 MWD IFR 252 13067.00 89.03 311.88 41.47 4355.91 9239.89 8270.74 -4120.79 9240.46 333.52 0.00 Projected to TD [(c)2004 IDEAL ID8 1C_02] e - e eOL/-COl Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-200 Date Dispatched: 18-Jan-04 I nstallation/Rig Nabors 9ES Dispatched By: F. Alabi Data No Of Prints No of Floppies Surveys 2 RECEVED Hi\¡~ 2 3 2004 "~ . . --, Received By: U:: \ \..:\.. -/~ \"'\ \. c.. {~~.. c 'v-...... 1; j1~~{~aQ¡!& Ga$Cor S. Commisakm fJímage Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska .99503 nrose1@slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, 10-02-03 Schlumberger Private ~~.~.<\\\ \'~ . J . / FRANK H. MURKOWSKI, GOVERNOR / / ! / í 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 A.I,ASIiA ORAND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L-200 BP Exploration (Alaska), Inc. Permit No: 204-001 Surface Location: 2567' NSL, 3705' WEL, Sec. 34, T12N, RIlE, UM Bottomhole Location: 313' NSL, 2477' 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. 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). Sincerely, BY ORDER OF THE COMMISSION DATED thisf day of January, 2004. cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. B Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2567' NSL, 3705' WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2632' NSL, 4199' WEL, SEC. 27, T12N, R11E, UM Total Depth: 313' NSL, 2477'WEL, SEC. 21, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-583209 y-5978290 Zone;A.SP4 16. Deviated Wells: Kickoff Depth 1$,iCasing ProgrålTl Size Casing 20" x 34" 10-3/4" 7-5/8" 4-1/2" i;.L G Å; 'I <; / z...oo,/ ALASKA It AND ~~T~g~S~L~:iìON COaSSION RECEIVED PERMIT TO DRILL DEC 3 I 2003 20 MC 25.005 / Alaska Oil 8J Ga~ r.nn~ Commission 11b. Current Well Class 0 Exploratory B Development O~ncO M\!l.t!ple Zone o Stratigraphic Test 0 Service 0 Development GitS' I!!r~ygle Zone 5. Bond: IHI Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU L-200 ~ 6. Proposed Depth: 12. Field I Pool(s): MD 13058 TVD 4423 Prudhoe Bay Field I Polaris Pool 7. Property Designation: ADL 047447 8. Land Use Permit: 13. Approximate Spud Date: January 15, 2004 ./ 14. Distance to Nearest Property: 4550' 9. Acres in Property: 2560 Weight 215.5# 45.5# 29.7# 12.6# Length 80' 3623' 7844' 5588' 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool (Height above GL): = 72.6 feet L-117 is 1420' away 17. Anticipated pressure (see 20 AAC 25.035) ,/ Max. Downhole Pressure: 1970 psig. Max. Surface Pressure: 1530 psig ·.!ii!Settil'lgDèþth Ch.låotitY'ofOØmØot·· Top Bottom (c.f. or sacks) MD TVD MD TVD (including stage data) 29' 29' 109' 109' ,260 sx Arctic Set (Approx.) 29' 29' 3652' 2573' 692 sx AS Lite, 361 sx Class 'G' 29' 29' 7873' 4475' 530 sx Class 'G' 7462' 4352' 13050' 4413' Uncemented Slotted Liner ,/ Hole 48" 13-1/2" 9-718" 6-3/4" 300 ft Maximum Hole Angle SpecificatiOns Grade Coupling A53 Welded L-80 BTC L-80 BTC-M L-80 IBT 93° 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Depth MD (ft): I Effective Depth TVD Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments IHI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): IHI Drilling Program 0 Time vs Depth Plot o Seabed Report IHI Drilling Fluid Program o Shallow Hazard Analysis 1H120 AAC 25.050 Requirements Date: Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name.... L0711 Crane Title Senior Drilling Engineer Signature ~;?:~~Æ-1 Ú___ Phone 564-~'1 Date IZ-31-~:; l/ Commission Use Only Permit To Drill. I API Number: I Permit Approva ·/'1 Number: 2ð '7 - Dol 50- <:::>:2-9 - Z 3/ /' / Date: \ 1<; (¡t Conditions of Approval: Samples Required DYes E No Mud Log Required Hydrogen Sulfide Measures D Yes ~ No Directional Survey Required Other: -Te~t toPE-Io ·~~OO rc¡,{. Contact Michael Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble. 564-4628 I See cover letter for other requirements DYes ~No ~Yes D No Approved By: Form 10-401 Revised 3/2003 Original Signed By Sarah Palin COMMISSIONER ORIGINAL BY ORDER OF THE COMMISSION Date \/ (,) rCi L/ Submit In Duplicate Well Plan Summary . Greater Prudhoe Bay L-200 ML Permit e IWell Name: I L-200, L-200 L 1 and/,[-200 L2"'1 Surface Location: 2,567' FSL, 3,705' FEL, Sec. 34, T12N, R11E X 583,209.30 Y 5,978,289.70 L-200 OBd Target Start: 2,632' FSL, 4,199' FEL, Sec. 27, T12N, R11 E 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, R11 E 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, R11 E 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, R11 E 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, R11 E X = 579,083 Y = 5,986,571 Z = 4,150' TVDss I Type of Well (producer or injector): I Schrader OBd, OBa and OA Multilateral Producer / ",/ ,/ I AFE Number: I ORD5M3540 KBE = 72.60' I Rig: I Nabors 9ES / I Estimated Start Date: I Jan. 15m 2004 I I Operating days to complete: 134.04 OBd MD 13,058' Well TVDrkb: TD 4,423' Max Inc. 93° KOP 300' OBa MD 13,025' Well TVDrkb: TD 4,284' Max Inc. 98° KOP 7,396' OAMD 13,011 ' Well TVDrkb: TD 4,223' Max Inc. 9]0 KOP 7,215' Target Estimates: Estimated Reserves OA I OBa I OBd: Expected Initial Rate OA I OBa I OBd: Expected 1 Year avg OA I OBa IOBd: Current Well Information Distance to Nearest Property: Distance to Nearest Well in Pool: Original Well API #: L-200 L 1 API OBa #: L-200 L2 API OA #: Well Type: Current Status: H2S: BHP: BHT: Expected reserves 7.56 mmbbl Production rate: 3,900 bId Production rate: 1,800 bId 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 TD: 3,010' away from NWEILEEN-1 (old exploration well- to be abandoned in February, 2004) 50-029- XXXXX -00 50-029- XXX XX -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 q. 'j.. 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 . Conductor: Cellar Box Height: Nabor 9ES: Greater Prudhoe Bay L-200 ML Permit e 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB Above MSL = 44.10' KB I MSL = 72.60' Materials Needed Surface Casing: Amount 4.010' 1 each 25 each 1 assembly 1 lot 1 each Intermediate Casing: 'AmöûHt 7,600' 1 each 75 each 20 each 2 lots 3 each 2 each Production Liner: Amount 3 x Production Liners: 7,300' 183 each 3 each 3 each 2 assemblies 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 Description 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-W' Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 10-3,4" casing pups 5',10',20'. 1 0-3,4" TAM Port Collar DescriptiQJ; 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- Ys" Rigid Straight Blade Centralizers 7-%" Stop Rings 7-%" casing pups 5',10',20' 7-%" RA Tag 7-%" 29.7# L-80 BTC-M Casing Short Joint Description 4 W, 12.6#, L-80, IBT-Mod Slotted Liner 4 W' x 5 3,4" x 8" Straight Blade Centralizers 7-%" x 4-W' Baker ZXP Liner Top Packer 4- W' Halliburton Float Shoes Baker Level 3 Hookwall Hangers with LEM " '" Description 4-%", 12.6 Ib/ft, L-80, BTC-M tubing Baker PRM Production Packer 7-%" X 4-%" 11" X 4-%" FMC tubing hanger 4-1/16", 5m Cameron Tree Halliburton XN-Nipple (3.725" ID) Halliburton X-Nipple (3.813" ID) 4-%" Baker CMD 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-W 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 Approach Well List: Well Name", ¿~Ctr~ttr Di~,ªnce L-103 91.46-ft L-115 97.92-ft L-117 86.60-ft L-118 55.24-ft . Referenc,ewlVlb '. 494.22-ft 543.33-ft 494.91-ft 743.33-ft ~~~ffl1fon..5', ',Precauff6harY0ÇOmm~t(\' 83.77-ft Use Traveling Cylinder (Gyro) 89.01-ft Use Traveling Cylinder (Gyro) 78.95-ft Use Traveling Cylinder (Gyro) 42.04-ft Use Traveling Cylinder (Gyro) 2 Final Permit 12/31/03 . Mud Program 13-%" Surface Hole Mud Properties: Interval! Density (ppg) Funnel vis 0- 1,700 8.6 - 9.2 250 - 300 1,700 - 2,500 9.0 - 9.5 T' 200 - 250 2,500 - 4,010 9.3 - 9.5 200 Interval Specific Objectives: 9-%" Intermediate Hole Mud Properties: Interval! Density.(ppg) Funnel vis 9.0 - 9.3 / 45 - 55 Interval Specific Objectives: . . . - . . 6-%" Production Hole Mud Properties: Interval! Densi~ (ppg) Stability 9.2 650 - 900 Interval Specific Objectives: Well Control Greater Prudhoe Bay L-200 ML Permit e I Spud - Freshwater Mud YP Tauo PH Plastic Vis 50 - 70 10 - 18 8.5 - 9.0 20 - 45 30 - 45 8 - 16 8.5 - 9.0 20 - 40 30 - 40 9 -14 8.5 - 9.0 14 - 20 Maintain Viscosity greater then 250 Ensure fluid loss below permafrost is below 6 Maintain mud temperature below 50° F ~ ",.;., ;w: ~ ~ ".... I Freshwater Mud (LSND) PH: 9.0 - 9.5 Tauo I PV I API Filtrate I MBT 3 - 6 12 - 18 4 - 6 < 20 TBD YP I 26 - 30 ..-"-.,,.--.-.-... . ..----- FL NC-8 8 5.5-8 ..---..... .. MBT <6 Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blindlshear 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. YP 18 - 25 - --TL\lt ~'20Ò"M0Ë3ïv'" (Vërsa-Pro j--_...... I Oil : H20 Ratio I PV I API Filtrate I 80 : 20 15 - 20 4 - 5.5 TBD 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 surface pressure: 1,530 psi @ surface ,/ (based on BHP and a full column of gas from TO @ 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 Diesel 5,000 psi Working Pressure (entire stack and valves 3,500/250 psi Rams & Valves 3,500/250 psi 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 DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 3 Final Permit 12/31/03 Formation Markers e Greater Prudhoe Bay L-200 ML Permit e 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 Hydr. SV1 2,465 3,582 1,120 8.7 Poss. Gas Hydr. UG4 2,755 4,161 1,255 8.8 Yes - Heavy 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 - Heavy Oil q,~ 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 q,t. 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 Hole Size Csgl WtlFt Gr~ Conn Length Top Bottom Tbg O.D. ./' MD I TVDrkb MD I TVDrkb 48" 20" X 34" 215.5# A53 Welded 80' 29' I 29' 109' 1109' 13- %" 10-3,4" 45.5# L-80 BTC 3,623' 29' / 29' 3,652' 12,573' 9-%" 7-%" 29.7# L-80 BTC-M 7,844' 29' I 29' 7,873' 14,475' 6-3,4" OSd 4- W' slotted 12.6# L-80 1ST 5,588' 7,462' /4,352 13,050' /4,413' 6-3,4" OSa 4- W' slotted 12.6# L-80 1ST 5,668' 7,362' 14,319' 13,030' 14,283' 6-3,4" OA 4- W' slotted 12.6# L-80 1ST 3,729' 7,163' /4,243' 13,011'/4,213' Tubing 4-%" 12.6# L-80 IST-M 7,121' 29' I 29' 7,150' 14,238' Cement Calculations Casing Size 110-3,4 -in 45.5-lb/ft L-80 STC surface casing Basis 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:Jt>/gal MudPush spacer...-..,-~ Lead 527-bbl¡t39~sx 10.7-lb/gal ASL~felsx (cemen~surface) ~ Tail 75-bbl, ß6ßsx 1 Premium G c2J-nelsx of 'fiíil at Temp SHST "" 55°F from SOR, SHCT 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 Casing Size 17-% -in 29.7-lb/ft L-ffu [HC-M intermediate casing ...~-' Basis Top of tail cement 700-ft MD above top of Schrader Ma-sand. 30% excess over gauge. Total Cement Vol: Wash 25-bbl Water Spacer 45-bbI1~. Igal MudPush Spacer {j< Tail 113 bbl, .. 3-sx 15:ª=-'-b(gal Premium -. t;:!/sx (top of ta a~Q.4t'MD) Top Ma: , 27' MD T~~p" TBHST "" 120°i:-1fum SOR'SHCT 9Ó~F estimated by Halliburton 10-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,652' 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 longlshort 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 RA tag above the first window, 1 RA tag above the second window, and 1 RA tag above the third window. RA 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-Ys" (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 W' Solid Liner Centralizer Placement a) Run 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-%" Hole Section: Open Hole Drilling: Cased hole: 9-%" Hole Section: Open Hole Drilling: Open Hole: Cased Hole: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) MWD I GR None Surveys will need to be IFR + MS corrected real time MWD I GR I Res I Den I Neu I PWD (Den Neu recorded only) None USIT Bond Lo 6-%" Hole Section: Surveys will need to be IFR + MS corrected real time Open Hole Drilling: 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 Greater Prudhoe Bay L-200 ML Permit Drillilt Hazards and Contin'nCies POST THIS NOTICE IN THE DOGHOUSE II. 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 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. /' I. 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 i.e. Seabee. IV. Kick Tolerance/Integrity Testing A. The 10-%" casing will be cemented to surface. B. The 7-%" casing will be cemented with 15.81b/gal tail cement to 700' MD above the Ma sand -5,800' MD. C. The Kick Tolerance for the surface casing is;ro:~bbls with 9.2 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure (most likely 8.6 ppg based on receÌl'r1\ífDT'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 infinitãV;ith 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-%-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 top window 20-ft minimum from top 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 I 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 an' Complete Procedure sulmary Pre-Rhz 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. Drillinq Riq Operations: /' ..~.", 1. MIRU Nabors 9ES Nipple up diverter spool and riser. Function test diverter. PU 4,500' o~oP·å's required and stand back in derrick (this will enable both holes to be drilled without changing the DP handling êqUipment in open hole). 2. MU 13-112" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,652' MD 12,573' TVD. The actual surface hole TD will be +/-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. /' ND drilling spool and riser and NU casing / 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 TD (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 TD. 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 TD. Cement in one stage to 700' MD above the Schrad~ 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 MW DIG R/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 TD geosteering through t~.. OBd to TD at 13,050' MD I 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-%" 12.6# L-80 BTC-M slotted liner with hanger and liner top packer to TD. 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 I GR / Res / Azimuthal Den recorded I Neu recorded I AIM) to whipstock. / Directionally drill to 6-3;4" TD. Planned TD is 13,030' MD. Circulate and condition mud and perform wiper trip. POOH. 15. Pull whipstock #1. Run and set 4-112" 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 / GR / Res I Azimuthal Den recorded I Neu recorded I AIM) to whipstock. / Directionally drill to 6-3;4" TD. Planned TD 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 I move off Nabors-9ES. /' / 7 Final Permit 12/31/03 POST RIG - COMPLETION ~ L-200, L-200 L 1 & L-200 L2 / ./ ....-.--- '" -,' TREE: FMC 4-1/16" 5M . _ , WELLHEAD: FMC Gen 5 System Ong KB elev (N-9ES) - 28.5 11 ", 5M csg.head wI?" mandrel hanger & packoff 11" x 11", SM, 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.Slb/ft, A53 ERW Insulated 109' X-Nipple (3.813" 10) 12,200' TVD I 4-1/2", 12.6 Ib/ft, L-80, BTC-M Coupling 00: 5.2" OritvlO: 3.833"13.958" Junction Specifications: Junction 10 through LEM Module without diverter: 3.65" .AI .... 10-3/4",45.5# L-80 BTC Csg @ 3,652' MD -, 7-5/8" X 5-1/2" Baker PRM Packer Halliburton X-Nipple (3.813" ID) 4.5"WLEG 1-7,140' I Baker ZXP Liner Top Packer Tie Back Sleeve @ 7,133' MD 9.2 PPG Versapro MOBM below Completion 6-3/4" OA Lateral 17,163'.13,011'1 Baker Hughes Hookwall Hanger @ 7,153' MD Window in 7-5/8" casing@ 7,163' MD Well Inclination @ Window = 68° r·::::::;~::::·:,,:.'::":· .. . .:.:.::.:.'::.'::" .~':'.;': ::....:::¡ ,::.:. ::.:.:::..::: ..':.::":";::", : . . :... ,,'.:.,"": . ..:.::":;: ,. . ..~ I . .. ~~.:7" ~ ~ -"':" -::- - ~ ~ -":' ~ ~:~:.~ ~ - ~ ~...~-::.:- '7 ~=:".:~ ':!-":, 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' MO Well Inclination @ Window = 68° . .I.·..·.~,··. ~.:.":.:... _""':;':" ~"".;,;/.:.~..,..:::;:~..: (~;II -------- Baker ZXP Liner Top Packer & Hanger @ 7,462' MD II 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" '.~.~-~~~~::':15 ~ 6-3/4" OBd Lateral 17,873'-13,0501/" DATE REV. BY COMMENTS 12/3012003 MIK TRIOLO Level 3 Multi-Lateral, 4-1/2" GL Completion '. r -1'--- ORIO~J n..'_h~-;_~~~~;:~~~~~ ""; WELL: L-200 ML 50-029-xxxxx-61 Report Date: Client: Field: Structure 1 Slot: Well: Borehole: UWUAPI#: Survey Name 1 Date: T,rtl AHD I DDII ERD ratio: Grld Coordinate System: location lat/long: location Grld NIE YIX: Grid Convergence Angle: Grid Scale Factor: Comne,ts Measured I Depth (It) 0.00 300.00 400.00 500.00 600.00 RTE KOP Bid 1.51J0 Bid 2.5/100 Cry 4/100 700.00 800.00 900.00 977.52 1000.00 SV6 1100.00 1200.00 1300.00 1400.00 1500.00 SV5 1600.00 1679.61 1700.00 1800.00 1850.70 SV4 Base Perm End Cry SV3 1900.00 2000.00 2014.30 2016.76 2593.47 L-200 (P10) Proposal Schlumberger December 19, 2003 Survey / DlS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit· WOA Vertical Section Orlgln: L-PAD / Plan L-200 (N-M) stbldY lVD Reference Datum: Plan L-2oo (N-M) I blllty TVD Reference Elevation: L-200 OBd Feas Sea Bed 1 Ground level Elevation: 50029 Magnetic DeclinatIon: L-200 (P10) OBd 1 December 19,2003 Total Field Strength: 176.263· 127816.00 ft 17.153/6.187 Magnetic Dip: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: N 70.35065562, W 149.32442018 Magnetic Declination Model: N 5978289.700 ftUS, E 583209.300 ftUS North Reference: -+D.63624294· Total Corr Mag North·> True North: 0.99990787 local Coordinates Referenced To: Inclination I (deg) 0.00 0.00 1.50 4.00 6.50 9.00 12.40 16.08 19.02 19.88 23.74 27.64 31.56 35.50 39.45 43.41 46.57 47.37 51.34 53.35 55.31 59.29 59.86 59.95 59.95 Azimuth I (dog) 350.00 350.00 350.00 350.00 350.00 350.00 1.50 7.96 11.26 12.04 21.66 22.27 22.41 23.08 23.39 23.68 24.22 24.30 24.31 24.31 TVD I Sub·Sea TVD I (It) (It) 0.00 -72.60 300.00 227.40 399.99 327.39 499.87 427.27 599.44 526.84 698.52 796.77 893.69 967.60 988.80 14.84 16.90 18.48 19.74 20.78 1081.62 1171.72 1258.65 1342.00 1421.34 1496.30 1552.60 1566.51 1631.63 1662.60 1691.35 1745.36 1752.60 1753.83 2042.60 NellDesign Ver 3.1 RT -SP3.03-HF2.03 Bld( d031 rt-546 ) 625.92 724.17 821.09 895.00 916.20 1009.02 1099.12 1186.05 1269.40 1348.74 1423.70 1480.00 1493.91 1559.03 1590.00 1618.75 1672.76 1680.00 1681.23 1970.00 Vertical I Along Hole I Section Departure (It) (It) 0.00 0.00 0.00 0.00 1.26 1.31 5.87 6.11 14.68 15.26 119.39 151.71 187.48 226.54 268.70 313.75 351.53 361.47 411.63 437.91 463.99 518.28 526.19 527.55 847.38 27.65 44.72 65.77 84.77 90.70 28.74 47.25 71.82 95.18 102.66 NS (It) 0.00 0.00 1.29 6.01 15.02 28.30 46.75 71.21 94.23 101.56 137.66 179.33 226.37 278.54 335.60 397.27 449.46 463.24 533.20 570.08 606.80 683.69 694.93 696.87 1151.82 Minimum Curvature / Lubinski 334.150· N 0.000 ft, E 0.000 ft Rotary Table 72.6 ft relative to MSL 44.100 ft relative to MSL 25.108' 57553.566 nT 80.819' January 10, 2004 BGGM 2003 True North +25.108· Well Head EW I DlS I Build Rate I Walk Rate (It) (deg/100 It) (deg/100 It) (deg/100 It) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.23 1.50 1.50 0.00 -1.06 2.50 2.50 0.00 -2.65 2.50 2.50 0.00 -4.99 -6.07 -3.87 0.08 1.59 10.30 22.20 37.24 55.35 76.43 100.39 121.45 127.11 156.46 172.30 188.29 222.45 227.52 228.39 433.89 2.50 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 2.50 3.40 3.68 3.79 3.83 3.96 3.96 3.97 3.97 3.97 3.97 3.97 3.98 3.98 0.00 Plan L-200 (N-M)IPlan L-200 (N-M)IL-200 OBd1L-200 (P10) OBd 139.80 183.14 232.53 287.76 348.59 414.75 471.02 485.92 561.79 601.93 641.98 726.11 738.44 740.57 1239.78 3.86 3.90 3.92 3.94 3.95 ,'0.88 0.77 0.72 0.67 0.61 Tool Face I (deg) -10.00M -10.00M -10.00M -10.00M O.OOG 0.00 11.50 6.46 4.25 3.47 37.85G 26.55G 20.28G 17.13G 16.40G 2.80 2.05 1.58 1.26 1.04 13.79G 11.94G 10.57G 9.51G 8.69G 8.03G 7.60G 7.50G 7.06G 6.87G 0.58 0.54 0.52 0.51 0.00 6.70G 6.41G 6.37G O.OOG O.OOG Northing (ltUS) 5978289.70 5978289.70 5978290.99 5978295.70 5978304.69 5978317.94 5978336.37 5978360.85 5978383.92 5978391.26 5978427.45 5978469.25 5978516.45 5978568.81 5978626.10 5978688.02 5978740.44 5978754.28 5978824.55 5978861.60 5978898.50 5978975.75 5978987.04 5978988.99 5979446.15 Easting (ltUS) 583209.30 583209.30 583209.06 583208.17 583206.48 583204.00 583202.71 583204.64 583208.34 583209.77 583218.07 583229.51 583244.02 583261.55 583282.00 583305.27 583325.74 583331.25 583359.82 583375.24 583390.82 583424.13 583429.07 583429.92 583630.34 e latnude longnude N 70.35065562 W 149.32442018 N 70.35065562 W 149.32442018 N 70.35065914 W 149.32442202 N 70.35067205 W 149.32442879 N 70.35069666 W 149.32444168 N 70.35073294 W 149.32446069 N 70.35078333 W 149.32446945 N 70.35085015 W 149.32445160 N 70.35091305 W 149.32441951 N 70.35093307 W 149.32440723 N 70.35103169 W 149.32433657 N 70.35114553 W 149.32423994 N 70.35127403 W 149.324. N 70.35141657 W 149.32 1 N 70.35157245 W 149.32~. . J5 N 70.35174092 W 149.32360512 N 70.35188350 W 149.32343419 N 70.35192115 W 149.32338820 N 70.35211227 W 149.32314994 N 70.35221302 W 149.32302135 N 70.35231333 W 149.32289149 N 70.35252338 W 149.32261412 N 70.35255408 W 149.32257300 N 70.35255938 W 149.32256588 N 70.35380223 W 149.32089727 Generated 12/19/2003 11: 21 AM Page 1 of 3 I Comn","!, Measured I Inclination I Azimuth I TVD Sub-Sea TVD I Vertical I AJong HOle NS EW I DLS I Build Rate I Walk Rate I Tool Face Northing Ea.tlng Latitude Longitude Depth Section Departure (It) (deg) (deg) (It) (It) (It) (It) (It) (It) (dog/100 It) (deg/100 It) (deg/100 It) (deg) (ltUS) (ltUS) SV2 2913.01 59.95 24.31 2202.60 2130.00 1024.59 1516.38 1403.89 547.75 0.00 0.00 0.00 O.OOG 5979699.46 583741.38 N 70.35449087 W 149.31997264 SV1 3582.06 59.95 24.31 2537.60 2465.00 1395.62 2095.51 1931.68 786.15 0.00 0.00 0.00 O.OOG 5980229.81 583973.88 N 70.35593269 W 149.31803649 10-3/4" CS9 ,"I 3651.96 59.95 24.31 2572.60 2500.00 1434.39 2156.02 1986.83 811.06 0.00 0.00 0.00 O.OOG 5980285.22 583998.17 N 70.35608332 W 149.31783419 UG4 4161.23 59.95 24.31 2827.60 2755.00 1716.82 2596.85 2388.58 992.53 0.00 0.00 0.00 O.OOG 5980688.93 584175.15 N 70.35718081 W 149.31636019 UG4A 4221.15 59.95 24.31 2857.60 2785.00 1750.04 2648.72 2435.84 1013.88 0.00 0.00 0.00 O.OOG 5980736.42 584195.97 N 70.35730992 W 149.31618677 UG3 4850.25 59.95 24.31 3172.60 3100.00 2098.92 3193.28 2932.12 1238.04 0.00 0.00 0.00 O.OOG 5981235.11 584414.59 N 70.35866562 W 149.31436572 Cry 4/100 4874.91 59.95 24.31 3184.95 3112.35 2112.60 3214.62 2951.58 1246.83 0.00 0.00 0.00 -102.71G 5981254.66 584423.16 N 70.35871876 W 149.31429434 4900.00 59.74 23.17 3197.55 3124.95 2126.66 3236.32 2971.44 1255.57 4.00 -0.86 -4.52 -102.14G 5981274.61 584431.68 N 70.35877302 W 149.31422336 5000.00 58.97 18.61 3248.54 3175.94 2185.59 3322.34 3051.78 1286.25 4.00 -0.76 -4.56 -99.81G 5981355.28 584461.46 N 70.35899248 W 149.31397408 5100.00 58.38 13.98 3300.55 3227.95 2248.89 3407.75 3133.73 1310.22 4.00 -0.60 -4.63 -97.40G 5981437.49 584484.52 N 70.35921636 W 149.31377930 5200.00 57.95 9.30 3353.33 3280.73 2316.26 3492.69 3216.90 1327.36 4.00 -0.43 -4.68 -94.93G 5981520.84 584500.73 N 70.35944356 W 149.31_ 5300.00 57.69 4.58 3406.61 3334.01 2387.38 3577.31 3300.88 1337.58 4.00 -0.26 -4.72 -92.42G 5981604.91 584510.02 N 70.35967298 W 149.31 5400.00 57.61 359.85 3460.14 3387.54 2461.89 3661.78 3385.25 1340.85 4.00 -0.08 -4.73 -89.89G 5981689.32 584512.35 N 70.35990349 W 149.313. ,I 5500.00 57.70 355.11 3513.66 3441.06 2539.43 3746.25 3469.62 1337.13 4.00 0.10 -4.73 -87.35G 5981773.63 584507.70 N 70.36013397 W 149.31356021 5600.00 57.98 350.40 3566.91 3494.31 2619.63 3830.89 3553.57 1326.46 4.00 0.27 -4.71 -84.84G 5981857.44 584496.09 N 70.36036330 W 149.31364679 5700.00 58.42 345.72 3619.63 3547.03 2702.10 3915.87 3636.68 1308.87 4.00 0.45 -4.68 -82.38G 5981940.34 584477.59 N 70.36059037 W 149.31378947 UG1 5705.68 58.45 345.46 3622.60 3550.00 2706.84 3920.71 3641.36 1307.67 4.00 0.54 -4.65 -82.24G 5981945.02 584476.34 N 70.36060316 W 149.31379924 5800.00 59.04 341.10 3671.56 3598.96 2786.42 4001.33 3718.56 1284.47 4.00 0.62 -4.62 -79.97G 5982021.94 584452.28 N 70.36081406 W 149.31398758 5900.00 59.81 336.54 3722.44 3649.84 2872.20 4087.41 3798.80 1253.36 4.00 0.78 -4.56 -77.65G 5982101.82 584420.29 N 70.36103329 W 149.31424015 6000.00 60.74 332.06 3772.04 3699.44 2959.01 4174.25 3877.01 1215.70 4.00 0.93 -4.48 -75.43G 5982179.61 584381.76 N 70.36124698 W 149.31454594 6100.00 61.82 327.67 3820.10 3747.50 3046.43 4261.94 3952.82 1171.67 4.00 1.08 -4.39 -73.32G 5982254.92 584336.90 N 70.36145410 W 149.31490347 6200.00 63.04 323.37 3866.40 3793.80 3134.04 4350.57 4025.86 1121.48 4.00 1.22 -4.30 -71.33G 5982327.38 584285.91 N 70.36165364 W 149.31531099 6300.00 64.38 319.16 3910.71 3838.11 3221.40 4440.21 4095.76 1065.39 4.00 1.34 -4.20 -69.47G 5982396.65 584229.05 N 70.36184463 W 149.31576653 6400.00 65.84 315.06 3952.81 3880.21 3308.10 4530.92 4162.18 1003.66 4.00 1.46 -4.11 -67.74G 5982462.38 584166.59 N 70.36202613 W 149.31626787 6500.00 67.41 311.05 3992.50 3919.90 3393.71 4622.70 4224.82 936.59 4.00 1.57 -4.01 -66.15G 5982524.26 584098.84 N 70.36219726 W 149.31681256 Ma 6526.52 67.84 310.00 4002.60 3930.00 3416.18 4647.23 4240.75 917.95 4.00 1.63 -3.95 -65.75G 5982539.98 584080.02 N 70.36224080 W 149.31696398 6526.55 67.84 310.00 4002.61 3930.01 3416.20 4647.25 4240.77 917.93 4.00 1.64 -3.94 88.61 G 5982540.00 584080.00 N 70.36224084 W 149.31696413 End Cry 6542.80 67.86 310.70 4008.74 3936.14 3429.97 4662.30 4250.51 906.46 4.00 0.11 4.32 O.OOG 5982549.62 584068.42 N 70.36226747 W 149.31705729 Mb1 6645.91 67.86 310.70 4047.60 3975.00 3517.59 4757.80 4312.79 834.06 0.00 0.00 0.00 O.OOG 5982611.08 583995.34 N 70.36243763 W 149.31764533 Mb2 6818.36 67.86 310.70 4112.60 4040.00 3664.13 4917.54 4416.96 712.96 0.00 0.00 0.00 O.OOG 5982713.89 583873.11 N 70.36272224 W 149.31862889 Nb 6844.89 67.86 310.70 4122.60 4050.00 3686.67 4942.11 4432.98 694.33 0.00 0.00 0.00 O.OOG 5982729.70 583854.30 N 70.36276602 W 149.31_ Nc 6964.28 67.86 310.70 4167.60 4095.00 3788.13 5052.70 4505. 10 610.49 0.00 0.00 0.00 O.OOG 5982800.87 583769.68 N 70.36296305 W 149.31 " OA 7163.26 67.86 310.70 4242.60 4170.00 3957.21 5237.01 4625.29 470.77 0.00 0.00 0.00 O.OOG 5982919.49 583628.64 N 70.36329143 W 149.320b~v<J8 Cry 4/100 7166.42 67.86 310.70 4243.79 4171.19 3959.89 5239.93 4627.19 468.55 0.00 0.00 0.00 -135.53G 5982921.37 583626.40 'N 70.36329663 W 149.32061406 7189.50 67.20 310.00 4252.61 4180.01 3979.41 5261.25 4641.00 452.30 4.00 -2.85 '~3.04 -90.85G 5982935.00 583610.00 N 70.36333436 W 149.32074608 7200.00 67.19 309.54 4256.68 4184.08 3988.22 5270.93 4647.19 444.86 4.00 -0.05 -4.34 -90.67G 5982941.11 '583602.49 N 70.36335128 W 149.32080652 End Cry 7286.00 67.20 305.81 4290.02 4217.42 4059.18 5350.21 4695.64 382.13 4.00 0.00 -4.34 O.OOG 5982988.85 583539.23 N 70.36348364 W 149.32131610 OBa 7362.32 67.20 305.81 4319.60 4247.00 4121.10 5420.56 4736.81 325.08 0.00 0.00 0.00 O.OOG 5983029.38 583481.73 N 70.36359611 W 149.32177950 OBb 7486.17 67.20 305.81 4367.60 4295.00 4221.59 5534.74 4803.61 232.49 0.00 0.00 0.00 O.OOG 5983095.15 583388.42 N 70.36377863 W 149.32253159 Cry 4/100 7558.81 67.20 305.81 4395.75 4323.15 4280.52 5601.69 4842.79 178.19 0.00 0.00 0.00 17.30G 5983133.72 583333.69 N 70.36388567 W 149.32297267 7600.00 68.77 306.34 4411.19 4338.59 4314.22 5639.88 4865.28 147.32 4.00 3.82 1.28 17.10G 5983155.86 583302.58 N 70.36394710 W 149.32322339 7632.12 70.00 306.74 4422.50 4349.90 4340.86 5669.94 4883.18 123.17 4.00 3.82 1.25 O.OOG 5983173.49 583278.23 N 70.36399600 W 149.32341960 Cry 6/100 7632.12 70.00 306.74 4422.50 4349.90 4340.86 5669.95 4883.18 123.17 0.00 0.00 0.00 -4.35G 5983173.49 583278.23 N 70.36399600 W 149.32341960 OBc 7632.41 70.02 306.74 4422.60 4350.00 4341.10 5670.22 4883.34 122.95 6.25 6.23 -0.50 -4.35G 5983173.65 583278. 01 N 70.36399645 W 149.32342139 Nell Design Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) Plan L-200 (N-M)IPlan L-200 (N-M)IL-200 OBd1L-200 (P10) OBd Generated 12/19/2003 11:21 AM Page 2 of 3 Co;-m:nrn: 1$ Measured I Inclination I Azimuth I TVD I Sub·Sea TVD I Vertical I Along Hole I NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Eastlng Latitude Longitude Dopth Section Departure (It) ( dog) (deg) (It) (It) (It) (It) (It) (It) (deg/100 It) (degJ100 It) (deg/100 It) (dog) (ltUS) (flUS) 7700.00 74.23 306.41 4443.34 4370.74 4398.10 5734.53 4921.66 71.30 6.25 6.23 -0.49 -4.24G 5983211.39 583225.94 N 70.36410113 W 149.32384095 - 7800.00 80.46 305.94 4465.23 4392.63 4484.23 5832.05 4979.22 -7.43 6.25 6.23 -0.47 -4.14G 5983268.06 583146.59 N 70.36425837 W 149.32448049 End Cry 7859.98 84.20 305.67 4473.24 4400.64 4536.54 5891.49 5013.99 -55.63 6.25 6.23 -0.45 O.OOG 5983302.29 583098.00 N 70.36435335 W 149.32487210 7873.39 84.20 305.67 4474.59 4401.99 4548.26 5904.83 5021.76 -66.47 0.00 0.00 0.00 O.OOG 5983309.94 583087.08 N 70.36437460 W 149.32496014 7-5/8" Csg Ft 7873.49 84.20 305.67 4474.60 4402.00 4548.35 5904.93 5021.82 -66.55 0.00 0.00 0.00 O.OOG 5983310.00 583087.00 N 70.36437476 W 149.32496079 OBd 7873.59 84.20 305.67 4474.61 4402.01 4548.44 5905.03 5021.88 -66.63 0.00 0.00 0.00 O.DOG 5983310.06 583086.92 N 70.36437492 W 149.32496144 Cry 6/100 7893.49 84.20 305.67 4476.62 4404.02 4565.84 5924.83 5033.42 -82.72 0.00 0.00 0.00 8.53G 5983321.42 583070.71 N 70.36440645 W 149.32509211 7900.00 84.59 305.72 4477.26 4404.66 4571.53 5931.30 5037.20 -87.98 6.00 5.93 0.89 8.52G 5983325.14 583065.41 N 10.36441678 W 149.32513484 End Cry 7970.46 88.77 306.35 4481.34 4408.74 4633.56 6001.63 5078.57 -144.84 6.00 5.93 0.89 O.OOG 5983365.87 583008.09 N 70.36452980 W 149.32559679 Cry 6/100 8624.45 88.77 306.35 4495.37 4422.77 5211.93 6655.47 5466.12 -671.45 0.00 0.00 0.00 15.88G 5983747.51 582477.26 N 70.36558845 W 149.32987502 L-200 OBd -91 2 8645.76 90.00 306.70 4495.60 4423.00 5230.81 6677.07 5478.80 -688.57 6.00 5.77 1.64 16.17G 5983760.00 582460.00 N 70.36562309 W 149.33~. End Cry 8671.66 91.49 307.13 4495.26 4422.66 5253.84 6702.97 5494.35 -709.28 6.00 5.76 1.67 O.OOG 5983775.32 582439.12 N 70.36566558 W 149.330 T Cry 6/100 9529.26 91.49 307.13 4472.92 4400.32 6017.59 7560.28 6011.88 -1392.76 0.00 0.00 0.00 177.42G 5984285.18 581750.01 N 70.36707916 W 149.33573575 L-200 OBd 1 g. 3 9554.16 90.00 307.20 4472.60 4400.00 6039.78 7585.18 6026.92 -1412.60 6.00 -5.99 0.27 178.09G 5984300.00 581730.00 N 70.36112024 W 149.33589698 End Cry 9570.96 88.99 307.23 4472.75 4400.15 6054.76 7601.98 6037.09 -1425.98 6.00 -6.00 0.20 O.OOG 5984310.01 581716.51 N 70.36714800 W 149.33600570 Cry 6/100 10404.77 88.99 307.23 4487.41 4414.81 6798.12 8435.66 6541.51 -2089.74 0.00 0.00 0.00 39.02G 5984806.99 581047.26 N 70.36852562 W 149.34139959 L-200 OBd 1} 4 10426.38 90.00 308.05 4487.60 4415.00 6817.46 8457.27 6554.71 -2106.85 6.00 4.66 3.78 39.70G 5984820.00 581030.00 N 70.36856167 W 149.34153867 End Cry 10499.31 93.37 310.85 4485.46 4412.86 6883.67 8530.16 6601.02 -2163.13 6.00 4.61 3.84 O.OOG 5984865.68 580973.21 N 70.36868814 W 149.34199606 Cry 6/100 11285.75 93.37 310.85 4439.29 4366.69 7604.72 9315.24 7114.51 -2757.00 0.00 0.00 0.00 166.60G 5985372.49 580373.74 N 70.37009042 W 149.34682291 11300.00 92.53 311.05 4438.56 4365.96 7617.80 7123.84 -2767.74 6.00 -5.84 1.39 166.61G 5985381.70 580362.89 N 70.37011588 W 149.34691026 L-200 OBd 1,r 5 11343.41 90.00 311.65 4437.60 4365.00 7657.80 9372.86 7152.51 -2800.32 6.00 -5.84 1.39 166.30G 5985410.00 580330.00 N 70.37019416 W 149.34717505 End Cry 11358.88 89.10 311.87 4437.72 4365.12 7672.11 9388.34 7162.81 -2811.86 6.00 -5.83 1.42 O.OOG 5985420.18 580318.34 N 70.37022231 W 149.34726888 Cry 6/100 12293.44 89.10 311.87 4452.43 4379.83 8536.79 10322.78 7786.50 -3507.70 0.00 0.00 0.00 44.30G 5986036.04 579615.69 N 70.37192535 W 149.35292554 12300.00 89.38 312.14 4452.52 4379.92 8542.86 10322.78 7790.89 -3512.58 6.00 4.29 4.19 44.29G 5986040.37 579610.76 N 70.37193734 W 149.35296518 L-200 OBd 1 gl 6 12314.44 90.00 312.75 4452.60 4380.00 8556.28 10343.78 7800.63 -3523.24 6.00 4.29 4.19 44.85G 5986050.00 579600.00 N 70.37196395 W 149.35305182 End Cry 12391.88 93.29 316.03 4450.38 4377.78 8629.11 10421.17 7854.76 -3578.53 6.00 4.25 4.24 O.OOG 5986103.51 579544.11 N 70.37211176 W 149.35350140 TD /4-1/2" Lnr 13049.66 / 93.29 316.03 4412.60 4340.00 9253.24 11077.87 8327.39 -4034.47 0.00 0.00 0.00 O.OOG 5986571.00 579083.00 N 70.37340230 W 149.35720865 Leaal Desci:!Rtlon: Northlna (V) rftUS! Eastlna (X) rftUS! 3urface: 2567 F5L 3705 FEL 534 T12N R11 E UM 5978289.70 583209.30 e L-200) 'd Tgt 1 : 2309 F5L 3762 FEL 527 T12N R11 E UM 5983310.00 583087.00 L-200:.J£d Tgt 2: 2766 FSL 4383 FEL 527 T12N R11 E UM 5983760.00 582460.00 L-200 md Tgt 3: 3314 FSL 5106 FEL 527 T12N R11 E UM 5984300.00 581730.00 L-200 D(d Tgt 4: 3842 F5L 519 FEL 528 T12N R11E UM 5984820.00 581030.00 L-200 lid Tgt 5: 4439 F5L 1212 FEL 528 T12N R11E UM 5985410.00 580330.00 L-200:JFd Tgt 6: 5087 F5L 1933 FEL 528 T12N R11E UM 5986050.00 579600.00 TD /4-1/2" _ r / BHL: 334 FSL 2444 FEL 521 T12N R11 E UM 5986571.00 579083.00 NellDesign Ver 3.1RT-5P3.03-HF2.03 Bld( do31rt-546} Plan L-200 (N-M}\Plan L-200 (N-M}\L-200 OBd\L-200 (P10) OBd Generated 12/19/2003 11 :21 AM Page 3 of 3 ?5 ð " - ,~ ) -j ) () p ( Schlumberger WEll Prudhoe Bay Unit - WOA STRlJCTlJRE L-PAD FiElD L-200 (P10) OBd MagneücPeramelers Model: BGGM2003 SIJrfac.eLocatIon Lat: N10212.360 Lon: W1491921.913 NAD21 Alaska StIIte Planes, Zone 04, US Feet NoIthIng: 6Q78289.10 ftUS GrId Conv: +0.63824294' Eating: 583209.30 flUS Scale Fact: 0.99990186S2 - Slot: ÞIanL-200(N-M) Plan: L·200(ptO)oed TVDRef: Ftd.-yTIIbIe(12.80ftabcYeMSL.) Srvyo.te: c-nbert9,2003 Dip: 80.819' Mag Dee: +25.108' Date: J_ry 10. 2004 FS: 51553.8nT o 1200 2400 7200 8400 3600 4800 6000 9600 o e o 1200 1200 ····"··········'·'···········t······················'"'·..·······~····················..··············t·····...............................~......................··············t···················..···············~·..·................................!....................................~.. ~ ~ ¡ ¡ ~ ~ ; ~ 7;·""" E!!~ ~q. ........ ......... .-....... ~.._..... .......... ........ ~.. ..._..... .......... ..... _~. - .._..... _........ - ....... +.. ...... _.. ..._.... ._.._..~.... .... _.. - ........ - .._u_.¡_. ._u_..... _u.....· .u.ut.. -...... ""-I''''', ....-....... ............... ._.~_...... .-........... ._..........., _ ........... '"''_H''''' ..a_H"", ...._....._...... ...._.,.... ._.._....... .........,.... ._............... ........... ...."'to.......... ._............ ...._..... .....J.......... .._.......... .............. .+.. ................ ...........-..-. ..... ..... _"_Ht·· ........................- ...··.......··-..t··........··..·····...··..··...· .. ¡ ¡ ¡ ¡ Cry 4I100End Cry Cry 4.!100 Cry 6/100 ¡ , ¡ L-200 OBd 7915; TO 14-112" Lnr ___ ¡ ...-..-.....i........_....._.._.._u..._L_.._....._u......-.......{-..-..-.....-..-..... ..J..... ·-"-/-.·-.f/!:! 'J}.1!!_0 - - ._. -. . .'·-V ...l=?d. Crv.. .. C!"~/100\ lnd Cry ¡ :t ¡ -... - = .. .. - - - ...: ... - - _..~ : = >. '.' :";;'~'.~ .~~~~:.:': . = _ jL; ~:.~.~ :': ;' - : :. ~ \l~T'~':~ 'n r~-r( ;; ~::~·tl:jj::~ .~..~ ·~~tttl ...~--- I ~ - /\ /\ ~--- rlll,":r'" '. E: 'c' :r"; Cry c¡ :::0 '. . LilC': crY" . 7-514" C PI ¡ Cry 6/100 ¡ End 9" Cry 8/1~ L.200 OBd 7916 I sg Cry 8/100 End irv L-200 OBd 791 21 L-200 OBd 791 ¿ 1 ¡ 2400 2400 3600 3600 e 4800 4800 o 1200 2400 3600 4800 6000 7200 Vertical Section (ft) Azim = 334.15°, Scale = 1(in):1200(ft) Origin = 0 Nt-S, 0 EI-W 8400 9600 o 1200 -3600 2400 «< W H....................n........,........... .,............................................ · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . · . Scale = 1200 1(in):1200(ft) ···ë;:,·4Îiör:;::::l.":····...· Bid 2.5110("7 "- KOP Bid 1.5/100 I RTE .................................... j1D-3I4" Csg PI ........'...n........ E »> o 1::0 ....................... ..."........................ ............................. o 1200 ^ ^ ^ z e õ o N ..... ~ ..... II Q) ãi o en en v v v 2400 4800 6000 7200 3600 bp Þ VÆU. L-200 (P10) OBd -- Model: BGGM 2003 "". 80.819" Dale: Mag Dee: +25.108" FS, 8400 -3600 ~ i (Ë.~~~~:...... ~ ':.. r~...............·...·.~.;.·....·.................................................... ........... ¿¡:j......... .N~W"....'.. ~. 1If.····· ; "< , . ~6 , , ¡ 5110'".\ ". L-¡ Fft 3 .. ··T·..······ .....:;;; ........ ............ .... .......¡. ........ ¡ EndCrv ¡ -. ¡ iL-2OO OBd T~ 5, ¡ ¡ Crv6l100 ~¡ ¡ ~ E~CN: i ! ~~~ ¡ ¡ ~~ : ······1·..·..··..·....··..··..··.....······1......········....··.. ·......········.......········..····1·····..· ~ ! EndCrv : ~ ~ ~ L-2000BdT~3 : ~ I ¡ Cry 61100 J Cry ! ¡ L-200 OÌ3d T~ 2 ¡ I I~~: I ........... "............. ........... -, ......... ..;............. ........... -,. ..,......,-.~~.. ........... ......... .~... ¡ ¡ 7·518" Csg PI ¡ ¡ ¡ ¡ Cry 6I10Ö ¡ ¡ ¡ Crv4HOO ¡ ] I -l~-------¡ : Cry 4/100 ¡ ~ ........................... 2400 3600 4800 6000 7200 8400 January 10, 2004 57553.6nT -2400 ...-""""'" lat; N70 21 2.360 Lon: W1491927.913 Prudhoe Bay Unit - -1200 NAD27 AIa$ka Slate Planes, Zaoe 04, us Feet Northing: 5978289.70 flUS Grid Conv: +Oß3824294" Easting: 583209.30 ftUS Scale Fact: 0.9999078652 WOA STRUCTURE L-P AD ............... Slot PlanL-200(N-M) 1VD Ret. Rotary Table (72.60 It abo¥e MSl) "". L-200(P10)0Bd Srvy Dale: Deoember 19, 2003 0 1200 e FEU> e Schlumberger Field: Site: Well: Wellpath: Prudhoe Bay PB L Pad Plan L-200 (N-M) Plan L-200 OBd --294 o 291 Plan L-211 (N-H) (Plan L-211) Plan L-124 (N-C) (Plan L-124) e ······200 100 -0 270 90 . ~~IOO e 200 -294 L-OJ..flhl)\!l'Bl) L-I¿ll \~-l¿HI8) L-115 (L-II?)I L-1I4 (L-114) 10 LU;!JQI~~ ··r nn (ØL-n~ L-I09 (L- 109) L-I05 (L-105) L~~~r¿q¡-J¡°3) L-I07 (L-107) L-lO¡/f'É_f/o;i¡06) 180pra~L_123 (N-Rf~la~~~IHì Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] , Company: Field: Reference Site: Reference Well: Reference Well path: BP Amoco Prudhoe Bay PB L Pad Plan L~200 (N-M) Plan L-2000Bd e BPX AK Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 13049.66 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 10/23/2003 Validated: No Planned From To Survey ft ft 28.50 13049.66 Planned: Plan #10 V1 Casing Points MD ft 3651.96 7873.49 13049.66 TVD ft 2572.60 4474.60 4412.60 Diameter in 10.750 7.625 4.500 Summary < Site Offset Well path Well PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad L-01 L-01 L-02 L-02 L-102 L-102 L-102 L-103 L-104 L-105 L-106 L-107 L-108 L-109 L-110 L-111 L-112 L-114 L-115 L-116 L-117 L-118 L-119 L-120 L-121 L-121 L-122 Plan L-113 (N-B) Plan L-123 (N-R) Plan L-124 (N-C) Plan L-201 (N-U) Plan L-21 0 (N-W) Plan L-211 (N-H) Hole Size in Name 13.500 9.875 6.750 103/4" 7 5/8" 41/2" .,. Well path L-01 V14 L-01 L 1 V2 Plan: Plan # L-02 V1 L-02PB1 V21 L-102 V2 L-102PB1 V10 L-102PB2 V2 L-103 V23 L-104 V7 L-105 V4 L-106 V14 L-107 V14 L-108 V18 L-109 V12 L-110V11 L-111 V24 L-112V8 L-114 V14 L-115V7 L-116 V10 L-117V11 L-118 V9 L-119V9 L-120 V8 L-121 V14 L-121A V1 L-122 V5 Plan L-113 V5 Plan: PI Plan L-123 V1 Plan: PI Plan L-124 V1 Plan: PI Plan L-201 OBd V1 Plan Plan L-210 V2 Plan: PI Plan L-211 V1 Plan: PI Date: 12/19/2003 e Time: 11: 11:44 Co-ordinate(NE) Reference: Vertical (fVD) Reference: Well: Plan L-200 (N-M), True North L-200 Plan N-M 72.6 Page: Version: Toolcode MWD+IFR+MS Reference MD ft 295.90 295.90 636.19 636.19 243.60 243.60 243.60 494.22 341.65 341.88 622.99 245.25 530.00 296.20 295.49 246.39 340.39 391.69 543.33 391.89 494.91 743.33 544.40 293.48 196.19 196.19 345.48 349.79 801.38 548.67 1623.06 400.23 449.57 Offset MD ft 300.00 300.00 650.00 650.00 250.00 250.00 250.00 500.00 350.00 350.00 650.00 250.00 550.00 300.00 300.00 250.00 350.00 400.00 550.00 400.00 500.00 750.00 550.00 300.00 200.00 200.00 350.00 350.00 800.00 550.00 1600.00 400.00 450.00 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Náme MWD + IFR + Multi Station Ctr-Ctr No-Go Distance Area ft ft 180.56 4.71 180.56 4.71 157.80 10.07 157.80 10.18 244.58 3.89 244.58 3.98 244.58 3.98 91.46 7.68 223.51 5.67 203.91 6.01 202.07 10.03 180.98 5.26 190.23 9.33 192.36 6.04 214.81 5.28 285.48 4.32 177.21 6.97 260.79 6.01 97.92 8.91 200.44 5.78 86.60 7.65 55.24 13.20 138.45 8.84 167.15 4.92 232.77 3.52 232.77 3.52 130.89 5.54 205.33 7.56 71.53 13.29 191.80 9.51 74.39 30.93 150.50 6.95 116.02 7.76 -r Allowable Deviation ft 175.85 175.85 147.73 147.62 240.69 240.60 240.60 83.77 217.84 197.90 192.05 175.73 180.90 186.32 209.54 281.16 170.24 254.78 89.01 194.66 78.95 42.04 129.61 162.22 229.25 229.25 125.35 197.77 58.25 182.30 43.46 143.55 108.26 Warning . ;;r Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk p 055199 DATE 11/25/2003 PR1118031 INVOICE / CREDIT MEMO ··-:.p{~lA_ t,_, Al)() '~p b L( L - 7__.0 () l-~ l , ) c") . \ _" _ ..'} ¡. \::::)\J._, ,"'-. 1-..u<..) ~.~ ^--- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY: TO THE ORDER OF: DESCRIPTION PERMIT TO DRILL FEES TOTAL .. B·..·...· p..... t:~' "fr ,.1111) ,"I!lf ...... .. 'J l'luti tpl'l' . . ...... .., " I DATE 11/25/2003 CHECK NO. 055199 GROSS VENDOR DISCOUNT NET ~ECE'VEC DEC 3 12003 . ·01' A\8S~a Oil & Gas Cons. ComnlSSI Anchorage NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. p 055199 CONSOLIDATED COMMERCIAL ACCOUNT ""'1 fut" AMOUNT *******$100.00******1 NOTl· ';~~~~::f:f!~~::~~~~~~~~J/~~~K~;i.~:::~ ~\::~! ;:··,:':~T1.· ...... ..... &'~L~ ::.. ....~ ..... ..-,.,..... :"2"r!~ ~§i\;&2;;~~::;.~j DATE November 25, 2003 J . ..1 ALASKA OIL &.GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 1110 5 5 l. q q III I: 0 I. . 20 3r 8 q 5 I: O. 2 ? 8 q bill H e e e . TRANSMJT AL LETTER CHECKLJST CIRCLE APPROPRJATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMJTT AL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing weD Permit No, API No. Productionsbould continue to be reported as a function of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), al1 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). Pn.,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\j ody\templates Tbe permit is approved subject ·to full compliance with 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 tbe spacing exception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals tbrough target zones. ~~~l;.J3._'& Field & Pool PRUDHOE BAY, POLARIS OIL - 640160 Well Name: PRUDHOE BAY UN POL L-200 PTD#: 2040010 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV /1-0IL GeoArea Unit Administration 1 P.ß[mit fee attached _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 Leas.ßnumberappropriate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nique weltn_arn.ß_a[ld Ol!mb_e[ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeUJQcat.ßd inadefine~pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ 5 WelUQcat.ßd proper distance from driJling unitb_ound_a[y_ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WelUQcat.ßd pr_oper _distance_ from otber welJs_ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_utficient acreageaYailable indrilliog unjL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jf.d.ßviated, js wellbQre plaUncJuded _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _O-perator only: affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O-perator bas_appropriate_bo[ld lnJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yß!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 P.ß!T1Jit ca[l be iSSl!eçl wjtbout co_nservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 12 P.ßunitca[l be lSSl!eçl witbout ad_minist[atille_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yß!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 1/2/2004 13 Can permit be approved before 15-day wait Yes 14 WeIUocat.ßdwithinareaand_strata_authorizedby_I[ljectiooOrde[#(puUOtlin_cornrn_eotsHFor_ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 15 AJlwelJs_wit]1inJl4_llJile_area_ofreyie,,./jd.ß[ltified(Forservjc.ßweUonly). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 Pre-producedi[ljector; ~uration_ofpre--pro~uctionlß!ssthan3montbs(For_servlcewel[only) _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 17 _ACMP_FJnding.ofCon$i$te[lcyhasbeenissued_forJbisproject _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Appr RPC Engineering Appr Date WGA 1/5/2004 Geology Appr Date RPC 1/2/2004 Geologic Commissioner: fJr~ Program DEV On/Off Shore On o o Well bore seg Annular Disposal - - - - - - - - -- - - - - - - - ~ - - - - - - - - - - - - - - - - ~ Date e 18 _C_oodu_ctor string_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yß!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_urfaœ_casingprotects alLknown USQWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yß!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20CMTvoladeQuateJo çirculate on conductor & SUJf.csg _ _ _ _ _ _ _ _ _ .Yß!S _ _ _ _ _ _ Ade~uate excess, _ _ 21 _CMT v_ol adeQuateJo tie-lnJQngstri[lg to_surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwilJ coyeraJl knownpro_ductiye bori;1:on_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ Slotte_d, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _Casi[lgde_sig[lsad_eç ua.teforC,_T~B_&_permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yß!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 24 Aç/equate_tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ Nabors_9ES, _ _ _ _ 25 Jf.a.re-ç/rilt has_a_ 10-403 fQr abançlonment be.ß[l aPPJov.ßd _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ New well, _ _ _ _ _ _ _ _ 26 _AdequateweUboreseparation'p[oposeç/_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yß!s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jf.diverter req_uired, does it meet regula.tions_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 Drilliogfluid_PJogramschematic_&e(!uipJistaçlequatß!_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes_ _ _ _ _ _ _MaxMW9~~ppg. _ _ _ _ __ 29 _B.oPEs,_dJ) they meetreguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30B.oPEpre_ss raiiog appropriate; testto(pu.t psig in _comrnents)_ _ _ _ _ _ _ _ _ _ _ _ _ .Y.ßS _ _ Testt03500_ psLMS~ 15_30 psi._ 31 _C_hoke_manifold compJies w/APIRP-53 (May 84)_ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ 32 WQrk will occ_ur withoutoperationsbutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ 33 Jsprese[lce_ofH2Sgas_probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ 34 MecbanicaLcolJdition of wells within AOß verified (For_ s_erviœ w.ß1J Only) _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - 35 P.ß[mitca[l Þe iSSl!eçl wlo_ hyçlrogens_ulfide meaSUre$ _ _ _ _ _ _ _ _ _ _ . . . . . . Yß!s _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ . 36 _D_ata_preselJted On pote_ntial pveJpressuœzones _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ NA _ _ _ _ _ _ _ _ . _ _ _ _ _ 37 _S.ßi$rnicanalysJs_ of shaJlow gas_zooes_ _ _ _ _ _ _ _ _... _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ . . _ . . . _ _ _ _ _ _ _ _ _ _ 38 _S.ßabeçl_cOlJdjtjJ)o Sl!rvey(if off-sh_ore) _ . _ _ _ _ _ _ _ _ _ . . . _ _ . . _ _ _NA _ . . . . _ _ _ _ _ _ _ _ _ . _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Conta_ct namelp]1oneJorJ....eekly progressreRorts [e)(ploratpry _o[lly]. _ _ _ _ _ _ . . _ . . . . _ _ _ NA _ _ . . _ _ _ _ _ _ _ _ _ _ . . _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ fY:~ Public Comm"~"" 07~ - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date J)~/1-
