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Home My WebLink About205-052 · . 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.$ - 0 5 ~ Well History File Identifier Organizing (done) o Two-sided 11111111111 ""111I R'7CAN \Ø' Color Items: o Greyscale Items: DIGITAL DATA ~kettes, No. , o Other, No/Type: o Poor Quality Originals: o Other: NOTES: Date? / c¡, ~7 BY: ~ Project Proofing BY: ~ Date 7/1, ~7 :;t X 30 = b () Date:1/q ! ð7 Scanning Preparation BY: ~ Production Scanning Stage 1 <6'6 (Count does include cover sheet) VYES Page Count from Scanned File: BY: Page Count Matches Number in Scanning Preparation: Date:7/~ J07 If NO in stage 1, page(s) discrepancies were found: ~ 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 1/111111I11" 1/111/ OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mP III /111111111/1111I VV)~ 151 151 + ~ 7 = TOTAL PAGES ~ 7 (6ount does not include cover sheet) I A A¡P· 151 V r I III 1111111111111111 YES NO 151 VVl P NO 151 111111/111111111111 III 1111111111111111 151 Quality Checked 111111/1111I 111111I 10/6/2005 Well History File Cover Page. doc ell .~;~1 ~~_.u..n~ •N~ y~ ~ ~. d.-- ...:b p.. V. f ,.1c. §. ` ~~~ '.9 ~. ' ~... J JuJ~ DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050520 Well Name/No. PRUDHOE BAY UN ORIN L-214 Operator BP EXPLORATION (ALASKA) INC MD 7640--- TVD 4726 ..- Completion Date 6/3/2005 Completion Status WAGIN REQUIRED INFORMATION Mud log No Samples No DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, DIR / GR / RES / AZI-DEN / NEU / PWD, lWD: DIR / GR / Well Log Information: Log/ Electr Data Digital Dataset r;e Med/Frmt Number Name RRt Directional Survey i~ D Asc Directional Survey cJD C Lis 14134 Sonic ~ C Lis 15075 Induction/Resistivity Log Log Run Scale Media No log ".,. 15075 Induction/Resistivity 25 Blu /Log 15075 Induction/Resistivity 25 Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? 'i"'t-N Analysis 't'+1f Received? Daily History Received? Formation Tops Comments: Current Status P&A 5p~¿ [to "Ì ~ ~ API No. 50-029-23258-00-00 ~ Directional survey~ (data taken from logs Portion of Master Well Data Maint e Interval OH/ Start Stop CH Received Comments 0 700 7/1/2005 Directional Survey Report 0 7640 6/10/2005 7638 7639 Case 9/12/2006 UBI-GR Imager CCl 27- May-2005 W/Graphics 103 7634 Open 4/30/2007 LIS Veri, FET, ROP, GR, DRHO, NPHI w/Graphics PDS & TXT 108 7640 Open 4/30/2007 MD Composite Vision Service 25-May-05 108 7640 Open 4/30/2007 TVD Composite Vision Service 25-May-05 Sample Set Number Comments e c)N G/N DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050520 Well Name/No. PRUDHOE BAY UN ORIN L-214 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23258-00-00 MD 7640 TVO 4726 __11comPletion Date 6/3/2005 Compliance Reviewed By: ......~ Completion Status WAGIN Current Status P&A UIC Y Date: 3 J~ ~ ~7-~ e e Scblum~ergep Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth (JIQ. QO~-- OGd 11 [.5"O1-~ Well Job# Log Description L-103 V-121 L-214 S-111 11626079 INJECTION PROFILE 11630464 USIT 40011949 OH EDIT MWD/LWD 40011960 OH EOIT MWD/LWD e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: APH 3 0 Z007 e :~ (;ü¡mr~$§iua j 8: 03/27/07 03/29/07 OS/25/05 07/01/05 04/2(/( NO. 4232 Company: Alaska Oil & Gas Cons Carom Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Aurora Date BL Color CD 2 2 Schlumberger~DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·2838 A TTN: Beth Received by' RECEIVED Scblumberger SEP 1 22006 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~QjI&GasCoos.Co~ Anchorage Well Job# Log Description S-03 L-214 L-214A L-210 11223120 PPROF 8. RST WFL 11054295 CH EDIT OF PDC FROM UBI 11217230\'· CH EDIT OF PDC FROM USIT 10687666 CH EDIT OF PDC FROM USIT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: U Ie.- 80S- -()5J. Ii 14r~/f 08/28/06 NO. 3947 Company: Alaska Oil & Gas Cons Comm Att": Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Color CD 06113/06 OS/27/05 03/16/06 01/14/04 . Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage. AK 99503·2838 ATTN: Beth Received by: . (~E'\lED a STATE OF ALASKA _ ALAS~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 181 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: DIR I GR, DIR I GR I RES I AZI-DEN I NEU I PWD, LWD: DIR I GR I RES I All-DEN I NEU I Acoustic Caliper, UBI, US IT CASING, LINER AND CEMENTING RECORD SETTIN<l[)E!'tHMD SETTING .DEPTHTVD HOLË I OF> BOTTOM I OF> BOTTOM· SIZE Surface 109' Surface 109' 42" 29' 3872' 29' 2715' 16" 26' 7253' 26' 4445' 12-1/4" 7128' 7622' 4359' 4713' 8-1/2" 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: 2430' NSL, 3515' WEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 2546' NSL, 1760' EWL, SEC. 35, T12N, R11 E, UM Total Depth: 2551' NSL, 2022' EWL, SEC. 35, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583400 y- 5978154 Zone- ASP4 TPI: x- 588674 y- 5978331 Zone- ASP4 Total Depth: x- 588936 y- 5978339 Zone- ASP4 18. Directional Survey 0 Yes 181 No 22. 20" 13-3/8" 9-518" 215.5# 68# 47# 29# I 26# A-53 L-80 L-80 13CrBO 7" 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD Zero Other 5. Date Comp., Susp., or Aband. 3/5/2006 6. Date Spudded 5/16/2005 7. Date TD. Reached 5/25/2005 8. KB Elevation (ft): 78.9' 9. Plug Back Depth (MD+ TVD) 7640 + 4726 10. Total Depth (MD+TVD) 7640 + 4726 11. Depth where SSSV set NIA MD 19. Water depth, if offshore NIA MSL 24. TVD SIZE 4-1/2", 12.6#, L-80 3-1/2", 9.2#, L-80 ,JR. 2 5 2006 Co-mmission 25. 1 b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 205-052 305-346 13. API Number 50-029-23258-00-00 14. Well Name and Number: PBU L-214i 15. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff Ft Ft 16. Property Designation: ADL 028238 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 260 sx Arctic Set (Approx.) 957 sx Arcticset Lite, 605 sx 'G' 484 sx Class 'G', 491 sx Class 'G' Expanded Slotted Liner Screens DEPTH SET (MD) 6818' - 7077' 7077' - 7493' PACKER SET (MD) 7063' 7348' & 7469' DEPTH INTERVAL (MD) 6900' 6520' 6501' AMOUNT & KIND OF MATERIAL USED P&A wI 48.1 Bbls Cement and 32 Bbls Class 'G' Set EZSV Set Whipstock 26. Date First Production: Not on Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 24-HoUR RATE 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". PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA OIL-BSL GAs-McF WATER-BsL OIL-BsL None GAs-McF W A TER-BSL Form 10-407 Revised 12/2003 0 RIG I NÄrED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO OIL GRAVITy-API (CORR) RBDMS BFL APR 2 S 2006 (, 28. GEOLOGIC MARKEe NAME MD TVD Ugnu 4332' 2944' Ugnu MA 6541' 4025' Ugnu MB1 6616' 4064' Ugnu MB2 6761' 4141' Ugnu MC 6931' 4234' Schrader Bluff NA 7042' 4302' Schrader Bluff NB 7082' 4328' Schrader Bluff NC 7134' 4363' Schrader Bluff OA 7258' 4449' Schrader Bluff OBa 7355' 4518' Schrader Bluff OBb 7417' 4562' Schrader Bluff OBc 7496' 4620' Schrader Bluff OBd 7565' 4671' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 29. .ORMATION 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 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /f.fMLt.. ~ Title Technical Assistant Date Ol/./:JJ..{ /O(P PBU L-214i 205-052 305-346 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Scott Kolstad, 564-5347 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . Well: Field: API: Perm it: L-214A Prudhoe Bay Unit 50-029-23258-01-00 206-027 Accept: Spud: Release: Rig: 03/09/06 03/13/06 03/18/06 Nabors 9ES PRE-RIG WORK 03/04/06 PERFORM BOP TESTS. MU BHA WI 3.0" BDN. RIH. TAG AT 7085', PUH AND PAINT FLAG AT 7063'. PUH AND PARK AT 6983'. LOAD IA W/5 BBLS DIESEL AND PU TO 1500. HOLD PJSM. START BATCH MIXING CEMENT AT 23:45. JOB IN PROGRESS. 03/05/06 CEMENT SQUEEZE WI 50 BBLS OF SLB SQUEEZECRETE CEMENT. BATCH MIX AND PUMP 48.1 BBLS 14# PPG SQUEEZECRETE. DID NOT GET SQUEEZE. OVER FLUSH. ORDER OUT 50 BBLS CLASS G. PUMP 21 BBLS CLASS G CEMENT. PLACE 10 BBLS BELOW COLLAPSE. LAY IN 11 BBLS. HOLD 1100 PSI ON SQUEEZE 1 HR. CONTAMINATE AND CLEAN OUT CEMENT TO 6900'. CHASE OUT OF HOLE AT 70%. JOB IN PROGRESS. 03/06/06 POH CHASING BIOZAN AND CONTAMINATED CEMENT TO SURFACE. RBIH AND FP WELL TO 2500' WI DIESEL. CLOSEfTRAP 750 PSI ON WH RD. JOB COMPLETE. DRIFT TUBING WI 3.7" CENT TO 6881' SLM. RECOVERED CEMENT ON BAILER SHOE. MIT-T TO 2000#, PASSED. MIT-IA TO 3000#, PASSED. WELL LEFT SII. 03/07/06 CUT TUBING WITH SLB 3.65" POWER CUTTER AT 6818', CCL STOP DEPTH 6803.6'. CCL TO CUTTER 14.4'. DID NOT TAG TD. . . BP EXPLORATION OperationS~i....rnmary Report Page 1 . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/9/2006 Rig Release: 3/18/2006 Rig Number: Spud Date: 5/15/2005 End: 3/18/2006 Date From- To Hours Task Code NPT Phase DescriþtionofOperations 3/9/2006 00:00 - 02:00 2.00 MOB P PRE PJSM on rig move. Pull pits away from sub base. 02:00 - 03:00 1.00 MOB P PRE Rig down cattle chute. 03:00 - 04:00 1.00 MOB P PRE Unpin and lower derrick. 04:00 - 06:00 2.00 MOB P PRE Move sub off of V-112i. Position rig to leave V-Pad. , 06:00 - 09:00 3.00 MOB P PRE Move rig from V-Pad to L-Pad. 09:00 - 12:00 3.00 MOB P PRE Set matting boards and lay herculite. Spot rig on L-214Ai 12:00 - 13:00 1.00 MOB P PRE Position and spot mud complex. 13:00 - 14:00 1.00 MOB P PRE Raise derrick and cattle chute. Start taking on heated seawater. Accept rig for operations on L-214Ai @ 14:00 hr 3/9/2006. 14:00 - 17:00 3.00 RIGU P OECOMP Bridle down, pin blocks, secure bridle line in derrick. Remove beam over Iron Roughneck. Rig up floor. 17:00 - 18:30 1.50 KILL P DECOMP Rig up lines for pumping out freeze cap. Set cuttings tank by mud complex. 18:30 - 19:00 0.50 KILL IP OECOMP Hold Pre-Spud meeting with all personnel 19:00 - 20:30 1.50 DHB iP OECOMP Attempt to retrieve BPV. Ice above BPV several inches. Heat up wellhead. Retrieve BPV - OK. Tbg - 0 psi, Tbg ann - 0 psi. 20:30 - 23:00 2.50 KILL P DECOMP Fill and pressure test surtace lines to 3,500 psi - OK. Reverse circulate with 8.5 ppg, 180 deg seawater down tubing annulus and take diesel returns from tubing through choke @ 3 bpm, 310 psi. Shut down, wait 15 minutes, line up to pump down tubing. Displace annulus diesel @ 3 bpm, 135 psi. Recovered total of 150 bbls diesel plus 25 bbls of diesel/seawater mix. 23:00 - 00:00 1.00 KILL P DECOMP Circulate complete tubing and annulus volume with 8.5 ppg heated seawater @ 4 bpm, 180 psi. 3/10/2006 00:00 - 00:30 0.50 KILL P OECOMP Continue circulate with 8.5 ppg heated seawater. Shut down pumps, check for flow - no flow. 00:30 - 01 :00 0.50 OHB P OECOMP Install 2-way check valve with dry rod. Test same to 1,000 psi from below - OK. 01 :00 - 01 :30 0.50 OHB P OECOMP Blow down, rig down surtace lines. 01 :30 - 04:00 2.50 WHSUR P DECOMP Bleed off pressure from metal to metal seal void. Nipple down tree adapter flange and tree. 04:00 - 04:30 0.50 WHSUR P OECOMP Inspect tubing hanger threads. Function test tubing spool lock-down screws - OK. 04:30 - 12:00 7.50 BOPSUF P DECOMP Nipple up BOPE. Removed 13-5/8' x 11" adaptor spool from BOP. Install 13-5/8' x 13-5/8' mud cross spacer spool. 12:00 - 13:00 1.00 BOPSUP P OECOMP Rig up to test BOPE 13:00 - 16:30 3.50 BOPSUP P DECOMP Test BOPE to 250 psi low, 4,000 psi high. Annular to 250 psi low, 3,500 psi high. Accumulator Orill/Test. Witnessing of test waived by AOGCC rep Chuck Scheve. Test witnessed by BP WSL Brian Buzby, NAD TP Bill Bixby. 16:30 - 17:00 0.50 BOPSUF P OECOMP Rig down BOPE test equipment. 17:00 - 18:30 1.50 OHB P DECOMP Pull 2-way check valve with lubricator. 18:30 - 19:30 1.00 PULL P OECOMP Make up crossovers from tubing hanger to 4" drill pipe. Pull tubing hanger to rig floor with pick up weight of 1OOk. 19:30 - 20:00 0.50 PULL P OECOMP Circulate bottoms up @ 588 gpm, 575 psi. No gas or oil to surtace. 20:00 - 21 :00 1.00 PULL P OECOMP Finish rigging up Haliburton spool and tubing equipment. 21:00 - 21 :30 0.50 PULL P OECOMP Well U-tubing up tubing. Circulate bottoms up while mixing dry job. 21 :30 - 22:00 0.50 PULL P OECOMP Lay down drill pipe joint, crossovers. Lay down tubing hanger. 22:00 - 00:00 2.00 PULL P OECOMP POH laying down 4.5' 12.6# L-80 TCII tubing. Remove and count clamps, spooling up wire as pipe is pulled Printed: 3/20/2006 12:11 :50 PM . . BP EXPLORATION Operations Summary Report Page 2_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 3/9/2006 Rig Release: 3/18/2006 Rig Number: Spud Date: 5/15/2005 End: 3/18/2006 Date From - To Hours Task Code NPT Phase Description of Operations 3/11/2006 00:00 - 09:30 9.50 PULL P DECOMP Continue POH with 4.5" 12.6# L-80 TCII tubing from 6,400' to surface. Recovered total of 159 joints plus 21.89' of cut-off joint. Recovered all pins, clamps, and I Wire. Clean cut on tubing and I Wire. 09:30 - 11 :00 1.50 PULL P DECOMP Rig down tubing equipment, clear rig floor. 11 :00 - 11 :30 0.50 CLEAN P OECOMP Pick up Baker tools to rig floor. 11:30-12:00 0.50 WHSUR P DECOMP Install wear bushing. 12:00 - 15:00 3.00 CLEAN P OECOMP Pick up and RIH with 21 joints 4" HWDP, 60 joints 4" drill pipe to 2,529'. 15:00 - 16:30 1.50 CLEAN P DECOMP POH from 2,529' to surface. 16:30 - 17:00 0.50 CLEAN P DECOMP Pick up, make up Baker mill assembly BHA #1 for hole gauge run. 17:00 - 18:00 1.00 CLEAN P DECOMP Pick up 9 6-1/2" steal drill collars. 18:00 - 18:30 0.50 CLEAN P DECOMP RIH with BHA #1 on 4" HWOP to 1,026'. 18:30 - 19:00 0.50 CLEAN P DECOMP Service topdrive, traveling blocks, and drawworks. 19:00 - 23:30 4.50 CLEAN P DECOMP Continue RIH with BHA #1, picking up 4" drill pipe from 1,026' to 6,130'. 23:30 - 00:00 0.50 CLEAN P DECOMP Continue RIH with BHA #1, running 4" drill pipe out of derrick from 6,130" to 6,800'. 3/12/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Wash from 6,800' to top of cut tubing @ 6,818'. Circulate bottoms up @ 500 gpm, 1,760 psi, 60 rpm, 8k TO, PU - 150k, SO - 88k, RT - 115k, MW - 8.5 ppg. 01 :00 - 03:00 2.00 CLEAN P OECOMP POH with BHA #1 from 6,818' to 1,025'. 03:00 - 04:00 1.00 CLEAN P OECOMP Stand back HWDP and drill collars. 04:00 - 04:30 0.50 CLEAN P DECOMP Lay down BHA #1. 04:30 - 05:30 1.00 PXA P DECOMP PJSM with Baker and Schlumberger on setting WL bridge plug. Rig up SLB wireline and bridge plug. 05:30 - 08:30 3.00 PXA P DECOMP RIH with Baker bridge plug on wireline to plug and abandon L-214i. Set EZSV bridge plug @ 6,520'. POH with wireline, rig down same. 08:30 - 09:00 0.50 PXA P OECOMP Test EZSV bridge plug and 9-5/8" casing to 4,000 psi - 15 minutes - 0 pressure loss. 09:00 - 10:00 1.00 STWHIP P WEXIT PJSM on BHA. Pick up, make up whipstock BHA #2. 10:00 - 11 :00 1.00 STWHIP P WEXIT RIH with BHA #2 on 6-1/2" drill collars and 4" HWDP. 11 :00 - 12:00 1.00 STWHIP P WEXIT Shallow hole test MWO @ 565 gpm, 1,045 psi - OK. 12:00 - 16:00 4.00 STWHIP P WEXIT RIH with BHA #2 on 4" drill pipe from 1,025' to top of EZSV @ 6,523' drill pipe measurement. 16:00 - 16:30 0.50 STWHIP P WEXIT Orient 63 deg left of high side. PU - 140k, SO - 90k. Set down 20k to set bottom anchor. Pick up 10k over string weight to verify anchor set. Slack off and set down 35k to shear out. Whipstock set with top of window @ 6,501', bottom of window @ 6,518'. 16:30 - 17:00 0.50 STWHIP P WEXIT Displace well from 8.5 ppg seawater to 9.4 ppg LSNO mud @ 585 gpm, 1,320 psi. 17:00 - 00:00 7.00 STWHIP P WEXIT Mill 47# 9-518" casing window from 6,501' to 6,511 '. 588 gpm, 1,570 psi, 90 rpm, 6k TO OFF, 9k TO ON, 7k WOB. PU- 140k, SO - 90k. 3/13/2006 00:00 - 01:15 1.25 STWHIP P WEXIT Continue milling 47# 9-5/8" casing window from 6,511 to 6,518". 588 gpm, 1,570 psi, 90 rpm, 6k TO OFF, 9k TO ON, 7k WOB. PU -130k, SO - 90k. 01 :15 - 05:30 4.25 STWHIP P WEXIT Ori1l20' new hole from 6,518' to 6,538'. 588 gpm, 1,670 psi, 105 rpm, 8.5k TO. 05:30 - 07:00 1.50 STWHIP P WEXIT Pull above window and work back through several times. Printed: 312012006 12:11:50 PM - . Page 3. BP EXPLORATION Operªtions Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L-214 L-214A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From -±ours Task Code NPT 05:30 - 07:00 ! 1.50 STWHIP P Phase 3/13/2006 WEXIT 07:00 - 07:30 i 0.50 STWHIP P WEXIT 07:30 - 10:00 I 2.50 STWHIP P WEXIT I I 10:00 - 11 :00 I 1.00 STWHIP P WEXIT 11:00 -12:00 1.00 STWHIP P WEXIT I 12:00 - 13:00 1.00 STWHIP P WEXIT 13:00 - 15:00 2.00 STWHIP P WEXIT 15:00 - 15:30 0.50 STWHIP P WEXIT 15:30 - 16:00 0.50 STWHIP P WEXIT 16:00 - 18:00 2.00 STWHIP P WEXIT 18:00 - 18:30 0.50 STWHIP P WEXIT 18:30 - 19:00 0.50 STWHIP P WEXIT 19:00 - 00:00 5.00 DRILL P PROO1 3/14/2006 6.00 ORILL P PROD1 06:00 - 06:30 P PROO1 06:30 - 09:30 3.00 PROO1 09:30 - 10:00 0.50 ORILL P 10:00 - 11:00 1.00 DRILL P 11 :00 - 13:30 2.50 ORILL P 13:30 - 14:30 1.00 DRILL 14:30 - 17:00 2.50 ORILL P P PR001 RUNPRO 4.50 CASE P RUNPRD Start: 3/9/2006 Rig Release: 3/18/2006 Rig Number: Spud Date: 5/15/2005 End: 3/18/2006 Description of Operations Circulate high vis sweep surface to surface @ 585 gpm, 1,650 psi, 100 rpm, 9k TO. Perform FIT. TMD - 6,818', TVD - 4,012', PSI - 338 psi, MW- 9.4 ppg, EMW - 11.0 ppg. Monitor well, 9.4 ppg MW, pump dry job. POH from 6,500' to 380'. PJSM. Lay down 9 6-1/2" drill collars. Lay down window milling assembly BHA #2. Upper mill "in gauge" . Pick up ported sub and flush out BOP stack. PJSM on nuclear source. Pick up directional drilling BHA #3 RIH with BHA #3 on 7 stands 4" HWDP and 2 stands 4" drill pipe from 256' to 1,090'. Shallow hole test MWO @ 585 gpm, 1,060 psi - OK. Continue RIH with BHA #4 on 4" drill pipe from 1,090' to 6,440'. Service topdrive, crown section, traveling blocks, and drawworks. RIH 1 stand. Orient 63 deg left of high side, shut down pump and go through window without problem. PU - 140k, SO - 85k without pump @ window. Acquire slow pump rates. Oirectionally drill from 6,538' to 6,822' - 100% sliding. GPM- 585 gpm, PSI OFF - 2,010 psi, PSI ON - 2,150 psi, RPM - 6 rpm, TO OFF - 7.5k, WOB - 5k, PU - 140k, SO - 85k, 109k. AST - 1.51 hrs, ART - 0.0 hrs. Backream e survey every 30'. Directionally drill from 6,822' to 7,652' (TD PM - 585 gpm, PSI OFF - 2,330 psi, PSI ON - 2,590 ., RPM - 80 rpm, TO OFF - 9.3k, TO ON - 10.5k, WOB -10k, PU - 153k, SO - 90k, RT - 122k. Backream each s d, survey every 30'. AST- 1.92, ART - 2.28 Circulate an open ho olume at 585 gpm, 100 rpm, 2,400 psi. MW in - 9.4 ,W out - 9.4 ppg. MAO pass I e well from TO to 6,520' - 585 gpm, 2,380 psi, 70 rpm, - 9.5k, PU - 153k, SO - 86k, RT - 122k. Orie and pull the BHA through the window to 6,440'. culate a high visc sweep from surface to surface - 585 gpm, 2,170 psi, 70 rpm, TO - 8.5k, PU - 150k, SO - 75k, MW in - 9.4 ppg, MW out - 9.4 ppg. Monitor the well - stable. POH standing back 4" DP from , 0' to the top of the HWOP at 902'. Slip a cut 81' of drilling line. Hold PJS or LD BHA#3 and removal of nuclear source. Stand back th " HWOP. LO the jar stand, xo, 2 x nm flex dc's. Remove nuc r source and LO the AON, MWO, ARC, nm stab, motor and bit. .5" OSX147gvw bit graded: 1-1-CT-A-X-I-BT-TO. Clear and clean the floor. Func· the blind/shear rams. RU the casing handling tools to run "26# L-80 BTC liner. Bring cement head to the rig floor. Hold PJSM. PU and RIH with 7" 26# L-80 liner. Checked the floats after running in the hole with the shoe ct - holding. Each connection of the shoe tract was Bakerloc'd. tinue RIH with 7" Liner utilizing BOL 2000 NM thread lubricant Printed: 312012006 12: 11 :50 PM . ~... ., Ii.. .. ffi.R\,A , u. ¡ Œ;.· rm1ut"\. Ilr¡r=a . mfji\ r. I.·. .'. fA.\,.@..'.1.1.Q . ·ri\..·.ll i i¡lll ·1 ¡. lill.· !!J.\¡¡ fU'_\'il\\llJ\ , L LJ ..l ¡ ~ . Lr\..\ L!-::J LrJ @ Uu Lru . ~"IASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: PBU L-214i Sundry Number: 305-346 Dear Mr. Wesley: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, ,or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Encl. c. ... Cf/¡ 1/ 7 -05 . WGrr . STATE OF ALASKA D~'17(S ALASKA OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25,280 H 111 2- ¡)oÇ" ~ ; V 1. Type of Request: aD Abandon / o Alter Casing o Change Approved Program o Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate 0 Other o Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: D Development D Exploratory D Stratigraphic IBI Service ./ 5. Permit To Drill Number 205-052 - 6. API Number: 50- 029-23258-00-00 /' 99519-6612 11. Total Depth MD (ft): 7640 Casing Structural Conductor Surface Intermediate Production Liner 9. Well Name and Number: PBU L-214i / 10. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff PRESENT WELL CONDITION SUMMARY Total Depth rvD (ft): I Effective Depth MD (ft): I Effective Depth rvD (ft): 4726 7640 4726 Length Size MD rvD 78.9' 8. Property Designation: ADL 028238 Plugs (measured): None Burst Junk (measured): None Collapse 109' 20" 109' 109' 3843' 13-318" 3872' / 2715' 4930 2270 7227' 9-5/8" 7253' / 4445' 6870 4760 494' 7· 7128' - 7622' / 4359' - 4713' 7240 5410 Perforation Depth MD (ft): I Perforation Depth rvD (ft): I Tubing Size: 7257' - 7612' 4448' - 4705' 4-112', 12.6# x 3-112',9.2# Packers and SSSV Type: 7· x 3-1/2· WTFD UPTH packer; 7" x 3-1/2" WTFD Hellcat packer; 9-5/8" x 4-1/2" WTFD Hellcat packer 13. Well Class after proposed work: / D Exploratory D Development IBI Service Tubing Grade: Tubing MD (ft): L-80 7493' Packers and SSSV MD (ft): 7469', 7348', 7063' 12. Attachments: IBI Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: Novemb4")005 Date:'" 15. Well Status after proposed work: DOil DGas D WAG D GINJ / 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~ve ~~Sl, / Title Senior Drilling Engineer SignatureÆ'u-e ~~ ¿.t--- Phone 564-5153 Commission Use Only D Plugged DWINJ IBI Abandoned D WDSPL Contact Brandon Peltier, 564-5912 Scott Kolstad, 564-5347 / ~.- Prepared By NamelNumber: Date / ;f¢ f/ (1':::> Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: :~5" 34V D Plug Integrity urBOP Test D Mechanical Integrity Test D Location Clearance Other: T~ to't· 'RBOMS 8Ft I) '7 2005 COMMISSIONER APPROVEO BY THE COMMISSION Date 11/1"j;;S s,tmi~/D;licate , 1N^~ '" . . Obp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Scott Kolstad Drilling Engineer Date: October 26, 2005 Re: Prep L-214i for rotary sidetrack Sundry approval is requested to prepare L-214i for a sidetrack. L-214i was drilled in July of 2005 and completed with a technology trial of expandable sand screens and zonal isolation packers. The completion was run and after the production packers were set the tubing below the upper production tubing buckled, restricting well bore access. As a result, injection ,../ monitoring and control is not possible. A replacement sidetrack with the conventional injector isolation packers is planned for early December. The sidetrack, L-214Ai, is scheduled to be drilled by Nabors 9ES on or about December 5th, 2005. The plan calls for existing zones to be squeezed and the sidetrack drilled from a window to be milled above the upper production packer. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram ofthe existing well is attached for reference. Pre-RÌI~ Work The pre rig work is slated to begin about November 9,2005. 1) Complete integrity testing. a. PPPOT T and Casing. b. Function test casin-& and tubing LDS. / 2) Brush and flush tubing to~pr~pare for rerunning. 3) RU coil tubing. Pump" 25 bbls cement to shut-off existing injection. a. 20 bbls tubing7casing volume plus 5 bbls excess. b. TOC at -7128' MD ,/ 4) Pressure test tubing and IA. 5) Chemically cut tubing at ± 7,048'. / 6) Circulate well bore and freeze protect. 7) Remove flow line, remove well house, and level pad. RÌI~ Work 1) MIRU 9ES. / " 2) ND tree. NU BOPE and test. 3) Pull the 4 W' tubing from cut at ± 7,048'. LD tubing. Visually inspect to rerun. .4) RU eline. Run GR/JB. Set 9 5/8" CIBP at ± 6,551'. ../ .rÎ· Iv ~ 4v;;) PU whipstock and RIH on DP. Orient and set bottom trip whipstock on CIBP. MS. -'6) Displace to milling fluid. Lvt.'I)\'VV"'(' 7) Mill window at ± 6,528'. 8) TOH. PU 8 W' drilling BHA. 9) RIH to window, drill 20' into formation. Perform FIT. 10) Drill replacement sidetrack to TD at ± 7,700' MD. Circulate and condition hole. POOH. 11) Run 7" 26# L-80 solid liner and cement. Test liner. 12) Perforate 7" liner in the Schrader Bluff OA, OBa, OBb, OBd sands. 13) Run 4 Y2" 12.6# L-80 x 3 W' 9.2# L-80 tubing with three packers and water flood mandrels to ±7,370'. 14) ND BOPE, NU tree. 15) Freeze protect well and RDMO. Post-Ri2 Work 1) Install well house and production flow line. 2) Start i~ection. Scott Kolstad Drilling Engineer 564-5347 TREE = WELLHF~D = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum 1VD = 4-1/16" cm FMC NA 78.9' 50.4' 300' 63 @ 5878' xxxx' xxxx'SS l 13-3/8" CSG, 68#, L-80,1D = 12.415" H [Minimum ID = 2.813" 3-1/2" HES X NIPPLE I 4-1/2" TBG JOINT W/ RA MARKER 19-5/8", SHORT JTW/ RA TAG 14-1/2" BKR, CMD SLOG SLEEVE, 10 = 3.813" 14-1/2" TBG, 12.6#, L-BO, .0152 bpf, ID = 3.958" 19-5/8" CSG, 47#, L-BO, .0732 bpf, 10 = 8.681" Ii I 7" WTFD EXP ZONAL ISOLATION PKR . 3872' H 6405' H 6525' H 7032' H 7077' 7253' H 7314' I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H 7493' \ EXPANDABLE SLOTTED SCREEN SUMMARY REF LOG: SWS USIT 5/31/05 ANGLE AT TOP PERF: 45° @ 7260' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 7" ESS 7257-7314 Open 05/30/05 7" ESS 7359-7434 Open 05/30/05 7" ESS 7554-7612 Open 05/30/05 I 7" WTFD EXP ZONAL ISOLATION PKR H 7436' I 7" CSG,e 13Cr, ID = 6.059" I~ 7622' DATE REV BY COMMENTS 06/03/05 TA ORIGINAL COMPLETION 08/02/05 RWLITLH GL V C/O " L-214i . DRLG DRAFT AFervNOTES: GLM'S@STA#1-#4ARE _12" X 1" KBGs, WHICH ARE WATERFLOOD MANDRELS. - - ~ I 1017' H 13-3/8" TAM PORT COLLAR I 6938' H 4-1/2" HES X NIP, ID = 3.813" I ~ ~ - WA TERFLOOD MANORELS ST MO 1VD DEV TYPE VLV LATCH PORT OATE 5 6958 4251 55 MMG-W OMY RK 0 07/27/05 ~ ~ ~ 4 7257 4448 45 KBG DMY BK 0 06/03/05 I ~ r 3 7282 4466 45 KBG DMY BK 0 06/03/05 - 2 7381 4536 44 KBG DMY BK 0 06/03/05 I I I 1 7407 4555 44 KBG DMY BK 0 06/03/05 ~~-II 7:::' I :5~:~n~:::~::::'~D=3933' ~·%.;i~ ~&;~~;\~~ ::::: _~ :_:~.::.':~::2L:·D=6~ r- --.I., ~ -, : ---¡ t/l 7309' H 3-1/2"HESXNIP,ID=2.813" I I -~. I 7320' H 3.5" WTFD SNGL GAUGE MANDREL,ID = 2.98" 7348' H7"X3-1/2" WTFD HELLCAT PKR, 10=2.992" I - --L ~ I ~ t~ i 7433' I 7438' H 3-1/2" HES X NIP, 10 = 2.813" I 13.5" WTFD DUAL GAUGE MANOREL,ID = 2.98" r /1 í I I \ I \·..1 \.-. 1 1 7" WTFD EXP ZONAL ISOLATION PKR 7,469' H 7" X 3-1/2" WTFD UPTH PKR, ID = 2.98" I 7485' 7493' H 3-1/2" HES X NIP, 10 = 2.813" I H 3-1/2" WLEG, 10 = 2.98" I I 1 I I I -'\ I .Jlb OA TE REV BY ORION UNIT WELL: L-214i PERMIT No: 205-052 API No: 50-029-23258-00 SEC 34, T12N, R11 E, 2430'f=SL-8, 3515' FEL COMMENTS BP Exploration (Alaska) 13-3/8" CSG, 68#, L-80,10=12.415" 1M 4-1/2" TBG JOINT W/ RA 9-5/8", SHORT JT W/ SLOG SLEEVE, ID .0152 bpf, Rig 47#, L-SO, .0732 bpf, 10 '" P&A WTFO EXP ZONAL ISOLATION PKR 9.2#, L-80, .0087 WTFO EXP ZONAL ISOLATiON PKR EXPANDABLE SLOTTED SCREEN SUMI'v1ARY REF LOG: SWS usrr ANGLE AT TOP PERF: 45° @ 7260' Note: Refer to Production DB for historical SIZE Opn/Sqz . 7" ESS 7257-7314 7" ESS 7359- 7 434 T' ESS 7554-7612 Open Open ¡ 7" CSG, 29#, 13Cr, 10 = 6.059" REV BY COMMENTS TA RWLffLH GL V C/O 6405' datå DATE 05/30/05 05/30105 05/30/05 ~ . 8T 5 6958 7257 7282 7381 --' I:) __ I I 7077' 7128' TVD 4251 4448 4466· KBG OMY BK 7469' 7" X DA TE REV BY 34, t . .. !II I i X I fK~_ -------------- -~ ~----------------- DATE 06103/05 REV T A ORIGINAL COM PLETtON RWUTLH GL V C/O Proposed Completion \ I I I I o REV ---I Milled Window x Packer Water Flood Packer Rood Mandrel Packer 3- 112" 7" CSG, 26#, L-BO BTC-MOD, 10 '" 12.415" TC-II, 10 SEe 34, SF 1 MEMORANDUM · State of AlaSkØ Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'R~(11/110~ DATE: Monday, August IS, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-214 PRUDHOE BAY UN ORIN L-214 ~..............,." C\~........................" " ~. . . . .... ... '. . FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN ORIN L-214 Insp Num: mitJJ050810114819 Rei Insp Num: API Well Number: 50-029-23258-00-00 Permit Number: 205-052-0 Inspector Name: Jeff Jones Inspection Date: 8/6/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I L-214 ¡Type Inj. w TVD 4316 IA 320 1620 1550 i 1530 P.T. I 2050520 I TypeTest SPT Test psi 1079 OA I 0 0 0 0 Interval INITAL PIF P Tubing I 500 500 500 500 Notes: 3 BBLS 60/40 methanol pumped. I well house inspected, no exceptions noted. Monday, August IS, 2005 Page I of I 13-3/8" CSG, 68#, L-80,ID= 12.415" 1-1 3872' ~ . ST MD TVD 5 6958 4251 6405' I ~~ _~ ~2 ;~~~ :::: 7381 4536 6525' I I I 1 7407 4555 ::::: ~- .~I 7043' 1-1 4-1/2"HESXNIP,10=3.813" 1 ~~ 7063' I 19-5/8"X4-1/2"WTFDHELLCATPKR,10=3.933" 1'-518" CSG, 47#, L-80, .0732 bpI, ID· 8.681" H 7253' ~i. ~ 7077' 6'" 7128' : ~ :~ 7309' I ~. ~. L I 7320' 1-1 3.5" WTFD SNGL GAUGE MANDREL,ID = 2.98" 1-1 7314' 7348' H 7"X3-1/2" WTFD HELLCAT PKR, ID=2.992" I , 13-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" l-l 7493' ~--1 ~~ ~ 7433' H 3-1/2"HESXNIP,D·2.813" I H 7436' ~ ::::::¡; t '. !.'. I 7473486'9' 3.5" WTFDDUAL GAUGE MANDREL,ID = 2.98" ''-z ~ 1-1 7"X3-1/2"WTFDUPTHPKR, ID= 2.98" I I TR~ = 4-1/16" CrN .'vVELLHEA D = .. ..... FMC . ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Oatum MD = Oatum TVD = NA 78.9' 50.4' 300' 63 @ 5878' xxxx' xxxx'SS /Minimum ID = 2.813" 3-1/2" HES X NIPPLE /4-1/2" TBG JOINTW/ RA MARKER 19-5/8", SHORT JTW/ RA TAG 14-1/2" BKR, CMO SLOG SLEEVE, 10 = 3.813" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 17" WTFD EXPZONAL ISOLATION PKR I 7" WTFD EXP ZONAL ISOLATION PKR 1-1 1-1 H 1-1 EXPANDABLE SLOTTED SCREEN SUMMARY REF LOG: SWS USIT 5/31/05 ANGLE AT TOP ÆRF: 45° @ 7260' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 7" ESS 7257-7314 Open 05/30/05 7" ESS 7359- 7 434 Open 05/30/05 7" ESS 7554-7612 Open 05/30/05 I 7" CSG, 29#, 13Cr, ID = 6.059" H 7622' DA TE REV BY COMMENTS 06/03/05 T A ORIGINAL COM PLETION 08/02/05 RWLITLH GL V C/O L-214i . DRLG DRAFT - - =-I 1017' I 6938' r~~: I ~I I I I I I SAFETY NOTES: GLM'S @ STA#1-#4 ARE 3-1/2" X 1" KBGs, WHICH ARE W ATERFLOOD MANDRELS. H 13-3/8" TAM PORT COLLAR I H 4-1/2"HESXNIP,ID=3.813" I WA TERFLOOD MANORELS DEV lYÆ VLV LATCH 55 MMG-W DMY RK 45 KBG DMY BK 45 KBG DMY BK 44 KBG DMY BK 44 KBG DMY BK PORT DATE o 07/27/05 o 06/03/05 o 06/03/05 o 06/03/05 o 06/03/05 1-1 4-1/2" X 3-1/2" XO, ID = 2.992" I I H 9-5/8" X 7" BKR MLZXP, L TP, ID = 6.059" 3-1/2" HES X NIP, ID = 2.813" I 7485' 1-1 3-1/2" HES X NIP, ID = 2.813" I 7493' 1-1 3-1/2" WLEG, ID = 2.98" I 7519' I I 7" WTFD EXP ZONAL ISOLATION PKR I I I L- _I DA TE REV BY COMMENTS ORION UNrr WELL: L-214i PERMrr No: 205-052 API No: 50-029-23258-00 SEe 34, T12N, R11 E, 2430' FSL & 3515' FEL BP Exploration (Alaska) a STATE OF ALASKA . 0ECEIVED ALAS~ AND GAS CONSERVATION COM lOr-! " _ « . WELL COMPLETION OR RECOMPLETION REPORT AND LOA\JG 0 8 2005 R~yiled: O8I08lO~, Put on, Injection Alaska uil ðl Gas Cons. l;ommisslOn 1 b. WelÄfrL'Hbrsne o Developmen' 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 205-052 13. API Number 50- 029-23258-00-00 14. Well Name and Number: PBU L-214i 15. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff " No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 181 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: DIR / GR, DIR I GR I RES / AZI-DEN I NEU I PWD, LWD: DIR I GR I RES / AZI-DEN I NEU I Acoustic Caliper, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HoLË ., OP BoTTOM , OP BoTTOM SIZE Surface 109' Surface 109' 42" 29' 3872' 29' 2715' 16" 26' 7253' 26' 4445' 12-1/4" 7128' 7622' 4359' 4713' 8-1/2" 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: 2430' NSL, 3515' WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2546' NSL, 1760' EWL, SEC. 35, T12N, R11E, UM Total Depth: 2551' NSL, 2022' EWL, SEC. 35, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583400 y- _ 5978154 Zone- AS~ TPI: x- 588674 y- 5978331 Zone- ASP4 Total Depth: x- 588936 y- 5978339 Zone- ASP4 u_________ ~__________~_ __________________ 18. Directional Survey 181 Yes 0 No 22. CASING SIZE 20" 13-3/8" 9-5/8" 7" WT. PER Fr. 215.5# 68# 47# 29# I 26# GRADË A-53 L-80 L-80 13Cr80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 7" Expanded Slotted Sections MD TVD MD TVD 7257' - 7314' 4448' - 4489' 7359' - 7434' 4521' - 4575' 7554' -7612' 4663' - 4705' One Other 5. Date Comp., Susp., or Aband. 6/3/2005 6. Date Spudded 5/16/2005 7. Date T.D. Reached 5/25/2005 8. KB Elevation (ft): 78.9' 9. Plug Back Depth (MD+ TVD) 7640 + 4726 10. Total Depth (MD+TVD) 7640 + 4726 11. Depth where SSSV set (Nipple) 6938' MD 19. Water depth, if offshore N/ A MSL Ft Ft 16. Property Designation: ADL 028238 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) UBI, US IT CEMENTING.·.RËCORP 260 sx Arctic Set (Approx.) 957 sx Arcticset Lite, 605 sx 'G' 484 sx Class 'G', 491 sx Class 'G' Expanded Slotted Liner Screens AMOUNT PULLED 24. TUBINGRËOORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 7077' 7063' 3-1/2",9.2#, L-80 7077' - 7493' 7348' & 7469' 25. ACID, FRAcrÛAE,CEMËNTSQÛEezE,ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect wI 245 Bbls of Diesel 26. Date First Production: July 14, 2005 bate of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 24-HoUR RATE 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". PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BBL GAs-McF WATER-BBL OIL -BBL None Form 10-407 Revised 12/2003 GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) R8DMS BFl AUG 1 1 1005 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER. 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Ugnu 4332' 2944' None Ugnu MA 6541' 4025' 6761' 4141' RECEIVED AUG 0 8 Z005 Ugnu MB1 Ugnu MB2 Ugnu MC 6616' 4064' 6931' 4234' A'ª;;ka Oil ¿?; Gormn¡Z;1i:cm Schrader Bluff NA 7042' 4302' Schrader Bluff NB 7082' 4328' Schrader Bluff NC 7134' 4363' Schrader Bluff OA 7258' 4449' Schrader Bluff OBa 7355' 4518' Schrader Bluff OBb 7417' 4562' Schrader Bluff OBc 7496' 4620' Schrader Bluff OBd 7565' 4671' 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 ~nlt. A tJ /J (J¡) Ttl T h· I A . t t D t 08-08-05 Terrie Hubble /' 1.0 v~ ~ i e ec mca SSIS an a e PBU L-214i 205-052 Prepared By NamelNumber: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tirpack, 564-4166 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 Oisposal, 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 1 0-407 Revised 12/2003 Submit Original Only MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation CommissIOn TO: ~~~ S~:~!visor~117 ~cß ¡ 0 5 DATE: Wednesday, July 27,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-214 PRUDHOE BAY UN ORIN L-214 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv -:f.&e- Comm Well Name: PRUDHOE BAY UN ORIN L-214 Insp Num: mitCS050724094011 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-23258-00-00 Permit Number: 205-052-0 Inspector Name: Chuck Scheve Inspection Date: 7/23/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-214 IType Inj. I N I TVD 4316 I IA 320 I I I· i OA P.T. I 2050520 ¡TypeTest r SPT I Test psi 1079 80 . I ! Interval INITAL P/F F Tubing 50 Notes: Attempt to pressure test IA failed. Tubing and IA pressure tracked and an injection rate of 1.5 bbl per minute at 1220 psi was established. The well had been on water injection just prior to this test. Wednesday, July 27,2005 Page 1 of 1 L-2I4 (PTD 2050520) Failed MITIA ch Hello all. An MITIA failed on injection well L-214 (PTD 2050520) on 7/23/05. After reviewing the well history, we determined the shear-style gas lift valve in the top gas lift mandrel is sheared. Current plan is to replace the sheared GL V with a dummy GL V and repeat the MITIA. Attached is a wellbore schematic and the MIT form. Please call if you have any questions or prefer some other plan. «L-214.ZIP» «MIT PBU L-214 07-23-05.xls» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: L-214.ZIP Content- Type: application/x -zip-compressed Content-Encoding: base64 PBU L-214 Content-Description: MIT PBU L-214 07-23-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of! 7/26/2005 9: II AM L-214i G DRAFT ~NOTES: GLM'S@STA#1-#4ARE /2" X 1" KBGs, WHICH ARE WATERFLOOO MANORELS. TREE = WELLHEA D = ACTUA TOR = KB. ELEV '" BF. ELEV = KOP= tvlax Angle '" __ _n~n^ ~~_ Datum MD == Datum ND == 4-1/16" CIW FMC NA 78.9' 50.4' 300' 63 @ 5878' xxxx' xxxx' SS . =, I 11 13-318" TAM PORT COLLAR Ii 4-1/2" HES X NIP, ID == 3.813" - - 1017' 6938' 13-3/8" CSG, 68#, L-80,ID == 12.415"--{ I Minimum ID = 2.813" 3-1/2" H ES X NIPPLE 14-1/2" TBG JOINTW/ RA MARKER ~ WA TERFLOOD MANDRELS DEV TYÆ VLV LATCH 55° MMG-W SHR RKP 45° KBG DUM BK 45° KBG DUM BK 44° KBG DUM BK 44° KBG DUM BK 3872' . ST 5 4 3 2 1 ND 4251 4448 4466 4536 4555 MD 6958 7257 7282 7381 7407 PORT DATE YES 06/03/05 NO 06/03/05 NO 06/03/05 NO 06/03/05 NO 06/03/05 ~L ~II ~ ~ I~<g I H 6405' 19-5/8", SHORT JT WI RA TAG 1-1 H 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID == 3.958" H 6525' 14-1/2" BKR, CMD SLDG SLEEVE, ID'" 3.813" 7032' H 4-1/2" HES X NIP, ID'" 3.813" I 7043' ~ -~ ~~ 7077' II 9-5/8" X 4-1/2" WTFD HELLCAT PKR, ID '" I í 3.933" 7063' 19-5/8" CSG, 47#, L-80, .0732 bpf, ID == 8.681" 1-1 4-1/2" X 3-1/2" XO, ID = 2.992" I I H H H I 9-5/8" X 7" BKR MLZXP, L TP, ID == 6.059" I 7077' 7253' 7128' 3-1/2"HESXNIP,ID==2.813" 7309' 3.5" WTFD SNGL GAUGE MANDREL,ID == 2.98" 7320' I 7" WTFD EXP ZONAL ISOLATION PKR H 7314' · L 7348' ~[ 7"X3-1/2" WTFD HELLCAT PKR, ID=2.992"I 13-1/2" TBG, 9.2#, L-80, .0087 bpf, ID == 2.992" H 7493' ~g~ N II ~I ::::¡ I I I ~ 7433' H 3-1/2" HES X NIP, ID = 2.813" I 7438' 'I 3.5" WTFD DUAL GAUGE MANDREl,lD = í 2.98" 17" WTFD EXPZONAL ISOLATION PKR H 7436' 7469' I! 7" X 3-1/2" WTFD UPTH PKR, 10 == 2.98" I EXPANDABLE SLOTTED SCREEN SUMMARY REF LOG: SWS USIT 5/31105 ANGLE AT TOP ÆRF: 45° @ 7260' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 7" ESS 7257-7314 Open 05/30/05 7" ESS 7359-7434 Open 05/30/05 7" ESS 7554-7612 Open 05/30/05 7485' H 3-1/2"HESXNIP,ID=2.813" I 7493' H 3-1/2" WLEG, ID = 2.98" I r 7519' I! 7" WTFD EXP ZONAL ISOLATION PKR '- -' 17" CSG, 29#, 130, 10 = 6.059" H 7622' DATE 04/22/05 06/03/05 REV BY RBT TA COMMENTS PROPOSED COMPLETION ORIGINAL COMPLETION DATE REV BY COMMENTS ORION UNIT WELL: L-214í ÆRMrf No: 205-052 API No: 50-029-23258-00 SEC 34, T12N, R11 E, 2430' FSL & 3515' FEL BP Exploration (Alas ka) . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I Pad-l 07/23/05 Joe Anders Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. wellL-214 Type In¡. N TVD I 4,316' TUbingl 501 7501 Interval P.T.D. 2050520 Type test P Test psi 1,500 Casing 320 1,220 P/F F Notes: MIT-IA failed, leak rate 1.5 BPM @ 1220 psi. Shear-style gas lift valve had been sheared, plan to replace valve and re-MITIA. weill Type Inj. I TVD I I TUb~ngl I Interval I P.T.D. Type test Test psi Casing P/F Notes: weill Type In¡. I TVD I I TUb~ngl Ilnterval P.T.D. Type test Test psi Casing P/F Notes: weill Type In¡.1 I TVD I I TUb~ngl I Interval I P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj. TVD I TUb~ng I Interval I P.T.D. Type test Test psi Casing P/F Notes: Test Details: Never obtained test pressure. llR = 1.5 BPM @ 1220 psi. w/1 0 bbls of 60/40 meth water. Well was shut-in for facility repairs. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2005-0723_MIT _PBU_L-214_cs.xls . STATEOFALASKA _ ALASKA AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended IBI WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: DIR I GR, DIR I GR I RES I AZI-DEN I NEU I PWD, LWD: DIR I GR I RES I AZI-DEN I NEU I Acoustic Caliper, CASING, LINER AND CEMENTING RECORD SrnlNGOEPTH MD SETTING DEPTHT\IÐ HoLE lOP BOTTOM 'lOP BOTTOM SIZE Surface 109' Surface 109' 42" 29' 3872' 29' 2715' 16" 26' 7253' 26' 4445' 12-1/4" 7128' 7622' 4359' 4713' 8-1/2" 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: 2430' NSL, 3515'WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2546' NSL, 1760' EWL, SEC. 35, T12N, R11E, UM Total Depth: 2551' NSL, 2022' EWL, SEC. 35, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583400 y- 5978154 Zone- ASP4 TPI: x- 588674 y- 5978331 Zone- ASP4 Total Depth: x- 588936 y- 5978339 Zone- ASP4 18. Directional Survey IBI Yes 0 No 22. CASING SIZE 20" 215.5# 68# 47# 29# I 26# A-53 L-80 L-80 13Cr80 13-3/8" 9-518" 7" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 7" Expanded Slotted Sections MD TVD MD TVD 7257' - 7314' 4448' - 4489' 7359' - 7434' 4521' - 4575' 7554' - 7612' 4663' - 4705' 26. Date First Production: Not on Injection Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""'" One Other 5. Date Comp., Susp., or Aband. 6/3/2005 6. Date Spudded 5/16/2005 7. Date T.D. Reached 5/25/2005 8. KB Elevation (ft): 78.9' 9. Plug Back Depth (MD+ TVD) 7640 + 4726 10. Total Depth (MD+TVD) 7640 + 4726 11. Depth where SSSV set (Nipple) 6938' MD 19. Water depth, if offshore N/A MSL 24. SIZE 4-1/2", 12.6#, L-80 3-1/2", 9.2#, L-80 1b. Well Class: o Development 0 Exploratory o Stratigraphic IBI Service 12. Permit to Drill Number 205-052 13. API Number 50- 029-23258-00-00 14. Well Name and Number: PBU L-214i 15. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff Ft Ft 16. Property Designation: ADL 028238 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) UBI, US IT 260 sx Arctic Set (Approx.) 957 sx Arcticset Lite, 605 sx 'G' 484 sx Class 'G', 491 sx Class 'G' Expanded Slotted Liner Screens TUSING RecORD DEPTH SET (MD) 7077' 7077' - 7493' PACKER SET (MD) 7063' 7348' & 7469' 25. DEPTH INTERVAL (MD) 2500' AMOUNT & KIND OF MATERIAL USED Freeze Protect wI 245 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-BSl GAs-McF WATER-Bsl Oll-Bsl 27. GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) 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". rn"r" ~,iñ-;T" I tj-1JI'\!¡', ILl: I.Un .... None.I·,. _ IJI;. D TE, . ¡. ;6/3P-í .,r~~_\ Form 10-407 Revised 12/2003 RBDMS BFl JUl 1 3 2005 CONTINUED ON REVERSE SIDE GF 28. GEOLOGIC MARKERS. 29. .RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD rvD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4332' 2944' None Ugnu MA 6541' 4025' Ugnu MB1 6616' 4064' Ugnu MB2 6761' 4141' Ugnu MC 6931' 4234' Schrader Bluff NA 7042' 4302' Schrader Bluff NB 7082' 4328' Schrader Bluff NC 7134' 4363' Schrader Bluff OA 7258' 4449' Schrader Bluff OBa 7355' 4518' Schrader Bluff OBb 7417' 4562' Schrader Bluff OBc 7496' 4620' Schrader Bluff OBd 7565' 4671' 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~ O.J ~ Title Technical Assistant Date D7 ~Öl-OS" PBU L-214i 205-052 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tirpack, 564-4166 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 Oisposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only (psi 11.01 (ppg) ,984 (psi 14.03 (ppg) 2,425 (psi) 10.50 (ppg) . . Printed; 6/6/2005 11 :23:49 AM (psi 740 (psi 347 (psi (ppg) 8.80 (ppg) 9.00 (ppg) t 2,722.0 (ft) 4,444.0 (ft) (ft) 3,907.0 (ft) 7,252.0 (f Legal Name L-214 Common Name: L-214 5/14/2005 LOT 5/21/2005 LOT 5/25/2005 FIT Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 5/14/2005 6/3/2005 Spud Date: 5/15/2005 End: 5/14/2005 23:00 - 00:00 1.00 MOB P PRE Move Pits to L-214i. Lower the derrick and prep to move off of L-124. 5/15/2005 00:00 - 04:00 4.00 MOB P PRE Move sub to L-214i. 04:00 - 08:00 4.00 RIGU P PRE Lay pit liner around cellar area. Set the wellhead equipment in cellar area. Ready the diverter spool and lay the diverter line. Position the sub over L-214i. Close the cellar doors and center the rig on L-214i. RU sub and pits on L-214i. Rig accepted 0800. 08:00 - 09:00 1.00 RIGU P PRE Spot the pits and level. RU service lines. 09:00 - 10:00 1.00 RIGU P PRE PJSM. Inspect and raise the derrick. 10:00 - 12:00 2.00 RIGU P PRE Raise the pipe chute, bridle down the blocks and pin the top drive. Hang back the bridle lines. 12:00 - 17:00 5.00 RIGU P PRE Change out the drip pan nipple. RU the 20" riser and diverter system. 17:00 - 18:00 1.00 RIGU P PRE RU the rig floor. 18:00 - 19:00 1.00 DRILL P SURF MU 16" bit, near bit stabilizer and 1 stand of 5" HWDP. 19:00 - 20:00 1.00 DRILL P SURF Orill ice from the conductor - 470 gpm, 200 psi. 20:00 - 20:30 0.50 DRILL P SURF LD 16" bit and stabilizer. Stand back the stand of 5" HWDP. 20:30 - 00:00 3.50 DRILL P SURF PU 5" DP and stand back 37 standsihthe derrick. Hold Pre-spud meeting with oncoming crew 5/16/2005 00:00 - 01 :00 1.00 DRILL P SURF PU HWDP and stand back in the derrick. 01 :00 - 02:00 1.00 DRILL P SURF Bring remaining BHA items to the rig floor. 02:00 - 03:00 1.00 ORILL P SURF MU 16" MXC-1 Hughes bit, 9-5/8" motor, lead collar, stabilizer, MWO and RIH. 03:00 - 03:15 0.25 BOPSUP P SURF Function test the diverter system - good. Witness of the test was waived by Jeff Jones of the AOGCC. 03:15 - 04:00 0.75 ORILL P SURF RU SLB E-line to run gyro. 04:00 - 04:30 0.50 DRILL P SURF PU xo, stabilizer and 1 x HWOP. 04:30 - 05:30 1.00 ORILL P SURF Spud the well. Drill out conductor shoe and new formation to 150' - 680 gpm, 350 psi, 50 rpm. 05:30 - 07:00 1.50 DRILL N RREP SURF Cuttings tank plugged off causing the drag chain to fail. Remove cuttings from the drag line and repair drag chain. Adjust drag chain tension. 07:00 - 08:30 1.50 DRILL P SURF Drill ahead to 173' - 600 gpm, 480 psi, 50 rpm. 08:30 - 09:00 0.50 ORILL P SURF PU UBHO sub and 3 x nm drill collars. Orient UBHO sub with motor. 09:00 - 09:30 0.50 DRILL P SURF RIH with gyro and orient MWD. 09:30 - 13:00 3.50 DRILL P SURF Drill directionally from 173' to 544'. PU - 75K, SO - 68K, 750 gpm, 1,362 psi 13:00 - 13:30 0.50 DRILL P SURF POH from 544' to 172'. PU jars. 13:30 - 14:00 0.50 DRILL P SURF RIH from 172' to 544'. Precautionary wash and ream last stand to bottom. 14:00 - 16:00 2.00 DRILL P SURF Orill directionally from 544' to 823'. PU -76K, SO -71K, ROT- 74K, 750 gpm, 1,470 psi, 40 rpm. 16:00 - 17:00 1.00 DRILL P SURF Conduct a multishot gyro ssurvey. RD Gyrodata and Schlumberger E-line. 17:00 - 00:00 7.00 DRILL P SURF Drill directionally from 823' to 1,485'. PU - 93K, SO - 63K, ROT - 78K, 750 gpm, 1,840 psi, 40 rpm, TQ on - 9k, TO off - 4k. Daily AST - 5.61 hours. Daily ART - 5.56 hours. 5/17/2005 00:00 - 01 :30 1.50 DRILL P SURF Drill directionally from 1,485' to 1,768'. PU - 95K, SO - 71 K, ROT - 80K, 750 gpm, 1,850 psi, 40 rpm, TO on - 7k, TO off - 4k. AST - 0.48, ART - 1.8. 01 :30 - 02:30 1.00 DRILL P SURF Circulate sweep around and clean up the hole. Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/17/2005 02:30 - 03:30 1.00 ORILL P SURF POH and stand back 5" DP from 1,768' to 635'. Worked tight hole from 1,100' to 950'. 03:30 - 05:00 1.50 DRILL P SURF Handle BHA#1 from 635'. LO the UBHO sub. All stabilizers and the bit were balled up with clay. Change out bit. 05:00 - 05:30 0.50 DRILL P SURF Clean the floor. 05:30 - 06:30 1.00 DRILL P SURF Set motor to 1.83, PU near bit stabilizer and RIH with remaining BHA from the derrick. BHA#2: 16" MXC-1, 9-5/8" motor w/1.83, nm lead collar, nm stabilizer, MWO, nm stabilizer, 2 x nm drill collars, nm stabilizer, nm drill collar, jars, 14 x 5" HWOP. 06:30 - 08:00 1.50 ORILL P SURF RIH from 637' to 969'. Work pipe down to 1,180'. RIH to 1,768'. 08:00 - 21 :00 13.00 DRILL P SURF Orill directionally from 1,768' to 3,606'. PU - 122K, SO - 70K, ROT - 90K, 750 gpm, 2,530 psi, TQ on - 10k, TQ off - 6k. AST - 2.88, ART - 4.85. Hydrates seen from 2,900' to 3,600'. Gassed up the desilter pump and the desilter lost efficiency. 21 :00 - 00:00 3.00 ORILL N DPRB SURF Observed a flow line and pit volume decrease. Picked up off bottom and reduced rate. Initial loss rate - 400 bph. Loss rate decreased with the reduction of pump rate. Begin adding Mix" LCM to the mud while keeping the hole full and reciprocating the pipe - PU - 120K, SO - 70K. Called 7es and had a load of 142 bbls they were sending for disposal diverted to ges. Off load 9.5 ppg fluid from 7es into the pit system. Condition the mud in the pits. Continue to pump LCM down hole. Loss rate -90 bph. Keeping the hole full with 121 gpm while adding water the mud system at 40 bph. Losses for the day - 230 bbl. 5/18/2005 00:00 - 02:45 2.75 ORILL N DPRB SURF Circulated 40 bbls of 20 ppb Mixseal LCM pill to the bit. Staged the pumps up to 100 spm, 352 gpm, 636 psi - losses reduced. Continued to circulate while waiting for precautionary loads of water, more LCM products, and 290 bbls of 8.6 ppg mud. Offloaded the new fluid and conditioned it with the fluid on surface. Stage pumps up to 600 gpm without losses and without adding water. 02:45 - 05:00 2.25 ORILL P SURF Drill ahead directionally from 3,606' to 3,887' (TD) at 100 fph, 80 rpm, 600 fph, 1,600 psi without losses. Mud weight was a 9.3 ppg fluid going in and a 9.4 ppg fluid coming out. Increase ROP to 200 fph, 80 rpm, 650 gpm, 1950 psi without losses. Water on - 50 bph. 05:00 - 08:30 3.50 DRILL P SURF Circulate hi-vise sweep surface to surface and elean up the well for short trip - 715 gpm, 1,822 psi. Hydrates were seen circulated to surface. 08:30 - 14:00 5.50 DRILL P SURF POH from 3,887', PU - 140K, SO - 70K. At 3,749' , pipe started to pull tight, +50K. Backream out to 2,430' - 600 gpm, 1,650 psi, 60 rpm. POH without backreaming from 2,430' to 1,960' with intermittent drag of 25k. Worked pipe across intervals where drag was seen, but after working the pipe it pulled clean. Hole started to swab at 1,960'. Pump out of the hole to 1,770'. POH without pumps from 1,770' to 732'- appear to be pulling a boulder up the hole. Work pipe to 545' to get the boulder down past the stabilizers with 500 gpm, 60 rpm. 14:00 - 14:30 0.50 DRILL P SURF Clean the floor. 14:30 - 16:30 2.00 DRILL P SURF RIH from 545' to 1,250'. RIH from 1,250' to 3,887' - appear to Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/18/2005 14:30 - 16:30 2.00 DRILL P SURF 16:30 - 20:30 4.00 DRILL P SURF 20:30 - 00:00 3.50 ORILL P SURF 5/19/2005 00:00 - 02:00 2.00 ORILL P SURF 02:00 - 03:00 03:00 - 05:30 1.00 DRILL P 2.50 CASE P SURF SURF 05:30 - 12:00 6.50 CASE P SURF 12:00 - 15:30 3.50 CASE P SURF 15:30 - 17:30 2.00 CASE P SURF 17:30 - 18:00 0.50 CEMT P SURF 18:00 - 20:30 2.50 CEMT P SURF 20:30 - 21 :00 0.50 CEMT P SURF 21 :00 - 00:00 3.00 CEMT P SURF be pushing a boulder in front of the bit. Stage up the pumps to 750 gpm, 2,050 psi to condition the mud for running casing - 9.5 ppg, 200 FV. Clear the derrick of ice while circulating. Monitor the well - static. POH standing back 5" OP from 3,887' to 638'. Stand back 5 stands of 5" HWDP and jars to 176'. An intermittent drag of 15K seen throughout the trip. LD remaining BHA #2 components. LD 1 x nm drill collar and nm stabilizer. Crossover to 4-1/2" IF and PU single joint of 5" DP. Stand back the single plus 2 x nm drill collars. LD nm stabilizer, MWO, nm stabilizer, lead collar, motor and the 16" bit - graded 1/1/WT/AlE/I/NO/T0. Clear and clean the rig floor. Rig up casing handling tools and rig floor. Make dummy run with hanger and mark pipe. PU 13-318" Float shoe joint, float collar assembly and 20' pup joint. Bakerlock first 3 connections. Check floats - holding. RU Franks fillup tool. PU 13-3/8" 68# L-80 BTC casing to 2,272'. Use Best-o-life 2000 NM thread lubricant on each connection and torque to the mark @ 10,000 ftlbs. Continue running surface casing to 3,841'. Pump down joints as required from 2,200' to 2,800'. Ran 93 joints of casing plus TAM port collar assembly, 20' pup joint and float equipment. PU casing hanger and pup. Land hanger with split landing joint. Stage up pumps through the Franks tool to 8 bpm, 568 psi. Reciprocate the pipe, PU - 250K, SO - 105K. Circulate and condition mud. Float shoe - 3,872' Float collar - 3796' TAM port collar - 1017' LO the Franks tool and make up the cement head. Break circulation. Circulate and condition the mud at 9 bpm, 608 psi - PU - 250K, SO - 130K. Reciprocate the string with -15' stroke length. Conditioned the mud to 65FV and 9.6 ppg prior to cement job. Hold PJSM with all personnel. Prime up the cement unit and pump 100 bbls of mud treated with bicarb and SAPP down the casing. PU - 288K, SO - 125K. Stop circulating with the rig pumps and line up to the Schlumberger cement unit. Reciprocate the casing with -15' stroke length. Pump 5 bbls of fresh water ahead to warm up the lines. Pressure test the lines to 3,000 psi - good test. Batch up 10.2 ppg Mudpush spacer. Pump 76 bbls of spacer at 7 bpm, initial pressure 490 psi, final pressure 470 psi. Shut down, batch lead cement and drop the bottom plug - good indication of plug leaving the cement head. Pump 765 bbls of 10.7 ppg lead cement at 7.4 bpm, initial pressure 760 psi, final pressure 856 psi. Shut down and batch tail cement. Pump 15.8 ppg tail cement at 4 bpm 783 psi initial and at 4.5 bpm 740 psi final. At 40 bbls into the tail cement, the casing was held up -4' off bottom. Worked the pipe and at 60 bbls of tail cement pumped, the pipe was landed on the hanger. Shut Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/19/2005 21 :00 - 00:00 3.00 CEMT P SURF down and drop the top plug - good indication of plug leaving the cement head. Kick out the plug with 10 bbls of fresh water using the Schlumberger cement unit. Shut down and line up to the rig pumps for displacement. 5/20/2005 00:00 - 01 :30 1.50 CEMT P SURF Continue cement job. Oisplace the cement using the rig pumps - 9.3 bpm, 520 psi after catching the cement with 19 bbls pumped. Lead cement returned to surface 294 bbls into the displacement. Dropped the rate to 3 bpm 535 bbls into the displacement. Pressure prior to the rate reduction was 1,048 psi. Pressure after the rate reduction was 749 psi. At the same time the rate was reduced, we lost returns at surface. Pressure continued to increase over the remaining 25 bbls pumped even though no returns came to the surface. The plug as bumped at 6,705 strokes (562 bbls) with -96% efficiency and 1,500 psi. Approximately 243 bbls of lead cement was returned to surface. Floats holding. Cement in place at 0100, 5/20/2005. 01 :30 - 04:00 2.50 CEMT P SURF Drain and flush the stack. Attempt to back out the split landing joint - started to break at the split collar instead of the at the hanger. Call for the welder and tack a couple of spots on the split collar to hold it in place. Back out the landing joint. Clean up the cellar and the drip pans. 04:00 - 05:00 1.00 CASE P SURF Rig down the casing handling equipment. OS:OO - 08:00 3.00 BOPSUP P SURF ND the diverter system and associated equipment. 08:00 - 09:00 1.00 WHSUR P SURF NU 13-3/8" Split Speed Head. Test seals with 1,000 psi and hold for 10 minutes - good test. 09:00 - 14:00 5.00 BOPSUP P SURF NU BOPE. 14:00 - 19:30 5.50 BOPSUF P SURF RU BOPE testing equipment. Fill the BOP stack with water. Test BOPE, choke and all related valves to 250/4,000 psi. Test Annular Preventer to 250/3,500 psi. Witness of the test was waived by Chuck Shieve of the AOGCC. Test witnessed by BP reps Alan Madsen and James Franks and Nabors reps Chris Clemens and Kelly Cozby. 19:30 - 20:30 1.00 BOPSUP P SURF RD testing equipment. Install 12-5/8" 00 wear ring. 20:30 - 21 :30 1.00 DRILL P INT1 PU 18 joints of 5" DP and stand back in the derrick. 21 :30 - 00:00 2.50 DRILL P INT1 PU BHA #3 - 12-1/4" Hycalog DS103, 9-S/8" motor(1.5), nm stabilizer, ARC8, MWD and ADN8. Orient MWD. 5/21/200S 00:00 - 02:00 2.00 DRILL P INT1 Continue picking up BHA #3. PU nm drill collar, nm stabilizer, and nm drill collar. Hold PJSM and clear the area. Load nuclear source and RIH. PU jars, 14 x 5" HWDP, 12 x 5" DP, ghost reamer and 1 x S" OP to 1,046'. 02:00 - 03:00 1.00 DRILL P INT1 PU S" DP from the pipe shed and RIH to 1,250'. Shallow test the MWD/LWD tools - good test. Pressure test the casing to 1,500 psi for 5 minutes after running the stabilizers past the TAM port collar at 1,017' - good test. 03:00 - 05:00 2.00 DRILL P INT1 PU 5" DP from the pipe shed to 3,370'. 05:00 - 06:00 1.00 DRILL P INT1 Slip and cut 240' of drilling line due to bad spots in the line. 06:00 - 06:30 0.50 DRILL P INT1 Service the top drive and the crown. 06:30 - 07:00 0.50 DRILL P INT1 RIH with S" OP from the derrick to 3,760' 07:00 - 08:00 1.00 CASE P SURF Line up to pressure test the casing. Test the casing to 3,SOO psi, chart and hold for 30 minutes. 08:00 - 09:30 1.50 DRILL P INT1 Tag float collar @ 3,795'. Drill up float equipment and shoe track to the top of the float shoe @ 3,780'. Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/21/2005 09:30 - 11 :30 2.00 ORILL P INn Pump a 50 bbl sweep and displace the well over to new 8.8 ppg LSND drilling fluid. 11 :30 - 12:30 1.00 DRILL P INT1 Orill float shoe and rat hole to 3,887'. Drill 20' of new formation to 3,907'. Pull back into the shoe to conduct LOT. 12:30 - 13:00 0.50 DRILL P INT1 Perform LOT at 3,907' MD /2,722' TVO to 14.03 ppg EMW with 8.8 ppg fluid and 740 psi surface pressure. 13:00 - 00:00 11.00 ORILL P INT1 Drill directionally from 3,907' to 5,667'. PU - 160K, SO - 85K, ROT - 120K, 80 rpm, 700 gpm, TO on - 15k, TQ off - 12k. AST - 1.3, ART - 4.66. 5/22/2005 00:00 - 13:30 13.50 DRILL P INT1 Orill directionally from 5,667' to 7,260' (TD). PU - 180K, SO - 155K, ROT -135K, 80 rpm, 700 gpm, 1,811 psi, TO on -17k, TO off - 14k. AST - 1.58, ART - 5.75. 13:30 - 15:30 2.00 DRILL P INT1 Circulate for geological sample. Pump a weighted sweep from surface to surface @ 700 gpm, 1,522 psi, 110 rpm. Calculated ECD - 9.6 ppg, Actual ECD - 9.76 ppg. 15:30 - 17:30 2.00 DRILL P INT1 Monitor the well - static. POH without problems from 7,260' to 3,871' - inside the 13-3/8" shoe. 17:30 - 18:00 0.50 DRILL P INT1 Monitor the well - static. Service the top drive and clean the rig floor. 18:00- 19:30 1.50 DRILL P INT1 RIH without problems from 3,871' to 7,260' 19:30 - 21 :00 1.50 DRILL P INT1 Circulate and condition the hole. Calculated ECD - 9.6 ppg, Actual ECD - 9.79 ppg. No appreciable solids seen coming across the shakers. 21 :00 - 00:00 3.00 DRILL P INT1 Monitor the well - static. POH from 7,260' to 5,477' without problems. 5/23/2005 00:00 - 03:00 3.00 DRILL P INT1 POH standing back 5" DP and 5" HWDP from 5,477' to the top of the jars at 198' without problems. 03:00 - 06:00 3.00 DRILL P INT1 PJSM. LD BHA#3. LD jars, nm drill collar, nm stabilizer and nm drill collar. Clear the floor, hold PJSM and remove the nuclear source. LD ADN8, MWD, ARC8, nm stabilizer, motor and bit. 12-1/4" Hycalog DS103 graded 1/2/CT/GIX/1/WTITD. 06:00 - 06:30 0.50 DRILL P INT1 Clear and clean the floor. 06:30 - 08:30 2.00 BOPSUF P INT1 Pull wear ring. Change out the upper rams to 9-5/8". Test the door seals to 3,500 psi. 08:30 - 12:30 4.00 CASE P INT1 RU 350 ton casing equipment and Franks fillup tool. 12:30 - 17:00 4.50 CASE P INT1 PU 9-5/8" 47# shoe track. Bakerlok shoe track connections. RIH. Continue to RIH with 9-5/8" 47# x 40# L-80 BTC-m casing. All connections made up with Best-o-life 2000 thread lubricant and torqued to 9,800 ftlbs. RIH to 3,871' - inside the surface casing shoe. 17:00 - 18:00 1.00 CASE P INT1 Circulate and condition the mud prior to entering the open hole. 18:00 - 21 :30 3.50 CASE P INT1 RIH with 9-5/8" 40# L-80 BTC-m casing from 3,871' to 7,212'. PU landing joint and hanger. Land casing at 7,252', PU - 290K, SO - 175K. Ran a total of 23 joints of 9-5/8" 47# L-80 BTCM casing on bottom and 152 joints 9-5/8" 40# L-80 BTC~M casing on top. RA pip tags located at the top of the MA sand @ 6,525' in a 20' 47# pup joint. 21 :30 - 23:00 1.50 CASE P INT1 Circulate and condition the hole for the cement job. Reciprocate the pipe during circulation. 23:00 - 23:30 0.50 CASE P INT1 LD the Franks fillup 1001 and RU the Schlumberger cement head. 23:30 - 00:00 0.50 CASE P INT1 Circulate and condition the hole. Reciprocate the pipe during circulation. Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/24/2005 00:00 - 01 :30 1.50 CASE P INT1 Circulate and condition. Hold PJSM. Start batching 15.8 ppg tail cement @ 0045. 01 :30 - 05:00 3.50 CEMT P INT1 Line up to Schlumberger. Pump 3 bbls of fresh water to warm up the lines. Shut in and perform a pressure test to 4,000 psi. Pump 25 bbls CW100 followed with 81 bbls of 10.5 ppg Mudpush spacer. Shut down and drop the bottom plug. Pump 108 bbls of 15.8 ppg Class G plus adds lead followed by 98 bbls of 15.8 ppg Class G with Gasblok. Shut in and drop the top plug. Kick out the plug with 10 bbls of fresh water from Schlumberger. Turn over to the rig and displace with 532 bbls of seawater -7712 strokes - 94% efficiency. Bumped the plug and pressure tested the casing to 4,000 psi - recorded on chart. Had full returns during the cement job and good indication of lift throughout. The cement was in place @ 0415. 05:00 - 06:30 1.50 CEMT P INT1 RO cement head, lay down landing joint, rig down casing tools, change bails and elevators to 5". 06:30 - 08:00 1.50 WHSUR P INT1 Make up packoff running tool, install and test packoff to 5,000 psi for 10 min. lay down running tool. 08:00 - 10:30 2.50 BOPSUF P INT1 Install test plug, Change top rams to'3.5" X 6" variables and test to 4,000 psi. 1 0:30 - 12:00 1.50 BOPSUPP INT1 Rig down test equipment and installl wear ring. 12:00 - 14:00 2.00 EV AL P INT1 Prepare pits and rig to take on MOBM. 14:00 - 16:30 2.50 DRILL P PROD1 Make up 8.5" rotary assembly with 8.5" Hughes MX-09DX, NB stab, NM lead collar, NM stab, LWO, MWO, ADN, NM flex DC, NM stab, NM flex DC, XO, 1 jt HWDP, Jars, 13 jts 5" HWDP, shallow test MWD. 16:30 - 19:30 3.00 ORILL P PR001 RIH from 622' to 7,133', fill DP @ 4,866'. 19:30 - 21 :00 1.50 DRILL P PROD1 Make up topdrive and wash down to float collar @ 7,169' drill float collar and clean out cement to 7,242', 550 gpm, 1130 psi, 100 rpm, torque 16k, wob 5-15k, up wt = 200k, dwn wt = 90k, rt wt = 135k. 21 :00 - 00:00 3.00 DRILL N WAIT PROD1 Pump sweep @ 550 gpm, 1130 psi, rotating @ 100 rpm, reciprocating pipe 50'. Continued circulating until trucks on location for mud displacement. 5/25/2005 00:00 - 02:00 2.00 DRILL P PROD1 Pump 100 bbl oil base spacer and displace well to 9.0 ppg MOBM @ 550 gpm 1,900 psi, rotating 120 rpm, reciprocating pipe 50', shut down once MOBM at surface, clean shakers and troughs, continue circulating, slowed pump rate from 550 gpm to 300 gpm, loosing mud over shakers, continued loosing at reduced rate , changed out end screen on all three shakers to 175's. 02:00 - 02:30 0.50 DRILL P PROD1 Drill remaining cement and float shoe, clean out rat hole and drill 20' of new hole to 7,280', 5-25k wob, 550 gpm, 2,010 psi, 110 rpm, torque 13.5K. 02:30 - 03:00 0.50 DRILL P PROD1 Pull back inside shoe, circulate bottoms up at 550 gpm, 2000 psi rotating 110 rpm, torque 12-14k 03:00 - 03:30 0.50 DRILL P PROD1 Perform FIT, mud weight 9.0 ppg, 4,444' tvd, pressure achieved 347 psi, EMW 10.5 ppg 03:30 - 09:00 5.50 ORILL P PROD1 Drill 8.5" production hole from 7,280' to 7,640, 20-25k wob, 550 gpm, 2010 psi, 130 rpm, torque 11-13k, up wt = 200k, dn wt = 90k, rt wt = 125k. 09:00 - 09:30 0.50 DRILL P PROD1 Obtain additional surveys to satisfy JORPS. 09:30 - 10:30 1.00 DRILL P PROD1 Circulate sweep around, 550 gpm, 2040 psi Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/25/2005 10:30 - 11 :00 0.50 ORILL P PROD1 POH to 7,222' no hole problems. 11 :00 - 12:00 1.00 DRILL P PROD1 Circulate 2x bottoms up inside casing shoe @ 550 gpm,1950 psi, rotating 120 rpm, torque 12k. 12:00 - 12:30 0.50 DRILL P PROD1 RIH from 7,222' to 7,640' 12:30 - 14:00 1.50 DRILL P PROD1 Circulate, @ 550 gpm, 2,030 psi, 120 rpm, torque 13k, pumped 2 open hole volumes shut down rotary, continue circulating until hole is clean, reciprocating from 7,620' to 7,640' monitor well . 14:00 - 17:00 3.00 DRILL P PR001 POH from 7,640' to 622', no problems pulling in open hole. 17:00 - 19:00 2.00 DRILL P PROD1 Lay down BHA per Annadrill personnel. 19:00 - 19:30 0.50 ORILL P PROD1 Clear floor of all directional tools. 19:30 - 22:00 2.50 CLEAN P SURE Make up clean out assembly, RR Hughes MX-09DX, bit sub, 12 joints 5" DP, Baker window mill, 26 1/4" DC's, XO, casing scraper, XO, bumper sub, oil jar, 76 1/4" DC's, 12 joints 5" HWOP. 22:00 - 00:00 2.00 CLEAN P SURE RI H with clean out assembly from 1,066' to 3,231' 5/26/2005 00:00 - 02:00 2.00 CLEAN P SURE RIH from 3,231' to 7,570' 02:00 - 03:00 1.00 CLEAN P SURE Make up topdrive, ream down from 7,570' to 7,640' and work mill through shoe area several times from 7,256' to 7,225', 200 gpm, 720 psi, 80 rpm, torque 15k. 03:00 - 03:30 0.50 CLEAN P SURE POH from 7,570' to 7,193' up WI = 225k, dn WI = 87k 03:30 - 05:00 1.50 CLEAN P SURE Circulate bottoms up 2x 550 gpm, 1950 psi, 80 rpm, torque 12.5k, reciprocating pipe full stand, Circulate until mud meets Weatherford Flow through test criteria. 05:00 - 05:15 0.25 CLEAN P SURE RIH from 7,193' to 7,640' 05:15 - 05:30 0.25 CLEAN P SURE Circulate 2 open hole annular volumes @ 200 gpm, 750 psi. 05:30 - 06:00 0.50 CLEAN P SURE POH from 7,640 ' to 7,193' 06:00 - 12:00 6.00 CLEAN P SURE Circulate and condition mud @ 550 gpm, 1830 psi, 60 rpm, torque 12k. 2 x bottoms up, install and clean 10 ditch magnets after each bottoms up,Shut down pumps, function annular, upper and lower pipe rams, to remove any solids build up. Continue circulating @ 550 gpm, 1830 psi with no pipe rotation or reciprocation, until mud meets Weatherford Flow through test criteria. 12:00 - 14:00 2.00 CLEAN P SURE Monitor well, pump dry job,. POH from 7,640' to 688' Freeze protect 13 3/8" X 9 5/8" annulus with 165 bbls diesel, initial rate 1 bpm @ 1,300 psi, final rate 1.5 bpm @ 1,400 psi. 14:00 - 17:00 3.00 CLEAN P SURE Lay down 12 joints 5" HWOP and 9 DC's, lay down remaining BHA 17:00 - 17:30 0.50 CLEAN P SURE Make up ported sub, function annular, upper and lower rams flush BOP stack 17:30 - 20:00 2.50 EVAL P SURE PJSM, rig up Schlumberger logging tools. 20:00 - 00:00 4.00 EVAL P SURE RIH with UBI to 7,630', log up with UBI from 7,630' to 6,400', tie in to RA tag in 9 5/8' casing for primary depth control. 5/27/2005 00:00 - 01 :30 1.50 EVAL P SURE POH with UBI, lay down same. 01 :30 - 02:30 1.00 EVAL P SURE Make up USIT, and calibrate. 02:30 - 06:00 3.50 EV AL P SURE RIH with USIT to 7,252' and log up from 7,250 to the top of the cement @ 3,910', POH with E-line 06:00 - 07:00 1.00 EVAL P SURE Rig down E-line tools, clear floor. 07:00 - 1 0:00 3.00 CASE P PROD1 Pickup casing running equipment and expandable liner running tools to rig floor. 10:00 - 13:00 3.00 CASE P PROD1 Rig up casing tools, make up safety joint for well control and Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/27/2005 10:00 - 13:00 3.00 CASE P PROD1 lay in pipe shed, repair stabbing board. 13:00 - 13:30 0.50 CASE P PR001 Remove ice from derrick. 13:30 - 14:30 1.00 CASE P PROD1 Held PJSM with Co Rep, Toolpusher, Weatherford, Baker and rig personnel, for running the expandable liner. 14:30 - 21 :00 6.50 CASE P PROD1 Run 7" 29# 13 Cr Vam Top HT LH expandable screens and 7" 26# 316 alloy expandable zonal isolation joints per running order, make up Baker ML-ZXP liner top packer, String weight 49k. 21 :00 - 22:30 1.50 CASE P PROD1 Rig down casing running equipment, clear floor of all excess liner equiment and casing tools. Change to short bails and 5" elevators. 22:30 - 00:00 1.50 CASE P PROD1 RIH with expandable liner on 5" OP to 977', pickup RA sub. continue running liner to 1,200' @ 1.5 min per/stand in 9 5/8" casing. 5/28/2005 00:00 - 04:30 4.50 CASE P PROD1 RIH with expandable liner on 5" OP from 1,200', to 7,106' @ 1.5 min per/stand in 95/8" casing. filling OP every 10 stands with casing fill up hose. 04:30 - 05:00 0.50 CASE P PROD1 UO 2 singles from sting and P/U 20 ft. pup joint. Break circulation and pump/record a various rates. 1.5 BPM=350 PSI; 2 BPM=410 PSI3 BPM=496 PSI. Record up and down wts. prior to entering open hole, 185/85K. 05:00 - 05:30 0.50 CASE P PR001 Continue RIH from 7,106 to setting depth of 7622. Position pipe to run GRlCCL with Schlumberger 05:30 - 10:00 4.50 EV AL P PROD1 Rig up to run GR/CCL logs and tie in well to Pip tag in 9 5/8. POH with E-line and rig down wire line tools. 10:00 - 11 :00 1.00 CASE P PR001 Position pipe on depth, pressure test lines to 4,300 ps. 11 :00 - 12:00 1.00 CASE P PR001 Break circulation, drop 1 3/4" ball and pump to seat @ 3 bpm, 490 psi, pressure up to 1,500 psi to set liner hanger, set down 65k to ensure slips are holding, pressure up to 3,000 psi to activate pusher tool to set packer, bleed off, pressure up to 1,000 psi on annulus to test packer, ok. Perform torque test to 10K. Pressure up to release HR running tool, sheared @ 3,400 psi. Pull running tool from liner. 12:00 - 17:00 5.00 CASE P PROD1 Monitor well, pump dry job, POH lay down liner running tool. 17:00 - 18:00 1.00 CASE P PROD1 Cut and slip drilling line, service rig. 18:00 - 20:00 2.00 CASE P PROD1 RIH picking up 30 4 3/4" steel DC's 20:00 - 21 :00 1.00 CASE P PR001 Circulate 2 hole volumes to clear any deris from the drill collars and hole @ 270 gpm, 550 psi 21 :00 - 23:00 2.00 CASE P PROD1 POH rack back 10 stands of 4 3/4" OC's. 23:00 - 00:00 1.00 CASE P PROD1 Clean Floor, P/U Weatherford tools to rig floor. 5/29/2005 00:00 - 02:30 2.50 CASE P PROD1 Held PJSM with Co Rep, Toolpusher, Weatherford and rig personnel. Make up 5.5" Slick drill collar, Antech data sub, XO and one joint of 5" DP, establish circulating pressures at various rates to determine pressure loss through surface equipment. Make up expansion tool and lower in the hole. Perform surface flow test @ various pressures. Determined that the operating pressure was too high for proper tool function. Pulled expansion tool to floor and adjust flow diverter to reduce operating pressure. Lower tool in the hole and perform flow test, tool functioned properly. 02:30 - 08:30 6.00 CASE P PROD1 RIH, with expansion assembly to 7,004', fill DP every 10 stands. 08:30 - 12:30 4.00 CASE P PROD1 Circulate and condition mud 2.5 bpm @ 1270 psi. MOBM thick Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/29/2005 08:30 - 12:30 4.00 CASE P PROD1 from sitting static. Rate and pressure values off from ones taken at surface, roll mud until values met Weatherford critirea. 12:30 - 15:00 2.50 CASE P PROD1 Perform expansion simulation with rig crew, obtain parameters per Weatherford representative. Up wt = 215k dn wt = 92k. 15:00 - 23:00 8.00 CASE P PROD1 RIH from 7,004' tag locating ring on EZI at 7,330' to verify depth, Pull up to 7,257', begin expansion of first ESS from 7,263' to 7,296' at 4 fpm, 45 spm, 1,650 psi, 50 rpm, torque 12-18k, 15-25k wt on tool. RIH tag EZI at 7,330' to verify depth, begin expansion of first EZI joint from 7,330 to 7,350' @ 4 fpm, 81 spm, 3040 psi, 50 rpm, torque 12-17k, 25-30k wt on tool. RIH tag top of second EZI @ 7,452' to verify depth, Pulled up to 7,364' to begin expansion of second ESS, expand ESS from 7,364' to 7,438', 45 spm 1650 psi, 50 rpm, torque 12-17k, diverter valve bypassed not allowing ESS expansion rollers to function. EZI portion of expansion tool was functioning properly. Oecision was made to continue with the expansion of the remaining EZI joints RIH tagged second EZI joint to verify depth, Began expansion of second EZI joint, expand from 7,452' to 7,473', 4 fpm, 200 gpm, 3040 psi, 50 rpm torque 12-18k, 20-25k wt on tool. RIH, tag third EZI at 7,538', began expansion, drill string torqued up and stalled top drive, shut down rotary. Picked up on srting to 250K no movement, discussed opptions, Pulled up to 270k, pipe came free. 23:00 - 00:00 1.00 CASE P PROD1 POH slowly from 7,538' to 7,098', expansion rollers hanging up, 200 to 220k, drop 1 3/4" ball to open circ sub. 5/30/2005 00:00 - 01 :00 1.00 CASE N DFAL PR001 Pump ball to seat 2 bpm, 1,220 psi, circ sub sheared open @ 1800 psi, monitor well, Pump dry job, blow down topdrive. 01 :00 - 05:00 4.00 CASE N DFAL PROD1 POH to 4 3/4" DC's, Monitor well 05:00 - 06:30 1.50 CASE N DFAL PR001 Lay down 12 4 3/4" DC's, stand back 6 stands of 4 3/4' De's 06:30 - 08:00 1.50 CASE N DFAL PROD1 Lay down circ sub, inspect ESS/EZI expansion tool and lay down. EZI expander failed. (rollers siezed to pins) 08:00 - 11 :00 3.00 CASE N DFAL PR001 Make up new expanding tool and circ sub, RIH below rotary table, flow test tool. Pulled up, changed out ESS expander, RIH below table and perform flow test, tools functioning properly. Blow down topdrive. 11 :00 - 17:00 6.00 CASE N DFAL PR001 Pickup remaining BHA and 12 joints 5" OP, RIH with expansion tools to 7,013' @ 60 fpm, fill DP every 10 stands and obtain up and down weights every 10 stands. 17:00 - 18:00 1.00 CASE N DFAL PROD1 Perform function test of ESS & EZI diverter, and obtain parameters prior to entering 7" liner, up wt = 183k, dn wt = 84k, rt wt = 124k, 25 rpm, torque 13k. 18:00 - 18:30 0.50 CASE P PR001 RIH, tag EZI #3 @ 7,530' to confirm depth, pulled up to 7,412'. Expand ESS from 7,412' to 7,434',100 gpm, 1,425 psi, 50 rpm torque 14-16k, 13k weight on tool. 18:30 - 19:00 0.50 CASE P PROD1 RIH, tagged EZI #3 @ 7,530' to verify depth, attempt to function EZI expander, failed three attempts. function ESS expander and pass through EZI #3 to expand screens below 7,530' 19:00 - 22:00 3.00 CASE P PROD1 RIH tag Bullnose @ 7,622' to verify depth, pulled up to 7,561' and expand ESS from 7,561' to 7,617',100 gpm, 1,480 psi, 50 Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 5/30/2005 19:00 - 22:00 3.00 CASE P PROD1 rpm, torque 12-16k, 10-15k weight on tool. 22:00 - 00:00 2.00 CASE P PROD1 Attempt to function EZI expander with no sucsess, POH slowly to 7,013' 5/31/2005 00:00 - 00:30 0.50 CASE P PROD1 Once above 7" Liner top, attempt to function EZI diverter. Tool functioned @ 3,150 psi, cycled tool two more times once @ 2850 psi and the last time @ 2750 psi. 00:30 - 01 :00 0.50 CASE P PROD1 RIH from 7,013' to 7,539', make up topdrive, EZI expander shifted @ 2,750 psi, begin expanding the last EZI from 7,539' to 7,560',200 gpm, 3,000 psi, 60 rpm torque 13-18k, 20-30k weight on tool. 01 :00 - 01 :30 0.50 CASE P PR001 POH slowly from 7,560' to 7,013', 10 to 15k drag while pulling out of 7" liner. 01 :30 - 02:30 1.00 CASE P PROD1 Drop 1 3/4" ball and pump to seat @ 2 bpm, 1120 psi, sheared lopen @ 2000 psi, monitor well and pump dry job. 02:30 - 07:30 5.00 CASE P PROD1 POH from 7,013' to 602' monitor well. lay down expansion tool. 07:30 - 08:30 1.00 CASE P PROD1 Clear floor of all expansoin tools and related equipment. Clean floor 08:30 - 14:00 5.50 EVAL P PROD1 Rig up Schlumberger e-line, RIH with USIT to 7,620' log up to 7,000' to confirm proper expansion of ESS and EZI joints. POH with e-line, lay down USIT, rig down e-line tools. 14:00 - 19:00 5.00 CASE P PROD1 Make up mule shoe and float sub, RIH to 7,615' fill DP as needed. 19:00 - 21 :30 2.50 CASE P PROD1 Make up topdrive and break circulation, pump 45 bbl Vers-Pro spacer, 40 bbls high vis 9.0 ppg brine w/4 ppb HEC-10, displace well with 530 bbls 9.0 ppg brine @ 600 gpm, 775 psi, 60 rpm, torque12.5k. 21 :30 - 22:00 0.50 CASE P PROD1 POH with mule shoe, position mule shoe above 7" liner top @ 7,123' 22:00 - 00:00 2.00 CASE P PR001 Prep pits for clean brine, clear and flush lines of all MOBM. 6/1/2005 00:00 - 02:30 2.50 CASE P PROD1 Remove all excess MOBM from pits, (Vac-trucks having difficult time loading MOBM) 02:30 - 04:00 1.50 CASE P PROD1 Pump 40 bbl high vis pill from truck, followed by 40 bbl 9.0 ppg brine with 3 drums Safe Surf 0, pumped remaing 40 bbl high vis pill from truck, displace with 500 bbls 9.0 ppg brine @ 445 gpm, 870 psi, 60 rpm, torque 11.5k 04:15 - 04:45 0.50 CASE P PROD1 RIH to 7,615'. 04:45 - 06:00 1.25 CASE P PROD1 Mix 25 bbls EMS-6420 filter cake breaker pill in pill pit per MI I mixing procedure, spot pill in 7" liner, @ 150 gpm, 125 psi. 06:00 - 09:00 3.00 CASE P PROD1 Clean out under shakers, clean troughs and trip tank, monitor well. 09:00 - 18:00 9.00 CASE P PROD1 POH from 7,615' to 7,127' up wt = 200k. Lay down drill pipe, 18 43/4" drill collars, mule shoe and float sub. 18:00 - 21:00 3.00 RUNCOMP I RUNCMP Rig up tubing running equipment, pickup I-wire spool and related equipment to rig floor and rig up. Pull wear bushing, make dummy run with tubing hanger. 21 :00 - 00:00 3.00 RUNCOMP RUNCMP Held PJSM with Co Rep, Toolpusher, Weatherford, Halliburton and rig crew. Make up 3.5" 9.2# L-80 "X" nipple packer assembly, make up Weatherford dual gauge mandrel "X" nipple assembly, and connect I-wire, pickup 2 injection mandrels, second Weatherford packer and single gauge mandrel. 6/2/2005 00:00 - 02:00 2.00 RUNCOMP RUNCMP Feed I-wire thru second Weatherford packer, connect wire to I single gauge mandrel and secure. Make splice to Gauge Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 6/212005 00:00 - 02:00 02:00 - 04:30 2.00 RUNCOMP 2.50 RUNCOMP 03:30 - 04:30 1.00 RNTBHG P RUNCMP mandrel and test wire. RUNCMP Continue picking up 3.5" 9.2# L-80 TC-II completion jewelry to 95/8" Weatherford packer change over to 4.5" handling equipment, pickup "X" nipple and sliding sleeve assemblies, cut and feed I-wire through packer and make splice, secure wire and test. RUNCMP Run 4.5" 12.6# L-80 TC-II tubing per running order. Makeup torque 3,850 ftllbs, place I-wire clamp on every joint, test wire every 1,000', running speed 25-30 fpm. Up wt = 96k, dn wt = 73k prior to entering 7" liner. Lower packer hung up in tie back extension, worked string several times setting down 10k to get through. Second packer also hung up in tie back extension, worked string setting down 10k several times, gradually increasing weight each time, and finaly dropped in with 25k, test I-wire ok. Continue running completion, picked up required space out pups and landing joint, position string at planned setting depth, hole taking 4 bph while running completion. Ran a total of 5 joints 3.5" 9.2# L-80, 163 joints 4.5" 12.6# L-80, three space out pups and jewelry. OTHCMP Rig up Schlumberger E-line, make up safety valve and pump in sub, RIH with GR/CCL tie in to RA tag in 9 5/8" @ 6,524', correlate depth with RA tag in tubing string @ 6,405' for packer space out. POH with GR/CCL, rig down Schlumberger. TUBHGR POH lay down landing joint, makeup tubing hanger, make penetration through hanger with i-wire and test. land tubing. Up wt = 100k, dn wt = 75k. Ran a total of: 167 4.5" full clamps, 9 half clamps 16,3.5" full clamps, 7 half clamps 3 SS bands. 04:30 - 00:00 19.50 RUNCOMP 6/3/2005 00:00 - 03:30 3.50 EV AL P 04:30 - 05:00 0.50 RNTBHG P TUBHGR 05:00 - 06:30 1.50 RUNCOMP RUNCMP 06:30 - 08:30 2.00 BOPSUF P OTHCMP 08:30 - 13:30 5.00 WHSUR P WHDTRE 13:30 - 14:30 1.00 WHSUR P WHOTRE 14:30 - 15:30 1.00 ZONISO P OTHCMP 15:30 - 16:00 0.50 ZONISO P OTHCMP 16:00 - 19:30 3.50 ZONISO P OTHCMP Losses while running tubing = 115 bbls. RILDS, back out landing joint, Install TWC and test to 1,000 psi. Rig down tubing equipment, rig down i-wire sheave and spooling unit, clear floor. Nipple down BOPE, and drilling nipple. Pickup adapter flange, prep I-wire, penetrate I-wire through adapter flange, nipple up and test adapter flange to 5,000 psi, terminate I-wire, nipple up and test tree to 5,000 psi. Rig up DSM lubricator and pull TWC. Rig up circulating lines to tree, break circulation, bleeding air from annulus and tubing. Drop 1 5/16" roller rod and ball, test lines to 4,300 psi Pressure up on tubing to 3,200 psi, and held for 20 min, to set lower packer, pressure up to 4,300 psi to set middle and upper packers, (no indication of packer setting) held pressure for 30 min record on chart. Bled tubing pressure to 2,500 psi, rigged up on annulus, pressure up on annulus, started pumping away at 800 psi, shut down, pressure quickly bled to 100 psi, Rigged to pump down tubing, pressured up to 4,000 psi with rig pumps, continued to pressure up with test pump, @ 4,900 psi, saw a 100 psi pressure drop, pressured up to 5,000 psi held for Printed: 6/6/2005 11 :23:57 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-214 L-214 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 5/14/2005 Rig Release: 6/3/2005 Rig Number: Spud Date: 5/15/2005 End: 6/3/2005 16:00 - 19:30 3.50 ZONISO P OTHCMP 30 min. record on chart, bled tubing pressure to 2,500 psi, pressure up on back side to 4,000 psi held for 30 min. record on chart, bled annulus pressure to zero, bled tubing pressure to zero, pressure up on annulus to shear OCR shear valve in upper GLM, sheard at 3,500 psi, pumped through both ways @ 2 bpm 500 psi Rig up Little Red, test lines to 3,500 psi, pump 245 bbls diesel down IA @ 2.5 bpm, 1,250 psi to freeze protect tubing and annulus to 2,500' tvd. Allow diesel to U-tube. Install BPV with lubricator, test from below to 1,000 psi. Install VR plugs, secure well. 19:30 - 22:00 2.50 WHSUR P OTHCMP 22:00 . 23:00 1.00 WHSUR P OTHCMP 23:00 - 00:00 1.00 SIT P CLEAN Release rig from L-214i @ 24:00 hrs 6/3/2005 Printed: 6/6/2005 11 :23:57 AM bp L-214 Survey Report Schlumberger Report Date: 25-May-05 Survey / DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 88.690' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: L-PAD 1 S-W TVD Reference Datum: Rotary Table Well: L-214 TVD Reference Elevation: 78.90 ft relative to MSL Borehole: L-214 Sea Bed / Ground Level Elevation: 50.40 ft relative to MSL UWI/API#: 500292325800 Magnetic Declination: 24.467' Survey Name / Date: L-2141 May 25, 2005 Total Field Strength: 57612.149 nT Tort / AHD / DDI/ ERD ratio: 144.681' 15561.89 ft/6.114/1.177 Magnetic Dip: 80.811' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 15, 2005 . Location LatlLong: N 70 211.008, W 14919 22.369 Magnetic Declination Model: BGGM 2004 Location Grid N/E Y/X: N 5978154.310 ftUS, E 583400.480 ftUS North Reference: True North Grid Convergence Angle: -+{).63769163' Total Corr Mag North -> True North: +24.467' Grid Scale Factor: 0.99990790 Local Coordinates Referenced To: Well Head Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude Longitude Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (ftUS) (ftUS) RTE 0.00 0.00 0.00 -78.90 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978154.31 583400.48 N 70 21 1.008 W 14919 22.369 First GYD-GC-SS 100.00 0.22 276.22 21.10 100.00 -0.19 0.19 0.19 0.02 -0.19 0.22 5978154.33 583400.29 N70211.008 W1491922.375 200.00 0.24 315.38 121.10 200.00 -0.52 0.58 0.56 0.19 -0.53 0.16 5978154.49 583399.95 N 70 21 1.010 W 14919 22.385 300.00 1.20 344.19 221.09 299.99 -0.93 1.82 1.66 1.35 -0.96 1.00 5978155.65 583399.50 N70211.021 W1491922.397 400.00 4.24 24.55 320.97 399.87 0.42 6.42 5.73 5.72 0.29 3.42 5978160.03 583400.71 N70211.064 W1491922.361 500.00 8.65 42.65 420.32 499.22 7.26 17.56 16.17 14.62 6.92 4.80 5978169.00 583407.24 N 70 211.151 W 1491922.167 600.00 13.48 59.43 518.46 597.36 22.66 36.62 34.17 26.09 22.07 5.76 5978180.64 583422.25 N 70 211.264 W 14919 21.724 Last GYD-GC-SS 700.00 17.82 69.70 614.75 693.65 47.31 63.52 59.61 37.33 46.47 5.13 5978192.15 583446.53 N70211.375 W1491921.011 First MWD+IFR+MS 761.24 21.31 76.88 672.45 751.35 67.07 84.00 78.92 43.11 66.10 6.91 5978198.15 583466.09 N 70 21 1.432 W 14919 20.437 856.18 25.18 81.15 759.68 838.58 104.00 121.45 114.44 50.14 102.88 4.44 5978205.58 583502.78 N 70211.501 W 1491919.363 952.65 26.70 83.76 846.43 925.33 145.94 163.64 155.04 55.65 144.70 1.97 5978211.56 583544.54 N 70211.555 W 1491.0 1 046.45 30.44 86.58 928.79 1007.69 190.70 208.49 198.4 7 59.36 189.39 4.24 5978215.77 583589.18 N70211.591W1491 4 1140.15 33.72 87.35 1008.18 1087.08 240.43 258.24 246.98 61.98 239.08 3.53 5978218.94 583638.83 N 70 211.617 W 1491915.382 1235.68 34.28 84.63 1087.38 1166.28 293.78 311.66 299.65 65.72 292.35 1.70 5978223.27 583692.06 N70211.654 W1491913.825 1330.95 35.90 86.00 1165.33 1244.23 348.45 366.42 353.96 70.18 346.93 1.89 5978228.34 583746.58 N70211.698 W1491912.230 1423.76 38.07 85.81 1239.46 1318.36 404.21 422.25 409.40 74.17 402.62 2.34 5978232.95 583802.21 N 70 211.737 W 1491910.603 1517.65 39.30 87.00 1312.75 1391.65 462.85 480.93 467.71 77.84 461.19 1.53 5978237.27 583860.73 N 70 211.773 W 149 198.891 1612.03 41.31 87.21 1384.72 1463.62 523.87 541.98 528.39 80.92 522.16 2.13 5978241.03 583921.66 N 70 211.803 W 14919 7.109 1706.83 43.30 87.02 1454.83 1533.73 587.65 605.79 591.89 84.14 585.88 2.10 5978244.95 583985.33 N 70 211.835 W 149195.247 1804.33 42.13 87.20 1526.47 1605.37 653.77 671.92 657.78 87.47 651.94 1.21 5978249.02 584051.34 N 70 211.868 W 149 193.317 1898.78 42.34 89.08 1596.40 1675.30 717.24 735.41 720.96 89.53 715.38 1.36 5978251.79 584114.76 N 70 211.888 W 149191.462 1993.31 42.58 91.01 1666.14 1745.04 781.03 799.22 784.31 89.48 779.19 1.40 5978252.44 584178.55 N 70 211.887 W 14918 59.597 2085.82 45.21 91.87 1732.80 1811.70 845.09 863.35 847.87 87.85 843.31 2.92 5978251.54 584242.68 N 70 211.871 W 14918 57.724 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) S-W\L-214\L-214\L-214 Generated 6/1/2005 4:22 PM Page 1 of 3 Comments Measured I Inclination I Azimuth I Sub·Sea TVD I TVD Vertical I Along Hole I Closure I NS EW I DLS I Northing Easting Latitude LongitudlT Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (ftUS) (ftUS) 2182.61 48.86 92.86 1798.76 1877.66 915.76 934.17 917.99 84.91 914.06 3.84 5978249.38 584313.45 N 7021 1.842 W 149 18 55.656 2275.28 53.66 92.30 1856.73 1935.63 987.86 1006.43 989.62 81.67 986.25 5.20 5978246.95 584385.66 N70211.810 W1491853.546 2370.26 59.18 90.65 1909.25 1988.15 1066.86 1085.53 1068.29 79.67 1065.32 5.99 5978245.83 584464.74 N70211.791 W1491851.236 2463.99 59.57 91.10 1957.00 2035.90 1147.46 1166.18 1148.64 78.44 1145.96 0.59 5978245.49 584545.39 N 70 21 1.778 W 1491848.879 2556.68 60.63 91.51 2003.20 2082.10 1227.72 1246.53 1228.68 76.61 1226.29 1.21 5978244.55 584625.73 N70211.760 W1491846.531 2651.98 60.80 91.23 2049.82 2128.72 1310.75 1329.66 1311.51 74.62 1309.39 0.31 5978243.49 584708.83 N 70211.741 W 14918 44.103 2746.55 61.64 88.08 2095.36 2174.26 1393.61 1412.54 1394.29 75.13 1392.26 3.05 5978244.92 584791.69 N 70 211.745 W 14918 41.681 2840.54 60.50 89.02 2140.82 2219.72 1475.87 1494.80 1476.51 77.22 1474.49 1.50 5978247.92 584873.88 N70211.766 W1491839.278 2935.20 59.91 90.70 2187.86 2266.76 1558.00 1576.94 1558.56 77.42 1556.63 1.66 5978249.04 584956.01 N 70 21 1.768 W 14918 36.877 3030.00 61.08 88.69 2234.56 2313.46 1640.48 1659.44 1640.98 77.87 1639.13 2.22 5978250.41 585038.49 N 70 21 1.772 W 14918 34.466 3123.48 61.65 88.79 2279.35 2358.25 1722.53 1741.49 1723.00 79.67 1721.16 0.62 5978253.12 585120.48 N70211.789 W14918.9 3217.09 62.54 88.23 2323.16 2402.06 1805.25 1824.21 1805.71 81.82 1803.85 1.09 5978256.20 585203.14 N 70 211.810 W 14918 2 3312.95 62.53 86.69 2367.38 2446.28 1890.28 1909.27 1890.76 85.59 1888.82 1.43 5978260.91 585288.05 N70211.847 W1491827.169 3407.31 62.24 87.34 2411.12 2490.02 1973.86 1992.88 1974.37 89.95 1972.32 0.68 5978266.19 585371.49 N 7021 1.890 W 149 1824.729 3500.76 59.94 87.81 2456.29 2535.19 2055.64 2074.68 2056.17 93.41 2054.04 2.50 5978270.57 585453.16 N 70211.924 W 14918 22.340 3595.50 61.40 89.47 2502.70 2581.60 2138.23 2157.27 2138.74 95.36 2136.61 2.17 5978273.44 585535.69 N 70 211.943 W 1491819.927 3689.44 60.96 87.99 2547.98 2626.88 2220.53 2239.57 2221.02 97.19 2218.89 1.46 5978276.17 585617.94 N70211.960 W1491817.522 3783.71 61.02 89.36 2593.70 2672.60 2302.97 2322.02 2303.44 99.09 2301.31 1.27 5978279.00 585700.32 N70211.979 W1491815.114 3826.45 61.59 89.15 2614.22 2693.12 2340.46 2359.51 2340.91 99.58 2338.79 1.40 5978279.90 585737.80 N 70211.984 W 1491814.018 ( Inc only + Trend) 3894.41 59.44 89.62 2647.67 2726.57 2399.61 2418.66 2400.04 100.22 2397.95 3.22 5978281.20 585796.94 N70211.990 W1491812.290 3989.29 58.53 90.30 2696.56 2775.46 2480.90 2499.97 2481.29 100.28 2479.26 1.14 5978282.16 585878.24 N 70 211.990 W 149189.913 4085.58 60.85 91.75 2745.15 2824.05 2563.95 2583.10 2564.27 98.78 2562.36 2.74 5978281.59 585961.35 N 70 211.975 W 149 18 7.484 4179.75 61.19 91.53 2790.78 2869.68 2646.22 2665.47 2646.47 96.42 2644.71 0.41 5978280.15 586043.70 N 7021 1.951 W 149 18 5.078 4273.98 60.27 90.84 2836.85 2915.75 2728.34 2747.67 2728.53 94.72 2726.89 1.17 5978279.36 586125.89 N 70211.934 W 149182.676 4368.86 62.08 91.87 2882.60 2961.50 2811.37 2830.79 2811.51 92.75 2809.98 2.13 5978278.31 586208.99 N 70 211.915 W 149180.248 4462.58 61.23 91.84 2927.09 3005.99 2893.73 2913.28 2893.83 90.08 2892.42 0.91 5978276.56 586291.45 N70211.888 W1491757.839 4557.83 60.40 91.56 2973.54 3052.44 2976.77 2996.43 2976.83 87.61 2975.54 0.91 5978275.02 586374.59 N 70 211.864 W 1491755.409 4653.01 59.91 91.79 3020.91 3099.81 3059.21 3078.99 3059.25 85.20 3058.07 0.56 5978273.52 586457.12 N 70 211.839 W 149 17 52.998 4746.96 61.66 93.12 3066.76 3145.66 3141.03 3160.98 3141.05 81.68 3139.98 2.24 5978270.92 586539.06 N70211.805 W1491~r 4841.24 60.67 92.93 3112.23 3191.13 3223.38 3243.57 3223.39 77.32 3222.46 1.06 5978267.48 586621.57 N70211.761W1491 4 4935.88 59.47 93.26 3159.45 3238.35 3305.16 3325.59 3305.16 72.89 3304.35 1.30 5978263.96 586703.51 N 70 211.717 W 149174 .800 5030.47 59.69 93.42 3207.34 3286.24 3386.46 3407.16 3386.47 68.14 3385.78 0.27 5978260.12 586784.98 N 70 211.670 W 14917 43.420 5124.41 59.50 92.14 3254.89 3333.79 3467.27 3488.18 3467.30 64.21 3466.71 1.19 5978257.09 586865.93 N 70 21 1.631 W 14917 41.056 5218.55 61.10 92.26 3301.53 3380.43 3548.89 3569.95 3548.94 61.07 3548.42 1.70 5978254.86 586947.66 N 70 211.600 W 1491738.668 5312.50 61.83 91.60 3346.41 3425.31 3631.29 3652.49 3631.37 58.29 3630.91 0.99 5978253.00 587030.17 N 70211.572 W 14917 36.257 5407.89 61.02 91.94 3392.04 3470.94 3714.94 3736.26 3715.05 55.70 3714.64 0.91 5978251.34 587113.92 N 70 211.547 W 1491733.810 5501.83 60.06 89.94 3438.24 3517.14 3796.66 3818.05 3796.80 54.35 3796.41 2.12 5978250.90 587195.69 N70211.533 W1491731.420 5596.80 62.08 89.95 3484.18 3563.08 3879.76 3901.16 3879.91 54.43 3879.53 2.13 5978251.91 587278.79 N 70 211.533 W 14917 28.991 5690.29 61.02 90.00 3528.72 3607.62 3961.93 3983.36 3962.10 54.47 3961.72 1.13 5978252.86 587360.98 N70211.533 W1491726.589 5783.58 61.43 91.19 3573.62 3652.52 4043.66 4065.13 4043.84 53.62 4043.49 1.20 5978252.92 587442.74 N 70 211.524 W 1491724.200 5878.44 62.93 89.92 3617.89 3696.79 4127.50 4149.02 4127.71 52.81 4127.38 1.98 5978253.05 587526.62 N70211.516 W1491721.748 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) S-W\L-214\L-214\L-214 Generated 6/1/20054:22 PM Page 2 of 3 Comments ( 'nc only + Trend) Last MWO+IFR+MS TO ( Projected) Measured I Depth (It) 5972.90 6067.81 6161.37 6254.63 6349.56 6443.99 6537.26 6632.00 6726.26 6820.45 6914.71 7008.73 7103.33 7185.30 7259.97 7354.41 7448.56 7542.87 7585.33 7640.00 Inclination I (deg) 62.02 61.58 60.73 59.64 58.81 58.86 58.33 58.20 58.01 57.64 54.80 51.28 48.15 46.42 45.18 44.29 43.30 42.48 42.00 42.00 Azimuth I Sub-Sea TVD I (deg) (It) 89.40 3661.55 87.68 87.92 87.36 87.68 86.41 85.90 85.83 85.20 85.59 85.24 85.17 86.55 87.49 87.98 88.60 88.92 89.27 89.96 89.96 3706.40 3751.54 3797.91 3846.48 3895.35 3943.95 3993.78 4043.58 4093.74 4146.15 4202.67 4263.83 4319.43 4371.49 4438.58 4506.53 4575.63 4607.07 4647.69 TVD (It) 3740.45 3785.30 3830.44 3876.81 3925.38 3974.25 4022.85 4072.68 4122.48 4172.64 4225.05 4281.57 4342.73 4398.33 4450.39 4517.48 4585.43 4654.53 4685.97 4726.59 Vertical I Section (It) 4211.26 4294.90 4376.84 4457.74 4539.28 4620.05 4699.58 4780.06 4859.96 4939.55 5017.76 5092.74 5164.80 5225.00 5278.52 5344.99 5410.15 5474.33 5502.87 5539.44 Along Hole I Departure (It) 4232.79 4316.43 4398.38 4479.30 4560.86 4641.66 4721.26 4801.84 4881.87 4961.59 5039.93 5115.05 5187.20 5247.42 5300.96 5367.42 5432.58 5496.77 5525.31 5561.89 Closure I (It) 4211.48 4295.11 4377.04 4457.92 4539.45 4620.19 4699.69 4780.14 4860.02 4939.59 5017.79 5092.75 5164.81 5225.00 5278.53 5344.99 5410.15 5474.33 5502.87 5539.45 NS (It) 53.31 55.44 58.58 61.91 65.44 69.61 74.95 80.76 87.01 93.41 99.67 105.95 111.18 114.32 116.44 118.42 119.83 120.85 121.04 121.07 ~~ I (de;~:OIt) I 4211.14 1.08 4294.75 4376.64 4457.49 4538.97 4619.67 4699.09 4779.46 4859.24 4938.71 5016.80 5091.65 5163.61 5223.75 5277.24 5343.68 5408.82 5473.00 5501.54 5538.12 Northing (ltUS) 5978254.47 1.66 5978257.53 0.94 5978261.59 1.28 5978265.82 0.92 5978270.26 1.15 5978275.32 0.74 5978281.54 0.15 5978288.24 0.60 5978295.39 0.53 5978302.67 3.03 5978309.80 3.74 5978316.91 3.49 5978322.94 2.27 5978326.74 1.73 5978329.46 1.05 5978332.18 1.08 5978334.32 0.91 5978336.05 1.57 5978336.56 0.00 5978336.99 Survey Type: Definitive Survey NOTES: GYD-GC-SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leqal Description: Surface: 2430 FSL 3515 FEL S34 T12N R11 E UM BHL: 2549 FSL 3257 FEL S35 T12N R11 E UM SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) Northing (Y) [ftUS] 5978154.31 5978336.99 Easting (X) [ftUS] 583400.48 588936.39 S-W\L-214\L-214\L-214 Easting (ltUS) 587610.37 587693.95 587775.79 587856.58 587938.02 588018.65 588098.01 588178.29 588257.99 588337.38 588415.38 588490.16 588562.05 588622.15 588675.60 588742.01 588807.13 588871.28 588899.82 588936.39 Latitude Longitude. N70211.520 W1491719.300 N 70 21 1.541 W 1491716.856 N70211.571 W1491714.463 N 70 211.604 W 1491712.100 N70211.638 W149179.719 N 70 21 1.678 W 149 17 7.361 N70211.730 W149175.039 N 70 21 1.787 W 14917 2.691 N 7021 1.848 W 149170.359 N 70 211.910 W 14916 58.036 N 70 21 1.971 W 149 1655.754 N 70 21 2.033 W 14916.6 N 70 21 2.084 W 149 1651.463 N 70 21 2.114 W 149 1649.705 N 70 212.135 W 14916 48.142 N 70 212.154 W 1491646.200 N 70 21 2.167 W 149 1644.297 N 70 212.177 W 14916 42.421 N 70 21 2.178 W 149 1641.587 N 70 212.178 W 14916 40.518 . Generated 6/1/2005 4:22 PM Page 3 of 3 TREE = W~LHEA[!O= A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/16" CrN FMC NA 78.9' 50.4' 300' 63 @ 5878' xxxx' xxxx'SS 13-3/8" CSG, 68#, L-80,ID = 12.415"-1 I Minimum ID = 2.813" 3-1/2" HES X NIPPLE /4-1/2" TBG JOINTW/ RA MARKER 19-5/8", SHORT JT W/ RA TAG 14-1/2" BKR, CMD SLDG SLEEVE, ID = 3.813" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9-5/8" CSG, 47#, L-80, .0732 bpf, ID = 8.681" I 7" WTFD EXP ZONAL ISOLATION A<R I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, 10 = 2.992" H I 7" WTFD EXP ZONAL ISOLATION A<R . L-214i - - =1 I 3872' ~ H 6405' ~~ H 6525' _ ____ I I H 1032' ~- _ I H 1071' \' ,~---j H 1253' ~?S ~ 1--1., I - :~ I ---L ~ --l : ~~ ....J ~!:::¡ I I I 7436' I I ~ H 7314' EXPANOABLE SLOTTED SCREEN SUMMARY REF LOG: SWS usrr 5/31/05 ANGLE AT TOP PERF: 45° @ 7260' Note: Refer to Production OB for historical perf data SIZE SFf" INTERV AL Opn/Sqz OA TE 7" ESS 7257-7314 Open 05/30/05 7" ESS 7359-7434 Open 05/30/05 7" ESS 7554-7612 Open 05/30/05 17" CSG, 29#, 13Cr, ID = 6.059" H 7622' DATE 04/22/05 06/03/05 REV BY RBT TA COMMENTS PROPOSED COMPLETION ORIGINAL COMPLETION r '- OATE REV BY I I I I I -' COMMENTS ~AFETYNOTES: Gl..M'S@STA#1-#4ARE -112" X 1" KBGs, WHICH ARE ATERFLOOD MANDRELS. 1017' 6938' 1-1 13-3/8" TAM PORT 1 COLLAR H 4-1/2" HES X NIP, ID = 3.813" I ¡ ST 5 4 3 2 1 WA TERFLOOD MANDRELS MD TVD DEV TYÆ VLV LATCH PORT DATE 6958 4251 55° MMG-W SHR RKP YES 06/03/05 7257 4448 45° KBG DUM BK NO 06/03/05 7282 4466 45° KBG DUM BK NO 06/03/05 7381 4536 44° KBG DUM BK NO 06/03/05 7407 4555 44° KBG OUM BK NO 06/03/05 7043' 1-1 4-1/2" HES X NIP, ID = 3.813" I 7063' H 9-5/8" X 4-1/2" WTFD HELLCA T PKR, ID = I 3.933" 7077' 1-1 4-1/2" x 3-1/2" XO, ID = 2.992" 1 7128' I I 9-5/8" X 7" BKR MLZXP, L TP, ID = 6.059" I 7309' H 3-112" HES X NIP, ID = 2.813" I 7320' H 3.5" WTFD SNGL GAUGE MANOREL,ID = 2.98" 7348' H 7"X3-1/2" WTFD HELLCA T PKR, ID=2.992" I 7433' 1-1 3-1/2" HES X NIP, ID = 2.813" , 7438' LI 3.5" WTFD DUAL GAUGE MANDREL,ID = í 2.98" 7469' I I 7" X 3-1/2" VVTFD UPfH A<R, ID = 2.98" I 7485' H 3-1/2" HES X NIP, ID = 2.813" I 7493' H 3-1/2" WLEG, ID = 2.98" I 7519' I I 7" WTFO EXPZONAL ISOLATION A<R ORION UNrr WELL: L-214i ÆRMrr No: 205-052 API No: 50-029-23258-00 SEC 34, T12N, R11E, 2430' FSL & 3515' FEL BP Exploration (Alaska) SCRLUMBERGER Survey report Client. ........... .......: BP Exploration (Alaska) Inc Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: L-214 API number... ... .........: 50-029-23258-00 Engineer.... ... ..........: F. Medina 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.......: 50.30 ft KB above permanent.......: N/A Top Drive DF above permanent. ......: 78.90 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 Vsect Origin to target: 88.69 degrees ~ V '1 c "", r [(c)2005 IDEAL ID9_lC_01.4] 25-May-2005 11:49:52 Spud date. . . . .. . . . . . . . . . . : Last survey date...... ...: Total accepted surveys. . . : MD of first survey.... ...: MD of last survey........: Page 1 of 4 16-May-05 25-May-05 84 0.00 ft 7640.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date..... .......: 15-May-2005 Magnetic field strength..: 1152.25 RCNT Magnetic dec (+E/W-).. ...: 24.47 degrees Magnetic dip........... ..: 80.81 degrees ----- MWD survey Reference Reference G..............: Reference R. .......... ...: Reference Dip.......... ..: Tolerance of G.... .......: Tolerance of R....... ....: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1152.25 RCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.47 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 24.47 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Sch1umberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 25-May-2005 11:49:52 Page 2 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- ----~--- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.22 276.22 100.00 100.00 -0.19 0.02 -0.19 0.19 276.22 0.22 GYRO None 3 200.00 0.24 315.38 100.00 200.00 -0.52 0.19 -0.53 0.56 289.83 0.16 GYRO None 4 300.00 1. 20 344.19 100.00 299.99 -0.93 1. 35 -0.96 1. 66 324.49 1. 00 GYRO None 5 400.00 4.24 24.55 100.00 399.87 0.42 5.72 0.29 5.73 2.90 3.42 GYRO None 6 500.00 8.65 42.65 100.00 499.22 7.26 14.62 6.92 16.17 25.35 4.80 GYRO None . 7 600.00 13 .48 59.43 100.00 597.36 22.66 26.09 22.07 34.17 40.23 5.76 GYRO None 8 700.00 17.82 69.70 100.00 693.65 47.31 37.33 46.47 59.61 51.22 5.13 GYRO None 9 761. 24 21. 31 76.88 61. 24 751.35 67.07 43.11 66.10 78.92 56.89 6.91 MWD_ IFR_MS 10 856.18 25.18 81.15 94.94 838.58 104.00 50.14 102.88 114.44 64.02 4.44 MWD_ IFR_MS 11 952.65 26.70 83.76 96.47 925.33 145.94 55.65 144.70 155.04 68.96 1. 97 MWD - IFR_MS 12 1046.45 30.44 86.58 93.80 1007.69 190.70 59.36 189.39 198.47 72.60 4.24 MWD_ IFR_MS 13 1140.15 33.72 87.35 93.70 1087.08 240.43 61. 98 239.08 246.98 75.47 3.53 MWD_ IFR_MS 14 1235.68 34.28 84.63 95.53 1166.28 293.78 65.72 292.35 299.65 77.33 1. 70 MWD_ IFR_MS 15 1330.95 35.90 86.00 95.27 1244.23 348.45 70.18 346.93 353.96 78.56 1. 89 MWD_ IFR_MS 16 1423.76 38.07 85.81 92.81 1318.36 404.21 74.17 402.62 409.40 79.56 2.34 MWD_ IFR_MS 17 1517.65 39.30 87.00 93.89 1391.65 462.85 77.84 461.19 467.71 80.42 1. 53 MWD_ IFR_MS 18 1612.03 41. 31 87.21 94.38 1463.62 523.87 80.92 522.16 528.39 81.19 2.13 MWD_ IFR_MS 19 1706.83 43.30 87.02 94.80 1533.73 587.65 84.14 585.88 591.89 81. 83 2.10 MWD_ IFR_MS 20 1804.33 42.13 87.20 97.50 1605.37 653.77 87.47 651. 94 657.78 82.36 1. 21 MWD_ IFR_MS 21 1898.78 42.34 89.08 94.45 1675.30 717.24 89.53 715.38 720.96 82.87 1. 36 MWD - IFR_MS . 22 1993.31 42.58 91. 01 94.53 1745.04 781. 03 89.48 779.19 784.31 83.45 1. 40 MWD_ IFR_MS 23 2085.82 45.21 91. 87 92.51 1811.70 845.09 87.85 843.31 847.87 84.05 2.92 MWD_ IFR_MS 24 2182.61 48.86 92.86 96.79 1877.66 915.76 84.91 914.06 917.99 84.69 3.84 MWD_ IFR_MS 25 2275.28 53.66 92.30 92.67 1935.63 987.86 81. 67 986.25 989.62 85.27 5.20 MWD - IFR_MS 26 2370.26 59.18 90.65 94.98 1988.15 1066.86 79.67 1065.32 1068.29 85.72 5.99 MWD_ IFR_MS 27 2463.99 59.57 91.10 93.73 2035.90 1147.46 78.44 1145.96 1148.64 86.08 0.59 MWD_ IFR_MS 28 2556.68 60.63 91. 51 92.69 2082.10 1227.72 76.61 1226.29 1228.68 86.43 1.21 MWD_ IFR_MS 29 2651.98 60.80 91. 23 95.30 2128.72 1310.75 74.62 1309.39 1311. 51 86.74 0.31 MWD_ IFR_MS 30 2746.55 61. 64 88.08 94.57 2174.26 1393.61 75.13 1392.26 1394.29 86.91 3.05 MWD - IFR_MS [(c)2005 IDEAL ID9_1C_01.4J SCHLUMBERGER Survey Report 25-May-2005 11:49:52 Page 3 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2840.54 60.50 89.02 93.99 2219.72 1475.87 77.22 1474.49 1476.51 87.00 1. 50 MWD_IFR_MS 32 2935.20 59.91 90.70 94.66 2266.76 1558.00 77.42 1556.63 1558.56 87.15 1. 66 MWD_IFR_MS 33 3030.00 61.08 88.69 94.80 2313.45 1640.48 77.87 1639.13 1640.98 87.28 2.22 MWD_IFR_MS 34 3123.48 61. 65 88.79 93.48 2358.25 1722.53 79.67 1721.16 1723.00 87.35 0.62 MWD - IFR_MS 35 3217.09 62.54 88.23 93.61 2402.06 1805.25 81. 82 1803.85 1805.71 87.40 1. 09 MWD_IFR_MS 36 3312.95 62.53 86.69 95.86 2446.28 1890.28 85.59 1888.82 1890.76 87.41 1.43 MWD_IFR_MS . 37 3407.31 62.24 87.34 94.36 2490.02 1973.86 89.95 1972.32 1974.37 87.39 0.68 MWD_IFR_MS 38 3500.76 59.94 87.81 93.45 2535.19 2055.64 93.41 2054.04 2056.17 87.40 2.50 MWD_IFR_MS 39 3595.50 61. 40 89.47 94.74 2581. 60 2138.23 95.36 2136.61 2138.74 87.44 2.17 MWD_IFR_MS 40 3689.44 60.96 87.99 93.94 2626.88 2220.53 97.19 2218.89 2221.02 87.49 1. 46 MWD_IFR_MS 41 3783.71 61.02 89.36 94.27 2672.60 2302.97 99.09 2301.31 2303.44 87.53 1.27 MWD_IFR_MS 42 3826.45 61.59 89.15 42.74 2693.12 2340.46 99.58 2338.79 2340.91 87.56 1. 40 MWD_IFR_MS 43 3894.41 59.44 89.62 67.96 2726.57 2399.61 100.22 2397.95 2400.04 87.61 3.22 INC_TREND 44 3989.29 58.53 90.30 94.88 2775.46 2480.90 100.28 2479.26 2481.29 87.68 1.14 MWD_IFR_MS 45 4085.58 60.85 91. 75 96.29 2824.05 2563.95 98.78 2562.36 2564.27 87.79 2.74 MWD - IFR_MS 46 4179.75 61.19 91. 53 94.17 2869.68 2646.22 96.42 2644.71 2646.47 87.91 0.41 MWD_IFR_MS 47 4273.98 60.27 90.84 94.23 2915.75 2728.34 94.72 2726.89 2728.53 88.01 1.17 MWD_IFR_MS 48 4368.86 62.08 91. 87 94.88 2961.50 2811.37 92.75 2809.98 2811.51 88.11 2.13 MWD_IFR_MS 49 4462.58 61. 23 91. 84 93.72 3005.99 2893.73 90.08 2892.42 2893.83 88.22 0.91 MWD - IFR_MS 50 4557.83 60.40 91. 56 95.25 3052.44 2976.77 87.61 2975.54 2976.83 88.31 0.91 MWD_IFR_MS 51 4653.01 59.91 91.79 95.18 3099.80 3059.21 85.20 3058.07 3059.25 88.40 0.56 MWD_IFR_MS . 52 4746.96 61. 66 93.12 93.95 3145.66 3141. 03 81. 68 3139.98 3141. 05 88.51 2.24 MWD_IFR_MS 53 4841.24 60.67 92.93 94.28 3191.13 3223.38 77 .32 3222.46 3223.39 88.63 1. 06 MWD_IFR_MS 54 4935.88 59.47 93.26 94.64 3238.35 3305.16 72.89 3304.35 3305.16 88.74 1. 30 MWD_IFR_MS 55 5030.47 59.69 93.42 94.59 3286.24 3386.46 68.14 3385.78 3386.47 88.85 0.27 MWD_IFR_MS 56 5124.41 59.50 92.14 93.94 3333.79 3467.27 64.21 3466.71 3467.30 88.94 1.19 MWD_IFR_MS 57 5218.55 61.10 92.26 94.14 3380.43 3548.89 61.07 3548.42 3548.94 89.01 1. 70 MWD_IFR_MS 58 5312.50 61.83 91. 60 93.95 3425.31 3631.29 58.29 3630.91 3631.37 89.08 0.99 MWD_IFR_MS 59 5407.89 61.02 91. 94 95.39 3470.94 3714.94 55.70 3714.64 3715.05 89.14 0.90 MWD - IFR_MS 60 5501.83 60.06 89.94 93.94 3517 .14 3796.66 54.35 3796.41 3796.80 89.18 2.12 MWD - IFR_MS [(c)2005 IDEAL ID9_1C_01.4J ; SCHLUMBERGER Survey Report 25-May-2005 11:49:52 Page 4 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5596.80 62.08 89.95 94.97 3563.08 3879.76 54.43 3879.53 3879.91 89.20 2.13 MWD_ IFR_MS 62 5690.29 61.02 90.00 93.49 3607.61 3961.93 54.47 3961.72 3962.10 89.21 1.13 MWD_ IFR_MS 63 5783.58 61.43 91.19 93.29 3652.52 4043.66 53.62 4043.49 4043.84 89.24 1.20 MWD_ IFR_MS 64 5878.44 62.93 89.92 94.86 3696.79 4127.50 52.81 4127.38 4127.71 89.27 1. 98 MWD_ IFR_MS 65 5972.90 62.02 89.40 94.46 3740.45 4211.26 53.31 4211.14 4211. 48 89.27 1. 08 MWD_ IFR_MS 66 6067.81 61. 58 87.68 94.91 3785.30 4294.90 55.44 4294.75 4295.11 89.26 1. 66 MWD_ IFR_MS . 67 6161. 37 60.73 87.92 93.56 3830.44 4376.84 58.58 4376.64 4377.04 89.23 0.94 MWD - IFR_MS 68 6254.63 59.64 87.36 93.26 3876.80 4457.74 61. 91 4457.49 4457.92 89.20 1.28 MWD_ IFR_MS 69 6349.56 58.81 87.68 94.93 3925.38 4539.28 65.44 4538.97 4539.45 89.17 0.92 MWD - IFR_MS 70 6443.99 58.86 86.41 94.43 3974.25 4620.05 69.61 4619.67 4620.19 89.14 1.15 MWD_ IFR_MS 71 6537.26 58.33 85.90 93.27 4022.85 4699.58 74.95 4699.09 4699.69 89.09 0.74 MWD_ IFR_MS 72 6632.00 58.20 85.83 94.74 4072.68 4780.05 80.76 4779.46 4780.14 89.03 0.15 MWD_ IFR_MS 73 6726.26 58.01 85.20 94.26 4122.48 4859.96 87.01 4859.24 4860.02 88.97 0.60 MWD_ IFR_MS 74 6820.45 57.64 85.59 94.19 4172 . 64 4939.55 93.41 4938.71 4939.59 88.92 0.53 MWD_ IFR_MS 75 6914.71 54.80 85.24 94.26 4225.05 5017.76 99.67 5016.80 5017.79 88.86 3.03 MWD - IFR_MS 76 7008.73 51. 28 85.17 94.02 4281.57 5092.74 105.95 5091.65 5092.75 88.81 3.74 MWD - IFR_MS 77 7103.33 48.15 86.55 94.60 4342.73 5164.80 111.18 5163.61 5164.81 88.77 3.49 MWD_ IFR_MS 78 7185.30 46.42 87.49 81. 97 4398.33 5225.00 114.32 5223.75 5225.00 88.75 2.27 MWD_ IFR_MS 79 7259.97 45.18 87.98 74.67 4450.39 5278.52 116.44 5277.24 5278.52 88.74 1. 73 INC_TREND 80 7354.41 44.29 88.60 94.44 4517.48 5344.99 118.42 5343.68 5344.99 88.73 1. 05 MWD_ IFRjiS - SAG 81 7448.56 43.30 88.92 94.15 4585.43 5410.15 119.83 5408.82 5410.15 88.73 1. 08 MWD_ IFR_MS - SAG . 82 7542.87 42.48 89.27 94.31 4654.53 5474.33 120.85 5473.00 5474.33 88.74 0.91 MWD_ IFR_MS - SAG 83 7585.33 42.00 89.96 42.46 4685.96 5502.87 121.04 5501.54 5502.87 88.74 1. 57 MWD - IFR_MS - SAG 84 7640.00 42.00 89.96 54.67 4726.59 5539.44 121. 07 5538.12 5539.45 88.75 0.00 Projection to TD [(c) 2005 IDEAL ID9_1C_01.4] . . Schlumberger Drilling & Measurements MWD/lWD log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman (AOGCC) Well No L-214 Date Dispatched: l-Jun-05 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 Received By: ~/Jt1J Please sign and return to: James H. Johnson BP Exploration (Alaskallnc. Petratechnical Data Center (LR2-11 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery Vl.l, 10-02-03 ).ò S'-- or J.- · ~ · · e gyro data Gyrodata Incorporated 1682 W Sam Houston Pkwy. N. Houston. Texas 77043 713/461-3146 Fax: 713/461-0920 e SURVEY REPORT BP L-PAD #L-214 NABORS #9ES PRUDHOE BAY, AK AK0505G _549 MAY 17, 2005 (Ç (Q)O-:~'·'.'. r r··:::-~;~..;. '\'\ ¡';ï' \ I ¡ ! ¡. <J I ! It::/ H Serving the Worldwide Energy Industry with Precision Survey Instrumentation · · · e gyro data e Gyrodata Incorporated 1682 W Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 May 26, 2005 Ms. Sharmaine Copeland BP Exploration (Alaska) Inc. 900 E. Benson Blvd. Anchorage, Alaska 99508 Re: L-Pad, Well #L-214 Prudhoe Bay, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) discs of the completed survey of the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, dl54p Rob Snoup North American Operations Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation . . . A Gyrodata Directi onal Survey for BP EXPLORA nON (ALASKA) INC. Lease: L-Pad Well: L-214, e Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK0505G_549 Run Date: 17 May 2005 Surveyor: Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350280 deg. N Longitude: 149.322880 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North e Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location . . . A Gyrodata Directi onal Survey BP Exploration (Alaska) Inc. Lease: L-Pad Well: L-214 Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK0505G 549 deg. deg. BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg.l 1 00 ft. VERTICAL DEPTH feet CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet MEASURED DEPTH feet IN C L AZIMUTH 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0.00 N 0.00 E e ...--..-------------------------------...-------------------...------------------..------------------------------------------------..------------------------------------------------..------------------...-- 0- 700 FT. RATE GYROSCOPIC MULTI SHOT AND MOTOR ORIENTATION ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9ES R.K.B. OF 28.50 FT. ----------------....-----------------------------..------------------------------------------------------------------------------------------------------------------..---.._----.._---.._----.._--------- 100.00 0.22 276.22 N 83 47 W 0.22 100.00 0.2 276.2 0.02 N 0.19W 200.00 0.24 315.38 N 44 37 W 0.16 200.00 0.6 289.8 0.19 N 0.53W 300.00 1.20 344.19 N 15 48 W 0.99 299.99 1.7 324.4 1.35 N 0.97W 400.00 4.24 24.55 N 24 33 E 3.42 399.87 5.7 2.9 5.72 N 0.29 E 500.00 8.65 42.65 N 42 39 E 4.80 499.22 16.2 25.3 14.62 N 6.92 E 600.00 13.48 59.43 N 59 26 E 5.76 597.36 34.2 40.2 26.09 N 22.07 E 700.00 17.82 69.70 N 69 42 E 5.13 693.65 59.6 51.2 37.34 N 46.48 E Final Station Closure: Distance: 59.61 ft Az: 51.22 deg. e 2 BP Earation. (Alaska) Inc. Well: L-Pad L-214 Location: Nabors #9ES, Prudhoe Bay, Alaska . etrun Gyrodata AKOSOSG_S49 DEFINITIVE 35 BOTTOM HOLE LOCATED MD: 700.00 30 I ---T e 25 --- -+------- I ---- .:t= '-" --I 19 20 ---~---~-~-------~--- z ........ I I I ~ 1 0 I z 15 - A e 10 5 ~ \ 1 ; i I Ai i 1,,11 1 1 1 I o 5 i I I I I I I I I I I I I I I 1 I I I I I I I I I I I o 10 15 20 25 30 35 EASTING (ft) 40 45 BP Earatioli (Alaska) Inc. Well: L-Pad L-214 Location: Nabors #9ES, Prudhoe Bay, Alaska 15.0 . .trun Gyrodata AK0505G_549 DEFINITIVE 12.5 e 10.0 -~~-~-- ~ it= 0 0 ri ........ 01 OJ "'0 ........ ~ 7.5 ...... a:: LU > BOIOM HOLE LU (f) LOCATED t9 MD: 700.00 LU -1 t9 0 5.0 0 e 0.0 I 2.5 -- I ¡ I I I I+T I 100 .. ···-I---T---¡---a ,.-- 200 300 I I 400 500 MEASURED DEPTH Cft) 600 700 800 BP E.ration- (Alaska) Inc. Well: L-Pad L-214 Location: Nabors #9ES, Prudhoe Bay, Alaska I z ¡ 9 10.0 --------t- ~ I :J I U I Z I ..... ì 7. 5 ------r---~ I I i I I I i I I I I I i I I - I -LT------r I 100 17.5 15.0 12.5 0.0 - 5.0 2.5 I I -r---r---.- - I 200 / -. . A _A --·-A 300 400 500 MEASURED DEPTH Cft) I 600 .trun Gyrodata AK0505G_549 DEFINITIVE A ~----~_.,---- BOTTOM HOLE LOCATED MD: 700.00 I -~-- e --- -.---'-~~.-----.--'---'------_. -~-_._~-------~----" e ~-~._---.-- ~--- I I 700 800 BP EaratiOrt (Alaska) Inc. Well: L-Pad L-214 Location: Nabors #9ES, Prudhoe Bay, Alaska ! I --~----¡ ! , t I I t I I i 350 --- 300 - 250 200 :r: I- :J :E ....... N « 150 100 50 - - I . ._~-- --- ----&- .11(- 100 200 300 400 500 MEASURED DEPTH Cft) -- 600 .trun Gyrodata AK0505G_549 DEFINITIVE ~-,~_..-----~--,--.-._----,,- e --~~._-_.._-_.._-----~~ - t--- ---- e BOTTOM HOI F__. LOCATED M): 700.00 --A -------~ 700 I 800 ~u~1Œ . (ID~ . fÆT.\ r./r-I.FI. (Q~L.~.Vl m. ^ lJ\ ¡! '1\\ \, ¡ r' !/j\ \ L6L~ c0 UÙLru FRANK H. MURKOWSKI, GOVERNOR A"~~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-214i BP Exploration (Alaska) Inc. Permit No: 205-052 Surface Location: 2430' FSL, 3415' FEL, SEC. 34, TI2N, RIlE, UM Bottomhole Location: 2554' FSL, 2023' FEL, SEC. 35, TI2N, RIlE, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or 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. se provide at least twenty-four (24) hours notice for a representative of the Commissio to w~tness any required test. Contact the Commission's petroleum field inspector at (907) 65 -3607 ]Jager). DATED this30 day of March, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. /: . \ I STATE OF ALASKA · ALAS . Oil AND GAS CONSERVATION æMMISSION PERMIT TO DRILL wGA- S/ZIf/tbo5 ."" RECr=IVED MAR 2 5 2005 18. Casing Program: Size Casing 20" 13-3/8" 9-518" III Orill 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: 2430' NSL, 3515' WEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 2553' NSL, 1976' EWL, SEC. 35, T12N, R11 E, UM Total Depth: 2554' NSL, 2023' EWL, SEC. 35, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583400 y- 5978154 Zone- ASP4 16. Deviated Wells: Kickoff Oepth: 300 feet Maximum Hole Angle: 61.1 degrees Specifications Grade Coupling A-53 Welded L-80 BTC L -80 BTC-M 13Cr80 20 AAC 25.005 A'a~~8 Oil St. r, ~. . 1b. Current Well Class 0 Explorato~ 0 Oevelopment Oil ultl~'lbWJ)jH'SS' on o Stratigraphic Test II Service 0 Oevelopment Gas 'one 5. Bond: 1m Blanket 0 Single Well 11. Well Name and Number: ~ Bond No. 2S100302630-277 PBU L-214i ---- 6. Proposed Depth: 12. Field I Pool(s): MD 7713 TVD 4719 Prudhoe Bay Field I Orion 7. Property Designation: Schrader Bluff ADL 028238 8. Land Use Permit: 13. Approximate Spud Date: May 9, 2005 ~ 14. Distance to Nearest Property: 8,030' 9. Acres in Property: 2560 Hole 42" Weight 215.5# 68# 40#/47# 29# Length 80' 3832' 7279' 505' 10. KB Elevation 15. Distance to Nearest W~hin Pool (Height above GL):Plan 78.9 feet L-102 ~ 6.9W 17. Maximum Anticipated Pressures in psig (see 20 AAC . 5) Downhole: 2100 Surface: 63§/' Setting Depth· . . ..Quan .. .ofC.ement Top Bottom .(c.1; orisacks) MD TVD MD TVD (including stage data) 29' 29' 109' 109' 260 sx Arctic Set (Approx.) 29' 29' 3861' 2699' 958 sx Arcticset Lite, 599 sx 'G' 29' 29' 7308' 4422' 519 sx Class 'G' ~ 7208' 4347' 7713' 4719' Expanded Slotted Liner Screens -- 16" 12-1/4" 8-112" 7" 19. PRESENT WELL CONDITION SUMMARY (To be completed for RedriIlANDRe-entryOperations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Casing Length Size Cement Volume MD Structural Conductor Surface Intermediate Production Liner Junk (measured): TVD 20. Attachments 1m Filing Fee, $100 0 BOP Sketch 1m Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 1m Drilling Program 0 Time vs Depth Plot o Seabed Report 1m Drilling Fluid Program o Shallow Hazard Analysis 1m 20 AAC 25.050 Requirements Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name Robert Tirpack Title Senior Drilling Engineer ~.ð ./ . ~ Prepared By Name/Number: Signature /~~~~ Phone 564-4166 Date ,j.;;;5)tð - Terrie Hubble, 564-4628 Commission Use Only Permit To Drill I API Number: ..r-, I Permit Approval I See cover letter for Number: ZoS - 0 .Ç Z. 50- '0 :z '? - ..2 3.2..:;) ?' Date: other requirements Conditions of Approval: Samples q ired D Yes~No Mud Log Required D Yes ~No Hydro n Suit de Measures Yes;8J No Directional Survey Required )8Yes D No Other:T.e ~ t ß 0 P E 00 r <;. ¡ . ML T) e.t ~l.u.dÕ /.-U'-(¿ t:t.-l /.c 1 H¡ u-í ¡,...( d. APPROVED BY THE COMMISSION Date~¿i~ · I Well Name: I L-21~ Well Plan Summary I Type of Well (producer or injector): I Big Bore Injector Surface Location: 2,430' FSL, 3,515' FEL, Sec. 34, T12N, R11E / J!~~,!!:w~!2!,'!::~L",m=,,_=%_=,~,~~,~~,~':~~~w!w:~~,,?2~;,,~~~w__*_""_'_Wz&8*'m=_,_m='__ L-214i Polygon 2A Target 1 Top 2,553' FSL, 3,303' FEL, Sec. 35, T12N, R11E OBd: X = 588,890 Y = 5,978,340 Z = 4,590' TVDss L-214i Polygon 2A BHL: 2,554' FSL, 3,256' FEL, Sec. 35, T12N, R11E ,/ X = 588,937 Y = 5,978,342 Z = 4,640' TVDss TD: I 7,713' MD I Nabor~~ I GL: I 50.4' I I KB: I 28.5' I I Operating days to complete: I 20.5 I 4,719' I Max Inc: I 61.1° I I KBE: I 78.9' I I AFE Number: I ORD5M3582 I Rig: I Estimated Start Date: I May 9th, 2005 I TVD: Well Design: Big Bore Grassroots Schrader Injector with Expandable Liner & Screens 4-W' X 3-W' TCII Completion. The 0 sands will have a 4-%" X 3-%" TCII Completion in the Schrader Bluff. Current Well Information General Distance to Nearest Property: Distance to Nearest Well in Pool: API Number: Well Type: Current Status: Conductor: BHP: pressure gradient. BHT: -8,030' at top Na sand to the nearest PBU property line 600' to L-102 at the base of the OBd sand (closest point between the two wells) 50-029-XXXXX Development - Orion Schrader Injector New well, 20" X 34" insulated conductor 20" X 34", 215.5 Iblft, A53 ERW set at 109' RKB 2,100 psi @ 4,640' TVDss (8.7 ppg EMW). Normal 90°F @ 4,640' TVDss estimated % Mile Wellbore Near Wellbore Mechanical Integrity Summary: '¿1JÎ, o~(p L-102 is 600' from L-214i at the base of the OBd. L-102 had a planned TOC of -5,500' MD, which is 500' MD above the top of the Schrader Bluff. There were no problems reported during the pumping of the L-102 cement job. There were no losses and the plug was bumped on schedule. 2<>4-- C?4~ - ? L-201 has two horizontal laterals which are with-in % mile of L-214i. The OBd lateral is 990' away and the OA lateral is 1130'. L-201 had a planned TOC of -4700', which is 700' above the top of the Ma. There were no problems were reported during the pumping of the L-201 cement job. There were no losses, the casing was reciprocated, and the plug was bumped on schedule. /' No near wellbore integrity issues. Target Estimates Estimated Reserves: 1.212 MMBO , . . . " Formation Markers L-214i (Based on Schlumberger wp04b) Formation Tops MD TVD TVDss Pore psi EMW ppg Hydrocarbons G1 329 329' 250' 113 8.7 No Fault #1 895 889' 810' SV6 936 929' 850' 383 8.7 No SV5 1,669' 1,564' 1 ,485' 668 8.7 No SV4 1,861' 1,699' 1,620' 729 8.7 Poss Gas Hydrates Base Permafrost 1,970' 1,769' 1,690' 761 8.7 No SV3 2,578' 2,079' 2,000' 900 8.7 Poss Gas Hydrates SV2 2,930' 2,249' 2,170' 977 8.7 Poss Gas Hydrates SV1 3,654' 2,599' 2,520' 1,134 8.7 Poss Gas Hydrates UG4 4,327' 2,924' 2,845' 1,280 8.7 Thin Coal UG4A 4,400' 2,959' 2,880' 1,296 8.7 Heavy Oil: 2,875'-2,950' TVOss Fault #2 5,217' 3,354' 3,275' UG3 5,217' 3,354' 3,275' 1,474 8.7 Thin Coals/Poss Gas Hyrates UG1 5,942' 3,704' 3,625' 1,631 8.7 Heavy Oil: 3,870'-3,940' TVOss Ma Sand 6,574' 4,009' 3,930' 1,774 ~ Heavy Oil: 3,940'-3,970' TVOss Mb1 6,667' 4,054' 3,975' 1,815 No - water Mb2 6,822' 4,129' 4,050' 1,845 No - water Me 6,996' 4,219' 4,140' 1,885 8.8 No - water Na 7,113' 4,289' 4,210' 1,915 8.7 No Nb 7,151' 4,314' 4,235' 1,930 8.8 Yes Ne 7,211' 4,354' 4,275' 1,945 8.7 Yes OA 7,324' 4,434' 4,355' 1,800-1,975 7.9-8.7 Yes OBa 7,420' 4,504' 4,425' 1,800-2,000 7.8-8.7 Yes OBb 7,481 ' 4,549' 4,4 70' 1,820-2,020 7.8-8.7 Yes OBe 7,563' 4,609' 4,530' 2,040 8.7 Yes OBd 7,631' 4,659' 4,580' 1,860-2,060 7.8-8.7 Yes TO* 7,713' 4,719' 4,640' 1,860-2,060 7.8-8.7 Yes OBe N/A N/A 4,650' 2,085 8.6 Not Penetrated *Planned TO: 14' MO above Top OBe Casingrrubing Program Hole Csgl WtlFt Grade Conn Burst Collapse Length Top Bottom Size Tbg O.D. (psi) (psi) MD 1 TVDrkb MD/TVDrkb 42" 20" 215.5# A-53 Welded 80' 29' / 29' 109' / 109' 16" 13-3/8" 68# L-80 BTC 5,020 2,260 3,832' 29' / 29' 3,861' /2,699' 12-1/4" 9-5/8" 40# L-80 BTC-M 5,750 3,090 6,979' 29' / 29' 7,008' /4,223' 12-1/4" 9-5/8" 47# L-80 BTC-M 6,870 4,750 300' 7,008' / 4,223' 7,308' /4,422' 8-1/2" 7" 29# 13Cr80 Expanded slotted liner/screen 505' 7,208' / 4,347' 7,713' / 4,719' Tubing 4%" 12.60# L-80 TCII I 8,430 I 7,500 7,122' 29' / 29' 7,151'/4,314' Tubing 3%" 9.30# L-80 TCII 10,160 10,530 412' 7,151' /4,314' 7,563' / 4,609' Mud Program: 16" Surface Hole Mud Properties: Interval Density Initial 8.5 - 9.2 Base Perm 9.0 - ~ Interval TO 9.5 - ~ Funnel Vis 250-300 225-250 225-250 I Spud - Freshwater Mud PV yp 20-45 50-70 20-40 30-45 15-20 30-40 I FL NC-8.0 8.0 5.0-7.0 Chlorides <500 <500 <500 PH 8.5-9.0 8.5-9.0 8.5-9.0 12-1/4" Intermediate Hole Mud Properties: I Freshwater Mud (LSNO) I Interval I Density I Funnel Vis I PV I yp FL I pH I Chlorides I MBT I Shoe to casing point 9.0 - 9.3 38-50 12-18 26-35 4-6 9.0-9.5 <600 < 20 8-1/2" Production Hole Mud Properties: Interval I Density I PV Shoe to casing point 9.0 - 9.2 <20 L-214i Permit to Drill I Mineral Oil Based Mud I I YP I HTHP FL I Oi/:Water Ratio I Electrical Stability I 15 - 19 10.0 65:35 >600 Page 2 . . Survey and Loggin~ Program: 16" Hole Section: Surface Gyro will be needed (run to 1200' or as conditions dictate) Open Hole: Dir / GR Cased hole: None 12-1/4" Hole Section: Surveys to be IFR + Multi-Station corrected Open Hole: Dir / GR / Res / Azi-qen / Neu / PWD (All realtime with recorded porosity) Cased Hole: USIT Bond Log ./ 8-1/2" Hole Section: Surveys to be IFR + Multi-Station corrected Open Hole: LWD: Dir / GR / Res / Azi-Den / Neu / Acoustic Caliper (All realtime with recorded porosity) E-Line: UBI caliper log Expanded Liner: USIT Log Bit Recommendations BHA Hole Size Surface 16" Surface 16" Intermediate 12-1/4" Production 8-1/2" Depths (MD) 0' - 1,954' 1,954' - 3,861' 3,861' - 7,308' 7,308' -7,713' Bit Type Hughes MXC-1 Hughes MXC-1 Hycalog DS103H+GJFW Hughes MX-20 Nozzles 16/20/20/20 16/20/20/20 4X12,3x11,4X10 3X20 K-Revs 750 Motors and Required Doglegs BHA Motor Size and Motor Required Flow Rate RPMs Required. Doglegs 1 9-%" Anadrill A962M3445SP Mud Motor, 2.12° with 700-750 gpm 60-80 1.5°/100' initial build 15-7/8" string stabilizer (gyro to +1200') 3.5°/100' final build 2 9-%" Anadrill A962M3445SP Mud Motor, 1.83° with 700-750 gpm 60-80 3.5°/100' Build 15-7/8" string stabilizer 61 ° Hold 3 9-%" Anadrill A962M3445SP Mud Motor, 1.50° with 650 gpm 80-1 00 61 ° Hold 12-1/8" string stabilizer 4.0°/100' Drop 4 Rotary drill with 8-1/2" tri-cone bit 500 - 600 gpm 60-120 43° Hold Surface and Anti-Collision Issues Surface Shut-in Wells: I Nearby Well I L-102 I L-104 I L-123 Distance to L-214i 15' 15' 30' I L-106 I 45' L-102 and L-104 will require surface shut-in and wellhouse removal in order to move over well L-214i. L-123 should only be a conductor only. L-106 should be evaluated to see if wellhouse removal is required. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name Ctr-Ctr Distance L-102 15.64-ft L-104 16.83-ft L-106 45.72-ft L-105 58.74-ft L-108 76.85-ft Reference MD 250-ft 400-ft 350-ft 448-ft 350-ft Allowable Deviation 11.47-ft 10.31-ft 40.23-ft 50.83-ft 70.46-ft Precautionary Comment Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) L-214i Permit to Drill Page 3 . . Cement Calculations Casing Size: 113-3/8", 68-lb/ft L-80 BTC - Single Stage I Basis: Lead: 350%æ~J>. s ver gauge hole in permafrost, 50% excess over gauge hole below permafrost Lead TOC: rf9.eé Tail: 1,000' 0 ópen hole with 50% excess, plus 80' shoe track Tail TOC: 2,861' MD I Total Cement Volume: Spacer Lead Tail Temp 75 bbls of ViScosifiede· er weighted to 10.2 ppg (MUd~U I) 730 bbls, 4099 cuft, . ks 10.7Ib/gal ASL (G + adds) - cufVsk 125 bbls, 702 cuft,.6.99 sks 15.8 Ib/gal Class G + adds 1. cutVsk BHST == 60° F, BHCTtoo F estimated by Schlumberger ~ 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. Casing Size: 9-%-in 40 & 47-lb/ft L-80 BTC-M - Single Stage I Basis: Lead: N/A Lead TOC:N/A Tail: 1 ,234~0 enhole with 50% excess, plus 80' shoe track Tail TOC: ,0 ' MD (500' MD above the planned Ma top at 6,574' MD) I Total Cement Volu . Wash 25 bbls of CW100 Spacer 75 bbls of Viscosified~cer weighted to 10.5 ppg (Mud ~) Tail 111 bbls, 632 cuft, l!>t9"Sks 15.8 Ib/gal Class G + adds -~cufVsk Temp BHST == 90° F, BHCiãoo F estimated by Schlumberger Centralizer Recommendations: 13-3/8" Casing Centralizer Placement a) Run (25) 13-3/8" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,861' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 9-5/8" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 6,074' MD (500' MD above planned Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. 7" String Centralizer Placement a) Run 1 x-coupling solid body, straight vane centralizer on all blank 7" casing. Weatherford will supply these centralizers. Confirm placement with Weatherford prior to picking up the 7" liner and screens. b) Run 1 x-coupling solid body, straight vane centralizer on all EZI and ESS connections that will be expanded. Weatherford will supply these centralizers. Confirm placement with Weatherford prior to picking up the 7" liner and screens. L-214i Permit to Drill Page 4 . . Materials Needed - (use PES stock when possible) Surface Casing: Intermediate Casing: Production Liner: Production Tubing: L-214i Permit to Drill 3,861' 1 each 1 each 25 each 1 assembly 1 lot 7,000' 300' 1 each 35 each 1 lot 505' 7,258' 305' 1 each 1 each 1 each 2 each 4 each 1 each 1 each 1 each 1 each 1 each 4 each 1 each 13-3/8",68#, L-80 BTC Casing 13-3/8", BTC Float Shoe and Float Collar 13-3/8",68#, BTC TAM Port Collar 13-3/8" X 16" Bow Spring Centralizers FMC 13-5/8", 5m Big Bore Wellhead System 13-3/8" casing pups 5', 10', 20' 9-5/8",40#, L-80 BTCM Casing 9-5/8", 47#, L-80, BTCM Casing 9-5/8",47#, BTC Float Shoe and Float Collar 9-5/8" x 12" Rigid Straight Blade Centralizers 9-5/8" casing pups 5', 10', 20'. 7" Weatherford Expandable liner and screens See Attached Weatherford Equipment List 4 W' 12.60 I b/tt , L-80, TCII tubing 3 W' 9.30 Ib/tt, L-80, TCII tubing Weatherford 7" X 4-1/2" Ultra Pack TH Permanent Packer with crossovers to 3-1/2" Weatherford 7" X 3-1/2" Hell-Cat II Retrievable Packer Weatherford 9-5/8" X 4-1/2" Hell-Cat II Retrievable Packer Halliburton 4-W' X-Nipple (3.813" (0) Halliburton 3-W' X-Nipple (2.813" 10) Weatherford Dual Pressure Mandrel Weatherford Single Pressure Mandrel 13-5/8" X 4-W' FMC tubing hanger 4-1116", 5m Cameron Tree 4-W' x 1" KBG-2 GLM 3- 112" x 1-112" MMG injection mandrels 4-1/2" RA Tag Page 5 . . Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon /' calculations below, BOP equipment will be tested to 4,000 psi. Due to test pressures not exceeding 5,OOOpsi it will not be necessary to have two sets of pipe rams installed at all times. *" BOP regular test frequency for L-214i will be 14 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Interval · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Kick Tolerance: · 13-3/8" Casing Test: Intermediate Interval · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · 9-5/8" Casing Test: · Integrity Test - 12-1/4" hole: · Kick Tolerance: Production Interval · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · 7" Liner Test: · Integrity Test - 8-1/2" hole: · Kick Tolerance: · Planned completion fluid: 1,185 psi - (8.7 ppg @ 2,620' TVDss) 923 psi - Based on a full column of gas @ 0.10 psi/ft Function Test Diverter N/A - diveter 3,500 psi 1,988 psi - Base of N Sand (8.8 ppg @ 4,344' TVDss) 1,554 psi - Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams / 2,500 psi/250 psi Annular 4,000 psi 11.5 ppg minimum EMW LOT 20' from 9-5/8" shoe 150 bbls with an 11.5 ppg EMW LOT t.æPSi - Base of Schrader (8.7 ppg @ 4,640' TVDss) ,~Si - Based on a full c91umn of gas @ 0.10 psi/ft . ,000 psi/250 psi Rams /' 2,500 psi/250 psi Annular N/A - expanded slotted liner with screens 10.5 ppg minimum EMW FIT 20' from 9-5/8" shoe Infinite with an 10.5 ppg EMW FIT Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. L-214i Permit to Drill Page 6 · . Drillina Hazards and Continaencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 2A fault block is expected to be normal pressured at 8.5-8.6 ppg EMW. This pressure could be as low as 7.5 ppg EMW depending on offset producer influence. II. Hydrates and Shallow gas A. Gas Hydrates are present at L-pad and have been encountered in wells as close as L-117 and 118 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. III. Lost Circulation/Breathing A. Lost circulation is not expected at the L Pad. The L-Pad fault has been intersected by several other wells on L-pad at this depth with out problem. The well path crosses the faults at high angles and moves away quickly Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. Breathing is not expected on this well. IV. Kick Tolerancellntegrity Testing A. The 13-3/8" casing will be cemented to surface. B. The 9-5/8" casing will be cemented to 6,074' MD (500' MD above the planned Ma top). C. The 7" liner will be expanded slotted liner with screens. No cementing required. D. The 16" surface hole will be drilled on diverter. E. The Kick Tolerance while drilling the 12-1/4" Intermediate hole is 150 with 9.0 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure. F. The Kick Tolerance while drilling the 8-1/2" Production hole is with 9.0 ppg mud, 10.5 ppg FIT and an 8.8 ppg pore pressure. G. 12-1/4" hole Integrity Testing -11.5 ppg EMW LOT H. 8-1/2" hole Integrity Testing -10.5 ppg EMW FIT V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: L-106 5 ppm L-116 10ppm Adjacent producers at TO: No readings VII. Faults A. Two faults are expected to be crossed at L-214i. No losses are expected to be associated with either fault. Details are listed below for reference: Fault #1 (SV6, L-Pad Fault): Fault #2 (UG3): 895' MD 5,217' MD 889' TVD 3,354' TVD 810' TVDss 3275' TVDss Throw: 100' W Throw: 150' W CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L-214i Permit to Drill Page 7 · . L-214; Dr;lIand Complete Procedure Summary Pre-Rig Work: 1. The L-214i conductor has been set. See As-Built. 2. Weld an FMC landing ring for the FMC Big Bore Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in L-102 and L-104 and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and function test diverte/ PU 4" DP as required and stand back in derrick. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,861' MD. The actual surface hole TO will be +1-100' TVD below the top of the SV1 sands. / 4. Run and cement the 13-3/8", 68-lb/ft. surface casing back to surface. A TAM port collar will be run in the casing string if hole conditions dictate. .. 5. NO diverter spoof and NU casing I tubing head. NU BOPE and test to 4,000 psi. / 6. MU 12-1/4" drilling assembly with MWD/GR/Res/PWD and RIH to float collar. Test the 13-3/8" casing to 3,500 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace.over to new 9.0 ppg mud. 8. Drill new formation to 20' below 13-3/8" shoe and perform LOT (If a 11.5 ppg EMW is not obtained contact ODE). 9. Drill ahead to the base of the NC sand. Target TO at 7,308' MD. 10. Circulate and condition hole, POOH to run casing. Perform wiper trip only if hole conditions dictate. 11. Run and cement the 9-5/8", 40 & 47# intermediate casing as required to cover all significant hydrocarbon ~ervals. Displace the casing with seawater during cementing operations. 12. Confirm 500 psi cement compressive strength. Freeze protect the 9-%" X 13-3/8" annulus with dead crude. ../ 13. MU 8-1/2" drilling assembly with MWD/GR/Res/Den/Neu and RIH to float collar. Test the 9-5/8" casing to 4,000 psi for 30 minutes. 14. Drill shoe tract with seawater and sweeps. 15. Circ hole-OYerto 9.0 ppg MOBM. 16. Drill new formation to 20' below 9-5/8" shoe and perform FIT (If a 10.5 ppg EMW is not obtained contact ODE). 17. Drill ahead to the base of the 0 sands. Target TO at 7,713' MD, (14' MD above Top OBe marker). ;./ 18. Circulate MOBM twice bottoms up and pull back to casing shoe, back ream only if required. 19. Circulate whilst rotating and reciprocating until well is clean. Run check trip to TO without rotation or circulation. POOH 20. End of drilling section and start of completion / 21. RIH with bit, water string mill and casing scraper clean out assembly to TO. Rotate to scrape casing and dress shoe track with string mill. POOH to shoe and condition mud over 250 US Mesh screen. RIH to TO and circulate at least 1 Y2 times bottoms until mud passes mud flow through screens test. POOH. 22. RU E-Lìne. RIH with GR/UBI and log open hole to determine well bore diameter. Continue to log up into the 9-5/8" casing past the PIP tag. UBI will be the Primary Depth Control log. 23. USIT log 9-5/8" casing from shoe to TOC with E-Lìne. Confirm cement bond. POOH. 24. PU and RIH with Weatherford expandable completion and expansion BHA. RU E-line and run GR/CCI to locate short pup in drill string and correlate depth with RA tag in 9 518" casing. 25. Set liner hanger, conduct push pull test, test annulus to 500psi. Expand 7" expandable completion. Open circulatipn sub. POOH with expansion tools. / 26. RU E-line. Run USIT log across 7" expanded liner to determine formation compliance. Evaluate to determine if re- expansion is necessary. 27. PU and RIH with open ended DP to TO. 28. Circulate entire well to 9.0ppg brine. POOH. 29. Run the 4-W' X 3-Y2", L-80 TCII completion with a 9-5/8" x 4-1/2" and two (2) 7" x 3-Y2" straddle packer af3sembly, pressure gauge mandrels, injection mandrels and PIP tag. / L-214i Permit to Drill Page 8 /" . . 30. RU E-line. Correlate and set completion on depth. 31. Run in the lockdown screws and pressure up to set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCK shear valve. /' 32. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 33. Freeze protect the well to -2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 9-5/8"x 4-Y2" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 34. Rig down and move off. Post-Rig Work: 1. Circ out diesel freeze protect through DCK with 9.0 ppg brine. 2. R/U Slickline and pull ball and rod I RHC from the tailpipe. 3. Replace the DCK shear valve with GL V. 4. Pressure up against OBd screens to 2000 psi. 5. Flow back OBd to ASRC test unit using gas-lift gas. Get OBd oil sample. 6. Establish injection into OBd, perform step-rate test. 7. Shut down injection and obtain pressure fall-off test. 8. Set plug in tubing tail. 9. Pull dummy valve from OBa/OBb injection mandrel. Install flow sleeve. 10. Pressure up against OBa/OBb screens to 2000 psi. 11. Flow back OBa/OBb to ASRC test unit using gas-lift gas. Get OBa/OBb oil sample. 12. Establish injection into OBa/OBb, perform step-rate test. 13. Shut down injection and obtain pressure fall-off test. 14. Install dummy valve in OBa/OBb injection mandrel. 15. Pull dummy valve from OA injection mandrel. Install flow sleeve. 16. Pressure up against OA screens to 2000 psi. 17. Flow back OA to ASRC test unit using gas-lift gas. Get OA oil sample. 18. Establish injection into OA, perform step-rate test. 19. Shut down injection and obtain pressure fall-off test. 20. Install plug in X nipple below 9-5/8" packer. 21. Freeze protect annulus to 2000' TVD. 22. Install DGLV. 23. Install orifice valves for the OA, OBa/OBb, and OBd. 24. Establish injection. 25. Pull VR plug. L-214i Permit to Drill Page 9 · . L-214i Detailed Drilling Procedure Job 1: MIRU Critical Issues: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ L-102 and L-104 will have to be shut in and require wellhouse removal before rig can be moved over the well. L-123 should have a conductor only set. Evaluate L-106 to see if this well requires shut-in and wellhouse removal. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. I NearbyWell I L-102 I L-104 I L-123 I L-106 I Distance to L-214i 15' 15' 30' 45' ~ L Pad is J]5?idesignated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: L-106 5 ppm 1: L-116 10 ppm ') Adjacent producers at TD: No readings Reference SOP: .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 16" Surface Hole Critical Issues: ~ At L-Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. ~ Close Approach: The L-102 and L-104 will be required to be shut in and have the well house removed due to surface location proximity to the L-214i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. A gyro should be run to at least 900'-1200'. ~ Faults: One fault is expected to be crossed at L-214i in the surface hole. The L-Pad fault has been crossed many times by offset wells at similar depths with out problems. Losses are not expected to be associated with this fault. Details are listed below for reference: Fault #1 (SV6, L-Pad Fault): 895' MD 889' TVD 810' TVDss Throw: 100' W ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections and allow for easier 13-3/8" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the surface hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. L-214i Permit to Drill Page 10 . . ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 2.12° motor bend. Vary flowrates 650-750 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 750 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observed, and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Reference RPs: .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations Job 3: Run 13-3/8" Surface Casinq Critical Issues: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates are prevalent on L-pad all the way into the SV1. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 13-3/8",68# casing is being used (12.415" ID, 12.259" drift). Ensure that casing equipment is properly drifted to ensure adequate ID for the 12-1/4" bit (float equipment, casing hanger, Port Collar, etc). ~ Cement to surface: A single-stage job will be done on this well using 350% excess in the permafrost and 50% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MD as a contingency, if hole conditions warrant. ~ Losses during cement job: Lost circulation has been experienced on offset pads while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7-lb/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs: .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" L-214i Permit to Drill Page 11 . Job 4: Drill 12-1/4" Intermediate Hole Critical Issues: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across permeable sands. ~ LOT: Perform a LOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the ma~pected Schrader reservoir pressure of 8.8 ppg and 9.0 ppg mud, a 11.5 ppg leak-off will provide 0 þôls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.5 ppg. Based upon "Set drilling data, a minimum leak-off of 13 ppg is expected at the 13-3/8" shoe. ~ Penetration Rate: Penetration rates should not exceed 500 fph instantaneous. This should allow for EGO's not to exceed 0.5 ppg above calculated. EGO's will be difficult to track with such a large annulus. Small changes in the EGO result in a very large annular cuttings loading. For this reason, maintain EGO's with in 0.5 ppg of clean hole while drilling ahead. If EGO's are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. EGO should not exceed 11.0 ppg once the M sand has been penetrated. ~ Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Faults: One fault is expected to be crossed at L-214i in the 12-1/4" hole. Losses are not expected to be associated with this fault. Details are listed below for reference: . Fault #2 (UG3): 5,217' MD 3,354' TVD 3275' TVDss Throw: 150' W ~ Screen Blinding: Add BDF-263 as per MI mud program while drilling the Ugnu/heavy oil sands ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the production hole section. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the NG sand using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ~ Directional Constraints: It is important to keep the wellbore smooth and the tangent angle close to plan to facilitate casing running and slickline access. It is important to design a BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to :;;;1 ° over planned. Dogleg will take priority over angle as tong as mainbore tangent angle does not approach 68 degrees. ~ 12-%" Section TD and 9-5/8" Casing Landing Point: The 12 W' section should TO in the middle of the base NG siltstone. 9-5/8" casing setting point will be determined by depth based on changes in GR/Res curves associated with the top Nc marker. The objective will be to: o get cement across the mid NG shale, o set 9-5/8" no closer than 15 feet to top of OA sand o keep 12- W' rat hole less than 10 feet, preferably 5 feet If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Survey program per JORPS: Dogleg Severity Survey Frequency <1°/100' 90'(Every stand, not exceeding 100') 1° - 5°/100' 90'(Every stand, not exceeding 100') >5°/100' 30'(Every joint) Reference RPs: .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "ERD Operating Practices" L-214i Permit to Drill Page 12 . Job 6: Run and Cement 9-5/8" Intermediate CasinQ Critical Issues: ~ Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. ~ Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job and the TOC above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. ~ Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 9-5/8" x 13-3/8" casing outer annulus with 173 bbls of dead crude (2,900' MD, 2,200'TVD), the hydrostatic pressure will be 8.0 ppg vs. 8.8 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be over 100 psi underbalance to the open hole. ~ Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 1 RA tag placed in the 9-5/8" casing for depth control. Placement strategy is: o Pip #1: c 6,930' ± 50' MD (locate at top of 47# casing) ~ Mud Requirements: Thin the mud as per Ml's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 9-5/8" casing. ~ TIW Valve: Ensure that a TIW valve with a cross over to 9-5/8" BTC casing is on the rig floor before running casing. ~ Casing Weights: The 9-5/8" casing string will consist of 47# and 40# pipe. The 47# is required on the bottom of the string to allow the proper setting of the 7" Liner Hanger and 4-1/2" Injection packer. . Reference RPs: .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 7: Drill 8-1/2" Production Hole Critical Issues: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. ~ FIT: Perform a FIT (minimum 10.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the x xpected Schrader reservoir pressure of 8.8 ppg and 9.0 ppg mud, a 10.5 ppg leak-off will an I INITIE kick tolerance. Contact Anchorage personnel if FIT is less than 10.5 ppg. Based upon 0 -.~~t&illing data, a minimum leak-off of 13 ppg is expected at the 9-%" shoe. ~ Penetration Rate: A gauge hole is required for the success of the expandable liner. Keep RaP's below 200 fph through this section to avoid washouts or ledges. The 8-1/2" hole will be drilled in rotary mode only (no mud motor). ~ Hole Quality: Open hole diameter must be at least 8.5" and must not exceed 9.25" in the sands and must be less than 9.1" for at least 6 feet within each shale section. ~ Torque: OBM will be used to drill this interval. Lubricants will not be required. L-214i Permit to Drill Page 13 . - . . ~ Faults: no faults are expected in the 8-1/2" hole. ~ Critical LWD Tools: It is critical to have the GR tool in order to identify all of the zones for accurate location of screens and zonal isolation devices. Therefore if the GR tool is lost, a trip will have to be made to change it out. The density based caliper will be used to give an immediate indication of hole quality but is not essential. ~ Well TD: The 7" expandable completion setting point will be determined by depth based on changes in GR/Res curves associated with the top OBa, OBb, and OBc markers. After seeing these tops, TD will be picked based on 14' MD above the OBe. This should leave at least 13 feet below base OBd sand. This footage is critical for future liner expansion. ~ OBM Displacement: See attached MI mud program for detail on displacing from seawater to OBM. Ensure that the OBM has been heated and flow tested at the plant before delivery to the rig. ~ BOP Test: Minimize the time between drilling 8 W' hole and running expandable completion. Consider doing BOP test before drilling 8 W' section Reference RPs: .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "ERD Operating Practices" .:. MI Mud Program Job 8: Wellbore Clean Up and Mud ConditioninQ. Caliper LOQ 8-1/2" Hole and 9-5/8" CasinQ: Critical Issues: ~ Wellbore Cleanliness: Damage to the screens while RIH could result in rupture during the expansion process or damage to the elastomers. A dedicated clean out trip will be run to TD including a string mill to dress any irregularities in the shoe track. ~ Casing Scraper: Residual cement left within the 9 5/8" casing will prevent setting of the upper completion packer and liner hanger. The wellbore clean out trip will include a casing scraper to scrape the setting areas. ~ Mud Conditioning: Plugging of the screens while RIH could result in collapse of the screens or poor injectivity during the life of the well. Mud will be conditioned over 250 US mesh shaker screens during the clean out trip. Mud condition will be verified by Weatherford using a mud flow through screens tester supplied by MI. ~ Dry Jobs/Slugging Pipe: slugging the pipe with barite laden mud can block screens. Keep pipe slugging to a minimum, use only calcium carbonate as weighting material in slugs and ensure that particle size is small enough to pass through screens by testing slug using Mud Flow Through Screen Tester. ~ Pipe Dope: Note that pipe dope is extremely detrimental to formation and expandable screens. Do not put dope on boxes while POOH after the clean out. Lightly dope pin threads with a paintbrush while running in hole. ~ Base Plan: Following the clean out trip a UBI is required to determine accurate caliper log of the 8-1/2" open hole. The expansion team will use this data to determine 1) if the expandable will be run and 2) if run, the placement of ESS's (screen sections) and EZl's (external zonal isolation sections). After the UBI is run. A USIT will be run to determine bond quality and TOC for the 9-5/8" casing. ~ DPC: Running the logs on DP should not be required. Schlumberger will have their TLC tools lined up and ready to go at the shop, but not deployed to location. In the event that the logs will not go to bottom on e-line, they will be run DP. The UBI and USIT are absolutely required. ~ Hole Quality: If the UBI shows that the 8 W' hole is washed out to more than 9.1" the expandable completion will not be run. The contingency conventional liner will be run instead. L-214i Permit to Drill Page 14 . . . . Reference RPs: .:. Follow Schlumberger logging practices and recommendations .:. See attached Baker recommended clean out BHA sheet .:. Weatherford Product Bulletin for Mud Conditioning Job 9: Run and Expand 7" Liner and Screens Critical Issues: >- Hole Quality: Open hole diameter must be at least 8.5" and must not exceed 9.25" in the sands and must be less than 9.1" for at least 6 feet within each shale section >- Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential sticking could be a problem if lost circulation is occurring or if the liner is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. >- Mud Requirements: See attached MI Mud Program for OBM fluid properties and requirements. Soilds control and partical size distribution are of paramount importance. Everything that is put into the well bore must be able to pass through the screens. >- Drill pipe: All drill pipe and drill collars must be drifted to 2.0" >- Well control: Ensure that a TIW valve with a cross over from 7" 29ppf V AM TOP HT left hand thread to 7" BTC-M casing is made up to a joint of 7" BTC-M casing and ready in the pipe shed. >- USIT Log: A USIT log run will be run following expansion to evaluate the degree of compliance. If the liner was not expanded correctly on the first attempt, Weatherford expansion tools will be re-run in a second attempt to fully expand the liner. >- Surface handling: The expandable completion is made from high chrome (25%) alloys and must be handled carefully to avoid damage. Surface scores can initiate failure during expansion. Damage to elastomers could prevent sealing. Handling of the equipment will require working within 10 feet of the pipe handling machine to prevent damage when loaded onto the skate. A full risk assessment will be reviewed by drill crews before picking up completion equipment. Protective donuts will be applied to each ESS and EZI to prevent damage when moving up the skate. >- Tubulars: All blank pipe and completion components will be shipped to location with storage compound on threads. All pipe will need to be drifted as per Weatherford procedures and threads cleaned. API modified compound will be put on connections. All connections are 7" V AM TOP HT 80ksi yield Special Clearance 90 left hand thread. All lower completion connections will be made using tongs dressed with non marking dyes and monitored using joint analysed make up equipment. Tubular make up torques are specified in the detailed Weatherford procedures. Verify connection is made up correctly before moving to next joint. >- Space Out and Depth Correlation: It is important to get the EZI devices into the optimum location in the open hole if they are to seal when expanded. Tallies must be discussed and double checked with BP Completion Engineer to eliminate errors. An electric line correlation run will be carried out to double check the location of the expandable completion. >- Running in hole: ensure string is self filling, if necessary fill from top every 5 stands and record volumes pumped to check if screens are plugging. Do not rotate at any time. Weatherford engineer to be on rig floor at all times. Minimize time during which string is stationary when completion is in open hole. >- Data Acquisition: It is vital to ensure that Epoch system is calibrated, functioning and set up to display key operating parameters on one screen on the rig floor and one remote screen in geo-shack. Expansion data will need to be saved, and downloaded from rig hard drive and processed in Anchorage into a usable ASCII format. L-214i Permit to Drill Page 15 . . . . Reference RPs: .:. Weatherford Expansion Procedures .:. Follow Schlumberger logging practices and recommendations .:. Casing and Tubing Specifications Sheet Job 11: Liner Clean-out Critical Issues: · Thorough displacement from OBM to 9.0 ppg brine is critical. Refer to the attached MI mud program. · DP will be run open-ended with bit float and mule shoe to allow maximum displacement rates. · Lost Circualtion: the well may start to loose brine during the displacement. Continue with displacement until clean brine is seen in the returns. Shut down and monitor losses. L-214i is planned as an injector, so losses are acceptable. Reference RPs: .:. MI Mud Program .:. Baker Clean out BHA proposal Job 12: Run 4-%" Completion Critical Issues: }> Barriers: o The well will have the OA, aBa, OBb, and OBd production intervals open with an 8.6 ppg EMW formation pressure during completion operations. o Completion will be run with BOPs in place and kill weight fluid for annulus side barriers. Tubing side barriers will be provided via TIW and kill weight fluid. o Once packers are set the annulus above the packer will be tested to 4,000 psi to verify packer/annulus integrity. Kill weight fluid and the tubing hanger provide additional annulus side barriers. At this point the ball and rod with kill weight fluid and a TIW valve comprise the tubing side barriers. o Since it is not feasible to test the lower packer/annulus integrity, when the DCK valve is sheared a casing annulus valve must be in place along with kill weight fluid to provide sufficient annular barriers. Tubing side barriers are still kill weight fluid on ball and rod and a TIW. o A TWC will be installed and tested from above to 1,000 psi for 30 minutes prior to nippling down the BOP's. With the DCK valve sheared the TWC in addition to kill weight fluid provide the tubing side barrier. The annular side barrier is the casing annulus valve and the kill weight fluid. With the TWC in place BOPs can be nippled down and the tree nippled up. o With the tree nippled up freeze protecting removes the kill weight fluid as a barrier. We then count on the tree for tubing side barriers, and two casing annulus valves for annulus side protection. o Before rigging down a BPV tested from below to 1,000 psi will be left in the tubing hanger to provide an additional tubing side barrier once the rig is off. Since the DCK valve is still open it will be necessary to leave one casing annulus valve and a VR plug for annular barriers. Make sure that a lubricator is used to install the VR plug while both casing annulus valves are still in place. }> Thread Dope: Jet Lube is the BP approved thread compound for Premium Carbon API connections. All TCII pipe should arrive on location with Jet Lube thread compound. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. }> Torque Turn: Injectors will be used for MI injection and therefore must have all connections torque turned and charted to help reduce risk of leaks. ~ Shear Valve: We will be using a DCK-2 shear valve due to the RP shear valve failure on numerous wells. The DCK-2 shear valve has had good success due to the locking mechanism that keeps the sleeve from L-214i Permit to Drill Page 16 # . . . migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. > Injection Mandrels: Remove the check valves from the MMGW waterflood mandrels. This will allow us the flexibility to circulate between mandrels and clean up the tubing/casing annulus later in the well life. Verify that dummy valves have been installed. > Tail Pipe: set WLEG at the top OBc to allow for future perfs. Reference RPs: .:. "Completion Design and Running" RP .:. "Tubing Connections" RP .:. Weatherford Completion Program Job 13: ND/NU/Release Riq Critical Issues: )ò> See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. )ò> Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs: .:. "Freeze Protecting an Inner Annulus" RP L-214i Permit to Drill Page 17 14i - mp 4-112" Tag above packer 20" Conductor 4-1/2" X Nipple at 2500' TOC 500' MD above Ma MD RA Abolle packer setting Weatherford Liner Hanger with modified to be run with the liner To be set in the base of the lower Nc siltstone. 9-5/8",40 & 47#, BTC-M Inter - 7308' MD I-Wire to surface for pressure monitoring OA l Pressure Mandrels , formation. OBa , OBb \ , " .-- 08c - WLEG to be set future perforating, if desired. -, " ,. J I I OBd 771 Liner 01/19/04 RBT . . w a:: I -~- I PLANT L1S'OO'OO" GRID -~.~,- ~,"-- ~'.~- L-PAD . N-L (NWE-1) , 2 '~~,. \J ' ,) '/-- VICINITY MAP N.T.S. L-1111 . 1'-' ("H) L-113 L-114. L-124 L-SD · L-112i L-D2 L-121. · L-122 L-11D. .L-211i L-SI · · L-115i L-116. · L-117 L-1D9 . · L-118 j L-SL · t L-D1 · · L-2DO L-107 . 151<105021 · L-202 L-D3 · · L-2121 rn; · L-SPARE L-213i. · L-203 L-108i. · L-2161 L-105i. ~ · L-1031 L-106 . D_ · L-21Si L-123i. · L-201 L-104 .L-119i L-214i · L-21Oi L-102 D! · L-120 LEGEND ~ RENAMED CONDUCTOR . EXISTING CONDUCTOR ~ ~ ..... 1 SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 14, 2005. WELL NO, L-214i REVISION NOTE THIS AS-BUILT DRAWING IS A REISSUE OF A PREVIOUS AS-BUILT DRAWING FOR CONDUCTOR SLOT S-W. SLOT S-W IS BEING RENAMED TO L-214i. NOTES 1. DATE OF SURVEY: JUNE 20-21, 2002. 2. REFERENCE FIELD BOOK: W002-08 PAGES 16-19. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAO 27. 4. BASIS OF HORIZONTAL LOCATION IS L-PAD OPERATOR MONUMENTA TlON. 5. BASIS OF ELEVATION IS L-PAD OPERATOR MONUMENTS. ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINA TES COORDINA TES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS L-214i Y= 5,978,154.31 N= 9,819.77 70'21'01.008" 70.3502800' 504' 2,430' FSL X= 583,400.48 E= 5,369.63 149'19'22.369" 149.3228803' . 3,515' FEL o 1/14/05 ISSUED FOR INFORMA l10N NO. OA 1E REVISION ~Oil DRAWN: ObP JACOBS CHECKEO'FENTlE DATE: 1/14/05 DRAINING: GPB WOA L-PAD FRBOS WOL 01-00 SHEET: i ¡U~~[IJ[~o JOB NO: SCALE: AS-BUILT CONDUCTOR NAME CHANGE JJ JIIF ENGINEERS AND LAND SUR'ÆYOA$ WELL L-SW TO L-214i 1 OF 1 !I01WEST ARt'iIEW lANE 1"= 150' BY CHK '""""""'" ""'"' """ Ö L-214 (P4b) Schlumberuer Report Date: February 9, 2005 ~ """ ''''' "'"-~ ...... Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 88.690' Field: Prudhoe Bay Unit - WOA d Vertical Section Origin: S 148.680 ft, E 146.310 ft Structure J Slot: L-PAD J SoW Feasibility st Y TVD Reference Datum: Rotary Table Well: Plan L-214 (S-W) TVD Reference Elevation: 78.90 ft relative to MSL Borehole: Plan L-214 Sea Bed J Ground Level Elevation: 50.40 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 24.519' Survey Name J Date: L-214 (P4b) J February 9, 2005 Total Field Strength: 57608.357 nT Tort J AHD / DDI J ERD ratio: 81.531' 15553.18 ft J 5.869 J 1.177 Magnetic Dip: 80.811" - Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 05, 2005 Location Lat/Long: N 70.35027993, W 149.32288035 Magnetic Declination Modol: BGGM 2004 Location Grid HIE YIX: N 5978154.310 ftUS. E 583400.480 ftUS North Reference: True North Grid Convergence Angle: +0.63769163' Total Corr Mag North·> True North: +24.519' Grid Scale Factor. 0.99990790 Local Coordinates Referenced To: Well Head I Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (dog) (It) (It) (It) (It) (It) (It) (dog/100 It) (deg) (deg/100 It) (deg/100 It) (ltUS) (ltUS) RTE 0.00 0.00 20.00 -78.90 0.00 -142.87 0.00 0.00 0.00 0.00 20.00M 0.00 0.00 5978154.31 583400.48 N 70.35027993 W 149.32288035 KOP Bid 1.5/100 300.00 0.00 20.00 221.10 300.00 -142.87 0.00 0.00 0.00 0.00 20.00M 0.00 0.00 5978154.31 583400.48 N 70.35027993 W 149.32288035 G1 328.90 0.43 20.00 250.00 328.90 -142.83 0.11 0.10 0.04 1.50 20.00M 1.50 0.00 5978154.41 583400.52 N 70.35028021 W 149.32288004 Cry 2.5/100 400.00 1.50 20.00 321.09 399.99 -142.40 1.31 1.23 0.45 1.50 38.84M 1.50 0.00 5978155.54 583400.91 N 70.35028329 W 149.32287671 500.00 3.87 38.84 420.97 499.87 -139.74 5.96 5.09 3.01 2.50 43.23M 2.37 18.84 5978159.43 583403.44 N 70.35029383 W 149.32285589 Cry 3.5/100 600.00 6.34 43.23 520.57 599.47 -133.69 14.86 11.75 8.92 2.50 49.29G 2.47 4.39 5978166.15 583409.26 N 70.35031202 W 149.32280797 700.00 9.02 60.39 619.67 698.57 -122.91 28.13 19.65 19.52 3.50 32.28G 2.68 17.16 5978174.17 583419.78 N 70.35033361 W 149.32272188 800.00 12.13 69.32 717.97 796.87 -106.09 46.45 27.24 36.17 3.50 23.50G 3.10 8.93 5978181.94 583436.34 N 70.35035433 W 149.32258672 Fault Crossing 894.72 15.22 74.35 810.00 888.90 -84.65 68.82 34.11 57.46 3.50 18.60G 3.27 5.32 5978189.05 583457.55 N 70.35037310 W 149.32241389 900.00 15.40 74.58 815.09 893.99 -83.30 70.22 34.48 58.80 3.50 18.39G 3.32 4.20 5978189.44 583458.89 N 70.35037412 W 149.32240299 SV6 936.32 16.61 75.98 850.00 928.90 -73.56 80.23 37.02 68.49 3.50 17.04G 3.33 3.86 5978192.08 583468.54 N 70.35038106 W 149.322_ 1000.00 18.75 78.01 910.67 989.57 -54.62 99.57 41.35 87.33 3.50 15.10G 3.36 3.19 5978196.63 583487.34 N 70.35039289 W 149.322 1100.00 22.15 80.43 1004.36 1083.26 -20.16 134.50 47.83 121.65 3.50 12.83G 3.40 2.42 5978203.48 583521.58 N 70.35041058 W 149.3218 1200.00 25.57 82.23 1095.80 1174.70 19.96 174.94 53.88 161.64 3.50 11.19G 3.42 1.80 5978209.98 583561.49 N 70.35042712 W 149.32156817 1300.00 29.01 83.63 1184.65 1263.55 65.57 220.78 59.49 207.14 3.50 9.94G 3.44 1.40 5978216.10 583606.92 N 70.35044244 W 149.32119880 1400.00 32.47 84.75 1270.59 1349.49 116.52 271.89 64.64 257.98 3.50 8.98G 3.45 1.13 5978221.81 583657.70 N 70.35045650 W 149.32078604 1500.00 35.93 85.68 1353.29 1432.19 172.61 328.08 69.30 313.98 3.50 8.21G 3.46 0.93 5978227.10 583713.64 N 70.35046924 W 149.32033144 1600.00 39.39 86.47 1432.44 1511.34 233.64 389.17 73.47 374.93 3.50 7.58G 3.47 0.79 5978231.94 583774.53 N 70.35048060 W 149.31983668 SV5 1669.22 41.80 86.95 1485.00 1563.90 278.65 434.21 76.05 419.89 3.50 7.22G 3.47 0.69 5978235.02 583819.46 N 70.35048764 W 149.31947165 1700.00 42.87 87.15 1507.75 1586.65 299.37 454.94 77.11 440.59 3.50 7.07G 3.47 0.65 5978236.31 583840.15 N 70.35049055 W 149.31930362 1800.00 46.34 87.74 1578.94 1657.84 369.56 525.15 80.23 510.73 3.50 6.65G 3.47 0.60 5978240.21 583910.24 N 70.35049906 W 149.31873423 SV4 1860.66 48.45 88.07 1620.00 1698.90 414.20 569.79 81.86 555.34 3.50 6.43G 3.48 0.54 5978242.33 583954.83 N 70.35050349 W 149.31837207 1900.00 49.82 88.27 1645.74 1724.64 443.95 599.54 82.80 585.08 3.50 6.29G 3.48 0.51 5978243.61 583984.55 N 70.35050608 W 149.31813066 Base Perm 1970.40 52.27 88.62 1690.00 1768.90 498.68 654.28 84.29 639.80 3.50 6.08G 3.48 0.48 5978245.70 584039.24 N 70.35051011 W 149.31768647 2000.00 53.30 88.75 1707.91 1786.81 522.26 677.85 84.83 663.37 3.50 6.00G 3.48 0.46 5978246.51 584062.80 N 70.35051159 W 149.31749513 WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) S-WlPlan L-214 (S-W)\Plan L-214\L-214 (P4b) Generated 2/9/2005 9:31 AM Page 1 of 2 Comments Measured I Inclination I Azimuth I Sub-Sea TVD I TVD Vertical I Along Hole I NS EW I DLS I Tool Face I Build Rate I Walk Rate I Northing Easting Latitude Longitude Depth Section Departure (II) (deg) ( deg) (II) (II) (II) (II) (II) (II) (deg/100 II) (deg) (degl100 II) (deg/100 II) (IIUS) (IIUS) 2100.00 56.78 89.19 1765.20 1844.10 604.20 759.79 86.29 745.29 3.50 5.75G 3.48 0.44 5978248.88 584144.70 N 70.35051557 W 149.31683004 2200.00 60.26 89.59 1817.41 1896.31 689.46 845.06 87.19 830.56 3.50 5.53G 3.48 0.40 5978250.73 584229.94 N 70.35051800 W 149.31613786 End Cry 2224.57 61.12 89.69 1829.43 1908.33 710.88 866.48 87.33 851.98 3.50 O.OOG 3.48 0.39 5978251.11 584251.35 N 70.35051837 W 149.31596397 SV3 2577. 70 61.12 89.69 2000.00 2078.90 1020.05 1175.70 89.02 1161.19 0.00 O.OOG 0.00 0.00 5978256.23 584560.50 N 70.35052286 W 149.31345381 SV2 2929.67 61.12 89.69 2170.00 2248.90 1328.19 1483.89 90.70 1469.37 0.00 O.OOG 0.00 0.00 5978261.35 584868.61 N 70.35052731 W 149.31095196 SV1 3654.31 61.12 89.69 2520.00 2598.90 1962.60 2118.39 94.16 2103.87 0.00 O.OOG 0.00 0.00 5978271.87 585502.97 N 70.35053636 W 149.30580109 13-3/8" Csg pt 3861.34 61.12 89.69 2620.00 2698.90 2143.86 2299.68 95.15 2285.15 0.00 O.OOG 0.00 0.00 5978274.88 585684.22 N 70.35053892 W 149.30432942 UG4 4327.18 61.12 89.69 2845.00 2923.90 2551.70 2707.58 97.38 2693.05 0.00 O.OOG 0.00 0.00 5978281.64 586092.02 N 70.35054463 W 149.30101814 UG4A 4399.65 61.12 89.69 2880.00 2958.90 2615.14 2771.03 97.73 2756.50 0.00 O.OOG 0.00 0.00 5978282.70 586155.46 N 70.35054552 W 149.30050305 Fau/t Crossing 5217.45 61.12 89.69 3275.00 3353.90 3331.11 3487.12 101.64 3472.57 0.00 O.OOG 0.00 0.00 5978294.57 586871.38 N 70.35055539 W 149.29468992 UG3 5217.47 61.12 89.69 3275.01 3353.91 3331.13 3487.13 101.64 3472.59 0.00 O.OOG 0.00 0.00 5978294.57 586871.40 N 70.35055539 W 149.294_ UG1 5942.09 61.12 89.69 3625.00 3703.90 3965.53 4121.62 105. 10 4107.07 0.00 O.OOG 0.00 0.00 5978305.10 587505.74 N 70.35056397 W 149.28953904 Ma 6573.56 61.12 89.69 3930.00 4008.90 4518.37 4674.55 108.12 4659.99 0.00 O.OOG 0.00 0.00 5978314.27 588058.54 N 70.35057133 W 149.28505042 Mb1 6666.73 61.12 89.69 3975.00 4053.90 4599.94 4756.13 108.56 4741.57 0.00 O.OOG 0.00 0.00 5978315.62 588140.10 N 70.35057241 W 149.28438816 Mb2 6822.00 61.12 89.69 4050.00 4128.90 4735.88 4892.09 109.31 4877.53 0.00 O.OOG 0.00 0.00 5978317.88 588276.03 N 70.35057420 W 149.28328440 Drp 4/100 6853.83 61.12 89.69 4065.37 4144.27 4763.75 4919.96 109.46 4905.40 0.00 -176.12G 0.00 0.00 5978318.34 588303.90 N 70.35057457 W 149.28305815 6900.00 59.28 89.54 4088.32 4167.22 4803.80 4960.02 109.73 4945.46 4.00 -176.05G -3.99 -0.31 5978319.06 588343.94 N 70.35057523 W 149.28273296 Me 6995.85 55.45 89.22 4140.00 4218.90 4884.50 5040.72 110.59 5026.15 4.00 -175.88G -3.99 -0.33 5978320.82 588424.62 N 70.35057745 W 149.28207786 7000.00 55.29 89.21 4142.36 4221.26 4887.91 5044.14 110.64 5029.57 4.00 -175.87G -3.99 -0.35 5978320.90 588428.03 N 70.35057757 W 149.28205014 7100.00 51.30 88.84 4202.12 4281.02 4968.06 5124.29 112.00 5109.71 4.00 -175.65G -3.99 -0.37 5978323.16 588508.15 N 70.35058114 W 149.28139955 Na 7112.53 50.80 88.79 4210.00 4288.90 4977.81 5134.04 112.20 5119.45 4.00 -175.62G -3.99 -0.39 5978323.47 588517.89 N 70.35058167 W 149.28132045 Nb 7151.44 49.25 88.63 4235.00 4313.90 5007.62 5163.85 112.87 5149.26 4.00 -175.52G -3.99 -0.40 5978324.47 588547.68 N 70.35058345 W 149.28107846 7200.00 47.31 88.43 4267.31 4346.21 5043.86 5200.09 113.80 5185.49 4.00 -175.38G -3.99 -0.43 5978325.80 588583.89 N 70.35058592 W 149.28078435 Ne 7211.29 46.86 88.38 4275.00 4353.90 5052.13 5208.36 114.03 5193.75 4.00 -175.35G -3.99 -0.44 5978326.12 588592.15 N 70.35058653 W 149.28071727 7300.00 43.32 87.96 4337.62 4416.52 5114.95 5271.18 116.03 5256.54 4.00 -175.05G -3.99 -0.47 5978328.82 588654.91 N 70.35059189 W 149.28020756 End Drp 7308.11 43.00 87.92 4343.53 4422.43 5120.49 5276.73 116.23 5262.08 4.00 O.OOG -3.98 -0.51 5978329.09 588660.45 N 70.35059242 W 149.28016256 9-5/8" Csg pt 7308. 12 43.00 87.92 4343.54 4422.44 5120.50 5276.73 116.23 5262.09 0.00 O.OOG 0.00 0.00 5978329.09 588660.45 N 70.35059242 W 149.28016251 OA 7323.79 43.00 87.92 4355.00 4433.90 5131.18 5287.42 116.62 5272.77 0.00 O.OOG 0.00 0.00 5978329.59 588671.13 N 70.35059346 W 149.28007581 OBa 7419.50 43.00 87.92 4425.00 4503.90 5196.45 5352.69 119.00 5338.00 0.00 O.OOG 0.00 0.00 5978332.69 588736.32 N 70.35059982 W 149.27954624 OBb 7481.03 43.00 87.92 4470.00 4548.90 5238.41 5394.66 120.52 5379.94 0.00 O.OOG 0.00 0.00 5978334.69 588778.23 N 70.35060391 W 149.279~. OBe 7563.07 43.00 87.92 4530.00 4608.90 5294.36 5450.61 122.56 5435.85 0.00 O.OOG 0.00 0.00 5978337.34 588834.12 N 70.35060936 W 149.27875 OBd 7631.43 43.00 87.92 4580.00 4658.90 5340.98 5497.23 124.25 5482.44 0.00 O.OOG 0.00 0.00 5978339.56 588880.69 N 70.35061390 W 149.27837360 T arget 7645.11 ~3.00 87.92 4590.00 4668.90 5350.30 5506.56 124.59 5491.76 0.00 O.OOG 0.00 0.00 5978340.00 588890.00 N 70.35061481 W 149.27829795 TD 7713.47 ~ 43.00 87.92 4640.00 4718.90 5396.93 5553.18 126.29 5538.36 0.00 O.OOG 0.00 0.00 5978342.21 588936.57 N 70.35061935 W 149.27791968 Leaal Description: Northing (VI rftUSl Eastina (XI rftU$l Suñace : 2430 FSL 3515 FEL S34 T12N R11E UM 5978154.31 583400.48 Target: 2552 FSL 3304 FEL 535 T12N R11E UM 5978340.00 588890.00 BHL: 2554 FSL 3257 FEL 535 T12N R11E UM 5978342.21 588936.57 Well Design Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) S·w\Plan L-214 (S-W)\Plan L-214\L-214 (P4b) Generated 2/9/2005 9:31 AM Page 2 of 2 L-214 (P4b) FIELD Prudhoe Bay Unit - WOA STRUCTURE L....P AD MagnoticP"rarnel¡¡f$. M()d¡¡! BGGM 2004 Dip Mag Dee Dal( Aprn05,2005 FS 57608.4nT Surim;",Lo¢alÌof¡ La! Nï0211,Où8 Lon W1491922.369 NAD27 Alaska Slate P¡ilMS, Zone 04. US Feet Nurthíng 597815431 aus Grid Cmw: +0-63769163" 58340G.48iìUS Sca!eFact: 0.9999079014 Mi$(:8llaneüu$ Slot TVD Ref'. R()tary Table (78.90 it abow> MSLj SrvyDate: FBbruary09,2005 o 800 1600 2400 3200 4000 4800 5600 o o 800 800 1600 1600 II 2400 2400 OJ ro 0 (f) 0 > I- 3200 3200 4000 4000 2400 (it) Azim '" 88.69°, Scale'" 1(in):800(ft) '5600 o .. L-214 (P4b) I FIELD I Lo" S>~ Plan NO Re~ Rotary Tabl" US-90 11 ilbove MSLj SrvyOale: røbruary09.200S Bay Unit - WOA STRUCTURE MagnelicPararnG!0r" Model 8GGM 2004 Dip MifgD"ç N10211,OOB W1491922.369 Northiflg 5978154,:)1 ftUS 583400ABftUS o 800 1600 2400 3200 4000 4800 5600 6400 1600 1600 800 800 ^ ^ A Z ¢; Õ 13·318" 0 ro ~ ~ 0 0 II Q.> œ <..) [f) [f) V V V -800 -800 -1600 -1600 o 800 1600 2400 4000 4800 5600 6400 == 1 (in):800(ft) E >>> . Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB L Pad Plan L-214 (S-W) Plan L-214 . BP Alaska Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MO Interval: 50.00 ft Depth Range: 28.50 to 7713.47 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 12/21/2004 Validated: No Planned From To Survey ft ft 28.50 1400.00 Planned: Plan #4 V1 28.50 7713.47 Planned: Plan #4 V1 Casing Points MD ft 3861.34 7308.12 7713.47 TVD ft 2698.90 4422.44 4718.90 Diameter in 13.375 9.625 8.750 Summary < Site Offset Wellpath 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 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-02 L-02 L-02 L-101 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-114 L-115 L-116 L-117 L-118 L-119 L-120 L-121 L-121 L-122 L-200 L-200 L-200 L-201 L-201 L-201 L-201 L-201 L-201 L-201 L-201 L-210 L-210 Hole Size in 16.000 12.250 8.750 Name 13 3/8" 95/8" 8-3/4" open > Wellpath L-01 V14 L-02 V1 L-02A V5 L-02PB1 V21 L-101 V4 L-102 V2 L-102PB1 V10 L-102PB2 V2 L-103 V23 L-104 V7 L-105 V4 L-106 V14 L-107V14 L-108 V18 L-109 V12 L-110 V11 L-111 V24 L-112V8 L-114V15 Plan L-114A V1 Plan: P L-115V7 L-116V10 L-117V11 L-118V9 L-119V9 L-120 V8 L-121 V14 L-121A V1 L-122 V5 L-200 V7 L-200L 1 V3 L-200L2 V6 L-201 V6 L-201 L 1 V9 L-201L1PB1 V10 L-201L2 V5 L-201L3 V2 L-201L3PB1 V6 L-201PB1 V12 L-201 PB2 V3 L-21 0 V6 L-210PB1 V8 Date: 2/9/2005 . Time: 10:30:39 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan L-214 (S-W), True North L-214 Plan SoW 78.9 Version: Toolcode MWD MWD+IFR+MS Reference MD ft 399.92 533.67 538.97 533.67 490.12 802.32 1970.33 249.90 697.09 399.54 448.01 349.67 541.78 349.94 399.20 397.78 302.55 441.69 397.72 397.72 588.55 350.92 449.28 497.89 703.97 904.14 350.05 350.05 351 .77 201.30 201.30 201.30 250.20 250.20 250.20 250.20 250.20 250.20 250.20 250.20 1256.99 1256.99 Offset MD ft 400.00 550.00 550.00 550.00 500.00 800.00 1950.00 250.00 700.00 400.00 450.00 350.00 550.00 350.00 400.00 400.00 300.00 450.00 400.00 400.00 600.00 350.00 450.00 500.00 700.00 900.00 350.00 350.00 350.00 200.00 200.00 200.00 250.00 250.00 250.00 250.00 250.00 250.00 250.00 250.00 1250.00 1250.00 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name MWD - Standard MWD + IFR + Multi Station Ctr-Ctr No-Go Distance Area ft ft 149.63 6.51 355.06 8.80 355.12 8.99 355.06 8.91 409.91 8.51 21.79 12.51 55.69 46.34 15.64 4.17 181.54 10.96 16.83 6.51 58.74 7.91 45.72 5.50 123.06 10.21 76.85 6.38 220.06 8.00 265.57 7.16 371.34 5.33 374.13 8.89 340.93 6.19 340.93 6.24 301.16 9.73 234.68 5.48 297.43 7.03 284.93 9.02 177.94 11.68 171.14 16.12 295.65 6.24 295.65 6.24 333.49 5.73 235.08 3.59 235.08 3.59 235.08 3.59 183.41 4.39 183.41 4.39 183.41 4.39 183.41 4.39 183.41 4.39 183.41 4.39 183.41 4.39 183.41 4.39 145.69 26.79 145.69 26.78 Allowable Deviation ft 143.11 346.26 346.13 346.15 401.39 9.29 9.35 11.47 170.58 10.31 50.83 40.23 112.85 70.46 212.06 258.40 366.00 365.24 334.74 334.69 291.43 229.20 290.41 275.91 166.26 155.02 289.41 289.41 327.77 231.48 231.48 231.48 179.02 179.02 179.02 179.02 179.02 179.02 179.02 179.02 118.91 118.91 Warning ~ 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 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 . BP Alaska . Anticollision Report Company: BP Amoco Date: 2/9/2005 Time: 10:30:39 Page: 2 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: Plan L-214 (S-W), True North Reference Well: Plan L-214 (S-W) Vertical (TVD) Reference: L-214 Plan SoW 78.9 Reference Wellpath: Plan L-214 Db: Sybase Summary < Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft , PB L Pad L-211 L-211 V6 495.42 500.00 314.37 8.85 305.51 Pass: Major Risk PB L Pad L-211 L-211 PB1 V6 495.42 500.00 314.37 8.85 305.51 Pass: Major Risk PB L Pad L-216 L-216 V6 250.50 250.00 195.13 4.38 190.75 Pass: Major Risk PB L Pad NWE1-01 L-100 V2 301.80 300.00 490.01 5.22 484.80 Pass: Major Risk PB L Pad NWE1-01 NWE1-01 V5 301.80 300.00 490.01 5.22 484.80 Pass: Major Risk PB L Pad Plan L-03 (S-O) Plan L-03 V3 Plan: Pia 446.83 450.00 120.78 8.33 112.45 Pass: Major Risk PB L Pad Plan L-113 (N-B) Plan L-113 V5 Plan: PI 355.55 350.00 398.12 7.88 390.24 Pass: Major Risk PB L Pad Plan L-123 (S-U) Plan L-123 V3 Plan: PI 399.43 400.00 30.35 7.37 22.98 Pass: Major Risk PB L Pad Plan L-124 (N-C) Plan L-124 V5 Plan: PI 404.69 400.00 385.57 7.22 378.35 Pass: Major Risk PB L Pad Plan L-124 (N-C) Plan L-124PB1 V2 Plan: 404.69 400.00 385.57 7.22 378.35 Pass: Major Risk PB L Pad Plan L-202 (N-N) Plan L-202 V1 Plan: PI 598.62 600.00 224.86 10.45 214.41 Pass: Major Risk PB L Pad Plan L-202 (N-N) Plan L-202L 1 OBb V3 PI 598.62 600.00 224.86 10.57 214.29 Pass: Major Risk PB L Pad Plan L-202 (N-N) Plan L-202L2 OBa V3 PI 598.62 600.00 224.86 10.57 214.29 Pass: Major Risk PB L Pad Plan L-202 (N-N) Plan L-202L3 OA V3 Pia 598.62 600.00 224.86 10.57 214.29 Pass: Major Risk PB L Pad Plan L-203 (N-Q) Plan L-203 V4 Plan: PI 647.41 650.00 199.79 12.01 187.77 Pass: Major Risk PB L Pad Plan L-212 (N-O) Plan L-212 V8 Plan: PI 403.18 400.00 216.63 7.20 209.43 Pass: Major Risk PB L Pad Plan L-212 (N-O) Plan L-212PB1 V4 Plan: 403.18 400.00 216.63 7.09 209.54 Pass: Major Risk Field: Prudhoe Bay Site: PB L Pad Well: Plan L-214 (S-W) Wellpath: Plan L-214 -294 o 291 100 ·200 Plan L-203 (N-Q) (Plan L-203) L-120(L-120) L-!l9 (l-119) L-lOOrqu{lOOlJJ) Planll1ú!ß2-\!Il2Q~fI'J~HJaD ß2-1J111) L-J06 (L-I06) Plan L-123 (S-U) (Plan L-123) -0 Plan L-03 (S-O) (Plan L-03) 100 ~200 loa -~- -294 180 h<+ TmveIJing Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] J . 90 . Ie . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Iffa PTD# Development ~ Service CHECK WHAT APPUES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dum bel" last two. (2) digits are between 60-69) Pn.,OT (PH) ¿- 2/2// ~d>.Ç-Òç2- Exploration Stratigraphic "CLUE"· Tbe permit is for a Dew weJlbore ·segmeDt of e~istiDg weD·. . Permit No, .. APJ No. . . Pl"oduCCion. sbould cODtinue to be reponed as a fUDCtioD· of tbe origiDal API Dumber. stated above. . HOLE )D accordaDce with· 20 AAC 25.005(1), aU records, data aDd logs acquired.'or tbe pilot bole must be clearly differeDtiated ïD both Dame (Dame OD permit plus PH) aDd API Dumber (50 70/80) from records, data aDd logs acquired for well (Dame OD permit). SPACING EXCEPTION DRY DITCH SAMPLE The permi1 is approved subject ·to fuD compJiaDce with 20 AAC 2S~05S~ Approval to peñorate aDd produce is cODtiDgeDt UpoD issuaBce of " cOBserYatjoD order approviag a spaciag· e~reptioD. {Company Name} assumes tbe liabiUt)' of aD)' protest to tbe spariDg . ~~ceptioD that BI')' occur. AU dry ditcb sample sets submitted to the CommissioD must be in DO greater 1haD 30' sample intervals from below the permafrost or from wbere samples are fint caught aDd ] 0' samplehiter-vals through target 2.0Des. DATE 03/3 1105 MEMO ~ .;)J 4 ~ ~ TERRIE. L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB7-5 ANCHOAAGE,AK 99519-6612 ',,-- "Mastercard Check" 89-6/1252 190 I: ¡. 25 2DOO¡;OI:qq ¡.t.III¡; 2 27111 ¡. 5 51;11- 0 ¡'QO e ~? b/~ ?G Well bore seg Annular Disposal On Program On/Off Shore Well Name: PRUOHOE BAY UN ORIN L-214i GeoArea Unit . ðlO 24.Well$t-102 _and S:201are in_the_AOR. S-201 js_amultHatteral --- t09' ðdequate exce&s, l\ab_orsRE$, I\ewwel 20U x34u@ . 1636 psi I\otan H2S pad. Rec~rd~ in~icate nlechanical integrity_of all MSP Max MW9,Q ppg._ Test to AOOO psi Yes Yes Yes No_ Yes Yes Yes NA _Yes Yes Yes Yes Yes Yes Yes No_ Yes ClasslType Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes yes NA NA Initial 640135 PRUOHOE BAY, ORION SCHR BL OIL INC Field & Pool Company BP EXPLORATION (ALASKA) '1 Permittee attache~ _ leé!s_enumberappropriate _ _ _U_n[que weltl1ame_and ourTJb_er JOCÇIted ina d_efine~PPQI JQCÇlted proper distance_ from driJling unitb_ound_ary Well Wel Wel IQcated prJ)per _distance from otber wells S_uffjcientacreé!ge_aYé!ilable indrilliog unjt Jfdeviated, js weJlbore platincJuded 2 3 4 5 6 7 8 PTD#: 2050520 Administration in Jorce Permit c_ao be issued witbQut conservation order Permit can be issued witbout administratÎlle apprJ)vaJ Can permit be approved before 15-day wait WeJIJQcated within é!reé! é!l1dstrata authorized byJojectipo Order # (Put 10# in_cJ)mmel1t~)(fQr Operator only: affected party _Operator has_apprJ)priate_ ~ond onJy) AJI wells_ within tl4_mite_area_of reyiew id_eotified (FJ)r servjce-,^,-ell pnly) Pre-produ_ced injector; ~1.(atiQn_of pre:pro~uctipn less_ th¡;m :3 montbs (For service wel ACMP Fïndjng of Consistencyh_as beeRi&sued_ fpr this proiect _Conductor st(ÌngpJQvided _ _ _ _ _ _ _ _ _S_ul"fé!ce _casing protects allknQwl1 USDW& _ _ _ CMTvotadequateJo circutateon_cpnductpr_& surfC$g _ CMTv_ol adequateJo tie-inlQngstring tos.JI:f ~g_ _ _ _ CMTwill coyera]l koownproductiye horizon_s_ _ _ _ _ _ _ _ C_asing design& adequa_te f~r c,or, B _& permafrost _Adequate tankage OJ re_serve pit _ _ JfaJe-drill, has_a_ 10-403 fQr abandon_ment been approved _Mequate _wellQore &eparatjo_n -Pfoppsed Ifdiverter JequiJed, dQe~ it meet reguJatipos_ DJiUil1g fJujd prQgré!m schematic & eq_uip Jistadequate in comments) _BOPEs,_dJ) they meetreguJation BOPEpress ratil1g appropriate; test to (put PSig C_hoke_ manifold cQmplies w/API RF'-5:3 (May 134) WQrk will PCCUr withpytoperatjonshutdo-,^,-n Is pre&ence_ Qf H2S gas prob_able _ _ wells within ðOR yerified I~O 11 12 13 14 15 16 7 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Date Appr RPC 3/25/2005 Engineering Oate 3/29/2005 Appr WGA AOR well$._ Yes NA NA NA NA (Fpcservice well onJy:) Permit can be issued w/Q hydrogen_ sulfide meé!S_Ure~ _D_atapJeseoted on pote_ntialpveJþre&sur.ezone$_ Seisl11icanalysjs_ Qf $baJIQW gé!s_zol1es_ _ _ Sea~edcondjtjJ)o survey _(if off-sh_ore) _ _ Conta~tnam_elpj1Q"-eJor_weekly prPgress_reports [explorç¡tpryonlyt Mecba_nicç¡Lcpndjtjon pt 35 36 Oate 37 3/25/2005 38 39 Geology Appr RPC Oate ~/~ Æ1rc y/t; ;00" Date Engineering Comm issioner: Date: "ì '7') é' <-. ì~' \ Geologic Commissioner: i \\;- \ , '"