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Home My WebLink About203-029 Image F _ ~ject Well History File CL _:~r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 3 - ():L ft Well History File Identifier Organizing (done) D Two-sided 1IIII1I1I1111111111 o Rescan Needed I RESCAN DIGITAL DATA ~iskettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Scanning Preparation ,1 x 30 = (~o + D Other:: . I J Date: <¡{ I? t)..s --- ISIVVl , , I Date:~ I r 05 Isl \"Vt.) I J.Jtl = TOTAL PAGES ..s It, (Count does. not in ;Iude cover sheet) tAA-.:) Date: Cl. I r, óì-/S/II r V f BY: HelencMo/ Project Proofing BY: Helen C-Maria/ BY: Helen (Maria ? Production Scanning Stage 1 Page Count from Scanned File: ð 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Hele~ Date: <6 ; I Cj ()~ 151 m--0 BY: Stage 1 BY: If NO in stage 1 page(s) discrepancies were found: YES NO Date: 151 IUIIIIIIUIIIIIIII 1IIIII11U 111111111 I Date: 151 Quality Checked 1111111111111111111 Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ~ Exploratory ^ 203-0290 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20410-02-00 8. Property Designation (Lease Number) : ,i 9. Well Name and Number ~ ADLO-028280 PBU F-106 10. Field/Pool(s): , ~. PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11379 feet Plugs (measured) 10560' 6/11/10 feet true vertical 9033.15 feet Junk (measured) None feet Effective Depth measured 11344 feet Packer (measured) 8493 8701 true vertical 9032.16 feet (true vertical) 7743 7926 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2678 13-3/8" 72# L-80 SURFACE - 2678 SURFACE - 2678 4930 2670 Intermediate 9250 9-5/8" 47# L-80 SURFACE - 9250' SURFACE - 8420 6870 4760 Liner 616 7" 29# L-80 8744 - 9360 7965 - 8520 8160 7020 Liner 2622 3-1/2"X3-3/16"X2-7/8" 8757 - 11379 7976 - 9033 10160 10530 Liner 9.3#/6.23#/6.16# Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6#/12.75# 13CR80/L-80 SURFACE - 8805 SURFACE - 8019 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" BKR S-3 PKR 8493 7743 9-5/8" BKR PKR 8701 7926 12. Stimulation or cement squeeze summary: Intervals treated (measured): x ~( ~,y d`~k: ri~a ~ 9: ~!. s#~ ~~ .. v v a ,~~(~ 2r ~ ~~~~ Treatment descriptions including volumes used and final pressure: laska 0'sl £~ ~a ~~,~EW. Commissiar~ 13. Representative Daily Average Production or Injection Da ~IanO~i: , Et Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 609 31656 29 1691 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run ~ Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 6/29/2010 ,.~~~~ ~~-~„-. ~~.~~~,. „~,,,,~ ~ JUN ~ ~! a~~. ~,. ~ y~~~a~ .,~~~, F-10B 203-029 DDRD ATTA~_I-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F-10B 6/13/03 PER 10,590. 10,710. 9,030.96 9,033.87 F-10B 6/13/03 PER 10,760. 11,150. 9,034.63 9,033.35 F-10B 6/13/03 PER 11,200. 11,320. 9,033.67 9,031.71 F-10B 6/10/10 APF ~ 10,490. 10,520. 9,034.2 9,033.26 F-10B 6/10/10 BPS / 10,560. 10,590. 9,031.98 9,030.96 F-10B 6/11/10 APF / 10,110. 10,140. 9,021.72 9,027.25 F-10B 6/11/10 APF ~ 10,190. 10,220. 9,032.32 9,032.55 F-10B 6/11/10 APF / 10,270. 10,300. 9,031.57 9,031.05 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • F-lOB DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/9/2010... CTU 5 , 1.75" CT ,JOB SCOPE: GR/CCL log, Set CIBP, Adperf 120'. MIRU on ~ F-10B. RIH w/ PDS GR/CCL on 2.20" carrier. ***JOB CONTINUED on 6/10/10"*" l 6/10/2010 CTU 5, 1.75" CT, JOB SCOPE: GR/CCL, Set CIBP, Adperf. Log w/ GR/CCL from 10700 to 9900'. Paint flag at 10,050'. Corr -12.5' to SWS MCNL 6/12/2003. Set HES 2-7/8" CIBP at 10560'. Perf stun run #1 (30') 10490-10520'. POOH. RIH with pe gun run #2 (30') **Job~continued on 6/11/10"* 6/11 /2010 __ ~_.. ___~ ~ __w _ _ ____ ._._.__. CTU 5 1.75" CT, JOB SCOPE: GR/CCL, Set CIBP. 120' Adperfs. RIH with pert run_#2. Shoot interval #2 (10,270-10,300 ft) .POOH. At surface, confirm guns fired and ball recovered. RIH w/ pert gun run #3. Perforate 10190- 10220'. POOH. ASF, recoverd ball. RIH w/ pert gun run #4. Perforate 10110- 10140'. POOH. At surface, ball recovered. Conduct man down drill. Blow down reel. RDMO.'JOB CONTINUED on 6/12/10* 6/12/2010~CTU 5.1.75" CT. JOB SCOPE: GR/CCL, Set CIBP, 120' Adperfs. iContinue RDMO from F-10B.'`'"JOB COMPLETE** FLUIDS PUMPED BBLS 277 1 % KCI W/0.6% SAFE-CUBE 25 50/50 MEOH 302 Total ;EE _« 6" CM! WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 66.33' BF. ELEV = 37.68' KOP = 9360' Max Angle = 94 @ 11300' Datum MD = 9812' Datum TV D = 8800' SS • SAFETY N+~: WELLBORE 70° @ 10052'. ***4-112" F ~~ ~ ~ NO ENMTRYGUIDEI@ 8573' & 9- 8E PKR @ 870 G w/ 20" CONDUCTOR, 110` __ ' 2105` 4-1/2" HES X NIP, lD = 3.813" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3293 3293 4 MMG DOME RK 16 06/15/10 3 5908 5606 38 MMG SO RK 20 06(15!10 2 7615 6989 33 MMG DMY RK 0 06/13/06 1 8433 7691 29 MMG DMY RK 0 06/13/06 Minimum ID = 2.37" @ 10231' 8472` -i4-1(2" HES X NIP, ID = 3.813" 3-3/16" X 2-718" XO 8493' 9-5(8" X 4-1 /2" BKR S-3 PKR, ID = 3.870" 8527' 4-1/2" HES X NIP, ID = 3.813" -""""""""""""' 4-1/2" TBG, 12.6#, 13CR-80 8573` $573' 4-1/2" MULESHOE, ID = 3.958" VAM TOP, .0152 bpf, ID = 3.958" -- $701' 9-5/8" BKR PKR, ID = 4.000" 4-112" TBG STUB 8701' 8743` 4-112" OTIS X NIP, ID = 3.813" TOP OF 7" LNR $744' 8757` 3.75" BKR DEPLOY SLV, ID = 3.00" 8763` 3-314" X 3-112" XO, ID = 2.880" $774` 4-1/2" XN NIP (MILLED) ID = 3.80" B EH LI 8776' 3-1/2" HOWCO X NIP, ID = 2.813" 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.990" 8777' 4-112" TBG, 12.75#, L-80, ID = 3.958" $$05` 8777` 3-1/2" X 3-3/16" XO, ID = 2.880" 8805` 4-1/2" SOS TBG TAIL (BEHIND CT LNR) 9-5/8" CSG, 47#, L-80, BUTT, ID = 8.681" 9250` 7" LNR, 29#, L-80, BUTT, 10140` .0372 bpf, ID = 6.184" TOP OF WHIPSTOCK 9355` RA TAG 9365' 2-7/8" LNR, 6.16#, L-80, STL..0058 bpt, ID = 2.37" 11055' PERFORATION SUMMARY REF LOG: MCNL / CGL / GR ON 06/13/03 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 91 @ 10590' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10110 - 10140 O 06/11/10 2" 6 10190 - 10220 O 06/11/10 2" 6 10270 - 10300 O 06111!10 2" 6 10480 - 10520 O 06/11/10 2" 4 10590 - 10710 C 06/13/03 2" 4 10760 - 11150 C 06/13/03 2" 4 11200 - 11320 C 06/13/03 MILLOUT WINDOW (F10B) 9360' - 9368 3-3/16" LNR, 6.23#, L-80, TCII, (-) 10231, .0076 bof. ID = 2.805" 10231' I-i 3-3(16" X 2-7/8" XO, ID = 2.377" 10560' I-i2-7/8°CIBP(06/11/1 ( PBTD I 2-7/8" LNR, 6.16#, L-80, STL, .0055 bpf, ID = 2.372" (-~ 11379' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/26/79 ORIGINAL COMPLETION 05/29/07 JAF/PJC DRLG DRAFTCORRECTIONS O6/06!00 CTD HORIZ. SDTRCK (F-10A) 09/05/08 RDB/PJC PERF GORRECTIONS 06!14103 JLM/KK CTD SIDEt'RACK (F-10B) 06(18/10 CJS/SV SET CIBP/ ADPERF (06/11/10} 06106/06 N2ES RWO 06(18/10 TARlSV GLV C/O (06!15/10) 07/13/06 KSB/TLH GLV C!O 03/23/07 JLJ/TLH GLV GO PRUDHOE BAY UNIT WELL: F-106 PERMff No: "2030290 API No: 50-029-20410-02 SEC 2, T11 N, R13E, 2318' SNL & 2871' WEL BP Exploration (Alaska) • • <-.~.._ .~~~ -- . MICROFILMED 03101 /2008 DO NOT PLACE ~: ~r ~.. .~-: ; ~~; ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc RE: PBU F-pad - High OA Pressures . 0'6 Hello Jim. Attached are TIO plots for F-10 and F-24. They are provided with 2 time scales - the previous year and the previous 2-months to more easily see recent pressure trends. We take these events seriously and are conducting an investigation into both wells. We will share the results of the investigation and the corrective actions identified once complete. /' Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWell . com (Alaska) Inc. SCANNED JAN 0 8 2007 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Monday, December 18, 2006 3:54 PM To: NSU, ADW Well Integrity Engineer Subject: PBU F-pad - High OA Pressures Inspector witnessed SVS tests on PBU F-pad 12/16/06; OA pessures exceeding 1000 psi were found on following wells: F-10B (PTD 2030290) : F-24 (PTD 1831540): *1060 psi* ; no waiver *1060 psi*; no waiver (well on gas lift) There were several others with Tubing and IA pressures nearly equal in the 1300 to 1800 psi range; none of these wells had waivers and none were on gas lift. A copy of his inspection report is attached. The OA pressures observed exceed the reporting thresholds established in CO 492. Both wells have a history of TxIA communication, failing TIFLs (F-10B last reported 6/5/2005; F-24 last reported 7/4/2004) . Please review and provide TIO plots for both wells. Jim Regg AOGCC Content-Description: F-IO TIO Plot.jpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of2 12/26/2006 10:41 AM Kb: PBU F-pad - High OA Pressures . . Content-Description: F-IO TIO Plot - 2 Month.jpg F-IO TIO Plot - 2 Month.jpg Content-Type: image/jpeg Content-Encoding: base64 Content-Description: F-24 TIO Plot.jpg F-24 TIO Content-Type: image/jpeg Content-Encoding: base64 Content-Description: F-24 TIO Plot - 2 Month.jpg F-24 TIO Plot - 2 Month.jpg Content-Type: image/jpeg Content-Encoding: base64 20f2 12/26/200610:41 AM PJotjpg (JPEG Image, F-IQ TIO PIot . 2 Month.jpg (JPEG Image. 827x280 pixels) F-24 TIO Plotjpg (JPEG Image, 827x280 pixels) Plot - 2 Monthjpg (JPEG Image, 827x280 pixels) -- STATE OF ALASKA. RECE\VEO ALASKAaIL AND GAS CONSERVATION C MISSION ..JUN 2, 7 2006 REPORT OF SUNDRY WELL OPERATION5 comnission ~\aSKa Qi\ & Gas Cons. ._A 1. Operations Performed: ... o Abandon o Repair Well o Plug Perforations o Stimulate o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension o Re-Enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit I 0 Urill Number: BP Exploration (Alaska) Inc. ~ Development 0 Exploratory 203-029 J. Aooress: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20410-02-00 7. KB Elevation (ft): 66.33' 9. Well Name and Number: PBU F-10B 8. Property Designation: 10. Field / Pool(s): ADL 028280 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11379 feet ., if-, ", "'. ' i~-' :,- true vertical 9033 feet Plugs (measured) :Non\?A~"~:;:;·.' Effective depth: measured 11344 feet Junk (measured) None true vertical 9032 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2678' 13-3/8" 2678' 2678' 4930 2670 Intermediate 9250' 9-5/8" 9250' 8420' 6870 4760 Production Liner 616' 7" 8744' - 9360' 7965' - 8520' 8160 7020 Liner 2622' 3-1/2" x 3-3/16" x 2-7/8" 8757' - 11379' 7976' - 9033' 10160 10530 Perforation Depth MD (ft): 10590' - 11320 Perforation Depth TVD (ft): 9031' - 9032' 4-1/2",12.6# / 12.75# 13Cr80 / L-80 8805' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker packer; 8701'; 9-5/8" x 4-1/2" Baker 'S-3' packer 8493' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft JUN 2 S 2006 Treatment description including volumes used and final pressure: 13. Representative Daily AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service ~ Well Schematic Diagram 16. Well Status after proposed work: ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt Contact David Reem, 564-5743 N/A Printed Name Terrie Hubble Title Technical Assistant Signature ~~ 0 \i¡..l~ Phone Date O"Iz.t,/~ Prepared By Name/Number: 564-4628 Terrie Hubble, 564-4628 . . Form 10-404 Revised 04/20060 RIG I f~ A L Submit Onglnal Only TREE = Wa.LHEAO = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= 6" crvv McEVOY OTIS 66.33' 37.68' 9360' 94 @ 11300' 9812' 8800' SS From DRLARAFT 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2678' r-- Minimum ID = 2.37" @ 10231' 3-3/16" X 2-7/8" XO 1 TOP OF 7" LNR I 8744' 13-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I 14-1/2" TBG, 12.75#, L-80 I 8777' 8805' 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9250' 17" LNR, 29#, L-80, .0372 bpf, ID = 6.184" I 10140' TOP OF WHIPSTOCK I 1 RA TAG I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" I ÆRFORA TION SUMMARY REF LOG: MCNL / CCL 1 GR ON 06/13/03 TIE-IN LOG: GEOLOGY PDC LOG ANGLEATTOPÆRF: 91 @ 10590' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2" 4 10590 - 10710 C 06/13/03 2" 4 10760-11150 C 06/13/03 2" 4 11200 - 11320 C 06/13/03 DATE 12/26/79 06/06/00 06/14/03 08/24/03 04/30/04 03/02/05 REV BY COMMENTS ORIGINAL COM PLETION CTD HORlZ. SDTRCK (F.10A) JLM/KK CTD SIDETRACK (F-10B) BJfvVKK SET WEA THERFORD PATCHES DAV/KAK GLV C/O NBF/TLH GLV C/O (02/12/05) DATE 06/07/05 09/22/05 09/28/05 F-10B e 2104' H 2616' -i 4-1/2" HES X NIP, ID - 3.813" 9-5/8" DV PKR I GAS LIFT MANDRELS DEV TYÆ VLV LATCH 29 MMG OCR RKP 33 MMG DMY RKP 38 MMG DMY RKP 4 MMG OMY RKP MD 1VD 8433 7691 7615 6989 5908 5606 3293 3293 PORT DATE o 06/13/06 o 06/13/06 o 06/13/06 o 06/13/06 8471' H 4-1I2"HESXNIP,ID=3.813" I 9 5/8" x 4 1/2" Baker S-3 packer 4-1/2" HES X NIP, 10 = 3.813" 9-5/8" BAKER PKR, ID=4.75" 4-1/2" OTIS X NIP, 10 = 3.813" I 8757' H 3.75" BKR DEPLOYMENT SLV, ID= 3.0" I 8774' -14-1/2" XN NIP, MILLED ID = 3.80" (BEHIND CT LNR) 8776' 3-1/2"HOWCOXNIP,ID=2.813" I 8777' 3-1/2" X 3-3/16" XO, ID = 2.880" I -14-1/2" SOS TBG TAIL (BEHIND CT LNR) I MILLOUT WINDOW 9360' - 9368' 13-3/16" LNR, 6.23#, L-80, .0076 bpf, ID = 2.805" I 12-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.380" REV BY COMMENTS KDClTLH GL V C/O JGMlTLH PLUG SET / PATCH PULLED JAFITLH PLUG PULL / PATCH CORRECT. PRUDHOE BA Y UNIT WELL: F-10B ÆRMIT No: "2030290 API No: 50-029-20410-02 SEC 2, T11 N, R13E. 2871' FWL & 2962' FNS BP Exploration (Alaska) e e F-10B Prudhoe Bay Unit 50-029-20410-02 203-029 Accept: Spud: Release: Ri: 06/06/06 N/AO 06/14/06 Nabors 2ES PRE-RIG WORK 05/30/06 WELL SHUT-IN AT ARRIVAL. T/I/O 0/0/500. IBP SET AT 8710' IN 41/2" TUBING. MEDIUM CHARGES TUBING PUNCER OVER 7930' -7935'. 2' X 16' STRING SHOT OVER 7961' -7977'. 53/4" CHEMICAL CUTTER CUT 7" TUBING AT 7955'. THE CORRELATION LOG SHOWED 160 JOINTS INSTEAD OF 161 JOINTS OF TUBING BELOW THE SSSV AS DESCRIBED IN THE TUBING TALLY DATED 12/25/79. THE SSSV IS ALSO APPROXIMATELY 40' DEEPER THAN TUBING TALLY INDICATES. EXTRA JOINT APPEARS TO BE ABOVE SSSV INSTEAD OF BELOW SSSV. 06/02106 CIRC-OUT MIT OA 2000 PSI PASSED (PRE RWO) 2BBLS METH SPACER FOLLOWED BY 140 BBLS OF 120° DIESEL DOWN TBG, U-TUBE TXIA FOR F-PROTECT. F-PROTECT IA CASCO JUMPER 1 BBL DIESEL PUMPED 6.6 BBLS OF 40° DIESEL DOWN OA TO REACH 2000 PSI. 1 ST TEST 1 ST 15 MIN LOST 60 PSI 2ND 15 MIN LOST 60 PSI FOR A TOTAL OF 120 PSI IN 30 MIN. 2ND TEST 1ST 15 MINLOST 40 PSI 2ND 15 MIN LOST 20 PSI FOR A TOTAL OF 60 PSI IN 30 MIN. BLEED OA PSI DOWN TO 300 PSI, BLED FLUID UNTIL SWAPPED TO GAS, SI BLEED AND RIGGED DOWN. FINAL WHP'S= VACNAC/300. T/I/O= VACNAC/410 CMIT TX IA TO 3000 PSI (PREP RWO) (POST CIRC OUT) PUMPED 7.5 BBLS OF 40° DIESEL DOWN IA TO REACH 3000 PSI FOR CMIT TXIA. 1 ST TEST 1 ST 15 MIN LOST 30/0 PSI 2ND 15 MIN LOST 30/0 PSI FOR A TOTAL OF 60/0 PSI IN 30 MIN. 3RD 15 MIN LOST % PSI FOR A TOTAL OF 30/0 PSI IN 45 MIN. BLEED TXIA PSI OFF BLEED BACK 6+ BBLS. FINAL WHP'S=0/0/400. 06/03/06 T/IA/OA= 0/0/0 PRE-RIG MIT PPPOT-T/IC TUBING PASSED/ IC HANGER FAILED. PPPOT-T PASSED. BLEED OFF TEST VOID PRESSURE TO O. CYCLE ALL LDS ON TUBING SPOOL. ALL OPERATE FREE. RIG UP TEST VOID TO 5000 PSI. FOR 30 MINUTES. PRESSURE AT 4850 AFTER 30 MINUTES. TUBING HANGER TEST PASSED. PPPOT-IC FAILED. BLED OFF TRAPPED PRESSURE ON IC HANGER VOID TO O. CYCLE ALL LDS ON IC HANGER. ALL OPERATE FREE. RIG UP TEST PUMP. PRESSURE UP VOID TO 3800, BLED OFF TO 3400. REMOVE l' TESTPORT BLEEDER, FOUND GREEN PACKING IN PACKING VOID. ATTEMPT TO RE-PACK, WAS ABLE TO PUSH SMALL AMOUNT OF PACKING. RE-TEST ONLY BUILD TO 3000 PSI. T/I/0=/0/450. TEMP=SI. BLEED WHP'S TO 0 PSI. (PRE-CAMERON, RWO). TP REMSINED ON VAC OVERNIGHT. lAP WENT FROM VAC TO 0 PSI OVERNIGHT. OAP INCREASED 150 PSI OVERNIGHT. OA FL AT 12' «1 BBL). BLED OAP FROM 450 PSI TO 2 PSI IN 5 HOURS. SI FOR 2 MINUTES AND OAP INCREASED 13 PSI TO 20 PSI. WILL CONTINUE TO BLEED OAP WHILE CAMERON TESTS THE WELLHEAD. TBG HANGER PASSED. IC HANGER FAILED. RID AND MONITOR BUR FOR 15 MINUTES. OAP INCREASED 52 PSI TO 55 PSI DURING MONITOR. OA FL AT 30' « 2 BBL). 28 GALLONS OF FLUID WAS RETURNED DURING BLEED. FINAL WHP'S=VAC/0/55. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/5/2006 Rig Release: Rig Number: 2ES Spud Date: 6/2/2000 End: 6/4/2006 18:00 - 22:00 4.00 RIGD P POST Rig down floor, lay down derrick. 22:00 - 00:00 2.00 RIGD P POST Prepare for repairs on tires 6/5/2006 00:00 - 19:00 19.00 RIGD C POST Change tires on rig. 19:00 - 22:00 3.00 MOB C PRE Move rig from R pad to F pad. 22:00 - 00:00 2.00 MOB C PRE Lay herculite,spot rig on F-10. Close cellar doors, prepare to raise derrick. 6/6/2006 00:00 - 05:00 5.00 MOB P PRE Raise Derrick. Spot mud pits and support buildings. Rig accept 05:0006/06/2006. 05:00 - 06:00 1.00 MOB P PRE Pre spud meeting, take on seawater continue to rig up. 06:00 - 14:30 8.50 WHSUR P DECOMP RlU DSM lubricator & pull BPV - UD lubricator. RlU lines to tree & annulus & reverse out freeze protect fluid via choke. Shut down & line up on tubing. Pump 40 bbl Safe Surf pill & circulate surface to surface @ 3 - 4 BPM, 300 psi. BID lines. 14:30 - 15:00 0.50 WHSUR P DECOMP Dry rod in TWC & test from below to 1000 psi. BID & RID circulating lines. 15:00 - 16:30 1.50 WHSUR P DECOMP N/D tree & adaptor flange. Remove from cellar. 16:30 - 18:30 2.00 BOPSU P DECOMP Function BOP's - check for hydraulic leaks. N/U BOPE. 18:30 - 19:30 1.00 BOPSU P DECOMP C/O top set of rams to 7". 19:30 - 00:00 4.50 BOPSU P DECOMP Test BOPE per BP & AOGCC Regs to 250 psi I 3500 psi. Tested all equipment utilizing 7" test it except lower set of 2 7/8" x 5" variable rams which will be completed utilizing 4" test it once 7" tubing has been removed from the well. Witness of test was waived by AOGCC Rep Chuck Sheve & test witnessed by Tool Pusher Ronnie Dalton & WSL Mike Dinger. 6/7/2006 00:00 - 02:00 2.00 BOPSU P DECOMP Test BOPE per BP & AOGCC Regs to 250 I 3500 psi. 1 failure on test. Changed out TIW valve & replaced with spare. Break out & UD test it. BID top drive & lines. 02:00 - 03:00 1.00 BOPSU DECOMP M/U lubricator & extension. Pull TWC & UD lubricator. 03:00 - 04:30 1.50 PULL DECOMP M/U x-overs onto it of 4" DP & screw into tubing hanger. M/U to top drive. BOLDS. PJSM on pulling hanger. Pull hanger free wI 180K. Pull hanger to rig floor. Break out hanger & x-overs. UD it of 4" DP & hanger. RlU control line spooling unit & power tongs. 04:30 - 09:30 5.00 PULL P DECOMP POH & UD 7" 26# L-80 TC4S tubing. RID & UD spooling unit. Recovered 4 stainless steel bands, 22.5 out of 25 control line clamps, & 23 out of 25 control line clamp pins. Continue POH & UD 7" tubing. 09:30 - 10:30 1.00 PULL P DECOMP Service top drive & drawworks. 10:30 - 13:00 2.50 PULL N RREP DECOMP Troubleshoot & repair controls for lowering skate. Replaced & checked loose electrical connections. 13:00 - 19:00 6.00 PULL P DECOMP POH & UD 7" 26# L-80 TC4S tubing. Recovered a total of 192 its & 1 cut it (21.93') Chemical cut of it nice & smooth. Noted five 3/8" perf holes in it 97 @ -3980'. RID 7" handling equip't - clean & clear floor. 19:00 - 20:00 1.00 BOPSU P DECOMP Close blind rams & C/O top set of rams from 7" to 3 1/2" x 6" variables. 20:00 - 21 :30 1.50 BOPSU P DECOMP Open blinds & install test plug. Test top & bottom rams, annular preventer, 4" TIW, & 4" dart sub to 250 I 3500 psi wi 4" test it. Witness of test waived by AOGCC Rep Lou Grimaldi & Printed: 6/20/2006 12:16:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/5/2006 Rig Release: Rig Number: 2ES Spud Date: 6/2/2000 End: witnessed by Tool Pusher Ronnie Dalton & WSL Mike Dinger. Pull test plug & install bowl protector. 21 :30 - 23:30 2.00 PULL P DECOMP M/U K anchor retrieval BHA - Model B spear, stop sub, XO, bumper sub, oil jars, 9 drill collars, accelerator jars, 21 jts of 5" HWDP, & XO to 4" HT-40 DP. 23:30 - 00:00 0.50 PULL P DECOMP C/O handling equip't. P/U 4" DP singles from pipeshed & RIH. 6/8/2006 00:00 - 04:00 4.00 PULL P DECOMP P/U 4" DP singles from pipeshed & RIH. 04:00 - 05:30 1.50 PULL P DECOMP M/U 95/8" storm packer & set below wellhead. Test to 800 psi from below packer. BOLDS & pull bowl protector. 05:30 - 12:30 7.00 BOPSU P DECOMP Remove turnbuckles & N/D riser & BOPE. Remove tubing spool & packoff. Clean & dress casing head & stub. Install new packoff & tubing spool & torque. Pump plastic & test void to 3800 psi for 30 minutes. RID Cameron. 12:30 - 14:30 2.00 BOPSU P DECOMP PJSM - N/U BOPE. 14:30 - 15:00 0.50 BOPSU P DECOMP Install test plug, close blind shear rams & attempt to test tubing spool flange & BOP flange. Leaking by blind shear rams. 15:00 - 17:30 2.50 BOPSU N RREP DECOMP Remove blind shear rams & repair. Install blind shear rams. 17:30 - 18:30 1.00 BOPSU P DECOMP Test blinds & tubing spool I BOP flange to 250 I 3500 psi. Remove test plug & install bowl protector. 18:30 - 19:00 0.50 PULL P DECOMP Stab into RTTS with running tool, release RTTS, UD running tool & RTTS. 19:00 - 20:30 1.50 PULL P DECOMP RIH to 7" stub wI spear. P/U w1185K, SIO w1155K. Top of 7" tubing stub @ 7972' - engage spear & rotate 12 RH turns, 15K ft Ibs TQ. Work pipe & jar until fish free. Max overpull of 125K while working & jarring on fish. Pull free - P/U w1210K - fish on. 20:30 - 22:00 1.50 PULL P DECOMP Pump hi-vis sweep surface to surface @ 11 BPM, 1700 psi. No significant solids / debris once sweep at surface. Monitor well - static - BID top drive. Perform derrick inspection. 22:00 - 00:00 2.00 PULL P DECOMP POH from 7972' to 2361' with fish. 6/9/2006 00:00 - 01 :00 1.00 PULL P DECOMP POH from 2361' to 964'. 01 :00 - 02:30 1.50 PULL P DECOMP Stand back HWDP & DC's. UD accelerator jars, oil jars, bumper sub. RlU power tongs & C/O to 7" handling equip't. UD spear & cut off jt of 7" tubing. Recovered a partial piece of control line protector between spear & top of 7" stub. 02:30 - 04:30 2.00 PULL P DECOMP UD 16 jts of 7" 26# TC4S tubing & SBR. Casing patch inside jt 194. Total of 209 jts recovered. 04:30 - 05:30 1.00 PULL P DECOMP Clear & clean floor. Mobilize tools from Baker Fishing. 05:30 - 07:00 1.50 PULL P DECOMP Slip & cut 102' drilling line. Inspect traction motor brushes. Lube Elmago splines. Service top drive & crown 07:00 - 08:30 1.50 PULL P DECOMP M/U K anchor & slick stick retrieval BHA & RIH - Overshot guide, bowl wI 5" grapple, bushing, bowl wI 5" grapple, overshot extension, top sub, bumper sub, oil jars, 9 drill collars, accelerator jars & 7 stands 5" HWDP. 08:30 - 11 :30 3.00 PULL P DECOMP RIH from 966' to 7964'. 11 :30 - 12:30 1.00 PULL P DECOMP P/U 4" DP singles from pipeshed & RIH. P/U w1 206K, SIO w1160K 12:30 - 14:00 1.50 PULL P DECOMP Break circulation @ 4BPM, 300 psi & wash down to top of fish Printed: 6/20/2006 12: 16:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/5/2006 Rig Release: Rig Number: 2ES Spud Date: 6/2/2000 End: 6/9/2006 12:30 - 14:00 1.50 PULL P DECOMP @ 8663'. Swallow 8' - Rotate & jar up to 120K over. Release K anchor. Monitor well. 14:00 - 17:30 3.50 PULL P DECOMP Pump dry job - BID top drive. POH to BHA. 17:30 - 19:00 1.50 PULL P DECOMP Stand back HWDP & DC's. Make service breaks on overshot assy & UD slick stick & K anchor. 19:00 - 21 :00 2.00 PULL P DECOMP M/U clean out assy & RIH - Used 81/2" MXC-1 bit, 95/8" casing scraper, 2 boot baskets, bit sub, bumper sub, oil jars, 9 drill collars, & 7 stands 5" HWDP. 21 :00 - 00:00 3.00 PULL P DECOMP RIH from 958' to 8424'. 6/10/2006 00:00 - 00:30 0.50 PULL P DECOMP RIH from 8421' & tag top of packer @ 8686'. P/U wt 210K, SIO wt 165K. 00:30 - 01 :30 1.00 PULL P DECOMP Pump 20 bbl hi-vis sweep & circulate surface to surface @ 12 BPM 1750 psi. No significant solids I debris seen @ shakers with sweep @ surface. 01 :30 - 02:30 1.00 PULL P DECOMP RlU hose & line up to reverse circulate. Pump 20 bbl hi-vis & circulate surface to surface @ 9 BPM, 1900 psi. No significant solids I debris seen @ shakers with sweep @ surface. 02:30 - 03:00 0.50 PULL P DECOMP RID circ lines & BID. Monitor well - static. 03:00 - 06:00 3.00 PULL P DECOMP POH from 8686' to BHA. Monitor well @ BHA. 06:00 - 08:00 2.00 PULL P DECOMP Stand back HWDP & DC's. UD 8 1/2" bit & 9 518" scraper & check boot baskets. (no debris) Clear & clean floor. 08:00 - 12:00 4.00 PULL P DECOMP C/O handling equip't & M/U BHA - 3 3/4" mill head extension, reverse circulating basket, reverse basket extension, reverse basket head, bit sub, 2 jts 2 7/8" PAC DP, X-over, pump out sub, X-over, 2 boot baskets, bit sub, bumper sub, oil jars, 9 DC's, & 7 stands HWDP. C/O handling equip't for 4" DP. 12:00 - 15:00 3.00 PULL P DECOMP RIH & P/U single jt of DP & tag packer top @ 8686'. Continue RIH to 8697' & tag w/5-10K 15:00 - 17:00 2.00 PULL P DECOMP Drop ball & open reverse circulaing ports on reverse circulating junk basket. Pump 20 bbl hi-vis sweep while attempting to get beyond 8697'. Unable to get deeper that 8697'. Circ out sweep @ 7 BPM, 1070 psi. 17:00 - 20:00 3.00 PULL P DECOMP POH to BHA to check junk basket contents. 20:00 - 21 :30 1.50 PULL P DECOMP Stand back HWDP & DC's & UD jars & bumper sub. Make service breaks on reverse circulating basket & clean out. Basket completely full of rubber, scale, & 2 large pieces of metal from control line protectors. (5 gals of solids recovered) 21 :30 - 23:00 1.50 PULL P DECOMP M/U same BHA back up & RIH. 23:00 - 00:00 1.00 PULL P DECOMP RIH wI reverse circulating junk basket BHA on 4" DP. 6/11/2006 00:00 - 02:00 2.00 PULL P DECOMP RIH wI reverse circulating junk basket on 4" DP. 02:00 - 03:30 1.50 PULL P DECOMP M/U single jt of DP & lower string below top of packer @ 8686'. P/U wt 215K, SIO wt 155K. Record parameters off bottom - pump rate 5.5 BPM, 800 psi, 30 RPM, off bottom TQ 6K. Shut down pump & rotary. Lower string & tag up @ 8697' w/5K. P/U off bottom & engage pump. Wash from 8697' to 8708'. UD single & rack back one stand of DP. 03:30 - 05:30 2.00 PULL P DECOMP PJSM - Slip & cut drilling line. Service top drive & adjust brakes. Printed: 6/20/2006 12: 16:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/5/2006 Rig Release: Rig Number: 2ES Spud Date: 6/2/2000 End: 6/11/2006 05:30 - 08:30 3.00 PULL P DECOMP POH wI reverse circulating junk basket to BHA Monitor well.. 08:30 - 10:30 2.00 PULL P DECOMP Stand back HWDP & DC's. Check reverse circulating junk basket for debris (5 chunks of metal & control line protector rubber recovered) UD reverse circulating junk basket. 10:30 - 12:00 1.50 PULL P DECOMP M/U IBP retrieval BHA - 3 5/8" sure catch overshot, X-over, 2 jts of 2 7/8" PAC DP, X-over, pump out sub, X-over, 2 boot baskets, bit sub, bumper sub, oil jars, 9 DC's, & 7 stands 5" HWDP. 12:00 - 14:30 2.50 PULL P DECOMP RIH wI overshot to 8645'. 14:30 - 15:30 1.00 PULL P DECOMP M/U top drive & break circ @ 1 BPM, 90 psi. Wash & work overshot down to 8705'. Increase pump rate to 3 BPM, 300 psi & continue to wash & work overshot down. P/U off bottom & engage rotary - 10 RPM, TQ 5500. Continue to wash & work with & wlo pumps or rotary. Max WOB 10K. Unable to engage IBP. Monitor well. 15:30 - 19:00 3.50 PULL P DECOMP POH to BHA. 19:00 - 21 :00 2.00 PULL P DECOMP UD jars & bumper sub. R/U power tongs - break & UD overshot. Recovered control line protector metal including control line protector pin jammed up inside overshot collet. Appears overshot was over IBP fishing neck, but was unable to engage due to metal. Clear & clean floor. 21 :00 - 22:00 1.00 PULL P DECOMP M/U BHA - 3 3/4" mill head extension, reverse circulating junk basket, reverse basket extension, reverse basket head, bit sub, 2 jts 2 7/8" PAC DP, X-over, pump out sub, X-over, 2 boot baskets, bit sub, bumper sub, oil jars, 9 DC's, & 7 stands 5" HWDP. 22:00 - 00:00 2.00 PULL P DECOMP RIH to top of packer @ 8686'. 6/12/2006 00:00 - 01 :00 1.00 PULL P DECOMP M/U single & break circ. Wash down to 8708' @ 8 BPM 1400 psi. Work string tagging @ 8708' w/10K. P/U off bottom & engage rotary @ 30 RPM, off bottom Tq 6200 ft Ibs. Ease down wI low wt on junk basket & Tq @ 6400 ft Ibs. Was able to work down to 8709'. 01 :00 - 03:30 2.50 PULL P DECOMP UD single & monitor well. POH to BHA. 03:30 - 05:00 1.50 PULL P DECOMP Stand back HWDP & DC's. UD jaes & bumper sub. Break down reverse circulating basket - recover 2 pcs of metal from control line protectors. 05:00 - 06:00 1.00 PULL P DECOMP M/U overshot BHA for retrieving IBP - sure catch overshot, x-over, 2 jts 2 7/8" PAC DP, x-over, pump out sub, x-over, 2 boot baskets, bit sub, bumper sub, oil jars, 9 DC's, & 7 stands HWDP. 06:00 - 08:30 2.50 PULL P DECOMP RIH to 8646. Break circulation & get parameters: P/U wt 215K, SIO 155K, Rot wt 180K, 30 RPM, off bottom Tq 6K. 08:30 - 10:00 1.50 PULL P DECOMP Circ @ 1.5 BPM, 70 psi & wash down over IBP. Tag up @ 8709'. Verify latch w/5-10K overpull. Allow elements to relax & push plug down to 8715'. Pull up to 8705' & monitor well. Lost 6 bbls fluid initially & losses stabilized to 0 before POH. 10:00 - 11 :00 1.00 PULL P DECOMP POH & UD DP to 8646'. Printed: 6/20/2006 12: 16:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 WORKOVER NABORS ALASKA DRILLING I NABORS 2ES Start: 6/5/2006 Rig Release: Rig Number: 2ES Spud Date: 6/2/2000 End: 6/12/2006 11 :00 - 12:30 1.50 PULL P DECOMP Slip & cut 83' of drilling line. Inspect & adjust brakes. BID top drive. 12:30 - 19:00 6.50 PULL P DECOMP POH & UD DP to BHA @ 1025' 19:00 - 00:00 5.00 PULL P DECOMP CIO elevators & UD HWDP, DC's, & BHA. Retrieved IBP & all associated pieces (good shape) Clear & clean floor. 6/13/2006 00:00 - 01 :00 1.00 RUNCO RUNCMP C/O to long bails on top drive. 01 :00 - 02:30 1.50 BOPSU RUNCMP Pull bowl protector, install test plug, P/U test jt & TIW valve. Test upper & lower pipe rams with 4 1/2" test jt to 250 I 3500 psi per AOGCC & BP Regs. Test witnessed by Tool Pusher Ronnie Dalton & WSL Mike Dinger. UD test jt & pull test plug. Clear tools from floor. 02:30 - 04:00 RUNCMP Bring tools to floor. PJSM & RlU tools & handling equip't for running chrome completion. PJSM for running completion. 04:00 - 17:00 RUNCMP M/U tailpipe ass'y & packer - Bakerlok connections below packer. Run 4 1/2" chrome completion per running tally utilizing Torque Turn on connections. M/U Tq 4440 ftIlbs & utilizing Jet Lube Seal Guard thread compound on connections. Ran a total of 198 jts 41/2" 12.6# 13CR80 Yam Top tubing. 17:00 - 19:00 RUNCMP RID compensator & C/O elevators. M/U landing jt & hanger. Land hanger - 85K in slips wlo top drive wt. RILDS, UD landing jt, & RlU circ lines to annulus. 19:00 - 22:30 RUNCMP Line up & reverse circulate 130 bbls clean sea water, 283 bbls sea water treated wI corrosion inhibitor followed by 176 bbls clean sea water. Pump rate 3 BPM 200 psi. 22:30 - 00:00 RUNCMP Install landing jt, drop 1 7/8" ball & rod, UD landing jt. Close blind rams & line up to pump down tubing. Set packer wI 3500 psi & hold test for 30 minutes. Bleed off tubing to 1500 psi & line up on annulus and pressure test to 3500 psi & hold for 30 minutes. Bleed off tubing and observe DCR valve shear wI 2500 psi differential. Open blind rams & pump 3 bbls both ways to ensure DCR valve completely sheared. 6/14/2006 00:00 - 01 :30 1.50 BOPSU P RUNCMP Dry rod in two way check valve. Test from underneath to 1000 psi. 01 :30 - 03:30 2.00 WHSUR P WHDTRE Pul mouse hole & riser. NID BOPE & secure in cellar. 03:30 - 07:30 4.00 WHSUR P WHDTRE Lift & secure bottom section of beaver slide. Mobilize adaptor flange & tree to cellar. Install adaptor flange & tree. Test tree & adaptor flange to 5000 psi. BID lines in pit complex in preparation for rig move. 07:30 - 08:30 1.00 WHSUR P WHDTRE RlU DSM lubricator & pull two way check valve. RID lubricator. 08:30 - 11 :30 3.00 WHSUR P WHDTRE RlU Little Red & pressure test lines to 3500 psi. Pump 147 bbls diesel down IA @ 1.5 BPM, 300 psi. 11 :30 - 12:30 1.00 WHSUR P WHDTRE Line up & U-tube to balance point. 12:30 - 15:00 2.50 WHSUR P WHDTRE Dry rod in BPV & test from below to 1000 psi wI Little Red. Remove secondary annulus valve, install flanges, manifolds, gauges, & secure tree. Release rig 6/14/2006 @ 1500 hrs. Printed: 6/20/2006 12: 16:05 PM e e WELL LOG TRANSMITTAL {)D?;-o;;,q To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 /?J(v 4-D RE: MWD Formation Evaluation Logs F-lOB, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 F-IOB: LAS Data & Digital Log Images: 50-029-20410-02 1 CD Rom ~ :;/8{}/r7(P _ STATE OF ALASKA _ ALA_ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED DEC 0 5 2005 Alft.l.ft na o. ,.., ,.. '" 1. Operations Abandon 0 Repair Well [] Plug Perforations 0 Stimulate 0 umer I I._w.. -v..... î ~ Performed: Alter Casing 0 Pull Tubing D Perforate New Pool 0 Waiver 0 Time Extension [j\1¡¡;IIUI (lye Change Approved Program 0 Opera!. Shutdown D Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development R1 Exploratory D 203-0290 ~. 3. Address: P.O. Box 196612 Stratigraphic D Service D a.API Number: Anchorage, AK 99519-6612 50-029-20410-02-00 7. KB Elevation (ft): 9. Well Name and Number: 66.33 KB F-10B 8. Property Designation: 10. Field/Pool(s): ADL-028280 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11379 feet Plugs (measured) None true vertical 9033.15 feet Junk (measured) None Effective Depth measured 11344 feet true vertical 9032.16 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 33 - 113 33 - 113 1490 470 Surface 2646 13-3/8" 72# L-80 32 - 2678 32 - 2677.84 5380 2670 Production 9219 9-5/8" 47# L-80 31 - 9250 31 - 8419.68 6870 4760 Liner 616 7" 29# L-80 8744 - 9360 7964.51 - 8520.33 8160 7020 Liner 22 3-1/2" 9.3# L-80 8757 - 8779 7976.05 - 7995.59 10160 10530 Liner 1452 3-3/16" 6.2# L-80 8779 - 10231 7995.59 - 9032.42 Liner 1148 2-7/8" 6.16# L-80 10231 - 11379 9032.42 - 9033.15 13450 13890 Perforation depth: Measured depth: 10590 - 10710 10760 -11150 11200 - 11320 '8 True Vertical depth: 9030.96 - 9033.87 9034.63 - 9033.35 9033.67 - 9031.71 ~ ($;) "",,-I Tubing: (size, grade, and measured depth) 7" 26# L-80 29 - 8701 U 5-1/2" 15.5# L-80 3986 - 4008 W..J 0 5-1/2" 15.5# L-80 7998 - 8018 rC} 4-1/2" 12.6# L-80 8701 - 8805 ~ % Packers and SSSV (type and measured depth) 9-5/8" DV Packer 2616 ~ 5-1/2" Weatherford ArrowPac Packer 7898 \) 5-1/2" Weatherford ArrowPac Packer 8014 rJ'?' 7" Baker ZXP Packer 8701 12. Stimulation or cement squeeze summary: RBDMS BFl DEC 0 6 2005 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development W' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil R1 Gas D WAG D GINJ D WINJ D WDSPL [J 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal P",ted Name 8ha",:";" V..tal , ¿ Title Data Mgmt Engr Signat~ '::12 Phone 564-4424 Date 11/30/2005 . . Form 10-404 Revised 04/2004 !~J¡4' Submit Onglnal Only .. F-10B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I~CTIVITYDA TE I SUMMARY 10/3/2005 TIO= 50/vac/510. TBG & IA FL (pre - TBG Patch). TBG FL @ 1020' (38 bbls), IA FL @ 1230' (32 bbls). 10/4/2005 CORRELATED TO SWS PATCH SETTING RECORD 8/24/03. SET LOWER ARROW PAC PACKER @ 4012' ELMD. COULD NOT GET PATCH TO SET INTO LOWER PACKER DUE TO MISFIRE. PATCH WOULD NOT COME BACK THROUGH SSSVN @ 2015' MD. PULLED OUT OF WEAK POINT WITH APPROX. 6300 LB OVERPULL. POOH, SECURED WELL AND LAID DOWN FOR THE EVENING. 10/13/2005 ***WELL SHUT IN ON ARRIVAL***(FISH PATCH) RIG UP BRAIDED LINE EQUIPMENT ***CONTINUED ON WSR 10-14-05*** 10/14/2005 ***CONTINUED FROM WSR 10-13-05***(FISHING) RAN 4.5 LIB. SAT DOWN @ 3959 SLM. MARKS OF CLEAN F.N. RAN 41/2 GR,W/ 3.95 OVERSHOT W/ 25/16 GRAPPLE,SAT DOWN @ 3959 SLM. LATCHED FISH,SHEARED GR@ SSSV. RAN 41/2 GS,LATCHED FISH @ 3947 SLM. POOH WORKED THRU SSSV,RECOVERED ALL FISH, RIG DOWN BRAIDED LINE EQUIPMENT AND RIG UP .125 WIRE. RAN 4.5" GR AND LOWER ANCHOR TEST TOOL. ***CONTINUED ON WSR 10-15-05*** 10/15/2005 ***CONTINUED FROM WSR 10-14-05***( TEST LOWER ANCHOR) RAN SEAL ASSEMBLY W/ KAT STANDING VALVE TO 4008 SLM. LRS PUMPED 30 BBLS DIESEL, DID NOT PRESSURE UP, PUMPED 25 BBLS CRUDE, PRESSURED UP TO 2500 PSI, WILL NOT HOLD. RIG DOWN LRS.SHEARED GR. RAN 41/2 CENT,4 1/2 GS,LATCHED STANDING VALVE @ 4006 SLM. PULLED, ALL PACKING GOOD. RDMO. *** LEFT WELL SHUT I~~!URNED WELL OVER TO PAD OPER. *** 10/20/2005 *** WELL SHUT IN UPON ARRIVAL *** RAN 41/2 GS W/ WEATHERFORD PRT. SAT DOWN @ 4016 SLM. LATCHED AND PULLED LOWER ANCHOR,RDMO. *** LEFT WELL SHUT IN,TURN~º-.YYÉbbOVER TO PAD OPER. *** 10/30/2005 *** WELL SHUT IN ON ARRIVAL *** {TEST LOWER PATCH} RIG UP SLlCKLlNE SURF EQPT ,RIH W/CAT STANDING VALVE. STANDBY FOR FLUID TRANSPORT. LRS BEGAN LOADING TUBING WITH DIESEL. ***CONTINUED ON 10/31/05 WSR*** 10/31/2005 ***CONTINUED FROM 10/30/05 WSR*** (test lower patch) LRS LOADED TUBING W/DIESEL. SET 4.5 CAT STANDING VALVE IN PATCH @ 7094'SLM , PRESSURED UP TUBING & IA TO 2400 PSI BUT UNABLE TO PERFORM CMIT, ESTABLISHED LEAK RATE OF .3 BBL A MIN @ 2400 PSI. PULLED & RERAN VALVE WITH SAME RESULT. PULLED STANDING VALVE, LEFT PATCH IN WELL. ***TURNED WELL OVER TO LEFT SHUT IN*** FLUIDS PUMPED e e BBLS I 162 Diesel 162 . TOTAL ) J ~ U\,~ ~~~J- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030290 Well Name/No. PRUDHOE BAY UNIT F-10B Operator BP EXPLORATION (ALASKA) INC ::> y1t..4.- ¿ -, J wv-~"'" 3 API No. 50-029-20410-02-00 MD 11379 ~ ND 9033- Completion Date 6/13/2003 -- Completion Status 1-01L Current Status 1-01L UIC N ---- -------- - - REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes -~--~-- -- - - -~--- DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR, & EWR, MGR, CCL, CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments I Rpt D Asc Directional Survey final 9300 11379 Open 7/1/2003 i I ¡ 1 C Tf f'\- c.1\I '-- ¡ ED 12145 L~riflJ:ati.on 8462 11341 Case 9/20/2003 Compensated Neutron i Log - Memory ! ! GRlCCUCNL I <nog Neutron 2 Blu 8462 11341 Case 9/20/2003 Compensated Neutron v1 Log - Memory GRlCCUCNL I Log Casing collar locator 2 Blu 8462 11341 Case 9/20/2003 Compensated Neutron ,f- Log - Memory GRlCCUCNL ¡ ED D Las 12201 Induction/Resistivity 9340 11335 Open 10/30/2003 GR, EWR4, ROP I l~on/R.C3i5ti'Oity h j 5 V' ,{ I .JJ I Rpt {¡rv f \. íVV 9340 11335 Open 1 0/30/2003 GR, EWR4, Rap ¡ED D Las 12201 Rate of Penetration 9340 11335 Open 1 0/30/2003 GR, EWR4, Rap I Rpt RatQ of f1cnctr::ltion 9340 11335 OpAn 1 O/30/?003 GR, F\J\jR4, nor I Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030290 Well Name/No. PRUDHOE BAY UNIT F-10B Operator BP EXPLORATION (ALASKA) INC MD 11379 Completion Date 6/13/2003 Completion Status 1-01L Current Status 1-01L ND 9033 ADDITIONAL INFORMATION Well Cored? Y / ~ Chips Received? Y I r~ Daily History Received? (yyN ð/N Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: h Date: API No. 50-029-20410-02-00 UIC N --------- --- L( ff:j~r·~ ~.~- F-IOB (PTD #2030290) Classified as Problem Well ) ) Subject: F-10B (PTD #2030290) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 05 Jun 2005 14:24:43 -0800 To: "Schmoyer, AI" <SchmoyAL@BP.com>, "GPB, GCl Area Mgr" <GPBGCl TL@BP.com>, "Rossberg,R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor"· <NSUADWW ellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E..mail)" <jim_regg@admin.state.ak.us>, "AOGCC Winton Aubert (E:"mail)" <winton_auberl@admin.state.ak.us>, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, GCIWellpad Lead" <GPBGCIWeHpadLead@BP.com> ' CC: "NSU,AIJWWell Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Reeves, Donald P" <R~evesDf@BP.com> All, Well F-10B (PTD #2030290) has sustained casing pressure on the IA and is classified as a Problem well. The TIO's on 05/31/05 were 2330/2330/780. A TIFL failed post patch replacement. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Run DGL V 3. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «F-10B.pdf» 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.eom Content-Description: F-IOB.pdf F-IOB.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/20/2005 3 :40 PM SAFETY NOTES: :LLHEAO == McEVOY :TUÄTOR; .... ···ëihs· '.) ::"ELE:V :::: 66.33' ~""ELEV" ;....... ....... ""0 ..,,·......·'3~i~6·8·'· )P :::: 9360' ·~v~·~~1~,~v~,~~~"~~~.,5.~w~·2Q:: tum MD:::: 9812' tünïïvÖ; 8SÖOiSS' F-108 ') 2015' J-{ I-{ .---Ÿ/tI/ r I. 2616' 7" OTIS SSSV LANDING NIP, ID:::: 5.962" . 9-5/8" DV A<r~ I ~ z r-J ;: 3983' - 4008' 1- WFD 7" ARROWPAC PATCH W/ GL STRADDLE, ID == 2.867" GA S LIFT MA NORELS ST MD TVD DEV TYÆ VLV LATCH PORT 1 3996 3982 19 CA SO BK? 20 113-3/8" CSG, 72#, L-80, 10 == 12.347" 1-1 2678' J. ~ ~ Z I Minimum ID = 2.37" @ 10231' 3..3/16" X 2..7/8" XO DA1 02/12, c· ~ 7998' - 8018'I-IWFD 7" ARROWPAC PA TCH,-ID:::: 3.951 )- -r 8676' I-{ . TOPPBR I ~ I 8701 ' l-i 9-5/8" BAKER PKR, ID:::: 4.000" I I I 8743' 1-1 4-1/2" OTIS ~ NIP, ID:::: 3.813" 1 . i 8757' 1-1 3.75" BKR DEPLOYMENT SLY, 10:::: 3.0" . { 8774' 1- 4-1/2" XN NIP, MILLED OUT TO 3.80" ID ( (BEHIND CT LNR) I 8776' 1-1 3-1/2" HOWCO X NIP, ID:::: 2.813" I I 8777' 1-1 3-1/2" x 3-3/16" XO, ID:::: 2.880" I " 8805' 1- 4-1/2" SOS TBG TAIL ~ ... (BEHIND CT LNR) 17" TBG, 26#, L-BO, .0378 bpf, ID:::: 6,228" 1-1 8676' I TOP OF 7" LNR 1-1 8744' 'II p ~ I /2" LNR, 9,3#, L-BO, .0087 bpf, 10::::' 2.992"1-1 14-1/2" TBG, 12.75#, L-80 1-1 8777' 1 8805' ~ 9250' 1 I ,4 9-5/8" CSG, 47#, L-80, ID:::: 8.681" )-1 17" LNR, 29#, L-80, .0372 bpf, ID == 6.184" 1-1 10140' r- MILLOUT WINDOW 9360' _ 9368' TOP OF WHIPSTOCK 1-1 9355' f RA TAG 1-1 9365' 7/8" LNR, 6.16#, L-80, .0058 bpf, ID == 2.37" 1-1 11055' 10231' 1-( 3-3/16" x 2-7/8" XO, 10:::: 2.377" ÆRFORA TION SUMMARY REF LOG: MCNL / CCL / GR ON 06/13/03 TIE-IN LOG: GEOLOGY POC LOG ANGLEATTOPÆRF: 91 @ 10590' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 10590 - 10710 0 06/13/03 2" 4 10760 - 11150 0 06/13/03 2" 4 11200 - 11320 0 06/13/03 I 11344' 1-1 PBT[ 13-3/16" LNR, 6.23#. L-80, .0076 bpf, ID:::: 2.805" 1-1 10231' I 12-7/8" LNR, 6.16#, L-80, .0055 bpf, ID == 2.380" 1-1 11379' DATE 12/26/79 06/06/00 06/14/03 )8/24/03 )8/30/03 )3/17/04 REV BY COMMENTS ORIGINAL COM PLETION CTD HORlZ. SDTRCK (F-1 OA) CTD SIDETRACK (F-10B) SET W'EA THERFORD PA TCHES GLV C/O GL V DATE CHA NGE DA TE REV BY COMMENTS 04/30/04 DAV/KAK GLV C/O 03/02/05 NBF/TLH GL V C/O (02/12/05) PRUDHOE BA Y UNIT WELL: F-10B PERMIT No: 2030290 API No: 50-029-20410-02 SEC 2, T11 N, R13E, 2871' FWL & 2962' FNS JLM/KK BJMlKK DTRlKK JLJITLP BP Exploration (Alas ka) ') STATE OF ALASKA "\ ALASKA OIL AND GAS CONSERVATION COM....SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator SuspendD Repair WellŒJ Pull Tubing D Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Name: BP Exploration (Alaska), Inc. Development I]] 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Perforate D WaiverD Stimulate D Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0290 ExploratoryD OtherD 6. API Number 50-029-20410-02-00 Stratigraphic 0 Service D 9. Well Name and Number: F-10B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 66.33 8. Property Designation: ADL-028280 11. Present Well Condition Summary: Total Depth measured 11379 feet true vertical 9033.2 feet Effective Depth measured 11344 feet true vertical 9032.2 feet Length 80 25 100 616 22 1452 1148 9219 2646 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Plugs (measured) Junk (measured) Size 20" 91.5# H~40 7" 26# L-80 4-1/2" 12.6# L-80 7" 29# L-80 3-1/2" 9.3# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD 33 113 8676 - 8701 8705 ~ 8805 8744 - 9360 8757 - 8779 8779 - 10231 10231 - 11379 31 9250 32 2678 Oil-Bbl 2936 2422 None None TVD Burst Collapse 33.0 113.0 1490 470 7904.3 7926.4 7240 5410 7929.9 8018.7 8430 7500 7964.5 8520.3 8160 7020 7976.1 7995.6 10160 10530 7995.6 9032.4 9032.4 9033.2 13450 13890 31.0 8419.7 6870 4760 32.0 2677.8 4930 2670 @ @ @ @ @ @ 8676 4008 8018 3986 4004 7898 8014 8701 2616 Casing Conductor Liner Liner Liner Liner Liner Liner Production Surface Perforation depth: Measured depth: 10590 -10710,10760 -11150,11200 -11320 True vertical depth: 9030.96 - 9033.87,9034.63 - 9033.35,9033.67 n 9031.71 Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 29 5-1/2" 15.5# L-80 @ 3986 5-112" 15.5# L-80 @ 7998 Packers & SSSV (type & measured depth): 5-1/2" Weatherford ArrowPac Packer 5-1/2" Weatherford ArrowPac Packer 5-1/2" Weatherford ArrowPac Packer 5-1/2" Weatherford ArrowPac Packer 7" Baker ZXP Packer 9-5/8" DV Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure 5.9 95 2000 15.8 139 900 15. Well Class after proposed work: ExploratoryD RECEIVED JAN 2 0 2004 Alaska Oil & G as COr· " , 'v', am . J1n'h .... mlg"Îon '" urage Tubing Pressure 1173 1230 Development ŒJ Service D 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations, ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )k, C~ Signature Form 10-404 Revised 12/2003 OQlhlt\f)! Phone 564-4657 Production Technical Assistant Date 1/15/04 ) (.\('\ h ,i. " I ~ I Title ')'··"U··'·\Ji{;' I....~I:> . ~_,,_, l~\.'L__ ~ ~ ';I: ~Yß""~I ~) ) ') F-10B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/20/03 T/I/O = 1900/2000/880. Double Truck Well Kill. (Pre POGLM Set). Pump 300 bbls water down IA to kill well. Freeze protect IA w/ 72 bbls crude. Pump 584 bbls water down tbg to kill well. Freeze protect tbg w/ 97 bbls crude. FWP=80/150/640. 08/21/03 T/I/O= VAC/30/580. Bleed OA (Secure Well) TBG pressure decreased 80+ psi from previous day. lAP decreased 120 psi from previous day. OAP decreased 60 psi from previous day. OA FL Near Surface. Bled OAP down from 580 psi to 10 psi in 3 hrs. OA fluid to surface during bleed. Monitored for 30 minutes. OAP rose from 10 psi to 90 psi. Final WHP's = VAC/30/90. 08/23/03 SET FIRST OF TWO WFD 7in ARROW PAC TUBING PATCHES TO ISOLATE TUBING PUNCHER HOLES. PATCH SET FROM 7998 - 8018' REFERENCED TO TUBING PUNCH RECORD. MIN ID := 3.958in. TUBING PUNCHER HOLES FROM 8007-8008'. 08/24/03 SET WFD 7in ARROW PAC PATCH W/ WFD GAS LIFT STRADDLE FROM 3986-4008'. PATCH SET ACROSS TUBING PUNCHER HOLES FROM 3997 - 3998'. GLV = 1in OGLV WFD W/ BK LATCH W/20/64TH PORT. MIN ID = 2.875in. DEPTH REFERENCED TO TUBING PUNCHER RECORD DATED 9/1/00. 08/24/03 Change out GLV Station 1 to test MIT-T. 08/27/03 T/I/0=1 080/1 000/280. TIFL FAILED (Post patch) Temp 100. SI Well TBG & IA stacked out to 1950 psi. IA FL @ 1820'. Bled IA from 1950 psi to 1640 psi in 1.5 hrs. IA FL rose to surface. IA has a gas jumper line from F-30 it is SI and not leaking by. Monitored lAP for 30 mins, lAP increased back to 1950 psi. Final WHP's 1950/1950/280. Well back on-line. 08/29/03 T/I/0=2000/2000/340. (for Wire Line) IA FL @ 3988'. 08/29/03 T/I/O 2080/2040/300. Assist slickline. Pressure up IA to test DGV to 3000 psi Pressured up IA 1 st test lost 75 psi in 15 mins and 65 2nd 15 mins for a total of 140 psi in 30 minsFail. Repressured IA 2nd test lost 50 psi in 15 mins and 50 psi 2nd 15 mins for a total of 100 psi in 30 mins, Fail. repressure IA. 3rd test lost 25 psi in 15 minutes and 65 psi 2nd 15 mins for a total of 90 psi in 30 mins, Fail. repressure lA, 4th test lost 50 psi in 15 mins and 75 psi 2nd 15 mins for a total of 125 psi in 30 mins, Fail. 08/30/03 Set Dummy GLV in Station 1. 08/30/03 Assist slickline. MIT IA to 3000 psi. TEST INCONCLUSIVE (Test DGV) Pressured up IA to 3000 psi. 1 st test lost 190 psi. in 15 mins Fail Re-pressured IA. 2nd test lost 150 psi. in 15 mins and 75 2nd 15 mins for a total of 225 in 30 mins, Passed. Bleed IA to 2050 psi. re- pressure IA to 3000 psi to see if IA will pass w/ better results. 3rd test lost 100 psi in 15 mins and 75 in 2nd 15 mins for a total of 175 in 30 mins, Fail. Repressure IA 4th test lost 100 psi in 15 mins and 75 psi in 2nd 15 mins for a total of 175 psi in 30 mins, Fail. Bleed lAP. Final WHp1s 2040/900/300. FLUIDS PUMPED BBLS 884 Water 340 Crude 20 Methanal 1244 TOTAL Page 1 lREE = 6" CW WELLHEAD = McEVOY AClUA TOR = 011S KB. B.EV = 66.33' 'BF~"ej3T;-""""-'-"-'-'"'''37~68'' 'KOP-~"'-""--~"'-""""^'-""-9'3"'6Õ' "MV<Angle =-94@ 11300";" "~turri"Mb';" -"""""""'"""'"9812: 'bätum'iVb~" . . ..... ãäõo'SS 113-318" CSG, 72#, L-80, ID = 12.347" 1-1 Minimum ID = 2.37" @ 10231' 3-3/16" X 2-7/8" XO 17" TBG, 26#, L-80, .0378 bpf, ID = 6.228" 1-1 I TOP OF 7" LNR l-i 13-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" 1-1 14-112"18G, 12.75#, L-80 1-1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 I 7"LNR, 29#,L-80, .0372 bpf,ID=6.184" 1-1 10140' TOPOFWHlPSTOO< 1-1 9355' I RA TAG 1-1 9365' 12-7/8"LNR, 6.16#, L-80,.0058bpf, ID= 2.37" H PERFORATION SUrvTv1ARY REF LOG: MO\JL / CCL / GR ON 06/13/03 TIS-IN LOG: GEOLOGY PDC LOG ANGLEATTOPÆRF: 91 @ 10590' I\bte: Refer to A-oduction DB for historical perf data SIZE SPF INlERVAL OpnlSqz DATE 2" 4 10590 - 10710 0 06/13/03 2" 4 10760 - 11150 0 06/13/03 2" 4 11200-11320 0 06/13/03 DATE 12/26/79 06/06/00 06/14/03 08/24/03 08/30/03 REV BY COMWENTS ORIGINAL COMPLETION CTDHORIZ. SDTRCK(F-10A) JL M/KK CTD SIŒTRACK (F-10B) BJMKK SET WEA Tl-ERFORD PA Ta;ES DTRlKK GL V C/O ) 2678' 8676' 8744' 8777' 8805' 9250' I 2015' H 7" 011S SSSV LA NDING NIP, D = 5.962" ~ 2616' 1-1 9-5/8" [N A<R 1 ~ ~ 3986' . 4008' I- WFD 7" ARROWPA CPA Ta; W/ GL SlRADDLE, D = 2.867" GA S LIFT I'vtð. N ORB. S ST rvo TVD I DEV TYPE VLV LATa; PORT DAlE 1 3996 3982 19 WFD DMY INT 0 08/30/03 ~ 7998' ·8018' HWFD T' ARROWPACPATCH, ID= 3.958" F-10B SAFETY NOTES: ') 1-1 TOPPBR I 1-1 1-1 1-1 9-5/8" BAKER A<R, ID = 4.000" I 4-1/2" OTIS X NIP, D = 3.813"1 3.75" BKR DEPLOYMENT SLY, ID = 3.0" 1-4-112" XN NIP, MILLEDOUfTO 3.80"ID (BEHIND CT LNR) 1-1 3-1/2" HOWCOX NIP, D =2.813" I 1-1 3-1/2" X 3-3/16" XO, ID = 2.880" I 1-4-112" SOS TBG TAIL (BEHIND CT LNR) MLLOUTWINDOW 9360' - 9368' 10231' 1-1 3-3/16" X 2-7/8" XO, ID = 2.377" I I 11344' H PBTD 1 13-3116" LNR, 6.23#, L-80, .0076 bpf, ID = 2.805" H 10231' I . 8 ~ g Z ~ :8: & & ) ~ I 8676' 8701' . 8743' llilli. .~~ I ~ r , : 8757' 8774' 8776' 877T 8805' / , 1---41 .. 12-7/8" LNR, 6.16#, L-80, .0055 bpf, ID=2.380" H 11379' DATE REV BY 00 rvTv1ENTS ffiUŒlOE SA Y UNIT WB.L: F-10B ÆRfII1IT No: 2030290 API No: 50-029-20410-02 SEe 2, T11 N, R13E, 2871' FWL & 2962' FNS BP Exploration (Alaska) ) I ) (90,3 '-"08'1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th. Avenue, Suite 100 Anchorage, Alaska September 26, 2003 RE: MWD Formation Evaluation Logs F-10B, AK-MW-2488905 1 LDWG formatted Disc with verification listing. ) tJ 80 ,. API#: 50-029-20410-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed:~<~/~~ OCT C' -- - \..' .:'··'~·:'->.:I.~;.":;";"',. i_,,~: \.~:. 09/16/03 Schlumberger NO. 2959 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description D.S. 15·21A I~ l{ -~ý 23318 MCNL D-03A ro-I,-~ / 23404 MCNL W·34A :"> -n~~ 23347 MCNL F-10B ~ -{"ì 23401 MCNL F-45A ~--() 23308 MCNL F-268 n - . () D.S.7·30A ("):;¡,m:. 23399 MCNL 23420 MCNL W-16A 'Ø'~f)C) 23426 MCNL P1-18A (j T(r; 23276 RST Color Date Blueline Prints CD - 05/15/03 1 1 j5i1~f 06/26/03 1 1 OS/22/03 1 1 If&J J~ ~ 06/12/03 1 1 05/03/03 1 1 ~1~ 06/23/03 1 1 08/08/03 1 1 07/19/03 1 1 r~/) J 04/04/03 1 1 - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 =-="ã ?'" .i'"'\ ~ I\/J...... D krvC.ï .... !:. ~ --...~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Date Delivered: SED 2 f'¡ f)¡!{",7.J _I '~ L"n) Received b~, iý\""-:ü < 0 ~ .i:\ 0'-'\1\ ,..!...,"'~,... '~1:" :1, {~~:; (:r,ns. C-ommis.'3ioo M!C!.;:;r,~ "w';I \,¡;, v'__ --'~ AnchOiage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 1. Location of well at surface 2318' SNL, 2871' WEL, SEC. 02, T11 N, R13E, UM At top of productive interval 3649' SNL, 281' WEL, SEC. 02, T11 N, R13E, UM X = 654576, Y = 5973204 10. Well Number At total depth 2908' SNL, 1391' WEL, SEC. 02, T11 N, R13E, UM X = 653451, Y = 5973922 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 66.33' ADL 028280 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/7/2003 6/11/2003 6/13/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11379 9033 FT 11344 9032 FT a Yes 0 No 22. Type Electric or Other Logs Run SGRC Combined GR & EWR, MGR, CCL, CNL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 2011 X 30" Insulated Conductor Surface 110' 36" 13-3/811 72# L-80 Surface 2678' 17-1/2" 9-5/8" 47# L-80 Surface 9250' 12-1/4" 7" 29# L-80 8744' 9360' 8-1/2" 9.3#/6.2#/6.16# L-80 8757' 11379' 4-1/S" x 3-3/4" Classification of Service Well 7. Permit Number 203-029 8. API Number 50- 029-2041 0-02 9. Unit or Lease Name X = 651958, Y = 5974482 Prudhoe Bay Unit F-10B 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2015' MD 1900' (Approx.) CEMENTING RECORD 7.5 cu yds Concrete 3720 cu ft Arcticset II 1262 cu ft Class 'G', 130 cu ft Arcticset 278 cu ft Class 'G' 140 cu ft Class 'G' AMOUNT PULLED * 3-1/2" x 3-3116" x 2-7/S" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD MD TVD 10590' - 10710' 9031' - 9034' 10760' - 11150' 9035' - 9033' 11200' - 11320' 9034' - 9032' SIZE 711,26#, L-80 TUBING RECORD DEPTH SET (MD) 88051 PACKER SET (MD) 87011 25. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1500' Freeze Protected with MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 27, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL 7/1/2003 4 TEST PERIOD 2,185 4,398 74 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL Press. 1,07C 24-HoUR RATE CHOKE SIZE 53° GAS-OIL RATIO 2,013 OIL GRAVITY-API (CORR) 25.8 28. CORE DATA Brief description of lithology, porosity, fractures. apparent dips and presence of oil, gas or water. Submit core chips. r-:~,~ ~= No core samples were takè'n~;6\,'~::Ñ_:~: f'" """ E ";',:"":. , " ~ C}Él43- ~,' .~. IIl:P 'FlI:" · ! 'IJ l4..1 I -~.)~ : #¿.._..". ~l_.:~:~-_...··" ~"I-"- .' " JUL } 0 I ] Ah~3k2 ~} Form 10-407 Rev. 07-01-80 n R , G , ~, A , ( ·I~ \J Submit In Duplicate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. Shublik 9380' 8538' Sadlerochit 9450' 8599' Top CGL 9613' 8732' Base CGL 9732' 8816' 25N 9814' 8868' 21P 10017' 8991' JtJL 1. 0 2003 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin: is true and correct to the best of my knowledge Signed TerrieHubble -'1QM.uL, ~ Title Technical Assistant Date 0'7"09·03 F-10B 203-029 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mark Johnson, 564-5666 Permit No. / 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL ) ) BPAMOCO Oper~tionsSurnmaryRèp()rt Page 10f9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From -To Hours Task Code NPT Phase Description of Operations 6/3/2003 11 :00 - 12:00 1.00 MOB P PRE Rig released from 02-05A @ 11 :OOHrs on 6/3/2003. Prep to move rig off well. 12:00 - 13:00 1.00 MOB P PRE PJSM. Pull rig off well & clean up location. Conduct post operations pad inspection. 13:00 -16:00 3.00 MOB P PRE PJSM. LID windwalls. Scope down & LID derrick. 16:00 - 18:00 2.00 MOB P PRE Held safety standown to investigate recent recordable incident. 18:00 - 19:00 1.00 MOB P PRE Crew change. Held pre-move safety meeting with crew, security, tool services & CPS. 19:00 - 00:00 5.00 MOB P PRE Moving rig from 02-05 to F-pad. 6/4/2003 00:00 - 05:00 5.00 MOB P PRE Move rig from DS#02 to F-pad & set down adjacent to F-1 O. 05:00 - 06:00 1.00 MOB P PRE Conduct pre operations pad inspection with DSO. Meanwhile prep to raise derrick & windwalls. 06:00 - 06:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation to raise derrick and wind walls. 06:15 - 10:00 3.75 MOB P PRE Raise derrick and wind walls. Pick up injecter head. 10:00 - 11 :00 1.00 MOB P PRE Back rig over well. Well is dead with CIBP set in liner. ACCEPT RIG ON F-1 OB AT 11 :00 HRS, 06/04/2003. 11 :00 - 13:00 2.00 BOPSURP PRE N/U BOPE and M/U hardline. 13:00 - 14:00 1.00 RIGU P PRE R/U tanks, berms, spot trailers, Stab CT into injecter head. 14:00 - 18:30 4.50 BOPSUR P PRE Pressure / function test BOPE. AOGCC witness waived by Jeff Jones. Sent test report to AOGCC. Meanwhile R/U tigger tank/hardline & PIT - OK. 18:30 - 19:00 0.50 PULL P DECaMP Held pre-operations safety meeting. Reviewed well plan & potential hazards. Carried out HA/HM for injector inspection, packoff C/O & fishing BHA M/U procedures. 19:00 - 21 :30 2.50 PULL P DECaMP Open up well & bleed off 300psi WHP. Inspect/grease injector chains & C/O 4 bearing pins. C/O packoff. 21 :30 - 22:00 0.50 PULL P DECaMP Cut CT. Install Baker CTC & pull test to 35k - OK. 22:00 - 23:00 1.00 PULL P DECaMP Circulate & fill coil. PIT CTC to 3500 psi. prr inner reel valve to 3500 psi. 23:00 - 23:30 0.50 PULL P DECaMP M/U liner retrieval BHA # 1 with Baker 3" GS spear, MHA, & 1 jt of PH6 tbg. Stab injector on well. 23:30 - 00:00 0.50 PULL P DECaMP RIH with BHA #1 taking FP & crude contaminant fluid to tigger tank. 6/5/2003 00:00 - 01 :30 1.50 PULL P DECaMP RIH BHA #1 to 8500'. Up wt check = 39k, Down Wt = 25k. Continue RIH BHA#1 to TOF tagged @ 8741'. 01 :30 - 01 :40 0.17 PULL P DECaMP P/U & confirm liner engagement with 42.5k up wt. Retag @ same depth. P/U with liner @ 42k. 01:40 - 03:15 1.58 PULL P DECaMP POOH with liner fish pumping across the wellhead. 03:15 - 05:45 2.50 PULL P DECaMP OOH. PJSM. SIB injector. UD BHA #1 & recovered 100% of cut liner assembly consisting of BKR deploy sub, XIOs & 22.5 jts of 2-7/8" STL tbg. 05:45 - 06:15 0.50 CLEAN P DECaMP Crew change & prep for P/U under-reamer & motor BHA. 06:15 - 06:30 0.25 CLEAN P DECaMP SAFETY MEETING. Review procedure, hazards and mitigation to M/U 6.0" Underreamer BHA, with Reeves underreamer and Weatherford motor. 06:30 - 07: 1 0 0.67 CLEAN P DECaMP M/U Underreamer BHA with 6.00" Blades, 4 blades.. Total length = 51.84 ft. 07:10 - 09:10 2.00 CLEAN P DECOMP RIH with UR BHA. Up wt at 8800' = 40K, RIH. Tag top of 2-7/8" liner at 9416', correct CTD to 9411' [-5']. 09:10 -10:00 0.83 CLEAN P DECOMP Underream up from 9405 to 8810', 2.8 bpm, 1700 psi, 12 fpm, 42K upwt. No extra motor work sean on up pass. 1 PPB Biozan water for milling fluid. Oil/ gas in returns. Divert to tiger Printed: 6/16/2003 2:04:30 PM ') ) BP AMOCO Operations Summary Réport Page 2 Of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/5/2003 09:10 - 10:00 0.83 CLEAN P DECaMP tank. 10:00 - 10:30 0.50 CLEAN P DECaMP Underream from 8810' to 9400'. 20 fpm, 2.8 bpm, 1820 psi, 23K down wt. Oil and gas in returns. 10:30 - 12:00 1.50 CLEAN P DECaMP Underream from 9400' - 9300' and 9300 - 9400'. 5 fpm, 2.8 bpm, 1820 psi, 23K down wt. Oil/ Gas in returns. No motor work sean. 12:00 - 13:00 1.00 CLEAN P DECaMP Underream from 9400' - 9300' and 9300 - 9400'. 5 fpm, 2.8 bpm, 1820 psi, 23K down wt. Returns clean enough to return to rig mud pits. No motor work sean 13:00 - 16:00 3.00 CLEAN P DECaMP Circ. 20 bbl high vis sweep to clean hole. Under ream 9400 - 9300' while circ. sweep around. Chase sweep with 1 PPB Biozan water. POH. 16:00 - 16:15 0.25 CLEAN P DECaMP SAFETY MEETING. Review procedure, hazards and mitigation to LlO Underreamer BHA. 16:15 - 16:30 0.25 CLEAN P DECaMP LlO BHA. Recovered all 4 Underreamer blades. Blades had some wear and 2 chipped cutters. 16:30 - 17:15 0.75 CLEAN P DECaMP M/U Slickline BHA with 20 ft long X 3.69" aD drift to drift well for BKR Whipstock. 17:15 -18:00 0.75 CLEAN P DECaMP RIH with 3.69" drift on slickline. Tag PBTD at 9412' SL depth. 18:00 - 18:45 0.75 CLEAN P DECaMP POH & LID Drift. Prep to run PDS Memory Caliper Log. 18:45 -19:00 0.25 EVAL P DECaMP Held PJSM with S/L & PDS logging crews on caliper job. 19:00 - 19:15 0.25 EVAL P DECaMP M/U PDS caliper tools on 0.125" SIlo 19:15 - 20:35 1.33 EVAL P DECaMP RIH with PDS memory caliper logging tools to 9400' SLM. 20:35 - 20:50 0.25 EVAL P DECaMP Log up @ 55fpm from 9400' to 8600' SLM. 20:50 - 21 :30 0.67 EVAL P DECaMP POOH with PDS memory caliper logging tools. 21 :30 - 22:30 1.00 EVAL P DECaMP LID PDS caliper tools. Download data - caliper log shows 7" liner to be in good condition. R/D slickline unit. 22:30 - 22:45 0.25 WHIP P DECaMP Held PJSM with Baker & SWS logging crews on whipstock setting job. 22:45 - 00:00 1.25 WHIP P DECaMP P/U Baker 4-1/2" x 7" "new gen" whipstock & set on catwalk. Insert 2 RA pip tags in whipstock - distance from TOWS to RA tag = 10'. R/U SWS E-line unit. 6/6/2003 00:00 - 01 :30 1.50 WHIP P DECaMP Calibrate E-line P~S tool to HS & arm. Observe loose rod in W/S setting tool. 01 :30 - 02:30 1.00 WHIP N SFAL DECaMP Fetch replacement setting tool from Baker shop. SWS back up tool across Kuparuk river. 02:30 - 03:15 0.75 WHIP P DECaMP Align/orient setting tool to 15degs LOHS & M/U to whipstock. CCL to TOWS = 12'. 03:15 - 04:20 1.08 WHIP P DECaMP RIH with whipstock & setting tool to 9380' ELM. 04:20 - 04:30 0.17 WHIP P DECaMP P/U wt @ 9380' = 3.8k. Log up hole to 9200' ELM. Tie-into SWS Sonic log of 12/22/79 & CBL log of 12/25/79 (all on depth with missing 11/13/87 CNL log copy on page-12 of well plan). 04:30 - 05:20 0.83 WHIP N DPRB DECaMP Check W/S tray orientation - 15-30degs ROHS. RBIH to 9384' & PUH to 8900' 5x in attempt to flip orientation to LOHS - no luck. RBIH to 9400' & set down on cut 2-7/8" Inr. Yo-yo a couple of times to flip to LOHS - still no luck. Decide to POOH to check P~S tool & adjust setting tool orientation. 05:20 - 06:15 0.92 WHIP N DPRB DECaMP POOH with whipstock & setting tool. 06:15 - 07:00 0.75 WHIP N DPRB DECaMP Check P~S tool - OK. Re-align/orient setting tool to 35degs LOHS. No wt bars on site - only good one across the Kup river. SWS shop prepping one wt bar in case we need it. 07:00 - 09:00 2.00 WHIP N DPRB DECaMP RIH with BKR whipstock. No problems getting to PBTD. Printed: 6/16/2003 2:04:30 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/6/2003 13:30 - 13:45 13:45 - 14:15 14:15 - 16:15 16:15 - 17:30 17:30 - 18:30 18:30 - 19:00 19:00 - 20:30 20:30 - 21 :20 21 :20 - 21 :45 21 :45 - 00:00 6/7/2003 00:00 - 00:30 00:30 - 00:50 00:50 - 01:45 01 :45 - 03:30 03:30 - 04:15 04:15 - 04:30 04:30 - 06:00 06:00 - 06: 15 06: 15 - 06:45 06:45 - 08:50 08:50 - 09:00 09:00 - 10:30 0) ) BPAMOGO Operat:ions SUrnrnaryReport Page 3 of9 0.25 STWHIP P WEXIT F-10 F-10 REENTER+COMPLETE Start: 5/28/2003 NORDIC CALISTA Rig Release: 6/13/2003 NORDIC 1 Rig Number: From-To Hours Task Code NPT Phase 07:00 - 09:00 2.00 WHIP N DPRB DECaMP 09:00 - 10:00 1.00 WHIP N DPRB DECaMP 10:00 - 11 :00 1.00 WHIP N DPRB DECaMP 11 :00 - 13:30 2.50 WHIP P DECaMP 0.50 STWHIP P WEXIT 2.00 STWHIP P 1.25 STWHIP P WEXIT WEXIT 1.00 STWHIP P WEXIT 0.50 STWHIP P WEXIT 1.50 STWHIP P WEXIT 0.83 STWHIP P WEXIT 0.42 STWHIP P WEXIT 2.25 STWHIP P WEXIT 0.50 STWHIP P WEXIT 0.33 STWHIP P WEXIT 0.92 STWHIP P WEXIT 1.75 STWHIP P 0.75 STWHIP P WEXIT WEXIT 0.25 DRILL PROD1 P 1.50 DRILL P PROD1 0.25 DRILL 0.50 DRILL 2.08 DRILL PROD1 PROD1 PROD1 P P P 0.17 DRILL PROD1 P 1.50 DRILL P PROD1 Spud Date: 6/2/2000 End: 6/13/2003 Descriþtion of Operations Position whipstock at 9355', 2L TF. Unable to set whipstock. POH to check setting tool. Repair SWS setting tools. RIH and set BKR whipstock top at 9355 ft. TF = 12L. POH. Rig down SWS. SAFETY MEETING. Reviewed procedure, hazards and mitigation for M/U milling BHA. M/U 3.80" window milling BHA. 3.80" diamond mill, 3.80" string reamer, 2-7/8" BKR motor. RIH with window milling BHA. Top of whipstock at 9355', Pinch point in 7" liner is at 9360'. Start milling at 9360', flag CT at 9360'. 2.7 bpm, 1200 - 1400 psi, Full returns. 2 stalls to start milling, Milled to 9361'. Milling 3.80" window with 1 # Biozan. 2.7 / 2.7 bpm, 1200- 1450 psi, 1800 wob, Milled to 9362.1 ft. Mill to 9363' with 2.7/2.7bpm, 1250/1450psi, 2k WOB & 2fph ave Rap. P/U clean @ 38k & ease back into milling. Mill to 9365' with 2.7/2.7bpm, 1250/1450psi, <1k WOB & 2.5fph ave Rap. Pump down 15bbls of 2ppb bio hi-vis sweep. P/U clean @ 38k & ease back into milling. Mill to 9367' with 2.7/2.7bpm, 1250/1450psi, <1k WOB & 2.5fph ave Rap. Pump down 15bbls of 2ppb bio hi-vis sweep. P/U clean @ 38k & ease back into milling. Mill to 9368' with 2.7/2.7bpm, 1250/1450psi, <1k WOB & 2.5fph ave Rap. Should be @ BOW now. Window is from 9360' to 9368'. Control mill formation to 9372' with 2.7/2. 7bpm, 1250/1300psi, <1 k WOB & 2fph ave Rap. Pump down 15bbls of 2ppb bio hi-vis sweep. P/U clean @ 38k & ease back into milling. Control mill formation to 9373' with 2.7/2.7bpm, 1250/1300psi, <1 k WOB & 2fph ave Rap. Mill formation to 9378' with 2.7/2.7bpm, 1250/1550psi, 2k WOB & 22fph ave Rap. Start pumping flopro mud downhole. Swap wellbore to 8.9 ppg flopro mud. Meanwhile dress/drift window/rat hole & make several back ream passes with & without pumping. Window looks clean. Paint EOP flag @ 9276' & POOH window milling BHA#4. PJSM. LID BHA#4 & inspect mills. Diamond speed/string mills gauge 3.80" go / 3.79" no-go. Wear on window mill face indicates center crossed the liner wall. Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. Rehead & M/U DS CTC. Pull & pressure test. M/U build section BHA #5 with 2 deg bend motor, MWD [with "Taperlock" style probe] & new Bit #2 [HYC DS 100 3-3/4" X 4-1/4" bicenter]. Crew change & PJSM. M/U injector. RIH with bha #5, MWD build assembly. 2.0 deg motor, HYC 3.75x4.25" Bi-center bit. Tie-in to CT flag at 9339.5 ft. [-12 ft CTD]. Orient TF to 65L SAFETY STAND-DOWN. Reviewed GPB safety statistics and Printed: 6/16/2003 2:04:30 PM ') ) BP AMOCO Operations Summary Report Page Aof 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From~· To Hours Task Code NPT Phase Description of Operations 6/7/2003 09:00 - 10:30 1.50 DRILL P PROD1 specific injurys. 10:30 - 12:00 1.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3350 - 3900 psi, 70L TF, 20 fph. Clean window, went thru it at 66L. Corrected CTD to previous depth of 9378' [+6 ft CTD]. Drilled to 9,397'. 12:00 - 14:30 2.50 DRILL P PROD1 Drilling Shublik, 2.6/2.6 bpm, 3350 - 3900 psi, 70L TF, 20 fph. Drilled to 9422 ft. 14:30 - 16:00 1.50 DRILL P PROD1 Drilling Shublik 2.6/2.6 bpm, 3350 - 3900 psi, 70L TF, 20 fph. Drilled to 9450 ft. 16:00 - 16:40 0.67 DRILL P PROD1 Log Tie-in with RA tag to original well. On depth. RA marker is at 9365' for later tie-in. 16:40 - 18:00 1.33 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3200 - 3900 psi, 70L TF, 40 fph. Drilled to 9,500 ft. 18:00 - 19:00 1.00 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3900 psi, 70L TF, 40 fph. Drilled to 9,543 ft. 19:00 - 19:25 0.42 DRILL P PROD1 Drill to 9576' with 75L TF, 2.8/2.8bpm, 3200/3600psi, 75fph ave Rap. 19:25 - 20:00 0.58 DRILL P PROD1 Orient 1 click & drill to 9600' with 60L TF, 2.8/2.8bpm, 3200/3600psi, 40fph ave Rap. 20:00 - 20:20 0.33 DRILL P PROD1 Wiper trip clean to window. PUH to 9100'. 20:20 - 22: 15 1.92 DRILL P PROD1 SAFETY STAND-DOWN with night crew. Reviewed GPB HSE statistics & specific incidents. Meanwhile circulate hole @ min rate. 22: 15 - 22:40 0.42 DRILL P PROD1 Orient TF to LOHS & RBIH clean thru window to btm. 22:40 - 23:00 0.33 DRILL P PROD1 Orient TF to 65L. 23:00 - 00:00 1.00 DRILL P PROD1 Drill to 9625' with 65L TF, 2.8/2.8bpm, 3300/3600psi, 25fph ave Rap. Penetrated top zone-3 conglomerates @ 9610' (8663 ftvd). 6/8/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Drill to 9635' with 60L TF, 2.8/2.8bpm, 3300/3600psi, 1 Of ph ave Rap. Occasional motor stalling. Having problems getting valid surveys due to downhole vibration in zone-3. 01 :00 - 01 :30 0.50 DRILL P PROD1 Drill to 9640' with 60L TF, 2.8/2.8bpm, 3300/3600psi, 1 Of ph ave Rap. Frequent motor stalling. 01 :30 - 02:40 1.17 DRILL P PROD1 Drill to 9644' with 55L TF, 2.8/2.8bpm, 3300/3600psi, 5fph ave Rap. Very slow progress - decide to POOH for bit. 02:40 - 04:05 1.42 DRILL P PROD1 POOH for bit change. 04:05 - 04:30 0.42 DRILL P PROD1 OOH. PJSM. B/O & check bit - 8/4/1 with face of pilot completely rung out. 04:30 - 04:50 0.33 DRILL P PROD1 M/U drilling BHA #6 with same 2deg bend motor, MWD & re-run Bit #3 [HYC DS49, 1/1/1 ]. M/U injector. 04:50 - 06:30 1.67 DRILL P PROD1 RIH with BHA #6. SH Test tools - OK. Continue clean to RIH. Went thru window with no wt loss. RIH to TD clean. Tagged TD and corrected CTD [- 6 ft]. 06:30 - 06:50 0.33 DRILL P PROD1 Orient TF to 70L. 06:50 - 08:30 1.67 DRILL P PROD1 Drilling, 2.8 / 2.8 bpm, 3500 / 4400 psi, 70L, 5 fph, several stalls. Drilled to 9657 ft. MWD tools failed. No information or TF. 08:30 - 10:00 1.50 DRILL N DFAL PROD1 Sperry MWD tool failure. POH to C/O BHA. 10:00 -10:15 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for BHA C/O. 10:15-11:30 1.25 DRILL N DFAL PROD1 C/O MWD, motor, bit and orienter. 11 :30 - 12:45 1.25 DRILL N DFAL PROD1 RIH, Shallow test tools, orienter failed. POH. 12:45 - 13:00 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for BHA C/O. Printed: 6/16/2003 2:04:30 PM ) ') BPAMOCO Operations Summary Report Page 5 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From- To Hours Task Code NPT Phase Description of Operations 6/8/2003 13:00 - 14:00 1.00 DRILL N DFAL PROD1 cia orienter. 14:00 - 16:00 2.00 DRILL N DFAL PROD1 RIH with Hughes Tri-cone 3.75" bit and 2.29 deg motor. RIH clean to TD, hole clean. Tag TD, correct [ - 10' CTD ] CTD. 16:00 - 17:30 1.50 DRILL P PROD1 Drilling Zone 3 with roller cone bit. 2.4/2.4 bpm, 2500/ 3000 psi, 2000# WOB, 65L, 25 FPH, smooth drilling with good G totals, Drilled to 9694 FT. 17:30 - 18:45 1.25 DRILL P PROD1 Drilling Zone 3 with roller cone bit. 2.4/2.4 bpm, 2500/ 3000 psi, 2000# WOB, 60L, 20 FPH, smooth drilling with good G totals, Drilled to 9718 ft, 18:45 - 20:10 1.42 DRILL P PROD1 Attempt to orient - not getting clicks. PUH to 9550' & orient to 80L. RBIH to btm & TF flip back to 40L again. PUH & reorient to 90L. RBIH & TF flop to 11 OL. Attempt to get 1 click on btm - no luck. PUH & grab a click. 20:10 - 21 :05 0.92 DRILL P PROD1 Drill to 9730' with 85L TF, 2.6/2.6bpm, 2900/3100psi, 15fph ave Rap. Seeing some drilling break @ 9730'. Decide to POOH due to hrs on tricone bit & hi-DLS from 2.29deg motor. 21 :05 - 22:40 1.58 DRILL P PROD1 POOH drilling BHA #8. 22:40 - 23:05 0.42 DRILL P PROD1 OOH. PJSM. B/O & check bit - 3-5-1/16" out of guage. 23:05 - 23:35 0.50 DRILL P PROD1 M/U drilling BHA #8 with 1.69deg bend motor, MWD & new Bit #5 [HYC DS100 3-3/4" x 4-1/4" bicenter]. M/U injector. 23:35 - 00:00 0.42 DRILL P PROD1 RIH with BHA #8. SHT tools - OK. Continue RIH. 6/9/2003 00:00 - 01 :20 1.33 DRILL P PROD1 Continue RIH clean thru window to 9415'. 01 :20 - 01 :50 0.50 DRILL P PROD1 Log up GR & tie-into RA pip tag (-12' from CTD). 01 :50 - 02:00 0.17 DRILL P PROD1 Precautionary ream in hole & see slight motor work @ 9668'. 02:00 - 02:30 0.50 DRILL P PROD1 Ream to btm tagged @ 9730' with 85L TF, 2.7/2.7bpm, 3000/3060psi, 150fph ave Rap. 02:30 - 03:00 0.50 DRILL P PROD1 Drill to 9748' with 90L TF, 2.7/2.7bpm, 3000/3300psi, 36fph ave Rap. 03:00 - 04:00 1.00 DRILL P PROD1 Drill to 9800' with 95L TF, 2.7/2.7bpm, 3000/3400psi, 50fph ave Rap. 04:00 - 06:10 2.17 DRILL P PROD1 Drill to 9900' with 105-120L TF, 2.7/2.7bpm, 3000/3350psi, 50fph ave Rap. 06: 10 - 06:50 0.67 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 06:50 - 10:00 3.17 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3050 - 3600 psi, 85L, 45 FPH, 50 deg incl. Drilled to 9996' 10:00 - 10:30 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 10:30 - 11 :30 1.00 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3050 - 3600 psi, 5L, 45 FPH, 55 deg incl. Drilled to 10,033'. 11:30-13:10 1.67 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3050 - 3600 psi, 45R, 45 FPH, 75 deg incl. Drilled to 10,105'. 13:10 - 14:00 0.83 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3150 - 3600 psi, 45R, 45 FPH, 80 deg incl. Drilled to 10,133'. 14:00 - 15:00 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. Clean hole to TD. 15:00 - 17:30 2.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3150 - 3600 psi, 45R, 45 FPH, 90 deg incl. Drilled to 10,237' 17:30 - 18:00 0.50 DRILL P PROD1 Orient TF to 80L. 18:00 - 18:30 0.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3170 - 3600 psi, 80L, 50 FPH, 90 deg incl. Drilled to 10,250'. Landed well at 10,219 ft, at 8966'NDSS. 18:30 - 20:15 1.75 DRILL P PROD1 POOH for RES/GR and 1.0 deg. motor. 20:15 - 21:05 0.83 DRILL P PROD1 OOH. PJSM. B/O & check bit - 5/2/1. UO MWD. 21 :05 - 22:45 1.67 DRILL P PROD1 M/U lateral BHA #9 with 1.04deg bend motor, RES/GR MWD & new Bit #6 [HYC DS49]. Initialize RES tool & M/U injector. Printed: 6/16/2003 2:04:30 PM ) ) BPAMOCO Operations Summary Report Page6of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From -To Hours Task Code NPT Phase Description of Operations 6/9/2003 22:45 - 00:00 1.25 DRILL P PROD1 RIH with BHA #9. SHT tools - OK. Continue RIH to 7000'. 6/10/2003 00:00 - 00:30 0.50 DRILL P PROD1 Continue RIH clean thru window to 9430'. 00:30 - 00:55 0.42 DRILL P PROD1 Log up GR & tie-into RA pip tag (-14' from CTD). 00:55 - 01 :05 0.17 DRILL P PROD1 RIH to 9850' circ @ min rate to prevent RES tool pulsing thru hi-DLS area. 01 :05 - 02: 1 0 1.08 DRILL P PROD1 Log RES MAD pass from 9900' to btm @ 315fph. 02:10 - 02:35 0.42 DRILL P PROD1 Orient TF around to 75L. 02:35 - 03:35 1.00 DRILL P PROD1 Drill to 10310' with 90-105L TF, 2.7/2.7bpm, 3100/3450psi, 60fph ave Rap. 03:35 - 03:55 0.33 DRILL P PROD1 Drill to 10339' with 105-125L TF, 2.7/2.7bpm, 3100/3450psi, 87fph ave Rap. 03:55 - 04:05 0.17 DRILL P PROD1 Orient TF to 75L. 04:05 - 04:30 0.42 DRILL P PROD1 Drill to 10375' with 85L TF, 2.7/2.7bpm, 3100/3450psi, 85fph ave Rap. Possibly penetrated 14N shale (could have crossed a fault). 04:30 - 04:40 0.17 DRILL P PROD1 Orient TF around to 75R. 04:40 - 05:00 0.33 DRILL P PROD1 Drill to 10400' with 60R TF, 2.7/2.7bpm, 3100/3450psi, 75fph ave Rap. 05:00 - 06:00 1.00 DRILL P PROD1 Wiper trip clean to window circ @ min rate thru hi-DLS section. RBIH. 06:00 - 06: 1 0 0.17 DRILL P PROD1 Orient TF to 20R. Geo wants to build back to 8965ftvd. 06:10 - 06:45 0.58 DRILL P PROD1 Drill with HS TF, 2.7/2.7bpm, 3250/3550psi, 75fph ave Rap. Drilled to 10457'. 06:45 - 06:55 0.17 DRILL P PROD1 Orient TF to 80R. 06:55 - 08:00 1.08 DRILL P PROD1 Drilling, 3280 - 4000 psi, 2.7/2.7 bpm, 120 fph, 92 deg incl, Drilled to 10,550'. 08:00 - 09:15 1.25 DRILL P PROD1 Wiper trip to window. Clean hole. Slow pump across high dogleg at 9700'. RIH. 09:15 -11:00 1.75 DRILL P PROD1 Drilling, 3280 - 4000 psi, 2.7/2.7 bpm, 60L, 100 fph, 91 deg incl, Drilled to 10,656'. 11:00-11:15 0.25 DRILL P PROD1 Orient TF. 11: 15 - 11 :35 0.33 DRILL P PROD1 Drilling, 3280 - 4000 psi, 2.7/2.7 bpm, 60L, 100 fph, 91 deg incl, Drilled to 10,700'. 11 :35 - 13:00 1.42 DRILL P PROD1 Wiper trip to window. Clean hole. Slow pump across high dogleg at 9700'. RIH clean. 13:00 - 14:45 1.75 DRILL P PROD1 Drilling, 3350 - 4000 psi, 2.7/2.7 bpm, 45R, 100 fph, 88 deg incl, Drilled to 10,747'. 14:45 -15:10 0.42 DRILL P PROD1 Orient TF to 120L. 15:10-15:25 0.25 DRILL P PROD1 Drill to 10768' with 125L TF, 2.7/2.7bpm, 3350/3750psi, 85fph ave Rap. 15:25 - 15:30 0.08 DRILL P PROD1 Orient TF to 90L. 15:30 - 15:40 0.17 DRILL P PROD1 Drill to 10782' with 90L TF, 2.7/2.7bpm, 3350/3750psi, 85fph ave Rap. 15:40 - 16:05 0.42 DRILL P PROD1 Orient & drill to 10817' with 30-60L TF, 2.7/2.7bpm, 3350/3750psi, 85fph ave Rap. 16:05 - 16:35 0.50 DRILL P PROD1 Short 100' wiper. RBIH & orient TF to 60L. 16:35 - 16:50 0.25 DRILL P PROD1 Orient & drill to 10852' with 90L TF, 2.7/2.7bpm, 3350/3800psi, 140fph ave Rap. 16:50 - 17:50 1.00 DRILL P PROD1 Wiper trip. a/pulled & temporarily stuck (differentially) @ 10825'. RBIH & pulled free with 66k. Continue wiping clean to window circ @ min rate thru hi-DLS section. 17:50 - 18:30 0.67 DRILL P PROD1 Log up GR & tie-into RA pip tag (+13' from CTD). 18:30 - 19:05 0.58 DRILL P PROD1 RIH to 9850' circ @ min rate to prevent RES tool pulsing thru Printed: 6/16/2003 2:04:30 PM ) ) BPAMOCO Operations Summary Report Page 7bf9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From - To Hours Task Code NPT Phase Description. of Operations 6/10/2003 18:30 - 19:05 0.58 DRILL P PROD1 hi-DLS area. Start pumping down new Flo-pro mud. Tag TD @ 1 0860'. 19:05 - 19:35 0.50 DRILL P PROD1 Drill to 10895' with 115L TF, 2.6/2.6bpm, 3000/3350psi, 70fph ave Rap. Meanwhile swap well to new Flo-pro mud. 19:35 - 19:40 0.08 DRILL P PROD1 Orient TF to 70L. 19:40 - 20:40 1.00 DRILL P PROD1 Drill from 10895' 2.7/3000/80L to 11000' 20:40 - 22:00 1.33 DRILL P PROD1 Wiper to window, clean. Fin displacement to new/used 9.0 ppg mud 22:00 - 22:40 0.67 DRILL P PROD1 Tag at 10998' at 80L. Orient around. Then work on charge pump pressure 22:40 - 00:00 1.33 DRILL P PROD1 Drill from 10998' 2.5/2700/90L holding at 8965' 1VD to 11100' 6/11/2003 00:00 - 00:30 0.50 DRILL P PROD1 Continue drilling from 11100' 2.6/3050/90R holding 90 deg at 8965' 1VD. Drill to 11150' 00:30-01:15 0.75 DRILL P PROD1 Wiper to window 01: 15 - 01 :35 0.33 DRILL P PROD1 Log tie-in up from 9415'. Add 1.5' 01 :35 - 02:10 0.58 DRILL P PROD1 RBIH 02:10 - 02:30 0.33 DRILL P PROD1 Tag at 11150' at 11 OR. Orient to left 02:30 - 03:45 1.25 DRILL P PROD1 Drill from 11150' 2.7/3120/90L to 11229' and acts like a shale at 11200' 03:45 - 03:55 0.17 DRILL P PROD1 Orient to HS 03:55 - 04: 15 0.33 DRILL P PROD1 Drill from 11229-259' 2.6/3080/30L 04: 15 - 04:30 0.25 DRILL P PROD1 Orient around 04:30 - 04:40 0.17 DRILL C PROD1 Drill from 11259' to 11269', 2.7/3130/90L 04:40 - 05:00 0.33 DRILL C PROD1 Drill to 11300' with 65L TF 2.7/3130/65L 05:00 - 06:30 1.50 DRILL P PROD1 Wiper trip to window. RBIH & set down @ 10830'. 06:30 - 07:00 0.50 DRILL P PROD1 Orient TF to LHS & ream/backream tight area clean. 07:00 - 07:20 0.33 DRILL P PROD1 RBIH to btm. 07:20 - 07:45 0.42 DRILL C PROD1 Orient TF around to 90L. Flopped to 65L. Reorient to 90L. 07:45 - 08:50 1.08 DRILL C PROD1 Drill to to TD @ 11375' with 90L TF, 2.7/2.7bpm, 3080/32500psi, 70fph ave Rap. 08:50 - 10:00 1.17 DRILL P PROD1 Wiper trip clean to 9430'. 10:00 - 10:30 0.50 DRILL P PROD1 Log up GR & tie-into RA pip tag (+6' from CTD). 10:30 - 11 :15 0.75 DRILL P PROD1 RBIH clean & tag TD @ 11379'. 11:15-14:15 3.00 DRILL P PROD1 Paint EOP flags @ 8700' & 6700' and POOH for liner. 14:15 - 14:30 0.25 DRILL P PROD1 OOH. PJSM for UD drilling BHA. 14:30 - 15:50 1.33 DRILL P PROD1 Download resistivity data & UD drilling BHA#9. Bit grades 8/7/1. 15:50 - 16:30 0.67 CASE P CaMP PJSM. Install Baker CTC. Pull test to 35k - OK. Pressure test to 3500psi - OK. 16:30 - 17:30 1.00 CASE P CaMP M/U dart catcher. Load/launch wiper dart & check. Chase dart with mud & pig CT. Dart bumped on catcher @ 57.6bbls. 17:30 - 17:45 0.25 CASE P CaMP Held PJSM on M/U & RIH with liner. 17:45 - 18:15 0.50 CASE P CaMP RlU & M/U 2-7/8" liner float equipment & shoe jt. 18:15 - 18:30 0.25 CASE P CaMP Crew change & PJSM. 18:30 - 22:35 4.08 CASE P CaMP MU additional 35 jts 2-7/8" 6.16# L-80 STL, pups, LSL sub, 47 jts 3-3/16" 6.2# L-80 TC11,' X' nipple, 2 pups 3-1/2" 9.3# L80 STL. MU BOT CTLRT (2631.4' OA) Kick drill 22:35 - 23:50 1.25 CASE P CaMP RIH w/liner on CT 23:50 - 00:00 0.17 CASE P CaMP See flag at 9334.8' -1.4' 40k, 23k. RIH w/liner in OH 6/12/2003 00:00 - 00:25 0.42 CASE P CaMP RIH w/liner to TD tagged at 11386' CTD. Recip 40' 49k. TaL @ -8757' ELMD 00:25 - 01 :10 0.75 CASE P CaMP Load 5/8" steel ball. Circ to seat w/ mud. Ball seat sheared at Printed: 6/16/2003 2:04:30 PM ) .) BP AMOCO Operations Summary Report Page 8 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/12/2003 00:25-01:10 0.75 CASE P CaMP 3900 psi. PU 31 k and released 01:10 - 04:10 3.00 CASE N WAIT CaMP Circ 0.4/1160 while wo vac trucks (VECO busy, Peak drivers on rig moves) 04:10 - 07:15 3.08 CASE P CaMP Begin displacement to KCI at 2.5/2.5/2000,3.1/3.0/1760. Meanwhile batch mix 25bbls 15.8ppg cmt slurry with additives. Cmt to wt @ 06:50 hrs. Prepare 30bbls of biozan pill. 07:15 - 07:30 0.25 CEMT P CaMP PJSM with all personnel concerning cementing operations. 07:30 - 09:00 1.50 CEMT P CaMP Flush/PT lines to 4k. Pump 25bbls cmt slurry @ 2.6/2.5bpm & 2200psi. Close inner reel valve & clean lines. Load/launch CTWP with 750psi & confirm launch. Chase with bio & KCL @ 3.1/2.9bpm & 2600psi. CTWP engage LWP at 57.6bbls away. Shear plug with 2670psi. Continue displacing LWP @ 2.5/2.3bpm, 1860psi & bump @ 75.3bbls away with 1000psi. 23bbls cmt pumped around shoe. Floats held. Pressure up to 500psi & sting out of liner. CIP at 09:00 hrs 09:00 - 11 :05 2.08 CEMT P CaMP POOH pumping only to replace CT volume. 11:05-11:15 0.17 CEMT P CaMP PJSM for LID CTLRT. 11 : 15 - 11:45 0.50 CEMT P CaMP LID & LlO CTLRT & other BKR tools. 11:45-17:30 5.75 BOPSURP CaMP PJSM. Perform weekly BOPE pressure & function test. AOGCC test witness waived by John Crisp. Also test LEL & H2S alarms. 17:30 - 18:50 1.33 EVAL P CaMP Bring in logging tools thru beaver slide. R/U for P/U mill/motor, CNL tools & CHS tbg. Fill pill pit with 150k LSRV perf pill. 18:50 - 19:05 0.25 EVAL P CaMP Safety mtg re: source/CSH 19:05 - 19:40 0.58 EVAL P CaMP MU 2.31" D331 mill, 2-1/8" motor, CNL carrier, MHA 19:40 - 22:00 2.33 EVAL P CaMP MU 86 jts 1-1/4" CSH workstring 22:00 - 23:00 1.00 EVAL P CaMP RIH w/ BHA #11 23:00 - 0.00 EVAL P CaMP Log down from 8500' at 30'/min 6/13/2003 00:00 - 00:45 0.75 EVAL P CaMP Continue logging down at 30'/min w/ CNL. Tag at 11357' CTD 00:45 - 01 :40 0.92 EVAL P CaMP Log up at 60'/min to 8500' leaving fresh mud in liner 01:40 - 02:35 0.92 EVAL P COMP POOH 02:35 - 04:20 1.75 EVAL P CaMP Stand back CSH 04:20 - 04:30 0.17 EVAL P CaMP Safety mtg re: source 04:30 - 04:45 0.25 EVAL P CaMP LD CNL carrier 04:45 - 05:50 1.08 EVAL P CaMP Cement compr strength 2400 psi. RU and PT wellbore to 1735 psi w/ 3.1 bbls. IA initial was 260 psi and rose to 2000 psi. OA stable at 338 psi. Record press for 40 min while load perf guns in pipeshed and prep to run. Final pressures were tubing 1683 psi, IA 1942 psi and OA 339 psi. Bleed off press, RD lub 05:50 - 06:30 0.67 PERF P CaMP WO CNL data, crew change. RlU safety jt & prep to M/U & RIH perf guns. 06:30 - 07:00 0.50 PERF P CaMP PJSM on perforation job. Meanwhile fax CNL log to ANG Geo. From log data, PBTD = 11343' & TaL = 8754' ELMD. 07:00 - 08:30 1.50 PERF P CaMP M/U 35jts of 2" HSD 4 spf PJ guns & blanks with CBF firing system. 08:30 - 09:30 1.00 PERF P CaMP M/U 31 doubles of 1-1/4" CSH tbg. M/U injector. 09:30 -11:15 1.75 PERF P CaMP RIH with perforating BHA#12 circ perf pill @ min rate. Wt check @ 11000' = 39k. Tag PBTD 11347'. Pull to P/U wt & depth was dead correct @ 11343' (PBTD as per MCNL log). 11: 15 - 11 :20 0.08 PERF P CaMP PUH to ball drop postion @ 11312'. 11 :20 - 11 :50 0.50 PERF P CaMP Load 5/8" steel ball with a total of 14bbl perf pill pumped ahead. Blow ball into CT & circ down while positioning guns for btm shot @ 11320'. Chase ball to seat slowing to 1.2bpm @ Printed: 6/16/2003 2:04:30 PM ) ) BPAMOCO Op~"ations :Summary RepQrt Page 90f9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-10 F-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/28/2003 Rig Release: 6/13/2003 Rig Number: Spud Date: 6/2/2000 End: 6/13/2003 Date From - To Hours Task . Code NPT Phase Description of Operations 6/13/2003 11 :20 - 11 :50 0.50 PERF P CaMP 44bbls. Ball on seat after 50.6bbls away. Ramp up to 3500psi & observe guns fire with good pressure drop indication & 1 bbl fluid loss. Perforated interval = 10590' - 10710', 10760' - 11150' & 11200' - 11320'. 11:50-13:30 1.67 PERF P CaMP POOH with perf gun BHA pumping across the WHD to keep hole full. 13:30 - 13:45 0.25 PERF P CaMP PJSM on RIB 1-1/4" CSH. 13:45 - 15:45 2.00 PERF P CaMP SIB injector & RIB 31 doubles of 1-1/4" CSH tbg. 15:45 - 16:00 0.25 PERF P CaMP PJSM on LID Perf guns. 16:00 - 18:45 2.75 PERF P CaMP LID perf guns. ASF! Load out guns 18:45 - 19:05 0.33 CHEM P CaMP MU nozzle assy 19:05 - 20:45 1.67 CHEM P CaMP RIH. FP to 1500' w/ MeOH. POOH 20:45 - 21:15 0.50 RIGD P POST SI swab and master (34). Blow back CT w/ air 21:15-23:00 1.75 RIGD P POST ND BOPE. NU tree cap and PT 23:00 - 00:00 1.00 RIGD P POST RREL 2300 hrs 6/13/2003. Begin Standby for F-26 prep Report continued on F-26 (when initialized on DIMS) Printed: 6/16/2003 2:04:30 PM ) ) 25-Jun-03 AOGCC .' ~€ ~ loward Okland' Lì s/\ lAJ,Q{?tßl- 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well F-10B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 9,300.00 I MD Window / Kickoff Survey: 9,360.00' MD (if applicable) Projected Survey: 11,379.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, ~03-D~q RECEIVED JUL 0 1 2003 William T. Allen Survey Manager þJ~~~~~~n ,\I\A;'L~ (.:J.V~ AUachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA FPad F-10B Job No. AKMW0002488905, Surveyed: 11 June, 2003 Survey Report 25 June, 2003 Your Ref: API 500292041002 Surface Coordinates: 5974482.00 N, 651958.00 E (70020'14.3071" N, 148046'01.1960" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974482.00 N, 151958.00 E (Grid) Surface Coordinates relative to Structure Reference: 1932.98 N, 1037.51 E (True) Kelly Bushing: 66.33ft above Mean Sea Level Elevation relative to Project V Reference: 66.33ft Elevation relative to Structure Reference: 66.33ft 5pe!........y-SUf1 DRILLING SERVices A Halliburton Company DEF N TIVE - - Survey Ref: 5vy4057 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad· F-10B Your Ref: AP/500292041002 Job No. AKMW0002488905, Surveyed: 11 June, 2003 BPXA North Slope A/aska Measured Sub-Sea Vertical Local Coordinates Global Coordínates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9300.00 23.820 134.900 8399.02 8465.35 1550.79 S 2494.56 E 5972982.08 N 654483.47 E -2860.50 Tie On Point MWD Magnetic 9360.00 23.390 137.150 8454.01 8520.34 1568.08 S 2511.24 E 5972965.13 N 654500.50 E 1.664 -2884.51 Window Point 9394.62 27.070 124.880 8485.34 8551.67 1577.63 S 2522.39 E 5972955.81 N 654511.84 E 18.422 -2899.15 9424.37 31 .900 115.550 8511.24 8577.57 1584.90 S 2535.05 E 5972948.80 N 654524.64 E 22.360 -2913.24 '- 9454.42 32.170 107.440 8536.73 8603.06 1590.72 S 2549.85 E 5972943.27 N 654539.56 E 14.335 -2927.83 .~/ 9483.67 32.700 100.730 8561.42 8627.75 1594.53 S 2565.05 E 5972939.78 N 654554.83 E 12.431 -2941.27 9500.97 33.540 97.250 8575.91 8642.24 1596.00 S 2574.38 E 5972938.49 N 654564.19 E 12.014 -2948.91 9527.07 35.070 89.800 8597.48 8663.81 1596.89 S 2589.04 E 5972937.90 N 654578.87 E 17.112 -2959.90 9566.32 37.530 75.910 8629.17 8695.50 1593.93 S 2611.95 E 5972941.32 N 654601.72 E 21.826 -2974.01 9595.29 38.940 68.350 8651.93 8718.26 1588.42 S 2628.98 E 5972947.18 N 654618.63 E 16.859 -2982.16 9623.42 41.750 60.090 8673.39 8739.72 1580.48 S 2645.33 E 5972955.45 N 654634.82 E 21.457 -2988.10 9654.99 43.350 49.250 8696.68 8763.01 1568.15 S 2662.68 E 5972968.13 N 654651.91 E 23.744 -2991.65 9680.57 45.290 36.210 8715.01 8781.34 1555.06 S 2674.72 E 5972981.46 N 654663.69 E 36.369 -2990.91 9703.59 48.990 22.990 8730.71 8797.04 1540.42 S 2682.97 E 5972996.26 N 654671.64 E 44.995 -2986.39 9740.98 49.430 4.490 8755.26 8821.59 1513.14S 2689.63 E 5973023.67 N 654677.74 E 37.409 -2971.81 9775.40 50.930 357.970 8777.31 8843.64 1486.74 S 2690.18 E 5973050.08 N 654677.75 E 15.183 -2953.53 9806.33 51.450 346.870 8796.73 8863.06 1462.92 S 2687.00 E 5973{}73.83 N 654674.09 E 27.998 -2934.43 9837.53 51.280 340.350 8816.23 8882.56 1439.56 S 2680.13 E 5973097.05 N 654666.75 E 16.329 -2913.06 9868.78 51.010 332.250 8835.85 8902.18 1417.31 S 2670.37 E 5973119.10 N 654656.54 E 20.197 -2890.42 9901.38 48.990 322.910 8856.83 8923.16 1396.25 S 2657.03 E 5973139.88 N 654642.78 E 22.792 -2866.10 9934.48 49.600 316.740 8878.43 8944.76 1377.10 S 2640.85 E 5973158.70 N 654626.22 E 14.248 -2841.12 9975.13 54.100 312.160 8903.54 8969.87 1354.76 S 2618.02 E 5973180.57 N 654602.94 E 14.175 -2809.18 10006.55 60.700 309.870 8920.46 8986.79 1337.41 S 2598.05 E 5973197.51 N 654582.62 E 21.883 -2782.79 _J 10035.40 66.430 309.690 8933.30 8999.63 1320.89 S 2578.20 E 5973213.62 N 654562.44 E 19.869 -2757.08 10068.55 72.160 306.870 8945.02 9011.35 1301.70 S 2553.87 E 5973232.31 N 654537.72 E 19.027 -2726.30 10099.65 77.360 310.400 8953.19 9019.52 1282.97 S 2530.45 E 5973250.57 N 654513.92 E 19.985 -2696.49 10129.55 79.650 316.390 8959.16 9025.49 1262.85 S 2509.17 E 5973270.26 N 654492.25 E 21.071 -2667.22 10163.08 83.610 319.380 8964.04 9030.37 1238.24 S 2486.94 E 5973294.41 N 654469.52 E 14.741 -2634.10 10197.90 89.340 320.090 8966.18 9032.51 1211.74 S 2464.48 E 5973320.45 N 654446.53 E 16.581 -2599.48 10228.73 90.840 313.740 8966.13 9032.46 1189.23 S 2443.44 E 5973342.53 N 654425.03 E 21.163 -2568.68 25 June, 2003 - 15:01 Page 2 0'4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-10B Your Ref: API 500292041002 Job No. AKMWOO02488905, Surveyed: 11 June, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10263.00 91.540 308.810 8965.42 9031.75 1166.64 S 2417.69 E 5973364.60 N 654398.84 E 14.527 -2534.50 10302.22 90.570 306.170 8964.69 9031.02 1142.77 S 2386.58 E 5973387.82 N 654367.25 E 7.170 -2495.63 10331.59 86.700 303.350 8965.39 9031.72 1126.04 S 2362.47 E 5973404.07 N 654342.80 E 16.301 -2466.74 10363.84 86.340 295.950 8967.35 9033.68 1110.12 S 2334.51 E 5973419.41 N 654314.53 E 22.931 -2435.72 10398.27 87.400 299.290 8969.23 9035.56 1094.19 S 2304.06 E 5973434.73 N 654283.76 E 1 0.164 -2402.92 '-. 10423.42 90.040 301.230 8969.80 9036.13 1081.52 S 2282.34 E 5973446.95 N 654261.79 E 13.025 -2378.61 - 10459.27 92.250 301.760 8969.08 9035.41 1062.79 S 2251.78E 5973465.05 N 654230.85 E 6.339 -2343.76 10489.50 92.250 305.990 8967.89 9034.22 1045.96 S 2226.71 E 5973481.38 N 654205.44 E 13.982 -2314.13 10523.12 91.280 313.210 8966.86 9033.19 1024.55 S 2200.83 E 5973502.25 N 654179.14 E 21.658 -2280.69 10558.45 92.420 315.680 8965.71 9032.04 999.83 S 2175.62 E 5973526.46 N 654153.44 E 7.697 -2245.39 10592.24 91.450 321 .140 8964.57 9030.90 974.58 S 2153.22 E 5973551.25 N 654130.52 E 16.402 -2211.69 10625.69 89.780 318.850 8964.21 9030.54 948.97 S 2131.72 E 5973576.43 N 654108.51 E 8.4 73 -2178.37 10662.14 88.900 315.680 8964.63 9030.96 922.20 S 2106.99 E 5973602.69 N 654083.24 E 9.025 -2141.96 10693.31 84.850 311 .1 00 8966.33 9032.66 900.83 S 2084.38 E 5973623.60 N 654060.21 E 19.596 -2110.86 10723.24 88.460 309.870 8968.08 9034.41 881.43 S 2061.66 E 5973642.53 N 654037.10 E 12.740 -2081.08 10754.14 90.570 310.220 8968.34 9034.67 861.55 S 2038.01 E 5973661.92 N 654013.05 E 6.922 -2050.30 10787.29 88.630 305.460 8968.57 9034.90 841.22 S 2011.84 E 5973681.72 N 653986.4 7 E 15.505 -2017.42 10825.94 91.720 302.640 8968.46 9034.79 819.59 S 1979.82 E 5973702.70 N 653954.02 E 10.823 -1979.48 10853.81 91.890 301.230 8967.58 9033.91 804.85 S 1956.18 E 5973716.95 N 653930.09 E 5.093 -1952.35 10880.49 90.130 298.940 8967.11 9033.44 791.48 S 1933.10 E 5973729.85 N 653906.74 E 10.824 -1926.57 10911.14 89.960 295.590 8967.08 9033.41 777.44 S 1905.86 E 5973743.34 N 653879.22 E 1 0.944 -1897.38 10942.51 90.930 292.250 8966.84 9033.17 764.73 S 1877.19 E 5973755.47 N 653850.30 E 11.087 -1868.12 10974.06 91.100 289.780 8966.28 9032.61 753.41 S 1847.75 E 5973766.18 N 653820.63 E 7.846 -1839.30 11003.56 90.220 288.540 8965.94 9032.27 743.73 S 1819.88 E 5973775.30 N 653792.58 E 5.154 -1812.75 ~J 11040.01 89.960 292.770 8965.88 9032.21 730.88 S 1785.78 E 5973787.46 N 653758.23 E 11.627 -1779.55 11067.87 89.340 297.360 8966.05 9032.38 719.08 S 1760.55 E 5973798.74 N 653732.76 E 16.624 -1753.37 11095.71 88.810 300.000 8966.50 9032.83 705.72 S 1736.14 E 5973811.60 N 653708.08 E 9.671 -1726.65 11127.99 89.600 303.350 8966.95 9033.28 688.78 S 1708.67 E 5973827.99 N 653680.28 E 10.662 -1695.25 11159.87 90.220 307.050 8967.00 9033.33 670.40 S 1682.62 E 5973845.83 N 653653.86 E 11.768 -1663.84 11194.31 88.990 301.060 8967.24 9033.57 651.13 S 1654.11 E 5973864.53 N 653624.96 E 17.755 -1630.04 11225.01 89.070 295.950 8967.76 9034.09 636.48 S 1627.14 E 5973878.62 N 653597.70 E 16.645 -1600.62 11265.31 91 .190 292.250 8967.67 9034.00 620.03 S 1590.36 E 5973894.32 N 653560.60 E 10.581 -1562.98 11300.79 93.830 286.430 8966.11 9032.44 608.30 S 1556.93 E 5973905.38 N 653526.94 E 17.997 -1531.05 11332.56 88.370 282.200 8965.50 9031.83 600.45 S 1526.17 E 5973912.60 N 653496.03 E 21 .736 -1503.75 11379.00 88.370 282.200 8966.82 9033.15 590.64 S 1480.80 E 5973921.49 N 653450.47 E 0.000 -1464.73 Projected Survey 25 June, 2003 - 15:01 Page 3 of4 DríllQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA F Pad - F-10B Your Ref: API5D0292041002 Job No. AKMW0002488905, Surveyed: 11 June, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 315.000° (True). Magnetic Declination at Surface is 25.812°(07 -Jun-03) 0,-- Based upon Minimum Curvature type calculations, at a Measured Depth of 11379.00ft. The Bottom Hole Displacement is 1594.25ft., in the Direction of 111.745° (True). .O~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 9300.00 9360.00 11379.00 8465.35 8520.34 9033.15 1550.79 S 1568.08 S 590.64 S 2494.56 E 2511.24 E 1480.80 E Tie On Point Window Point Projected Survey Survey tool program for F-10B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) ~ 0.00 9300.00 0.00 8465.35 9300.00 11379.00 8465.35 BP High Accuracy Gyro (F-10) 9033.15 MWD Magnetic (F-10B) 25 June, 2003 - 15:01 Page 4 of 4 DrillQuest 3.03.02.005 ì @ìí!M'.ú.:rn..c ¿g) LJ Lru J Lf: Œ} !Æ~!Æ~~~!Æ FRANK H. MURKOWSK/, GOVERNOR AI/A~KA. OIL AND GAS CONSERVATION COltDlISSION 333 W. pH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Unit F-I0B BP Exploration (Alaska), Inc. Permit No: 203-029 Surface Location: 2318' SNL, 2871' WEL, Sec. 02, TIIN, R13E, UM Bottomhole Location: 3010' SNL, 1227',WEL, Sec.. 02, TIIN, RI3E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redriU the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). S incerel y, ~?~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 7e!- day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ii"GA- Ll Ú' I G) 1 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 651958, Y = 5974482 2318' SNL, 2871' WEL, SEC. 02, T11 N, R13E, UM At top of productive interval x = 655030, Y = 5972642 4220' SNL, 160' EWL, SEC. 01, T11 N, R13E, UM At total depth x = 653617, Y = 5973823 3010' SNL, 1227' WEL, SEC. 02, T11 N, R13E, UM " STATE OF ALASKA, ALASKA '-'It AND GAS CONSERVATION COMMI""SION PERMIT TO DRILL 20 AAC 25~005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 66.33' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028280 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / F-10B 9. Approximate spud date 03/01/03 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 112501 MD / 8969' TVDss o 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 90 Maximum surface 2301 psig, At total depth (TVD) 8940' / 3195 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD (include staae data) 8750' 7904' 11250' 8969' 152 cu ft Class 'G' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well / ADL 028277,3010' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9360' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Hole Casina Weiaht Grade Couplina Lenath 4-1/8" x 3-3/4" 3-3/16"x2-7/S" 6.2#/6.16# L-80 TCII / STL 2500' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11055 feet Plugs (measured) true vertical 9054 feet Effective depth: measured 10992 feet Junk (measured) true vertical 9055 feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Liner 110' 20" x 30" 2649' 13-3/8" 9221' 9-5/8" 1396' 7" 2309' 2-7/8" 7.5 cu yds Concrete 3720 cu ft Arcticset II 1262 cu ft Class 'G', 130 cu ft AS 110' 2678' 9250' 110' 2678' 8420' 278 cu ft Class 'G' 95 cu ft Class 'G' 8744' - 9667' a1î'k. ~':- ,t11 ~ ~ ~'C-T '~ ~~: ~~ 1~ ~[".I:I, \\!~:; ~I:,.:": ~, 7965' - 8804' ~i6! - 90541 ~,:r,.,.. ð1"/'" Perforation depth: measured 1 0350' - 1 0520', 1 0520' - 1 0540', 1 0540' - 1 0622', 10680' - 10920' ('! ·'t. true vertical 9041' - 9043', 9043' - 9043', 9043' - 9042', 9044' - 9056' (~!as¡(a m¡ g( 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number. Mark Johnson, 564-5666 Prepared By Name/Number. Terrie Hubb/e, 564-4628 21. I hereby certify that th~. !~regoing is true a~lcorrect to the be~t of my kn~~ledge . Signed Mark Johnson /~ (j )1{~~Tltle CT Drilling Engineer .r J'.:'CC)ro~i.iOÌi:·UsêOn,y, ," Permit Number API Nuntb6 -? 0 3 - 0 2- 9 50- 029-20410-02 Conditions of Approval: Samples Required 0 Ves lEI No Hydrogen Sulfide Measures BVes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: nS:t-- RcPE f-" ~5L~{,) f~ ¡'. Date l' .. ~íS Ie 3 App.ç~~ Ø~,I ':p-¡/' See cover letter '1"'1 flu I> for other reauirements Mud Log Required 0 Yes 181 No Directional Survey Required I8J Ves 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU Approved By Form 10-401 Rev. 12-01-85 Commissioner by order of the commission Date ·1 ·i 1fi'l7 .-?' I Sub it I Triplicate C>RIGINAl SIGNt:U i:jy M L 8iH ) ') BP F-IOb Sidetrack Summary of Operations: Well F-I0A is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing 9rilling rig on ~3/1/03. The sidetrack, F-I0B, will exit QUt-6f7"casing from a whipstock and target Zone 2 reserves. This is the second time CTD will sidetrack tIns well. The existing 2 7/S" liner will be abandoned with a CIBP which competes the P&A (form 10-403 already submitted). The following describes work planned. A schematic diagram of the proposed sidetrack is attached. Pre CTn Summary 1) Slickline -Drift tubing. Pull 2 packoff gas lift mandrels (POGLMs). Set plug in X nipple at 8743' and perform combination MIT of tubing and intermediate case to 2500 psi. Pull plug. Drift 2 7 IS" liner down to 9500'. RDMO. 2) Electric line - Set CIBP at 9450' md in the 2 7/S" liner. PT wellbore to 1000 psi. Wellbore abandonment is complete. 3) Electric line - Chemical cut 2 7 IS" liner at 9410' which is free pipe above 2 7 IS" liner TOC of 9434' . 4) Service Coil- Latch on to 2 7/S" liner, POOH and lay down liner above chemical cut. Make underream run in 7" casing in whipstock setting area. 5) Electric line - Set 7" whipstock at 9360' md. ern Sidetrack Summary 1) MIRV CTD rig. I 2) Mill window out of 7" liner from whipstock at 9360'. 3) Drill 4 1/S" x 3.75" bicenter openhole sidetrack to ~11250' TD with MWD/gamma ~ /' 4) Run 3 3/16" x 2 7/S" liner completion. Top of liner will be at S750'. Cement with (j,1/Bbls cement. 5) RDMO . Mud Program: · Phase 1: 8.4 ppg seawater I · Phase 2: 8.5 ppg used Flo Pro for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / · A 3 3/16" x 2 7/8" solid cemented liner co~.e. ion from 8750' to TD at 12250'. TOC is planned for 9150' md. The liner cement volume is planned to be ~bls of 15.8 ppg class G. Well Control: · BOP diagram is attached. . · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi.-/' · The annular preventer will be tested to 400 psi and 2500 psi. ') ') Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray log will be run over all of the open hole section. · A CNL/GR/CCL cased hole log is optional after the liner has been run and cemented. Hazards /' . F pad is not an H2S pad and has historically low H2S readings. Maximum recorded on the pad was 100 ppm fTom well F-24 on 10/23/02. F-I0a has never had an IDS sample because it has never sustained production. . The risk of lost circulation is considered low. A mapped 20' throw fault will be cut near the beginning of the sidetrack, but the parent wellbore did not have losses when cutting the same fault. Reservoir Pressure .,/' Res. press. is estimated to be 3195 psi at 8940'8S (6.9 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2301 psi. V' MOl 2/4/03 DATE REV BY COMM:NTS 11/01101 WBITP SURFLOC OORRECTION ) TREE = Wa.LHEAD = A CTlJð. TOR = KB. B.EV = BF. 8.EV = K<P= Max Ange = Datum MD = Datum TVD = 6"cm tkEVOY OTIS 66.33' 37.68' 3400' 92 @ 11027' 9737' 8800' SS 8: 1133/f!' COO, 72#, L-80, BlRS, 10 = 12.347" H 2678' ~ Minimum 10 = 2.37" @ 8746' 27/8" STL LNR 7" TaG, 26#, L-80, AB- TC-4S, -I 8676' .0383 bpf, 10 = 6.2276" I TOPOF7" LNR H 8744' TOPOF2-7/8" LNR, 6.16#, L-80, STL, -4 0.0058 bpf,lD =2.44" 8746' 14-1/2", 12.75#, L-OO TaG 1 I 95/8"CSG,47#.L-80BTRS,ID=8.681" H 9250' ~ PERFORATION SUMMA. RY REF LOG: SWS BI-CS 12/22/79 TIE-IN LOG: SWS WEM. GN..-GR 6-5-00 ANGlEA T TOP PERF: 89 @ 10350' N::>te: Refer to Ftoductbn œ for historical perf data S~E SPF INTERVAL OpnlSqz DATE Z' 6 10350' -10520' 0 07/01/00 Z' 10 10520' -10540' 0 07/01/00 Z' 4 10540' -10622' 0 06/06/00 Z' 4 10680' -10920' 0 06/06/00 I 7" LNR, 29#, L-80 BTRS, .0371 bpf, 10 = 6.184" H 10140' Oð. 1E 12/26/79 06106100 11/13/00 01/22/01 01/18/00 02/14/01 RBI BY COMfÆNTS ORIGINð.L COMA...ET1ON cm H:>ReONfAL SlOET"RACK CONVERlED TO CANV AS FINð.L RBlISEO CORÆC11ONS SIS-.H SIS-M) RBT TP F-1 OA . ~l ~ L ) ~ I I . I I I / " ) SAÆTY NOTES: TWO 7" POGLMS, 10 = 2.875" 1 2015' H 7" 011S SSSV LAf\I)lNG NP, 10 = 5.962" 1 ~ 2616' H 95/f!' DV PKR ~ , GAS LlFr MA.Næa.S ST MD TVD DEV 1YÆ VLV LATCH PORT DATE 2 3988 3908 19 POGLM I-ES-RK 1 7998 7249 31 POGLM I-ES-RK 8676' H TOP PBR 1 8701' H 95/8" BAKERPKR, 10= 4.000" I 8743' H 41/2"OTISXNIP,ID= 3.813" 1 l 8774' H 4 1/2" XN NIP, MILLED OUT TO 3.80" 10 I 8805' H 41/Z' SOS TaG TAIL 1 I 8789' H ELMO TT LOGGED I .. 9664' H WHIPSTOCKSEr, N:> RA. TAG Wlf\I)OW 9667' - 9675' 1 2 7/8" LNR, 6.16#, Sl1. L-80, .0058 bpf, 10 = 2.37" H 11055' 1 PRUDH:>E BAY LtJIT WEll.: F-10A PERMT NJ: 200-0670 AR NJ: 50-029-20410-01 Sa:; 2, T11N. R13E BP Exploration (Alaska) 1 9 S/8" CSG, 47#, L-80 BTRS, ID = 8.681" H 9250' ~ I TREE =. WB.LHEAD = ACTUA TOR = KB. REV = BF. REV = KOP= Max Angle = Datum Me = Datum TVD = 6" aN McEVOY OTIS 66.33' 37.68' 3400' 92 @ 11027' 9737' 8800' SS ') 1133/8" CSG, 72#, L-80, BTRS, D = 12.347" H 2678' Minimum 10 = 2.37" @ 8746' 2 7/8" STL LNR 7" TBG, 26#, L-80, AB- TC-4S, -1 8676' .0383 bpf, Ð = 6.2276" I TOP OF 7" LNR H 8744' I TOP OF 2-7/8" LNR, 6.16#, L-80, Sn., -t 8746' 1 0.00S8 bpf, Ð = 2.44" 14-1/2", 12.7S#, L-80 TBG t PERFORATION SUMMARY REF LOG: SWS BHCS 12/22/79 TIE-~ LOG: SWS MEM. GNL-GR 6-S-00 ANGLE AT TOP PERF: 89 @ 10350' Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 2" 6 10350' -10S20' isolated proposed 2" 10 10S20' -10540' isolated proposed 2" 4 10540' -10622' isolated proposed 2" 4 10680' -10920' isolated proposed 1 Wt-FSTOCK SET, NO RA TAG H 9664' WNOOW 9667' - 967S' 1 7" LNR. 29#. L-80 BTRS, .0371 bpf, Ð = 6.184" H 10140' F-10B Proposed CTD Sidetrack I ') SAFETY NOTES: TWO 7" POGLMS, Ð = 2.875" , \ 2015' 1-1 7" OTIS SSSV LANDNG NP, [) = S.962" 1 . 8 ~ &>---i 2616' H 9 S/8" DV PKR 1 ~ GAS LFT MANDR8..S ST MD TVD DEV TYÆ VLV LATœ PORT DATE 2 3988 3908 19 POGLM HES-RK 1 7998 7249 31 POGLM HES-RK ~~ ::8: L ) ~ 8676' H TOP A3R I 8701' H 9 S/8" BAKER PKR, D = 4.000" 1 - I 'c:::J 8743' H 4 1/2" OTIS X NP, D = 3.813" 1 8750' 1-1 Top of 3-3/16" Liner I 8760' H3.5" XN Nip, ID =2.75" I 8774' H 4 1/2" XN NIP, MLLED OUT TO 3.80" Ð I / .... 8805' H 4 1/2" SOS TBG TAIL 1 8789' H RMD TT LOGGED 1 9150' 1-1 Top of cement I - .......- .. '~.> ~"""~' ...", I 10200'. H3-3/16 x 2-718 x-ove,. Iìi.i..~ . .)¡ . r---> r---> P 3-3/16" X 2-7/8" cmt'ed and perfedl-i 11250' 9360' - Mechanical Whipstock 9450' - CIBP I 27/8" LNR, 6.16#, STL, L-80, .0058 bpf, D = 2.37" H 11055' PRUDHOE SAY UNIT waL: F-10A PERMIT No: 200-0670 AA No: 50-029-20410-01 SEC2, T11N, R13E BP Exploration (Alaska) REV BY DATE REV BY COM'ÆNTS 11/01/01 WBfTP SURF LOC CORRECTION DATE 12/26/79 06106100 11/13100 01/22/01 01/18100 02114/01 COM'ÆNTS ORIGNAL COM\..ET1ON ern HORIZONTAL SDETRAO< OOMIERTED TO CAtoN AS ~L REVISID CORRECT1ONS SIS-JH SIS-M:> RBT TP :;;~;r~¡;:,7:E;~~f~::: -: 8400-+----1 -- - - --- - j - --L ___---L- --- -- =! -- -! -~,. -: -I __n~ ---. F-10Bh.1 13~::.¡::J:::: 1.-:r::::~~;'I·J ~ ....~~ 5 ~----~--! - - _n__.___ ¥---- - a. -- I 1, i:J·. ;.; .. :¡:.. ¡!::~II z:i.·J::.l-l·:J; jª~~~1¡~·¡I~fl;] \.i·1=r.·CFI ·fl···~~:1L¡ -Ti-T4:Þtr . tt~·.. .~... .. .. I . I I I I . I í ' - I I I j I I ' , I ¡ ., , i~L; :~/~-~t~::)rf:~,:~++1--! nt! my n!-c~i!-I--rn+~~t~1U-.uf--~.~::=~ -1C: ..J.:':cc___: -~ ' I J I 1 I . I I I I I I . ' I I . , .. I ,..' .1 -I I I- .-, . , ,. I . ; ., , ~~~'~fJ0~0~~i~~~j~~~tfl~J=~~~~ 9O~: ; : - ¡ .: : ~ ~ ;; /1~ ~Fi1:01~; j -~Î: ::Î ~ j- -;:7 ~~ ~1 ;- ¡; ~~~~~-;! :;~-¡;A; ¡:I~1i! ; , ; ! : ' ~-h~~~~¡ ; ; : ¡ : i I ¡ :¡iit.-¡ Î~~-1¡,~ : I I ; I : : ¡ ¡;-¡,11ij L.--f~~ -~¡ I ¡ : ¡~,~!; - --i --~ :¡~T ; ;-;- :i: -~ -3250 -3200 -3150 -31'00 -3050 -3000 -2950 -2900 -2850-2800 -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250-2200 -2150 -2100 -2050 -2000 -1950 -1900 -1850 -1800 -1750 -1700 -1650 -1600 -1550 -1500 -1450 -1400 -1350 -1300 Vertical Section at 315.00· [50ft/in] 1/31/2003 3:29 PM ANNOTATION. TVD liD _.._ U..... ....... TIP MU.M ._... KOP Mn.n ....... , .N7..... _... . .U.A. .171,.1 . ".IA7 taTl,.. . ."'AI .nl,.1 7 ....,.7. .171,.1 . IN,.n l.n..I1 . .H'.'. 1.1u.J1 Ie _,.,. UNa.l1 11 _,.,. U7U... 11 ~I~t ~n~!-!! ~ C<>otdlnatecm! Reference: wen Centre: F-IO. True North V~on (Vs¡ ~==: ~~~Ó ~cX!N~o::)~ MeasunId Depth Reference; 10: 10 1~8I197900:00 66_30 Celculatlon Method: MinImJrn CUMIt"8 IIIC'TIOtIIIHTAIU ... _ ... AD 1'VIi ...... ...,......... TP__ va.« T...,et t ....00 I'J".e:I t...... u..... -1MO.7' ........ 0... 0.00 ·2110..., J ==:::::rn :m:: ~M7::: =:~:; vt: u:::: == : ::::::::::: '=::J =.-:: :~Etl¡ :::;;:J ::: == :=:: , :m::::tt: ::::: ~ ~~I mtjl :::: == :=::: . ""'.01 .,. lit'" ....,. -101.11 1TU.0D -'00 aeo... -2Ul.J' :. ~:::= ::::: m::: =~ ~r~ :::::; = a: :::-.:: ;i~æt= :: em Eñ -5i ;æ 1~E :~5 :~ 1.1'1...... ..,... 11U" .....01 .-a.aI t........ 1:L00 "'00 *"UU4 -- ::::~1 '.108TJZ '.1081'2) TAIÐ£T OETNlS 1"w'O tfU.a ~.w 000 .-s.& 1S44U ~oo -'*12 2S14t2 lt6.5oo -122331 2$1793 awloo 412 ss 16($ U "'- ~ -- J i. 1- ··f'r-! ..~. FJ- -500 j¡ ! i j I -I ! i ; ! ~~~[ttt --! ~~7"'tcÞ in . ~- '- I ì---- .-~ '- [131 I ---1=e ~ . -¡ . ., ¡ -' ,.,. I . .! -c - -~+--I ---î --r --. .l,,----j----t-- ;-i------t-- '':'':'':-1 j t .!"., 1- -9OO--::IT-:i. i¡I.! : ---¡ '121 - ·1 I -+-__L- I I_C_ ~- ¡ i '-- I --t- _ I I -1----1 -- I -'---r I , 1~ I F-10B PoIyg0n2.1 ¡;;. ! I , ~ - ~I·---~-_=±-:-r--~...:....~t· _-11~·!-+ ., -:¡ .!, I ::--.. + ::-t------+- - ----J---~' I 1_- - ,I I I·" I , .c -1200 _I I I : i : I I' I t: I ' - o ~-------+- -- -+- ---'----__+--+--¡_----l___ ~=:) F-10B Z 1300----+- -- - - - --- ¡ ---~- I --- - - _1- - - ~- -- - - I - -' - - ~ -""I - - ~-- - - - -- - _ -- -- ---- -----f---T -l.::=t----- ~-- ":"-1400 - , I!: ¡ 5 +--- 'I ¡ Iii " :I - Ii, , I o -1~ I I' - 1 - ¡ - t ¡ _ ffiP1. en ::1-.-.. I ~.':"':"¡-' I i IF-1OBT211 -1600:1= I:: I ~ ~ . :-=-- ! --t-- ¡ I '1 -17 I I I, ::------1- ¡ I I -1800 : _ . I . I .. ! ¡ I i IF - .. . .11 .. II I I i ------+----t-- I -! I I -1900 ~ __~_____1..._1 : . ¡ ¡ I -I .! . '. I ' -. -. . -~--- . -+--. -L-- I I I -- -2000-=-t-----J---. i ¡ -! I ~ I . -- =~~~~1~~~1-;-~~1~~;r~ ¡ ¡ I: t ~-~t~~i¡~~~~-~;;~ ¡ i ~-¡¡ I I 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 West(-)/East(+) [100ft/In] - -- Ita.... ~I n... liD. ..... "01.- v...._ ....... Ul...· ~ .... BP Amoco _LUOATM œTAlIA _ ..lea aoozeH41eo2 "11 .aN", .1.1IN1UI _ M"'" ~~ :~ .... .... ObP -tA: INTEQ ~~ '.'~....'. ~ -n ~ -_--.; ~;;" ! ~~~/ LEGEND - ~:1g !~:~gl) - Plan#2 F-10B Plan ff2 T ^M ¿ Magnetic Field Strent,h: 57537nT O~ale:g~~~~z~; Model: BGGM2oo2 Azimuths tD True NDrth Magnetic North; 25_94° Direct (907) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 ObP ) BP ) Baker Hughes INTEQ Planning Report ... .... INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-10 Wellpath: Plan#2 F-10B Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 1/31/2003 Time: 15:29:39 Page: Co-ordinate(NE) Reference: Well: F-10, True North Vertical (fVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.OON,O.00E,315.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5972527.29 ft 650960.70 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 55.283 N 148 46 31.468 W True 1.15 deg Well: F-10 Slot Name: 10 F-10 Well Position: +N/-S 1934.39 ft Northing: 5974482.00 ft Latitude: 70 20 14.307 N +E/-W 1036.51 ft Easting : 651958.00 ft Longitude: 148 46 1.196 W Position Uncertainty: 0.00 ft Wellpath: Plan#2 F-10B 500292041002 Current Datum: 10 : 10 12/8/1979 00:00 Magnetic Data: 1/31/2003 Field Strength: 57537 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 F-10 9300.00 ft Mean Sea Level 25.94 deg 80.83 deg Direction deg 315.00 Height 66.30 ft Targets Map Map <-- Latitude --> <-- Longitude --> Name Description TVD +N/-S +EI-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft F -1 OB Polygon2.1 0.00 -888.54 1544.43 5973625.00 653520.00 70 20 5.567 N 148 45 16.095 W -Polygon 1 0.00 -888.54 1544.43 5973625.00 653520.00 70 20 5.567 N 148 45 16.095 W -Polygon 2 0.00 -1488.19 2752.62 5973050.00 654740.00 70 19 59.666 N 148 44 40.819 W -Polygon 3 0.00 -1670.33 2608.89 5972865.00 654600.00 70 19 57.875 N 148 44 45.018 W -Polygon 4 0.00 -1920.26 2848.89 5972620.00 654845.00 70 19 55.416 N 148 44 38.012 W -Polygon 5 0.00 -1518.52 3262.14 5973030.00 655250.00 70 19 59.366 N 148 44 25.941 W -Polygon 6 0.00 -1293.69 3026.63 5973250.00 655010.00 70 20 1.578 N 148 44 32.815 W -Polygon 7 0.00 -477.95 1767.81 5974040.00 653735.00 70 20 9.604 N 148 45 9.569 W F-10B T2.1 8454.00 -1568.32 2510.92 5972965.00 654500.00 70 19 58.879 N 148 44 47.877 W -Plan hit target F-10B T2.2 8965.00 -1223.38 2567.93 5973311.00 654550.00 70 20 2.271 N 148 44 46.209 W F-10B T2.3 8969.00 -692.53 1645.43 5973823.00 653617.00 70 20 7.494 N 148 45 13.144 W Annotation MD TVD ft ft 9300.00 8399.06 TIP 9360.00 8454.04 KOP 9380.00 8472.28 3 9420.00 8507.84 4 9571.05 8629.66 5 9671.05 8701.07 6 9771.05 8772.41 7 9871.05 8843.70 8 10178.25 8963.78 9 10253.25 8963.78 10 10503.25 8963.78 11 10753.25 8963.78 12 ObP ') BP ) ... .... Baker Hughes INTEQ Planning Report INTEQ Company: BPAmoco Date: 1/31/2003 Time: 15:29:39 Page: 2 Field: Prudhoe Bay Co-ordlnate(NE) Reference: Well: F-10, True North Site: PB F Pad Vertical (lVD) Reference: System: Mean Sea Level Well: F-10 Sec:tion(VS) Reference: Well (0.ooN,O.00E,315.00Azi) Wellpatb: Plan#2 F-10B Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 10978.25 8963.78 13 11250.00 8969.03 TD Plan: Plan #2 Date Composed: 1/31/2003 Identical to Lamar's Plan #2 Version: 3 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Ind Azim TVD +N/-S +EI-W DLS Build. Turn TFO Target ft deg deg ft ft ft deg/10OO deg/10OO deg/10OO deg 9300.00 23.82 134.90 8399.06 -1550.70 2494.56 0.00 0.00 0.00 0.00 9360.00 23.39 137.15 8454.04 -1567.98 2511.24 1.66 -0.72 3.75 116.54 9380.00 24.96 135.02 8472.28 -1573.88 2516.93 9.00 7.87 -10.66 330.00 9420.00 29.73 120.95 8507.84 -1584.97 2531.42 20.00 11.91 -35.17 300.00 9571.05 45.00 76.46 8629.67 -1591.89 2617.47 20.00 10.11 -29.45 280.00 9671.05 45.05 48.04 8701.07 -1559.62 2678.78 20.00 0.05 -28.42 260.00 9771.05 45.10 19.65 8772.41 -1502.02 2717.40 20.00 0.05 -28.39 260.00 9871.05 45.14 351.28 8843.70 -1432.93 2724.00 20.00 0.04 -28.37 260.00 10178.25 90.00 303.69 8963.78 -1219.23 2564.06 20.00 14.60 -15.49 302.80 10253.25 90.00 312.69 8963.78 -1172.91 2505.17 12.00 0.00 12.00 90.00 10503.25 90.00 282.69 8963.78 -1058.05 2286.33 12.00 0.00 -12.00 270.00 10753.25 90.00 312.69 8963.78 -943.19 2067.49 12.00 0.00 12.00 90.00 10978.25 90.00 285.69 8963.78 -834.47 1872.88 12.00 0.00 -12.00 270.00 11250.00 87,85 318.24 8969.03 -692.58 1645.46 12.00 -0.79 11.98 94.00 Survey MD Incl Azlm SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10OO deg 9300.00 23.82 134.90 8399.06 -1550.70 2494.56 5972982.28 654483.28 -2860.43 0.00 0.00 TIP 9325.00 23.64 135.83 8421.94 -1557.85 2501.63 5972975.27 654490.50 -2870.49 1.66 116.54 MWD 9350.00 23.46 136.77 8444.86 -1565.07 2508.53 5972968.19 654497.54 -2880.47 1.66 115.69 MWD 9359.96 23.39 137.15 8454.00 -1567.97 2511.23 5972965.35 654500.30 -2884.43 1.66 114.83 F-10B T2 9360.00 23.39 137.15 8454.04 -1567.98 2511.24 5972965.34 654500.31 -2884.45 1.66 114.48 KOP 9375.00 24.57 135.53 8467.74 -1572.39 2515.45 5972961.02 654504.61 -2890.54 9.00 330.00 MWD 9380.00 24.96 135.02 8472.28 -1573.88 2516.93 5972959.56 654506.11 -2892.63 9.00 331 .48 3 9400.00 27.17 127.42 8490.25 -1579.64 2523.54 5972953.94 654512.84 -2901.38 20.00 300.00 MWD 9420.00 29.73 120.95 8507.84 -1584.97 2531.42 5972948.77 654520.83 -2910.73 20.00 306.83 4 9425.00 29.92 118.98 8512.18 -1586.21 2533.58 5972947.57 654523.01 -2913.13 20.00 280.00 MWD 9450.00 31.28 109.52 8533.71 -1591.40 2545.16 5972942.62 654534.69 -2924.99 20.00 281.71 MWD 9475.00 33.28 100.93 8554.85 -1594.87 2558.02 5972939.41 654547.62 -2936.53 20.00 289.86 MWD 9500.00 35.81 93.31 8575.45 -1596.59 2572.06 5972937.97 654561.69 -2947.68 20.00 297.13 MWD 9525.00 38.75 86.63 8595.35 -1596.55 2587.18 5972938.32 654576.81 -2958.35 20.00 303.41 MWD 9550.00 42.03 80.80 8614.40 -1594.76 2603.27 5972940.44 654592.85 -2968.45 20.00 308.72 MWD 9571.05 45.00 76.46 8629.67 -1591.89 2617.47 5972943.60 654606.99 -2976.46 20.00 313.17 5 9575.00 44.87 75.36 8632.46 -1591.21 2620.17 5972944.33 654609.68 -2977.89 20.00 260.00 MWD 9600.00 44.28 68.28 8650.28 -1585.74 2636.82 5972950.13 654626.22 -2985.80 20.00 260.78 MWD 9625.00 44.14 61.11 8668.21 -1578.30 2652.56 5972957.89 654641.80 -2991.67 20.00 265.82 MWD 9650.00 44.45 53.96 8686.11 -1568.94 2667.27 5972967.54 654656.32 -2995.46 20.00 270.97 MWD 9671.05 45.05 48.04 8701.07 -1559.62 2678.78 5972977.10 654667.63 -2997.00 20.00 276.09 6 9675.00 44.92 46.94 8703.86 -1557.73 2680.84 5972979.02 654669.65 -2997.12 20.00 260.00 MWD 9700.00 44.34 39.87 8721.66 -1545.00 2692.89 5972992.00 654681.45 -2996.64 20.00 260.78 MWD 9725.00 44.19 32.71 8739.58 -1530.95 2703.21 5973006.25 654691.47 -2994.00 20.00 265.81 MWD 9750.00 44.50 25.56 8757.47 -1515.70 2711.70 5973021.67 654699.66 -2989.23 20.00 270.95 MWD 9771.05 45.10 19.65 8772.41 -1502.02 2717.40 5973035.46 654705.07 -2983.58 20.00 276.06 7 9775.00 44.97 18.55 8775.20 -1499.38 2718.31 5973038.12 654705.93 -2982.36 20.00 260.00 MWD 9800.00 44.38 11.48 8792.99 -1482.43 2722.86 5973055.16 654710.14 -2973.59 20.00 260.78 MWD 9825.00 44.24 4.33 8810.89 -1465.15 2725.26 5973072.48 654712.19 -2963.07 20.00 265.80 MWD ObP ) BP ) Bii. .... Baker Hughes INTEQ Planning Report INTEQ Company: BPAmoco Date: 1/31/2003 Time: 15:29:39 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: F-10, True North Site: PB F Pad Vertical (fVD) Reference: System: Mean Sea Level Well: F-10 . Sec:tion(VS) Reference: Well (0.ooN,O.00E,315.00Azi) Wellpath: Plan#2 F-10B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 9850.00 44.54 357.19 8828.77 -1447.69 2725.49 5973089.94 654712.06 -2950.88 20.00 270.93 MWD 9871.05 45.14 351.28 8843.70 -1432.93 2724.00 5973104.67 654710.27 -2939.39 20.00 276.03 8 9875.00 45.57 350.35 8846.48 -1430.16 2723.55 5973107.43 654709.77 -2937.11 20.00 302.80 MWD 9900.00 48.47 344.77 8863.53 -1412.32 2719.59 5973125.18 654705.45 -2921.70 20.00 303.45 MWD 9925.00 51.61 339.70 8879.59 -1394.09 2713.73 5973143.29 654699.22 -2904.67 20.00 307.26 MWD 9950.00 54.95 335.05 8894.54 -1375.61 2706.01 5973161.60 654691.13 -2886.14 20.00 310.52 MWD 9975.00 58.45 330.78 8908.26 -1357.02 2696.49 5973179.99 654681.23 -2866.27 20.00 313.30 MWD 10000.00 62.09 326.83 8920.66 -1338.47 2685.24 5973198.32 654669.61 -2845.19 20.00 315.64 MWD 10025.00 65.83 323.14 8931.64 -1320.09 2672.34 5973216.43 654656.35 -2823.07 20.00 317.61 MWD 10050.00 69.66 319.66 8941.11 -1302.02 2657.91 5973234.20 654641.55 -2800.09 20.00 319.23 MWD 10075.00 73.55 316.35 8949.00 -1284.40 2642.03 5973251.49 654625.32 -2776.41 20.00 320.55 MWD 10100.00 77.49 313.17 8955.25 -1267.37 2624.85 5973268.17 654607.79 -2752.21 20.00 321.59 MWD 10125.00 81.46 310.08 8959.82 -1251.05 2606.48 5973284.12 654589.10 -2727.68 20.00 322.39 MWD 10150.00 85.47 307.06 8962.66 -1235.57 2587.06 5973299.20 654569.38 -2703.01 20.00 322.95 MWD 10175.00 89.48 304.08 8963.76 -1221.04 2566.75 5973313.31 654548.78 -2678.38 20.00 323.30 MWD 10178.25 90.00 303.69 8963.78 -1219.23 2564.06 5973315.06 654546.05 -2675.19 20.00 323.43 9 10200.00 90.00 306.30 8963.78 -1206.76 2546.24 5973327.17 654527.98 -2653.77 12.00 90.00 MWD 10225.00 90.00 309.30 8963.78 -1191.44 2526.49 5973342.09 654507.93 -2628.97 12.00 90.00 MWD 10250.00 90.00 312.30 8963.78 -1175.10 2507.57 5973358.04 654488.68 -2604.04 12.00 90.00 MWD 10253.25 90.00 312.69 8963.78 -1172.91 2505.17 5973360.18 654486.24 -2600.80 12.00 90.00 10 10275.00 90.00 310.08 8963.78 -1158.53 2488.86 5973374.23 654469.64 -2579.09 12.00 270.00 MWD 10300.00 90.00 307.08 8963.78 -1142.94 2469.31 5973389.42 654449.78 -2554.25 12.00 270.00 MWD 10325.00 90.00 304.08 8963.78 -1128.39 2448.98 5973403.54 654429.16 -2529.59 12.00 270.00 MWD 10350.00 90.00 301.08 8963.78 -1114.93 2427.92 5973416.57 654407.83 -2505.18 12.00 270.00 MWD 10375.00 90.00 298.08 8963.78 -1102.59 2406.18 5973428.47 654385.85 -2481.08 12.00 270.00 MWD 10400.00 90.00 295.08 8963.78 -1091.41 2383.83 5973439.20 654363.28 -2457.36 12.00 270.00 MWD 10425.00 90.00 292.08 8963.78 -1081.41 2360.92 5973448.73 654340.17 -2434.09 12.00 270.00 MWD 10450.00 90.00 289.08 8963.78 -1072.62 2337.52 5973457.04 654316.60 -2411.33 12.00 270.00 MWD 10475.00 90.00 286.08 8963.78 -1065.07 2313.69 5973464.11 654292.62 -2389.14 12.00 270.00 MWD 10500.00 90.00 283.08 8963.78 -1058.78 2289.49 5973469.91 654268.31 -2367.59 12.00 270.00 MWD 10503.25 90.00 282.69 8963.78 -1058.05 2286.33 5973470.57 654265.13 -2364.84 12.00 270.00 11 10525.00 90.00 285.30 8963.78 -1052.79 2265.22 5973475.40 654243.92 -2346.19 12.00 90.00 MWD 10550.00 90.00 288.30 8963.78 -1045.56 2241.29 5973482.14 654219.85 -2324.16 12.00 90.00 MWD 10575.00 90.00 291.30 8963.78 -1037.10 2217.78 5973490.13 654196.17 -2301.54 12.00 90.00 MWD 10600.00 90.00 294.30 8963.78 -1027.41 2194.73 5973499.35 654172.94 -2278.40 12.00 90.00 MWD 10625.00 90.00 297.30 8963.78 -1016.53 2172.23 5973509.77 654150.22 -2254.79 12.00 90.00 MWD 10650.00 90.00 300.30 8963.78 -1004.48 2150.32 5973521.37 654128.08 -2230.79 12.00 90.00 MWD 10675.00 90.00 303.30 8963.78 -991.31 2129.08 5973534.11 654106.57 -2206.45 12.00 90.00 MWD 10700.00 90.00 306.30 8963.78 -977.04 2108.55 5973547.95 654085.76 -2181.85 12.00 90.00 MWD 10725.00 90.00 309.30 8963.78 -961.72 2088.80 5973562.87 654065.70 -2157.05 12.00 90.00 MWD 10750.00 90.00 312.30 8963.78 -945.39 2069.88 5973578.82 654046.46 -2132.12 12.00 90.00 MWD 10753.25 90.00 312.69 8963.78 -943.19 2067.49 5973580.96 654044.02 -2128.87 12.00 90.00 12 10775.00 90.00 310.08 8963.78 -928.81 2051.17 5973595.01 654027.41 -2107.16 12.00 270.00 MWD 10800.00 90.00 307.08 8963.78 -913.23 2031.63 5973610.20 654007.56 -2082.32 12.00 270.00 MWD 10825.00 90.00 304.08 8963.78 -898.68 2011.30 5973624.33 653986.94 -2057.66 12.00 270.00 MWD 10850.00 90.00 301.08 8963.78 -885.22 1990.23 5973637.36 653965.61 -2033.25 12.00 270.00 MWD 10875.00 90.00 298.08 8963.78 -872.88 1968.49 5973649.25 653943.63 -2009.15 12.00 270.00 MWD 10900.00 90.00 295.08 8963.78 -861.69 1946.14 5973659.98 653921.06 -1985.44 12.00 270.00 MWD 10925.00 90.00 292.08 8963.78 -851.69 1923.23 5973669.51 653897.95 -1962.17 12.00 270.00 MWD 10950.00 90.00 289.08 8963.78 -842.91 1899.83 5973677.83 653874.38 -1939.41 12.00 270.00 MWD 10975.00 90.00 286.08 8963.78 -835.36 1876.00 5973684.89 653850.40 -1917.22 12.00 270.00 MWD 10978.25 90.00 285.69 8963.78 -834.4 7 1872.88 5973685.72 65384 7 .26 -1914.38 12.00 270.00 13 ) " ) ... ObP BP .... Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 1/31/2003 Time: 15:29:39 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: F-1.o, True North Site: PB F Pad Vertical ((VD) Reference: System: Mean Sea Level Well: F-1.o Section (VS) Reference: Well (.o.OON,O.O.oE,315..o.oAzi) Wellpath: Plan#2 F-1.oB Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10OO deg 11.00.0..00 89.82 288.30 8963.81 -828.11 1852.07 5973691.65 653826.34 -1895.18 12.00 94..00 MWD 11.025..0.0 89.61 291.29 8963.94 -819.64 1828.55 5973699.64 653802.65 -1872.56 12.0.0 94..00 MWD 11.05.0..0.0 89.4.0 294.28 8964.16 -809.96 1805.51 59737.08.85 653779.42 -1849.42 12.00 93.98 MWD 11075.00 89.2.0 297.27 8964.46 -799..09 1783.0.0 5973719.26 653756.69 -1825.82 12.00 93.96 MWD 11100..00 88.99 300.27 8964.86 -787.06 1761..09 5973730.84 653734.55 -1801.82 12..00 93.92 MWD 11125.00 88.79 303.26 8965.34 -773.91 1739.84 5973743.56 653713..04 -1777.49 12..00 93.87 MWD 1115.0.00 88.59 3.06.26 8965.91 -759.66 1719.31 5973757.39 653692.22 -1752.90 12..00 93.81 MWD 11175..00 88.40 3.09.25 8966.57 -744.36 1699.55 5973772.29 653672.16 -1728.11 12..00 93.74 MWD 1120.0.00 88.21 312.25 8967.31 -728.05 1680.63 5973788.21 653652.91 -17.03.19 12.0.0 93.67 MWD ~~ 88..02 315.24 8968.13 -710.77 1662.58 59738.05.11 653634.51 -1678.21 12.00 93.58 MWD 1125.0..0.0 87.85 318.24 8969.03 -692.58 1645.46 5973822.95 653617..03 -1653.24 12.0.0 93.48 TD , ., .\If. ........~ ~ b P ~..- ..e:...- '-."\ ~..... .,.,.,.\- ". ) ') ENGINEERING DATA SHEET NO. OF SUBJECT BASED ON ENGINEER BUDGET/AFE NO. DEPT. APP'VL DATE FILE NO. :>< ! ~ ~ -- F701 F--/613 - t L J' , k - ~ 1ý(f 87Sd tH~"- ~ V~ 2%~of-\ IIZ.~~ _/OtOO('f.l~S:~'Z'S75'''\ ~ ?,';.I.If=ll.S 10 ~ , ) 3~(";~ 01-1 IOì(jO-'1.%o(.,./~S2.-3.'1"¿.) = :;-, f:o'1<I.'-I "':. 7. g /OLC¡ ) La. () 'i 31. 0 - 71S'~ ~ .1 8'f '2_ 3.19 ~ = 5. 7 I ¡oZ-'; ) ~ 0,02.7 5 ~ fy-Ø¡ c.-k..., 0,2.. 2.~ ,2. ßb \ ~ 1;;. "L7 6h ,.. /',,- " ~ ~~ .r - /) ¿) 0 \J / 1 ,,". " (",' f . (' 7lïìï í;Z~ I¡-- ?' , '0 C¡'OÓ c:(;¡~..., ~vt I ì/ïí; 'Cf3~ TðG. , Cf'lSo t:, ~p 110J 2/3/0 '3 AK2337-1 (11100) ') Nordic CTD BOP Detail I \ / I I ® I I ® I , THA I ~ -.)1 Tubing @ r Spool -, I I -@-~ /UI I ~ Methanol Injection ðJLð, Otis 7" WLA Quick II Connect - I 7-1/16" 10, 5000 psi working pressure I ( Ram Type Dual Gate BOPE Manual over Hydraulic \... I Flanged Fire Resistant Kelly Hose to Dual Choke Manifold I t=C t=C= HCR I =@~rn I TOT 7-1/16" 10, 5000 psi working pressure ~ Ram Type Dual Gate BOPE I TOT I=~ Manual over Hydraulic = XO Spool as necessary Full production christmas tree ~ L MOJ 9/15/02 ) o~ ~ -- CT Injector Head I 1 --- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ 7" Riser I I ~ Annular BOP (Hydril),7-1/16" 10 5000 psi working pressure ..) I /' I Blind/Shear I /' 2 3/8 " Combi Pipe/SIi~ Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on OS Hardline to StandpipE manifold I J1®1IJfBJ II"~ te I / I /' 1/ 2" Side outlets 2 3/8" X 3 1/2" VBRs 2 3/8" Combi Pipe/Slip 2 flanged gate valves Inner Annulus Outer Annulus P054995 DATE 12/19/2002 INV# CK121702D INVOICE I CREDIT MEMO --- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 PAY: ¡----- TO THE ORDER OF: DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ GROSS DATE CHECK NO. 12/19/2002 P054995 VENDOR DISCOUNT NET H ~~-J- \ ,"lL 1. ~ - ~10~ NATIONAL CITY BANK Ashland, Ohio B-" . P· c:;- ... l' It· tm; ð· ,- "'t'" ....., " ...._,0....,...... '. .. eo'" .'. .0 . ·t, ,,' .... I..'".J' f..,.·..·,· :--f .- _, - -In ",f - -- -" .tit _j I:~- -~ . ~~Uþ C IIIP' 'If"" ~Im)- "'" f< E C F J \1 E [J J/id\ì ~~ ( ¿OlU Aiaska OJ¡ & Gias ,--:(Hb_ l,;Jíd!¡¡i:>~iiJ! l-\!·tC(~Ü (fiQ-e 56-389 412 No. P 054995 CONSOLIDATED COMMERCIAL ACCOUNT DATE AMOUNT December 19, 2002 ***************$100.00*** ALASKA C)IL & GAS CONSERVATION CL),MMISSION 333 W 7TH A VEND E SUITE 100 ANCHORAGE, AK.!:}9501 11105 L¡ Ii '1 Sill 1:0 L. ~ 20 ~8Cg 51: 0 * 2 ?B g bill N?';:~.'r~7:~t:~\jj¿}.:~:~¡.S::;~~.~i;~2.\J .... í~t~ ::.. .....,.... ...... .... "'1 ~:/L..::~ {~¡;::::;:\;::;~:?::~:/;:i·~·i·ë5::J ') ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY . ßf.k WELL NAMEt'ßf..{ ç- /0{5 PROGRAM:Exp _ Dev~ RedrllÄ Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL h 7'0 / ç~ INIT CLASS Ce.l.; / - CI ,'/ GEOL AREA If 7 t? UNIT# II ç; .~ ~ ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . fA N 2. Lease number appropriate. . . ~ . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . , . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. ... . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Penn~ can be issued without administrative approval.. . . . . ~ (Service Well Only) 13. Well located w(in area & strata authorized by injection order #_ Y 1/( fJ. (Service Well Only) 14. All wells w/in % mile area of review identified. . . . . . . . ., Y ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . ¥---N-1U11t- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N 20. Casing designs adequate for C~ T, B & permafrost. . . . . . . N í'-r D u... 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . .. N '--"1 . 22. If a re-drill, has a 10-403 for abandonment been approved. ., X- Y N 23. Adequate wellbore separation proposed.. ...' . . . . . '.' . . ro N 24. If diverter required, does It meet regulations. .. . . . . .. . ~ "'/A- J. J 0 25. Drilling fluid program schematic & eq. uip IiS..t adequate. . . . . 1 N f'11.¡,t,íl t11.lAJ. " · 5" P P7.. . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ¡/)/J (' ) . ~7: BOPE press rating appropriate; test to v~~C)C) psig. N f Y ( :> I ¿ t) 01 r Ç. ¿~ ; I / 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \lJGk z.. (, 0'5 29. Work will occur without operation shutdown. . . . . . . . . . . N . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . .. . Y MJ (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . ~ rJ./A- GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . . . . Y@ APPR DATE 33. Data presented on potential overpressure zones. . . . . . .. fiy N ~ //). .\ /) \ Af# ~/ / 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . f/I.. ~ rJ /fÆ- -?' (;"/3 35. Seabed condition survey (if ·off-shore). . . . . .. ...... N . (Explorat ry Only) 36. Contact name/phone for weekly progress reports. ...... . N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE HL~3 APPR DATE UIC ENGINEER TEM JDH JBR Rev: 10/15/02 SFD_ WGA ./ MJW G:\geology\permits\checklist.doc COMMISSIONER: COT DTS 0'2. )0 7/0 :1 MLB C> ::L/Ð '"/03 {, Comments/Instructions: ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation. infomlation of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. ) ') f}03~Oð C( $Eevision: 3 $ LisLib $Revision: 4 $ Fri Sep 26 10:29:32 2003 I d-ì-~ I Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 09/ 2 6 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS W,t:"i ting Library. Scient,i fie Technj.cal Services Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/09/26 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tap(,:: Name....... UNKNOWN Comments...... ...........STS LIS Writing Library. Scierrtific Technical Services Physical EOr' Comment Record TAPE HEADER Prudhoe Bay M\i'iro/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # ,JOB DATA F-10B 500292041002 SF Exploration (Alaska) Inc. Sperry-Sun Drilling Services 26-SEP-()3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1. MW0002488905 B. ,JAHN J.EGBEJIMBA/ MWD RUN 2 MW0002488905 B. JAHN R. WHITLOW/ MWD RUN 3 MW0002488905 B. JAHN R. WHITLOW / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002488905 B. JAHN R. WHITLOW / MWD RUN 5 MW0002488905 B. JAHN R. WHITLOW / # SURFACE LOCATION SECTION: TOWNSHI P: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT fROM KELLY BUSHING: DERRICr, FLOOR: GROUND LEVEL: 2 llN 13E, 2318 2871 MSL 0) 66.33 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 8805.0 .... ' ~'. . (, ,,-. .:- l' # REtvIARKS: , " . ,'.'... .......":.. l.'" ~~Df\\0 STOP DEPTH 11335.5 11380.0 START DEPTH 9340.5 9380.0 ROP GR COrrUT\ent Record fI LE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # fILE SUMMARY t'BU TOOL CODE file Header Service name.... ....... ..STSLIB.001 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation.. .... .03/09/26 Maximum Physical Record..65535 file Type................ LO Previous file Name.......STSLIB.OOO $ SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTI-IED GAMM.A I~.AY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . 9. MWD RUNS 1 - 5 REPRESENT WELL F-I0B WITH API#: 50-029-20410-02. THIS WELL REACHED A TOTAL DEPTH (TO) OF 11379'MO/8967'TVDSS. 8. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN IN F-I0B ON 12 JUNE 2003. THESE POC DATA WERE PROVIDED TO SSDS BY DEWAYNE SCHNORR ON 15 SEPTEMBER 2003. LOG HEADER DATA RET.AIN OR,IGINAL DEPT'H REFERENCES. 7. MAD PASS DATA (EWR4 ONL,Y) FROM 9922 'M,D '1'0 THE START OF RUN 5, ACQUIFŒ:D WHILE lUH FOR RUN 5, WERE MERGED WITH RUN 5 MWD DATA. 6. MWD RUN 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG), UTILIZING SCINTILLATION DETECTORS. 3. THE WELL W!ò.,.S EFFECTED BY MEANS OF' AWHI PSTOCK, THE TOP OF WHICH WAS AT 9360'MD AND THE BOTTOM WAS AT 9368'MD. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 2. 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. ) ') ) ') FET 9889.5 11348.0 RPD 9889.5 11348.0 RPM 9889.5 11348.0 RPS 9889.5 11348.0 RPX 9889.5 11348.0 ~? !f BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9340.5 9341.0 9344.5 9366.5 9381.0 9389.5 9391. 5 9394.0 9395.5 9403.5 9412.0 9415.5 9418.5 9421.5 9424.5 9429.5 9433.0 9443.5 9448.0 9452.0 9458.0 9463.5 9466.0 9472.5 9482.0 9494.5 9497.0 9501.0 9.504.5 9514.0 9516.0 9524.0 9531.5 9539.0 9540.5 9544.0 9549.5 9556.5 9562.5 9564.0 9572.5 9578.5 9580.0 9584.0 9589.0 9593.0 %02.5 %12.0 9615.5 9617 .0 9627 . 0 9628.5 9636.5 9638.5 9641.0 9647 . 5 9654.5 9656.5 9665.5 9668.5 9677 . 0 9680. :] l~)() 8 6 . ~~ '1704.0 GR 9339.0 9339.5 9343.5 9365.0 9379.5 9387.0 9389.5 9391.5 9392.5 9401. 0 9409.0 9413.0 9415.5 9418.0 9421.5 9426.0 9430.0 9440.0 9444.5 9448.5 9454.5 9460.5 9462.5 9469.0 9478.5 9491.5 9493.5 9497.0 9501. 0 9509.5 9512.0 9519.0 9525.5 9534.0 9536.0 9540.0 9545.5 9553.5 9558.0 9559.5 9568.0 9574.0 9575.5 9579.0 9584.5 9588.0 9598.0 9607.5 9612.0 9614.5 9623.0 9626.0 9634.5 9636.0 9639.0 9648.0 9654.5 9655.5 9664. (I 9668.5 9675. 9679.(1 9685.5 9702.5 ') ) 9722.0 9726.5 9'730.5 9745.5 9760.0 9762.0 9774.0 9789.5 9795.5 9815.5 9818.5 9821.5 9832.0 9847.0 9873.5 9881.5 9884.5 9897.0 9900.5 9910.0 9930.5 9939.0 9947.0 9954.0 9955.5 9965.0 9968.0 9980.0 10000.0 10003.5 10008.0 10022.5 10031. 5 10044.5 10050.0 10053.5 10079.0 10090.5 10095.0 10097.5 10103.0 10122.0 10133.0 10134.0 10182.5 10195.5 10218.0 10238.5 10246.5 10258.0 10277.0 10296.5 10336.0 10342.5 10349.5 10355.0 10359.5 10369.5 10371.5 10373.5 10388.0 10408.0 10421.0 10426.5 10489.5 10540.5 10542.5 10551.0 10553.5 10570.5 10579.0 10583.5 10588.0 10593.0 10635.5 9722.0 9725.5 9730.0 9747.0 9763.0 9764.5 9777.0 9791. 5 9795.5 9813.0 9817.5 9819.5 9828.5 9845.0 9872.0 9882.0 9884.5 9896.5 9898.0 9908.0 9929.5 9938.0 9946.0 9952.5 9954.0 9964.5 9967.5 9980.0 9999.5 10003.0 10007.5 10020.0 10030.0 10043.0 10048.5 10052.5 10079.0 10089.5 10094.0 10095.5 10102.5 10120.5 10131.0 10132.5 10182.0 10194.0 10216.0 10238.0 10245.0 10254.0 10273.0 10298.0 10338.0 10344.0 10349.0 10355.5 10358.0 10370.0 10371.5 10373.5 10386.0 10406.5 10422.5 10426.(J 10488.5 10538.0 10540.0 10549.5 10552.5 10568.5 10579.C 1052:3. 10588.0 10592.5 10633.0 10652.0 10663.5 10669.5 10674.5 10695.5 10713.0 10724.0 10734.0 10740.0 10747.0 10753.5 10804.5 10812.0 10816.0 10820.5 10826.5 10833.0 10836.5 10842.5 10853.0 10869.0 10896.5 10906.0 10913.0 10914.0 10935.5 10938.5 10947.5 10958.5 10961.5 10982.5 10987.5 10997.5 11010.0 11016.5 11026.0 11036.5 11052.0 11088.5 11101. 0 11106.0 11.116.0 11134.0 11157.0 11167.0 11178.0 11180.0 11186.5 11201.5 11207.5 11209.5 11223.5 11231.0 11237.5 11258.0 11270.5 11286.5 11295.0 11309.0 11316.5 11320.5 11380.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD [,-[\"iD MWD MI'i1D !'lí'i1D $ ~ REtvIARKS: ) 10650.0 10660.5 10666.5 10671.0 10691.5 10710.0 10722.5 10731.5 10737.0 10745.0 10752.5 10804.0 10812.5 10816.0 10820.0 10825.0 10830.5 10834.5 10840.5 10851.5 10866.5 10895.5 10906.0 10914.5 10916.0 10934.0 10937.0 10945.5 10955.0 10960.0 10982.5 10987.0 10998.0 11012.0 11018.5 11027.5 11038.0 11053.0 11089.5 11102.5 11.106.5 11117.0 11136.0 11160.0 11169.5 11177.5 11179.0 11186.0 11202.5 11208.0 11209.5 11227.5 11233.0 11238.5 11258. .5 11272.0 11287.0 11294.5 11305.5 11313.5 11319.5 11379.0 BIT RUN NO MERGE TOP 1. 9339.0 9644.0 3 9657.0 4 9730.0 5 10252.0 '^' ~ MERGED MAIN PASS. ) MERGE BASE 9644.0 9657.0 9730.0 10252.0 11379. (I ) ') # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point........... ...Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/I-! 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD Ol-!MM 4 1 68 16 5 RPM MWD OI-lMM <1 1 68 20 6 RPD MWD OHMM 4 1 6e 24 7 FET MWD I-IOUR 4 1 68 28 8 First Last Name Service Unit .Min Max Mean Nsam Reading Reading DEPT FT 9340.5 11380 10360.3 4080 9340.5 11380 ROP MWD FT/H 0.09 1469.83 78.3461 4001 9380 11380 GR MWD API 15.27 753.56 44.6408 3991 9340.5 11335.5 RPX MWD OHMM 1. 24 36.19 9.33232 2918 9889.5 11348 RPS MWD OHMM 1. 52 57.14 10.939 2918 9889.5 11348 RPM MWD OHMM 1. 38 5E).05 11. 639 2918 9889.5 11348 RI?D MWD OHMM 1. 79 53.01 12.4333 29H3 9889.5 11348 FET MWD HOUR 0.15 19.31 3.96682 2918 9889.5 11348 First Reading For Entire File..........9340.5 Last Reading For Entire File...........11380 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation..... ..03/09/26 Maximum Physical Record..65535 File Type................ LO Next File Name.. .........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation.......03/09/26 Maximum Physical Record..65535 file Type................ LO Previous File Name..... ..STSL1B.OOl Comment Record FILE HEADER FILE NUMBER: 2 R,1\W ¡VIWD Curves and log header data for each bit run in separate files. 1311' RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9339.0 ROP 9378.5 1 .5000 STOP DEPTH 9613.5 9644.0 ) $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG IN'I'EEVAL (F'r): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (F'T): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERA.TURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER.ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction..... .......... ..Down Optical log depth units...........Feet Data Reference Point.......... ....Undefined Frame Spacing.....................60 .1IN Max frames per record.......... ...Undefined Absent value.............. ...... ..-999 Depth Units....................... Datum Specification Block sub-type...O 08-JUN-03 Insite 7.75 Memory 9644.0 9378.0 9644.0 23.4 41. 8 TOOL NUMBER 009 4.125 8805.0 Flow Pro 8.90 65.0 9.5 49000 8.8 .000 .000 .000 .000 Name Service Order Units Size Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 "- GR MWDOIO API 4 1 68 8 3 ) .0 124.8 .0 .0 First Last Name Service Unit Min Max Mean Nsarn Readinq Readin,~ DEPT FT 9339 9644 9491.~) 611 9339 96~ ROP MWD010 FT/H 0.09 582.18 46.0505 532 9378.5 9 6.:'~ GR ¡V¡WDOIO P\E)I 20.17 753.56 82.7592 550 9339 9613. Comment Record G"ILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: # FI LE SUMMARY VENDOR TOOL CODE START DEPTH GR 9614.0 ROP 9644.5 $ ') First Reading For Entire File..... .....9339 Last Reading For Entire File...........9644 File Trailer Service name... ..........STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/09/26 Maximum Physical Record..65535 File Type.... _ _ . . . . . . . . . . LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... ........ ..STSLIB.003 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.... ...03/09/26 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.002 3 .5000 STOP DEPTH 9627.0 9657.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DSE'Tll (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ~1UD i\T MEASURED TE~1PERI\TURE (MT): MUD i\T Mi\X CIRCULi\TING TERMPERPITURE: MUD FILTRATE AT MT: 1'1UO CA!'~E AT HT: ) 08-JUN-03 Insite 7.75 Memory 9657.0 9644.0 9657.0 43.4 45.3 TOOL NUMBER 009 3.750 8805.0 Fl OVi- P r·::· 8.90 65.0 9.5 49000 7.4 .000 .0 .COG 2.29. .GOO .000 .G ') ') NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): if TOOL STANDOFF (IN): EWR FREQUENCY (HZ): it REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing...... ..... .... ......60 .1IN Max frames per record........ ... ..Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Un:i.ts Size Nsam Rep Code OfÜ:¡et Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 6EJ 8 3 First Las"t Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9614 9657 9635.5 ß7 9614 9657 ROP MWD020 FT/H 0.32 56.45 15.1927 26 9644.5 9657 GR MWD020 API 15.27 40.91 23.5359 27 9614 9627 First Reading For Entire File..........9614 Last Reading For Entire File...........9657 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/09/26 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name. .... ... ...STSLIB.004 Physical EOF File Header Service name... ....... ...STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/09/26 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER. fI LE NUMBER: R..rl.í'IJ tvrwD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 4 header data for each bit run in separate files. 3 .5000 FILE SU¡v¡tvl.rl.RY VENDOR TOOL CODE START DEPTH GR 9627.5 STOP DEt='TH 9702.5 ROP $ 9657.5 9730.0 If LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR RE.AL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: It TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ If BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASINCJ DEPTH (FT): t¡ BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEEATURE (MT): MUD NT MAX CIRCULATING TERMP.EEATURE,: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): If TOOL STANDOFF (IN): EWR FREQUENCY (HZ): If REMARKS: $ If Data Format Specification Record Data Record 'Type.................. 0 Data Specification Block Type.....O Logging Direction.......... .......Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units...................... . Datum Specification Block sub-type...O ') 08-JUN-03 Insite 4.3 Memory 9730.0 9657.0 9730.0 43.4 49.1 'TOOL NUMBER 93091 3.750 8805.0 Flow-Pro 8.90 65.0 9.5 49000 7.4 .000 .0 .000 123.8 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 1 68 0 1 ROP Mí^iD030 FT/H 1 68 4 2 CR 1'1WDO 3 0 API 1 68 8 3 Firs Last Name Service Unit Min Max Mean Nsam Read nq Reacii DEPT FT 9627.5 9730 9678.7:) 206 96 -l . 5 9 ROP Hí^iDO 3 0 FT/H 2.45 42.12 23.0988 146 96 7.5 \~ GR t'-1WD030 ,I\PI 17.63 72.74 34.1484 151 96 7.5 970 ) First Reading For Entire File..........9627.5 Last Reading For Entire File.......... .9730 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/09/26 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name... ... ... ..STSLIB.005 Physical EOF' File Header Service namc........ .....STSLIB.005 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.......03/09/26 Maximum Physical Record..65535 File Type................LO Previous File Name... ....STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 ') header data for each bit run in separate files. 4 .5000 START nEPTH 9703.0 9730.5 STOP DEPTH 10224.0 10252.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOfTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ BOREHOLE l\ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTI! (fT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): t-1UD PH: MUD CHLORIDES (PPM): fLUID LOSS (C3): RESISTIVIT":{ (OH¡V¡jVi) AT TEMPER.i:l.TURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT HA.,'{ CIRCUL.I\TING TERJvlPERATUH.E: HUD FILTRATE AT MT: 09-JUN-03 Insite 4.3 Memory 10252.0 9730.0 10252.0 49.0 90.8 TOOL NUMBER 93091 4.125 8805.0 Flow-Pro 9.00 65. C' 9.5 4900C 7. .000 .000 .000 .0 137.9 .0 ) ) MUD CAKE AT MT: .000 .0 if NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point...... ... .....Undefined Frame Spacing. ................. ...60 .1IN Max frames per record........ .....Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-t.ype...O Name Servj..ce Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/I-! 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Read.ing Reading DEPT FT 9703 10252 9977.5 1099 9703 10252 ROP MWD040 FT/H 1. 35 149.63 50.7137 1044 9730.5 10252 GR MWD040 API 18.9 163.04 32.7652 1043 9703 10224 First Reading For Entire File... .......9703 Last Reading For Entire File...........10252 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.O.O Date of Generation. ......03/09/26 Maximum Physical Record..65535 File Type............ _ . . . LO Next File Name. ........ ..STSLIB.006 Physical EOF File Header Service name... ........ ..STSLIB.006 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.......03/09/26 Maximum Physical Record..65535 file Type................ LO Previous file Name.... ...STSLIB.005 Comment Record FILE HEADER E'ILE NUtvIBER: Rl\í"Ì tv¡WD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUtvlMARY VENDOR TOOL CODE G header data for each bit run in separate files. 5 .5000 ST.l\RT DEPTH STOP DEPTH ) RPD RPM RPS RPX FET GR ROP $ 9889.5 9889.5 98EJ9.5 9889.5 9889.5 10224.5 10252.5 11347.0 11347.0 11347.0 11347 . (I 11347.0 11334.5 11379.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWAEE VEESION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOT'I'OM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE GM EWH.4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) .A'I' TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE,: MUD FILTRATE AT M'I': MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL, STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ........... ...0 Data Specification Block Ty~e.....O Logging Direction................ . Down Optical log depth units..... .... ..Feet Data Reference Point..... ..... ....Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 11-LTUN-03 Insite 4.3 Memory 11379.0 10252.0 11379.0 86.3 93.8 TOOL NUMBER 82758 126589 3.750 8805.0 Flo Pro 8.90 60.0 9.5 55000 5.2 .090 .040 .300 .200 68.0 144.8 68.0 68.0 Name Service Order- Units Size Nsam Re¡=:, COj'2 O£'fset Cr:arlne ~ DEPT FT 4 1 68 0 ROP j\lWD050 FT/I-I 4 1 GO GR MWDOSO API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS ìv¡¡"JD 0 5 0 OI-lMrvl 4 1 68 16 5 ') ) RPM MWD050 RPD MWD050 FET MWD050 OHMM OHMM I-lOUR 1 68 1 68 1 68 20 24 28 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9889.5 11379 10634.3 29é30 9889.5 11379 ROP MWD050 FT/H 1.15 1469.83 102.706 2254 10252.5 11379 GR rvIWD050 API 21.77 168.98 41.6658 2221 10224.5 11334. S RPX MWD050 OHrvIrvI 1. 24 37.63 9.31605 2916 9889.5 11347 RPS MWD050 OHMrvI 1.52 57.14 10.9271 2916 9B89.5 11347 RPM MWD050 OHMM 1. 38 55.05 11. 6221 2916 9889.5 11347 RPD MWD050 OHMM 1. 7 9 53.01 12.3925 2916 9889.5 11347 FET MWD050 HOUR 0.15 19.31 3.93863 2916 9889.5 11347 First Reading For Entire File..........9889.5 Last Reading For Entire File.......... .11379 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/09/26 rvIaximum Physical Record..65535 Fi 1e Type................ LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name. ...... ......LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 09/26 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing LibnŒY. Scienti fic Technical Services Reel Trailer Service name.............LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 03/09/26 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........ ....UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS file