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206-011
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~j - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided I!I IIIlII II III I! III ^ Rescan Needed III !IIIII ll ll III III RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. , ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ /s/ Scanning Preparation _~ x 30 = D + _~ =TOTAL PAGES_~ Q (Count does not include cover sheet) BY: _ Maria Date: LJ /s/ Production Scanning III (IIIII IIIII II III Sta e 1 P nt fr C S d Fil g age ou o m canne e: ~ (Count does include cove sheet) Page Count Matches Number in Scanning Preparation : YES NO BY: Maria Date: ~/as ~ Q /s/ Stage 7 If NO in stage T, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I (III II I II II IIIII ReScanned II I 111111 IIIN II III BY: Maria Date: /s/ Comments about this file: Quality Checked I II I II II II I (III II I P P 10/6/2005 Well History File Cover Page.doc STATE OF ALAS i ALASKAAND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS - FR h 4 2011 1. Operations Abandon LJ Repair Well U Plug Perforations U Stimulate U Alriltteiti. 3 Getteent.Gesegisimi Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extensio❑ 4 C rt a Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re-enter Suspended W 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ . 206 -011 -0 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 I , 50- 029 - 20584 -02 -00 7. Property Designation (Lease Number): • 8. Well Name and Number: ADL0028346 • PBU 16 -06B 9. Field /Pool(s): 4 PRUDHOE BAY, PRUDHOE OIL 10. Present Well Condition Summary: Total Depth measured 12100 feet Plugs measured 11816 feet true vertical 9172.41 feet Junk measured 11862 feet Effective Depth measured 11816 feet Packer measured 6548 11366 11411 feet true vertical 8996.9 feet true vertical 6248 8743 8768 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H -40 32 - 112 32 - 112 1530 520 Surface 2619 13 -3/8" 72# L -80 31 - 2650 31 - 2583.43 4930 2670 Intermediate None None None None None None Production 6697 9 -5/8" 47# L -80 32 - 6729 32 - 6332.66 6870 4760 Liner 5057 7" 26# L -80 6548 - 11605 6248.22 - 8807.55 7240 5410 Liner 4 -1/2" 12.25# L -80 11411 - 12100 8767.56 - 9172.41 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet 410144ED FEB 2 8 Z011 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 25 - 11425 25 - 8708.62 Packers and SSSV (type, measured and true vertical depth) BAKER C -2 ZXP 6548 6248 Packer 7" X 4 -1/2" BKR S -3 11366 8743 Packer 7" X 4 -1/2" HRD ZXP 11411 8768 Packer 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 220 1249 5295 482 Subsequent to operation: 221 1209 5180 422 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 r Servic4 Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil r Ell Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Joe Lastufka Prepared by Joe Lastufka 564 -4091 Printed ■ - Joe l guff( Title Data Manager Signatur: Phone 564 -4091 Date 2/24/2011 nt3DMS FEB 2 4 2011 ci Form 10 -404 Revised 10/2010 ,2 2 1 � Submit Original Only 244. 16 -06B _ 206 -011 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 16-06B 4/16/06 PER 11,837. 11,867. 9,009.59 9,027.8 16 -06B 5/14/07 PER 11,773. 11,783. 8,971.06 8,977.05 16 -06B 5/15/07 PER 11,717. 11,732. 8,937.81 8,946.67 16 -06B 5/15/07 PER 11,755. 11,761. 8,960.32 8,963.9 16 -06B 1/27/11 BPS 11,528. 11,867. 8,831.41 9,027.8 16-068 2/6/11 BPP 11,528. 11,867. 8,831.41 9,027.8 16 -06B 2/7/11 BPS 11,816. 11,867. 8,996.9 9,027.8 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE III III 16 -06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1/26/2011 S***WELL SHUT IN ON ARRIVAL"" *(E - LINE -4.5" CIBP) [ INITIAL T /I /0 =1900/ 1960/ 0 PSI ;INITIAL VALVE POSITIONS: SWAB/WING = CLOSED, SSV/ MASTER/ GAUGES ITO TREE= OPEN `ATTEMPT TO SET 4.5" HES EZ DRILL PLUG AT 11816' MID ELEMENT. ATTEMPTING TO WORK TOOLS DOWN AT 11386'. ** *JOB CONTINUED ON 27- JAN - 2011 * ** 1/27/20111T/I/0= 2050/1960/0 Temp =SI Assist EL as directed. Pumped 5 bbls 60/40 and 291 bbls crude down TBG in unsuccessful attempt to free EL. Wing shut swab shut ssv shut master open casing valves open to gauges Final Whp's =700/ 1700/0 1/27/2011* *JOB CONTINUED FROM 26- JAN - 2011 * ** (E -LINE 4.5" CIBP) 'TOOL SAT DOWN AND AFTER MULTIPLE ATTEMPTS TO BREAK FREE INCLUDING PUMPING 291 BBLS OF CRUDE IN THE WELL WE WERE NOT ABLE ITO MOVE THE TOOL. CHANGE IN PROGRAM AS PER CLIENT REQUEST WITH NEW SET DEPTH = 11526.7' DUE TO STUCK TOOL. TOP OF 4.5" EZ DRILL SVB SQUEEZE PACKER WITH PLUG AT 11526.7'. TAGGED AFTER SET. TUBING ;FREEZE PROTECTED WITH CRUDE. I ** *JOB COMPLETE * ** 2/5/2011 CTU #8, 1.75" coil. Job Scope: Burn over and Push CIBP to bottom. Set second plug for WSO. MIRU CTU. N/U BOPE. PJSM to M/U Weatherford burn over BHA. (Continued on WSR of 02/06/11) 2 /6 /20111(Continued from WSR of 02/05/11) CTU #8, 1.75" coil, Job Scope: Burn over CIBP and push to bottom. Set second !CIBP. 'Continue to M/U CTC. Pull / press test. M/U Weatherford burnover BHA. RIH with burnover BHA. Circ returns to OT Tank thru choke. Dry tag plug at 11524'. Time drill and see free fall at 11527' RIH and sat down @ 11530' stack 5k down wt and could not stall motor or run deeper. Pooh. recover metel plug parts, rubber and a few small rocks (1/4" x 1/4"). RIH w/ motor and 3.7 „ cowboy mill w/ choke closed @ 3800' whp !climbed to 800 psi and fell to zero indicating fluid moving by plug. Dry tag @ 11535. Icome online down coil.. Jar down 4 times on fish with no movement. Started millin on fish and pushed it easily to bottom at 11862'. R eam and drift liner for next CIBP. I POH to surface. i Continued to WSR of 02/07/11) 2/7/2011 (Continued from WSR of 02/06/11) CTU #8, 1.75” Coil, Job Scope: Memory Log tie -in and drift liner. Set CIBP at 111816'. Continue POH. Freeze protect coil. L/O Milling BHA. Cut 50' coil for chrome. M/U ISWS Memory logging BHA and 3.69" drift. Log © 45 fpm from 11200 to btm @ 1 11860. PUH cont log © 45 fpm. paint referance flag at 11750. cont log to 11200. pooh. Good data +4' correction. RIH w/ MHA and HES 3.68" CIBP. Correct depth to flag. Set Halco CIBM with center of element at 11816'. Tag CIBP on depth. POH. Secure well and Rig down CTU. ** *Job Complete * ** FLUIDS PUMPED BBLS 233 60/40 METH 1 DIESEL 291 CRUDE 380 1% KCL 905 TOTAL TREE = 5-1/8" FMC WELLHEAD = 13 -3/8" FMC AFETY Nil: *** 4 -1/2" CHROMETBG*"* - EL ACTUATOR = AXSON 6 S KB. ELEV = 72.0' BF. ELEV = Q _ NA ` , 1 2200' H4 -1/2" HES X NIP, ID = 3.813" I KOP = 4300' GAS LIFT MANDRELS Max Angle = 63° @ 7748' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum MD = 11591' 5 3479 3479 1 MMG DOME RK 16 06/07/08 Datum TV D = 8800' SS 4 6012 5806 34 MMG DOME RK 16 06/07/08 3 8292 7284 63 KGB2 DOME BK 16 06/07/08 113 -3/8" CSG, 72 #, L -80, BUTT, ID = 12.347" H 2650' I 2 9957 8074 62 KGB2 DMY BK 0 03/29/06 1 11277 8696 59 KGB2 SO BK _ 22 06/07/08 6548' I — BKR C-2 ZXP LNR TOP PKR Minimum ID = 3.725" @ 11413' w/ 11.6'TIEBACKSLV, ID= 6.31" 4 -1/2" HES XN NIPPLE 6566' H9-5/8" X 7" BKR HMC LNR HGR, ID = 6.30" 1 MILLOUT WINDOW (16 -06B) 6712' - 6729' 1 {WHIPSTOCK (03/10/06) I — I 6712' I EZSV (03/09/06) I — I 6729' T , m 9-5/8" CSG, 47 #, L -80, BUTT XO TO SOO95 H 8438' • ►•ii• 19 -5/8" CSG, 47 #, L -80, SOO95, ID = 8.681" I 9537' ►� A 10000' H ESTIMATED TOP OF CEMENT I • • Z = ► ,� '� • i I 11345' H4-1/2" HES X NIP, ID = 3.813" I « � ■ i * /. • • i Ne ►r14 11366' II - 7" X 4 -1/2" BKR S -3 PKR, PERFORATION SUMMARY ■• . • j ID = 3.875" REF LOG: SPERRY DGR EWR 03/21/06 /•�•j i► : , * • R 1 11 390 1 HES X NIP, ID = 3.813" I ANGLE AT TOP PERF: 54° @ 11704' 1�•+ •� • Note: Refer to Production DB for historical perf data �" !1 • �1 • 11411' I- 7" X 4 -1/2" HRD ZXP LTP SIZE SPF INTERVAL Opn /Sqz DATE , �i 2 -7/8" 6 11717 - 11732 0 05/15/07 . ∎ � w/ 5" X 16' TBS, ID = 3.875" 2 -7/8" 6 11755 - 11761 0 05/15/07 ! ! .4 11413' 1-14 -1/2" HES XN NIP, ID = 3.725" I • 2-7/8" 6 11773 - 11783 0 05/15/07 • 1 r 3-3/8" 6 11837 - 11867 0 04/16/06 .4 n 11425' I - 1(2" WLEG, ID = 3.958" I • � �� ■ 11437' I — 7" X 4 -1/2" FLEX -LOK 4 -1/2" TBG, 12.6 #, 13CR -80, — 11425' � .10 LNR HGR, ID = 4.540" VAM TOP, .0152 bpf, ID = 3.958" 1 17" LNR, 26 #, L -80, BTC-M, .0383 bpf, ID = 6.276" 1-1 11605' 1 g .-,, 1 11816' 1-14 -1/2" HES EZ DRILL PKR (02/07/11)1 'FETID I-1 12017' , ? I 4 -1/2" HES EZ DRILL PKR (MILLED . ' •f•f••• i I eb(p� 1 & PUSHED TO BTM ON 02/07/11) 14-1/2" LNR, 12.25 #, L -80, HY DRILL 521, .0152 bpf, ID= 3.958 H 12100' Att. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT 05/13/81 MWG ORIGINAL COMPLETION 06/05/07 JGM/PJC DRLG DRAFT CORRECTIONS WELL: 16 -06B 05/18/91 N28E RWO 06 /08 /08 KSB/TD GLV C/O (6/7/08) PERMIT No: X 2060110 02/25/01 N3ES CTD SIDETRACK (16 -06A) 09/28/10 KL /PJC PERF CORRECTIONS AR No: 50- 029 - 20584 -02 04/05/06 N2ES SIDETRACK (16 -06B) 02/12/11 RRW /PJC MILL EZ/ SET EZ PKR (02/07/11) SEC. 24, T10N, R15E 1893' FNL & 1121' FWL 06/05/07 JGM/PJC DRLG DRAFT CORRECTIONS _ I BP Exploration (Alaska) 12/30/10 Schkunberger NO. 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503- 2838e1 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 / r 6 Anchorage, AK 99501 6 1 � Job # Log Description Date BL Color CD 0-050.) BL65 -00011 MEM DDL 12/18/10 1 1 3B AY1M -00056 PROD PROFILE aoc -, 11/27/10 1 ' 4„ 60 1 11 -12 BCZ2 -00033 PROD PROFILE ; C — ' 12/06110 1 # 'Wadi 1 01 -25 BG4H -00022 INJECTION PROFILE FIX:FRIR/I11111 Oi°i2, 1 04-24 AY1M -00058 PROD PROFILE • - • P2-16 B5JN -00077 F1 1 A-41 BCZ 2 - 00030 IEMIIIIIM ISI _ LZ; 1 04-08 BCRJ- 000566 C,#1XN[h9,` {�rt�• ijfillre= I � ' ,. , e irl 1 01 -24A BBSK -00043 11,`IIIXHIP1,19a•141441•In L!r ` v7•Mit 1 04 -10 AV1H -00051 • PR• 1 (J / • 12/07/10 1 1 15-260 BD88-00080 MEM PROD PROFILE . e it 12/12/10 1 • , 1 • 2- 288/0 -19 BCRJ -00055 (u:lel•7Ja. /214110 • — •!•T. , , kille jS 1 07-23B AY1M -00056 MGM C'D - ' 11/28/10 y o( . a 1 1 02 -21A BBSK -00042 SCMT 64 — 0 9 11/23/10 • 1 1 02 -22B BL65 -00006 SCMT • 12/11/10 4 '' 1 1 18 -12B BBUO -00029 SCMT fin- l • — 08 /30/10 6 1 1 P2 -16 BSJN -00077 USIT il S ' , (a'� 11/28/10 1 1 7'...) 05-27B BAUJ-00049 MCNL :30 • - ( 09/18/10 1 OS 1 16-06B BBSK-00037 RST _ • -- 11 /15/ I 1 1 G-09B BG27 -00005 RST O ■ ∎ • • 09/20110 1 • 1 E -3411 8088 -00050 MCNL a -( A 09/28/10 1 _ 1 W -219 BGZ7 -00012 CH EDIT PDC -GR USIT — • 11/22/10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ::)'L:,8' MAPs41Oi • i 11/01/10 sdiumbBPvtP NO. 5637 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shertzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 0 Log Description Date BL Color CD MPG -13 BCRJ -00038 X•FLOW CHECK/IBPSET RECORD .– 09115/10 1 1 MPS -43 gYKP -00104 SCMT 08 126 110 1 1 Pt -09 BCRJ -00036 PRODUCTION PROFILE 09/12110 1 W -37A BD88.00048 MEM PRODUCTION PROFILE 09/11/10 im W -31A AZ2F -00064 MEM PRODUCTION PROFILE 09/16/10 ODUCTION 06 -19A AWJI -00112 MEM PRODUCTION PROFILE 09119110 12 -OSALI BAUJ -00050 MEM PR PROFILE 09/20/10 P1 -16 BCRJ -00049 INJECTION PROFILE 10106/10 04 -03 BCRD -00059 PRODUCTION PROFILE 09/27/10 P -03A AZ2F -00065 MEM INJECTION PROFILE / 10106/10 G -19B AWJI -00114 MEM PRODUCTION PROFILE 10/04/10 Y -36 BD88.00058 MEM GLS – 10 /09/10 3- 031J -33 BCZ2 -00025 PRODUCTION PROFILE 09111110 1 1 L -214A BAUJ -00043 MEM INJE( _09/13110 1 1 H -01A AWJI -00118 MEM PRODUCTION PROFILE 1/14/10 1 1 16 -068 BBUO -00023 PRODUCTION PROFILE BP CORRECTION ^5108110 1 1 H -38 AZ2F -00068 MEM PRODUCTION PROFILE — ,0116110 1 1 P2-44 BCRD -00063 PRODUCTION PROFILE 10/15110 1 1 B -136 AYKP -00091 CH EDIT PDC -GR ('C'T) .i 07102110 �p 1 02 -228 10AKA0069 OH MWD /LWD EDIT 07107110 2 1 W -19B BCRJ -00034 CH EDIT PDC -GR (SCMT) 09/07/10 1 1 OWDW -SE APBPD3WELL RST REDO - PRINTS 09123110 1 OWDW -NW BBSK -00033 RST 09/24110 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 Zulu i' �OT"i� osn eat o • • l~ Scbtwnber~r Alaska Data & Consulting Services 2525 Gambell Street, Su0e 400 Anchorage, AK 99503-2a38 ATTN: Beth Well Job S N0.5545 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD E-19B BBUO-00015 STATIC BOTTOM & TEMP SURVEY 04/03/10 1 1 H-30 BCRO.00020 PRODUCTION PROFILE - 05/10/10 1 1 P2-34 B3S0-00071 STATIC PRESSURE SURVEY 05/15/10 1 t P2-34 B3S0-00073 IPROF WITH STATIC SURVEY 05/19/10 1 1 V-OS AWJI-00090 MEM CBL ? 05/24/10 1 1 P2-17 16-068 BCRC-00017 BBUO-00023 PRODUCTION PRO N-E PRODUCTKN PROFILE OW01/10 06/06/10 1 1 1 1 S-21 Z-46A BBSK-00018 BAUJ-00027 PRODUCTION PROFILE MEM CBL 06/03/10 06/01/10 1 1 1 1 V-05 BD88-00018 MEM LDL 06/08/10 1 1 01-26A B14B-001 D6 SCMT 06/10/10 1 1 B-13A 1-27/P-20 BBUO.00019 AYKP-00065 USR RST & FL RECOR 05/28/10 D6/O6/10 1 1 1 1 1-27/P-20 AYKP-00085 PRODUCTION PROFILE 06/06/10 1 1 MPF-82A BAUJ-00010 MCNL 04/06/10 1 1 Z-16A E-15D BCUE-DD005 AWJI.00081 CN EDIT PDC MEM CORR CATION MCNL 04/06/10 04/03/10 1 1 1 OS-19 BBKA-D0013 RST - 03/14/10 1 1 F•27A AYKP-00078 RST 03/17/10 1 1 J-18A BD88-00010 MCNL 04!18/10 1 1 ~.:.. - .,c ..c.,c.r , o. amrvevu ..rvu nc r urnnrvu vrvc r.vr r cHa.n ~ ~: BP Exploration (Alaska) Inc. Petrotechnicat Data Center LR2-1 900 E. Benson BIvA. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 .1~_)~ 1ld ~~ ~Q`~) .. &` ~' ~ ' ?~ ~~ . k ~~ ~ ' ' ~ r % ! .r # S '' .~, „ r.;~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc W~L1.. ~.®~ T12A1~1SI~1'1"g'AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 16-06B July 1, 2008 AK-MW-4265592 16-06B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-20584-02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-20584-02 Digital Log Images: 50-029-20584-02 ~~~NE® JUL ~ 5 200 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _. BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~o~ -~~l ~ 1~~d9 t` ~~ ~ DATA SUBMITTAL COMPLIANCE REPORT 6/16/2008 Permit to Drill 2060110 Well Name/No. PRUDHOE BAY UNIT 16-066 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20584-02-00 MD 12100 TVD 9172 Completion Date 4/16/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~~ Mud Log No Samples No Directional Su DATA INFORMATION Types Electric or Other Logs Run; MWD DIR / GR, RES / GR, MWD D1R / GR /RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments -- ---------------- D Asc Directional Survey --------- 6694 12100 Open 4/17/2006 ', C Las 15433~duction/Resistivity 6550 12100 Open 9/17/2007 Field Data, LAS, GR w/ EMF Graphics LIS~/erification 6564 12112 Open 5/19/2008 LIS Veri, GR, ROP, RPX, / RPS, RPM, RPD, FET / C Lis 16258 Induction/Resistivity 6564 12112 Open 5/19/2008 LIS Veri, GR, ROP, RPX, ', RPS, RPM, RPD, FET Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~N Chips Received? -~..._ QT'I~ Analysis 1`''j~L Received? Comments: Compliance Reviewed By: ~ Date: ____w^^--~~11 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~/ N WELL LOG TRANSMITTAL To: State of Alaska May 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~` Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 16-06B AK-MW-4265592 1 LDWG formatted CD rom with verification listing. API#: 50-029-20584-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~<,: ~~'Y ~~; ~ - ~~~; i Datc: ~~;~'t~ Signed: Y V ~ ~ WELL LOG TRANSMITTAL To: State of Alaska March 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1 J-102+L 1+L2+L2PB l+L2PB2+PB l+pB2+PB3 AK-MW-4559176 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 1J-102+L 1+L2+L2PB1+L2PB2+PB 1+PB2+PB3: 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23317-00,60,61,73,74,70,71,72 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23317-00,60,61 Digital Log Images 1 CD Rom 50-029-23317-00,60,61,73,74,70,71,72 Some sections of this well have no TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 690 ~ ~.~ ~ .+: Anclragea~~' Date: ' ~~~' ~ ~ ~"~?= Signed: ~ (J~C., poC~ -./l d ~ l ~ oil ~ O~,Co~UC~-lea ~ ~ X64(-~ c~SC aCS(o-lt ~ ,~~~~V~ Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have any questions, please contact 1)ougias llortcn at the rli~ at oo4-4y i ~ Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: u+KC ~svab 06-06B ~ aoS-c~l`6 ~ t-5 ya4 06-06BPB1 13-31 A - (~SCaoS I(o~ '~ ~~2'~ 14-11 A `~ aos X86 ~S~a 14-11AP61 14-21A u=~ao5 -+o~ ~ i5 ~a31 15-39A ao(o-o~'Ir ~ rQ'!3a 16-14Ba0(e-0~3 M ~Sy3y c-o36 aos ~~~ ~ ~s~s C-1 oA aos X37 ~' +5 ~a~ J-17C r~OfS-o~s2 ~' +5`s3~ NGI-07A u=eacx.-+aL +'" 15Kc3~1 r, ~ ,t ~ ~/~ f `~ J Please ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~, r~ n rk rtl ~,~~f ~R ~. ~-s ~.~?~I~c~~4e Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 ~~ ~ECEIV~Q STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM ~ LION', ` REPORT OF SUNDRY WELL OPERATIONS MAY ~ 5 ~0~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ 8 I ~nQ ~~~~ °° -~FHFS'St6r Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time ExteA~i~fl ~~~ Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended VVell 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 206-0110 3. Address: P.O. Box 196612 Stratigraphic Service "~' 6. API Number: Anchorage, AK 99519-6612 50-029-20584-02-00 7. KB Elevation (ft): 9. Well Name and Number: 66.5 KB PBU 16-06B - 8. Property Designation: 10. Field/Pool(s): ADLO-028346 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12100 feet Plugs (measured) None true vertical 9172.41 - feet Junk (measured) None Effective Depth measured 12017 - feet true vertical 9120 - feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 94# H-40 Surface - 80' Surface - 80' 1530 520 Surface 2650' 13-3/8" 72# L-80 Surface - 2650' Surface - 2650' 5380 2670 Production 6712' 9-5/8" 47# L-80 Surface - 6712' Surface - 6385' 6870 - 4760 Liner 5057' 7" 26# L-80 6548' - 11605' 6248' - 8874' 7240 5410 Liner 689' 4-1/2" 12.6# L-80 11411' - 12100' 8768' - 9172' 8430 7500 Perforation depth: Measured depth: 1 1704 - 11854 _ _ True Vertical depth: 8930 - 9092 _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 Surface - 11425' Packers and SSSV (type and measured depth) 7"x4-1/2" BKR S-3 11366' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 59 177 826 0 420 Subsequent to operation: 58 131 820 0 434 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ WINJ ~ WDSPL 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: Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ,,/l Phone 564-4944 Date 5/25/2007 Form 10-404 Revised 04/2006 ~ ` -' ~ ~ ~ ~t !~ Submit Original Only r • 16-06B DESCRIPTION OF WORK COMPLETED NRW O OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/12/2007""~~ WELL FLOWING ON ARRIVAL ""'* RIH W/ 2-7/8" DMY GUN / SB. TAG TD («3 11927 SLM (~ 73' OF RATHOLE) ; NO SAMPLE RECOVERED '.***WELL TURNED OVER TO DSO"** 5/14/2007 INITIAL T/I/O = 350/2000/0 PERFORATED INTERVAL 11,760-11,770'. 2-7/8" GUN w/ 2906 PJ OMEGA CHARGES, 6 SPF, 60 DEG PHASING USED GAMMA RAY TO CORRELATE TO MWD LOG DATED 21-MAR-2006. """JOB CONTINUED"" 5/15/2007':""*CONTINUED FROM PREVIOUS DAY**" ;PERFORATED: 11742'-11748' '' 11704'-11719' °2-7/8" GUN w/ 2906 PJ OMEGA CHARGES, 6 SPF, 60 DEG PHASING `DEPTH CORRECTED TO SPERRY MWD LOG DATED 3-21-06 ''***JOB COMPLETE**" FLUIDS PUMPED BBLS 0 None STATE OF ALASKA ALAS~IL AND GAS CONSERVATION CO SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1 b. Well Class: ®Development ^ Exploratory D Stratigraphic D Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/16/2006 12. Permit to Drill Number 206-011 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/11/2006 13. API Number 50-029-20584-02-00 4a. Location of Well (Governmental Section): Surface: 1893' FNL 1121' FWL SEC 24 7. Date T.D. Reached 3/21/2006 14. Well Name and Number: PBU 16-06B , , . , T10N, R15E, UM Top of Productive Horizon: 718' FSL, 595' FWL, SEC. 18, T10N, R16E, UM g• KB Elevation (ft): 66.5' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 843' FSL, 773' FWL, SEC. 18, T10N, R16E, UM 9. Plug Back Depth (MD+TVD) 12017 + 9120 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 719911 y- 5929055 Zone- ASP4 10. Total Depth (MD+TVD) 12100 + 9172 Ft 16. Property Designation: ADL 028346 TPI: x- 724585 y- 5931804 Zone- ASP4 Total Depth: x- 724759 Y- 5931935 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Surve Y ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR, RES / GR, MWD DIR / GR /RES ASING, LINER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 80' Surface 80' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2650' Surface 2650' 17-1/2" 3000 sx Fondu, 400 sx Permafrost 9-5/8" 47# L-aoisoo-ss Surface 6712' Surface 6385' 12-1/4" 500 sx Class 'G' 7" 26# L-80 6548' 11605' 6248' 8874' 8-1/2" 170 sx Class 'G' 4-1/2" 12.6# L-80 11411' 12100' 8768' 9172' 6-1/8" 130 sx Class 'G' 23. Perforations open to Production (MD +TVD of Top and B tt I S " " 24. TUBING RECORD o om nterval, ize and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 11425' 11366' MD TVD MD TVD 11824' - 11854' 9002' - 9020' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: April 18, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 5/12/2006 Hours Tested 5 PRODUCTION FOR TEST PERIOD • OIL-BBL 52 GAS-MCF 134 WATER-BBL 390 CHOKE SIZE 83 GAS-OIL RATIO 2,582 Flow Tubing Press. 20 Casing Pressure 1,802 CALCUTATED 24-HouR RATE OIL-BBL 250 GAS-MCF 645 WATER-BBL 1,870 OIL GRAVITY-API (CORK) 27- CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ---~ ~~ ~ None ~ ~ ~~, ~ ~~~~5 g~~ f~A!` ~ .` 20()~ ~~ v ~YJi/~l~ C~7~Z ~ 6.3~fs'f~/,b ~1~ -.~ Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ OMTIhUED ON REVERSE $IDE 28. ~ GEOLOGIC MARKE 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top HRZ 11330' 8724' None Base HRZ 11667 8909' LCU / 45P 11704' 8930' 44N 11734' 8948' 42N 11770' 8969' 41 P 11823' 9001' 31 P 11860' 9024' 27P 11922' 9061' HOT 11944' 9075' 26P 11978' 9096' 25N 12005 9003' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. h ds~ /' ~ Title Technical Assistant Date Signed Terrie Hubble ~ ~(jj ' ` ble, 564-4628 PBU 16-066 206-011 Prepared ey Name/Number: Terrie H ub Well Number Drilling Engineer: JeffCut/er, 564-4134 Permit No. /Approval No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 16-06A Common Name: 16-06A Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 3/10/2006 FIT 6,740.0 (ft) 6,408.0 (ft) 9.00 (ppg) 1,000 (psi) 3,996 (psi) 12.00 (ppg) 3/19/2006 FIT 11,625.0 (ft) 8,874.0 (ft} 8.50 (ppg} 525 (psi) 4,443 (psi) 9.64 (ppg) :~ Printed: 4/14/2006 11:09:11 AM • • BP EXPLORATION Page 1 of 10 Operatiotns Sutlntmary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date I From - To I Hours I Task I Code ~ NPT I Phase Description of Operations 3/6/2006 12:30 - 00:00 11.50 MOB P 3/7/2006 00:00 - 01:00 1.00 MOB P 01:00 - 02:00 1.00 WHSUR P 02:00 - 03:00 1.00 WHSUR P 03:00 - 06:00 I 3.001 WHSUR I P 06:00 - 07:30 I 1.501 WHSUR I P 07:30 - 08:00 0.50 WHSUR P 08:00 - 12:00 4.00 WHSUR P 12:00 - 14:00 2.00 WHSUR P 14:00 - 15:30 1.50 WHSUR P 15:30 - 16:00 0.50 BOPSU~P 16:00 - 16:30 0.50 BOPSU P 16:30 - 00:00 7.50 BOPSU P 3/8/2006 100;00 - 04:00 I 4.00 I BOPSUF~ P 04;00 - 06:00 I 2.001 PULL I P 06:00 - 07:00 1.00 PULL I P 07:00 - 15:30 8.50 PULL P 15:30 - 16:30 I 1.00 PULL ( P 16:30 - 20:30 4.00 PULL P 20:30 - 22:00 I 1.501 PULL I P 22:00 - 22:30 0.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 13/9/2006 100:00 - 01:00 I 1.001 CLEAN I P 01:00 - 02:30 I 1.501 CLEAN ( P 02:30 - 06:30 4.00 CLEAN P 06:30 - 08:00 1.50 CLEAN P 08:00 - 10:30 2.50 CLEAN P 10:30 - 11:30 1.00 CLEAN P 11:30 - 15:00 3.50 DHB P PRE Move rig over well. PRE Move rig over well and prepare for rig accept at 01:00 hrs on 03/07/06. DECOMP Pre-Spud Meeting. Install 2nd annular valve DECOMP Rig up lubricator. Pull back pressure valve Tubing = 50 psi Annulus = 10psi. DECOMP Rig up circulating lines. Displace freeze protect with seawater through choke to cuttings tank. DECOMP Dry rod BPV. Attempt to test from below to 1000psi, no test. Swap hoses and pump from the top to clean out debris. Swap hoses back and test from below to 1000psi. Good test DECOMP Rig down circulating lines DECOMP Nipple down Tree & adapter DECOMP Nipple up BOP DECOMP Rig up lubricator extension. Rig up DSM lubricator. Trouble pulling the BPV made 2 runs Rig down DSM lubricator and extension. Clear Floor DECOMP Dry rod tree test plug DECOMP Rig up test joint DECOMP Test BOPE 250psi low 3500psi high. Annular 2500psi. Test witnessed by AOGCC rep. Jeff Jones and BP Rep Blair Neufeld and NAD J. Henson. DECOMP Test BOP 250psi low 3500psi high. Annular 2500psi. Test witnessed by AOGCC rep Jeff Jones & BP Rep Blair Neufeld and NAD J. Henson. DECOMP Pull Tree test plug. PJSM Latch on to and pull tubing hanger. Purge chemical injection line with diesel. Difficult to purge line completely -could not pump freely thru line but may have got enough diesel in line to displace its capacity of -0.4 bbls. DECOMP Circulate, Pump dry job.Rig up 5 1/2" tubing equipment & spooling unit. Lay down hanger and landing joint. DECOMP Lay down 5 1/2" 17# tubing with injection line from 7000' to 2738' DECOMP PJSM Cut injection line. Change out control line spool. DECOMP Lay down 5 1/2" 17# tubing with injection line from 2738' to surface DECOMP Rig down spooling unit. Rig down 5 1/2" handling equipment. Clear and clean floor DECOMP Make up test joint. Set test plug DECOMP Test top and bottom rams & related valves with 4" test joint. 250psi low 3500psi high. Annular tested to 250psi low and 2500psi high. Test witnessed by BP Rep Blair Neufeld. NAD J. Henson DECOMP Pull test plug. Install wear ring and blow down surface equipment DECOMP Make up BHA #1 with mills, collars and HWDP DECOMP Run in hole picking up drill pipe from pipe shed. 165k up 150k do DECOMP Circulate 2 x bottoms up @12 BPM 1650psi. Pump dry job DECOMP POOH 6993'-963'. Change out handling equipment DECOMP POOH with BHA from 963' DECOMP PJSM Rig up E-line and run EZSV bridge plug with Gamma Printed; 4/14/2006 11:09:17 AM BP EXPLORATION. Page 2 of 10 Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT :Phase Description of Operations 3/9/2006 11:30 - 15:00 3.50 DHB P DECOMP and CCL log. Attempt to set EZSV -misfire. 15:00 - 19:00 4.00 DHB N DFAL DECOMP Pull out run #1. Troubleshoot at surface. Found short in GR tool. Change out tools and run in hole with EZSV and CCL log (no gamma ray) 19:00 - 20:30 1.50 DHB P DECOMP Set bridge plug with top at 6728' - 5' above coupling. 20:30 - 21:30 1.00 DHB P DECOMP Stage up pump to 3500psi casing test. Hold and chart for 30 mintutes. Blow down surface equipment 21:30 - 00:00 2.50 STWHIP P WEXIT PJSM MAke up BHA #2 Whipstock assembly with MWD. Orient and upload MWD tools. 3/10/2006 00:00 - 03:00 3.00 STWHIP P WEXIT Upload and pulse test MWD, Make up remainder of BHA 03:00 - 03:30 0.50 STWHIP P WEXIT Change out handling equipment. RIH 1029'-1688' 03:30 - 04:00 0.50 STWHIP N RREP WEXIT Repair blower motor on #1 SCR 04:00 - 06:30 2.50 STWHIP P WEXIT Run in hole with BHA #2,Whipstock assembly. Fill every 3000' 06:30 - 07:30 1.00 STWHIP P WEXIT Service top drive. Lubricate rig. Install blower hose. 07:30 - 08:30 1.00 STWHIP P WEXIT Orient whipstock to 50 deg left. 165k up 150k do Tag EZSV @6734' Set bottom trip anchor with 15k dn. Pick up 10k over to verify. Set down and shear bolt with 25k dn. Pick up and work pipe free rotating weight 155k. Top of window 6712' bottom of window 6729' 08:30 - 09:30 1.00 STWHIP P WEXIT Pump 40 bbl his vis spacer then displace the system to 9.Oppg LSND milling mud. 550gpm @1300psi 160k up 150k do 155k rotating. 5k ft/Ibs off bottom and 7-11 k ft/Ibs.on bottom 09:30 - 14:00 4.50 STWHIP P WEXIT Milling from 6712'-6729' then formation to 6740'. 160k up 150k do 155k rotating. 5k off bottom torque and 7k on bottom. 14:00 - 15:00 1.00 STWHIP P WEXIT Work window clean. Pump 20bb1 hi-vis sweep. Circulate bottoms up with 510gpm @1250psi. Pull into casing Mud weight in and out 9.Oppg 15:00 - 16:00 1.00 STWHIP P WEXIT Perform FIT to 12.0 ppg equivalent mud weight. =1000psi@6383TVD Monitor well. Pump dry job 16:00 - 17:00 1.00 STWHIP P WEXIT Cut drilling line 17:00 - 19:00 2.00 STWHIP P WEXIT POOH 6695' to 1007' stand back BHA to 821' 19:00 - 22:00 3.00 STWHIP P WEXIT Monitor well @BHA. Lay down BHA from 821' to 76' Download MWD tool. Lay down MWD and mills. (mills in gauge) clear floor 22:00 - 22:30 0.50 STWHIP P WEXIT Service wear ring 22:30 - 23:30 1.00 STWHIP P WEXIT Rig up and flush stack. Install wear ring 23:30 - 00:00 0.50 STWHIP P WEXIT PJSM Make up BHA to (i1' 3/11/2006 00:00 - 01:30 1.50 STWHIP WEXIT Upload and shallow pulse test MWD. PWD failed test and required changing. 01:30 - 05:30 4.00 STWHIP N DFAL WEXIT Touble shoot and change out PWD tool 05:30 - 06:00 0.50 STWHIP WEXIT Make up remaining BHA, Jars and HWDP. 06:00 - 10:30 4.50 STWHIP WEXIT Run in hole 342' to 5975' picking up pipe from pipeshed. Fill pipe every 3000'. 10:30 - 11:30 1.00 STWHIP WEXIT Service top drive, crown and drawworks. Install blower hose and fill pipe. 11:30 - 12:30 1.00 STWHIP WEXIT RIH 5975' to 6686' then orient toolface to 50deg left of highside. Slide through window at 6729' with no problems. Tag bottom @6740' and perform slow pump rates. 145k up 130k down 135k rotating. 12:30 - 00:00 11.50 DRILL INT1 Drill 8 1/2" hole 6740' to 7104'. AST 4.74hrs /ART 2.30hrs. 145k up 135k down torque off bottom 4k and on bottom 5-6k 451gpm @1650psi Printed: 4/14/2006 11:09:17 AM BP EXPLORATION Page 3 of 1D .Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task ..Code NPT Phase Description of Operations 3/12/2006 00:00 - 00:00 24.00 DRILL P INT1 Drill 8 1/2" hole 7104' to 8365'. 135k up 130k down 140k rotating. Torque off bottom 5k. On bottom 6-8k. 480gpm@1920 psi on bottom & 1780 psi off bottom. Mud wt in and out 9.1 ppg 3/13/2006 00:00 - 12:30 12.50 DRILL P INT1 Drill 8 1/2" hole 8365' to 9010'. 135k up 130k down 140k rotating. Torque off bottom 5k. On bottom 6-8k. 525gpm@2680 psi on bottom & 2500 psi off bottom. Mud wt in and out 9.2ppg 12:30 - 13:30 1.00 DRILL P INT1 Circulate bottoms up /Trouble shoot Mud Pump #1 13:30 - 15:00 1.50 DRILL N SFAL INT1 Monitor well .Static. Mud wt in and out 9.2ppg POOH 9010'-6592'. 25k overpull with occasional 50k up to shoe. Service topdrive and lubricate rig 15:00 - 18:30 3.50 DRILL N SFAL INT1 Replace Fluid end on mud pump #1 cylinder #2. Test pump to 4000psi 18:30 - 20:00 1.50 DRILL P INT1 Mad pass log with MWD from 6587-6838, 200 to 250 ft/hr Slide through window without problems. 20:00 - 21:00 1.00 DRILL P INT1 Run in hole from 6836' to 9013' No fill on bottom 21:00 - 00:00 3.00 DRILL P INT1 Drill 8 1/2" hole 9013' to 9110'. Mud wt in and out 9.3ppg. 170k up 135k down rotating wt 150k. Torque off bottom 6-7k on bottom 7k 3/14/2006 00:00 - 00:00 24.00 DRILL P INT1 Drill 8 1/2" hole from 9110' to 10230'. AST = 4.32 hrs, ART 12.90 hrs. UWT = 185K, DWT = 135K, RWT = 155K. Torque = 7/8K @ 80 rpm. WOB = 8K. Mud weight in and out = 9.1+. 3/15/2006 00:00 - 08:00 8.00 DRILL P INT1 Drill from 10230' to 10604'. ART = 6.54 hrs, UWT = 200K, DWT = 130K, RWT = 160K. Torque = 7/8K @ 80 rpm. WOB = 8/10K. Pump @ 525 gpm @ 2850 psi. Mud weight in and out = 9.1+ PPg• 08:00 - 14:00 6.00 DRILL P INT1 Tight hole and packing off. Hole packed off while reaming before connection was made. Pump @ 262 gpm @ 970 psi. Unable to pump @ full rate. High torque. Work pipe from 10510' to 10604' & increase pump rate until pipe is free up & down. 14:00 - 00:00 10.00 DRILL P INT1 Drill from 10604' to 10978'. AST = 1.67 hrs, ART = 6.35 hrs. UWT = 200K, DWT = 130K, RWT = 165K. Torque on & off bottom = 8/9K @ 80 rpm. Pump @ 534 @ 2950 psi. Mud weight in & out = 9.2 ppg. 3/16/2006 00:00 - 03:00 3.00 DRILL P INT1 Pump 14 ppg spike fluid and weight mud system up to 10.9 ppg. Pump @ 336 gpm while rotating & reciprocating. 03:00 - 21:30 18.50 DRILL P INT1 Drill ahead from 10978' to 11605' TD as per Geologist. AST = .68 hrs, ART = 5.78 hrs. UWT = 200K, DWT = 132K, RWT = 165K. Pump @ 502 gpm @ 3800 psi on bottom & 3620 psi off. WOB = 8/11 K. Torque = 9000 to 10000 on & off bottom @ 80 rpm. 21:30 - 00:00 2.50 DRILL P INT1 Circ up sample for Geoligist @ 11605'. Pump @ 500 gpm @ 3600 psi. Pump high vis sweep & CBU. Mud weight in & out = 10.9 ppg. 3/17/2006 00:00 - 01:30 1.50 DRILL P INT1 Monitor well, blow down top drive. POH from 11605' to 10465', pulling tight. UWT = 250K, DWT 120K. Screw in with top drive. Mud weight in & out = 10.9 ppg. 01:30 - 04:30 3.00 DRILL P INT1 Break circ, work & ream tight hole from 10465' to 10510'. Pump @ 250 gpm @ 700 psi. Rotate @ 80 rpm, torque = 8000 to 15000. Rotating up @ 160K, down @ 120K. Make connection & ream from 10510' to 10604'. Stage pumps up to 500 gpm @ 3800 psi. Printed: 4/14/2006 11:09:17 AM • BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/17/2006 04:30 - 07:00 2.50 DRILL P INT1 Pump high vis sweep &circ past BHA. Rack back 1 stand, ream and work tight hole from 10510' to 10417'. packing off from 10465' to 10430'. Reduce pump rate to 245 gpm @ 1250 psi. 07:00 - 09:00 2.00 DRILL P INT1 CBU, work pipe from 10324' to 10230'. Pump @ 510 gpm @ 3815 psi, reciprocate pipe, rotate @ 100 rpm. 09:00 - 12:00 3.00 DRILL P INT1 POH from 10324' to 8700'. UWT = 200K, max UWT = 250K, DWT = 130K. 12:00 - 13:30 1.50 DRILL P INT1 RIH from 8700' to 11605'. Hole in good shape. 13:30 - 19:00 5.50 DRILL P INT1 Pump sweep and circ, 465 gpm @ 3390 psi. UWT = 200K, DWT = 135K, RWT = 162K. Reciprocate pipe, rotate @ 100 rpm, torque = 9K. Circ until clean. Pump & spot liner running pill in open hole. Monitor well, pump dry job. Blow down top drive. 19:00 - 21:00 2.00 DRILL P INT1 POH from 11605' to 9 5/8" casing window @ 6712'. UWT = 215, max pull = 240K. 21:00 - 22:00 1.00 DRILL P INT1 Clean rig floor. Remove top drive blower hose. Service top drive. 22:00 - 00:00 2.00 DRILL P INT1 POH from 6712' to 342'. 3/18/2006 00:00 - 04:00 4.00 DRILL P INT1 Monitor well. L/D BHA from 342'. Flush tools with water. Down load MWD. Lay down HWDP, jars, flex collars, MWD & motor. 04:00 - 05:00 1.00 CASE P LNR1 R/U to run 7" 26# BTC-M L-80 drilling liner. Hold PJSM on running casing. 05:00 - 14:30 9.50 CASE P LNR1 Make up shoe track, Baker Lock bottom 3 jts. Check floats are holding. RIH with 7" liner to 5057'. P/U XO & pup jt. R/D power tongs and casing tools. Clear rig floor. 14:30 - 15:00 0.50 CASE P LNR1 RIH with liner on drill pipe to TOW @ 6712'. 15:00 - 16:00 1.00 CASE P LNR1 Circ drill pipe & liner volume @ 8 bpm @ 750 psi. UWT = 140K, DWT = 130K. 16:00 - 18:00 2.00 CASE P LNR1 Pass through window &RIH to 11582', hole in good shape. DWT = 110K. 18:00 - 20:00 2.00 CEMT P LNR1 M/U cement head & single of drill pipe. Break circ & tag bottom @ 11605'. UWT = 280K, DWT = 100K. Circ @ 3 bpm @ 950 psi. Stage pump up to 6 bpm @ 1500 psi. 20:00 - 22:00 2.00 CEMT P LNR1 PJSM with drill crew & cement crew. Pump 5 bbl water & test lines to 4000 psi. Pump 20 bbl MudPush spacer @ 12.0 ppg followed by 36.1 bbls (170 sx) Class "G" cement @ 15.8 ppg. Drop DP wiper dart and kick out with 5 bbl water. Displace with 256.5 bbl mud. Observed liner wiper plug latch up and bump plug with 3500 psi. Set hanger and bleed off pressure, check floats are holding. CIP @ 21:30 hrs. Rotate 15 turns to the right & release from hanger. Pressure up & unsting. Circ off liner top @ 455 gpm @ 2900 psi. Rotate down with 80K and set packer X 3 to confirm set. 22:00 - 22:30 0.50 CEMT P LNR1 CBU @ 400 gpm @ 2200 psi. 22:30 - 23:30 1.00 CEMT P LNR1 L/D cement head and single of drill pipe. Clear rig floor. 23:30 - 00:00 0.50 CEMT P LNR1 Cut & slip 75' of drill line. 3/19/2006 00:00 - 01:30 1.50 CEMT P LNR1 Service top drive & desks. 01:30 - 02:00 0.50 CEMT P LNR1 Break circ, 186 gpm @ 300 psi. Pump dry job. Monitor well. PJSM. 02:00 - 05:00 3.00 CEMT P LNR1 POH with liner running tool from 6438' L/D tools, clear rig floor. 05:00 - 08:30 3.50 DRILL P PROD1 PJSM. P/U BHA, orient MWD & up load. Shallow pulse test MWD @ 270 gpm @ 1420 psi. Printed: 4/14/2006 11:09:17 AM BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description ofiOperations 3/19/2006 08:30 - 13:30 5.00 DRILL P PROD1 RIH with 4" drill pipe from derrick from 357' to 11273'. Install blower hose on top drive. RIH, tag L.C @ 11522'. UWT = 250K, DWT = 120K. 13:30 - 14:30 1,00 CASE P PROD1 Fill pipe, break circ. R/U & test 7" casing to 3500 psi for 30 min, OK. 14:30 - 18:00 3,50 DRILL P PROD1 Drill float equip & cement from 11522' to 11600'. UWT = 190K, DWT = 125K, RWT = 155K. Pump @ 270 gpm, WOB = 10/18K, 20/70 rpm. 18:00 - 22:30 4.50 DRILL P PROD1 Pump 150 bbl water, 45 bbl high vis sweep & displace well to 8.4 ppg FloPro mud. Pump @ 270 gpm, Rotate & reciprocate. Clean shakers, troughs & pits. 22:30 - 00:00 1.50 DRILL P PROD1 Drill 7" shoe @ 11605' & 20' of new formation to 11625'. 3/20/2006 00:00 - 01:30 1.50 DRILL P PROD1 Pull to 7" casing shoe @ 11605 & perform F.I.T. test to 9.5 ppg EMW. Pressure = 525 psi. TVD @ 8874'. MW = 8.4 ppg. 01:30 - 00:00 22.50 DRILL P PROD1 Drill 6 1/8" hole from 11625' to 12072'. UWT = 190K, DWT = 140K, RWT = 165K. Torque = 8/9K @ 100 rpm. Pump @ 275 gpm @ 1780 on bottom & 1700 off. WOB = 12/15K. ART = 9.32 hrs. After drilling out of the 7" shoe it was discovered the 7" casing point was picked -100' high. -100' of HRZ is exposed in the 6-1/8" hole. 3/21/2006 00:00 - 01:00 1.00 DRILL P PROD1 Drill 6 1/8" hole from 12072' to 12100'. ART = 1.66 hrs. UWT = 190K, DWT = 140K, RWT = 165K. Torque = 8K off bottom, 9K on @ 100 rpm. WOB = 15K. Pump @ 275 gpm @ 1760 psi on bottom, 1650 off. 01:00 - 02:00 1.00 DRILL P PROD1 Survey, pump high vis sweep to bit and circ 2 open hole volumes. Monitor well. 02:00 - 02:30 0.50 DRILL P PROD1 POH from 12100' to 7" shoe @ 11605'.Monitor well, stable. HWT = 200K to 215K, DWT = 140K. Hole in good shape. 02:30 - 03:30 1.00 DRILL P PROD1 Drop dart & open circ sub, CBU @ 455 gpm @ 1675 psi. Rotate @ 100 rpm, reciprocate. Circ until clean. Monitor well. 03:30 - 04:00 0.50 DRILL P PROD1 Pump dry job. Remove top drive blower hose & blow down top drive. Monitor well. 04:00 - 08:00 4.00 DRILL P PROD1 POH from 11605' to BHA @ 357'. Monitor well. 08:00 - 10:00 2.00 DRILL P PROD1 PJSM. POH L/D BHA. Flush BHA with fresh water, down load MWD. 10:00 - 12:00 2.00 DRILL P PROD1 Clear rig floor. R/U to run 4.5" liner. 12:00 - 14:30 2.50 CASE P RUNPRD PJSM. M/U 4.5" 12.6# L-80 IBT-M shoe track, check floats are holding. M/U 11.6# LT & C liner, change out handling equipment. M/U hanger/packer assy & 4" pup to 694'. R/D casing tools. Clear floor. 14:30 - 19:00 4.50 CASE P RUNPRD Circ liner volume (10 bbls). RIH with liner on 4" drill pipe from 694' to 11517'. Fill pipe @ 10 stand intervals. 19:00 - 19:30 0.50 CASE P RUNPRD Circ drill pipe & liner volume @ 6 bpm @ 785 psi. UWT = 190K, DWT = 140K. 19:30 - 22:30 3.00 CASE N DPRB RUNPRD R1H from shoe @ 11605' to 11720'. Tight hole, liner will not go down. Pull 310K to free liner. Pull to 7" shoe, establish circ @ 130 gpm @ 600 psi. Work pipe down to 11625', tight & packing off. POH to 11424'. 22:30 - 00:00 1.50 CASE P RUNPRD PJSM. Remove wraps from drill line deadman. Slip on 1500' of new line. Cut & spool off old line. 3/22/2006 00:00 - 01:30 1.50 CASE P RUNPRD PJSM. Spool drill line off desks. Slip 1500' of new line on. Printed: 4/14/2006 11:09:17 AM BP EXPLORATION Page 6 of 10 Operatiolns Slummary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/22/2006 00:00 - 01:30 1.50 CASE P RUNPRD Inspect desks brakes. Circulating @ 105 gpm @ 400 psi. 01:30 - 02:00 0.50 CASE N DPRB RUNPRD Pump dry job. Blow down top drive, monitor well. 02:00 - 02:30 0.50 CASE N DPRB RUNPRD POH from 11424' to 11330'. Pulling tight in cased hole, 15/30K over UWT. Circ @ 336 gpm @ 820 psi. POH from 11330' to 11143'. UWT = 195K, DWT = 140K. 02:30 - 04:00 1.50 CASE N DPRB RUNPRD Pump high vis sweep, CBU. Pump @ 336 gpm @ 1130 psi. Circ until clean. 04:00 - 09:00 5.00 CASE N DPRB RUNPRD Blow down top drive. POH from 11143' to 694'. Monitor well. 09:00 - 10:30 1.50 CASE N DPRB RUNPRD R/U casing tools, POH L/D liner hanger/packer assy as per Baker Rep. 10:30 - 13:30 3.00 CASE N DPRB RUNPRD POH with 4.5" 11.6# L-80 IBT-M liner. Test atmosphere, fill out permits. Close annular preventor & heat Baker Locked shoe track joints, Break and L/D 12.6# IBT-M shoe track joints. Clear & clean rig floor. 13:30 - 19:30 6.00 BOPSU P RUNPRD PJSM. Drain BOP stack, pull wear ring. Instal! test plug, R/U to test BOPE. Test top & bottom rams, blind rams, choke manifold, manual and hyd choke & kill line valves and top drive valves to 250 low/ 3500 psi high test. Test annular preventor to 250/2500 psi. Install wear ring. Test witnessed by WSL John Rall &Tool pusher Cleve Coyne. Witness of test waived by AOGCC rep John Crisp. 19:30 - 21:00 1.50 CASE N DPRB RUNPRD PJSM. M/U 6 118" clean out assy BHA. P/U Hughs MX-18HDX bit, NB stab, DC, stb, 5 DC, 3 HWDP, drilling jar, 2 HWDP & XO to 383'. 21:00 - 00:00 3.00 CASE N DPRB RUNPRD RIH with clean out assy to 6821'. Fill pipe @ 30 stand intervals. 3/23/2006 00:00 - 02:30 2.50 CASE N DPRB RUNPRD RIH from 6821' to 11485', fill pipe @ 30 stand intervals. Break circ, wash & rotate down to 11579'. UWT = 195K, DWT = 140K, RWT = 165K. Torque = 6K @ 60 rpm. Pump @ 240 gpm @ 1040 psi. 02:30 - 06:00 3.50 CASE N DPRB RUNPRD Circ & cond mud. Rotate & reciprocate. Add 155 bbl of spike fluid containing black products. Stage pump up to 325 gpm @ 1650 psi. Weight up mud system to 9.5 ppg, adding SafeCarb 20 &SafeCarb 40. 06:00 - 18:00 12.00 CASE N DPRB RUNPRD Wash and ream from 7" shoe @ 11650' to 11690'. Pump @ 130/210 gpm @ 750/1275 psi. Torque = 8/11K @ 110 rpm. WOB = 2/6K. Trouble spots @ 11620', 11651', 11666' & 11690'. Stalling out rotary & packing off. Hung up @ 11690',Raising mud weight to 9.8 ppg. POH to 7" shoe @ 11605'. 18:00 - 19:30 1.50 CASE N DPRB RUNPRD Mix & pump high vis sweep @ 12 bpm @ 3750 psi. Rotate $ reciprocate. Circ until clean. 19:30 - 23:30 4.00 CASE N DPRB RUNPRD Resume reaming using same parameters to 11765'. Stalled out & packed off while back reaming @ 11690'. Able to rotate & reciprocate, can not circulate. Pull to 7" shoe. 23:30 - 00:00 0.50 CASE N DPRB RUNPRD Break circ, mix & pump 35 bbl high vis sweep. Pump @ 505 gpm @ 3750 psi. 3/24/2006 00:00 - 01:00 1.00 CASE N DPRB RUNPRD CBU @ 7" shoe, circ out high vis sweep @ 495 gpm @ 3790 psi. Raising mud wt to 10.2 ppg. Rotate @ 120 rpm & reciprocate, circ till clean. 01:00 - 06:00 5.00 CASE N DPRB RUNPRD Wash & ream from 7" shoe @ 11605'. Pump @ 225 gpm @ 1260 psi. Torque = 9/11 K @ 100/115 rpm. UWT = 195K, DWT = 135K, RWT = 165K. Tight spots @ 11660', 11690' & 11702'. Reaming is slow, tight & packing off. Pump 35 bbl 110 vis Printed: 4114!2006 11:09:17 AM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A ', Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLIING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To .Hours Task Code N~T Phase Description of Operations 3/24/2006 01:00 - 06:00 5.00 CASE N DPRB RUNPRD sweep @ 11670'. Ream to bottom @ 12100'. Raise mud weight to 10.5 ppg. 06:00 - 08:30 2.50 CASE N DPRB RUNPRD Circ &cond mud. Pump @ 300 gpm @ 2000 psi. Rotate @ Reciprocate. Torque = 8/10K. Mud weight in & out 10.5 ppg. 08:30 - 09:00 0.50 CASE N DPRB RUNPRD POH from bottom @ 12100' to 7" shoe @ 11605'. UWT = 215K, Max UWT = 245K. 09:00 - 12:00 3.00 CASE N DPRB RUNPRD Circ @ 450 gpm @ 3750 psi. weight up to 10.7 ppg. 12:00 - 13:00 1.00 CASE N DPRB RUNPRD RIH, tight hole @ 11700'. Pull up to shoe,Circ &cond mud. Pump @ 235 gpm @ 1550 psi. Raising mud weight to 11.0 PPg• 13:00 - 15:30 2.50 CASE N DPRB RUNPRD Wash & ream in hole. Work tight spot @ 11705', ream to 11859'. RIH without rotating or Circ from 11859' to 12014'. Wash & ream to bottom @ 12100'. Pump @ 235 gpm @ 1550 psi. Torque = 8/9K @ @ 110 rpm. Pump high vis sweep. 15:30 - 20:30 5.00 CASE N DPRB RUNPRD Circ &cond mud, weighting up to 11.0 ppg Pump @ 235 gpm @ 2600 psi. Torque = 8/9K @ 115 rpm. Mud weight in & out = 11.0 ppg, Vis = 50. Add 6 ppb black products. 20:30 - 21:00 0.50 CASE N DPRB RUNPRD Short trip to shoe, no pump. POH from 12100' to 11605'. UWT = 205K, DWT = 135K. Max pull = 245K @ 11705'. Monitor well @ 7" shoe. 21:00 - 22:00 1.00 CASE P RUNPRD Service rig & top drive. 22:00 - 23:30 1.50 CASE N DPRB RUNPRD RIH, tight hole @ 11705'. Break circ, attempt to pass tight spot with out rotating. No success. Ream from 11671' to 11765'. RIH to 12014', tight hole. Ream from 12014' to 12100'. 23:30 - 00:00 0.50 CASE N DPRB RUNPRD Circ &cond mud. Raising mud weight to 11.3 ppg. Rotate & reciprocate, torque = 8/9K @ 110 rpm. Pump @ 326 gpm @ 2570 psi. UWT = 210K, DWT = 140K, RWT = 160K. 3/25/2006 00:00 - 01:30 1.50 CASE N DPRB RUNPRD Circ @ 12100', rotate & reciprocate. Raise mud weight to 11.3 ppg. Pump @ 325 gpm @ 2600 psi. Monitor well. Mud weight = 11.3 ppg in & out. 01:30 - 02:00 0.50 CASE N DPRB RUNPRD POH from bottom @ 12100' to 7" shoe @ 11605'. UWT = 210K, max pull = 250K. 02:00 - 03:00 1.00 CASE N DPRB RUNPRD Circ &cond mud. Pump @ 500 gpm @ 3750 psi. CBU, increase in cuttings @ bottoms up. 03:00 - 06:30 3.50 CASE N DPRB RUNPRD RIH, tight hole @ 11705'. Ream 11685' to 11725'. RIH to bottom @ 12100'. 06:30 - 08:00 1.50 CASE N DPRB RUNPRD Weight up mud system to 11.5 ppg. Pump @ 310 gpm @ 2450 psi. Monitor well, static. Mud weight in & out = 11.5 ppg. 08:00 - 09:00 1.00 CASE N DPRB RUNPRD POH from 12100' to 7" shoe @ 11605'. Max pull = 25K @ 11705'. Blow down top drive. 09:00 - 17:00 8.00 CASE N DPRB RUNPRD RIH from 11605' to 11705'. Wash and ream tight spot, 11700' to 11715'. Rotate @ 20/120 rpm, torque = 8/10K. Pump 100/300 gpm. Attempt to RIH with no pump or rotary. No success. UWT = 185K, DWT = 135K, RWT = 155K. Ream to 11715'. 17:00 - 17:30 0.50 CASE N DPRB RUNPRD RIH from 11715' to bottom @ 12100'. No problems. 17:30 - 19:30 2.00 CASE N DPRB RUNPRD Circ, pump high vis sweep @ 300 gpm @ 2415 psi. Rotate @ 100 rpm, reciprocate. CBU. 19:30 - 20:00 0.50 CASE N DPRB RUNPRD Monitor well, stable. POH to 7" shoe @ 11605'. 20:00 - 22:00 2.00 CASE N DPRB RUNPRD RIH, to 11705'. Wash & ream to 11765', RIH to 12014'. Wash & ream to bottom @ 12100'. 22:00 - 00:00 2.00 CASE N DPRB RUNPRD Circ &cond mud. Reciprocate, rotate @ 100 rpm @ 8/10K torque. Pump @ 300 gpm @ 2400 psi. UWT = 185K, DWT = Printed: 4/14/2006 11:09:17 AM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From. - To Hours Task Code NPT Phase Description of Operations. 3/25/2006 22:00 - 00:00 2.00 CASE N DPRB RUNPRD 135K, RWT = 155K. Mud weight 11.5 ppg in & out. 3/26/2006 00:00 - 01:00 1.00 CASE N DPRB RUNPRD Monitor well. Mud weight in & out = 11.5 ppg. POH from bottom @ 12100' to 7" shoe @ 11605'. Over pull = 20/SOK. Pump dry job. 01:00 - 02:00 1.00 CASE P RUNPRD Blow down top drive. Cut drill line. Adjust brakes. Service desks. Inspect brushes on traction motor. 02:00 - 06:00 4.00 CASE N DPRB RUNPRD POH for 6 1/8" hole opener. 06:00 - 07:30 1.50 CASE N DPRB RUNPRD Stand back BHA. L/D 3 drill collars, stabs & bit. M/U 6 1/8" hole opener. 07:30 - 12:00 4.50 CASE N DPRB RUNPRD RIH from 289' to 11578'. Fill pipe @ 3000' intervals. Install top drive blower hose. 12:00 - 15:30 3.50 CASE N DPRB RUNPRD Take slow pump rates. RIH from 11578' to 11705', tag obstruction. Wash & ream from 11671' to 11730'. Ream section @ 10' per hr. Pump @ 220 gpm @ 1460 psi, torque = 8/12K @ 100 rpm. WOB = 2/5K. 15:30 - 19:30 4.00 CASE N DPRB RUNPRD Shut down pump & rotary. Work through tight spot to 11765'. Pull up to 11761'. Wash & ream from 11671' to 11730' @ 10' per hr. Pump @ 240 gpm @ 1510 psi, torque = 9/12K @ 100 rpm. 19:30 - 20:00 0.50 CASE N DPRB RUNPRD POH from 11730' to 7" shoe @ 11605'. UWT = 200K, DWT = 135K. Max pull = 240K. 20:00 - 22:00 2.00 CASE N DPRB RUNPRD RIH from 7" shoe @ 11605' to 11730'. Wash & ream through tight spot @ 11705' to 11725'. Pump @ 240 gpm @ 1450. torque = 9/12K @ 100 rpm. 22:00 - 22:30 0.50 CASE N DPRB RUNPRD RIH from 11725', to 12045'. Wash & ream from 12045' to bottom @ 12100'. Pump @ 240 gpm @ 1400 psi. Torque = 7/9K @ 100 rpm. 22:30 - 00:00 1.50 CASE N DPRB RUNPRD Pump high vis sweep, CBU. Rotate & reciprocate. Pump @ 240 gpm @ 1500 psi. Torque = 7/8K @ 100 rpm. Mud weight in & out = 11.5 ppg, vis = 46. UWT = 185K, DWT = 130K, RWT = 165K. 3/27/2006 00:00 - 00:30 0.50 CASE N DPRB RUNPRD CBU @ 12100', 250 gpm @ 1500 psi. Monitor well, static. Mud weight in & out = 11.5. ppg. 00:30 - 01:00 0.50 CASE N DPRB RUNPRD POH wet to 7" shoe @ 11605'. Max pull = 250K. 01:00 - 01:30 0.50 CASE N DPRB RUNPRD Pump dry job. Blow down top drive. Remove blower hose. Drop 2" drift down drill pipe. 01:30 - 05:30 4.00 CASE N DPRB RUNPRD POH with 6 1/8" hole opener to 289'. 05:30 - 06:00 0.50 CASE N DPRB RUNPRD L/D HWDP, drill collars & hole opener. Hole opener missing bull nose and both roller cones. Clear rig floor, 06:00 - 07:00 1.00 CASE N DPRB RUNPRD PJSM. P/U liner handling equipment & R/U to run 4.5" liner. 07:00 - 09:00 2.00 CASE N DPRB RUNPRD P/U float equip & check floats are holding. Run 4.5" 12.25# L-80 Hydril 521 liner, P/U liner hanger/ packer to 697'. Gel pack liner top. 09:00 - 09:30 0.50 CASE N DPRB RUNPRD P/U 1 stand of drill pipe. Circ liner volume. 09:30 - 16:30 7.00 CASE N DPRB RUNPRD RIH with 4.5" liner on drill pipe from derrick to 11519'. Fill pipe @ 10 stand intervals. UWT = 180K, DWT 130K, RWT = 150K. Torque = 5/6K in casing. 16:30 - 17:00 0.50 CASE N DPRB RUNPRD Break circ,stage pump up to 6 bpm @ 1200 psi. Pump drill pipe & liner volume. Blow down top drive, monitor well. 17:00 - 18:30 1.50 CASE P RUNPRD RIH from 11519' to 11684'. Tag obstruction, work pipe through tight spot from 11684' to 11720'. RIH to 12079'. 18:30 - 19:00 0.50 CEMT P RUNPRD P/U cement head on single of drill pipe. RIH & tag bottom @ 12100'. Printed: 4/14/2006 11:09:17 AM BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Descriptionof Operations 3/27/2006 19:00 - 20:30 1.50 CEMT P RUNPRD Circ & reciprocate, stage pumps up to 6 bpm @ 1700 psi. Hold PJSM with Drill Crew, Dowell, Veco and WSL. Batch mix cement. Shut down circ, switch valves to Dowell. Differential stuck pipe on bottom @ 12100'. Circ & work pipe in attempt to free. No success, good returns. 20:30 - 21:30 1.00 CEMT P RUNPRD Pump 5 bbl water & test lines to 4500 psi. Pump 15 bbl CW100 @ 8.4 ppg & 12 bbl mudPush II @ 12.4 ppg. Pump 27 bbl of class "G" cement @ 15.8 ppg. Wash lines through tee on rig floor with 5 bbl of pert pill. Drop wiper dart & pump remaining 20 bbl pert pill. Displace with 107 bbl 11.5 ppg mud & bump plug with 4500 psi. CIP @ 21:20 hrs. 21:30 - 00:00 2.50 CEMT P RUNPRD With liner on bottom set hanger and confirm with 50K weight down. Pressure up to 4500 psi to release HR running tool. Check floats are holding. P/U & hold 1000 psi pump pressure. Unsting from seals and pump 600 strokes @ 500 gpm. Slow pumps & weight set packer with 50K. Circ @ 500 gpm @ 3250 psi, reciprocate pipe. Liner shoe @ 12100', liner top @ 11411'. CBU X 2. 3/28/2006 00:00 - 01:30 1.50 CEMT P RUNPRD CBU @ 11,411' @ 12 bpm @ 2600 psi. Circ until clean, trace of cement in returns. 01:30 - 03:00 1.50 CEMT P RUNPRD Displace well to 8.5 ppg seawater @ 12 bpm @ 2400 psi. 03:00 - 05:00 2.00 CEMT P RUNPRD PJSM POOH Lay down drill pipe 11,411'- 8486' 05:00 - 06:00 1.00 CEMT P RUNPRD Service Top drive. Lubricate rig 06:00 - 07:00 1.00 CEMT P RUNPRD PJSM Cut drill line. Inspect brakes. Lubricate Elmago coupling. Inspect traction brushes. 07:00 - 07:30 0.50 CEMT P RUNPRD RIH 8464' - 9117' 07:30 - 17:00 9.50 CEMT N RREP RUNPRD Repair front ejector on skate. 17:00 - 00:00 7.00 CEMT P RUNPRD POOH Lay down drill pipe from 9117' to liner running tool. Lay down liner running tool and clear floor. 3/29/2006 00:00 - 00:30 0.50 CEMT P RUNPRD Test 4 1/2" liner to 3500psi for 30 minutes 00:30 - 01:00 0.50 RUNCO RUNCMP Pull wear ring 01:00 - 01:30 0.50 RUNCO RUNCMP Make up landing joint 01:30 - 02:00 0.50 RUNCO RUNCMP Install long bales and remove saver sub 02:00 - 04:00 2.00 RUNCO RUNCMP Rig up 4 1/2" tubing equipment with compensator 04:00 - 04:30 0.50 RUNCO RUNCMP Pick up tailpipe and packer 04:30 - 21:30 17.00 RUNCO RUNCMP Run 4 1/2" 12.6# 13CR80 Vam top tubing to 11425.49'. Tag no go and confirm tag. 21:30 - 22:00 0.50 RUNCO RUNCMP Change elevators, remove compensator. Pick up landing joint and hanger. Up wt 145k down wt.110k 22:00 - 23:00 1.00 RUNCO RUNCMP Land Hanger, run in lock down screws 23:00 - 00:00 1.00 RUNCO RUNCMP Reverse circulate seawater & corrosion inhibitor. 3 BPM @280psi 3/30/2006 00:00 - 02:30 2.50 RUNCO RUNCMP Reverse circulate corrosion inhibitor 3 BPM @280psi 02:30 - 04:30 2.00 RUNCO RUNCMP Drop ball & Rod. Pump down tubing to 4000psi to set packer. Chart and hold for 30 min. Bleed to 1500psi,pump down annulus to 3500psi. Hold and chart for 30 min. Bleed down tubing to Shear DCR valve. Blow down surface equipment. 04:30 - 05:00 0.50 RUNCO RUNCMP Dry rod BPV and test from below to 1000psi 05:00 - 07:00 2.00 BOPSU P RUNCMP Nipple down BOP 07:00 - 09:30 2.50 WHSUR P RUNCMP Nipple up tree and adapter 09:30 - 11:00 1.50 WHSUR P RUNCMP Rig up lubricator,trouble with actuator valve. Pump open va-ve. Pull BPV with lubricator. Rig down lubricator, clear floor. 11:00 - 13:00 2.00 WHSUR P RUNCMP Dry rod tree test plug. Test tree to 5000psi for 10 min on chart Printed: 4/14/2006 11:09:17 AM BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/30/2006 11:00 - 13:00 2.00 WHSUR P RUNCMP recorder. Bleed pressure,pull tree test plug. 13:00 - 17:30 4.50 WHSUR P RUNCMP Rig up to freeze protect well. PJSM with Littel Red Hot Oil services. Pressure test lines. Freeze protect well with 151 bbl Diesel to 2200',3BPM @200psi. U-Tube until balanced 17:30 - 21:30 4.00 WHSUR P RUNCMP Rig up DSM lubricator and set BPV,test from below to 1000psi (leaking) Pull BPV and redress. Set BPV and test to 1000psi from below for 5 min. (OK). Bleed pressure, Rig down lubricator. 21:30 - 22:30 1.00 WHSUR P RUNCMP Blow down lines. Remove secondary annular valve. Clear cellar. Rig release @22:30 03-30-2006 Printed: 4/14/2006 11:09:17 AM • • W el I: 16-06B Accept: 03/06/06 Field: Prudhoe Bay Unit Spud: 03/11/06 API: 50-029-20584-02-00 Release: 03/30/06 Permit: 206-011 Riq: Nabors 2ES POST RIG WORK 04/08/06 PULLED BANDR FROM 11395' SLM. PULLED STA# 5 SHEAR VALVE AND STA# 4 DGLV. SET LGLV IN STA# 5 AND S/O GLV IN STA# 4. PULLED RHC PLUG BODY AT 11,404' SLM. DRIFT W/ 12' X 3 8/8" DUMMY GUN AND S-BAILER TO 11,966' SLM. WELL LEFT S/I. 04h 6/06 CORRELATED TO SPERRY SUN DGR DUAL GAMMA RAY LOG DATED 21-MAR-2006, 2 MIS-RUNS DUE TO SHORT IN ADAPTER. PERFORATED 11824' - 11854' WITH 3-3/8" HSD 3406 PJ HMX WITH 60 DEG PHASE, 6 SPF, NO PROBLEMS REACHING REQUIRED DEPTHS. WELL LEFT SHUT IN AND TURNED OVER TO DSO. JOB COMPLETE. Halliburton Company Survey Report Company: BP Amoco Date: 4/5/2006 T ime: 10:22:59 Page: t Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-06, True North Site: PB DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-06 Section (VS) Reference: Well (O.OON,O .OOE,60.98Azi) " Wellpath: 16-06B Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coord inate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea L evel Geomagnetic Model: bggm2005 Well: 16-06 Slot Name: 16-06 Well Position: +N/-S 1585.16 ft Northing: 5929055.05 ft Latitude: 70 12 31.135 N +E/-W 987.97 ft Fasting : 719911.44 ft Longitude: 148 13 35.892 W Position Uncertainty: 0.00 ft Wellpath: 16-066 Drilled From: 16-06 500292058402 Tie-on Depth: 6694.50 ft Current Datum: 38+28.5 Height 66.50 ft Above System Datum: Mean Sea Level Magnetic Data: 3/8/2006 Declination: 24.79 deg Field Strength: 57621 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direcfion ft ft ft deg 28.50 0.00 0.00 60.98 Survey Program for Definitive Wellpath Date: 4/5/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 94.50 6694.50 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 6712.00 12062.24 16-066 I IFR+MS+ SAG (6712.00- 12 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Intl ~~im TVD Sys TYD 1/S E/W MapN MapE Tool j ft deg deg ft ft ft ft ft ft 28.50 0.00 0.00 28.50 -38.00 0.00 0.00 5929055.05 719911.44 TIE LINE 94.50 0.12 116.70 94.50 28.00 -0.03 0.06 5929055.02 719911.50 BOSS-GYRO 194.50 0.17 261.70 194.50 128.00 -0.10 0.01 5929054.95 719911.45 BOSS-GYRO 294.50 0.18 199.60 294.50 228.00 -0.27 -0.19 5929054.78 719911.26 BOSS-GYRO 394.50 0.23 207.60 394.50 328.00 -0.59 -0.34 5929054.45 719911.12 BOSS-GYRO 494.50 0.13 200.20 494.50 428.00 -0.88 -0.47 5929054.16 719911.00 BOSS-GYRO 594.50 0.18 245.80 594.50 528.00 -1.05 -0.65 5929053.98 719910.82 BOSS-GYRO 694.50 0.32 79.60 694.50 628.00 -1.06 -0.52 5929053.97 719910.95 BOSS-GYRO 794.50 0.05 311.00 794.50 728.00 -0.98 -0.28 5929054.06 719911.19 BOSS-GYRO 894.50 0.33 86.50 894.50 828.00 -0.94 -0.02 5929054.11 719911.44 BOSS-GYRO 994.50 0.08 81.20 994.50 928.00 -0.91 0.33 5929054.15 719911.80 BOSS-GYRO 1094.50 0.43 104.40 1094.49 1027.99 -0.99 0.77 5929054.08 719912.23 BOSS-GYRO 1194.50 0.17 185.50 1194.49 1127.99 -1.23 1.11 5929053.85 719912.59 BOSS-GYRO 1294.50 0.20 14.50 1294.49 1227.99 -1.21 1.14 5929053.87 719912.62 BOSS-GYRO 1394.50 0.22 172.60 1394.49 1327.99 -1.23 1.21 5929053.85 719912.69 BOSS-GYRO 1494.50 0.08 285.30 1494.49 1427.99 -1.41 1.17 5929053.68 719912.65 BOSS-GYRO 1594.50 0.72 99.40 1594.49 1527.99 -1.49 1.72 5929053.61 719913.20 BOSS-GYRO 1694.50 0.67 133.00 1694.48 1627.98 -1.99 2.77 5929053.14 719914.27 BOSS-GYRO 1794.50 0.93 162.30 1794.47 1727.97 -3.16 3.44 5929051.99 719914.97 BOSS-GYRO 1894.50 0.88 173.50 1894.46 1827.96 -4.70 3.78 5929050.46 719915.35 BOSS-GYRO 1994.50 0.83 164.90 1994.45 1927.95 -6.16 4.05 5929049.01 719915.67 BOSS-GYRO 2094.50 0.67 137.40 2094.44 2027.94 -7.29 4.64 5929047.90 719916.29 BOSS-GYRO 2194.50 0.40 126.80 2194.44 2127.94 -7.93 5.31 5929047.28 719916.98 BOSS-GYRO 2294.50 0.38 80.70 2294.44 2227.94 -8.09 5.92 5929047.14 719917.59 BOSS-GYRO 2394.50 0.30 96.10 2394.43 2327.93 -8.06 6.51 5929047.18 719918.18 BOSS-GYRO 2494.50 0.25 73.50 2494.43 2427.93 -8.03 6.98 5929047.23 719918.65 BOSS-GYRO 2594.50 0.53 133.50 2594.43 2527.93 -8.28 7.52 5929046.99 719919.20 BOSS-GYRO 2694.50 1.02 182.20 2694.42 2627.92 -9.49 7.82 5929045.79 719919.54 BOSS-GYRO 2794.50 0.82 194.10 2794.41 2727.91 -11.07 7.61 5929044.20 719919.37 BOSS-GYRO Halliburton Company Survey Report Company: BP Amoco Date 4/5/2006 Time 10:2259 Page: 2 Field: Prudhoe Bay Co-ordinute(N E) Reference: Wets: 16-06, True North Site• PB DS 16 Vcrt~cal (TVD ) Reference: 38+28.5 66.5 Well: 16- 06 Section (VS) Reference: Weli (O.OON,O .OOE,60.98Azi) Wellpath: 16- O6B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim _ TVD _ Sys TVD - N/S --- ElW _ Mapr _ MapE 'Cool ft deg deg ft ft ft ft ft ft 2894.50 0.87 192.80 2894.40 2827.90 -12.51 7.27 5929042.76 719919.07 BOSS-GYRO 2994.50 1.12 167.00 2994.38 2927.88 -14.20 7.32 5929041.07 719919.17 BOSS-GYRO 3094.50 0.97 172.50 3094.37 3027.87 -15.99 7.65 5929039.29 719919.56 BOSS-GYRO 3194.50 0.90 171.70 3194.35 3127.85 -17.61 7.88 5929037.68 719919.83 BOSS-GYRO 3294.50 0.65 195.10 3294.35 3227.85 -18.93 7.84 5929036.35 719919.83 BOSS-GYRO 3394.50 0.63 180.50 3394.34 3327.84 -20.03 7.69 5929035.25 719919.71 BOSS-GYRO 3494.50 0.60 190.90 3494.33 3427.83 -21.10 7.59 5929034.19 719919.64 BOSS-GYRO 3594.50 0.42 196.00 3594.33 3527.83 -21.96 7.39 5929033.31 719919.46 BOSS-GYRO 3694.50 0.50 182.90 3694.33 3627.83 -22.75 7.26 5929032.52 719919.36 BOSS-GYRO 3794.50 1.03 31.70 3794.32 3727.82 -22.42 7.71 5929032.86 719919.80 BOSS-GYRO 3894.50 2.88 52.80 3894.26 3827.76 -20.14 10.19 5929035.22 719922.21 BOSS-GYRO 3994.50 4.40 49.80 3994.06 3927.56 -16.14 15.12 5929039.36 719927.02 BOSS-GYRO 4094.50 6.58 59.00 4093.59 4027.09 -10.71 22.96 5929045.01 719934.70 BOSS-GYRO 4194.50 8.27 66.00 4192.75 4126.25 -4.84 34.44 5929051.22 719946.01 BOSS-GYRO 4294.50 9.93 73.00 4291.49 4224.99 0.61 49.26 5929057.09 719960.66 BOSS-GYRO 4394.50 11.83 76.70 4389.69 4323.19 5.49 67.48 5929062.50 719978.73 BOSS-GYRO 4494.50 13.87 78.70 4487.18 4420.68 10.20 89.21 5929067.84 720000.32 BOSS-GYRO 4594.50 16.02 80.90 4583.80 4517.30 14.73 114.60 5929073.11 720025.55 BOSS-GYRO 4694.50 18.07 81.70 4679.40 4612.90 19.15 143.57 5929078.37 720054.39 BOSS-GYRO 4794.50 20.93 82.10 4773.65 4707.15 23.84 176.62 5929084.03 720087.28 BOSS-GYRO 4894.50 23.42 82.90 4866.25 4799.75 28.76 214.04 5929090.02 720124.54 BOSS-GYRO 4994.50 25.95 83.00 4957.10 4890.60 33.88 255.48 5929096.35 720165.81 BOSS-GYRO 5094.50 28.83 82.20 5045.88 4979.38 39.82 301.09 5929103.62 720211.23 BOSS-GYRO 5194.50 31.82 82.10 5132.19 5065.69 46.72 351.10 5929111.97 720261.02 BOSS-GYRO 5294.50 34.22. 82.10 5216.03 5149.53 54.21 405.08 5929121.03 720314.75 BOSS-GYRO 5394.50 34.97 82.50 5298.35 5231.85 61.81 461.34 5929130.27 720370.76 BOSS-GYRO 5494.50 34.92 82.80 5380.32 5313.82 69.14 518.15 5929139.24 720427.33 BOSS-GYRO 5594.50 34.78 83.80 5462.39 5395.89 75.81 574.90 5929147.56 720483.86 BOSS-GYRO 5694.50 34.82 83.80 5544.50 5478.00 81.97 631.64 5929155.37 720540.39 BOSS-GYRO 5794.50 34.50 84.20 5626.76 5560.26 87.92 688.20 5929162.96 720596.75 BOSS-GYRO 5894.50 34.70 84.30 5709.07 5642.57 93.60 744.69 5929170.30 720653.06 BOSS-GYRO 5994.50 34.28 85.00 5791.49 5724.99 98.89 801.07 5929177.22 720709.26 BOSS-GYRO 6094.50 34.82 85.40 5873.86 5807.36 103.63 857.59 5929183.60 720765.61 BOSS-GYRO 6194.50 34.72 86.10 5956.00 5889.50 107.86 914.46 5929189.48 720822.33 BOSS-GYRO 6294.50 34.50 86.30 6038.31 5971.81 111.62 971.13 5929194.90 720878.87 BOSS-GYRO 6394.50 34.23 85.40 6120.85 6054.35 115.70 1027.43 5929200.62 720935.02 BOSS-GYRO 6494.50 33.83 85.60 6203.73 6137.23 120.10 1083.22 5929206.63 720990.65 BOSS-GYRO 6594.50 33.48 86.00 6286.96 6220.46 124.16 1138.49 5929212.30 721045.78 BOSS-GYRO 6694.50 33.28 85.30 6370.47 6303.97 128.33 1193.35 5929218.07 721100.49 BOSS-GYRO 6712.00 33.63 84.30 6385.07 6318.57 129.20 1202.95 5929219.22 721110.07 MWD+IFR+MS 6786.00 37.24 80.44 6445.36 6378.86 134.96 1245.44 5929226.21 721152.37 MWD+IFR+MS 6879.50 40.65 76.26 6518.08 6451.58 146.90 1302.95 5929239.82 721209.50 MWD+IFR+MS 6959.62 43.63 75.20 6577.49 6510.99 160.16 1355.04 5929254.59 721261.18 MWD+IFR+MS 7034.81 45.27 73.06 6631.16 6564.66 174.57 1405.68 5929270.47 721311.37 MWD+IFR+MS 7095.99 46.85 69.60 6673.62 6607.12 188.68 1447.39 5929285.79 721352.66 MWD+IFR+MS 7190.00 48.74 65.85 6736.78 6670.28 215.10 1511.79 5929314.07 721416.26 MWD+IFR+MS 7280.96 50.44 62.28 6795.76 6729.26 245.41 1574.05 5929346.18 721477.60 MWD+IFR+MS 7374.80 54.10 58.78 6853.18 6786.68 281.95 1638.61 5929384.58 721541.07 MWD+IFR+MS 7468.45 58.35 55.77 6905.24 6838.74 324.06 1704.04 5929428.58 721605.24 MWD+IFR+MS 7562.49 62.53 53.24 6951.63 6885.13 371.57 1770.59 5929478.00 721670.38 MWD+IFR+MS 7655.77 63.38 51.83 6994.05 6927.55 422.11 1836.53 5929530.44 721734.82 MWD+IFR+MS 7748.03 63.39 52.33 7035.38 6968.88 472.80 1901.60 5929583.00 721798.38 MWD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Date: 4/5/2006 Timc: 10:22:59 Page: 3 Field: Prudhoe Bay Co-ordin:tte~tiN:) Reference: Well: 16-06, True North ~ Site: PB DS 16 Vertical (TVD ) Reference: 38+28.5 66.5 ~ Well: 16- 06 Section (VS) Reference: Well (O.OON,O .OOE,60.98Azi) Wcllpath: 16- 06B Survey Calcu lation Method: Minimum Curvature Db: Oracle Survc~ __ MD Incl Azim TVD Sys "PV'D N/S E/W hlap~ MapE Tool ft deg deg ft ft ft ft ft ft ~ 7841.66 63.33 51.56 7077.36 7010.86 524.39 1967.50 5929636.48 721862.75 MWD+IFR+MS 7935.48 62.97 51.73 7119.74 7053.24 576.33 2033.14 5929690.31 721926.84 MWD+IFR+MS 8028.53 62.82 50.88 7162.13 7095.63 628.11 2097.79 5929743.95 721989.95 MWD+IFR+MS 8122.99 62.52 50.70 7205.50 7139.00 681.16 2162.81 5929798.87 722053.40 MWD+IFR+MS 8216.84 62.14 50.56 7249.08 7182.58 733.88 2227.06 5929853.44 722116.09 MWD+IFR+MS 8310.85 62.66 53.02 7292.64 7226.14 785.40 2292.52 5929906.84 722180.01 MWD+IFR+MS 8404.45 62.41 52.44 7335.81 7269.31 835.70 2358.61 5929959.04 722244.61 MWD+IFR+MS 8496.72 62.02 51.43 7378.82 7312.32 886.03 2422.88 5930011.21 722307.38 MWD+IFR+MS 8589.09 61.43 55.08 7422.59 7356.09 934.69 2488.04 5930061.75 722371.10 MWD+IFR+MS 8683.01 60.93 54.78 7467.87 7401.37 981.97 2555.39 5930110.97 722437.04 MWD+IFR+MS 8776.86 60.36 54.11 7513.87 7447.37 1029.53 2621.94 5930160.44 722502.17 MWD+IFR+MS 8870.03 62.09 53.54 7558.72 7492.22 1077.73 2687.86 5930210.54 722566.65 MWD+IFR+MS 8962.03 61.86 53.63 7601.95 7535.45 1125.94 2753.21 5930260.64 722630.57 MWD+IFR+MS 9055.56 61.45 52.64 7646.36 7579.86 1175.32 2819.07 5930311.91 722694.96 MWD+IFR+MS 9148.70 60.84 51.86 7691.30 7624.80 1225.27 2883.57 5930363.71 722757.98 MWD+IFR+MS 9241.94 60.33 51.91 7737.10 7670.60 1275.40 2947.47 5930415.68 722820.39 MWD+IFR+MS 9335.58 61.80 53.16 7782.40 7715.90 1325.24 3012.52 5930467.39 722883.95 MWD+IFR+MS 9429.26 61.73 53.02 7826.72 7760.22 1374.80 3078.51 5930518.85 722948.47 MWD+IFR+MS 9523.00 61.27 51.73 7871.45 7804.95 1425.09 3143.76 5930571.02 723012.22 MWD+IFR+MS 9616.95 62.28 51.57 7915.88 7849.38 1476.45 3208.67 5930624.25 723075.61 MWD+IFR+MS 9709.43 62.42 55.39 7958.81 7892.31 1525.19 3274.49 5930674.87 723139.98 MWD+IFR+MS 9802.41 62.46 55.98 8001.83 7935.33 1571.66 3342.57 5930723.30 723206.68 MWD+IFR+MS 9895.43 62.05 56.17 8045.14 7978.64 1617.61 3410.88 5930771.22 723273.62 MWD+IFR+MS 9988.35 62.38 54.49 8088.45 8021.95 1664.37 3478.49 5930819.93 723339.83 MWD+IFR+MS 10081.32 61.90 54.17 8131.90 8065.40 1712.30 3545.26 5930869.78 723405.18 MWD+IFR+MS 10174.32 62.99 52.99 8174.92 8108.42 1761.25 3611.60 5930920.64 723470.06 MWD+IFR+MS 10267.73 62.45 52.14 8217.74 8151.24 1811.71 3677.53 5930973.00 723534.48 MWD+IFR+MS 10361.72 61.92 51.94 8261.59 8195.09 1862.85 3743.07 5931026.02 723598.51 MWD+IFR+MS 10454.39 63.09 51.46 8304.38 8237.88 1913.79 3807.58 5931078.82 723661.50 MWD+IFR+MS 10547.61 62.35 51.14 8347.10 8280.60 1965.59 3872.24 5931132.48 723724.62 MWD+IFR+MS 10640.52 61.70 50.70 8390.69 8324.19 2017.32 3935.93 5931186.03 723786.78 MWD+IFR+MS 10736.27 61.55 52.60 8436.19 8369.69 2069.59 4002.00 5931240.20 723851.29 MWD+IFR+MS 10829.63 60.18 51.95 8481.65 8415.15 2119.48 4066.50 5931291.95 723914.31 MWD+IFR+MS 10924.08 60.98 52.74 8528.04 8461.54 2169.74 4131.63 5931344.08 723977.95 MWD+IFR+MS 11016.91 62.43 53.25 8572.04 8505.54 2218.93 4196.90 5931395.15 724041.76 MWD+IFR+MS 11109.24 62.29 54.20 8614.88 8548.38 2267.33 4262.84 5931445.44 724106.26 MWD+IFR+MS 11201.98 61.04 55.44 8658.89 8592.39 2314.36 4329.56 5931494.39 724171.57 MWD+IFR+MS 11295.84 58.32 54.54 8706.27 8639.77 2360.83 4395.92 5931542.78 724236.55 MWD+IFR+MS 11389.00 57.55 54.92 8755.73 8689.23 2406.42 4460.37 5931590.22 724299.65 MWD+IFR+MS 11483.02 56.81 54.16 8806.69 8740.19 2452.25 4524.73 5931637.91 724362.64 MWD+IFR+MS 11549.37 56.39 54.25 8843.21 8776.71 2484.65 4569.66 5931671.60 724406.60 MWD+IFR+MS 11638.46 56.21 55.13 8892.65 8826.15 2527.49 4630.14 5931716.18 724465.81 MWD+IFR+MS 11701.05 54.05 56.34 8928.43 8861.93 2556.41 4672.57 5931746.32 724507.38 MWD+IFR+MS 11794.77 53.04 56.59 8984.12 8917.62 2598.05 4735.40 5931789.77 724568.97 MWD+IFR+MS 11887.57 52.40 54.74 9040.33 8973.83 2639.69 4796.37 5931833.17 724628.70 MWD+IFR+MS 11981.51 51.87 55.38 9097.99 9031.49 2682.16 4857.17 5931877.39 724688.23 MWD+IFR+MS 12062.24 50.69 53.90 9148.49 9081.99 2718.61 4908.54 5931915.31 724738.51 MWD+IFR+MS 12100.00 50.69 53.90 9172.41 9105.91 2735.82 4932.14 5931933.21 724761.60 BLIND TREE = 5-1/8" FMC W~ELLHEAL?= FMC ACTUATOR = AXELSON KB. ELEV = 72.0' BF. E1EV = _ NA _ KOP = 4300' Max Angle = 99 @ 10190' Datum MD = 9567' Datum TV D = 8800' SS 16-0~ Actual Com letion p F ~.. °~ 4-1/2" X Nipple (3.813" ID) - 2200` 13-3/8" 72#, L-80 (12.347" ID) - 2650` 9-5/8" X 7" Baker Packer/Hanger (6.30" ID) - 6548` 4-1/2" X Nipple (3.813" ID) - 11345` 7" X 4-1/2" Baker S3 Packer - 11366` 4-1/2" X Nipple (3.813" ID) - 11390` 4-1/2" XN Nipple (3.725" ID) - 11413` 4-1/2" WLEG - 11424` 7" X 4-1/2" BKR ZXP PKR/HGR - 11411' 7", 26#, L-80, BTC-M Liner - 11605` 12,100` - 4-1/2", 12.6#, L-80, IBT-M Liner PBTD PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD/EWR/GR ON 02/22/01 ANGLE AT TOP PERF: 53 @ 11834' Note: Refer to Production DB for historical aerf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 11834 - 11854 O 04/16!06 7" LNR, 29#, L-80, ID = 6.184" - 10261 ` GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3479 3478 MMG DOME RKP 16 04/08/06 4 6012 5805 MMG SO RK 20 04!08/06 3 8292 7287 KBG2 DMY BK 0 2 9957 8077 KBG2 DMY BK 0 1 11277 8701 KBG2 DMY BK 0 Minimum ID = 3.725" @ 11413' 4-1 /2" XN Nipple 6712` - 9-5/8" Window 7000` - 5-1/2", 17#, L-80, tbg stub 9000` -Calculated TOC 9184" - 9-5/8" X 5-1/2" AVA PPB PKR, ID = 6.0" 9237` - 9-5/8" X 7" BOT LNR HGR W/TIEBACK SLV 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" 9725` - 3-3/16" X 2-7/8" XO 2-7/8" LNR, 6.5#, L-80, - 11129` DATE REV BY COMMENTS DATE REV BY COMMENTS 05/13!81 ORIGINAL COMPLETION 04/16/06 RRDIPJC ADPERFS 05/17/91 RWO 02!25/01 CTDSIDEfRACK (i6-O6A) 03!30/06 Actual 16-6B Completion 04/11/06 KSB/PAG GLV CIO (04!08/06) PRUDHOE BAY UNfr WELL: 16-06B PERMff No: API No: 50-029-20584-02 SEC. 24, T10N, R15E 1893' SNL & 1121' EWL BP Euploration (Alaska) • • 10-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 16-06B Dear Dear Sir/Madam: Enclosed is one disk with the "`.PTT and *.PDF files. Tie-on Survey: 6,694.50' MD Window /Kickoff Survey: 12,062.24' MD (if applicable) Projected Survey: 12,100.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~- s Date ~d Signed '~~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ,~oc~-®f9 ~,'~~ Ali GPB. Well 16-06B ~ • Subject: GPB Well 16-066 From: "Allen, Kenneth W" <Kenneth.Allen@bp.com> Date: Mon, 20 Mar 2006 09:47:20 -0900 To: Winton Aubert <Winton_aubert@admin.state.ak.us> CC: "Maskell, .Dick" <MaskelCR@bp.com>, "Wesley, Dave E" <Uave.V`Jesley@bp.com> Winton, Early this morning we drilled out of our 7" shoe and performed the FIT on GPB well 16-066 with Nabors 2ES. The ftT only made it to 9.5ppg before it started taking some fluid. We ran he numbers and this still gives us anirt~inite kick tolerance at 9.5ppg. I wanted to give you the notice since the hermit was submitted showing a 10.Oppg FIT. In reality, we should have only submitted the permit with a 9.5ppg FIT. The 6-1 /8" production hole is only 500' for this well and our planned ECD's at the shoe should only reach 9.4ppg with a cuttings load. If you have any questions or need further clarification please give me a call or ~-mail using the contact information listed below. Thanks, Ken Allen Operations Drilling Engineer Mobile: 907.748.3907 Office: 907.564.4366 e-mail: Kenneth.Allen~'a~BP.com 3/20/2006 10:10 AM 1 of 1 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay, PBU 16-06B BP Exploration (Alaska), Inc. Permit No: 206-O1 l Surface Location: 1893' FNL, 1121' FWL, SEC. 24, T10N, R15E, UM Bottomhole Location: 844' FSL, 750' FWL, SEC. 18, T10N, R16E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, `-. _ .~- ~~~ ~"~~~ Daniel T. Seamount Jr. Commissioner ~' DATED this~~day of January, 2006 cc: Department of Fish 8~v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO ISSION °'k~8~l+s~b JAN 2 4 2~~~ PERMIT TO DRILL i~,~,~, 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil Multi a Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 16-066 ~~~''~°G 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12057 TVD 9132 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1893' FNL 1121' FWL SEC 24 T10N R15E UM 7. Property Designation: ADL 028346 Pool , , , , , . Top of Productive Horizon: 786' FSL, 672' FWL, SEC. 18, T10N, R16E, UM 8. Land Use Permit: 13. Approximate Spud Date: February 15, 2006 Total Depth: 844' FSL, 750' FWL, SEC. 18, T10N, R16E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 9500' 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 719911 y- 5929055 Zone- ASP4 10. KB Elevation Plan (Height above GL): 66.5 feet 15. Distance to Nearest well within Pool 1165' 16. Deviated Wells: Kickoff Depth: 6700 feet Maximum Hole Angle: 62 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3667 Surtace: 2838 18. as ng rogram: Size Specifications Setting Depth To Bottom uantity o ement cf. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 5130' 6550' 6250' 11680' 8922' 170 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 526' 11530' 8838' 12056' 9132' 9 sx Class 'G' 19. PRESENT W ELL CONDITI ON SUMM ARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 11132 Total Depth TVD (ft): 9041 Plugs (measured): None Effective Depth MD (ft): 11071 Effective Depth TVD (ft): 9027 Junk (measured): None Casin Len th Size Cement Volume MD TVD n r 80' 20" 00 sx Permafrost 80' 80' 2650' 13-3/8" 000 sx Fondu, 400 sx Permafrost 2650' 2650' 9536' 9-5/8" 500 sx Class 'G' 9536' 8844' Pr i 'n 416' 7" 50 sx Class 'G' 9237' - 9653' 8569' - 8950' Liner 1894' ~-~rz• X ~-ans• x z-~ie• 106 sx Class 'G' 9236' - 11130' 8568' - 9041' Perforation Depth MD (ft): 9876' - 11066' Perforation Depth TVD (ft): 9042' -9026' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jeff Cutler, 564-4,134 Printed Name ave Wesley Title Prepared By NameMumber. Si nature l~`C. Phone 564-5153 Date /~~3/~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ,.Z d6 ~ O/ API Number: 50- 029-20584-02-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ~~No Mud Log Required ^ Yes ~' No Hydrogen Sulfide Measures 'Yes !, J No Directional Survey Required 'Yes ^ No Other: rit° S t ~ O )~(~ '~ ~ SO D ~ ~,' ~~ Zo /~fEC 25.035 ~k~ (t~, alte~~c,1,~c ~0~~ c~,~ >tesf ~trvGec~cti-e ave ~pprt~~t~~,. E ~ ~ APPROVED BY ~ ~~ A roved `~ ~ ~ THE COMMISSION Date Form 10-401 R ve is~06%2004 '.~.'(, `- ' `~'~ ~ `° ' t °"" Submit to Duplicate • ~ Well Name: 16-06B Planned Well Summary Well Slant Hole Target Ivishak Well 16-06B Type Sidetrack Objective Zone 2 Producer AFE Number: PBD4P2455 Surface Northin Eastin Offsets TRS Location 5,929,055 719,911 1,893' FNL/ 1,121' FWL 10N, 15E, 24 API Number: 50-029-20584-02 Target Northin Eastin Offsets TRS Location 5,931,874.5 724,660.9 786' FSL / 672' FWL 10N, 16E, 18 Bottom Northin Eastin Offsets TRS Location 5,931,935 724,737 844' FSL / 750' FWL 10N, 16E, 18 Planned KOP: 6,700' MD / 6,375' TVD Planned TD: 12,056' MD / 9,132' TVD Ri Nabors 2ES / CBE: 38.0' RTE: 66.5' Directional Program l A roved Well Ian: W 06 Exit oint: 6,700' MD / 6,375' TVD Maximum Hole Inclination: ~62° in the tanned intermediate section. Proximity Issues: All wells pass a Major Risk anti-collision survey with the minimum allowable deviation of 83' for 16-04A in the roduction interval at 11,993 MD Survey Program: Standard MWD/IIFR/MS. Nearest Well within pool: Well 16-04 (Plugged and Sidetracked), with center-to-center distance of 1165' @ TSAD, 11,680' MD. Nearest Pro ert Line 9500' to Unit Bounda to East. 16-06B Sidetrack Page 1 • • Logging Program Hole Section: Required Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR throughout the interval, for tie-in purposes MAD pass with GR 250 above the kickoff oint. 6 1/8" roduction: Real time MWD Dir/GR/Res throw hout the interval. Cased Hole: None Planned O en Hole: None tanned Mud Program Hole Section /operation: Mill window in the 9 5/8" casing to 100' above the top of the HRZ 11,200 MD T e Densit Viscosit PV YP API FL HTHP H LSND 9.0-9.4 50-60 15-22 30-40 <6.0 <11 9.0-9.5 Hole Section /operation: Drilling 8 1/2" interval from 100' above the top of the HRZ 11,200 MD to section TD T e Densit Viscosit PV YP API FL HTHP H LSND 0.9 42 - 52 18 - 25 22 - 28 <5.0 <11 9.0 - 9.5 `~~ Hole Section / o eration: Drillin 6 1/8" production interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >25,000 8 - 15 24 - 30 4 - 6 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8 1/2" 7" 26.0# L-80 BTC-M 5,130' 6,550' / 6,250' 11,680' / 8,922' 6 1/8" 4'/z" Solid 12.6# L-80 IBT-M 526' 11,530' / 8,838' 12,056' / 9,132' Tubin 4'/z" 12.6# 13-Cr VamTo 10,295' Surface 11,530' / 8,838' Cementing Program Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner Slurry Design Basis: Lead slurry: None planned. Tail slurry: 1,000' of 7" X 8-1/2" annulus with 40% excess, 85' of 7", 26# shoe track. Pre-Flush None tanned Fluids Se /V l S acer 35 bbls MudPUSH at 12.0 quence ume: o Lead Slur None tanned "~ Tail Slur 35 bbl / 197 cf / 17 sxs Class `G', 15.8 .1 cf/sk. ~_ ~% Casin Strin 4'/z", 12.6#, L-80, IBT-M Production Liner Lead slurry: none planned Slurr Desi n Basis: y g Tail slurry: 376' of 4-~/z" X 6-%8" annulus with 40% excess, plus 85' of 4-~h", " " ' " 12.6# shoe track, plus 100 of 7 X 4-~h liner lap, plus 200 of 7 X 4 drill pipe annulus. 16-066 Sidetrack Page 2 • • Pre-Flush 5 bbls CW 100 Fluids Se uence /Volume: S acer 20 bbls MudPUSH at 9.6 q Lead Slur None tanned Tail Slur 16.5 bbsl / 92.6 ft 79sxs Class `G', 15.8 .1 t /sk. .:,,. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 3,500 si surface 9 5/8" casin window 20' new formation be and FIT 12.0 EMW 7" casin Float a ui ment to surface 30 min recorded 3,500 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4'/z" reduction liner Float a ui ment to surface 30 min recorded 3,500 si surface Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum antici ated BHP: 3,667 psi at 8,297' TVD (based on seawater,8.s ppg, gradient in CMi) Maximum surface ressure: 2,8 "~1SI (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: I mitt with 12.0 pp EMW FIT Planned BOPE test ressure: 0 si low / 3,500 si hi h - 7 da test c cle Pre drillin hase /~ BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams drilling liner. while running 5,130' of 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Well Interval: 6 1/8" production interval Maximum antici ated BHP: 3,350 psi at 8,921' TVD Maximum surface ressure: 2,4 SI (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: init with 10.0 pp EMW FIT. Planned BOPE test ressure: si low / 3,500 si hi h -14 da test c cle Drillin o erations Planned com letion fluid: 8.4 seawater / 6.8 Diesel BPXA requests. a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well .control or equivalent ptatposes, .axes when the routine use of BOP ram type equipment may .have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a teal joint during routine operations.) The activities associated with this request .will .not compromise the integrity of the BOP equipment. 16-06B Sidetrack Page 3 • • Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Formation toffs and estimated pore pressures Est. Est. Formation Formation Tops To s Uncertain Commercial Hydrocarbon Bearin Est. ~` Pore Press. Formation MD (TVDss) (eet) (Yes/No) (Psi) Comments UG4 -4945 +/- 30 No Above KO in on final wellbore UG3 -5050 +/- 30 No Above KO in on 'nal wellbore UGl 6308 -5980 +/- 30 No Pro'ected above KO Point WS2 6915 -6480 +/- 30 No WSl 7242 -6710 +/- 30 No CM2 9349 -7723 +/- 30 No CMl 10433 -8230 +/- 30 No THRZ 11308 -8647 +/- 30 No BHRZ-T5AD (Truncated b LCU) 11680 -8855 +/- 30 No 7" liner set at BHRZ 45N 11680 -8855 +/- 30 Yes 3300 45P 11680 -8855 +/- 30 Yes 3300 44N 11680 -8855 +/- 30 Yes 3300 44P 11680 -8855 +/- 30 Yes 3300 43N 11698 -8865 +/- 30 Yes 3300 43P 11703 -8868 +/- 30 Yes 3300 42N 11716 -8875 +/- 30 Yes 3300 42P 11742 -8890 +!- 30 Yes 3300 41N 11746 -8892 +/- 30 Yes 3300 41P 11748 -8893 +/- 30 Yes 3300 31N 11770 -8905 +/- 30 Yes 3300 31P 11771 -8906 +/- 30 Yes 3300 27N 11895 -8975 +/- 30 Yes 3300 27P 11897 -8976 +/- 30 Yes 3300 26N 11984 -9025 +/- 30 Yes 3300 26P 11990 -9028 +/- 30 Yes 3300 MHO/HOT 11957 -9010 +/- 30 Yes 3300 TD Criteria: TD according to wellplan or after decision by town and rig drilling team. Drill enough rathole to be able to aet resistivity loos across the tog of the HOT. 16-06B Sidetrack Page 4 • • Oaerations Summar Current Condition: / Currently SI due to low productivity. / RWO, with new 5-1/2'; 17#, L-80 tubing, completed 03/2004 / 9-5/8'; 47#, L-80 casing landed at 9,536'. / 5-1/2'; 17#, L-80 tubing landed in AVA seal assy. at 9,183'. / 9-5/8" X 5-1/2"AVA PPB packer at 9,184'. / Top of 3-3/16" CTD liner at 9,236'. / 5-1/8 FMC tree with 13-5/8'; 5K FMC Gen 11 wellhead. SCOpe Pre-Riq Operations: 1. Replace all live gas lift valves with dummy valves and fluid pack as necessary for CT P&A. 2. RU SL and drift tbg to the 5-1/2" AVA locator seal assembly C«~ 9183" MD 3. RIH with CT and P&A the 16-06A well bore. Pump ~17 bbls of 15.8 ppg cement, leaving TOC in the 5-1/2" tbg at 9,000' MD. Cement volume based on: 1,346' of 2-7/8", 6.5#, (cap. = 0.00578 bbl/ft), liner -volume = 7.8 bbls. 489' of 3-3/16", 6.2#, (cap. = 0.0076 bbl/ft), liner -volume = 3.7 bbls. 236' og 5-1/2", 17#, (cap. = 0.0232 bbl/ft), tubing -volume = 5.5 bbls. 4. RU SL, RIH and drift 5-1/2" tbg to below cut depth of 7,000 MD. If able continue RIH and tag cement to verify TOC depth. 5. RIH with the appropriate chemical cutter and cut the 5'/z" tubing at 7,000' MD. 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. 7. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all lock down screws, repair or replace as needed. 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPV. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. 4. R/U. Pull 5'/z" tubing from the cut at 7,000' MD and above. 5. R/U E-line. M/U 8.5" gauge ring /junk basket / CCL. RIH and tag tubing stump. POH. 6. RIH with HES EZSV on E-line. Set bridge plug at -6,724', as required to avoid cutting a casing collar while milling the window. POH. R/D E-line. 7. Pressure-test the 9-5/8 casin to 3 500 si for 30 minutes. Record test. 9 p 8. P/U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly on 4" DP. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. ~-~S to _ ~1D. Mill window in 9-518" casing at ± 6,700' MD, plus approximately 20' beyond middle of window. ( Circulate well bore clean. a~P~1~~- 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POH. ~..1G-~' 12. M/U 8~h" Dir/GR/PWD assembly. RIH, kick off and drill the 8'h" intermediate section to 100' above / the HRZ with 9.0 - 9.3 ppg LSND. 13. By 11,200' MD (100' above the top of the HRZ) have the entire circulating system weighted up to 10.9 ppg with spike fluid from the MI plant. 16-066 Sidetrack Page 5 • • 14. Continue drilling ahead to the 7" liner point at top of the Ivashak, as per the directional plan. The Sag River is truncated by the LCU in this area so the liner pick will be done using an isopach data for the HRZ. Circulate well clean, short trip to window. POH. 15. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 3,500 psi. ~ 16. M/U 6-%8" Dir/GR/Res assembly. RIH to the 7" liner landing collar. 17. Drill out the 7" liner float equipment and cement to the shoe. 18. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 19. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to TD per directional proposal. 20. Circulate well bore clean, short trip to shoe, circulate. POH. 21. Run and cement 4'/z", 12.6#, L-80, IBT-M solid production liner. During displacement spot a pert pill inside the 4-1/2" liner. POH. 22. RU and RIH with DPC pert gun. Planned perfs are 2-7/8" PowerJets at 6 spf 23. R/U and run a 4'/z", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4'/z" liner tie back sleeve. 24. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 25. Set a BPV. 26. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. ~` 27. Freeze protect the well to 2,200' TVD. Secure the well. 28. Rig down and move off. Post-Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Job 1: Move In /Riq Up /Test BOPE Planned Job Time Planned Job Cost 55.9 hours $249,000 includes $120K re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - 16-05 is 120' to the North and will not require shut-in for the rig to move onto 16-06, there is no well to the South. Check the spacing and alert the pad operator prior to moving onto the well. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the 16-06 well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the 16-06A well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. /° 16-06B Sidetrack Page 6 • • Drill Site 16 is Signated as a H2S Site. Standard Operating Procedures for H2S precautions must be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 16-05 NA 16-03 NA 16-04 102 16-25 35 The maximum level recorded of H2S on the pad w 45 pm in well 16-21 on 05/28/2005. ~ - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Job 2: De-complete Well Planned Job Time Planned Job Cost 31.2 hours $129,000 Reference RP • "De-completions" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - The wellhead is a 13-5/8", 5K FMC Gen I1. Check with FMC to ensure all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. Make sure the BOT rep has grapples for both 15.5# and 17# tubing on location. - There is a 5-'/2" Camco BAL-O SSSVN set at 2182'. - Run GR/CCL Log from the bridge plug setting depth to 200' above the KO point after setting the EZSV. Job 3: Run Whip Stock Planned Job Time Planned Job Cost 27.6 hours $215,000 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - There is no historical data on the cement behind the 9-5/8" casing. 16-06B Sidetrack Page 7 • • - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Job 5: Drill 8-1/2" Intermediate Hole Interval Planned Job Time Planned Job Cost 151.7 hours $929,000 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - Tie MWD - GR back to PDC log from parent wellbore. - The Kingak in this well has been truncated by the LCU, the HRZ will require a mud weight of 10.9 PPg• - The directional plan has the wellbore building to 62 degrees then dropping to 56 degrees above the THRZ and holding this angle to the 7" liner point. - From milling the window to 100' above the top of the HRZ maintain the mud weight at 9.0 - 9.4 ppg. At 100 above the HRZ weight up the mud to 10.9 ppg with spike fluid from the MI mud plant, Maintain mud weight at 10.9 ppg, from 100' above the HRZ to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure at the CM1 depth, a fracture gradient of 11.5 ppg at the 9-5/8" casing window, and 10.9 ppg mud in the hole, the kick ~ tolerance is infinite. - The above kick tolerance is based on an FIT of 11.5 ppg EMW, the well plan calls fora 12.0 ppg EMW FIT for an extra margin of safety. Contact the ODE if a FIT of 11.5 ppg EMW is not reached. Job 6: Run and Cement 7" Intermediate Casing Planned Job Time Planned Job Cost 34.8 hours $365,000 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP :• "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab/surge pressures could initiate HRZ instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. 16-06B Sidetrack Page 8 ~ • - As per the Kingak/HRZ drilling RP centralization will be minimized on the 7" liner. Run 1 straight blade solid centralizer free floating on the bottom two joints of the 7" liner. Job 7: Drill 6 1/8" Production Hole Interval Planned Job Time Planned Job Cost 54.5 hours $342,000 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - The directional plan has the wellbore entering the Ivishak at 56 degrees and holding tangent to TD. - KICK TOLERANCE: In the worst-case scenario of 3,350 psi pore pressure in the Ivishak, a fracture gradient of 10.0 ppg at the 7" liner shoe, and 8.4 ppg mud in the hole, the kick tolerance ~,- is infinite. - The above kick tolerance is based on an FIT of 10.0 ppg EMW, contact the ODE if this EMW is not reached. - One of the well objective is to provide resistivity logs across the top of the HOT, this will be a factor in determining TD. - 16-066 is expected to cross a single, small fault at 10,647' MD, +/-3000', 8396' TVD. The throw is estimated at ~10', losses are not expected. Job 9: Run and Cement 4~/s" Production Liner Planned Job Time Planned Job Cost 12 hours $127,000 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4'h", 12.6#, L-80, IBT-M solid liner throughout the production interval. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be ~675psi over balanced to the Ivishak Zone 2 formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4-~h" liner will be run to extend 150' back up into the 7" liner shoe. - Ensure the 4-~/z" liner top packer is set prior to POH. 16-06B Sidetrack Page 9 • • Job 10: DPC Perforate Well Planned Job Time Planned Job Cost 32.9 hours $127,000 Hazards and Contingencies - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with pert guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot tag the landing collar due to cement/fill. Reference RPs • DPC Perforating RP • Schlumberger DPC Perforating Guidelines Job 12: Run 4 ~/x" 13-Cr Completion Planned Job Time Planned Job Cost 29hours $915,000 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 Asia at 100° F. - The completion, as designed, will be to run a 4~h", 12.6#, 13-Cr, VamTop production tubing string, stinging into the 4 ~h" liner tieback sleeve. Job 13: ND/NU/Release Rig Planned Job Time Planned Job Cost 12.0 hours $43,000 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - 16-05 is 120' to the North and will not require shut-in for the rig to move off of 16-06, there is no well to the South. Alert the pad operator prior to moving off of the well. Care should be taken while moving onto the well. Spotters should be employed at all times. 16-06B Sidetrack Page 10 TREE = 5-1 /8" FAAC W~LHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 72.0' BF. E3.EV = NA KOP = 4300' Max Angle = 99 @ 10190' Datum MD = 9567' Datum TV D = 8800' SS 16-0~ Proposed Completion GAS LIFT MANDRELS 4-1/2" X Nipple (3.813" ID) - 2200' 13-3/8" 72#, L-80 (12.347" ID) - 2650` 9-5/8" X 7" Baker Packer/Hanger (6/25" ID) - 6550` 4-1/2" X Nipple (3.813" ID) - 114200` 7" X 4-1/2" Baker S3 Packer - 11440` 4-112" X Nipple (3.813" ID) - 11460` 4-1/2" X Nipple (3.813" ID) - 11480` 4-1/2" XN Nipple (3.725" ID) - 11500' 4-1/2" WLEG - 11520` 7" X 4-1/2" BKR ZXP PKR/HGR - 11530` 7", 26#, L-80, BTC-M Liner - 11680` 4~?' - 4-1/2", 12.6#, L-80, IBT-M Liner PBTD IZoSt:' ~Uf~ PERFORATION SLRuhAF\RY REF LOG: SPERRY-SUN MWD/EWR/GR ON 02/22/01 ANGLE AT TOP PERF: 97 @ 9876' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9876 - 9940 S 07/07/01 2" 4 9972 - 10044 S 07/07/01 2" 4 10090 - 10112 S 07/07/01 2" 4 10150 - 10168 S 07/07/01 2" 6 10774 - 10804 S 02/24/01 2" 6 10838 - 10872 S 02/24/01 2" 6 11000 - 11020 S 02/24/01 2" 6 11050 - 11066 S 02/24/01 7" LNR, 29#, L-80, ID = 6.184" - 10261' 2-7/8" LNR, 6.5#, L-80, - 11129' Y DATE REV BY COMMBJTS DATE REV BY COMMENTS 05/13/81 ORIGINAL COMPLETION 12/05/05 JNC Roposed 16-O6B Completion 05/17/91 RWO 01/02/01 SIS-QAA CONVERTED TO CANVAS 02/25/01 CTDSIDETRACK (16-O6A) 04/09/02 CWTP CORRECTIONS PRUDIiOE BAY UNfr WELL: 16-06A PERMrr No: API No: 50-029-20584-02 SEC. 24, T10N, R15E 1893' SNL 8 1121' EWL BP Exploration (Alaska) ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3500 3500 MMG DMY 4 6004 5800 MMG DMY 3 8300 7295 MMG DMY 2 10000 8072 MMG DMY 1 11745 8958 MMG DMY Minimum ID = 3.375" @ 11500' 4-i'2" XN Nipple 6700` - 9-5/8"Window 7000` - 5-1/2", 17#, L-80, tbg stub 9000` -Calculated TOC 9184" - 9-5/8" X 5-1/2" AVA PPB PKR, ID = 6.0" 1 9237` - 9-5/8" X 7" BOT LNR HGR W/ TIEBACK SLV j-- 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" 9725' - 3-3/16" X 2-7/8" XO F 0] ~ z _ F = _ 5 _ ~ ~ v ;, ~, ~~T~x~ 9 O c ~ ~ ~-orc i? 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Dir. ft ft ft ft ft 16-066 T1 9066.50 2680.00 4830.00 5931874.46 724660.88 70 12 57.478 N 148 11 15.665 W -Plan hit target S err -Sun • P Y BP Planning Report Company: BP Amoco Date: 12/13/2005 Time: 12:37:13 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-06, True North Site: PB DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-06 Section (VS) Reference: Well (O.OON,O.OOE,60.84Azi) Wellpath: Plan 16-06B Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 6700.00 33.21 85.32 6375.07 128.57 1196.35 0.00 0.00 0.00 0.00 6720.00 34.91 82.30 6391.64 129.79 1207.49 12.00 8.52 -15.08 -46.00 7578.15 62.11 53.27 6961.32 397.56 1771.77 4.00 3.17 -3.38 -49.54 11151.81 62.11 53.27 8632.88 2286.74 4303.16 0.00 0.00 0.00 0.00 11304.61 56.00 53.26 8711.41 2365.09 4408.14 4.00 -4.00 0.00 -179.95 11939.61 56.00 53.26 9066.50 2680.00 4830.00 0.00 0.00 0.00 0.00 16-06B T1 12056.55 56.00 53.26 9131.89 2737.99 4907.69 0.00 0.00 0.00 0.00 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUComme 1 ft deg deg ft ft ft ft ft deg/100ft ft ft 6700.00 33.21 85.32 6375.07 6308.57 1107.40 128.57 1196.35 0.00 5929218.43 721103.23 Start Dir 12/10 6720.00 34.91 82.30 6391.64 6325.14 1117.71 129.79 1207.49 12.00 5929219.96 721114.32 Start Dir 41100 6800.00 37.06 78.26 6456.38 6389.88 1162.03 137.76 1253.79 4.00 5929229.28 721160.37 MWD+IFR+MS 6900.00 39.92 73.76 6534.66 6468.16 1222.08 152.87 1314.12 4.00 5929246.14 721220.24 MWD+IFR+MS 7000.00 42.93 69.77 6609.65 6543.15 1287.02 173.62 1376.90 4.00 5929268.71 721282.38 MWD+IFR+MS 7100.00 46.06 66.22 6680.99 6614.49 1356.53 199.92 1441.82 4.00 5929296.89 721346.51 MWD+IFR+MS 7200.00 49.29 63.03 6748.32 6681.82 1430.28 231.64 1508.57 4.00 5929330.54 721412.31 MWD+IFR+MS 7300.00 52.60 60.14 6811.33 6744.83 1507.90 268.62 1576.83 4.00 5929369.49 721479.45 MWD+IFR+MS 7400.00 55.98 57.49 6869.70 6803.20 1589.02 310.69 1646.25 4.00 5929413.55 721547.62 MWD+IFR+MS 7500.00 59.40 55.05 6923.15 6856.65 1673.24 357.63 1716.51 4.00 5929462.52 721616.47 MWD+IFR+MS 7578.15 62.11 53.27 6961.32 6894.82 1740.95 397.56 1771.77 4.00 5929504.04 721670.55 End Dir :7578 7600.00 62.11 53.27 6971.54 6905.04 1760.10 409.11 1787.25 0.00 5929516.03 721685.68 MWD+IFR+MS 7700.00 62.11 53.27 7018.32 6951.82 1847.71 461.97 1858.08 0.00 5929570.94 721754.94 MWD+IFR+MS 7800.00 62.11 53.27 7065.09 6998.59 1935.33 514.84 1928.92 0.00 5929625.84 721824.21 MWD+IFR+MS 7900.00 62.11 53.27 7111.86 7045.36 2022.94 567.70 1999.75 0.00 5929680.74 721893.47 MWD+IFR+MS 8000.00 62.11 53.27 7158.64 7092.14 2110.56 620.57 2070.59 0.00 5929735.64 721962.73 MWD+IFR+MS 8100.00 62.11 53.27 7205.41 7138.91 2198.17 673.43 2141.42 0.00 5929790.54 722031.99 MWD+IFR+MS 8200.00 62.11 53.27 7252.19 7185.69 2285.79 726.29 2212.25 0.00 5929845.45 722101.25 MWD+IFR+MS 8300.00 62.11 53.27 7298.96 7232.46 2373.40 779.16 2283.09 0.00 5929900.35 722170.52 MWD+IFR+MS 8400.00 62.11 53.27 7345.74 7279.24 2461.02 832.02 2353.92 0.00 5929955.25 722239.78 MWD+IFR+MS 8500.00 62.11 53.27 7392.51 7326.01 2548.63 884.89 2424.76 0.00 5930010.15 722309.04 MWD+IFR+MS 8600.00 62.11 53.27 7439.29 7372.79 2636.25 937.75 2495.59 0.00 5930065.05 722378.30 MWD+IFR+MS 8700.00 62.11 53.27 7486.06 7419.56 2723.86 990.61 2566.43 0.00 5930119.96 722447.56 MWD+IFR+MS 8800.00 62.11 53.27 7532.83 7466.33 2811.48 1043.48 2637.26 0.00 5930174.86 722516.83 MWD+IFR+MS 8900.00 62.11 53.27 7579.61 7513.11 2899.09 1096.34 2708.10 0.00 5930229.76 722586.09 MWD+IFR+MS 9000.00 62.11 53.27 7626.38 7559.88 2986.71 1149.21 2778.93 0.00 5930284.66 722655.35 MWD+IFR+MS 9100.00 62.11 53.27 7673.16 7606.66 3074.32 1202.07 2849.77 0.00 5930339.56 722724.61 MWD+IFR+MS 9200.00 62.11 53.27 7719.93 7653.43 3161.93 1254.93 2920.60 0.00 5930394.47 722793.87 MWD+IFR+MS 9300.00 62.11 53.27 7766.71 7700.21 3249.55 1307.80 2991.44 0.00 5930449.37 722863.14 MWD+IFR+MS 9348.73 62.11 53.27 7789.50 7723.00 3292.25 1333.56 3025.96 0.00 5930476.12 722896.89 CM2 9400.00 62.11 53.27 7813.48 7746.98 3337.16 1360.66 3062.27 0.00 5930504.27 722932.40 MWD+IFR+MS 9500.00 62.11 53.27 7860.25 7793.75 3424.78 1413.53 3133.10 0.00 5930559.17 723001.66 MWD+IFR+MS 9600.00 62.11 53.27 7907.03 7840.53 3512.39 1466.39 3203.94 0.00 5930614.07 723070.92 MWD+IFR+MS 9700.00 62.11 53.27 7953.80 7887.30 3600.01 1519.26 3274.77 0.00 5930668.97 723140.18 MWD+IFR+MS 9800.00 62.11 53.27 8000.58 7934.08 3687.62 1572.12 3345.61 0.00 5930723.88 723209.45 MWD+IFR+MS 9900.00 62.11 53.27 8047.35 7980.85 3775.24 1624.98 3416.44 0.00 5930778.78 723278.71 MWD+IFR+MS 10000.00 62.11 53.27 8094.13 8027.63 3862.85 1677.85 3487.28 0.00 5930833.68 723347.97 MWD+IFR+MS 10100.00 62.11 53.27 8140.90 8074.40 3950.47 1730.71 3558.11 0.00 5930888.58 723417.23 MWD+IFR+MS 10200.00 62.11 53.27 8187.67 8121.17 4038.08 1783.58 3628.95 0.00 5930943.48 723486.49 MWD+IFR+MS 10300.00 62.11 53.27 8234.45 8167.95 4125.70 1836.44 3699.78 0.00 5930998.39 723555.76 MWD+IFR+MS 10400.00 62.11 53.27 8281.22 8214.72 4213.31 1889.30 3770.62 0.00 5931053.29 723625.02 MWD+IFR+MS 10432.66 62.11 53.27 8296.50 8230.00 4241.93 1906.57 3793.75 0.00 5931071.22 723647.64 CM1 10500.00 62.11 53.27 8328.00 8261.50 4300.93 1942.17 3841.45 0.00 5931108.19 723694.28 MWD+IFR+MS S err -Sun • P Y BP Planning Report Company: BP Amoco Date: 12/13/2005 . Time: 12:37:13 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-06, True North Site: PB DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-06 Section (VS) Reference: Well (O.OON,O.OOE,60.84Azi) Wellpath: Plan 16-06B Survey Calculation Method: Minimum Curvature Db: Oracle MD ft Incl deg Azim deg TVD ft Sys TVD ft VS ft N/S ft E/W ft DLS deg/100ft MapN ft MapE ft TooUComme 1 10600. 00 62.11 53. 27 8374 .77 8308. 27 4388 .54 1995.03 3912.29 0.00 5931163 .09 723763 .54 MWD+IFR+MS 10700. 00 62.11 53. 27 8421 .55 8355. 05 4476 .16 2047.90 3983.12 0.00 5931217 .99 723832 .80 MWD+IFR+MS 10800. 00 62.11 53. 27 8468 .32 8401. 82 4563 .77 2100.76 4053.96 0.00 5931272 .90 723902 .07 MWD+IFR+MS 10900. 00 62.11 53. 27 8515 .10 8448. 60 4651 .38 2153.62 4124.79 0.00 5931327. 80 723971 .33 MWD+IFR+MS 11000. 00 62.11 53. 27 8561 .87 8495. 37 4739 .00 2206.49 4195.62 0.00 5931382. 70 724040 .59 MWD+IFR+MS 11100. 00 62.11 53. 27 8608 .64 8542. 14 4826 .61 2259.35 4266.46 0.00 5931437. 60 724109 .85 MWD+IFR+MS 11151. 81 62.11 53. 27 8632 .88 8566. 38 4872 .01 2286.74 4303.16 0.00 5931466. 05 724145 .74 Start Dir 4/100 11200. 00 60.18 53. 26 8656 .13 8589. 63 4913 .84 2311.99 4336.98 4.00 5931492. 26 724178 .81 MWD+IFR+MS 11300. 00 56.18 53. 26 8708 .84 8642. 34 4998. 06 2362.80 4405.07 4.00 5931545. 04 724245 .38 MWD+IFR+MS 11304. 61 56.00 53. 26 8711 .41 8644. 91 5001. 86 2365.09 4408.14 4.00 5931547. 42 724248 .38 End Dir :1130 11308. 35 56.00 53. 26 8713 .50 8647. 00 5004. 92 2366.95 4410.62 0.00 5931549. 34 724250 .81 THRZ 11400. 00 56.00 53. 26 8764. 75 8698. 25 5080. 24 2412.40 4471.51 0.00 5931596. 55 724310 .35 MWD+IFR+MS 11500. 00 56.00 53. 26 8820. 67 8754. 17 5162. 42 2461.99 4537.94 0.00 5931648. 05 724375 .31 MWD+IFR+MS 11600. 00 56.00 53. 26 8876. 59 8810. 09 5244. 60 2511.58 4604.38 0.00 5931699. 55 724440 .27 MWD+IFR+MS 11680. 31 56.00 53. 26 8921. 50 8855. 00 5310. 60 2551.41 4657.73 0.00 5931740. 92 724492 .44 7" 11698. 20 56.00 53. 26 8931. 50 8865. 00 5325. 30 2560.28 4669.61 0.00 5931750. 13 724504 .06 43N 11700. 00 56.00 53. 26 8932. 51 8866. 01 5326. 78 2561.17 4670.81 0.00 5931751. 06 724505 .23 MWD+IFR+MS 11703. 56 56.00 53. 26 8934. 50 8868. 00 5329. 70 2562.94 4673.18 0.00 5931752. 89 724507 .54 43P 11716. 08 56.00 53. 26 8941. 50 8875. 00 5339. 99 2569.15 4681.49 0.00 5931759. 34 724515 .67 42N 11742. 90 56.00 53. 26 8956. 50 8890. 00 5362. 04 2582.45 4699.31 0.00 5931773. 15 724533 .10 42P 11746. 48 56.00 53. 26 8958. 50 8892. 00 5364. 97 2584.22 4701.69 0.00 5931774. 99 724535 .42 41 N 11748. 27 56.00 53. 26 8959. 50 8893. 00 5366. 44 2585.11 4702.88 0.00 5931775. 91 724536 .58 41 P 11769. 73 56.00 53. 26 8971. 50 8905. 00 5384. 08 2595.75 4717.14 0.00 5931786. 97 724550 .52 31 N 11771. 52 56.00 53. 26 8972. 50 8906. 00 5385. 55 2596.64 4718.32 0.00 5931787. 89 724551 .68 31 P 11800. 00 56.00 53. 26 8988. 43 8921. 93 5408. 96 2610.76 4737.25 0.00 5931802. 56 724570. 19 MWD+IFR+MS 11894. 91 56.00 53. 26 9041. 50 8975. 00 5486. 95 2657.83 4800.30 0.00 5931851. 44 724631. 84 27N 11896. 70 56.00 53. 26 9042. 50 8976. 00 5488. 42 2658.72 4801.49 0.00 5931852. 36 724633. 00 27P 11900. 00 56.00 53. 26 9044. 35 8977. 85 5491. 14 2660.36 4803.68 0.00 5931854. 06 724635. 15 MWD+IFR+MS 11939. 61 56.00 53. 26 9066. 50 9000. 00 5523. 69 2680.00 4830.00 0.00 5931874. 46 724660. 88 16-066 T1 11957. 50 56.00 53. 26 9076. 50 9010. 00 5538. 39 2688.87 4841.88 0.00 5931883. 67 724672. 50 MHO/HOT 11984. 32 56.00 53. 26 9091. 50 9025. 00 5560.43 2702.17 4859.70 0.00 5931897. 49 724689. 92 26N 11989. 69 56.00 53. 26 9094. 50 9028. 00 5564. 84 2704.83 4863.27 0.00 5931900. 25 724693. 41 26P 12000. 00 56.00 53. 26 9100. 27 9033. 77 5573. 32 2709.95 4870.12 0.00 5931905. 56 724700. 11 MWD+IFR+MS 12056. 00 56.00 53. 26 9131. 58 9065. 08 5619. 34 2737.72 4907.32 0.00 5931934. 41 724736. 49 4 1 /2" 12056. 55 56.00 53. 26 9131. 89 9065. 39 5619. 79 2737.99 4907.69 0.00 5931934. 69 724736. 84 MWD+IFR+MS NJiLL Ulrrnas ANTI-COLLISION SEThIN(.;S ronu'nNS Dlrl:\as st!KC1:v reucRn M1l Hare ~N'-$ '1-N' Nulling lading LaliulJ. Lun1:UWc SI„1 Infspulation N1e1hoJ:MD Intenal: ?i.UD lil'nnl,a~„ U.~I,Ih l~nl D.~1xll ),i tiun.•)I'I~n Inul 15x15 IS%3.14 4v ~4'wl..i' '1441114 -J~I_'\II SN IJ,s'-Ii'r ,Xln\1 lu, ()~I)Ih Run_~•Cn)In- 671111.1111 Tlr. ~IIi(,.iJ C'al:ulunun Nl.•dlul~hWunlun tunulw. 51x1. NI 1'U36._5 I'Iwulul. 16 n61t \lix M, V'U M1I\\U UKM111 M1l;ullnunl Rung'. lill'_.icU It~li'!~'ll.._ PI:In_ 16-11611 \\11116 1~mx Syuent IS['\\s.\ S.an Atclh,xi' lra~ (~\-IinJ~~r N,nUI I~:rtur Suns..: Lllipnwl - C:.cing \\annng Ak h,xt Rule. It:~v 1 60 - Kkm 16tX5K 'olour To MD 150 - 500 ISnm \\bl¢X,W: 16+16 Ul1 1 • MU 6]iM1 - I UUU 1. ,m : . - ISUU K.(. I}ansl~' i%~'_%.5 6fi.31H1 - 2(]UU ' \ ti.~.x6m fkigin lkigul Starting 125 3000 mr+~- nal luel zxsu - 3500 - 4000 - 4500 - 5000 u~:uenD 100 5500 ~~;:~~„I~;a~~~:~~;;~k~ - 6000 16-nJ 115auL M1t1;or Kisk - - 7VUI) _ jM1~:1K'I.I~i.A U 11hA13u~M1i ~ II _..-__. ~~~~) . n -- le-U3115-n5,\1. M1l:ll,x Kisk (~!~ >V~~ 16-Un IIhJIO1. N()I.KKI)ItS ~ I1,-115111.116,\I. NI)I:KKUKS 7S - 11000 II.I 14115x141. M1i:lj„r Kisk ~ 15-IIYn 116-I X1,11. M1lrljlx Ki 12000 'I ' II ~ 1 ~ Ih-III \ 115 ln\ . M1I:U x KisA 1 3000 16-II116-IIL M1l:,jar Kick - 14000 ~ Ili-I?III,-I'_I. Alajur Kisk - u,-en 115-en1. M1l:lj„r w.k 50 15000 16~IN II5-I%A M1lajnr KUk ~ II ?UI ?n lll Alx r Ki k . . . ju c II*'_'_ 116-'''1. M1lnj„r Ki.k I<.'i lln-?i1. A1xI~r Ki~'k Il,-'_i II(~'_,1.\I. Aluj,r Kisk In."'?IIfi-'?,\1'131 1. Alaj.x Kuk - II.L II(~'_JI. Af:lj„r Kisk I<.'_311h-?t1. A1:,1'x Kisk 25 ~ I(.~I,I II~'nt Maj.x Ki.k Irr_I„\ II( _5n1. Alar,r Kiss: I1.~6.\PN I !I b__^5:\I'li i 1. hiulur Kisk IM_'b,\I'li'_ 116-_'S,\1'11'_1. Afaj4r KiJ: II.?7115-?]1. M1lnl,x Kisk 16-_']:\ ll6-~'nl. XI4hx Kid'. IM?],\1'111 (Ilr-?]:\YUII. Afelnr Risk I bi l I I ~J I t Ma)<x Kisk r~ V ~ Plan 15~X.If ~ IMIX,K xPIM 25 50 75 100 125 In.~ :1n -I\'U W-S ~1:,-K UL.•g Iracc \'Sec T:ug.t 150 160 ~, Travelling Cylinder Azi-nuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOft/in] J_ 11.?I N5.3? ii 41 %..111 h'_.Il 51.27 56.1X1 31.'_5 36.W SJ-~6 56.1X1 5.1.2fi hi" t 11- 6?41 M 5w, I?'_ NI~1~ %% %"111 J1 WXx1511 4111 K4 12x.57 1'_4.]4 147.56 "XI, ]J '_355114 11.44 IIWr.iS UIXI II.W IIU].W I _'U7.J4 12.1X1 -Ib.W 1117.71 1771.77 J.W J4.3J I]J11.95 Jllll Ifi II1X1 11011 JN]'!111 1{INt.IJ J.W -I ]4.43 51X11.%5 J%31tIX1 01X1 II.W 33'_1.64 Ih~N,Ii TI JW(„54 01X1 II.UII 3614_79 Sperry-Sun • Anticollision Report Company: BP Amoco Date: 12/13/2005 Time: 12:39:32 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 16 Co-ordinate(NE) Refe rence: Well: 16-06, True North Reference Well: 16-06 Vertical (TVD) Reference: 38+28.5 66.5 Reference Wellpath: Plan 16-066 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Tll~eidi@~ls in this fRl8lcipal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 6700.00 to 12056.55 ft Scan Method: Trav Cylinder North Maximum Radius: 1402.80 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/31/2005 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 94.50 6700.00 1 : Sperry-Sun BOSS gyro multi (94. 50-102483~~GYRO Sperry-Sun BOSS gyro multishot 6700.00 12056.55 Planned: 16-068 wp06 V20 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 11680.31 8921.50 7.000 8.500 7" 12056.00 9131.58 4.500 6.125 41/2" Summary ~_~____________ Offset Wellpath ---------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 16 16-02 16-02 V1 10447.36 9825.00 1333.12 728.94 604.18 Pass: Major Risk PB DS 16 16-03 16-03 V1 9303.99 9125.00 1101.99 646.37 455.63 Pass: Major Risk PB DS 16 16-04 16-04 V1 12000.19 11200.00 819.89 721.02 98.88 Pass: Major Risk PB DS 16 16-04A 16-04A V1 11993.18 11250.00 997.70 914.09 83.61 Pass: Major Risk PB DS 16 16-05 16-05 V1 6707.53 6850.00 1365.97 340.57 1025.40 Pass: Major Risk PB DS 16 16-05 16-05A V5 6707.53 6850.00 1365.97 340.57 1025.40 Pass: Major Risk PB DS 16 16-06 16-06 V3 6700.00 6700.00 0.00 No Reference Casings PB DS 16 16-06 16-06A V2 6700.00 6700.00 0,00 No Reference Casings PB DS 16 16-09 16-09 V1 Out of range PB DS 16 16-09A 16-09A V1 Out of range PB DS 16 16-10 16-10 V1 Out of range PB DS 16 16-10A 16-10A V3 Out of range PB DS 16 16-11 16-11 V1 Out of range PB DS 16 16-12 16-12 V1 Out of range PB DS 16 16-12A 16-12A V3 Out of range PB DS 16 16-18 16-18 V1 Out of range PB DS 16 16-20 16-20 V1 Out of range PB DS 16 16-22 16-22 V1 Out of range PB DS 16 16-23 16-23 V1 Out of range PB DS 16 16-23 16-23A V4 Out of range PB DS 16 16-23 16-23APB1 V10 Out of range PB DS 16 16-24 16-24 V1 Out of range PB DS 16 16-25 16-25 V1 6704.20 6900.00 928.50 142.54 785.96 Pass: Major Risk PB DS 16 16-26 16-26 V1 Out of range PB DS 16 16-26A 16-26A V2 Out of range PB DS 16 16-26APB1 16-26APB1 V2 Out of range PB DS 16 16-26APB2 16-26AP62 V4 Out of range PB DS 16 16-27 16-27 V1 8769.64 8175.00 374.91 230.60 144.31 Pass: Major Risk PB DS 16 16-27A 16-27A V1 8769.64 8175.00 374.91 230.60 144.31 Pass: Major Risk PB DS 16 16-27APB1 16-27APB1 V1 8769.64 8175.00 374.91 230.60 144.31 Pass: Major Risk PB DS 16 16-31 16-31 V1 Out of range Site: PB DS 16 Well: 16-02 Rule Assigned: Major Risk Wellpath: 16-02 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9044.98 7647.42 8225.00 7228.52 48.37 140.73 343.02 289.75 1402.21 571.77 830:44 Pass 9067.81 7658.10 8250.00 7248.11 48.40 141.59 342.61 289.35 1400.29 575.42 824.87 Pass 9090.60 7668.76 8275.00 7267.74 48.43 142.45 342.20 288.93 1398.47 579.08 819.40 Pass 9113.34 7679.40 8300.00 7287.43 48.46 143.31 341.78 288.51 1396.76 582.71 814.05 Pass l4 /3 23 2d rio ~ , ~iSE, ~~ ~- v ' ~r - ~ ~ /0/3' ~/ ~ a ; ~ ~~ m i ~ /034' \ ~'2 1 /O56 ' N m; ~~ ~i ~3 I ,~ i D.S. 16 - CONDUCTORS 1 THRU 6 AS BUILT LOCATIONS STATE PLANE LAT & LONG ti 1° Y = 5,929,642,07 L5. Y = 5,929,172.41 X = 719,785,36 X = 719,886.49. LAT = 70°12136.942" LAT = 70°12132.296" LONG = 148°13'39.055" LONG = 148°1336.518" ~ 2. Y 5,929,524.77 ~ 6° Y = 5,9290055.05 X = 719,810.53 X = 719,911.44 LAT = 70°1235°782" LAT = 70°12131.135" LONG = 148°13138.425" LONG = 148°13135.893" ~ 3. Y = 5,929,407,32 I HEREBY CERTIFY THAT I AM X = 719,835 80 PROPERLY REGISTERED AND LICENSED LAT = 70°1234.620" TO PRACTICE LAND SURVEYING IN LONG = 148°13137.790" THE STATE OF ALASKA AND THAT ~~~~~~~\\ THIS PLAT REPRESENTS AN ASS+~~.OFq~q\~) 4• Y = 5, 929, 290.09 BUILT SURVEY MADE BY ME, ~~ •• '•-. 5,~,1~ X = 719, 86118 THAT ALL D I MENS I ONS AND QF~R .•~ ~ LAT = 70°12133.460" DETAILS RE CORRECT, AS ~I~l; 49TH • *~~ LONG = 148°13137.153" DATE 28~~~ ~... ......~. ....... ... er~~: al~l~larr;~~ Col ® ~ •. No. 4277-S .; ~+° ~ ~ e a~ ~ 11~ ~O'~ P'~~ffSSIONAI~~=~~-~ t ~~ s: /h / ~ 6 COrI/Ol/lTOr4 AS mil//Lr AtlanticRichfieldCompany Q DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION /SEP~O ALASKA DISTRICT - PRUDHOE BAY TERRIE L RUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO T`HE ORDER OF First°NatiorPal~Bank Alaska ' Anchorage, AK 9/9,501 MEMO~,~! 1~ ~ 89-6/1252 2rJ0 DATE ~ ~ `~~~~J~ ~ f ~/(J , ~: 1 2 5 2 0 0 0 6.0 ~: 9 9 L 4 ~~~ 6 2 2 7 ~~~ 1 5 5 6 ~~• 0 2 5 0 • ,~ t ~,s. ~ ~ ~ s ~~~s ~ ~ TRANSMITTAL LETTER .CHECKLIST ~I ~~ ~ u' ~~ ~b^~, ~ ~~ 1`~WELL NAME ~ - c~ i~l~ ~~ ~ ~ ~ ~~ ~~~ ~ ~G Development Service Exploratory Stratigraphic Test r Jam-- iCGrJ Gone ~ on a Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE 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. j ~~ f. ~ ~~ GrQ/t/~~ t7't~~ 1/05/06 ody\transmitta _checklist C~~JJ ._~- ,~ ~ • ^^ , ~ ~ m ° d a , , o a ; ~ i ~ ~ ~ ; ; c ~ a i i , , ~ ~ ~ ~ ; ~ , ( . o ; ~, ; ~ ;~ ~ ~ ; 0 ~ o , : , , j ~ : ' m~ ~ ~~ ~~ ~~ ~ ~ ~ ~~ ~~ ~~ ~, ~ ~ ~ ~ ~~ Z ; , ~ ~ ; ; W ~ M, a~ ~ N a •N °~'' rn, °: ~ ~ ~ y M f 6 ~ ~ ~ ~ ~ " ' f0' N O, , U, 9, ~' ! ~ ~ w , ~~ , y~ y' ~ y~ y~ y' Vh y~ U? fM ~. ~: ~, ~ ~ a~ a~ y,. y' . ~ ~ y' ~ y' ~ ~, a. a. a. a; ' a, a: a. y' a; ~, y~ ~ y. VY ~, ~: UA ~ f/A y~ VA y~ y~ ~ a. ~: ~, ~: ~, ~ y~ ~ a, O, a, a, ~ a, Q } : ~: , : , ~-,} ~-,},~-,r:}: ~-:}. }~-~z z:zZ~ z~z z~ z~}~ } ~-'}' }'z }~~-}~''~'' } z' z z' ~z' z o' ~ ~ ~ ` °% ; ~ f6 U ~ ~ ~ W, Q: ~ ~ , , ~ ~ ~ ~ C. 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C 7 O 7 y O O T w~ 'd. f0 G C N Y N I ~ O O O f6 GY C N f0 I6, O ~ f0 (0 f0 y Q a: T O p~ °, N ,y C y ~ ~ ~ Or ~ ~ ~ , ~, t: L• ~~ ~ ~. ~, 7 y , -O ' j C' C d, W w. f 6, !=: t ~ ~ ' ~ : ~~ ~ ~ V 3 C 0. a . -+ f0: ' , : ' ' C: a, ._,: f6. G pi, ~ - . -+ -O, O, 'O: N, N N. ~~ ' w~ ° ~ M. ~ o ` y O, y. N. N~ . y O w' 0 O 3 ~ ~ ~ ° O w z ° a ~ y, ~, v. ~, N: ~, ' ~ ~: 3. ' 3, ~: d, ~: ..: ~ ~ ~, ~ - •. o a ~ , ~ Q ~, ~ o: , a o a> ~: rn c , a o Z y , o U O_ ° 4 .O o v. >, o, c w, : f0 N ~ f6 ° C"} °, o: O: O v, N a o, a °, E °, ~, o c Y o y, ~ °. O~ - : o, : y, a: E~ d E~ .L-P t6 , O , I N n c , °, ~ y, O , C. . f' I N L, 4 ~ N N N ~ N N. g ~ N ' O Oi 7 Q C ~ ~, w~ Q °' ~ .y.., O .y., - C ° f0 N e O N' N 'O ~ C U. O ~ OS ' N :_+ ~ ~ ° c: N t, oj) ~I U, O, ~ aS ,~ ~, ~ O, O, O: l0' N 4 .N ..' r O, f0. ~ G - N ~ p, t0, f O ~ ` y f6~ N , L~ a ~ ~ 'O' 2. C, N, ~ -O, O: •y, Q ~ OI ~ Y ~ ~ ~: o. o. m Nr x m y: . m d 3: c v' ~ a ~ ~ a' • a, a r > c. ~ o: 'a, a w a ~ o oo' I ~ ~ y c >, :o m ~ ° ~ '.` m' .a. E v -°, v: v c :: :: ::' a o n m L .Q = a: w 'v ~ w: ;~ N a ~ a, : ~' .N :° L, 3 m v o uyi' c' o °: o m' ~ c. ca c' ~ ~ ~ X I-- ar ~ ' ~ `° c v ° o ~ ~ 0 ~ c 3 LL ' ~ v o; ~ m m; ~ :? _ :: ~ ~ v m n E' ~ , o c ~, ~ - ' w t/~ a c m c i d o' o o ~ ~ m, 0 ° y o , a °, ~ a; ~ o. ~ °~ > o >' 3 ~ m ° ~' m, ~ ,~ 3' ° o °s w w: ~ , y m a ~ °, ' m ~ w Y ml ~; m c ~' o ~ ~ a' n 4 ~, € y' 3 d U m I o; ~ ~: ~, ~' .~ v ~ ~ ~ c O O, ~, ° ~ ~ m. m ~, m; .. o. p a ~ ~-; ~ O ~ ~; ~: ~: ~ m O a; a; , a U a ~, ~ a U U U U U , U a =, , a, - o m, m, U, ~, -: ~, ~ a: ° m, m, U, , , , , , , . , , , , , , , , ~ tV ~ O N M V ~ fD aD O O N M et to c0 I~ O O O N M d': ~ c° I~ a0 O O ~ N M_ d' tf) t° f~ 00 O) ___ _ N N ~N N N N N N N N M M M_ M M M M M M M U U ~ .. y O C ~ _ O N ON R N C U O_ N 81 N N y ui m O J N J ~ L U ~ N i~ Q,a ~ o,U ° U a a ~ w a~ 1 °' a~ • Well History File APPENDIX • Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify Tending information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically organize this category of information. ~ ~ 16-06b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 06 08:00:46 2008 Reel Header Service name .............LISTPE Date . ...................08/05/06 0ri9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/05/06 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS Lis writing Library. scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~~~"UG( MWD RUN 1 w-0004265592 C. COCHRAN D. MASKELL 16-066 500292058402 BP Exploration (Alaska), Inc. Sperry Drilling Services 06-MAY-08 MWD RUN 2 MWD RUN 3 w-0004265592 W-0004265592 C. COCHRAN A. SHANAHAN D. MASKELL D. MASKELL 24 lON 15E 1893 1121 66.50 38.00 Page 1 ~i~asft 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: File Header 16-06b.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 6712.0 6.125 7.000 11600.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 16-06 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 6712'MD/6385'TVD. 4. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUNS 1-3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). RUN 3 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR4). UPHOLE TIE-IN SGRC DATA ACQUIRED WHILE RIH AFTER A SHORT TRIP DURING RUN 2 WERE MERGED WITH RUN 1 MWD DATA. 6. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A CASED HOLE GAMMA RAY LOG RUN IN 16-06 ON 7 MAY 1981. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 22 APRIL 2008, AS AUTHORIZED BY COLE ABEL (BP). THIS SHIFTED DATASET IS THE PDCL FOR 16-066. 7. MWD RUNS 1-3 REPRESENT WELL 16-06B WITH API#: 50-029-20584-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12100'MD/9172'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. 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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. Page 2 16-06b.tapx Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 6564.5 12056.5 ROP 6725.0 12112.5 RPx 11602.5 12063.5 RPS 11602.5 12063.5 RPM 11602.5 12063.5 RPD 11602.5 12063.5 FET 11602.5 12063.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 6559.0 6550.0 6560.5 6551.5 6563.5 6556.5 6567.5 6560.0 6572.5 6565.0 6585.0 6575.5 6601.5 6592.0 6611.0 6601.5 6631.0 6623.0 6652.0 6644.5 6653.0 6645.5 6657.5 6648.5 6663.0 6653.5 6668.0 6659.5 6680.0 6670.5 6681.5 6673.0 6691.5 6683.5 6701.0 6694.5 6707.0 6699.5 6713.0 6706.0 12107.0 12100.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 6550.0 6740.0 MwD 2 6740.0 11605.0 MwD 3 11605.0 12100.0 REMARKS: MERGED MAIN PASS. Page 3 ~ ~ 16-06b.tapx Data Format specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units. .. .. ..... Datum specification Block sub-type ...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 6564.5 12112.5 9338.5 11097 6564.5 12112.5 RPD MWD OHMM 2.4 2000 77.3231 923 11602.5 12063.5 RPM MWD OHMM 1.99 1905.35 22.2918 923 11602.5 12063.5 RPS MWD OHMM 1.96 881.58 7.6497 923 11602.5 12063.5 RPX MWD OHMM 1.07 22.65 6.42387 923 11602.5 12063.5 FET MWD HOUR 0.47 79.26 5.08506 923 11602.5 12063.5 GR MWD API 21.58 528.02 127.555 10985 6564.5 12056.5 ROP MWD FT/H 0.98 316.87 68.8275 10776 6725 12112.5 First Reading For Entire File..........6564.5 Last Reading For Entire File...........12112.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/06 Maximum Physical Record..65535 File Type ................L0 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.......08/05/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLi6.001 Comment Record Page 4 ~.~J 16-06b.tapx FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6550.0 6693.5 ROP 6712.5 6740.0 LOG HEADER DATA DATE LOGGED: 10-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6740.0 TOP LOG INTERVAL (FT): 6712.0 BOTTOM LOG INTERVAL (FT): 6740.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 6712.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 80.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 1500 FLUID LOSS (C3): 8.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: 116.000 117.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Page 5 16-06b.tapx Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 • Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MwD010 API 4 1 68 4 2 RoP MwD010 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6550 6740 6645 381 6550 6740 GR MWDO10 API 33.73 70.08 51.6121 288 6550 6693.5 ROP MWDO10 FT/H 1.03 22.71 8.97571 56 6712.5 6740 First Reading For Entire File..........6550 Last Reading For Entire File...........6740 File Trailer service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/06 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6694.0 11569.0 ROP 6740.5 11605.0 Page 6 i ~ 16-06b.tapx LOG HEADER DATA DATE LOGGED: 16-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11605.0 TOP LOG INTERVAL (FT): 6740.0 BOTTOM LOG INTERVAL (FT): 11605.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 33.6 MAXIMUM ANGLE: 63.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 6712.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 58.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1000 FLUID LO55 (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 160.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 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 Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MwD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 Page 7 16-06b.tapx ;~ First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6694 11605 9149.5 9823 6694 11605 GR MWD020 API 24.01 420.54 129.595 9751 6694 11569 ROP MWD020 FT/H 0.98 316.87 71.4193 9730 6740.5 11605 First Reading For Entire File..........6694 Last Reading For Entire File...........11605 File Trailer Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/06 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11569.5 12044.0 FET 11590.0 12051.0 RPM 11590.0 12051.0 RPS 11590.0 12051.0 RPx 11590.0 12051.0 RPD 11590.0 12051.0 ROP 11605.5 12100.0 LOG HEADER DATA DATE LOGGED: 21-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12100.0 TOP LOG INTERVAL (FT): 11605.0 Page 8 16-06b.tapx BOTTOM LOG INTERVAL (FT): 12100.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 50.7 MAXIMUM ANGLE: 56.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10603445 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11600.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 48.0 MUD PH: 10.4 MUD CHLORIDES (PPM): 7600 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .740 60.0 MUD AT MAX CIRCULATING TERMPERATURE: .290 164.3 MUD FILTRATE AT MT: 1.080 60.0 MUD CAKE AT MT: 1.020 60.0 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 Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 Page 9 16-06b.tapx c: First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11569.5 12100 11834.8 1062 11569.5 12100 RPD MWD030 OHMM 2.4 2000 77.3231 923 11590 12051 RPM MWD030 OHMM 1.99 1905.35 22.2918 923 11590 12051 RPS MWD030 OHMM 1.96 881.58 7.6497 923 11590 12051 RPX MWD030 OHMM 1.07 22.65 6.42387 923 11590 12051 FET MWD030 HOUR 0.47 79.26 5.08506 923 11590 12051 GR MWD030 API 21.58 528.02 129.286 950 11569.5 12044 ROP MWD030 FT/H 1.59 125.61 46.7395 990 11605.5 12100 First Reading For Entire File..........11569.5 Last Reading For Entire File...........12100 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/06 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/05/06 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/05/06 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. Scientific Technical Services Library. scientific Technical services Page 10
